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Home My WebLink About203-133C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-07-716_16038_KRU_1B-101_VividLeakDetect_Transmittal.docx DELIVERABLEDISCRIPTION Ticket # Field Well # API # Log Description Log Date 16038 KRU 1B-101 50-029-23173-00 VIVID Leak Detect 7 & 16-Jul-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn:NaturalResourcesTechnician 333W.7thAve.,Suite100 Anchorage,Ak.99501Ͳ3539 DeliveredBy:CPAISharefile ___________________________________________________________________ DatereceivedSignature ____________________________________________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 203-133 T40679 7/24/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.24 09:35:05 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. 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From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1B-101 (PTD 203-133) Report of OA over Operating Pressure Limit Date:Tuesday, May 6, 2025 11:35:51 AM Attachments:1B-101 90 Day TIO Plot & Schematic.pdf From: Well Integrity Engineer CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, May 6, 2025 11:20 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 1B-101 (PTD 203-133) Report of OA over Operating Pressure Limit Well Name: 1B-101 Facility: CPF1 PTD: 203-133 Well Type: Prod AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: OA Exceeded OPL Maximum Pressure (if applicable): 1310 Date of Occurrence (if applicable): 5/5/25 Victoria, KRU 1B-101 (PTD 203-133) was reported by Operations yesterday 5/5/25 to have an OA pressure of 1310 psi. The 10 3/4” 40.5 lb/ft, J-55 has a burst rating of 3130 psi (45% burst rating = 1409 psi). The well was immediately shut in yesterday once the OA pressure spike was observed. The OA pressure fell back below the operating pressure limit directly after shutting in the well. CPAI plans conduct diagnostics. These diagnostics will inform if IA x OA communication exists and how the well should be repaired or secured. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1B-101 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Opened sliding sleeve, Set jet pump 1B-101 1/17/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTILATERAL WELL: B-SAND (1B-101), D-SAND (1B-101L1) 9/8/2003 triplwj 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 34.7 148.0 148.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.3 3,080.4 2,199.7 40.50 J-55 BTC WINDOW D-SAND 8 6.00 6,867.0 6,877.0 3,662.7 29.70 PRODUCTION 7 5/8 6.87 27.1 7,388.9 3,730.3 29.70 L-80 BTC-M LINER B-SAND 4 1/2 3.96 6,882.2 12,230.0 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.1 Set Depth … 6,129.6 Set Depth … 3,447.5 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 23.1 23.1 0.00 Hanger 10.750 4 1/2" x 11" Vault Gen 1 concentric hanger w/ 4.909 MCA top threads Vault Gen 1 3.893 3,538.7 2,391.0 65.32 Mandrel – GAS LIFT 6.376 4.5" x 1" KBMG GLM SLB KBMG 3.865 5,878.9 3,354.8 67.13 Mandrel – GAS LIFT 6.376 4.5" x 1" KBMG GLM SLB KBMG 3.865 5,946.3 3,380.6 67.88 Sleeve - Sliding (Opened 01/11/2024) 5.493 4.5" x 3.813" Baker NEXA-2 CMU sliding sleeve (Opened 1/11/2024) Baker CMU Sliding Sleeve 3.813 6,012.6 3,405.2 68.65 Sensor - Discharge Gauge 5.685 4 1/2" 12.6# L-80 Halliburton Opsis Gauge HES Opsis Gauge 3.920 6,036.5 3,413.8 68.92 Nipple - X 4.990 4 1/2" x 3.813" X/Nipple HES 3.813" X Nipple 3.813 6,100.8 3,437.0 68.78 Locator 5.500 Baker locater 5.5" OD Baker Locator 3.870 6,102.6 3,437.7 68.78 Seal Assembly 4.750 Baker 192-47 seal assembly (3.90' from fully located) Baker 192-47 Seal Assembl y 3.870 Top (ftKB) 6,095.7 Set Depth … 6,876.4 Set Depth … 3,662.6 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 6,095.7 3,435.2 68.79 Packer - Liner 6.380 5 1/2" x 7 5/8" Baker ZXP LTP W/10.98' x 5.75" tie back sleeve Baker ZXP LTP H29645 0131 4.920 6,115.3 3,442.3 68.74 SBE 6.250 Baker 190-47 Sealbore Extension W/18.70' x 4.75" seal bore 190-47 SBE H02433 17A1 4.750 6,188.8 3,468.6 69.38 Nipple - X 4.500 4 1/2" x 3.813" X-Nipple Halliburt on 3.813" X/Nipple 3.958 6,839.8 3,653.5 75.46 Hanger 4.500 Baker LEM #2 (Above Hook Hanger) (H289180004/5) Baker LEM II H28918 0004/5 3.910 6,874.9 3,662.2 75.66 Wireline Guide 5.250 4.5" Muleshoe WL Re-Entry Guide 3.940 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) 5,944.0 3,379.7 67.86 SLIP STOP Set slip stop on jet pump. 1/17/2024 2.250 5,946.0 3,380.5 67.88 JET PUMP Set jet pump w/ gauges on 3.81" X-lock. (11D ratio, OAL 114" SN # PH-1123) PH- 1123 1/17/2024 0.000 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) 3,538.7 2,391.0 65.32 1 GAS LIFT DMY BK 7.69 11/24/2023 SLB KBMG 1.000 5,878.9 3,354.8 67.13 2 GAS LIFT DMY BK 7.69 0.0 12/7/2023 SLB KBMG 0.000 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) 6,882.2 3,664.0 75.68 PACKER 6.690 BAKER SC-1R RETRIEVABLE PACKER w/ EXTENSION 4.000 6,887.0 3,665.2 75.69 EXTENSION 5.560 BAKER EXTENSION 4.890 12,196.5 3,713.9 91.66 BUSHING 4.500 BAKER PACKOFF BUSHING 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,480.0 12,196.0 3,734.4 3,713.9 WS B, 1B-101 9/8/2003 16.0 SLOTS SLOTTED LINER, 0.25" x 2.5" slots, alternating blank/slotted 31' joints w/16 shots per slotted joint 1B-101, 1/18/2024 8:41:42 AM Vertical schematic (actual) LINER B-SAND; 6,882.2- 12,230.0 SLOTS; 7,480.0-12,196.0 PRODUCTION; 27.1-7,388.9 WINDOW D-SAND; 6,867.0- 6,877.0 LINER D-SAND; 6,847.1- 12,172.6 Tubing - Pup Joint; 6,179.0 Seal Assembly; 6,102.6 Packer - Liner; 6,095.7 Nipple - X; 6,036.5 Sensor - Discharge Gauge; 6,012.6 JET PUMP; 5,946.0 Sleeve - Sliding (Opened 01/11/2024); 5,946.3 SLIP STOP; 5,944.0 Mandrel – GAS LIFT; 5,878.9 Mandrel – GAS LIFT; 3,538.7 SURFACE; 28.3-3,080.4 CONDUCTOR; 34.7-148.0 Hanger; 23.1 KUP PROD KB-Grd (ft) 34.70 RR Date 8/31/2003 Other Elev… 1B-101 ... TD Act Btm (ftKB) 12,230.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292317300 Wellbore Status PROD Max Angle & MD Incl (°) 92.86 MD (ftKB) 7,803.28 WELLNAME WELLBORE1B-101 Annotation Last WO: End Date 11/26/2023 H2S (ppm) 10 Date 8/12/2016 Comment SSSV: WRDP TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop Kuparuk 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 1A-15 50-029-20711-00 182017_1A-15_iProf_02Jun2022 1A-22 50-029-22127-00 191003_1A-22_RBP-LSL_22June2022 191003_1A-22_SBHPS-RBP_09June2022 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 1B-14 50-029-22452-00 194030_1B-14_CHC_15Mar2022 194030_1B-14_RCT Cutter_24Feb2022 194030_1B-14_UPCT Cutter_20Jun2022 194030_1B-14_Whipstock_13Apr2022 19430_1B-14_CHC_21Mar2022 1C-09 50-029-20859-00 182185_1C-09_IPROF_15Jan2023 1C-133 50-029-23013-00 201077_1C-133_RBP_07Apr2022 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 1of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38308 T38309 T38310 T38312 T38311 T38274 T38276 T38314 T38315 T38316 2/29/2024 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:11:35 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U WSAK 1B-101 JBR 01/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Bag Failed to test on 3 1/2" joint. It had to be changed out. I did not witness the retest on the new bag but was sent the chart to look at. CM #1 FP, it had to be serviced to pass. FSV Misc. EUE FOSV. BOP Misc.: 2 each 2 1/16” 5K gate valves on test spool located on BOP stack below the lower rams. Choke Misc.: 3” Demco valve located on the downstream of the manifold. Test Results TEST DATA Rig Rep:HansenOperator:ConocoPhillips Alaska, Inc.Operator Rep:Barr Rig Owner/Rig No.:Nordic 3 PTD#:2031330 DATE:11/18/2023 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopRCN231122170716 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 20 MASP: 446 Sundry No: 323-340 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 1 P 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 none NA Annular Preventer 1 13 5/8"F #1 Rams 1 2 7/8 x 5 1/2 P #2 Rams 1 CSO P #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 none NA BOP Misc 2 2 1/16" 5000 P System Pressure P3000 Pressure After Closure P1750 200 PSI Attained P22 Full Pressure Attained P107 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P17 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9999 9 9 9 9 9 9 9 9 9 7HVWFKDUWIRUUHSDLUHG$QQXODU3UHYHQWHUQRWDYDLODEOH-5HJJ F FP Bag Failed did not witness the retest ss ss CM #1 FP, 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: Replace Tubing 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 12230'feet None feet true vertical 3713' feet None feet Effective Depth measured 12230'feet 6096', 6882'feet true vertical 3713' feet 3435', 3664'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" 4-1/2" L-80 L-80 6130' 6876' 3448' 3663' Packers and SSSV (type, measured and true vertical depth)6096' 6882' 3435' 3664' 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: West Sak 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: 3080' 2200' Burst CollapseCasing 6877' 3730' 6867' 7389' 5348' 4-1/2" 12230' 3713' 3052' 148'Conductor Surface Window D Sand 16" 10-3/4" 113' Production B Sand Liner 10' 7362' measured TVD 8' 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-133 50-029-23173-00-00 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: ADL0025648 Kuparuk River Field/ West Sak Oil Pool KRU 1B-101 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) Gas-Mcf MDSize 148' Well Shut-In 323-340 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A PACKER: Baker ZXP LTP PACKER: SC-1R SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597CTD Engineer 7480-12196' 3734-3714' 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 2:34 pm, Dec 18, 2023 Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this document Location: Date: 2023.12.18 10:55:21-09'00' Foxit PDF Editor Version: 13.0.0 Page 1/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/8/2023 00:00 11/8/2023 08:00 8.00 MIRU, MOVE MOB P Pull sub off of well. Clean up around well. Set mats on 1B-101. Stage wellhead equipment in cellar. Hang tree. Spot sub over well. 11/8/2023 08:00 11/8/2023 10:30 2.50 MIRU, MOVE MOB P Get spotted over well, Have to jack up and shim 11/8/2023 10:30 11/8/2023 11:30 1.00 MIRU, MOVE RURD P Berm up cellar, Set cuttings box. Install cutting chute 11/8/2023 11:30 11/8/2023 12:00 0.50 MIRU, MOVE RURD P Take on 8.5 PPG seawater. Rig up manifold in cellar, Hardline crew making up TT piping. 11/8/2023 12:00 11/8/2023 14:30 2.50 MIRU, WELCTL RURD P Rig Accept 12:00, R/U TT line, Squeeze manifold 11/8/2023 14:30 11/8/2023 15:00 0.50 MIRU, WELCTL RURD P Pressure test TT line, Squeeze manifold 2500 PSI 11/8/2023 15:00 11/8/2023 15:30 0.50 MIRU, WELCTL RURD P Initial Pressures 60/vac/125. Bleed off tubing to zero with no flow. ON HIGHLINE 15:00 11/8/2023 15:30 11/8/2023 16:30 1.00 MIRU, WELCTL KLWL P PJSM, Line up down IA pump 200 BBls seawater down IA @ 4 BPM, Pressure 63 PSI 11/8/2023 16:30 11/8/2023 17:00 0.50 MIRU, WELCTL KLWL P Swap over to pump down tubing, Pump 115 BBls down tubing, Final circ pressure 63 PSI 11/8/2023 17:00 11/8/2023 17:30 0.50 MIRU, WELCTL OWFF P OWFF for 30 Min. Well on vac. 11/8/2023 17:30 11/8/2023 18:00 0.50 MIRU, WELCTL MPSP P Install HP BPV. 11/8/2023 18:00 11/8/2023 18:30 0.50 MIRU, WELCTL PRTS P Perform rolling test on BPV @ 5 BPM, 58 PSI. For 10 Min. Check top of BPV, dry no fluid on top of it. 11/8/2023 18:30 11/8/2023 19:00 0.50 MIRU, WHDBOP RURD P R/D squeeze manifold. R/U circ hose T/ IA to feed well during N/D, N/U & BOP test. Check IA well pushing gas. 11/8/2023 19:00 11/8/2023 21:30 2.50 MIRU, WHDBOP NUND P N/D tree & adaptor. Inspect hanger neck threads. Set tree test plug. Function LDS. Filling hole w/ 50 Bbls every 30 Min @ 5 BPM. Reducing T/ 40 Bbls every 30 Min @ 5 BPM to keep IA on a vac. 11/8/2023 21:30 11/9/2023 00:00 2.50 MIRU, WHDBOP NUND P N/U BOP. Install dutch riser locking ring. Install flow box and flow nipple. Filling hole w/ 30 Bbls every 30 Min @ 5 BPM to keep IA on a vac. 11/9/2023 00:00 11/9/2023 02:00 2.00 MIRU, WHDBOP NUND P Cont N/U BOP. N/U choke & kill lines. Filling hole w/ 25 Bbls every 1/2 hour to keep IA on a vac. 0.0 0.0 11/9/2023 02:00 11/9/2023 05:00 3.00 MIRU, WHDBOP WAIT T Phase 3 weather called field wide. Suspend N/U activities. Wait on weather. Reduce hole fill rate to 20 Bbls every 1/2 hour to attempt to conserve fluid. Greased HCR's and manuals. 0.0 0.0 11/9/2023 05:00 11/10/2023 00:00 19.00 MIRU, WHDBOP WAIT T Working hole fill down to 5 BBls every 30 minutes. Maintaining vac on well. Phase 3 condition still in effect. Take on 190 Bbls of fresh water into pits. 0.0 0.0 11/10/2023 00:00 11/10/2023 05:00 5.00 MIRU, WHDBOP WAIT T Wait on weather. @12:30 before filling hole slight flow observed from IA. Increase fill rate to 10 Bbls every 1/2" hour @ 5 BPM, keep IA on vac. Weight up fresh water in pits T/ 8.5 PPG. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 2/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/10/2023 05:00 11/11/2023 00:00 19.00 MIRU, WHDBOP WAIT T Wait on weather. Continue filling IA every 1/2 hour. 0.0 0.0 11/11/2023 00:00 11/11/2023 04:30 4.50 MIRU, WHDBOP WAIT T Wait on weather. Continue filling IA every 1/2 hour. Phase 3 lifted at 04:30 Hrs 0.0 0.0 11/11/2023 04:30 11/11/2023 05:30 1.00 MIRU, WHDBOP NUND P Complete N/U BOP. 0.0 0.0 11/11/2023 05:30 11/11/2023 15:15 9.75 MIRU, WHDBOP BOPE P Fill stack, Fluid pack lines. Attempt to get shell test. Leaking grey loc, Replaced whitey valve on top drive testing XO. Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBRs & annular w/ 4 ½ & 3 1/2" Test joint. Did not test 7" LPR, Tag out of service. Test 3 1/2" IF FOSV & dart. Test 4 1/2" EUE FOSV. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Perform accumulator test. Initial pressure=3025 PSI, after closure=1650 PSI, 200 PSI attained =15 sec, full recovery attained =129 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 14 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Austin McCloud 0.0 0.0 11/11/2023 15:15 11/11/2023 15:30 0.25 MIRU, WHDBOP BOPE T Test 2" rig floor Demco kill valve MM #13, failed initial test. Was rebuilt. Passed retest. 0.0 0.0 11/11/2023 15:30 11/11/2023 16:30 1.00 MIRU, WHDBOP RURD P B/D, R/D test equipment 0.0 0.0 11/11/2023 16:30 11/11/2023 18:00 1.50 MIRU, WHDBOP RURD P R/U HES spooling unit & tubing handling equipment. 0.0 0.0 11/11/2023 18:00 11/11/2023 18:15 0.25 MIRU, WHDBOP MPSP P Pull tree test dart & BPV. Install side outlet isolation sleeve. 0.0 0.0 11/11/2023 18:15 11/11/2023 18:30 0.25 COMPZN, RPCOMP RURD P B/D, R/D circ hose off of IA. Install mouse hole. 0.0 0.0 11/11/2023 18:30 11/11/2023 19:15 0.75 COMPZN, RPCOMP RURD P M/U landing joint. Set 10K down. BOLDS. 0.0 0.0 11/11/2023 19:15 11/11/2023 19:30 0.25 COMPZN, RPCOMP PULL P Pull hanger off seat @ 225K. PUW- 120K. Pull hanger T/ RF @6081'. 6,115.0 6,081.0 11/11/2023 19:30 11/11/2023 20:30 1.00 COMPZN, RPCOMP PULD P Terminate tec wire & SS control line. Break hanger off. Hanger has pitting and will need to be replaced. L/D landing joing. Filling hole w/ 15 Bbls every 30 Min. 6,081.0 6,081.0 11/11/2023 20:30 11/12/2023 00:00 3.50 COMPZN, RPCOMP PULL P L/D 4 1/2" completion F/ 6081' T/ 3975', spooling up Tec wire & SS control line. PUW=120K. 6,081.0 3,975.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 3/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2023 00:00 11/12/2023 05:00 5.00 COMPZN, RPCOMP PULL P Cont L/D 4 1/2" completion F/ 3975' T/ 800', spooling up Tec wire & SS control line. PUW=80K. At joint # 102 OOH clamp started showing heavy corrosion, clamps were split and rode up out of hole on clamp below. Clamps missing from # 138 - # 149. On #138 pulled several hundred foot of control line freely with spooler, found parted control line. Got clamps back on # 149 & #150. Regained control of control line on # 150, pulling pipe with control line but no clamps T/ # 167. Over pull 8K, wire stopped moving up hole. Stop and consult w/ town. 3,975.0 800.0 11/12/2023 05:00 11/12/2023 08:00 3.00 COMPZN, RPCOMP WAIT P Start working current plan forward to make e-line cut in tubing just below tree. Mobilize Ak E-line. WelTec is available with cutter. Start mobilization of additional BOT contingency tools. Maintain hole fill schedule 15BBl/30 Min. 800.0 800.0 11/12/2023 08:00 11/12/2023 11:00 3.00 COMPZN, RPCOMP FISH P E-line and weltec to be on location ~11:00. Call out wireline stem and magnets. Attempt to pull clamps from well. Call out for stronger magnets and wireline grabs. No sucess with magnets. Start pulling clamps loose with grabs. Recover 26 clamps. 800.0 800.0 11/12/2023 11:00 11/12/2023 12:00 1.00 COMPZN, RPCOMP FISH P Consult with town. Pull next joint. Wad of clamps wrapped with control line to floor. Grab with shepards hooks. Remove from well Recovered 2 more clamps with control line 800.0 770.0 11/12/2023 12:00 11/12/2023 18:00 6.00 COMPZN, RPCOMP PULL P Continue fishing clamps and pulling completion T/ sufrace. L/D total of 193 Joints & 17.21' cut joint. Clean cut. Total clamps recovered 197 ea Cannon clamps. 8 ea Half clamps. Believe we have 1 ea Half clamp left in hole. 770.0 0.0 11/12/2023 18:00 11/12/2023 20:30 2.50 COMPZN, RPCOMP RURD P R./D HES spooling unit & tubing handling equipment. Clean and clear RF and pipe shed. Remove clamps, pins and tubulars from rig. 0.0 0.0 11/12/2023 20:30 11/12/2023 21:00 0.50 COMPZN, RPCOMP MPSP P Install wear bushing. 7 5/8" ID. 0.0 0.0 11/12/2023 21:00 11/12/2023 22:00 1.00 COMPZN, RPCOMP SVRG P Service rig. Grease draw works, TD, blocks. 0.0 0.0 11/12/2023 22:00 11/13/2023 00:00 2.00 COMPZN, RPCOMP CLEN P Clean RF, Mobilize BHA #1 tools & DC's to pipeshed. 0.0 0.0 11/13/2023 00:00 11/13/2023 02:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #1 RCJB, boot baskets & magnets T/ 247', SOW=49K. 0.0 247.0 11/13/2023 02:00 11/13/2023 07:15 5.25 COMPZN, RPCOMP PULD P PUDP F/ 247' T/ 6003', PUW=125K, SOW=71K. 247.0 896.0 11/13/2023 07:15 11/13/2023 08:30 1.25 COMPZN, RPCOMP TRIP P Set down to 15K. Work 3 times. PUW=125K Kelly up, pump 4 BPM @420 PSI. 10 RPM 5400Lb/Ft torque. Walk right through. Shut down pumps continue in to 6080 6,003.0 6,080.0 11/13/2023 08:30 11/13/2023 10:15 1.75 COMPZN, RPCOMP TRIP P P/U next stand. Drop 7/8" ball to RCJB. Kelly up, continue in to 6115' @ 10 BPM @2700 PSI. Wash down over stub. Recipe three times with viscous fluid. 6,080.0 6,115.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 4/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2023 10:15 11/13/2023 14:15 4.00 COMPZN, RPCOMP TRIP P 6080', Shut down pump. B/D top drive. POOH. PUW=125K 6,115.0 247.0 11/13/2023 14:15 11/13/2023 15:45 1.50 COMPZN, RPCOMP BHAH P At collars, lay down two stands of collars. Pull BHA to floor. Magnets full, More pieces in RCJB and boot baskets. POOH. Retrieve 50# of metal on string magnets including 63 pins. Recovered 1/2 clamp in RCJB. .Clean up BHA to re run. 247.0 0.0 11/13/2023 15:45 11/13/2023 16:45 1.00 COMPZN, RPCOMP BHAH P P/U BHA #2, RCJB, Boot baskets, and magnet. 0.0 247.2 11/13/2023 16:45 11/13/2023 21:00 4.25 COMPZN, RPCOMP TRIP P Trip in well, BHA #2 RCJB #2 247.2 6,084.0 11/13/2023 21:00 11/13/2023 21:30 0.50 COMPZN, RPCOMP FISH P Kelly up stand #64, PUW=125K, SOW=71, 10 RPM, 6K Torque, Start vis fluid down, Ball on seat. Trip in 6113, Lightly tag TOF, 10 BPM @ 1690 PSI. Recipe twice with rotary 30', Recipe once more no rotary tag @ 6115 w/5K down with pump pressure increase to 2350. . PUH., S/D pump. 6,084.0 6,113.0 11/13/2023 21:30 11/13/2023 22:00 0.50 COMPZN, RPCOMP TRIP P POOH F/ 6113' T/ 6120'. PUW=125K, SOW=ssK. 6,113.0 5,620.0 11/13/2023 22:00 11/14/2023 00:00 2.00 COMPZN, RPCOMP SLPC P PJSM, Slip and cut 60' of drilling line 5,620.0 5,620.0 11/14/2023 00:00 11/14/2023 03:00 3.00 COMPZN, RPCOMP TRIP P POOH F/ 6125 T/ 247", PUW=118K 5,620.0 247.0 11/14/2023 03:00 11/14/2023 04:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #2 F/ 247' T/ sufrace, PUW=47K. Inspect magnets & RCJB. Retrieve 10# of metal on string magnets including 10 pins. Recovered 1/2 clamp in RCJB. Clean up BHA to re run. 247.0 0.0 11/14/2023 04:00 11/14/2023 05:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #3 RCJB #3 T/ 247', SOW- 49K. 0.0 247.0 11/14/2023 05:00 11/14/2023 06:00 1.00 COMPZN, RPCOMP TRIP P RIH F/ 247' T/ 2320', SOW=55K. 247.0 2,320.0 11/14/2023 06:00 11/14/2023 07:00 1.00 COMPZN, RPCOMP SFTY P Send hand up in derrick to know ice off of derrick. 2,320.0 2,320.0 11/14/2023 07:00 11/14/2023 08:30 1.50 COMPZN, RPCOMP TRIP P RIH F/ 2330' T/ 6084', PUW=127K, SOW=70K. 2,320.0 6,084.0 11/14/2023 08:30 11/14/2023 09:00 0.50 COMPZN, RPCOMP CIRC P K/U ball on seat for RCJB. Pump10 BPM, 1750 PSI. Rot @ 10 RPM, Free Tq = 6.2K. Wash & ream down and tag fish top @ 6116'. P/U 10'. Wash & ream down and re tag fish top. Kill rotarty. Circ total of 140 Bbls vis seawater chased by 40 Bbls seawater. PSI increased T/ 2350 PSI. 6,084.0 6,116.0 11/14/2023 09:00 11/14/2023 09:30 0.50 COMPZN, RPCOMP RURD P Rack back 1 stand T/ 6084'. B/D TD. 6,116.0 6,084.0 11/14/2023 09:30 11/14/2023 12:30 3.00 COMPZN, RPCOMP TRIP P POOH F/ 6084' T/ 247', PUW=127K. 6,084.0 247.0 11/14/2023 12:30 11/14/2023 14:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #3, Inspect magnets and RCJB. Reduced metal shavings on magnets. Increase metal in RCJB - 1 1/2 clamps, 6 pins, 15 hinges & 1 SS band recovered. 247.0 0.0 11/14/2023 14:00 11/14/2023 15:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #4, RCJB #4 T/ 247', SOW=49K, 0.0 247.0 11/14/2023 15:00 11/14/2023 17:00 2.00 COMPZN, RPCOMP TRIP P RIH F/ 247' T/ 6084'. PUW=126K, SOW=70K, ROT WT = 90K at 10 RPM, 6400# TQ 247.0 6,084.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 5/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/14/2023 17:00 11/14/2023 18:00 1.00 COMPZN, RPCOMP CIRC P Wash down F/6,084' T/6,116' Pump at 10 BPM 1500 PSI pimping Hi Vis sweep, tag stump at 6,116' with 10 RPM, pick up 5' off stump slack off tag again turn off rotarty, Pick up 5' chase Hi vis sweep with 2x DP vol at 8 BPM 2380 PSI 126K UP 70K DN 90K Rot 6400# TQ 6,084.0 6,116.0 11/14/2023 18:00 11/14/2023 21:00 3.00 COMPZN, RPCOMP TRIP P Blow down top drive POOH F/6,116' T/247' 6,116.0 247.0 11/14/2023 21:00 11/14/2023 21:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #4 Inspect magnets, boot baskets and RCJB Recover 1 pin from clamps on magnets, boot baskets and RCJB empty 247.0 0.0 11/14/2023 21:30 11/14/2023 22:00 0.50 COMPZN, RPCOMP BHAH P Clean clear rig floor Mobilize BHA #5 components to rig floor 0.0 0.0 11/14/2023 22:00 11/14/2023 22:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #5 5 3/4" overshot with sizing mill T/246' 0.0 246.0 11/14/2023 22:45 11/15/2023 00:00 1.25 COMPZN, RPCOMP TRIP P RIH F/246' T/3,300' 246.0 3,300.0 11/15/2023 00:00 11/15/2023 01:15 1.25 COMPZN, RPCOMP TRIP P RIH F/3,300' T/6,052' 126K UP 70K DN 90K at 30 RPM 7K TQ 3,300.0 6,052.0 11/15/2023 01:15 11/15/2023 01:45 0.50 COMPZN, RPCOMP FISH P Slack off engage fish @ 6,118' overshot depth, set DN 30K Pick up clean at 126K Rotate at 20 RPM 6200# TQ Rotate down to 6,123', turn off rotatry, slack off to 6,125' set DN 35K, Pick up to 6,115', slack off to 6,25' set DN 40K Pick up WT @ 130K See 40 PSI increase in pump pressure at 5 BPM from 470 PSI to 510 PSI 6,052.0 6,125.0 11/15/2023 01:45 11/15/2023 02:00 0.25 COMPZN, RPCOMP TRIP P POOH 2 stands to 5,990' 6,125.0 5,990.0 11/15/2023 02:00 11/15/2023 03:00 1.00 COMPZN, RPCOMP SVRG P Service top drive, drawworks and spinners Check derrick for ice build up remove as needed 5,990.0 5,990.0 11/15/2023 03:00 11/15/2023 06:00 3.00 COMPZN, RPCOMP TRIP P POOH F/5,990' T/246' 5,990.0 246.0 11/15/2023 06:00 11/15/2023 07:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #5, Seals recovered. 13..96' cut joint OAL 37.80'. Clean magnets & boot baskets . 246.0 0.0 11/15/2023 07:30 11/15/2023 08:00 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF and pipe shed. 0.0 0.0 11/15/2023 08:00 11/15/2023 08:45 0.75 COMPZN, RPCOMP BHAH P M/U BHA #6 Clean out w/ 6.75" string mill T/ 249', SOW=49K. 0.0 249.0 11/15/2023 08:45 11/15/2023 11:45 3.00 COMPZN, RPCOMP TRIP P RIH F/ 249' T/ 6086', PUW=129K, SOW=71K. 249.0 6,086.0 11/15/2023 11:45 11/15/2023 12:15 0.50 COMPZN, RPCOMP REAM P Wash @ 10 BPM, 800 PSI F/ 6086' tag PBR top @6141' w/ 10K down.. P/U 2' ROT @ 60 RPM, Free Tq= 8.5K. ROT=100K. Ream up T/ 6086' & back down 3 times. 6,086.0 6,086.0 11/15/2023 12:15 11/15/2023 12:30 0.25 COMPZN, RPCOMP RURD P B/D TD. 6,086.0 6,086.0 11/15/2023 12:30 11/15/2023 15:00 2.50 COMPZN, RPCOMP TRIP P POOH F/ 6086' T/ 249', PUW=129K 6,086.0 249.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 6/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/15/2023 15:00 11/15/2023 15:30 0.50 COMPZN, RPCOMP BHAH P Rack back DC's on BHA #6 F/ 249' T/ 64', PUW=49K. 249.0 64.0 11/15/2023 15:30 11/15/2023 16:00 0.50 COMPZN, RPCOMP SVRG P Service pipe handler on TD. 64.0 64.0 11/15/2023 16:00 11/15/2023 17:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #6 F/ 64' T/ surface 64.0 0.0 11/15/2023 17:00 11/15/2023 17:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #7 TST-3 test packer T/ 200' 0.0 200.0 11/15/2023 17:30 11/15/2023 21:45 4.25 COMPZN, RPCOMP TRIP P RIH F/200' T/6,129' 125K UP 70K DN 200.0 6,129.0 11/15/2023 21:45 11/15/2023 22:15 0.50 COMPZN, RPCOMP MPSP P Pick up single, tag PBR top at 6,139', P/U set packer at 6,136' bullnose depth, 6,130' COE 6,129.0 6,136.0 11/15/2023 22:15 11/15/2023 23:45 1.50 COMPZN, RPCOMP MPSP P Fill back side with 44 BBLS total seawater Let air/gas and oil come to surface 6,136.0 6,136.0 11/15/2023 23:45 11/16/2023 00:00 0.25 COMPZN, RPCOMP MPSP P Test 7 5/8" casing from 6,130' to surface to 3500 PSI F/30 min OA = 350 PSI at start OA = 600 PSI with 3500 PSI on casing 6,136.0 6,136.0 11/16/2023 00:00 11/16/2023 00:30 0.50 COMPZN, RPCOMP PRTS P Test 7 5/8" casing with TST 3 packer F/6,130' COE to surface for 30 min Start OA - 600 PSI IA = 3650 15 Min - OA = 600 IA = 3620 PSI 30 Min - OA = 600 PSI IA = 3610 PSI 6,136.0 6,136.0 11/16/2023 00:30 11/16/2023 01:00 0.50 COMPZN, RPCOMP MPSP P Bleed off pressure, open rams, pick up let elements relax on packer while blowing down lines Unset packer put in trip position, L/D single drill pipe 6,136.0 6,136.0 11/16/2023 01:00 11/16/2023 03:45 2.75 COMPZN, RPCOMP TRIP P POOH F/6,129' T/200' 6,129.0 200.0 11/16/2023 03:45 11/16/2023 04:15 0.50 COMPZN, RPCOMP BHAH P L/D BHA #7 Clean clear rig floor 200.0 0.0 11/16/2023 04:15 11/16/2023 04:45 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 11/16/2023 04:45 11/16/2023 06:30 1.75 COMPZN, RPCOMP BHAH P M/U BHA #8, MSC on a mud motor with a spear above for PBR Note function test motor/cutter at surface before RIH M/U BHA # * T/ 238', SOW=48K. 0.0 238.0 11/16/2023 06:30 11/16/2023 08:30 2.00 COMPZN, RPCOMP TRIP P RIH F/ 238' T/ 5973', PUW=120K, SOW=68K. 238.0 5,973.0 11/16/2023 08:30 11/16/2023 10:30 2.00 COMPZN, RPCOMP SLPC P Slip & cut 60' of drill line. 5,973.0 5,973.0 11/16/2023 10:30 11/16/2023 11:30 1.00 COMPZN, RPCOMP SVRG P Service rig. Change out saver sub. 5,973.0 5,973.0 11/16/2023 11:30 11/16/2023 12:30 1.00 COMPZN, RPCOMP TRIP P RIH F/ 5973' T/6102'. PUW=128K, SOW=73K. 5,973.0 6,106.0 11/16/2023 12:30 11/16/2023 13:30 1.00 COMPZN, RPCOMP FISH P K/U RIH set down 25K @ 6160'. P/U to bleed jars, slipped out. Repeat several times. P/U T/ 6130' 6,106.0 6,130.0 11/16/2023 13:30 11/16/2023 14:00 0.50 COMPZN, RPCOMP CIRC P Close annular and bullhead 150 Bbls down IA @ 10 BPM, 90 PSI. 6,130.0 6,130.0 11/16/2023 14:00 11/16/2023 14:30 0.50 COMPZN, RPCOMP FISH P RIH T/ 6164' set down 40K. P/U T/ 155K. Bleed jars. P/U T/ 175K. S/O T/ 125K. P/U T/ 175K. S/O T/ 145K. 6,130.0 6,164.0 11/16/2023 14:30 11/16/2023 15:00 0.50 COMPZN, RPCOMP CPBO P Circ @ 2.5 BPM, 560 PSI. Cut pipe @ 6164'. Tension fell off. 6,164.0 6,164.0 11/16/2023 15:00 11/16/2023 19:00 4.00 COMPZN, RPCOMP TRIP P Rack back stand & L/D working single. B/D TD. POOH F/ 6164' T/ 238', PUW=133K. 6,164.0 238.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 7/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/16/2023 19:00 11/16/2023 19:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #8 and fish Total fish recovered = 28.41' Pup JT cut above packer = 4.23' 238.0 0.0 11/16/2023 19:30 11/16/2023 20:15 0.75 COMPZN, RPCOMP BHAH P Clean clear rig floor Mobilize BHA #9 components to rig floor and organize pipe shed to pick up BHA 0.0 0.0 11/16/2023 20:15 11/16/2023 21:00 0.75 COMPZN, RPCOMP BHAH P M/U BHA #9 6 3/4" packer mill with 3.625" PRT on bottom 0.0 257.0 11/16/2023 21:00 11/17/2023 00:00 3.00 COMPZN, RPCOMP TRIP P RIH F/257' T/6,094' 135K UP 73K DN 257.0 6,094.0 11/17/2023 00:00 11/17/2023 00:30 0.50 COMPZN, RPCOMP MILL P Obtain milling perametrs 90 RPM 7.3K TQ 89K Rot WT 100 RPM 7K TQ 135K UP 73K DN Slack off with no rotary tag top of TBG stump at 6,166', set DN 5K Pick up to 6,160' Bring pumps on at 3 BPM 140 PSI Rotate at 100 RPM 7K TQ Slack off tag up on tubing stump @ 6,164' 6,094.0 6,164.0 11/17/2023 00:30 11/17/2023 02:00 1.50 COMPZN, RPCOMP MILL P Mill 4 1/2" tubing stump and S-3 packer Mill F/6,164' T/6,169' 2-3 BPM 60 - 140 PSI 100 RPM 7K TQ 3-10K WOM Pump 30 BBL Hi vis sweep while milling 6,164.0 6,169.0 11/17/2023 02:00 11/17/2023 04:00 2.00 COMPZN, RPCOMP CIRC P Push packer down to 6,219' with 5 BPM 650 PSI 100 RPM 6.5K TQ Set down 5K while rotating, pump 30 BBL Hi vis sweep, get returns to surface after pumping a total of 241 BBLS Pick up 10', turn off rotary, slack off tag packer with 10K DN at 6,221' Pump 70 BBL vi vis sweep, circulate packer gas and Hi vis sweeps out of hole 6 BPM 1550 PSI 10 BPM 3660 PSI ICP 10 BPM 2750 PSI FCP Dumping fluid as needed 6,169.0 6,211.0 11/17/2023 04:00 11/17/2023 04:45 0.75 COMPZN, RPCOMP OWFF P FLow check, fluid drop slowly Line up on TT montior static loss rate 24 BPH los rate Break out top drive, lay down single DP, blow down top drive 6,211.0 6,211.0 11/17/2023 04:45 11/17/2023 08:00 3.25 COMPZN, RPCOMP TRIP P POOH F/6,211' T/257' 6,211.0 275.0 11/17/2023 08:00 11/17/2023 09:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #9 F/ 275' T/ surface. PUW=45K. 275.0 0.0 11/17/2023 09:30 11/17/2023 10:30 1.00 COMPZN, RPCOMP WWWH P Jet BOP stack. Suck out stack. 0.0 0.0 11/17/2023 10:30 11/17/2023 11:30 1.00 COMPZN, RPCOMP MPSP P Pull wear bushing. Install test plug. R/U circ hose T/ IA to feed hole. Begin feeding well 15 Bbls every 30 Min. 0.0 0.0 11/17/2023 11:30 11/17/2023 12:00 0.50 COMPZN, RPCOMP RURD P R/U testing equipment. Fill BOPE w/ fresh water. Attempt T/ shell test. Blinds leaking. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 8/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2023 12:00 11/17/2023 20:15 8.25 COMPZN, RPCOMP BOPE T Blinds failed initial test. Opened up blinds and inspected. Found clamp from control line in blinds. Buttoned blinds back up. Attempted shell test again, blinds still failing. Opened up blinds and replace elements. Attempted to shell test again, blinds still failing. Opened blinds, inspect and flip over. Attempt to get shell test, blinds still leak. Change out blind rams. Obtain good shell test 0.0 0.0 11/17/2023 20:15 11/18/2023 00:00 3.75 COMPZN, RPCOMP BOPE P Weekly BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBRs & annular w/ 4 ½ Test joint. Did not test 7" LPR, Tag out of service. Test 3 1/2" IF FOSV & dart, test 4 1/2" EUE FOSV. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test manual and HCR kill valves, Test two ea 2 1/6" gate auxiliary valves below LPR. Witness by AOGCC rep Bob Noble 0.0 0.0 11/18/2023 00:00 11/18/2023 06:30 6.50 COMPZN, RPCOMP BOPE P BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBRs w/ 3 1/2" Test joint, Test 3 1/2" EUE FOSV, Test HCR choke valves. Perform accumulator test. Initial pressure= 3000 PSI, after closure= 1750 PSI, 200 PSI attained = 22 sec, full recovery attained = 107 sec. UVBR's= 4 sec, Annular= 17 sec. Simulated blinds= 4 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show Witness by AOGCC rep Bob Noble 0.0 0.0 11/18/2023 06:30 11/18/2023 16:30 10.00 COMPZN, RPCOMP BOPE P Annular failed test on 3 1/2" TJ. Changed out annular element. Test annular w/ 3 1/2" TJ. Test manual choke. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. 0.0 0.0 11/18/2023 16:30 11/18/2023 18:00 1.50 COMPZN, RPCOMP RURD P R/D testing equipment, blow down all lines. Suck out BOP. R/D circ hose F/ IA. Install mouse hole 0.0 0.0 11/18/2023 18:00 11/18/2023 18:30 0.50 COMPZN, RPCOMP MPSP P Pull test plug, set wear bushing 7 5/8" ID. 0.0 0.0 11/18/2023 18:30 11/18/2023 20:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #10 RCJB T/262' 0.0 262.0 11/18/2023 20:00 11/18/2023 23:00 3.00 COMPZN, RPCOMP TRIP P RIH F/262' T/6,006' 125K UP 73K DN 262.0 6,006.0 11/18/2023 23:00 11/19/2023 00:00 1.00 COMPZN, RPCOMP CIRC P Wash/Ream down F/6,006' T/6,220' Circulate at 9 BPM, 3060 PSI Rotate at 20 RPM 4600 TQ, 90K Rot WT Tag top of S-3 packer W/3-5K down Circulate 40 BBL Hivis sweep 6,006.0 6,220.0 11/19/2023 00:00 11/19/2023 03:30 3.50 COMPZN, RPCOMP TRIP P POOH F/6,220' T/262' 6,220.0 262.0 11/19/2023 03:30 11/19/2023 04:00 0.50 COMPZN, RPCOMP SVRG P Inspect DP 262.0 262.0 11/19/2023 04:00 11/19/2023 06:00 2.00 COMPZN, RPCOMP BHAH P L/D BHA #10. Clean magnets, minimal shavings. Clean boot baskets, 1/2 packer slip die. 262.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 9/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2023 06:00 11/19/2023 07:00 1.00 COMPZN, RPCOMP CLEN P Clear rig floor 0.0 0.0 11/19/2023 07:00 11/19/2023 11:00 4.00 COMPZN, RPCOMP RGRP T Close blinds. Filling hole w/ 15 Bbls every 30 Min. 3rd party welder repair welded pad eye back onto top drive extend frame assembly. 0.0 0.0 11/19/2023 11:00 11/19/2023 12:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #11 W/3.25" packer spear T/218, SOW=48K 0.0 218.0 11/19/2023 12:00 11/19/2023 14:30 2.50 COMPZN, RPCOMP TRIP P RIH F/218' T/ 6144', PUW=130K, SOW=73K. 218.0 6,144.0 11/19/2023 14:30 11/19/2023 15:00 0.50 COMPZN, RPCOMP FISH P Obtain parameters. Pump @ 3 BPM, 180 PSI. Rot @ 15 RPM, Free Tq = 4.6K. ROT=90K. Kill rotary. Wash down T/ 6225'. Set down 10K. P/U packer drag seen F/ 150-200K. Work packer up hole F/6,880' T/6,706', TOF @ 6,224' T/6,050' Fish length = 655.53' 6,144.0 6,706.0 11/19/2023 15:00 11/19/2023 15:15 0.25 COMPZN, RPCOMP CIRC P Circ 50 Bbls vis seawater followed by 50 Bbls neat seawater @ 10 BPM, 6,706.0 6,706.0 11/19/2023 15:15 11/19/2023 19:30 4.25 COMPZN, RPCOMP TRIP P POOH F/ 6706' T/872' PUW=138K. F/6,190' T/5,962' TOF depth, hit jars 13 times with 90K over and straight pull 130K over T/268K to get free 6,706.0 861.0 11/19/2023 19:30 11/19/2023 21:00 1.50 COMPZN, RPCOMP BHAH P L/D BHA #11 F/861' T/655' L/D spear with S-3 packer on it 861.0 655.0 11/19/2023 21:00 11/19/2023 21:30 0.50 COMPZN, RPCOMP RURD P Rig down spinners, rig up power tongs, change out elevtors to lay down 4 1/2" tubing 655.0 655.0 11/19/2023 21:30 11/19/2023 23:00 1.50 COMPZN, RPCOMP PULL P L/D 4 1/2" tubing Total fish L/D = 655.53' Note S-3 packer had 1.72' left of it with 1.34' of inner mandrel sticking up, total packer with stick up = 3.06' Packer body and mandrel have deep gouges in them indicating slips segments or other junk left in hole 655.0 0.0 11/19/2023 23:00 11/20/2023 00:00 1.00 COMPZN, RPCOMP RURD P Rig down 4 1/2" tongs and equipment Load shed with 2 JT 3 1/2" DP, prep shed to make up BHA #12, 4 5/8" RCJB clean out run 0.0 0.0 11/20/2023 00:00 11/20/2023 00:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #12, 4 5/8" RCJB T/39' 0.0 39.0 11/20/2023 00:30 11/20/2023 01:30 1.00 COMPZN, RPCOMP FISH P While making up BHA notice a piece of metal laying across well bore below the wear ring L/D BHA and unsuccessfully attempt to fish out with magnet, knock it down hole 39.0 0.0 11/20/2023 01:30 11/20/2023 03:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #12 4 5/8" RCJB T/294' 0.0 294.0 11/20/2023 03:00 11/20/2023 06:00 3.00 COMPZN, RPCOMP TRIP P RIH F/294' T/5,945', PUW=123K, SOW=70K 294.0 5,945.0 11/20/2023 06:00 11/20/2023 08:30 2.50 COMPZN, RPCOMP REAM P Wash and rotate down F/5,945' T/6820', @ 5 BMP, 980 PSI. Rot @ 50 RPM, Free Tq = 5K. ROT= 88K. @ 6,410' pump 47 BBLS Hi vis sweep. 5,945.0 6,820.0 11/20/2023 08:30 11/20/2023 10:30 2.00 COMPZN, RPCOMP WASH P Wash in hole through hook hanger F/ 6820' T/ 6875' @ 5 BPM 1000 PSI. Tag up at 6873', set DN 10K. Pick up and repeat at various pump rates. Pump 50 BBL Hi vis sweep @ 10 BPM 3000 PSI on bottom. Kill pumps tag 6874'. L/D working single T/ 6863' 6,820.0 6,863.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 10/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2023 10:30 11/20/2023 13:30 3.00 COMPZN, RPCOMP TRIP P POOH F/ 6863' T/ 294', PUW=137K. 6,875.0 294.0 11/20/2023 13:30 11/20/2023 14:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #12 F/ 294' T/ surface, PUW=48K. Clean magnets - Metal shavings, pin, hinge & large piece of metal. Boot baskets - Minimal metal, RCJB - Completely packed off w/ metal shavings & chunks of metal/slip. 294.0 0.0 11/20/2023 14:30 11/20/2023 15:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #13, RCJB #2 T/ 294', SOW=48K. 0.0 294.0 11/20/2023 15:30 11/20/2023 17:00 1.50 COMPZN, RPCOMP TRIP P RIH F/ 294' T/ 4735', PUW=104K, SOW=70K. 294.0 4,736.0 11/20/2023 17:00 11/20/2023 17:30 0.50 COMPZN, RPCOMP SVRG P Service rig. Derrick inspection. 4,736.0 4,736.0 11/20/2023 17:30 11/20/2023 19:15 1.75 COMPZN, RPCOMP TRIP P RIH F/ 4735' T/ 6820', PUW=129K, SOW=72K. 4,736.0 6,820.0 11/20/2023 19:15 11/20/2023 21:00 1.75 COMPZN, RPCOMP WASH P Wash in hole through hook hanger F/ 6820' T/ 6875' @ 5 BPM 1000 PSI. Set down @ 6839'. Orient string 180* out. RIH tag up at 6874', set DN 10K. Pick up and repeat at various pump rates. Pump 50 BBL Hi vis sweep @ BPM 3200 PSI on bottom. Kill pumps tag @ 6875. L/D working single T/ 6863' 6,820.0 6,836.0 11/20/2023 21:00 11/21/2023 00:00 3.00 COMPZN, RPCOMP TRIP P POOH F/ 6863' T/ 294', PUW=138K. 6,836.0 294.0 11/21/2023 00:00 11/21/2023 01:30 1.50 COMPZN, RPCOMP BHAH P L/D BHA #13 F/ 294' T/surface, PUW=48K. Clean magnets - Metal shavings, 1 medium and 2 small pieces of metal, Boot baskets - empty, RCJB clean 294.0 0.0 11/21/2023 01:30 11/21/2023 02:00 0.50 COMPZN, RPCOMP BHAH P Clean clear rig floor, mobilize BHA #14 components to rig floor 0.0 0.0 11/21/2023 02:00 11/21/2023 04:00 2.00 COMPZN, RPCOMP BHAH P M/U BHA #14 3 1/2" EUE stinger with Dolcater Snozzulator, spaced out to wash hook hanger/LEM collet profile W/ 3 1/2" EUE 6' ported pup JT T/297', RIH one stand DP T/390' Pump thru Snozzulater to make sure clear flow path - good, blow down top drive 0.0 390.0 11/21/2023 04:00 11/21/2023 05:00 1.00 COMPZN, RPCOMP SVRG P Service rig, top drive and derrick inspection 390.0 390.0 11/21/2023 05:00 11/21/2023 08:00 3.00 COMPZN, RPCOMP SLPC P Slip and cut 66' of drilling line 390.0 390.0 11/21/2023 08:00 11/21/2023 09:00 1.00 COMPZN, RPCOMP TRIP P RIH F/390' T/1,038' 390.0 1,038.0 11/21/2023 09:00 11/21/2023 18:00 9.00 COMPZN, RPCOMP RGRP T Replace traction motor drive chain on draw works 1,038.0 1,038.0 11/21/2023 18:00 11/21/2023 20:30 2.50 COMPZN, RPCOMP TRIP P PJSM after crew change. Fire drill and crownomatic test @ 18:30. TIH from 1,038' to 6,779'. 1,038.0 6,779.0 11/21/2023 20:30 11/21/2023 21:30 1.00 COMPZN, RPCOMP WASH P PUW = 134K, SOW = 70K. Bring pumps online @ 5 BPM and 720 psi. Wash down to max depth of 6,875'. Set down 5K. PU slowly while rotating 6 RPM to wash hook hanger profile. Saw repeated 5K overpull at 6,853'. Rotated pipe (5-6K ft-lbs) and pumped 20 bbls hi -vis pill. Came free. 6,779.0 6,875.0 11/21/2023 21:30 11/21/2023 22:00 0.50 COMPZN, RPCOMP WASH P TOOH to 6,835'. Saw weight bobbles drop off @ 6,839'. Believe square shoulders on 3 1/2" pups could be hanging up near hook hanger profile. 6,875.0 6,835.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 11/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2023 22:00 11/21/2023 23:30 1.50 COMPZN, RPCOMP WASH P Pump 60 bbls hi-vis sweep. Wash hook hanger profile while displacing hi-vis pill. TIH back to repeat tag @ 6,875' with pumps on. Pump 2X Tubing volumes. Established returns while flushing. SD pumps. PUH 10'. TIH and repeate dry tag @ 6,875'. Perform final hook hanger wash at 3 BPM and 270 psi. 6,835.0 6,875.0 11/21/2023 23:30 11/22/2023 00:00 0.50 COMPZN, RPCOMP TRIP P TOOH w/ BHA #14 to midnight depth of 6,260' 6,875.0 6,260.0 11/22/2023 00:00 11/22/2023 01:30 1.50 COMPZN, RPCOMP TRIP P Continue TOOH w/ BHA #14 to 297' 6,260.0 3,903.0 11/22/2023 01:30 11/22/2023 02:00 0.50 COMPZN, RPCOMP SVRG P Rig Service. Top Drive and drawworks maintenance. Performed cellar spill drill @ 2:00AM. 3,903.0 3,903.0 11/22/2023 02:00 11/22/2023 03:30 1.50 COMPZN, RPCOMP TRIP P Cont. TOOH w/ BHA #14. 3,903.0 297.0 11/22/2023 03:30 11/22/2023 05:30 2.00 COMPZN, RPCOMP BHAH P L/D BHA #14. Metal shavings on magnets. Slight wear on top of pup joint collars. 297.0 0.0 11/22/2023 05:30 11/22/2023 07:00 1.50 COMPZN, RPCOMP BHAH P Clean and clear rig floor. Kick out Baker fishing tools and 3 1/2" EUE pup joints. 0.0 0.0 11/22/2023 07:00 11/22/2023 08:00 1.00 COMPZN, RPCOMP RURD P Verify lower completions jewelry and run order, R/U to run 4 1/2" lower completion 0.0 0.0 11/22/2023 08:00 11/22/2023 10:15 2.25 COMPZN, RPCOMP PUTB P PJSM, run 4 1/2" lower completions as per detail T/736' C/O elevators to 3 1/2" DP, pick up and make up SBE and ZXP T/792' 47K UP/DN Liner WT = 12K 0.0 792.0 11/22/2023 10:15 11/22/2023 10:45 0.50 COMPZN, RPCOMP RURD P R/D tubing running equipment, R/U spinners and rig tongs for DP 792.0 792.0 11/22/2023 10:45 11/22/2023 14:45 4.00 COMPZN, RPCOMP RCST P RIH W/ 4 1/2" completion on 3 1/2" DP F/792' T/6,817' 115K 74K 792.0 6,817.0 11/22/2023 14:45 11/22/2023 15:45 1.00 COMPZN, RPCOMP RUNL P Locate LEM in hook Slack off F/6,817' T/6,874' See 2-3K drag at 2-3K @ 6,872' to 6,874' then set DN 5K, continue to set down to 20K down Pick up to 6,876', see 5-10K drag up for 2' then pick up clean no real indication of collet snap out Rotate string 1/2 turn to right, work pipe to get turn down Slack off tag up at same depths, working set down WT to 30K down Put 1/3 of a turn in work pipe, tag up at same depths work set DN WT to 35K Every time going into hook see 2-3K drag for 2-3' before taking weight and see 5-10K drag for 2' when picking up Set down a total of 7 times seeing never seeing a snap out but seeing the snap in at 15-20K down, giving all indications that LEM is lugged up to hook 6,817.0 6,874.0 11/22/2023 15:45 11/22/2023 16:15 0.50 COMPZN, RPCOMP OTHR P Call and discuss with Baker and CPAI town Decide to set ZXP 6,874.0 6,874.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 12/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2023 16:15 11/22/2023 17:30 1.25 COMPZN, RPCOMP PACK P Slack off set down 35K see snap in at 15-20K DN Pick up to 100K on hook Set ZXP LTP @ 6093.86', ZXP element @ 6109.86', M/S @ 6874.57' Set slips drop 1.125" ball Pump ball down at 2 BPM, ball on seat @ 289 STKS, PSI up to 1900 PSI shut down pumps hold for 2 min, PSI up to 2300 PSI, slack off to 50K = 23K DN, PSI up to 3300 PSI see shear at 2500 PSI hold for 2 min Bleed off PSI, P/U to confirm release, pick up to 110K, dont act released, slack off to 50K on hook, PSI up to 3400 PSI, slack off to 35K, bleed off PSI, P/U to 110K up 6,874.0 6,874.0 11/22/2023 17:30 11/22/2023 19:00 1.50 COMPZN, RPCOMP OTHR P Fill back side for pressure testing ZXP Packer. Took 30 BBLS to fill hole. Minimal air break out of annulus, 10 min. Blow down top drive. Prep for PT of ZXP Packer. 6,874.0 6,874.0 11/22/2023 19:00 11/22/2023 20:00 1.00 COMPZN, RPCOMP PRTS P Close UPR. Line up to kill line. PT ZXP Packer to 3,500 psi. Took 54 strokes to pressure up. Sensator on Test Spool. Initial = 3,680 psi. 15-min = 3,670 psi. 30-min = 3,670 psi. Bleed off. Open UPR. Arrange jewlery in pipe shed per run order. 6,874.0 6,874.0 11/22/2023 20:00 11/22/2023 21:00 1.00 COMPZN, RPCOMP RURD P Lay down 1 stand to pull pack-off from tieback sleeve F/6,095' T/6,034'. 125K up until pack off out tie back, 115K up clean RU head pin and pressure testing manifold on rig floor. Pressure up with rig pumps to 3,500 psi. Line up to test pump. Shear out ITTS at 3,743 psi w/ test pump. 6,095.0 6,034.0 11/22/2023 21:00 11/22/2023 23:00 2.00 COMPZN, RPCOMP PULD P TOOH laying down drill pipe from 6,034' T/3,938' 115K UP 6,034.0 3,938.0 11/22/2023 23:00 11/22/2023 23:30 0.50 COMPZN, RPCOMP TRIP P RIH excess DP from derrick F/3,938' T/4,923' 3,938.0 4,923.0 11/22/2023 23:30 11/23/2023 00:00 0.50 COMPZN, RPCOMP PULD P POOH Kitty Wells style F/4,923' T/4,124' 101K UP 4,923.0 4,124.0 11/23/2023 00:00 11/23/2023 04:00 4.00 COMPZN, RPCOMP TRIP P Continue TOOH laying down drill pipe from 4,124' to 32'. 4,124.0 32.0 11/23/2023 04:00 11/23/2023 04:30 0.50 COMPZN, RPCOMP RURD P L/D Baker running tool. Pul wear ring 32.0 0.0 11/23/2023 04:30 11/23/2023 09:00 4.50 COMPZN, RPCOMP RURD P Clean and Clear rig floor. Prep to run 4 1/2" Upper Completions. Verify jewelry, run order, and tubing count. Mobilize HES Tec wire and spooler and clamps to rig floor. Assemble HES spooler and tech wire on rig floor, hand tech wire sheeve in derrick 0.0 0.0 11/23/2023 09:00 11/23/2023 10:00 1.00 COMPZN, RPCOMP PUTB P PJSM - Run 4 1/2" IBT-M Upper Completions as per tallyT/126' 0.0 126.0 11/23/2023 10:00 11/23/2023 10:30 0.50 COMPZN, RPCOMP RURD P Hook up Halliburton tech wire to gauge, test to 10,000 PSI F/10 min 126.0 126.0 11/23/2023 10:30 11/23/2023 21:30 11.00 COMPZN, RPCOMP PUTB P RIH W/ 4 1/2" completion F/126' T/ 6,112' (Joint #149). Test tech wire every 15 JTS. Pump 1st 30 bbl pill of CI down backside about 1 hour before locating. 126.0 6,108.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 13/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2023 21:30 11/23/2023 22:00 0.50 COMPZN, RPCOMP WASH P M/U Head Pin and Circ Hose to top of Joint #149. PU 10'. With ORKB differences had potential to sting into SBE early. PUW = 105K. SOW = 65K. 6,108.0 6,100.0 11/23/2023 22:00 11/23/2023 23:00 1.00 COMPZN, RPCOMP RGRP T Attempt to bring pumps on to wash down. Unable. Pumps not functional. Nordic troubleshooting SCR's. Top Drive and Drawworks also not functioning. Pump 2nd 30bbl CI pill down backside. 6,100.0 6,100.0 11/23/2023 23:00 11/23/2023 23:30 0.50 COMPZN, RPCOMP WASH P SCR's Fixed. Blown foot throttle fuse. Systems functional. Obtain Parameters. PUW = 105K. SOW = 65K. Pump rate = 3 BPM @ 4 psi on Pason. Attempt to wash down Joint #149 watching for pressure indicator of SBE top. No indicator and low circ pressure doesn't allow a good indicator. R/D head pin and circ hose from Joint #149. Pump 3rd 30 bbl pill of CI down backside. 6,100.0 6,108.0 11/23/2023 23:30 11/24/2023 00:00 0.50 COMPZN, RPCOMP WASH P M/U Joint #150. TIH slowly watching weight indicating seals entering SBE. See 1K weight bobbles @ 6,120'. Cont TIH to fully locate Seals in SBE @ 6,137' N3 RKB. Set 5K down weight. 6,108.0 6,137.0 11/24/2023 00:00 11/24/2023 00:30 0.50 COMPZN, RPCOMP PUTB P PU 4' off No-Go. Mark Pipe @ 6,133'. Fill backside w/ 17 bbls SW. Observe static fluid level in stack to confirm seals are stung in and holding. 6,137.0 6,133.0 11/24/2023 00:30 11/24/2023 03:15 2.75 COMPZN, RPCOMP HOSO P Slowly PUH measuring Joint #150 partial. Watch for fluid level to start dropping indicating top of SBE @ 6,118'. L/D Joint #150, #149, #148. Measured 21.30' of Joint #150 partial joint. Calculate space out pups required. Need 27.35'. Space out pups = 9.81, 9.81, 7.83' = 27.45'. Final space out after landing is 3.90' off locator. M/U space out pups, Joint #148, Hanger w/ ISO sleeve, and Landing Joint. Align hanger orienting lug with wellhead orienting pin. Terminate HES Tec Wire through Hanger. Verify Tec wire electrical connection, 1187 PSI and 64.6° reading before landing hanger in well head Installed 154 Cross Collar Clamps and 4 Mid-Joint Clamps for TEC wire. 6,133.0 6,027.0 11/24/2023 03:15 11/24/2023 03:45 0.50 COMPZN, RPCOMP CIRC P TIH to 6,110' (approx. 8' above top of SBE). Pump last 30 bbls of CI down backside. Flush lines w/ 10 bbls of Seawater. 105K UP 65K DN 6,027.0 6,110.0 11/24/2023 03:45 11/24/2023 06:00 2.25 COMPZN, RPCOMP HOSO P Land Hanger. Confirm alignment of hanger w/wellhead outlet. RILDS. Test upper and lower hanger seals to 5000 psi for 15-min each Clear rig floor of Halliburton spooler equipment 6,110.0 6,133.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 14/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2023 06:00 11/24/2023 08:00 2.00 COMPZN, RPCOMP RURD P Lay down landing joint, pull ISO sleeve from hanger, Drop 1 7/8" Ball and Rod with rollers with 1.375" F/N, R/U head pin to landing joint. R/U pressure testing equipment, sensators, and valves on rig floor Fill lines, TBG and IA to get air out for testing - take 39 BBLS to fill TBG and IA 6,133.0 6,133.0 11/24/2023 08:00 11/24/2023 10:30 2.50 COMPZN, RPCOMP PRTS P PT Tubing to 3,000 PSI F/30 Min take 1.4 BBLS to pressure up, first test bleed down to F/3360 to 3240 in 15 min, to 3120 PSI in 30. IA stay at 200 PSI, No visable leaks at surface, bleed off PSI, pressure up again to 3,000 PSI F/30 min - Second test bleed from 3480 PSI to 3400 PSI in 15 min, to 3240 PSI in 30 min, IA stay at 200 PSI Bleed Tubing to 2,500 PSI - Fail MIT test PT IA to 3,500 PSI F/30 Min, IA = 3720 PSI, TBG = 3060 PSI, OA 465 PSI - 15 min IA = 3660 PSI TBG = 3000 PSI, OA = 460 PSI, 30 Min IA = 3600 PSI, TBG = 2880 PSI, OA = 460 PSI - Fail MIT test 6,133.0 6,133.0 11/24/2023 10:30 11/24/2023 11:30 1.00 COMPZN, RPCOMP PRTS P Believe RHC/ plug or ball and rod leaking by Bleed IA to zero, Bleed TBG to zero, install another block valve on TBG side to trouble shoot TBG/IA test Test TBG to 3000 PSI PSI up to 3400 on tubing bleed to 3300 PSI in 15 min, bleed to 3220 PSI in 30 min 6,133.0 6,133.0 11/24/2023 11:30 11/24/2023 13:45 2.25 COMPZN, RPCOMP RURD T R/D pressure testing equipment. Call slick line for options to pull ball and rod and RHC plug. Plan to install 3.813" PXX plug in X/nipple. Lay down landing joint to pick up shorter one for slick line work. 6,133.0 6,133.0 11/24/2023 13:45 11/24/2023 16:00 2.25 COMPZN, RPCOMP SLKL T Slick line on location, spot unit next to rig Dress tools for pulling ball and rod and RHC plug R/U slick line. 6,133.0 6,133.0 11/24/2023 16:00 11/24/2023 20:30 4.50 COMPZN, RPCOMP SLKL T RIH with slick line - Tag up at 1940'. POOH. M/U Bailer and drift through tight spot at 1,940'. M/U 3.80" OD drift. RUH. See tight spots @ 1,950', 2500', and 2,900'. Unable to work through tight spot at 2,900'. POOH. M/U 3" OD Bailer. RIH and drift tubing to B&R @ 6,036'. Clean Drift. POOH. 6,133.0 6,133.0 11/24/2023 20:30 11/24/2023 21:00 0.50 COMPZN, RPCOMP SLKL T PU/MU 2.88" GR. RIH and tap B&R on seat. Leave slickline weight on ball during PT. Reattempt PT Tubing to 3,000 psi, with SL keeping ball on seat. 6,133.0 6,133.0 11/24/2023 21:00 11/24/2023 22:30 1.50 COMPZN, RPCOMP PRTS T R/U hardline on rig floor for PT. Reattempt PT Tubing to 3,000 psi, with SL keeping ball on seat. Initial = 3,240 psi. 15-min = 3,110 psi, 30-min = 3,000 psi. Fail. Trend did not stabilize. 6,133.0 6,133.0 11/24/2023 22:30 11/24/2023 23:00 0.50 COMPZN, RPCOMP SLKL T Release SL Pack-off. Tap on B&R 3X. POOH. Standback Slickline 6,133.0 6,133.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 15/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2023 23:00 11/24/2023 23:30 0.50 COMPZN, RPCOMP PRTS T R/U PT equipment on rig floor. PT Tubing to 3,000 psi. Initial = 3,240 psi. 15-min = 3,050 psi. Fail. 6,133.0 6,133.0 11/24/2023 23:30 11/25/2023 00:00 0.50 COMPZN, RPCOMP SLKL T R/U Slickline (w/ Pump-in Sub + Pack- off). RIH w/ 3.76" OD GR to clean up tight spots. Drift freely to 5,895'. Unable to spang through. 6,133.0 6,133.0 11/25/2023 00:00 11/25/2023 02:30 2.50 COMPZN, RPCOMP SLKL T POOH w/ 3.76" GR. MU and RIH w/ 3.49" GR. Spang through tight spot @ 5,895'. Set down again @ 5,958' (below CMU sliding sleeve). Worked through tight spot. Drifted through 3 times. POOH. MU pulling tool for Ball and Rod. RIH. Latch and pull B&R from X- nipple @ 6,039'. Stand back SL. Ball had slight lowside wear but wear appeared to be above sealing profile. 6,133.0 6,133.0 11/25/2023 02:30 11/25/2023 03:00 0.50 COMPZN, RPCOMP CIRC T Pump 100 bbls Seawater down tubing. 4 BPM @ 137 psi. Flush debris/pipe dope from tubing. 6,133.0 6,133.0 11/25/2023 03:00 11/25/2023 06:00 3.00 COMPZN, RPCOMP SLKL T MU and RIH w/ 3.80" GR. Set down @ 2,901'. Worked Spangs. Sticky, Had to use oil jars to get free. POOH. PU and RIH w/ 3.76" GR. Drifted clean to RHC plug @ 6,036'. POOH. MU and RIH w/ 3.80" GR with knuckle joint T/2,901', unable to work thru, POOH 6,133.0 6,133.0 11/25/2023 06:00 11/25/2023 10:30 4.50 COMPZN, RPCOMP SLKL T RIH with 3.77" gauge, make it thru tight spot at 2,,901', RIH tag up at 5,895', same tag as 3.49" gauge, unable to work thru, POOH to pick up weight bars and 3.77" broach, RIH T/5,910', pick up to 5,890' pull heavy and act like dragging something up with tools, POOH small pieces os scale on broach. Bring magnets for next run from wireline shop 6,133.0 6,133.0 11/25/2023 10:30 11/25/2023 12:30 2.00 COMPZN, RPCOMP SLKL T RIH with 3.625" flat magnet with 3' of 1 7/8" mag stem T/6,043' RHC plug, POOH, magnets have a couple thin metal slivers 6,133.0 6,133.0 11/25/2023 12:30 11/25/2023 14:15 1.75 COMPZN, RPCOMP SLKL T RIH W/3.77" broach T/6,043' See bobble at 2,901', able to work thru with minimal work, work up thru CMU sliding sleeve @ 5,950' POOH 6,133.0 6,133.0 11/25/2023 14:15 11/25/2023 15:45 1.50 COMPZN, RPCOMP SLKL T RIH W/3.80" gauge T/5,953' Pump 30 BBLS 140° deep clean pill chase with 40 BBL seawater at 4 BPM to help clean inside of pipe Attempt to work thru with no sucess, loose spangs, POOH all tools there 6,133.0 6,133.0 11/25/2023 15:45 11/25/2023 17:15 1.50 COMPZN, RPCOMP SLKL T RIH W/3.78" swedge T/6,043' - RHC plug. No issues. POOH 6,133.0 6,133.0 11/25/2023 17:15 11/25/2023 20:30 3.25 COMPZN, RPCOMP SLKL T RIH to pull RHC plug. Pulled RHC plug from X-nipple @ 6,036'. POOH. PU and RIH w/ PXX Plug. Set PXX Plug in X-Nipple @ 6,036'. POOH. PU Plug Prong. RIH and set Prong in PXX Plug. POOH. Stand Back Slickline. Call Guy Cook (AOGCC) to give update on potential BOP test timing. Will call Guy back with results of MIT-T. Verbal witness waived. 6,133.0 6,133.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Page 16/16 1B-101 Report Printed: 12/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2023 20:30 11/25/2023 23:00 2.50 COMPZN, RPCOMP PRTS T RU rig floor pressure testing equipment to landing joint. Top fill Tubing to fluid pack. PT Tubing to 3,000 psi. Initial = 3,300 psi. 15-min = 3,250 psi. 30-min = 3,250 psi. Chart. Pass. Bleed Tubing to 2,500 psi. PT IA to 3,500 psi. Initial = 3,680 psi. 15-min = 3,640 psi. 30-min = 3,640 psi. Chart. Pass. Dump Tubing pressure. Shear SOV. Confirm flow path. 6,133.0 6,133.0 11/25/2023 23:00 11/26/2023 00:00 1.00 COMPZN, RPCOMP RURD P R/D and release Slickline. R/D pressure testing equipment. L/D Landing Joint. Suck out Stack. 6,133.0 0.0 11/26/2023 00:00 11/26/2023 00:30 0.50 COMPZN, WHDBOP MPSP P Set BPV. Test to 1,000 psi from below. Chart. Install blanking plug. 0.0 0.0 11/26/2023 00:30 11/26/2023 06:30 6.00 COMPZN, WHDBOP NUND P N/D BOP. C/O LPR from 7" fixed to VBRs. 0.0 0.0 11/26/2023 06:30 11/26/2023 09:30 3.00 COMPZN, WHDBOP NUND P N/U TBG head adaptor and test to 5000 PSI 15 min, terminate TEC Wire at wellhead. Final Readings: 1535 PSI and 68.26 °F 0.0 0.0 11/26/2023 09:30 11/26/2023 11:45 2.25 COMPZN, WHDBOP NUND P N/U tree, rig up LRS to squeeze manifold, test tree to 5000 PSI F/10min 0.0 0.0 11/26/2023 11:45 11/26/2023 12:15 0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV 0.0 0.0 11/26/2023 12:15 11/26/2023 14:00 1.75 DEMOB, MOVE FRZP P Line up to pump down IA and take returns F/TBG to kill tank, Pump 85 bbls diesel down IA. U-Tube diesel from IA/TBG 0.0 0.0 11/26/2023 14:00 11/26/2023 15:00 1.00 DEMOB, MOVE DMOB P Secure tree and cellar. Unload remaining fluid from pits. Secure rig for move from 1B to 1J. Final PSI readings OA = 50 PSI IA = 0 PSI TBG = 0 PSI 0.0 0.0 11/26/2023 15:00 11/26/2023 16:00 1.00 DEMOB, MOVE DMOB P Pull rig off 1B-101 Clean up around cellar Rig release at 16:00 HRS 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/26/2023 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1B-101 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swap SOV for DMY, Pull plug 1B-101 12/7/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTILATERAL WELL: B-SAND (1B-101), D-SAND (1B-101L1) 9/8/2003 triplwj NOTE: TREE CAP CONNECTION: 10.75"" CWCT ELECTRIC FEED THRU MANDREL, HORZT OUTLET 9/8/2003 triplwj NOTE: TREE: ABB VETCO GRAY / HORZT / 4 1/16"" 5M w/ PENETRATOR WIRE 9/8/2003 ninam 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 34.7 148.0 148.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.3 3,080.4 2,199.7 40.50 J-55 BTC WINDOW D-SAND 8 6.00 6,867.0 6,877.0 3,662.7 29.70 PRODUCTION 7 5/8 6.87 27.1 7,388.9 3,730.3 29.70 L-80 BTC-M LINER B-SAND 4 1/2 3.96 6,882.2 12,230.0 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.1 Set Depth 6,129.6 String Max No 4 1/2 Set Depth 3,447.5 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 23.1 23.1 0.00 Hanger 10.750 4 1/2" x 11" Vault Gen 1 concentric hanger w/ 4.909 MCA top threads Vault Gen 1 3.893 3,538.7 2,391.0 65.32 Mandrel GAS LIFT 6.376 4.5" x 1" KBMG GLM, DMY w/ BK latch SLB KBMG 3.865 5,878.9 3,354.8 67.13 Mandrel GAS LIFT 6.376 4.5" x 1" KBMG GLM, SOV w/ BEK latch SLB KBMG 3.865 5,946.3 3,380.6 67.88 Sleeve - Sliding 5.555 4.5" x 3.813" Baker NEXA-2 CMU sliding sleeve Closed Position Baker CMU Sliding Sleeve 3.813 6,012.6 3,405.2 68.65 Sensor - Discharge Gauge 5.685 4 1/2" 12.6# L-80 Halliburton Opsis Gauge HES Opsis Gauge 3.920 6,036.5 3,413.8 68.92 Nipple - X 4.990 4 1/2" x 3.813" X/Nipple W/RHC HES 3.813" X Nipple 3.813 6,100.8 3,437.0 68.78 Locator 5.500 Baker locater 5.5" OD Baker Locator 3.870 6,102.6 3,437.7 68.78 Seal Assembly 4.750 Baker 192-47 seal assembly (3.90' from fully located) Baker 192-47 Seal Assembl y 3.870 Top (ftKB) 6,095.7 Set Depth 6,876.4 String Max No 4 1/2 Set Depth 3,662.6 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 6,095.7 3,435.2 68.79 Packer - Liner 6.380 5 1/2" x 7 5/8" Baker ZXP LTP W/10.98' x 5.75" tie back sleeve (SN#:16001117) Baker ZXP LTP H29645 0131 4.920 6,115.3 3,442.3 68.74 SBE 6.250 Baker 190-47 Sealbore Extension W/18.70' x 4.75" seal bore 190-47 SBE H02433 17A1 4.750 6,188.8 3,468.6 69.38 Nipple - X 4.500 4 1/2" x 3.813" X-Nipple (SN#:3683984) Halliburt on 3.813" X/Nipple 3.958 6,839.8 3,653.5 75.46 Hanger 4.500 Baker LEM #2 (Above Hook Hanger) (H289180004/5) Baker LEM II H28918 0004/5 3.910 6,874.9 3,662.2 75.66 Wireline Guide 5.250 4.5" Muleshoe WL Re-Entry Guide 3.940 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) 3,538.7 2,391.0 65.32 1 GAS LIFT DMY BK 7.69 11/24/2023 SLB KBMG 1.000 5,878.9 3,354.8 67.13 2 GAS LIFT DMY BK 7.69 0.0 12/7/2023 SLB KBMG 0.000 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) 6,882.2 3,664.0 75.68 PACKER 6.690 BAKER SC-1R RETRIEVABLE PACKER w/ EXTENSION 4.000 6,887.0 3,665.2 75.69 EXTENSION 5.560 BAKER EXTENSION 4.890 12,196.5 3,713.9 91.66 BUSHING 4.500 BAKER PACKOFF BUSHING 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,480.0 12,196.0 3,734.4 3,713.9 WS B, 1B-101 9/8/2003 16.0 SLOTS SLOTTED LINER, 0.25" x 2.5" slots, alternating blank/slotted 31' joints w/16 shots per slotted joint 1B-101, 12/15/2023 9:12:34 AM Vertical schematic (actual) LINER B-SAND; 6,882.2- 12,230.0 SLOTS; 7,480.0-12,196.0 PRODUCTION; 27.1-7,388.9 WINDOW D-SAND; 6,867.0- 6,877.0 LINER D-SAND; 6,847.1- 12,172.6 Tubing - Pup Joint; 6,179.0 Seal Assembly; 6,102.6 Packer - Liner; 6,095.7 Nipple - X; 6,036.5 Sensor - Discharge Gauge; 6,012.6 Sleeve - Sliding; 5,946.3 Mandrel GAS LIFT; 5,878.9 Mandrel GAS LIFT; 3,538.7 SURFACE; 28.3-3,080.4 CONDUCTOR; 34.7-148.0 Hanger; 23.1 KUP PROD KB-Grd (ft) 34.70 RR Date 8/31/2003 Other Elev 1B-101 ... TD Act Btm (ftKB) 12,230.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292317300 Wellbore Status PROD Max Angle & MD Incl (°) 92.86 MD (ftKB) 7,803.28 WELLNAME WELLBORE1B-101 Annotation Last WO: End Date 11/26/2023 H2S (ppm) 10 Date 8/12/2016 Comment SSSV: WRDP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12230'None Casing Collapse Conductor Surface Window D Sand Production B Sand Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7480-12196' 5348' 3734-3714' 4-1/2" 4-1/2" 10-3/4" 8' 3052' 10' Perforation Depth MD (ft): 7-5/8"7362' MD 2200' 6877' 3730' 3080' 6867' 3713'12230' 7389' Length Size Proposed Pools: 148' 148' TVD Burst PRESENT WELL CONDITION SUMMARY 113' 16" 3713' 12230' 3713' 446 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025648 203-133 P.O. Box 100360, Anchorage, AK 99510 50-029-23173-00-00 ConocoPhillips Alaska, Inc. KRU 1B-101 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): 6172' MD and 3463' TVD 6882' MD and 3664' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 6830' 8/1/2023 Packer: Baker S-3 Packer: Baker SC-1R SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 CTD Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:01 pm, Jun 13, 2023 323-340 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.06.13 13:39:04-08'00' Foxit PDF Editor Version: 12.1.2 10-404 MDG 7/17/2023 X VTL 7/17/2023 X BOP test to 2500 psig Annular preventer test to 2500 psig DSR-6/13/23JLC 7/17/2023 07/18/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:07:44 -05'00' RBDMS JSB 071823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 13, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1B-101 (PTD# 203-133). Well 1B-101 was drilled and completed in August of 2003 by Doyon 141 as a West Sak D/B sands producer. In 2023 the well became a RWO candidate due to multiple identified tubing leaks. If you have any questions or require any further information, please contact me at +1406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to replace the tubing. During the RWO, we also plan to install a Lateral Entry Module (LEM) in the hook hanger to provide access to the upper lateral (D- sand). Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.06.13 13:39:27-08'00' Foxit PDF Editor Version: 12.1.2 1B-101 RWO Procedure Kuparuk Producer P&R Tubing PTD #203-133 Page 1 of 3 Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests. 2. Pull Jet pump. 3. Obtain SBHP. 4. Open lowest GLM in upper completion. 5. Cut tubing at ~6115’ RKB. 6. CMIT to 2500 psig. 7. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1B-101. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing and Packer 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to pre-rig cut (~6115’ RKB). 6. Pull tubing stub from PBR. 7. Mill through packer. 8. Pull remainder of completion. Cleanout Run 9. Perform a Cleanout run through hook hanger to confirm drift and condition of hook hanger for LEM install. Install LEM and new 4-½” Tubing 10. MU and run LEM assembly with liner top packer. Set down LEM into hook hanger. Set packer and test same. 11. MU 4 ½” completion with seal assembly, gauge carrier, sliding sleeve, and GLM’s. RIH to sealbore extension. 12. Once on depth, space out as needed and circulate CI brine. Sting into SBE and land tubing hanger. RILDS. 13. Pressure test tubing to 3000 psi for 30 minutes. 14. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 15. Confirm pressure tests, then shear out SOV with pressure differential. 16. Install BPV. 17. ND BOPE. NU tree. 18. Pull BPV, freeze protect well, and set BPV if necessary. 19. RDMO. Post-Rig Work 20. Install jet pump 21. Install gas lift design as needed 1B-101 RWO Procedure Kuparuk Producer P&R Tubing PTD #203-133 Page 2 of 3 General Well info: Wellhead type/pressure rating: Vetco Gray Horizontal, 5M psi top & bottom flange Production Engineer: Will Parker Reservoir Development Engineer: Marina Krysinski Estimated Start Date: 7/15/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 4-1/2” completion, install a new 4-1/2” completion with LEM. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / DSA (as needed) 1B-101 RWO Procedure Kuparuk Producer P&R Tubing PTD #203-133 Page 3 of 3 Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A (tubing leaks) CMIT-TxIA Passed 2/19/2023 MIT-OA N/A IC POT & PPPOT to be performed pre-rig TBG POT & PPPOT to be performed pre-rig MPSP: 446 psi using 0.1 psi/ft gradient Static BHP: 810 psi / 3640’ TVD measured on 02/19/2023 Tubing String: 4-1/2",12.6 #, L-80, IBT,ABModiifed (1054-2463)6,847': Top of Hook Hanger,Baker Model B, 7-5/8" x 5",Main Bore Drift = 5.315"Lateral Bore Drift = 3.875"(6,847' MD / 3,655' TVD)Control Line / TEC wire forGaurdian Gauges, held inplace with Canon Clamps onevery couplingTree Assy,, Vetco Gray “Producer” Casing / TubingHead AssyVetco Gray Gen1B, 11" API 5Mflange up.Tubing Hanger, Vetco Gray, 4-1/2", w/ 4.909" MCA TopConnection; 4-1/2", 12.6#, L-80 IBT-Mod box down, drilled forTEC wire & two SSSV control lines. WITH BPV INSTALLED.(85) Joints Tubing6,056': (1) Pressure Gauge, Internal Tubing, Baker Gaurdian, with 10' handling pups topand bottom (6,056' MD / 3,421' TVD)6,172': (1) Packer / Millout Assembly, Baker Model 7-5/8 x 4-1/2" ‘S3’, (ID 3.875), 4-1/2"IBTM, 6 ft handling pup installed on top and bottom. (6,172' MD / 6,463')5,996': (1) Profile Nipple, Camco DB, 3.75" Packing Bore (5996' MD / 3,399' TVD)(78) Joints Tubing2,665': (1) Nipple (1061-9229)for Sub Surface Safety Valve, Schlumberger (Camco)Model BP-6i, with 3.813" Camco ‘DB’ profile (3.813" ID Packing bore), IBT-Mod, set at2,665' MD / 2,031' TVD. Run with isolation sleeve (2.500” ID) installed, and 10' pups topand bottom.(20) Joints Tubing6,828': (1) Wire line Entry Guide, 4-1/2" L-80 IBT-Mod Box, (6,828' MD / 3,650' TVD)6,199': (1) Profile Nipple, 4-½ Camco DB , 3.687" ID packing bore, 4-1/2" L-80 IBT-Mod Box,set at 70 deg maximum inclination. With RHC Plug installed, and ball and rod in place. Rodwith 1.38" OD fishing neck up. With 10 ft handling pups. Top @ 6,199' MD / 3,472' TVD3,519': (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with DCKshear valve installed, pinned to shear when annular pressure is 2500 psi greater than tubingpressure, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom, set at +/- 2400 ftTVD, (3519' MD / 2383' TVD) SHEAR VALVE SHEARED.(27) Joints Tubing(2) Joints Tubing6,141': (1) PBR with Seal Assembly, 17 ft Baker Model 80-47, 4-1/2" L-80 IBT- Mod, 6 ft handlingpups installed on top & bottom. (6,141' MD / 3,452')5,941': (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with BK-2 dummy valveinstalled, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. (5,941' MD / 3,379' TVD)(1) Joint Tubing(1) Relief Groove Sub, Baker5,998': (1) Sliding Sleeve, 3.813 CMU (5998' MD / 3,400' TVD)6,004': (1) Polished Bore Sub, 3.750" ID polished bore, 24 inshes long. (6,004' MD / 3,402' TVD)(1) Relief Groove Sub, Baker10-3/4", 45.5#, L-80 x40.5#, J-55, BTCCasing Shoe - 3,080' MD/ 2,200' TVD7,389': Intermediate Casing Shoe7-5/8" 29.7# L-80 BTC ModSet @ 7,389' MD / 3,730' TVD(1) Joint Tubing(1) Handling pup, 10 ft long(1) Handling pup, 10 ft long1B-101 As Built Schematic.vsdprepared by Steve McKeever9/25/2003West Sak Production Well 1B-101AS BUILT Completion SchematicSheet 1 of 11B-101 As Built:Eastings: 550,229.19Northings: 5,969,646.86Pad Elevation: 60.4' AMSLDoyon Rig 141 RKB @ 0'Elevation: 88.4' AMSLLiners, every otherjoint slotted, (0.25"x 2.5" slots, 16 perfoot, 5.9% openarea), 4-½", 12.6#,L80, NSCT12,171': EccentricNose Shoe, 3-½", IBTBox12,228':EccentricNose Shoe6,987': Tattle Tale Sub,3.400" ID12,140': Bent Joint,3-½",9.3#, L-80, IBT6-¾" Upperlateral openhole TD @12,197 MD /3,659 TVD6-¾" Lowerlateral openhole TD @12,230 MD /3,713 TVD12,105': Pack Off Bushing Sub,Baker, 2.375" OD12,197':Pack Off Bushing Sub,Baker, 2.375" OD7,480': Uppermostslotted joint.Fluid Types in WellDiesel9.8 ppg KCl Brine9.6 ppg FloPro Mud2,770' MD / 2,073' MD:Brine Top Diesel Bottomin Tubing & Inner Annulus1B-101, TVD & Inclination v. MD05001,0001,5002,0002,5003,0003,5004,0000 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 13,000Measured Depth (feet)True Vertical Depth (feet)152535455565758595Inclination (degrees)D lateral TVDMainbore & B Lat ActualTVDD Lateral ActualInclinationMainbore & B LateralInclinationTubing & IA, 0'-2,770'OA, 0' - 3,080'Tubing & IA, 2,770' - 6,847'9.8 ppg KCl BrineInside and Outside Upper Liner,6,847' - 12,171'Inside and Outside Lower Liner,6,847' - 12,171'6,882':Lower Liner TopPacker, Baker SC-1R (6,882'MD / 3,664' TVD) 1B-101 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 148 148 16 15.06 62.5 H-40 Welded Welded Surface 3080 2200 10-3/4 9.95 40.5 J-55 BTC BTC Intermediate 7389 3730 7-5/8 6.87 29.7 L-80 BTC-M BTC-M B Liner (Main)12230 3713 4-1/2 3.96 12.6 L-80 NSCT NSCT D Liner (L1 Lat)12197 3659 4-1/2 3.96 12.6 L-80 NSCT NSCT Tubing 6829 3651 4 1/2"3.96 12.6 L-80 IBT-M IBT-M Surface Casing Conductor Perfs 4-1/2" DB Nipple @ 400' RKB (3.875" ID) 4-1/2" x 1" Camco KBMG GLMs @ 3519', 5941' RKB 4-1/2" Sliding Sleeve @ 6000' RKB (3.813" ID X Profile) w/ TEC wire orientation subs 4-1/2" Gauge Carrier, HAL Gauge @ 6056' RKB 4-1/2" X Nipple @ 6130' RKB (3.813" ID) 4-1/2" Locator/ Seal Assembly @ 6172' RKB 5-1/2" x7-5/8" ZXP Packer @ 6172' RKB 190-47 Seal bore extension 5-1/2" x 4.5" XO 4-1/2" X Nipple @ 6230' RKB (3.813" ID) 7 5/8" x 4 1/2" LEM @ 6847' RKB Modified by SJG 6/13/2023 B Sand Lateral (Mainbore): 4-1/2" x 7-5/8" Baker SC-1R retrievable packer @ 6882' RKB 4 1/2" 12.6lb/ft Slotted liner LEM Intermediate Casing D Sand Lateral (L1 Liner): 7-5/8" x 4-1/2" Baker Model "B" Hook Hanger @ 6847' RKB Main Bore Drift = 5.315" Lateral Bore Drift= 3.875" 4-1/2" Torque-Thru Swivel @ 6864' RKB 4 1/2" 12.6lb/ft Slotted liner Baker Model B Hook Hanger C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-11_22525_KRU_1B-101_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22525 KUP 1B-101 50-029-23173-00 LeakPoint Survey 11-Feb-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM • . WELL LOG TRANSMITTAL PROAc1ivE DiAgNOSric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : AkAii0 JUL 3 201 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 C ? 6( 1) Caliper Report 04- Jun -11 1B-101 1 Report/ CD 50 -029- 23173 -00 2) ./7i� Signed : Date : ' � �� ab 14 Print Name: o k PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E-MAIL : PDSANCHORAGE(C )MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets \ConocoPh llips_Transmit.docx R03—'133 ' • • Memory Multi- Finger Caliper 1 e Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1B-101 Log Date: June 4, 2011 Field: Kuparuk (West Sak) Log No.: 10157 State: Alaska I Run No.: 2 API No.: 50-029-23173-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBT- MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 6,851 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : I The caliper data is tied into the WLEG at 6,828' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I The caliper recordings indicate the 4.5" tubing appears to be in good condition, with no significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. This is the second time a PDS caliper has been run in this well and the 4.5" tubing has been logged. A 1 comparison between the current and the previous log (May 30, 2009) indicates a slight increase in recorded wall penetrations since the previous log. A comparison graph illustrating the difference in maximum recorded penetrations on a joint -by -joint basis is included in this report. I 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: I No significant wall penetrations are recorded. 4.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: I No significant areas of cross - sectional wall loss (> 7 %) are recorded. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: I No significant I.D. restrictions are recorded. 1 Mandrel Orientation IB -101 ConocoPhilli•s Alaska, Inc. Ku,aruk West Sak June 4, 2011 Tool Joint No. Dev iation Mandrel No. Latch t 7ricntation 112.2 65 1 12:00 1 190.2 68 2 4:00 1 Field Engineer: E. Gustin Analyst: M. Lawrence & C. Lucasan Witness: C. Kennedy I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com III Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 P. — i -, 1 • • Correlation of Recorded Damage to Borehole Profile 1 • Pipe 1 4.5 in (15.7' - 6827.5') Well: 1B-101 Field: Kuparuk (West Sak) Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: June 4, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 22 1 '1 25 _ 765 1 g 50 G 1536 a3 ,a 75 t 2311 I : ____A 1 100 . 3108 p GLM 1 E L Z 125 _ 1 o — 3905 y o Oa) 150 1 4672 1 175 1 5443 1 GLM 2 1 200 A 6364 1 il 214.1 6828 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 214.1 1 1 1 • • 1 Maximum Recorded Penetration Comparison To Previous I Well: 1 B-101 Survey Date: June 4, 2011 Field: Kuparuk (West Sak) Prev. Date: May 30, 2009 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 40 No. 217957 I Country: USA Tubing: 4.5" 12.61b L- 80IBT- -Mod Overlay Difference Max Rec. Pen. (mils) Diff. in Max Pen. (mils) 0 50 100 150 200 250 -100 -50 0 50 100 0.1 0.1 9 9 19 19 29 29 w 39 39 I 49 - 49 59 59 > 69 69 1 79 79 s— 86 86 1 96 96 d 106 d 106 IE E - Z 113 i 113 c 123 c 123 - - 133 133 I ;— 143 143 153 153 ' 163 163 —'_- 173 17T't 183 183 1 190.3 190.3 193 193 -: 1 194.9 194.9 204 204 I 214 714 -50 -25 0 25 50 • June 5, 2011 ■ May 30, 2009 Approx Corrosion Rate (mpy) 1 1 1 1 • • 1 PDS Report Overview tea. Body Region Analysis I Well: 1B-101 Survey Date: June 4, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 4.5 ins 12.6 ppf L -80 IBT -Mod Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4.5 ins 12.6 ppf L -80 IBT -Mod 3.958 ins 4.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 250 i NM Penetration body NI= Metal loss body 0 50 100 200 0 150 100 50 i 50 0 I 0 to 20% 20 to 40 to over 40% 85% 85% Number of joints analysed (total = 230) I I 230 0 0 0 98 1 ' Damage Configuration ( body) CLM 1 --- 10 i A ' 146 5 A 1 1 0 G LM 2 192 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pox Hole I Number of joints damaged (total = 8) 8 0 0 0 0 Bottom of Survey = 214.1 1 1 1 1 • PDS REPORT 1 OINT TABULATION SHE I Pipe: 4.5 in 12.6 ppf L -80 1BT Mod Well: 1B-101 Body Wall: 0.271 in Field: Kuparuk (West Sak) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 3.958 in Country: USA Survey Date: June 4, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 16 0 0 0 0 3.98 Hanger I 0.2 18 0 0.01 6 1 3.89 Pup Lt. Deposits. 1 22 0 0.02 6 1 3.89 Lt. Deposits. 2 53 0 0.02 7 1 3.90 3 84 0 0.02 9 2 3.86 Lt. Deposits. I 4 115 0 0.02 8 1 3.90 5 146 0 0.03 11 3 3.90 Lt. Deposits. 6 177 0 0.02 7 1 3.89 Lt. Deposits. 7 207 0 0.02 9 2 3.91 I 8 239 0 0.02 8 1 3.90 Lt. Deposits. 9 271 0 0.02 8 2 3.91 10 301 0 0.03 11 2 3.90 Lt. Deposits. ■ 11 333 0 0.03 11 1 3.89 Lt Deposits. ■ I 12 363 0 0.03 10 1 3.88 Lt. Deposits. 13 394 0 0.02 9 2 3.90 Lt. Deposits. 14 425 0 0.03 10 1 3.90 15 457 0 0.02 8 1 3.89 Lt. Deposits. 16 488 0 0.02 8 2 3.90 I 17 518 0 0.02 8 2 3.90 Lt. Deposits. 18 549 0 0.03 10 1 3.90 19 580 0 0.02 9 1 3.89 Lt. Deposits. 20 611 0 0.02 7 2 3.90 I 21 642 0 0.02 7 1 3.91 22 674 0 0.02 8 2 3.91 23 704 0 0.02 8 2 3.90 Lt. Deposits. 24 734 0 0.03 10 2 3.90 ■ I 25 765 0 0.03 10 3 3.87 Lt. Deposits. i• 26 797 0 0.03 11 2 3.89 Lt. Deposits. 27 828 0 0.02 8 1 3.90 Lt. Deposits. 28 858 0 0.03 10 3 3.90 Lt. Deposits. 3 I 29 889 0 0.02 8 2 3.90 Lt. Deposits. 30 919 0 0.02 8 1 3.90 31 950 0 0.03 9 2 3.89 Lt. Deposits. IN 32 980 0 0.03 10 2 3.90 Lt. Deposits. 33 1011 0 0.02 9 2 3.91 34 1042 0 0.02 8 1 3.90 35 1072 0 0.02 8 1 3.90 36 1103 0 0.03 11 2 3.89 Lt. Deposits. • 37 1134 0 0.03 10 2 3.91 I 38 1164 0 0.02 8 2 3.89 Lt. Deposits. 39 1195 0 0.02 8 2 3.91 40 1226 0 0.03 10 2 3.91 41 1256 0 0.02 8 1 3.90 Lt. Deposits. I 42 1288 0 0.02 7 1 3.91 43 1320 0 0.02 9 1 3.91 44 1350 0 0.02 8 2 3.88 Lt. Deposits. 45 1381 0 0.02 8 2 3.91 I 46 1411 0 0.03 11 3 3.91 ■ 47 1442 0 0.03 10 2 3.92 ■ 48 1473 0 0.03 11 3 3.90 tion Body I Metal Penetra Loss Body Page 1 1 1 PDS REPO RT J OINT TABULATION SHE I Pipe: 4.5 in 12.6 ppf L -80 IBT -Mod Well: 113-101 Body Wall: 0.271 in Field: Kuparuk (West Sak) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 3.958 in Country: USA Survey Date: June 4, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 49 1505 0 0.03 10 1 3.91 I 50 1536 0 0.02 8 2 3.92 51 1567 0 0.02 9 2 3.92 52 1599 0 0.03 10 2 3.90 Lt. Deposits. 53 1627 0 0.02 7 2 3.91 I 54 1658 0 0.03 9 1 3.92 55 1689 0 0.02 8 2 3.90 56 1719 0 0.03 11 3 3.92 ■ 57 1750 0 0.03 9 2 3.92 • I 58 1782 0 0.03 10 2 3.91 ■ 59 1813 0 0.03 10 2 3.90 60 1843 0 0.02 7 2 3.91 61 1874 0 0.02 8 2 3.91 I 62 1906 0 0.02 8 2 3.91 63 1936 0 0.03 10 3 3.85 Lt. Deposits. ■ 64 1967 0 0.03 11 2 3.91 m 65 1998 0 0.02 8 2 3.90 66 2029 0 0.03 10 3 3.93 I 67 2060 68 2091 0 0.02 8 3 3.91 0 0.02 7 2 3.92 3 69 2121 0 0.03 10 3 3.91 70 2152 0 0.02 8 2 3.90 Lt. Deposits. 71 2183 0 0.03 11 2 3.90 • 72 2215 0 0.03 10 3 3.89 Lt. Deposits. • 73 2247 0 0.02 9 2 3.90 Lt. Deposits. 74 2279 0 0.03 9 2 3.91 ■ I 75 2311 0 0.03 11 2 3.90 ■ 76 2342 0 0.03 10 3 3.91 77 2373 0 0.02 9 3 3.89 Lt. Deposits. 78 2405 0 0.02 7 1 3.92 3 I 79 2436 0 0.03 10 2 3.92 80 2466 0 0.02 9 2 3.90 Lt. Deposits. 81 2497 0 0.03 11 3 3.86 Lt. Deposits. ■ 82 2528 0 0.03 10 2 3.92 83 2559 0 0.02 8 1 3.92 I 84 2590 0 0.02 9 1 3.92 85 2621 0 0.02 8 2 3.92 85.1 2653 0 0.02 8 3 3.91 Pup 85.2 2662 0 0 0 0 3.81 Camco BP6 -1 Nipple I 85.3 2665 0 0.03 11 2 3.93 Pup 86 2675 0 0.02 8 2 3.90 Lt. Deposits. 87 2706 0 0.03 9 3 3.88 Lt. Deposits. 88 2738 0 0.02 7 2 3.90 I 89 2769 0 0.02 8 2 3.91 90 2799 0 0.02 8 2 3.93 91 2831 0 0.02 9 3 3.91 92 2861 0 0.02 7 2 3.92 I 93 2892 0 0.02 8 1 3.91 94 2923 0 0.02 7 1 3.91 95 2953 0 0.02 8 2 3.92 I Penetration Body 1 Metal Loss Body Page 2 1 ' REPO PD S REPORT JOINT TABULATION SHER O I Pipe: 4.5 in 12.6 ppf L -80 IBT -Mod Well: 1B-101 Body Wall: 0.271 in Field: Kuparuk (West Sak) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 3.958 in Country: USA Survey Date: June 4, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 96 2985 0 0.02 8 1 3.91 I 97 3016 0 0.03 11 3 3.91 • 98 3046 0 0.03 10 2 3.92 ■ 99 3076 0 0.03 11 3 3.91 100 3108 0 0.02 8 2 3.89 Lt. Deposits. I 101 3139 0 0.03 9 2 3.91 102 3171 0 0.02 8 3 3.92 103 3201 0 0.02 8 2 3.91 104 3232 0 0.03 10 2 3.86 Lt. Deposits. ■ I 105 3262 0 0.03 10 2 3.92 106 3294 0 0.02 7 2 3.92 107 3325 0 0.02 9 2 3.92 108 3357 0 0.02 8 3 3.84 Lt. Deposits. I 109 3389 110 3420 0 0.03 10 2 3.92 0 0.02 8 2 3.92 111 3450 0 0.03 10 1 3.91 112 3481 0 0.02 8 2 3.91 112.1 3512 0.04 0.04 16 4 3.93 Pup Shallow Line of Pits. I 112.2 3517 0 0 0 0 3.87 GLM 1 (Latch @ 12:00) 112.3 3524 0 0.03 11 3 3.92 Pup 113 3531 0 0.02 8 2 3.91 114 3562 0 0.02 8 3 3.92 I 115 3593 0 0.04 15 2 3.91 Shallow Pitting. ■ 116 3624 0 0.03 10 2 3.91 ■ 117 3656 0 0.03 10 3 3.87 Lt. Deposits. 118 3688 0 0.02 9 1 3.92 I 119 3719 0 0.03 10 3 3.90 Lt. Deposits. 120 3750 0 0.02 8 2 3.91 121 3780 0 0.02 8 1 3.92 122 3811 0 0.02 8 1 3.91 I 123 3843 0 0.02 9 3 3.92 124 3874 0 0.02 8 2 3.92 125 3905 0 0.03 10 2 3.92 126 3935 0 0.02 7 1 3.91 3 127 3965 0 0.02 8 2 3.92 ' 128 3996 0 0.02 8 1 3.91 ■ 129 4026 0 0.02 8 2 3.92 a 130 4057 0 0.02 8 2 3.89 Lt. Deposits. 131 4088 0 0.02 8 1 3.92 • I 132 4116 0 0.02 9 1 3.92 as 133 4147 0 0.03 9 1 3.88 Lt Deposits. ■ 134 4178 0 0.03 13 3 3.86 Shallow Line of Pits. Lt. Deposits. 135 4209 0 0.02 8 2 3.92 I 136 4240 0 0.03 11 2 3.89 Lt. Deposits. ■ 137 4271 0 0.03 9 3 3.87 Lt. Deposits. 138 4303 0 0.02 8 2 3.91 139 4334 0 0.03 10 2 3.90 I 140 4364 0 0.02 8 2 3.92 141 4395 0 0.03 10 1 3.93 ■ 142 4427 0 0.03 10 1 3.91 ain I I Penett0 r Metal Loss Body Page 3 . 1 1 • PDS REPORT JOINT TABULATION SHER I Pipe: 4.5 in 12.6 ppf L -80 IBT -Mod Well: 1 B -101 Body Wall: 0.271 in Field: Kuparuk (West Sak) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. 1 Nominal I.D.: 3.958 in Country: USA Survey Date: June 4, 2011 I Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 143 4457 0 0.03 11 4 3.91 144 4487 0 0.02 9 1 3.87 Lt. Deposits. 145 4518 0 0.03 11 3 3.91 146 4549 0 0.02 9 1 3.91 ] . 147 4581 0 0.02 9 2 3.91 I 148 4611 0 0.02 8 2 3.92 149 4641 0 0.03 10 2 3.91 NI 150 4672 0 0.03 10 1 3.91 no 151 4703 0 0.03 10 3 3.91 ■ I 152 4735 0.03 0.03 13 7 3.86 Shallow Line of Pits. Lt. Deposits. 153 4765 0 0.03 10 2 3.92 IN NI 4796 0 0.03 10 2 3.91 ■ 155 4826 0 0.03 10 2 3.91 3 156 4858 0 0.02 9 2 3.91 I 157 4889 0 0.02 8 2 3.90 158 4919 0 0.03 10 2 3.91 ■ 159 4950 0 0.03 9 2 3.90 ■ 160 4981 0 0.03 10 2 3.89 Lt. Deposits. I 161 5011 162 5042 0 0.02 8 2 3.91 0 0.03 11 2 3.90 ■ 163 5073 0 0.03 11 1 3.92 N 164 5103 0 0.03 12 1 3.91 Shallow Pitting. • I 165 5134 0 0.03 10 2 3.90 166 5165 0 0.02 8 1 3.91 167 5195 0 0.02 8 1 3.90 3 168 5226 0 0.03 11 2 3.90 IN I 169 5258 0 0.03 9 2 3.90 Ni 5289 0 0.03 10 3 3.86 Lt. Deposits. ■ 171 5319 0 0.03 11 3 3.86 Lt. Deposits. 7 172 5350 0 0.02 8 3 3.88 Lt. Deposits. 173 5381 0 0.03 10 3 3.89 Lt. Deposits. I 174 5412 0 0.02 8 2 3.91 175 5443 0 0.02 8 2 3.90 3 176 5475 0 0.03 9 3 3.90 Lt Deposits. 177 5505 0 0.02 8 2 3.90 I 3 178 5535 0 0.02 8 1 3.90 179 5566 0 0.03 10 2 3.90 180 5596 0 0.02 8 2 3.90 181 5626 0 0.03 10 3 3.85 Lt. Deposits. I 182 5658 0 0.02 9 2 3.91 183 5690 0 0.02 8 3 3.84 Lt Deposits. 184 5722 0 0.03 10 2 3.90 185 5753 0 0.02 8 1 3.90 I 186 5784 0 0.03 11 2 3.91 187 5815 0 0.02 9 2 3.89 Lt. Deposits. 188 5846 0 0.03 10 2 3.90 Lt. Deposits. 189 5877 0 0.03 10 2 3.87 Lt Deposits. I 1 90 5906 0 0.02 8 2 3.90 Lt. Deposits. 190.1 5936 0.04 0.03 13 4 3.92 Pup Shallow Line of Pits. 1 190.2 5942 0 0 0 0 3.82 GLM 2 (Latch @ 4:00) Penetration Body I Metal Loss Body Page 4 1 1 0 PDS REPORT JOINT TABULATION SHE I Pipe: 4.5 in 12.6 ppf L -80 IBT -Mod Well: 1B-101 Body Wall: 0.271 in Field: Kuparuk (West Sak) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 3.958 in Country: USA Survey Date: June 4, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 190.3 5949 0 0.04 14 3 3.90 Pup Shallow Line of Pits. 1 191 5955 0 0.02 8 2 3.89 Lt. Deposits. 191.1 5982 0 0 0 0 3.94 Camco DB Nipple 191.2 5984 0 0 0 0 3.81 Baker CMU Sliding Sleeve 191.3 6003 0 0 0 0 3.75 Baker Polished Sealbore I 191.4 6007 192 6016 0 0.02 7 1 3.91 Pup 0 0.03 11 2 3.90 192.1 6047 0 0.01 6 1 3.91 Pup 192.2 6056 0 0 0 0 3.87 Baker Guardian Gauge Bottom Sub I 192.3 6058 0 0.02 8 2 3.92 Pup 193 6067 0 0.03 10 3 3.85 Lt. Deposits. 194 6098 0 0.02 8 2 3.90 194.1 6130 0 0.02 8 3 3.91 Pup I 194.2 6136 0 0 0 0 3.87 Baker 80-47 Polish Bore Receptacle 194.3 6158 0 0.02 8 1 3.92 Pup 194.4 6164 0 0.01 6 1 3.90 Pup 194.5 6168 0 0 0 0 4.55 Packer Mill Out Ex 194.6 6180 0 0.02 7 1 3.91 Pup I 194.7 6187 0 0.02 7 2 3.88 Pup Lt. Deposits. 194.8 6197 0 0 0 0 3.69 Camco DB Nipple 194.9 6198 0 0.01 5 1 3.92 Pup 195 6208 0 0.03 10 2 3.89 Lt. Deposits. I 196 6240 0 0.02 8 2 3.89 Lt. Deposits. 197 6270 0 0.02 8 2 3.91 198 6301 0 0.02 8 3 3.89 Lt. Deposits. 199 6332 0 0.02 7 1 3.90 I 200 6364 0 0.03 12 3 3.84 Lt. Deposits. 201 6395 0 0.02 8 2 3.89 Lt. Deposits. 202 6427 0 0.03 9 2 3.90 Lt. Deposits. ■ 203 6458 0 0.03 10 1 3.90 Lt. Deposits. I 204 6489 0 0.03 11 2 3.90 Lt. Deposits. ■ 205 6520 0 0.03 11 2 3.90 Lt. Deposits. 206 6550 0 0.02 8 2 3.90 Lt. Deposits. N 207 6581 0 0.03 10 1 3.90 ■ 208 6611 _ 0 0.03 11 2 3.91 I 209 6642 0 0.02 8 2 3.89 Lt. Deposits. 210 6673 0 0.02 8 1 3.90 Lt. Deposits. 211 6703 0 0.02 7 2 3.89 Lt. Deposits. 212 6734 0 0.02 8 2 3.90 I 213 6764 0 0.02 8 3 3.85 Lt. Deposits. 214 6796 0.04 0.04 15 2 3.90 Shallow Pitting. Lt. Deposits. 214.1 6828 _ 0 0 0 0 3.87 WLEG I 111Pme at ion etanetr l Loss Bo dy 1 1 Page 5 1 1 I `, ConocoPhillips ti. lattributes7 ngle 8 MD 1 TD B -1 Alaska, Inc APIA/WI td Name Well Shdres I MD (ftKB) Ad aim (ftKB) Co,xmR��s 500292317300 EST SAK PROD 92.86 7,803.28 12230.0 Comment N2S(ppm) Date Annotation End Date K8&d(11) Mg Release Date I ••• Wen Goan - 1a1o1, 1o7s]zo10 1s72a PM S SSV: W RDP 75 6/18/2006 Last WO: 34.70 8/31/2003 Sin - 101, 1 Actual Annotation Depth MB) End Date Amotation Last Mod._ End Date Last Tag: Rev Reason: FORMAT UPDATE Imosbor 10/9/2010 Casino Strin 1 s HANGER. 23 i I i C asing Description Sing 0... String ID ... Tap (m66) Set Depth (L.. Set Depth (TVD) ... String Wt.. String... String Top 7hrd CONDUCTOR 16 15.062 34.7 148.0 148.0 62.50 H -40 WELDED I Casing g Description String 0... String ID ... Tap MKS) Set Depth p... Set Depth (ND) ... - t.. ng W Sing... String Top d ( SURFACE 103/4 9.754 28.3 3,080.4 2,199.8 40.55 L - 80 BTC - M Casing Description String 0... Wing g ID _. Tap (RKB) Set Depth (6... Set Depth (TVD) _ String Wt.. Siting... String Top 7199 PRODUCTION 75/8 6.875 27.1 7,388.9 3,730.3 29.70 L - 80 BTC - M . Casing Description .. ng 0... String ID ... Top (RKB) Sat Depth (L.. Set Depth (7VD) - .. String Wt.. Sing... S6Ng Top 11rd LINER B-SAND 4 1!2 3.958 6,882.2 12,230.0 12.60 L -80 NSCT CONDUCTOR Liner Retells 35-148 1 li Top Depth (ND) Top Inc! Nami- Top MB) Mti(N (') Rem Description Comment ID (11* WRDP, 2.655 6,882.2 3,664.0 75.68 PACKER BAKER SC - 1R RERIEVABLE PACKER w/EXTENSION 4.000 NIPPLE, 2.665 ..... 6,887.0 3,665.2 75.69 EXTENSION BAKER EXTENSION 4.890 I 6,889.1 3,665.7 75.70 X0 5.5x4.5" CROSSOVER 5.5'X45" 3.890 12,196.5 3,713.9 91.66 BUSHING BAKER PACKOFF BUSHING 3.958 S Tea 6 Tubing Strings Tubing Description String 0... String ID ... Top (1(B9 Set Depth (L.. Set Depth (ND) ... Sing Wt.. String ... String Top Tod TUBING 4 1/2 3.958 23.1 6,829.6 3,650.9 1250 L -80 )BT MOD I 0 3,5 9 Completion Details Ell Top Depth (TVD) Top Inc! Nom!_ Top anua MIKN (9 Item Description Comment ID (11* 23.1 23.1 -3.12 HANGER VETCO GRAY TUBING HANGER 4.500 - -- 2,665.1 2,031.7 67.07 NIPPLE CAMCO'BP6.1' NIPPLE 3.812 I GAS LIFT. , 5,996.1 3,399.3 69.03 NIPPLE CAMCO 'DB' NIPPLE 3.938 5 5.542 5,998.3 3,400.1 69.02 SLEEVE -O BAKER CMU SLIDING SLEEVE (OPENED 5/29/2009) 3.813 6,003.6 3,402.0 69.01 PSB BAKER POLISHED SEAL BORE 3.750 6,056.4 3,421.0 68.88 GAUGE BAKER GUARDIAN GAUGE CARRIER 3.980 - CARRIER I SLIPSTOP 6,141.1 3,449.2 67.46 PBR BAKER 80 POLISH BORE RECEPTACLE 3.870 5 995 NIPPLE, 5,996 6,171.7 3,461.6 68.32 PACKER BAKER S3 PACKER w/MILLOl7T EXTENSION @ 617T, ID 4.55" 3.875 6,177.1 3,463.7 68.47 EXTENSION PACKER MILLOUT EXTENSION 4.550 SLEEVE - 0, 5.998 - ,•,.._ 6,198.7 3,471.9 69.08 NIPPLE CAMCO 'DB' NIPPLE 3.687 PUMP, 5,996 I 6,828.2 3,650.5 75.37 SHOE WIRELINE ENTRY GUIDE 3.870 P99. 6,004 I ' Other In Hole e y reline retrievable plugs, valves, pumps, fish, etc.) Top (TVD) Top Ind Tap MKS) gem r) DesC9p9an Comment Run Date ID O1* _ 2,665.1 2,031.7 67.07 WRDP 3.81' DB WRDP 2 LO (HAAS GOOD 6/21/2009 2.125 I GAUGE CLOSURE TEST (OAL =69') MIli "MUST USE CENTRALIZER WHEN SETTING WRDP"' CMRER. 5,995.0 3,399.0 69.03 SLIPSTOP 4.5" SLIP STOP ON TOP OF JET PUMP @ 5996' RKB 6202009 2.500 6,056 5,996.0 3,399.3 69.03 PUMP 3.75 °DB LOCK w/ 3" RC JET PUMP ( SER. PH- 1092)12 -A 6/20/2009 0.000 RATIO: it 12 NOZZLE 8 12 THROAT ( 126" OAL ) I _ Perforations 8 Slots PBR, 6,141 Shot h , s T op (NN Sim (TVD) _ -.. Top ( Wm Mme) MIN root zone Date (sn.- hype Comment _ 7,480.0 12,196.0 3,734.4 3,713.9 WS B, 1B -101 9/8/2003 16.0 SLOTS SLOTTED LINER, 0.25'x 2.5" slots, PACKER, 6.172 _ alternating blank/slotted 31' joints i f w /16 shots per slotted joint EXTENSION, Notes: General & Safety 6,117 I End Date Annotation 9/52003 NOTE: MULTILATERAL WELL: B-SAND(1B-101), DSAND(1B-101L1) I NIPPLE, 6,189 ii:Tiji 9/8/2003 NOTE: TREE CAP CONNECTION: 10.75'" CWCT ELECTRIC FEEDTHRU MANDREL, HORZT OUTLET 9/8/2003 NOTE: TREE: ABB VETCO GRAY/ HORZT / 4 1116 "' 5M w /PENETRATOR WIRE 7/172009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 SHOE, 6O N I PRODUCTION. . 27 -],389 SLOTS. 7480 - 12.196 LINER DSAND, 6.847- 12.173 a I Mandrel Details I se Tap Depth Top Port (7VD) Ind OD Valve Latch Size 7120 Run Sin Top (MB) MAN 19 mite tom IW ry Type Type R+) (ps9 Run Date Com_ 1 3,519.4 2,382.9 65.29 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 11/8/2003 l 2 5,941.8 3,378.9 67.83 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 9/82003 I LINER B -SAND, 6.882-12230 TO (18 -101). 12,230 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 r ay . t iNED JUL r, 1E0 Commissioner Dan Seamount Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100t�,,,,��ission Anchorage, AK 99501+' Commissioner Dan Seamount: �0 _ 3 3 1 0— 01 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -03 50029206150000 1810880 _ 16" N/A 23" N/A 1.7 6/20/2011 1A-04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 _ SF _ N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 _ 18" N/A 18" N/A 2.5 6/21/2011 1B -05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1B -07 50029206160000 1810890 7'2" 1.00 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1 B -09 50029206550000 1811340 SF N/A 23" N/A _ 5 6/20/2011 1 B -10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 B -12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B 101 50029231730000 2031330 _ 3" _ N/A 22" N/A 1.7 6/21/2011 1E3-102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21 /2011 1E -05 50029204790000 1800580 _ 19" N/A 19" N/A 1.7 6/19/2011 1E -22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 1821840 58' 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 155" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 14'9" _ 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 10-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y -02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 ~ ~ S WELL LOG TRANSM/TTAL PROActivE D'u~cNOS~ic SeRVicES, INC_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration [Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastu~tka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 ~03 ^ ~33 and ProActive Diagnostic Services, Inc. ~ ~/~~ Attn: Robert A. Richey 130 West International Airport Road nn ~~tt Suite C ~ ~. .. Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 30-May-09 1 &101 2) Signed Print Name: 1 Report / EDE 173-00 .~ ,-~ SUN 0 ~ 20u9 ~ilae cans. ~~,missian anchorage PROACTNE DIAGNOSTIC SERVICES, MC., 130 W, INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE; (907)245-8951 FAX: (907)245$8952 E-WAIL : pdsanchorage(a~memoryloa.com WEBSITE : www.memoryloa.com ^ C:\Documen6 and Settings\Owner\Desktop\1Yansmit BP.docx • • Memory Multti-Finger Caliper & MTf Log Results aummary ~. Company: ConocoPhillips Alaska, Inc. Well: 1B-101 Log pate: May 30, 2009 Fiefd: West Sak Log No.: 7330 State: Alaska Run No.: 1 API No.: 50-029-23173-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBTM Top Log lntvl.: Surtace Pipet Use; Tubing Bot. Log Intvt.: 6,828 Ft. (MD) Pipet Desc.: 7.625" 29.71b. L-80 BTC-M Top Log lntvl.: 3,088 Ft. (MDR Pipet Use: Production Casing Bot. Log Intvl.: 6,828 Ft. (MD) inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS The log data is tied into the 4.S" tKLEG ~ 6,828' (Drlller's Depth). This is the first log of this well made with the Multi-Finger Caliper and 12 Arm Magnetic Thickness Tool (MTT). A single pass at 10Hz was made at 20 fpm. The additional metal volume of the 10.75" surface casing exceeds that in which the MTT can function normally, so no interpretable MTT results are available from the end of the 10.75" surface casing to surface. INTERPRETATION OF CALIPER LOG RESULTS : This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing is in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (>19°~) are recorded. 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss {> 7%) are recorded. 4.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. INTERPRETATION OF MTT LOG. RESULTS The 10Mz MTT log results cover the interval from 3,068' to 6,828'. A graph of the change in overall metal thickness on a joint-by joint taasis relative to the calibration point is included in this report. This graph indicates relative metal loss ranging from 0-4% throughout the logged interval, with these variances appearing to be more closely related to manufactured variances in the tubing wall thickness, rather than corrosive damage to the tubing or casing. A maximum overall metal volume toss of 4% is indicated in tubing joint 166 (5,161' - 5,191'). All reported variances in metal thickness are relative to the calibration point at 4,004', where the readings are assumed to represent undamaged pipe. All other readings are relative to this reference point. ProActive Diagnostic Services, Inc. ,' P.O. Box: 1369, Stafford, TX ??497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS!amemorylog.com Prudhoe Bay Field Office Phone: (90?) 659-230? Fax: (90?) 659-2314 X03 -/.~3 ~ ~~~ ~ • ! White indications of loss of overall metal thickness appear to be somewhat minimal, the recordings exhibit varying isolated event patterns resembling a line of corrosion with some areas of broader circumferencial distribution. These patterns of isolated metal loss indications point to potential areas of minor corrosive damage to the outside of the tubing or more significant damage to the casing. Lag plots of the 10Hz MTT recordings aver the intervals (3,162' - 3,226'), (3,907' - 4,055'}, (4,126' - 4,204') and (6,548' - 6,635') are included in the report to show these patterns. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5" and 7.625" pipe. if all of the metal toss is specific to the 7.625" production casing or 4.5" tubing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 7.625" production casing. Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@merr~orylog.com Prudhoe bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231.4 I ~1 Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (0.5' - 6828.0') Well: 1 B-101 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 30, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 4 750 1522 2299 3099 ~ GLM 2 c 3897 s . . Q a~ O 4666 5439 GLM 1 6363 214.1 6828 0 5 0 100 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 214.1 1 25 50 3 75 100 E Z 125 c ~ o 150 175 200 PDS Report Overview 1,_ s. Body Region Analysis Well: 18-101 Survey Date: May 30, 2009 Field: West Sak Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 IBTM 3.958 ins 4.828 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body y metal loss body 200 150 100 50 0 0 to 1 to 10 ro 20 to 40 ro over 1% 1n% 20% 40% 85% 85% Number of ~oints anal sed rota) = 231 pene. 26 195 10 0 0 0 loss 71 160 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 0 50 98 GLM 2 146 GLM 1 191 Bottom of Survey = 214.1 Analysis Overview page 2 PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: Body Wall: 0.271 in Field: Upset Wall: 0.435 in Company: Nominal I.D.: 3.958 in Country: Survey Date: s i LATI O N SHEET 18-101 West Sak ConocoPhillips Alaska, Inc. USA May 30, 2009 Joint No. Jt. Depth (Ft) N~~n. UI>.~~t (lrn-1 Pen. Body (Ins.) Pen. % Met,~l I~~~s ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 0 u 0. 1 3 I 3.9 PUP 1 4 ~) 0. 1 3 3.93 5 U 0.01 3 3.93 3 67 ~ 1 0.01 3.88 7 U 0.01 3 I 3.93 5 1 8 U 0. 1 l I 3.9 6 159 ~ i 0. 1 3 ~ 3.93 7 190 ~ ~ 0.01 4 I 3.9 2 2 t) 0.01 4 ~ 3.9 9 253 U 0. 1 4 3.92 1 284 tl 0.01 3.93 11 16 a 0.01 3 ' 3.93 2 346 a 0.01 3 _' 3.91 1 377 t) 0. 1 ~i 2 14 409 U .O1 3 3 3.93 15 440 ~) 0.01 i 3.92 16 471 t) 0.02 t3 3 3.92 17 5 2 i ~ 0.01 ~ (, .94 18 53 i ~ 0.01 3 I 3. 3 1 564 a .01 3 1 3.92 20 595 t) 0.01 4 I 3.95 21 6 U 0. 1 3 1 3.9 22 658 u 8 3.93 23 689 a 0.01 3 3.94 4 719 U 0.0 8 t 25 750 t1 0.00 1 I 3.91 26 782 U .O1 4 I 3.93 27 812 t) 0.01 2 _' 3.92 843 U 0.01 2 s .9 29 873 U 0.01 3 I 3.93 30 04 l) 0. 1 3 5 3.95 3 935 t) 0.01 5 I 3.93 3 965 t J 0.01 -1 3.93 33 996 U 0.00 1 ~ 3.94 34 102 7 ~) 0.01 4 s 3.93 35 1057 ! ~ 0.00 1 3 3.93 6 1088 U 0.01 4 ? 3.9 37 1119 t) 0.01 3 5 3.94 3 1150 t~ 0.01 Z _' 3.92 39 1180 t ~ 0.01 ; .? 3.92 40 1212 t) 0.01 5 ~ 3.92 41 1242 t) 0.00 1 Z 3.93 4 1274 a 0.01 ?' _' 3.9 43 1306 U 0.01 4 ~ 3.93 44 1336 t) 0.01 3 _' 3 92 45 1367 tt 0.01 3 I 3.93 46 1397 t) 0.01 Z ' .92 47 1428 ~) 0.01 ) 3.93 48 1 0 n 0.03 1 n a 3.89 49 1492 ~ ~ 0.02 ~s 3.91 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: Body Wall: 0.271 in Field: Upset Wall: 0.435 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ELATION SHEET 1 B-101 Kuparuk ConocoPhillips Alaska, Inc. USA May 30, 2009 Joint No. Jt. Depth (Ft.) I'~~n. Ul~ct~~ (Irn.) Pen. Body (Ins.) Pen. °4, ~1c~t,~l Lusti ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1 22 i~ 0.01 3 3.94 51 1554 i~ 0.01 ~ S 3.93 52 586 t ~ 0.00 1 :' 3.92 53 1614 t) 0.02 t3 3.92 54 1645 l~ 0.01 ~ 3.91 55 1676 U 0.01 t -' 3.91 56 1706 t ~ 0.01 ~ 3.92 57 1737 t~ 0.02 F3 ~ 3.94 58 1769 i~ 0.01 3 ~ 3. 2 59 1800 t ~ 0.01 4 .93 60 1830 (? 0.01 3 ~' 3.9 61 1862 t ~ 0.00 I I 3.9 6 1893 t ~ 0.01 ~' I 3.93 63 192 3 i ~ 0.01 ~ I 3.90 64 1954 (t 0.01 ~ I 3.93 65 1985 t) 0.00 I s 3.91 66 016 U 0.01 ~ I 3.95 67 2048 t) 0.01 ~ 3.94 68 2079 i i 0.01 ._' 3.94 69 2109 t~ 0.01 ~ ~" 3.93 70 214 t~ 0.01 2 I 3.91 71 2171 (~ 0.01 3 ! 3.92 72 2203 c~ O.Oi 2 ~ 3.91 73 2235 U 0.03 1(1 ? 3.90 74 22 7 t) 0.01 3 ~ 3.93 75 2299 l~ 0.01 4 1 3.93 76 2330 a 0.01 ~ ? 3.93 77 2361 O 0.01 ~ 3.91 78 2393 (~ 0.03 1 t ~ 1 3.95 79 2425 (~ 0.02 ~~ I 3.94 80 2455 t ~ 0.01 s 1 3.92 81 2486 t~ 0.01 t Z 3.85 82 2517 t~ 0.01 ; I 3.93 83 2549 U 0.01 4 I 3.94 84 2579 l) 0.00 1 1 3.95 85 2610 t) 0.01 I 3.95 85.1 2641 t~ 0.01 t 3.93 PUP 85.2 2651 U 0 i ~ i ~ 3.81 Carnco BP61 Ni le 85.3 2654 U 0.01 _' I 3. PUP 86 2664 t~ 0.02 ti t, 3.91 87 2696 U 0.01 3.88 88 2727 U 0.01 ~ 1 3.91 89 2758 U 0.03 11 2 3.93 90 2789 U 0.01 4 1 3.95 91 2821 t1 0.01 9 ~' 3.93 92 2851 t~ 0.01 ' 1 3.92 93 2882 a 0.02 is t 3.93 94 2913 (~ 0.01 s 1 3.93 95 2944 n 0.01 i I 3. 4 96 2975 i 1 0.01 4 3.93 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: Body Wall: 0.271 in Field: Upset Wall: 0.435 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • i CATION SHEET 1 B-101 West Sak ConocoPhillips Alaska, Inc USA May 30, 2009 Joint No. Jt. Depth (Ft.) I'c~n. 111 ~~c~l (ln~.) Pen. Body (Ins.) I'cn. `;4, ti1~~l;rl Lcx °-~> Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 97 3006 ti 0.01 3 1 3.93 9 3037 a 0.02 t3 ..' 3.94 99 3067 U 0.01 3 3. 4 100 3099 a 0.01 2 1 3.92 101 3130 t) 0.0 10 1 3.93 10 3162 U .01 4 _' 3.93 103 319 U Q.0 & 3.93 104 3223 U 0.02 ti ~ 3.84 105 3253 U 0.02 ~) I 3.94 106 3285 U 0.02 8 I 3. 3 107 3316 t~ .01 2 I 3.93 108 3348 t) 0.02 8 _' 3.86 109 338 t) 0.01 ~ 1 3.92 1 10 341 1 t~ 0.00 1 2 3.93 111 3441 a 0.01 3 1 3.93 112 34 a 0.01 4 ? 3.92 112.1 3503 U 0.02 8 I 3.96 PUP 112.2 3508 tl 0 t) t) N A GL 2 Latch ~ 12:30 11 .3 3516 a 0.01 2 I 3.93 PUP 113 3522 t) 0.03 11 ~ 3.92 114 3554 (~ 0.01 3 3.93 115 3 85 t ~ 0.00 1 1 3.93 116 3616 a 0.01 3 I 3. 3 117 3647 U 0.01 2 I 3.88 118 680 U 0.01 2 3. 3 119 3710 U 0.02 8 ~ 3.89 120 3742 U 0.00 1 ? 3.90 121 3773 l) 0.01 3 1 3.94 122 3804 a .00 1 I .9 123 3835 t) 0.01 _' I 3.92 1 4 3866 t) 0.01 Z I 3.93 125 3897 U 0.02 t3 I 3.92 1 6 3927 l) 0.01 .90 127 3958 U 0.01 3.94 128 398 t) 0.02 t3 I 3.92 129 4019 U 0.05 19 I 3.92 130 4050 t) 0 05 1 t3 3.89 131 4080 a 0.01 ~ I 3.93 132 4109 t> 0.03 11 3 93 133 4140 t ~ 0.01 _' 1 3.88 134 4171 O 0.02 8 ~ 3.82 135 4202 U 0.01 4 3.94 136 4233 O 0.03 11 ; 3.89 137 4264 t) 0.04 16 ; 3.91 138 4296 U 0.01 ~ I 3.92 139 432 7 t ~ 0.01 ~ ; 3.90 1 4358 t ~ 0.02 t3 ~' 3.92 141 4389 t ~ 0.01 ? _' 3.92 14 44 0 " 0.01 t I 3.9 143 4451 0.02 ~~ I 3.92 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: Body Wall: 0.271 in Field: Upset Wall: 0.435 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • iLATION SHEET 1 B-101 West Sak ConocoPhillips Alaska, Inc. USA May 30, 2009 Joint No. Jt. Depth (Ft,) I'~~n. 111s~~1 Iln..) Pen. Body (Ins.) Pa°n. °/~ Mct.~l I~~ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4481 I! 0.00 1 3.87 145 4512 I I 0.01 l -l 3.91 146 4543 ~ 1 0.00 1 I 3.92 147 4575 U 0.02 t3 3.93 148 4605 U 0.01 ~ i 3.93 149 4635 l1 0.01 i 3.91 150 4666 a 0.01 t I 3.93 151 4698 U 0.02 £i 3.91 15 4729 ~) 0.01 3 ? 3 86 153 4759 ~ I 0.00 1 3.91 154 4791 (! 0. 1 :' I 3.92 155 4821 i) 0.01 -1 I 3.92 156 4853 a 0.01 ~ _' 3.91 157 4884 tl 0.01 4 ~ 3.90 58 4915 ~> 0.01 I 3.93 159 4945 t I 0.04 I i 3.91 160 4976 U 0.01 1 _' 3.90 161 5006 11 0.01 .'. ? 3.92 162 5037 II 0.05 17 ~ 3.91 163 5068 tl 0.00 1 _' 3.92 164 5099 ~! 0. 3 1 U 3.91 165 5129 a 0.02 £i 3.91 6 5160 a 0.01 3. 2 167 5191 t1 0.02 £3 ~ 3.92 1 8 5 3 I1 .O1 -i ' 3. 1 169 5253 i! 0.03 lU ; 3.91 170 5285 ll 0.00 1 ~' 3.85 171 5315 (! 0.05 1 £i ? 3.91 172 5346 11 0.01 5 1 .91 173 5378 c! 0.02 £i 4 3.91 174 5409 t) 0.02 7 3.92 175 5439 n 0.00 I ! 3.91 176 5471 tl 0.02 ~~ 2 3.92 177 5501 It 0.00 1 ? 3.92 178 5532 U 0.02 £~ ,! 3.92 179 5563 n 0.00 1 3 3.91 180 5593 I! 0.02 £i ~' 3.92 181 562 3 n 0.01 ~' 3.86 182 5655 U D.00 I 3.92 183 5688 U 0.01 i 3.85 184 571 l) 0.00 I _' 3.9 185 5750 ~ I 0.01 i 1 3.91 186 5781 U 0.00 1 ? 3 89 187 5813 l! 0.01 t 3.88 188 5844 a 0.01 4 _' 3.90 189 5874 ~! 0.00 I 3.86 190 5903 n 0.01 > 3.90 190.1 5934 ~ ~ 0.02 3.92 PUP 190.2 5940 ~? 0 ~! N A GLM 1 Latch 4:00 190.3 5946 ~ 0.01 3.90 PUP Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 IBTM Well: Body Wall: 0.271 in Field: Upset Wall: 0.435 in Cornpany: Nominal I.D.: 3.958 in Country: Survey Date: • iLATION SHEET 1 B-101 West Sak ConocoPhillips Alaska, Inc USA May 30, 2009 Joint No. Jt. Depth (Ft.) 14~n. Uln~~t (In.) Pen. Body (Ins.) I'c~n. `;4~ ~t~ ~,jl lu,> ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 191 5953 ~) .02 ` ~ 3.89 191.1 5984 (~ 0.02 ~ 3.86 PUP 191.2 5995 ~ ~ 0 (l t ~ 3.75 Ca c B Ni le 19 .3 5996 ~~ 0 U U 3. 1 Baker MU Slidin Sleeve 191.4 6002 ~ 1 0 O ~ ~ 3.75 Baker Polished Seal Bore Sub 191. 6003 ~ ~ 0.01 ~ 3.90 PUP 19 6014 ~ ~ 0 02 £s ~~ 3.89 192.1 6044 ~~ 0.01 3.89 PUP 19 .2 6053 (~ 0 ! ~ ! ~ 3.98 Baker Guardian Gau e Carrier'Bottom Sub' 192.3 6055 ~~ 0.01 ~ 3.90 PUP 93 6064 ~ ~ 0.00 1 4 3.86 194 6096 U 0.01 3 4 3.89 194.1 6127 l1 0.03 10 i 3.86 PUP 194.2 6135 U 0 t1 U 3.87 Baker 80-47 Pilished Bore Rece tacle 194.3 61 7 ~? 0.02 1 3.91 P P 194.4 6163 O 0.01 s 2 3.91 PUP 194.5 6168 O 0 U (~ .88 Bak r S- Packer 7.625"X4.5" w Millout Ext 19 .6 6180 l~ 002 '~ ~ 3.86 PUP 194.7 6186 t) 0.01 -1 ~' 3.91 PUN 194.8 6196 u 0 U 0 3 69 Camco DB Ni le 194.9 6199 (? 0 01 3 1 3.91 PUP 195 6207 O 0.01 3 ~ 3.89 196 6 39 U 0.01 3 3.91 197 6270 O 0.01 4 i 3.88 01 O 1 ~ -1 199 6331 (~ 0.01 i 3.88 200 6363 I ~ 0 01 > ~ 3.85 201 6395 (~ 0.00 7 1 3.92 2 2 642 7 U 0.02 f.3 3 3.91 203 6458 I) 0.01 2 ~ 3.90 204 6489 a 0.01 3 2 3 89 205 6521 U 0.01 4 3 3.91 206 6550 U 0.01 .? 1 3.90 207 6581 ~ ~ 0.02 ~ ~ ' 3.90 208 6612 (> 0.02 t3 3.91 209 6642 c ~ 0.01 _' I 3.92 210 6673 t ~ 0.01 ~ I 3.92 211 6705 U 0.01 5 3.92 212 6734 (~ 0 02 £3 3 3.74 213 6764 U 0.01 3.84 14 6798 (~ 0.03 1O 3 3.91 214.1 6828 U 0 0 11 3.87 WI.FG _ Penetration Body Metal Loss Body Page 5 • Average Recorded Metal Thickness Relative to Calibration Point 4.5" Tubing / 7.625" Production Casing Well: 1 &101 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 30, 2009 ^ D ecrease ^ In crease 3099 3411 GLM 2 3742 4050 4358 4666 ~ 4976 .~ E ~ .5 Z s ~ 5285 n. 'o a, 5593 GLM 1 5903 OB Nipple Sliding S PSB Gauge PBR Packer DB Nipp 6363 6673 214.1 6828 - 50% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Survey = 214.1 100 110 120 130 140 150 160 170 180 ave le 200 210 le ~petail of 10Hz MTT Recordi~s (3,162' - 3,226') Showing Line of Metal Loss Indications ~~ nu~,~.~~ se~~„ ~~• 1 B-101 May 30, 2909 Database File: d:lwarriorldatal2 archivel1b-1011p1otslplot2.db Dataset Pathname: 1/1Nl10Hz Presentation Format: 3SCALE~1 Dataset Creation: Mon Jun 01 15:19:54 2009 Charted by: Depth in Feet scaled 1:100 -50 Delta Metal thickness {%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) -200 -5.8 MTTP12 (rad) 4.2 Metal thickness 3170 Jt. 102 3180 of Metal Loss Line of Metal Loss ' Tubing Collar 3190 - .625" Casing Collar 3200 Jt. 103 3210 of Metal Line of Metal Loss i ~ G ! 3??0 4.5" Tubing Collar -50 Delta Metal t hickness {%) 50 ~"~ Line Speed {ft~minj -~'00 3 MTTP01 (rad) -5.8 MTTP12 (rad) 13 4.2 II~ Detail of 10Hz MTT Recordi~ (3,907' - 4,055') Illustrating Variations in Recorded Metal Loss Patterns P~~ o~~~~ SE~~. ~~• 1 B-101 May 30, 2~l}9 Database Fite: d:lwarriorldatal1b-1011p1otslplot1.db Dataset Pathname: 1l1/1/10Hz Presentation Format: 3SCALE~1 Dataset Creation: Mon Jun 01 15:19:54 2009 Charted by: Depth in Feet scaled 1:100 -50 Delta Metal thickness (%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) -200 -5.8 MTTP12 (rad) 4.2 -~----~---~ 3910 Metal thickness ne Jt. 125 3920 ~~7.625" Casing Collar 4.5"Tubing Collar 3930 Area of Metal Loss-~--~-.Broad Area of Metal Loss 3940 Jt. 126 3950 Area of Metal Loss~groad Area of Metal ' 3960 4.5" Tubing Collar 7.625" Casing Collar 3970 Jt. 127 ~etail of 10Hz MTT Recordir~ (4,126' - 4,204') Showing Broad Area of Metal Loss Indications ~~ 0~„4,.~~ SE~~ ~~• 1 B-101 May 30, 2009 Database File: d:lwarrior\data\1b-101\plots\plot3.db Dataset Pathname: 1/1/1l10Hz Presentation Format: 3SCALE~1 Dataset Creation: Mon Jun 01 15:19:54 2009 Charted by: Depth in Feet scaled 1:120 -50 Delta Metal thickness (%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) -200 -5.8 MTTP12 (rad) 4.2 Line S peed 4130 Delta Metal t hick ness Jt. 132 7.625" Casing Collar 4. 5" T ubin g Collar _ B road er Area of M eta l Loss -_ 4150 Jt. 133 ro ader Are a of Me tal L oss 4160 4170 -Bro ade r Area o f M etal Loss - _ - -- ~ 4 .5" Tubing Collar 4180 7 6 25" Cas in Collar . g Jt. 134 4190 4.5 " Tubing Collar 4200 -50 Delta Metal thickness (%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) -200 -5.8 MTTP12 (rad) 4.2 Detail of 10Hz MTT Recordi~s (6,548'-6,635') Showing Line of Metal Loss Indications ~~ o~w~.~~ ~~a. ~~~ 1 B-101 May 30, 2009 Database File: d:lwarriorldatal1b-1011p1otslplot4.db Dataset Pathname: 1/1/1/10Hz Presentation Format: 3SCALE~1 Dataset Creation: Mon Jun 01 15:19:54 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal thickness (%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) -200 -5.8 MTTP12 (rad) 4.2 5"Tubing Collar Delta Metal thickness awn 7.625" Casing Collar Jt. 206 6570 4.5" 6~5" -50 Delta Metal thickness {%) 50 0 Line Speed (ftlmin) -200 6590 Jt. 207 6600 Collar 6610 6620 Jt. 208 6630 of Metal of Metal of Metal Loss lndicatione 3 MTTP01 (rad) 13 -5.8 MTTP1 ~ (rad) 4.2 6580 Colla ~~~ KUP ~ 1 B-101 C011000Philii ps Well At tributes Mtut le& lun To ' " '' ' W ore 500292317300 W d Nsne EST SAK W ep Slatue od7n) PROD Intl (') B) 92.86 7,803.28 G e~ Mm) 12,230.0 --- ~~~ - -.. __ Commere SSSV:WRDP H 8(ppm) 75 a 7/1/2008 Aregta6en Last WO: d ale KB 34 70 Rip RNease 8/312003 ~ _- $7,~2 ~~ . Amotatlon a ah Last Tag: R ev Reason: FORMAT UPDATE 1/2/2009 Ci$Sif1 $trl 'a flM M) T B) Sel DepM ~~ 1 (RKB) lmeatq t7ad e 8trYg Top TMO CONWCTOR I 1 1 I CONDLIC TO 16 15.062 0.0 148.0 148.0 62.50 H-40 WELDED . 148 ~ 'I , , SURFAC E 103!4 9.754 0.0 3,080.0 2.199.6 40.55 L-80 BTC-M PRODUC TION 758 6.059 0. 7,388.0 3.730.3 29.70 L-80 BTGM ~ NIPPLE, 2665 UNFJ2 BS AND 4 12 3.958 6,882.0 12,230-0 12.60 L~0 NSCT waoP.z~s o Tubl s TI+m19 D eecdptlon Sldrp lel) alwq On) Top BpIB) tset Depm ptK61 set txpn ptl(B) st wt (IDSIIq str+n Grad p e Strkg Top ltrd S RF CE TUBING 4 12 3.958 0.0 6,829-0 3.650.7 12.60 L-80 IBTM U A . 3.0~ I n Hole A ll J . Tu Run Retrieve F r oP (~) m8e1 Top Ylcl hl oa Canm.r tnn Date GAS LIFT. 3.519 2,665.0 2,031.7 6.07 NIPPLE CAMCO'BPE1'NIPPLE 9182003 3.812 2,665.0 2,031.7 67.07 WRDP 4.5" WRDP-1 (HMS768) set 1 "MUST USE CENTRALIZER WHEN SETTING WRDP'^ 12/2?2006 2.12 3.519.0 2, 2.7 65.29 GAS UFT CA CO/IBG-2!1/DMYBK/// Camlent: 11/82(103 3.930 5,941.0 3,378. 67.82 GAS U CAMCOIKBG-ZI/DMVBK/!/ CommenC STA 1 003 3.930 I 5,996.0 3,399.3 69.03 NIPPLE CAMCO'DB' NIPPLE 9/8/2003 3.7 0 Gas I IFT -.- 5.996.0 3.399.3 69.03 PUMP 4.5" Z~.3.75° 3.75 DB LOCK W/ 3" RC JE PUMP (SER PFI-1092) HAS A 13B RATIO: H 13 NOZZLE N 14 THROAT (126" OAL ). reset 2/24266 SET 4.5" SUP STOP ON TOP OF JET PUMP ~ 5.996' RKB. 2242006 ?24/2006 0.000 NIPPLE.8a96 5,998.0 3.400.0 69.02 SLEEVE-O BAKER'CMIf SUDINGSLEEVE, OPENED II/92003 982003 3.813 PumP.59s6 6, .0 3, 1. 89.0 B POLISHED OR SUB 9/8/2003 3.7 6,056.0 3,420. 68.89 GAUGE BAKER GUARDIAN GAUGE CARRIER' BO OM SUB' 3.960 6,141.0 3,449.1 67.46 PBR BAKER 807 POLISHED BORE RECEP ACLE 982 3.870 SLEEVE-0. _.__ ' ' 6,171.0 3,461.4 68.30 PAC R BAKER 'S3' PACKER 7.625` x4.5", WITH MILLOIlT EXTENSION ~1617T, ID 4.55" 918/2(103 3. s,ss6 6,198.0 3, 71.6 69.06 NIPPLE MCO'DB'NIPPLE 9182003 3.687 6.828.0 3.650.5 75.37 WLEG 9!820(13 3.870 6,847.0 3,655.3 75.59 HANGER DSAND F GED HOOK HANGER TO D-SAND G, L7 8/612003 6,877.0 3.862.7 75. WIN W L7 D-SAND WINDOW 982003 5.630 Pse. s ooa 6,882 0 3.664.0 75. PACKER BSAND BAKER SG1 R RETREIVABLE ACKER w/EJCTENSION 9/8200 3.875 t Notes: General 8 Flltl D ate Arrotapon B o56 GAUGE 9/82003 NO TE MULTILATERAL WE LL B-SAND(18-101), D-SAND (1B-101L7) . PlBR, 6141 1 P tt L PACKER, 6.1]1 I I NIPPLE, fi,198 i I V~LEG. 6 878 HANGER. 6 611 I HANGER LI, 6,61] `MNDOW L1. 6.6]] PACKER, 6,882 PROWCTION, ] 38B LINER 6SlWO, t2 172 1 1 I 1 LINER SAND. t2 130 TD (1 &161), 12 230 ~~ • ~~ i Tubing Detail Well: 1 B-101 ~ 41/Z" Jet Pump Completion pate: 9/812003 ConocoPhillins Ada:ka Ine. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOMS Doyon 141 RT to LDS 23.08 Vetco Gray 4-1/2" x 11" Tubing Hanger 2.07 23.08 4-1/2", 12.6#, L-80, IBT- Mod Tubing Pup 3.07 25.15 Jts 130 to 214 85 Jts 4-1 /2", 12.6#, L-80, IBT- Mod Tubing 2627.12 28.22 4-112", 12.6#, L-80, IBT-Mod Tubing Pup 9.80 2655.34 4-112"x 3.812" CAMCO'BP6-I' Nipple SSSV {w/ 2.500" Isolation sleeve) 2.72 2665.14 4-112", 12.6#, L-80, IBT-Mod Tubing Pup 9.87 2667.86 Jts 103 to 129 27 Jts 4-1l2", 12.6#, L-80, IBT- Mod Tubin 835.88 2677.73 4-112", 12.6#, L-80, IBT-Mod Tubing Pup 5.81 3513.61 CAMCO 4-1/2" x 1" KBG-2 GLM w/DCK -2 Shear Valve / BEK Latch 7.34 3519.42 4-1/2'", 12.6#, L-80, IBT-Mod Tubing Pup 5.83 3526.78 Jts 25 to 102 78 Jts 4-1/2", 12.6#, L-80, IBT- Mod Tubing 2403.40 3532.59 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 5.80 5935.99 CAMCO 4-1/2" x 1" KBG-2 GLM (3.938" ID 5.984" OD 7.33 5941.79 4-1/2", 12.6#, L-80, IBT- Mod Tubing Pup 5.$2 5949.12 Jts 24 to 24 1 Jts 4-112", 12.6#, L-80, IBT- Mod Tubing 31.35 5954.94 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 9.78 5986.29 4-1 /2" CAMCO'DB' Ni ple {ID 3.750" OD 5.57") 1.61 5996.07 Baker TEC Wire Orientation Sub {ID 3.96" OD 6.20'°) .64 5997.68 Baker Model "CMU" Slidin Sleeve {ID 3.813" OD 5.50'°} 4.61 5998.32 Baker TEC Wire Orientation Sub ID 3.95" OD 6.19") .64 6002.93 Baker Polished Seal Bore Sub (ID 3.75" OD 5.20") 2.67 6003.57 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 9.81 6006.24 Jts 23 to 23 1 Jts 4-1l2", 12.6#, L-80, IBT- Mod Tubing 30.57 6016.05 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 9.81 6046.62 Baker Guardian Ga a Carrier "Bottom Sub" ID 3.98" OD 6.20" .83 6056.43 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 9.04 6057.26 Jts 21 to 22 2 Jts 4-1/2", 12.6#, L-80, IBT- Mod Tubing 62.98 6066.30 4-112", 12.6#, L-80, IBT-Mod Tubin Pup 5.78 6129.28 S aced out 6' above full Located 6.00 6135.06 Baker 807 Polish Bore Receptacle (ID 3.87" OD5.53") 19.17 6141.06 4-1/2", 12.6#, L-80, IBT- Mod Tubing Pup 5.81 6160.23 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 5.63 6166.04 6171.67 6171.67 Ran 214 joints tubin total. Installed 197 Canon clamps, 9 Mid jts, 1 band for control Gne. Up Wt 83k Drifted Tubing with 3.833 drift and Jet Lube Pi a Do a Dn Wt 65K Note; PBR is sheared and tubing landed 6' above ful landed sition. Block Wt 35K Su "sor M. Thornton/P. Reilly Ir'1 U Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS 6171.67 Baker "S3" Packer 7~/8" x 4-1/2" (ID 3.875" OD 6.62") 4.11 6171.67 X-O 4-1/2" TC-II box x 5" LTC box 1.30 6175.78 Baker Mill out extension 5.40 6177.08 X-O 4-1/2" IBT pin x 5" LTC box .65 6182.48 4-112", 12.6#, L-80, IBT- Mod Tubing Pup 5.80 6183.13 4-112", 12.6#, L-80, IBT-Mod Tubing Pup 9.73 6188.93 4-112"x 3.687" CAMCO 'DB' Nipple (ID 3.687" OD 5.030") (wl RCH Plu) 1.54 6198.66 4-1/2", 12.6#, L-80, IBT-Mod Tubing Pup 9.86 6200.20 Jts 1 to 20 20 Jts 4-1/2", 12.6#, L-80, IBT- Mod Tubing 618.16 6210.06 4-1/2" Mule Shoe Wire Line Reentry Guide (ID 3.87" OD 5.00") 1.37 6828.22 Tail 6829.59 M. Thornton/P. • °;~';` PHILLIPS ~PAlaska,~ I n~. CASING TALLY PAGE: 1 of 2 WELL NUMBER: 1B-141 WG: Doyon 141 TUBMIG DESCRIPTION: 4-1/2",12.6#ti L-80, IBT- Mod Tubing DATE: !)08/03 Column 1 Cdumn 2 Column 3 Cdumn 4 Cdumn 5 Cdumn 8 Cdumn T Column 8 No Feet No Feet No Feet No Feet No Fed Na Feet No Feet Na Feet 1 30.70 26 28.70 51 30.65 76 30.55 101 31.20 126 30.45 151 30.65 176 31.11 2 31.88 27 30.46 52 30.55 77 30.67 102 32.04 127 31.33 152 31.00 177 30.64 3 30.63 28 30.66 53 30.68 78 31.94 103 30.70 128 31.61 153 30.34 17$ 30.67 4 30.43 29 31.44 54 30.61 79 30.69 104 30.69 129 31.37 154 30.68 179 30.49 5 30.51 30 31.19 55 30.51 80 31.40 105 30.12 130 31.38 155 31.20 180 30.67 6 30.66 31 30.50 56 30.54 81 30.80 106 30.68 131 30.92 156 30.50 181 30.49 7 30.67 32 31.81 57 30.53 82 30.90 107 31.99 132 30.49 157 30.47 182 30.65 8 30.70 33 31.87 58 30.69 83 30.99 108 31.94 133 31.32 158 31.89 183 30.55 9 30.54 34 31.81 59 30.52 84 28.56 109 31.28 134 31.31 159 30.69 184 30.60 10 30.50 35 30.68 sd 31.94 85 30.73 110 31.36 135 30.60 160 30.54 185 30.47 11 30.42 36 30.07 61 30.49 86 30.49 111 30.3!0 136 30.16 161 30.61 186 30.53 12 31.18 37 30.53 62 30.89 87 30.35 112 30.47 137 31.41 162 30.65 187 30.53 13 30.69 38 30.53 63 30.50 88 30.67 113 30.52 13$ 31.89 163 28.50 188 30.29 14 31.89 39 30.55 64 30.50 89 30.63 114 31.36 139 30.69 164 31.66 189 30.54 15 31.81 40 31.42 65 31.98 9D 29.58 115 31.20 140 31.58 165 31.24 190 31.85 16 31.37 41 30.70 66 30.50 91 31.37 116 31.36 141 31.33 166 30.68 191 30.67 17 30.67 42 30.68 67 30.15 92 30.51 117 30.54 142 31.96 167 31.91 192 30.39 18 30.55 43 31.6fi 68 30.17 93 31.32 118 30.69 143 31.82 168 31.29 193 30.54 19 30.47 44 30.79 69 31.95 94 31.21 119 30.52 144 31.87 169 30.49 194 31.35 20 31.89 45 30.13 70 30.59 95 30.54 120 31.35 145 31.35 170 30.56 195 31.48 21 31.17 46 31.30 71 30.93 96 31.33 121 30.55 146 30.55 171 30.66 196 30.66 22 31.81 47 31.11 72 30.12 97 30.51 122 30.57 147 30.55 172 30.08 197 31.12 23 30.57 48 31.38 73 30.66 98 31.96 123 31.09 148 30.66 173 31.33 198 30.70 24 31.35 49 30.56 74 31.38 99 31.38 124 30.51 149 31.48 174 31.90 199 30.70 25 30.26 50 30.59 75 31.12 100 30.55 125 31.33 150 30.58 175 30.67 200 31.13 Tot 773.32 Tat 771.12 Tot 769.15 Td 769.63 Tot 774.36 Tot 778.66 Tot 770.19 Tot 768.82 TOTAL LENGTH THIS PAGE ~ 6175.25 DIRECTbNS: TOTAL JOINTS THIS PAGE = 200 r °' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEINA CCTAPANY CASING TALLY PAGE: 2 of 2 WELL NUMBER: 1B-101 RIG: Doyon 141 TUBING DESCRIPTION: 4-112",12.6#, L-80, IBT- Mod Tubing DATE: 09!08/03 Column 8 Column 10 Column 11 Column 12 Column 13 Column 14 Column 1S Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 31.37 226 251 276 301 326 351 376 202 31.37 227 252 277 302 327 352 377 203 30.69 228 253 278 303 328 353 378 204 30.53 229 254 279 304 329 354 379 205 31.44 230 255 280 305 330 355 380 206 30.56 231 256 281 306 331 356 381 207 31.35 232 257 282 307 332 357 382 208 31.94 233 258 283 308 333 358 383 209 30.48 234 259 284 309 334 359 384 210 30.97 235 260 285 310 335 360 385 211 30.82 236 261 286 311 336 361 386 212 30.70 237 262 287 312 337 362 387 213 31.43 238 263 288 313 338 363 388 214 30.56 239 264 289 314 33.9 364 389 215 39:61- 240 265 290 315 340 365 390 216 3~7 241 266 291 316 341 366 391 217 3t1~0 242 267 292 317 342 367 392 218 31.35 243 268 293 318 343 368 393 219 3'4-25 244 269 294 319 344 369 394 220 31.88 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tort 6ZU.61 TOt TOt TOTAL LENGTH THIS PAGE = 620.61 TOTAL LENGTH = 6795.86 TOTAL JOINTS THIS PAGE = 20.00 TOTAL JOINTS = 220.00 AVERAGE JT = 30.89 TOt TOt TOt TOt T~ ConocoP h~flips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~N~~ AUG ~ 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECE~VE® AUG 2 5 2U08 Alaska Oi! & Gas Anchor~~e ao~~- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ~ Z ~~C~ ~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field air iicuus Well Name PTD # Initial top of cement ft Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date 2H-05 185-168 SF bbls ft al 2H-17 200.019 6" N/A SF " N/A 5.10 8/2/2007 2K-27 201-169 10" N/A 6 N/A 1.27 8/2/2007 2M-03 191-141 16" N/A 10" " N/A 8.92 8/2/2007 1 B-14 194-030 SF N/A 16 N/A 2.13 8/2/2007 1 B-18 194-061 9" N/A SF N/A 1.70 8/13/2008 18-19 194-064 SF N/A 9" N/A 8.07 8/13/2008 1 B-20 203-115 21" N/A SF " N/A 5.10 8/13/2008 1 B-101 1 B-102 203-133 203-122 3" 4" N/A N/A 21 3" " N/A N/A 5.95 1.00 8/13/2008 8/17/2008 1Y-05 183-087 6" N/A 4 " N/A 1.00 8/17/2008 1Y-07 183-068 6" N/A 6 " N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A 6 N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 1.27 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 2.12 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A SF " N/A 3.83 8/13/2008 1 E-119 204-031 14" N/A 14 " N/A 5.95 8/17/2008 1 E-121 204-246 6" N/A 14 " N/A 4.67 8/17/2008 1 E-123 204-074 5" N/A 6 " N/A 1.00 8/17/2008 N/A 5 N/A 1.00 8/17/2008 • ,-~'_ -~. MICROFILMED 03/01/2008. DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE F: ~L.aserFichelCvrPgs_Inserts\Microfilm_Marker. doc IB-IOl Converted Back to Jet Pump Producer . . d()~-\~~ Tom, The AOGCC was notified by email on 5/10/06 that the water injection line (header) on 1 B has been shut in for repairs. This line supplied the power fluid for the 1 B-1 01 jet pump. The email notified the AOGCC that we were placing this well on temporary gas lifted production until the injection line was repaired. After further inspection of the injection line (header) it was determine that the line needed to be replaced. The new line has been installed and 1 B-101 was converted back to jet pump production on 10/28/06. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 (1.:;[' ~~I""lr::n \c-:,y" t;_'i.:-,-,~!!.""'- 1 of 1 1 0/30/2006 8:07 AM 9 l) *' DATA SUBMITTAL eOMPLIANeE REPORT 12/5/2005 Permit to Drill 2031330 Well Name/No. KUPARUK RIV U WSAK 1B-101 Operator CONOCOPHILLlPS ALASKA INC S" ""¿ I f/9.. '^-) ;. ~ _ 1- API No. 50-029-23173-00-00 MD 12230 --- TVD 3713,.. Completion Date 9/9/2003 /' Completion Status 1-01L -~,- REQUIRED INFORMATION Mud Log No Samples No --" DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No ¿C Lis 12182 I nd uction/Resistivity LIS Verification ¡}tD C Pdf 12182 I nd uction/Resistivity 25 ~ Induction/Resistivity ,t4ð ..,,¿ r-vl) 25 Blu ~ !~ l_~__ ________.___ Well Cores/Samples Directional Survey Directional Survey Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y .G) Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ --,~.^---- --,-~_.^ Comments: Current Status 1-01L UIC N Directional s/u~~ (data taken from Logs Portion of Master Well Data Maint Interval OH/ . Start Stop CH Received Comments 3080 12230 Open 9/25/2003 LDWG 3080 12230 Open 9/25/2003 LDWG 3080 12230 Open 9/25/2003 Multiple Propagation Resistivity - Gamma Ray 3080 12230 Open 9/25/2003 Multiple Propagation Resistivity - Gamma Ray 148 12230 11/20/2003 148 3090 11/20/2003 PB1 Sample Set Number Comments .. &: Permit to Drill 2031330 MD 12230 rvD Compliance Reviewed By: DATA SUBMITTAL eOMPLIANeE REPORT 12/5/2005 Well Name/No. KUPARUK RIV U WSAK 1B-101 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23173-00-00 3713 ~tion Date 9/9/2003 Current Status 1-01Lr UIC .r::... Date:______\c ~~) Completion Status 1-01L . . ~ I -- Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJ"Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 5, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 18-101 / 18-101L 1 (APD # 2~~æ / 203-134) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 18-101 and 18-101 L 1 . If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling RT/skad RECEIVED DEC 11 2003 Alaska Oil & Gas Cons. Commission Anchorage ü~IG'NAL . STATE OF ALASKA _ ALAS OIL AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged D Abandoned D Suspended D WAG D 20AAC 25.105 20AAC 25.110 Gas U 1a. Well Status: Oil 0 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Pennitto Drill Number: GINJ D 2. Operator Name: D WDSPL D WINJ No. of Completions _ Other 5. Date Comp., Susp., or Aband.: September 9. 2003 6. Date Spudded: August 15, 2003 7. Date TD Reached: August 28, 2003 8. KB Elevation (ft): RKB 28' / 88' AMSL 9. Plug Back Depth (MD + TVD): 12230' MD / 3713' TVD 10. Total Depth (MD + TVD): 12230' MD / 3713' TVD' 203-133/ 13. API Number: 50-029-23173-00 14. Well Name and Number: 18-101 15. FieldlPool(s): Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 502' FNL, 210' FEL, Sec. 9, T11N, R10E, UM At Top Productive Horizon: 232' FSL, 973' FEL, Sec. 3, T11N, R10E, UM Total Depth: 211' FNL, 1821' FEL, Sec. 3, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550229 y- TPI: x- 554740 y- Total Depth: x- 553849 y- 18. Directional Survey: Yes 0 No D 16. Property Designation: ADL 25648 Zone-4 Zone-4 Zone-4 5969647 5970412 5975243 17. Land Use Pennit: ALK 466 / 463 11. Depth where SSSV set: SSSV @ 2665' 20. Thickness of Permafrost: 19. Water Depth. if Offshore: N/A feet MSL 1668' 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 148' Surface 3080' Surface 7389' 6882' 12230' AMOUNT PULLED CASING SIZE CEMENTING RECORD WT. PER FT. 62.5# 45.5#/40.5# 29.7# 12.6# GRADE H-40 L-80/J-55 L-80 L-80 HOLE SIZE 16" 132 sx ArcticCrete 24" 675 sx AS III Lite, 285 sx Class G 755 sx Class G 10.75" 7.625" 13.5" 9.875" 4.5" slotted liner 6.75" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): TUBING RECORD DEPTH SET (MD) 6830' 24. SIZE PACKER SET (MD) 6171',6882' 4.5" slotted liner 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 21, 2003 Flowing - shares production with 1 B-1 01 L 1 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/27/2003 18 hours TestPeriod--> 1992 455 0 31% 252 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 246 psi 1002 24-Hour Rate -> 2583 651 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessarynEC E IVE U Submit core chips; if none, state "none". f' rê6i;1G[·¿::;·:iT;"l r·";'(;; ; q.it'ð3¡ ! VE!}fiEG ¡ I~~~~"~ DEC 11 Z003 A\aska Oil & Gas Cons. COmm\ssion Anchorage NONE Fonn 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE Submit in duplicate DEC 1 0 11003 fØ)MS BfL ORiGiNAL ~),:; Di ~ 28. GEOLOGIC MARKERS" 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 B-1 01 West Sak 8 7315' 3726' NIA RECEIVED DEC 11 2003 Alaska Oil & Gas Cons" Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed N~ _ _ ~,Thoma¡> Signature \.. ~ \ ~ Title: Phone Kuparuk DrillinQ Team Leader ~~ 6'13 3c:> \'-¿(51/) "$ Date 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGt . . Page 1 of 10 ConocoPhillips Alaska Operations Summary Report . . Legal Well Name: 1 B-1 01 Common Well Name: 1 B-1 01 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date . From - To ¡ Hours Code Sub; Phase Code: ...un__.._ ._.... __.......... 8/15/2003 02:00 - 02:30 0.50 MOVE MOVE MOVE 02:30 - 03:30 1.00 MOVE MOVE MOVE 03:30 - 06:30 3.00 MOVE MOVE MOVE 06:30 - 07:30 1.00 MOVE MOVE MOVE 07:30 - 08:30 1.00 MOVE MOVE MOVE 08:30 - 09:30 1.00 MOVE MOVE RIGUP 09:30 - 10:30 1.00 MOVE OTHR RIGUP 10:30 - 12:30 2.00 WELCTL NUND RIG UP 12:30 - 14:00 1.50 RIGMNT RSRV RIG UP 14:00 - 15:30 1.50 RIGMNT RSRV RIGUP 15:30 - 16:00 0.50 RIGMNT RSRV RIGUP 16:00 - 17:30 1.50 DRILL PULD SURFAC 17:30 -18:00 0.50 DRILL PULD SURFAC 18:00 - 20:00 2.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 DRILL OTHR SURFAC 20:30 - 21 :00 0.50 DRILL DRLG SURFAC 21 :00 - 22:45 1.75 DRILL DRLG SURFAC 22:45 - 23: 15 0.50 DRILL SURV SURFAC 23:15 - 00:00 0.75 DRILL DRLG SURFAC 8/16/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 8/17/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC 06:00 - 07:00 1.00 DRILL CIRC SURFAC 07:00 - 08:30 1.50 DRILL REAM SURFAC 08:30 - 09:00 0.50 DRILL REAM SURFAC 09:00 - 09:15 0.25 DRILL REAM SURFAC 09:15 - 09:30 0.25 DRILL REAM SURFAC 09:30 - 10:45 1.25 DRILL REAM SURFAC 10:45 - 11 :00 0.25 DRILL OBSV SURFAC 11 :00 - 12:00 1.00 DRILL REAM SURFAC 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 13:30 1.00 DRILL PULD SURFAC 13:30 - 13:45 0.25 DRILL PULD SURFAC 13:45 - 14:30 0.75 DRILL TRIP SURFAC 14:30 - 15:45 1.25 DRILL REAM SURFAC 15:45 - 17:00 1.25 DRILL TRIP SURFAC 17:00 - 18:15 1.25 DRILL PULD SURFAC 18:15 - 19:00 0.75 DRILL TRIP SURFAC 19:00 - 19:15 0.25 DRILL SURV SURFAC Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations . -... ..-....-..,.. ,._,. Move pipe shed and rock washer. Move Modules and sub off of well 1 B-1 02. Prep gravel pad and NU 21 1/4' annular preventer. Spot sub over well 1 B-1 01. Spot pits, motors, boiler modules. (RIG ACCEPTED @ 0830 HRS 8/15/03) Spot pipe shed and rock washer. Complete rig acceptance checklist and mix spud mud. NU knife valve and cement flange and riser. Cut drlg. line, adjust and inspect brakes. Change out saver sub. Service top drive, fix service loop D-rings. PU 5" HWDP, jar, DC's, Stand back in derrick. PU surface rotary tools. MU BHA 1, Bit, motor, pony sub,mwd, xo, ubho. Orient. Flood conductor, check f/leaks. RU slickline for gyro. Drill ice from 122-148. 2115 hrs. Drill Surface from 148 to 257. Gyro survey and connection. Drill from 257 to 300. TVD 300. ADT 0.0 AST 0.3. Drilled from 300 to 1258. ART 1.0, AST 5.2, ADT 6.2. PU 56-90, SO 56-88. PU and SO values were consistent with TO and Drag model. Pump pressure 820 - 1550 psi. Mud pump #1 down for 1.5 hr. The BHA had difficulty holding angle. Drilled from 1258 to 2557. ART 2.3, AST 5.3, ADT 7.6. PU 90-100, SO 56-88. PU and SO values were consistent with TO and Drag model. Pump pressure 1550 - 1800 psi. Drilled from 255 - 3090. 2208 TVD. AST 1.2 ADT 4.0. PU 98-102, SO 79-84. PU and SO values were consistent with TO and Drag model. Pump pressure 1575 - 1825 psi. Pump sweep surface to surface. 600 gpm, 1550 psi. Backream to 1760 @ 30'/min. 140 spm, 80 rpm. At 1760 hole unloading. Continue to back ream to 1700 at reduced speed of 1 O'lmin while cleaning hole-2000 strokes. Turned off pumps and rotary. Slacked off from 1700 - 1755, hole took weight. PU, brought on pumps and rotary, attempted to ream through (bridge?) Worked down to 1785. Bridge did not appear to go away. Oriented toolface, wash and work down to 1817. Hole still taking weight and stalling motor. Plan forward-TOOH, PU hole opener. Backream out to BHA @ 1075 @ 30'/min. Flow check, POOH two stands, 15k overpull. Backream BHA out 215. Stand back HWDP, jars, De's. LD BHA 1. MU BHA 2 (Hole opener) RIH to 1817. tag and set down 30k. Ream from 1817 to 1820. 140 spm, 140 rpm, 1150 psi, 3k TQ, 95 PU, 84 SO. Unable to go further. Plan forward-TOOH, PU BHA 3 - motor assembly. TOOH, LD BHA 2 - hole opener. MU BHA 3, bit, motor, pony, MWD, 3 DC's. RIH to 1820. Survey & orient Hi side to attempt lost hole re-entry. New survey was Printed: 10/10/2003 1 :22:00 PM . . Page 2 of 10 ConocoPhillips Alaska Operations Summary Report 0.25 DRILL SURV SURFAC taken @ 1754 (Inc = 47.03, Azimuth = 103.82). The closest original hole survey was taken @ 1759 (Inc = 50.16, Azimuth = 103.96). The drilling assembly is now 3 degrees below the original hole at approximately the same MD. Drilled from 1820 to 2363. 1915 TVD. ART 1.4 AST 1.1 ADT 2.5. Drill fl 2363' to 3090' rvD 2203' AST = 1.3 hrs, ART = 4.2 hrs, ADT = 5.5 hrs, UP 103K, DN 78K, ROT 87K, WOB 15/20K, RPM 90, TO 6K onl 5K off, GPM 680 @ 2250 PSI Pump Hi-vis weighted sweep around, Stand back 1 stand every 45 min. to 2831', Pump 2nd sweep around due to high cuttings load on shakers. Back ream out to 1890' wI 595 GPM @ 1700 psi, 80 RPM Pump out to HWDP due to swabbing, POOH to BHA @ 191' Lay down BHA, Jars, 3- De's, MWD, Motor, Clear & clean rig floor Rig to run 10-3/4' casing, PJSM with all personal. Run 10-3/4" csg. to 2105' pipe stopped, Wash csg fl 2105' to 2192' w/3 bpm @ 300 psi, Run csg to 2244', Wash csg. f/ 2244' to 2290', Casing circulating good wI full returns, UP 120K, DN 70K Ran 10 3/4" csg from 2,290' to 3,040' PU Landing Jt & Hanger and Est Circ, Pull master bushing and cont circ hole at 6 bpm at 300 psi (Circ 400 bbls) LD Landing jt & hanger, damaged pin end on pup it below hanger, LD Jt # 71 due to damaged box, Replaced with new it of csg, LD Franks Fill Up tool, sent hanger to Baker to replace pup jt on hanger Circ & cond mud for cementing, lowered YP from 34 to 12 and Mw from 9.2 ppg to 9.1 ppg, circ & reciprocated csg at 6 bpm at 200 psi, Pu wt 130K, Dn wt 100K LD Jt used to circ hole, PU Landing JT & Hanger & landed csg, MU Cement Head, Ran a total of 56 Jts 2,414.37' of 10 3/4", 40.5# L-80 BTC csg with float equip followed by 15 its, 633.24' of 103/4' 45.5# L-80 BTC csg (71 Jts total), Landed csg with float shoe at 3,079' and float collar at 2,990'. 1.00 CEMENTCIRC SURFAC Cont to circ & cond mud for cementing, held PJSM with Dowell, APe vac truck drivers & rig crew on cementing csg, circ & reciprocated pipe at 6 bpm at 200 psi 2.00 CEMENT PUMP SURFAC Switch over to Dowell, Pump 5 bbls CW100, Test cement lines to 3000 psi. Pump 45 bbls CW100, 50 bbls Mudpush XL @ 10.5ppg. Drop bottom plug. Pump 513.5 bbls Lead cement, AS Lite III (675sx, yield 4.28) @ 10.7 ppg. Pump 60 bbls (285 sx, yield 1.16) Tail cement, class 'G' @ 15.8 ppg. Shut down 1.00 CEMENT DISP SURFAC Drop top plug, Pump 20 bbls H20. Switch to rig & displace cement with rig pumps @ 6 PBM. Slowed displacement rate to 3 PBM last 20 bbls of displacement. Bump plug with 269.7 bbls of 9.1 ppg mud (FCP 500 psi @ 3 bpm.) Pressure up to 1100 psi, bleed off pressure & check floats, Ck Ok. Had 150 bbls of 10.7 ppg cmt back at surface, CIP @ 1300 hrs 08/19/2003. Note; lost returns when cement went out the shoe for approximately 10 bbls then regained full retums. Reciprocated casing until 450 bbls Lead cement pumped. Reciprocation was 15' stroke @ 20 fpm. Tested 103/4" csg to 2,500 psi for 15 min, pressure dropped 200 psi in 10 min, no test LD Landing Jt, RD Doyon's Csg equipment & cleared rig floor Flushed out divertor & ND same NU Vetco Gray 11" 5M Gen 1 Horizontal wellhead, tested seals to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-101 18-101 ROT - DRILLING n 1334@ ppco.com Doyon 141 Date Sub From ~To Hours ··Code Code Phase 8/17/2003 19:00 -19:15 19:15 - 00:00 4.75 DRILL DRLG SURFAC 8/18/2003 00:00 - 08:45 8.75 DRILL DRLG SURFAC 08:45 - 12:00 3.25 DRILL CIRC SURFAC 12:00 - 13:30 1.50 DRILL TRIP SURFAC 13:30 - 15:15 1.75 DRILL TRIP SURFAC 15:15 - 17:30 2.25 DRILL PULD SURFAC 17:30 - 19:00 1.50 CASE RURD SURFAC 19:00 - 00:00 5.00 CASE RUNC SURFAC 8/19/2003 00:00 - 01 :00 1.00 CASE RUNC SURFAC 01 :00 - 03:00 2.00 CASE CIRC SURFAC 03:00 - 05:00 2.00 CASE RURD SURFAC 05:00 - 08:00 3.00 CASE CIRC SURFAC 08:00 - 09:00 1.00 CASE RURD SURFAC 09:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 13:30 0.50 CASE DEOT SURFAC 13:30 - 14:30 1.00 CASE RURD SURFAC 14:30 - 16:30 2.00 WELCTL NUND SURFAC 16:30 - 17:30 1.00 WELCTL NUND SURFAC Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations Printed: 10/10/2003 1 :22:00 PM - . Page 3 of 10 ConocoPhillips Alaska Operations Summary Report 5,000 psi for 10 min NU 135/8" BOP stack Installed test plug & RU to test BOP's Testing rams, manifold and valves to 250 psi low and 5,000 psi high. NOTE: John Crisp with AOGCC waived witnessing of BOP test Fin testing BOP's, tested blind rams to 250 psi low & 5,000 psi high, tested annular to 250 psi low & 3,500 psi high, performed accumulator test, pulled test plug & installed wear bushing Installed riser, elevator bales and PU 5" handling tools PU & RIH with 30 jts of 5" DP, POOH & stood back PU 9 7/8" Bit #3 & MU BHA #4 with 6 3/4" Autotrak and TIH to 1,100'. Had to pull wear bushing to run BHA, installed wear bushing after MU ghost reamer, tested Autotrak tool at 1,100' & Ck Ok TIH with BHA #4 from 1,100' to 2,837' PU 5" DP from pipe shed Est Circ washed down & took Ck shot survey at 2,916', RIH & tagged up at 2,985', (FC @ 2,990') Fin circ 1 complete hole volume, 8.8 ppg mw in & out, rot wt 87K, pu wt 105K, dn wt 72K, circ at 500 gpm at 500 psi and 60 rpm's RU & tested 10 3/4" csg to 2,500 psi for 30 min, good test Drilled out float collar at 2,990', drilled firm cmt in shoe, drilled float shoe at 3,079' and cleaned out to TD at 3,090', drilled fit equip with 80 rpm's, 3-5K wob, 510 gpm at 1,000 psi Drilled 20' of new formation from 3,090' to 3,110', ADT .10 hrs, started displacing hole with clean 9.1 ppg mud Fin circ 9.1 ppg mud in & out Performed FIT to 13.9 ppg EMW with 9.1 ppg mud at 2,200' rvD and 550 psi. Downlinked and initialized Autotrak tool Drilled 9 7/8" hole from 3,110' to 3,670' MD/2,449' TVD (560'), ADT 3.6 hrs, 5-10K wob, 100 rpm's, 142 spm, 600 gpm, 1,850 psi, off btm torque 4K ft-Ibs, on btm 6K ft-Ibs, rot wt 93K, pu wt 128K, dn wt 73K, Drilled 9 7/8" hole per directional plan from 3,670' to 4,783' MDI 2,909' TVD (1,113'), ADT 7.4 hrs, 2-10K wob, 110-130 rpm's, 150 spm, 640 gpm, 2,100 psi, off btm torque 1 OK ft-Ibs, on btm 12K ft-Ibs, rot wt 103K, up wt 170K, dn wt 73K, 9.1 ppg mwand 86 vis, pumped wt'd hi vis sweep 2#'s over mw and had 30% increase in cuttings back 12.00 DRILL DRLG INTRM1 Drilled from 4,783' to 5,619' MDI 3,265' rvD (836'), ADT 8.5 hrs, 5-10K wob, 130 rpm's, 153 spm, 653 gpm, 2,300 psi, off btm torque 12K ft-Ibs, on btm 14K ft-Ibs, rot wt 107K, up wt 182K, dn wt 73K, 9.1 ppg mwand 83 vis, began adding 5 sxs/hr Mix IIlcm while drlg Ugnu and pumped wt'd hi vis sweeps with 0-20% increase in cuttings 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 5,619' to 6,511' MD/ 3,591' TVD (892'), ADT 7.9 hrs, 2-10K wob, 130 rpm's, 150 spm, 634 gpm, 2,400 psi, off btm torque 12.5K ft-Ibs, on btm 14K ft-Ibs, rot wt 114K, up wt 155K, dn wt 83K, raised mw from 9.1 to 9.6 ppg per plan, Est top of K-13 6,401' MDI 3,557' rvD 12.00 DRILL DRLG INTRM1 Drilled from 6,511' to 7,291' MD/3,750' rvD (780'), ADT 7.4 hrs, 5-10K wob, 140 rpm's, 155 spm, 657 gpm, 2,725 psi, off btm torque 14K ft-Ibs, on btm 15K ft-Ibs, rot wt 113K, up wt 159K, dn wt 83K, pumped wt'd hi vis sweeps with 30-40% increase in cuttings, est top of West Sak "D" at 6,848' MD/3,682' rvD 1.50 DRILL DRLG INTRM1 Drilled from 7,291' to 7,395' MD/3,761, TVD (104'), ADT 0.9 hrs, 5-10K wob, 150 rpm's, 155 spm, 657 gpm, 2,800 psi, off btm torque 14K ft-Ibs, Legal Well Name: 18-101 Common Well Name: 18-101 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 m Date From - To Hours Code Sub Phase Code 8/19/2003 16:30 - 17:30 1.00 WELCTL NUND SURFAC 17:30 - 20:30 3.00 WELCTL NUND SURFAC 20:30 - 21 :00 0.50 WELCTL OTHR SURFAC 21 :00 - 00:00 3.00 WELCTL BOPE SURFAC 8/20/2003 00:00 - 01:15 1.25 WELCTL BOPE SURFAC 01:15 - 02:00 0.75 DRILL OTHR SURFAC 02:00 - 03:00 1.00 DRILL PULD SURFAC 03:00 - 07:30 4.50 DRILL TRIP SURFAC 07:30 - 10:30 3.00 DRILL TRIP SURFAC 10:30 - 11 :30 1.00 DRILL REAM SURFAC 11 :30 - 12:00 0.50 DRILL CIRC SURFAC 12:00 - 13:00 1.00 DRILL DEQT SURFAC 13:00 - 16:00 3.00 CEMENT DSHO SURFAC 16:00 - 16:15 0.25 DRILL DRLG SURFAC 16:15 - 16:45 0.50 DRILL CIRC SURFAC 16:45 - 17:30 0.75 DRILL FIT SURFAC 17:30 - 18:00 0.50 DRILL DEQT INTRM1 18:00 - 00:00 6.00 DRILL DRLG INTRM1 8/21/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 8/22/2003 00:00 - 12:00 12:00 - 00:00 8/23/2003 00:00 - 01 :30 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: .. . . . Description of Operations Printed: 10/10/2003 1 :22:00 PM . . ConocoPhillips Alaska Operations Summary Report Page 4 of 10 on btm 15K ft-Ibs, rot wt 114K, up wt 170K, dn wt 80K, 9.7 ppg mw, Est top of West Sak "B" at 7,315' MDI 3,756' rvD Pumped wt'd hi vis sweep (2# over mw) and circ a total of 2 btms up, 10% increase in cuttings from sweep, circ at 654 gpm at 2,825 psi and 150 rpm's Monitored well-static, POOH 10 stds from 7,395' to 6,480', ave 25K drag, hole did not take calc fill, no other problems POOH TIH from 6,480' to 7,325', washed 70' to btm with no problems Circ Btms up after wiper trip, had large amount of cuttings back at btms up, no increase in chlorides, pumped wt'd hi vis sweep and saw no increase in cuttings, circ at 654 gpm, 2,850 psi 150 rpm's and 14K ft-Ibs torque, up wt 170K, dn 80K Monitored well- static, backreamed out 15 stds from 7,395' to 5,990' with no problems, circ a 634 gpm, 2,700 psi and 130 rpm's, Circ btms up from 5,990' after backreaming out, had a large amount of cuttings back at btms up, circ a total of 2.5 btms up Monitored well-static, POOH wet 10 stds, hole took calc fill, pumped dry job and POOH to 3,020', (csg shoe) with no problems Monitored well at shoe-static, POOH LD 63 jts 5" DP, POOH to BHA at 1,073' Pulled wear bushing, LD ghost reamer, HWDP, jars, flex dc's, downloaded Autotrak tool & fin LD BHA #4 Changed out top set of rams to 7 5/8" csg rams Tested door seals to 250 psi low and 3,500 psi, good test RU doyon's 7 5/8" 350 ton csg equipment, changed out elevator bales and MU Franks fill up tool Held PJSM with casing operator & rig crew on running 7 5/8" csg MU 75/8" float shoe, 2 jts-7 5/8" 29.7#, L-80 BTC-Mod csg and 7 5/8" float collar, thread locked conn below fit collar and pumped thru fit equip & ck ok, cont PU & RIH with 7 5/8" csg to 3,018', Ran a total of 25 centralizers & stop rings per well program Circ 1 csg cap at 3,018', inside 103/4" csg shoe, circ at 5 bpm at 280 psi, up wt 98K, dn wt 65K RIH with add 59 jts of 7 5/8" 29.7#, L-80, BTC-Mod csg to 5,535' (130 jts total) Circ 1 annulus cap from 5,535' at 5 bpm at 700 psi, up wt 145K, dn wt 65K Fin RIH with 7 5/8" csg, MU landing jt and hanger & landed csg, no problems RIH, landed 7 5/8" csg at 7,389' MD/3,761, rvD with fit collar at 7,299', Ran a total of 172 jts and 2-pup jts of 7 5/8", 29.7#, L-80, BTC-Mod csg (7,361.79') 0.50 CASE RURD INTRM1 RD Franks fill up tool & MU Dowell's cement head 3.25 CEMENTCIRC INTRM1 Circ & cond mud for cementing, lowered YP to 15 and YP to 13 with 9.6 ppg mud, staged pumps up to 6 bpm at 475 psi, reciprocated pipe, up wt 210K, dn wt 65K, held PJSM with Dowell, APe and rig crew on cementing csg 1.50 CEMENT PUMP INTRM1 Switch over to Dowell, Pump 5 bbls CW1 00, Test cement lines to 3500 psi. Pump 45 bbls CW100, 50 bbls Mudpush XL @ 10.5ppg. Drop bottom plug. Pump 165.8 bbls, 756 sxs Tail cement, class 'G' @ 15.8 ppg and 1.17 yield with add. Ave 6 bpm at 250 psi 1.25 CEMENT DISP INTRM1 Drop top plug, Pump 20 bbls H20. Switch to rig & displace cement with rig pumps @ 6 BPM. Slowed displacement rate to 3 PBM last 20 bbls of displacement. Bump plug with 308.2 bbls of 9.6 ppg mud (3,092 Legal Well Name: 1B-101 Common Well Name: 1 B-1 01 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code -_.-- 8/23/2003 00:00 - 01 :30 1.50 DRILL DRLG INTRM1 01 :30 - 03:00 1.50 DRILL CIRC INTRM1 03:00 - 04:15 1.25 DRILL WIPR INTRM1 04:15 - 04:45 0.50 DRILL WIPR INTRM1 04:45 - 07:00 2.25 DRILL CIRC INTRM1 07:00 - 09:15 2.25 DRILL REAM INTRM1 09:15 - 10:30 1.25 DRILL CIRC INTRM1 10:30 - 12:45 2.25 DRILL TRIP INTRM1 12:45 - 14:00 1.25 DRILL PULD INTRM1 14:00 - 17:15 3.25 DRILL PULD INTRM1 17:15 - 18:15 1.00 WELCTL EaRP INTRM1 18:15 - 18:45 0.50 WELCTL BOPE INTRM1 18:45 - 19:30 0.75 CASE RURD INTRM1 19:30 - 19:45 0.25 CASE SFTY INTRM1 19:45 - 00:00 4.25 CASE RUNC INTRM1 8/24/2003 00:00 - 00:30 0.50 CASE CIRC INTRM1 00:30 - 02:45 2.25 CASE RUNC INTRM1 02:45 - 03:30 0.75 CASE CIRC INTRM1 03:30 - 05:15 1.75 CASE RUNe INTRM1 05:15 - 05:45 05:45 - 09:00 09:00 - 10:30 10:30 - 11 :45 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations Printed: 10/10/2003 1 :22:00 PM . . Page 5 of 10 ConocoPhillips Alaska Operations Summary Report 1.25 CEMENT DISP INTRM1 strokes) (FCP 610 psi @ 3 bpm.) Pressure up to 1100 psi for 5 minutes, bleed off pressure & check floats- Ok. CIP @ 1133 hrs 08/24/2003. Est T.O.C. 4,500' Note; lost returns when MUDPUSH went out the shoe for approximately 5 bbls then regained full returns. Reciprocated casing throughout cement job. Reciprocation was 20' stroke @ 20 fpm, decreasing to 5' stroke length. RU & tested 7 5/8" csg to 3,000 psi for 30 min, good test Closed annular preventer and pumped 10 bbls of 9.6 ppg mud down 7 5/8' x 103/4" annulus to clear csg shoe, pumped at 1/2 bpm at 510 psi RD cement head, Doyon's cag equipment, LD landing it, RU 5' elevator & bales Set 7 5/8" pack-off, RILDS, energized & tested to 5,000 psi for 15 min, ck ok Changed out btm set of 5" rams to 4' and changed top set of 7 5/8' csg rams over to 3 1/2' x 6" VBR's Changed over top drive saver sub, grabbers, stabbing guide and pipe handler to 4" DP, PU 4" handling tools and set test plug RU & began testing BOP rams, valves & choke manifold to 250 psi low and 5,000 psi high, while testing choke manifold, 11' 5M flange between csg head & 11' x 13 5/8' 5M DSA leaked, made several attempts to tighten with no success Drained stack, LD test it & ND stack, removed ring gasket and emery clothed ring groove on btm of DSA, (had some pitting) Changed out ring gasket on 11' 5M flange between csg head & DSA, N U Stack Fin testing BOP's, Rams, valves & choke manifold to 250 psi low & 5,000 psi high, annular to 250 psi low & 3,500 psi high, Jeff Jones with AOGCC witnessed test, pulled test plug & installed wear bushing Installed riser, turnbuckles and mousehole LD 47 stds (141 jts) of 5" DP from derrick in mousehole PU 54 stds 4" 14# XT 39 DP (162 its) & RIH, MU 4" LoTads, 1/std (54 total), while RIH POOH & stood back 54 stds 4" DP MU 6 3/4" BHA #5 on bit #4, orient & program MWD, RIH to 251' and surface test MWD TIH with BHA #5 PU 4" DP, TIH to 4,457' Cont TIH with BHA #5 PU 4" DP to 6,793' Cut & Slip 60' of Drlg Line, Serviced top drive and drawworks TIH from 6,793' to 7,260', washed down from 7,260' and tagged float collar at 7,299' Drilled plugs, float collar at 7,299', med-firm cement in shoe track, drilled float shoe at 7,389', cleaned out to TD at 7,395', drilled 20' of new formation to 7,415', ART 0.1 hrs, 5-10K wob, 60 rpm's, 260 gpm at 1,650 psi, rot wt 83K, up wt 130K, dn wt 63K Changed over 9.6 mud in hole to new 9.6 ppg Flo Pro mud Performed F.I.T. to 13.0 ppg EMW with 9.6 ppg mw at 3,761' rvD at 675 psi Performed base line PWD test Drill, slide & survey 6 3/4" hole from 7,415 to 7,620' MDI 3,767' TVD, (205') ART 2.3 hrs, AST 0.2 hrs, 2-1 OK wob, 110 rpm's, 66 spm, 280 gpm's, 1,700 psi, off btm torque 7K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 84K, up wt 135K, dn wt 55K, 9.6 ppg mw, ave ECD 11.0 ppg Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-101 18-101 ROT - DRILLING n1334@ppco.com Doyon 141 Date . . Sub . From - To Hours Code Code Phase 8/24/2003 10:30 - 11 :45 11 :45 -12:30 0.75 CASE DEQT INTRM1 12:30 -13:00 0.50 CASE OTHR INTRM1 13:00 - 14:30 1.50 CASE RURD INTRM1 14:30 -16:00 1.50 CASE OTHR INTRM1 16:00 - 18:00 2.00 WELCTL EQRP INTRM1 18:00 - 20:00 2.00 DRILL RIRD INTRM1 20:00 - 22:30 2.50 WELCTL BOPE INTRM1 22:30 - 00:00 1.50 RIGMNT RGRP INTRM1 8/25/2003 00:00 - 01 :30 1.50 RIGMNT RGRP INTRM1 01 :30 - 04:30 3.00 WELCTL BOPE INTRM1 04:30 - 05:30 1.00 DRILL RIRD INTRM1 05:30 - 09:30 4.00 DRILL PULD INTRM1 09:30 - 15:45 6.25 DRILL PULD INTRM1 15:45 - 18:30 2.75 DRILL TRIP INTRM1 18:30 - 20:30 2.00 DRILL PULD INTRM1 20:30 - 00:00 3.50 DRILL TRIP INTRM1 8/26/2003 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 03:00 1.50 RIGMNT RSRV INTRM1 03:00 - 03:30 0.50 DRILL TRIP INTRM1 03:30 - 05:30 2.00 CEMENT DSHO INTRM1 05:30 - 07:00 1.50 DRILL CIRC INTRM1 07:00 - 07:45 0.75 DRILL FIT INTRM1 07:45 - 08:15 0.50 DRILL CIRC PROD 08:15 - 12:00 3.75 DRILL DRLG PROD Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations Printed: 10/10/2003 1 :22:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 6 of 10 ConocoPhillips Alaska Operations Summary Report 1B-101 1 B-1 01 ROT - DRILLING n 1334@ppco.com Doyon 141 8/26/2003 12:00 - 00:00 From - To: . Hours Sub Code Code Phase 12.00 DRILL DRLG PROD Date· 8/27/2003 00:00 - 12:00 12:00 - 00:00 8/28/2003 00:00 - 09:00 09:00 - 09:30 09:30 - 17:15 17:15 - 18:30 18:30 - 20:45 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 9.00 DRILL DRLG PROD 0.50 RIGMNT RGRP PROD 7.75 DRILL DRLG PROD 1.25 DRILL TRIP PROD 2.25 DRILL DRLG PROD 20:45 - 21 :30 0.75 DRILL CIRC PROD 21 :30 - 21 :45 0.25 DRILL OBSV PROD 21 :45 - 00:00 2.25 DRILL REAM PROD 8/29/2003 00:00 - 03:45 3.75 DRILL REAM PROD 03:45 - 04:30 0.75 DRILL CIRC PROD 04:30 - 04:45 0.25 DRILL OBSV PROD 04:45 - 05:15 0.50 DRILL TRIP PROD 05:15 - 09:45 4.50 DRILL TRIP PROD 09:45 - 12:00 2.25 DRILL TRIP PROD Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations Drill, slide & survey 6 3/4" hole from 7,620' to 8,628' MD/ 3,760' TVD, (1,008') ART 4.7 hrs, AST 1.18 hrs, 2-5K wob, 115 rpm's, 66 spm, 280 gpm's, 1,850 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 84K, up wt 130K, dn wt 52K, 9.6 ppg mw, ave ECD 11.2 ppg Drill, slide & survey 6 3/4' hole from 8,628' to 9,596' MDI 3,755' TVD (968') ART 6.6 hrs, AST 1.2 hrs, 3-5K wob, 115 rpm's, 66 spm, 280 gpm, 2,000 psi, off btm torque 8.5K ft-Ibs, on btm 8.5K ft-Ibs, rot wt 85K, up wt 128K, dn wt 53K, 9.6 ppg mw, ave ECD 11.4 ppg with 2% Lubricants Drill, slide & survey 6 3/4' hole from 9,596' to 10,563' MDI 3,742' TVD (967') ART 5.4 hrs, AST 1.5 hrs, 2-1 OK wob, 115 rpm's, 71 spm, 300 gpm, 2,250 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 125K, dn wt 58 K, 9.6 ppg mw, ave ECD 11.4 ppg with 3% Lubricants Drilled 6 3/4' Hole from 10,563 to 11,288' MD, (725') ART 4.3 hrs, AST 1.2 hrs, 2-15K wob, 115 rpm's, 71 spm, 300 gpm, off btm press 2,350 psi, on btm 2,500 psi, off btm torque 8.5K ft-Ibs, on btm 8.5K ft-Ibs, rot wt 86K, up wt 126K, dn wt 55K Replaced ring gasket in mudline unibolt flange. Derrickman did great job in catching leak possibly preventing a spill! Drilled from 11,288' to 12,013', (725') ART 4 hrs, AST 0.5 hrs, 2-6K wob, 115 rpm's, 300 gpm, off btm press 2,375 psi, on btm 2,500 psi, on & off btm torque 9K ft-Ibs, rot wt 84K, up wt 133K, dn wt 43K, 9.6 ppg mw, ave ECD 11.6 ppg, ave bgg 35 units Backreamed out 3 stds to 11,726', MU 3 stds of 4" WT pipe to TD well & TIH NOTE: Corrected TVD's per new survey data, EST Top of West Sak 'D' 6,848' MDI 3,655' TVD West Sak 'B", 7,310' MD/ 3,726' TVD Drilled from 12,013' to 12,230' MDI 3,713' TVD, Lower Lateral T.D., (217') ART 1.0 hrs, AST 0.4 hrs, 2-6K wob, 115 rpm's, 71 spm, 300 gpm, off btm press 2,500 psi, on btm 2,675 psi, on & off btm torque 9K ft-Ibs, rot wt 89K, up wt 140K, dn wt 48K, mw 9.6 ppg, MBT's 4.5, ave ECD 11.5 ppg, ave bgg 36 units Circ btms up at 300 gpm, 2,600 psi, off btm torque 8.5K Monitored well-static Backreaming out from 12,230' to 10,663' to run 4.5' liner, backreaming out at 300 gpm, 2,500 psi, 115 rpm's Backreamed out from 10,663' to 7,398' (75/8" csg shoe) circ at 300 gpm at 1,850 psi, 115 rpm's with 4K ft-Ibs torque, no problems backreaming Circ 2 btms up and clean at shakers, circ at 300 gpm at 1,900 psi and 100 rpm's, no increase in cuttings at btms up Monitored well 15 min-static POOH 4 stds and hole didn't take calc fill, swabbing inside of csg. Pumped out of hole to 6,014', monitored well-static, worked pipe and still wanting to swab, cont to pump out of hole to 3,878', monitored well at 5,110' and 4,600' and still swabbing, monitored well at 5,110 & 4,600' and well-static POOH on elevators, hole taking calc fill, pumped slug at 2,000', POOH to BHA Printed: 10/10/2003 1:22:00 PM ..... . I ConocoPhiUips Alaska Page 7 of 10 . . .. . Operations SUmmary Report Legal Well Name: 1 B-1 01 Common Well Name: 1 B-1 01 Spud Date: 8/15/2003 Event Name: ROT - DRILLING Start: 8/15/2003 End: Contractor Name: n1334@ppco.com Rig Release: 9/9/2003 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 8/29/2003 12:00 - 13:15 1.25 DRILL PULD PROD Stood back std of flex dc's, download MWD, LD MWD, muud motor & bit 13:15 - 15:00 1.75 DRILL PULD PROD PU 6 stds of 4" hwdp & stood back 15:00 - 15:30 0.50 CASE RURD CMPL TN RU Doyon's 4 1/2' handling tools and held PJSM on running liner 15:30 - 20:30 5.00 CASE PULR CMPL TN PU & ran 173 jts of 41/2" 12.6# L-80 NSCT liner, ran 77 jts of slotted and 96 jts of blank liner, MU Baker 41/2' x 7 5/8' SC-1 R Packer Assembly. Overall liner & packer length 5,348.7', used 171 41/2" x 6 1/4" spiral guide centralizers 20:30 - 22:15 1.75 CASE RUNL CMPL TN RIH with liner & packer on 20 stds of 4" DP to 7,295' 22:15 - 22:30 0.25 CASE CIRC CMPL TN Circ 1 DP volume at csg shoe, circ at 3 bpm at 400 psi, up wt 90K, dn wt 72K, rotated at 10 rpm's with 3K ft-Ibs torque and 78K rot wt 22:30 - 00:00 1.50 CASE RUNL CMPL TN RIH with add 23 stds of 4" DP (43 total) with liner & packer to 9,513' with no problems and good returns, up wt 100K, dn wt 66K, Note: 1 st 54 stds 4' DP to have LoTads 8/30/2003 00:00 - 02:00 2.00 CASE RUNL CMPL TN Fin RIH with 41/2" liner on 4" DP from 9,513', tagged btm at 12,230', no problems RIH with liner, string wt up 112K, dn wt 65K 02:00 - 03:45 1.75 CASE RUNL CMPL TN Dropped 29/32" ball and pumped down, ball on seat after 62 bbls, staged pressure up to 3,100 psi to set SC-1 R pkr, slacked off, PU & closed annular and tested pkr to 1,000 psi, ck ok, press up to 2,000 and released setting tool, press up on DP to 4,600 psi with test pump and blew ball seat, set SC-1 R pkr at 6,882' with liner set to 12,230'. Note: After dropping ball and after 35 bbls pumped, bgg increased to 200 units and 9.6 ppg mud was gas cut to 8.2 ppg, with ball on seat bgg down to 130 units. 03:45 - 05:00 1.25 CASE CIRC CMPL TN Circ 1 complete hole volume at 6 bpm at 975 psi, initial bgg 130 units, 9.6 mud initially gas cut to 9.1, after btms up bgg down to 15 units and had 9.6 in & out. 05:00 - 05:30 0.50 CASE RUNL CMPL TN Monitored well, weeped slightly then static after 15 min, POOH 3 stds to 6,530' and didn't take proper fill 05:30 - 07:30 2.00 CASE CIRC CMPL TN Circ & raised MW from 9.6 ppg to 9.8 ppg, with 9.8 ppg mud in & out, circ at 8 bpm at 1,200 psi, monitored well-static 07:30 - 09:30 2.00 CASE RUNL CMPL TN Pumped out of hole from 6,530' to 5,590' due to well wanting to swab, pumped at 4 bpm at 550 psi. Monitored well-static. Blow down mud line 09:30 - 12:30 3.00 CASE RUNL CMPL TN POOH & LD packer setting tool, Note Changed out shock hose and Unibolt flange on mud line on trip out of hole. 12:30 - 14:30 2.00 WINDOWPULD CMPL TN PU & MU Baker's 7 5/8" btm trip whipstock on BHA #6 with MWD and oriented whipstock 14:30 - 15:00 0.50 WINDOWOTHR CMPL TN Retrieved rabbit from stand of HWDP 15:00 - 17:00 2.00 WINDOwrRIP CMPL TN TIH with whipstock and 9 stds of HWDP to 946', pressure tested mudline to 3,500 psi and pulse tested MWD. 17:00 - 20:00 3.00 WINDOwrRIP CMPL TN TIH slow with whipstock from 946' to 6,280' 20:00 - 20:30 0.50 WINDOWOTHR CMPL TN Log down with MWD from 6,230' to 6,260' and correlated well 20:30 - 21 :00 0.50 WINDOwrRIP CMPL TN TIH to 6,823', est circ at 6 bpm at 1,750 psi, up wt 102K, dn wt 77K 21 :00 - 21 :45 0.75 WINDOWSETW CMPL TN Oriented whipstock with MWD, set whipstock at 6,882' at 30 deg left with 76 deg angle. 21 :45 - 00:00 2.25 WINDOWSTWP CMPL TN Milled window from 6,849' MD/3,756' TVD to 6,852', 2-4K wom, 100 rpm's, 300 gpm at 2,000 psi, off btm torque 3K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 103K, dn wt 76K. Top of window at 6,849', planned btm of window at 6,861' (12') 8/31/2003 00:00 - 02:30 2.50 WINDOWSTWP CMPL TN Milled window in 7 5/8" Csg from 6,852' to 6,874', Top of window at 6,849', btm of window at 6,861', worked thru window several times with pumps off & ck ok 02:30 - 03:15 0.75 WINDOWCIRC CMPL TN Pumped wt'd hi vis sweep and circ hole clean at 300 gpm at 2,000 psi, Printed: 10/10/2003 1 :22:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 8 öf10 ConocoPhillips Alaska Operations Summary Report 1B-101 1 B-1 01 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Date From - To Hours Code Sub Phase Code 8/31/2003 02:30 - 03: 15 0.75 WINDOWCIRC CMPL TN 03:15 - 05:45 2.50 WINDOWTRIP CMPL TN 05:45 - 08:00 2.25 WINDOWPULD CMPL TN 08:00 - 08:45 0.75 WINDOWOTHR CMPL TN 08:45 - 13:30 4.75 WELCTL BOPE PROD 13:30 - 15:30 2.00 DRILL PULD PROD 15:30-18:15 2.75 DRILL TRIP PROD 18:15 - 20:30 2.25 RIGMNT RSRV PROD 20:30 - 20:45 0.25 DRILL OTHR PROD 20:45 - 00:00 3.25 DRILL DRLG PROD 9/1/2003 00:00 - 12:00 12:00 - 00:00 9/2/2003 00:00 - 12:00 12:00 - 00:00 9/3/2003 00:00 - 14:00 14:00 - 16:00 16:00 - 21:30 21 :30 - 21 :45 21 :45 - 00:00 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 14.00 DRILL DRLG PROD 2.00 DRILL 5.50 DRILL 0.25 DRILL 2.25 DRILL CIRC REAM OBSV CIRC PROD PROD PROD PROD Description of Operations had 10% increase in cutting from sweep Monitored well-static, pumped dry job & POOH to BHA at 912' Stood back HWDP and LD whipstock mills, top watermelon mill in gauge, RU & Flushed out BOP stack, cleared rig floor, pulled wear bushing & installed test plug RU & tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi low and 3,500 psi high, good test, pulled test plug & installed wear bushing. Note Chuck Scheve with AOGCC waived witnessing of test MU 6 3/4" BHA #7 with bit #4RR1, PU MWD & changed out battery and oriented tool. TIH from 251' to 6,742' Cut & Slip 65' of drlg line, serviced top drive, drawworks and changed out swivel packing Oriented BHA to 30 deg left, RIH thru window with no problems Drill, slide & survey 6 3/401 hole from 6,874' to 6,988' MD/ 3,672' TVD, ART -0-, AST 2 hrs, 2-10K wob, -0- rpm's, 60 spm, 255 gpm, 1,400 psi, up wt 108K, dn wt 72K, max gas while drlg 425 units, 9.6 ppg mud gas cut to 9.3 ppg Drill, slide & survey 6 3/401 hole per geologist from 6,988' to 7,630' MDI 3,676' TVD, (642'), ART 4.7 hrs, AST 3 hrs, 2-15K wob, 110 rpm's, 70 spm, 295 gpm, off btm press 1,650 psi, on btm 1,800 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 110K, dn wt 65K, 9.6 ppg MW, ave ECD 11.1 ppg, Ave BGG 200-250 units, max gas 600 units, 9.6 MW, ave gas cut.2 to .3 ppg, displaced hole with new 9.6 ppg Flo Pro mud at 7,126' Drill, slide & survey 6 3/401 hole per geologist from 7,630' to 8,673' MDI 3,661' TVD, (1,043'), ART 5.5 hrs, AST 2.3 hrs, 5-15K wob, 100-105 rpm's, 70 spm, 295 gpm, off btm press 1,750 psi, on btm 1,900 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 113K, dn wt 62K, 9.6 ppg MW, ave ECD 11.1 ppg, Ave BGG 150- 200 units, max gas 350 units, 9.6 MW, ave gas cut.1 to.2 ppg Drilled from 8673 - 9450. ART 4.5 AST 2.6. 295 gpm 2050 psi. PU(112-122) SO(60-46) ROT(85-83) TO and Drag values are corresponding to the following model friction factors: (15% casing) (30% open hole). The PU and SO values deteriorated 5-10k Ibs between 9200 and 9600 MD. Lubricant concentration was increased from 2-3 % and the values returned to the original trend line. Drilled from 9450-10704. ART 6.8 AST 1.0. 295 gpm 2400 psi. PU(122-128) SO(46-53) ROT(84-80) TO and Drag values are corresponding to the following model friction factors: (15% casing) (30% open hole). Drilled from 10704 - 12197. ART 7.7 AST 0.5. 295 gpm PP on BTM (2400-2800) PP off BTM (2250-2700). RPM 100. PU(126-145) SO(41-54) ROT(81-95) TQ off BTM (7.5-9) TO on BTM (8-9.5) ECD(11.8-12.4) WOB (2-5). TO and Drag values are corresponding to the following model friction factors: (0.15 casing) (0.30 open hole). Circulate sweep, 70 spm, 2800 psi, 115 RPM. Flow check - static. Backream out to 6935,100 rpm, 70 spm. Flow check - static. POOH across window to 6742. Circ/cond. RotatelRecip while wt up from 9.6 to 9.8 ppg. 70 spm, 1800 psi, 110 rpm. Printed: 10/10/2003 1 :22:00 PM - .. , Page 9 of 10 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-1 01 1B-101 ROT - DRILLING n1334@ppco.com Doyon 141 Date From - To Hours· Code ¿;o~e Phase 9/4/2003 00:00 - 00:30 00:30 - 05:15 05:15 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 - 10:30 0.50 DRILL CIRC PROD 4.75 DRILL OBSV PROD 1.75 DRILL PULD PROD 1.00 CMPL TN RURD CMPL TN 2.00 CMPL TN TRIP CMPL TN 0.50 CMPL TN OTHR CMPL TN 10:30 -11:15 11 :15 - 12:00 12:00 - 13:30 0.75 CMPL TN CIRC CMPL TN 0.75 CMPL TN OBSV CMPL TN 1.50 CMPLTN TRIP CMPLTN 13:30 - 14:00 14:00 - 14:45 0.50 CMPLTN TRIP CMPLTN 0.75 CMPL TN CIRC CMPL TN 14:45 - 15:30 0.75 CMPLTN CIRC CMPL TN 15:30 - 16:00 0.50 CMPL TN TRIP CMPL TN 16:00 - 18:00 2.00 CMPL TN TRIP CMPL TN 18:00 - 19:00 1.00 CMPL TN OBSV CMPL TN 19:00 - 19:30 0.50 CMPL TN TRIP CMPL TN 19:30 - 20:30 1.00 CMPL TN CIRC CMPL TN 20:30 - 22:30 2.00 CMPL TN CIRC CMPL TN 22:30 - 00:00 1.50 CMPL TN CMPL TN 9/5/2003 00:00 - 02:30 2.50 CMPL TN TRIP CMPL TN 02:30 - 03:15 0.75 CMPL TN OTHR CMPL TN 03:15 - 04:45 1.50 FISH PULD CMPL TN 04:45 - 05:45 1.00 FISH TRIP CMPL TN 05:45 - 06:30 0.75 FISH CIRC CMPL TN 06:30 - 07:30 1.00 FISH TRIP CMPL TN 07:30 - 09:15 1.75 WELCTL OBSV CMPL TN 09:15 -13:00 3.75 WELCTL CIRC CMPL TN 13:00 - 13:15 0.25 WELCTL OBSV CMPL TN 13:15 - 15:30 2.25 FISH CIRC CMPL TN 15:30 - 16:30 1.00 FISH CIRC CMPL TN 16:30 - 17:00 0.50 FISH OTHR CMPL TN 17:00 - 18:30 1.50 FISH FISH CMPL TN 18:30 - 21 :00 2.50 FISH TRIP CMPL TN 21 :00 - 23:00 2.00 FISH TRIP CMPL TN 23:00 - 00:00 1.00 FISH FISH CMPL TN 9/6/2003 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN 03:30 - 05:30 2.00 CMPL TN RURD CMPL TN Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations Spot lube pill. Observe well - TOH to 4176 - Pump dry job - TOH to BHA (251' MD). LD drilling BHA. PU whipstock retrieval BHA. TIH to 6854. Hook anchorlseal assy. Observe well. Pulled anchor loose with 77k overpull. Observe well. Circulate BU 6 bpm, 1450 psi. Observe well - TOH to 6660. Continue TOOH to 5710. 10-30 ftlmin. Gained 11.5 bbl total - mild swabbing. TIH to 6250, 20 ftlmin. CBU, 60 spm, 1475 psi. Very thick gas cut mud to surface @ 1100 stks. (BU strokes, 1870) Continue to circulate. Mud gas cut to 7.4 ppg @ BU. Continue to circulate and condition mud to 9.8 ppg in and out. TIH to 6815. 20 ftlmin. Circulate and condition. Stage up to 70 spm, 2000 psi, 3 BU. No very thick mud this time. Flow check, POOH 5 stands to 6350. Gained 4 bbls. TIH to 6815. Circulate and condition. Stage up to 85 spm, 2900 psi. Reciprocate pipe 60' @ 30 ftlmin. On bottoms up, mud cut to 7.4 ppg. Circulate and condition @ 60 spm, 1600 psi. Reciprocate pipe 70 ftlmin. Condition mud from Yp 34, vis 60, to Yp 28, vis 50. Flow check. POOH 20 ftlmin. Work pipe to insure proper hole fill. Continue TOH to 4742. Pump dry job, TOH to BHA (873'). Stand back HWDP, LD hook. (Whip stock not retrieved) MU box tap overshot, flex DC's, float sub, 9 stands HWDP. RIH to 3771. Fill pipe, circ and condition @ 6 bpm, 1050 psi. TIH to 6811. Circ and condition @ 7 BPM, 1700 psi. Lost 20 bbls in 5 minutes. Slow pump to 3 bpm. Lost 150 bbl total. Shut down, observe well 30 min. Well breathing. Record slow pump rates. Flow increased. 8 bbl gain. Shut in, monitor pressure, start to circulate out influx through choke @ 30 spm until 9.8 ppg mud all around. Check pressure, open annular, monitor well - static. Circulate and condition, rotate and recip., stage up to 60 spm, 1200 psi, 100 rpm, 3000 ft-Ib torque. Clean and load pit 5 with 9.8 ppg brine. Pump 20 bbl high vis spacer and displace with 9.8 ppg brine, 75 spm, 1350 psi, 120 rpm, 2500 ftlb torque. Monitor well - static. Check TQ and drag. Wash down tag top whipstock. Attempt to work box tap over - no success. CBU 75 spm @ 1200 psi. Trip to surface and LD box tap. MU hook, TIH to fish, tag @6856, PU 106, SO 80. Engage fish. Extra 2,000 Ibs on pick up weight. Pump out of hole to 6473. Observe well, continue TOOH on elevators to 873. LD whipstock and BHA. Clear floor in preparation for liner running equipment. Printed: 10/10/2003 1 :22:00 PM . . ConocoPhillips .Ålaska Operations Summary. Report RU to run 4.5" slotted upper lateral liner. PJSM wI co reps, toolpushers, and rig crew. Run 4.5" liner to 5295. (170 joints) RU to run 2 7/8" inner wash string. Run 2 7/8" inner wash string. Space out work string and MU liner hook hanger assembly. Run liner on DP to 6780. CBU 40 spm, 700 psi. Gas at surface, circulate an additional 1000 stks for a total of 3100 strokes. Flow check, continue running liner. Break circulation 10 stands outside of window. Continue running liner to setting depth of 12,172. Work and rotate string to line up hook hanger per on site Baker representative. Drop setting ball. Weights just above setting depth: (PU 130) (SO 71). 2.50 CMPL TN RUNT CMPL TN Continue to pump ball down. Ball on seat @ 640 stks. Pressure up to 2600 psi, release from HR running tool. Pressure up to 3200, blow ball seat. Circulate 1 BU @ 6 bpm, 2275 psi clean brine. Observe well, pump dry job. Service top drive and blocks. TOOH, LD 27 joints HWDP, 186 DP, 55 LoTads. Service running tool. LD inner string swivel and XO. RU to LD 2 7/8" wash string. LD inner wash string. Note: Performed injectivity test on 10.75" x 7.625" annulus with 750 psi 9.6 ppg mud. 2200' TVD = 16.2 EMW. Flushed annulus w/260 bbl fresh water and freeze protected with 130 bbl diesel. RD 2 7/8" equipment and clear floor tools. TIH with 61 stands DP from derrick. Slip and cut drilling line. LD 4" DP. Pull Wear ring and LD same. RU to run 4.5 tubing. PJSM. Run 4.5" 12.6# L-80 IBT mod tubing. Tail at 6830. Pressure tubing t/2500 to set packer @ 6172. Hole for 10 min. Unsting and circ clean 9.8 ppg brine. 100 SPM @ 1000 psi. Space out, MU hanger and landing joint. RU TEC and SSSV hanger control lines to hanger. Test lines to 5000 psi. Land tubing. RILDS. Test hanger seals to 5000 for 15 min. Pressure test annulus to 1500, bleeding off 100 every 10 min. Install TWC. ND BOP. Test annulus to 1500 - No success. NU tree. Pressure test tubing to 3500 psi to set packer - hold for 10 min. tubing test. Hold 2000 on tubing. Pressure test annulus to 3000 for 10 min. Good test. Bleed tubing to shear RP valve. Install TWC. Test tree to 5000. Pull TWC. Freeze protect with 115 bbls diesel. U-Tube the diesel. Install BPV. NU actuator valve on tree. Secure well. RIG RELEASED 09/09/2003 0400 HRS. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-1 01 1B-101 ROT - DRILLING n 1334@ppco.com Doyon 141 Date From - To Hours Code Sub .. Phase Code 9/6/2003 05:30 - 05:45 0.25 CMPL TN RURD CMPL TN 05:45 - 06:15 0.50 CMPL TN SFTY CMPL TN 06:15 - 11 :15 5.00 CMPL TN RUNT CMPL TN 11 : 15 - 12:00 0.75 CMPL TN RURD CMPL TN 12:00 - 16:45 4.75 CMPL TN RUNT CMPL TN 16:45 - 17:45 1.00 CMPL TN RUNT CMPL TN 17:45 - 19:00 1.25 CMPL TN RUNT CMPL TN 19:00 - 20:30 1.50 CMPL TN CIRC CMPL TN 20:30 - 23:00 2.50 CMPL TN RUNT CMPL TN 23:00 - 00:00 1.00 CMPL TN RUNT CMPL TN 9/7/2003 00:00 - 02:30 02:30 - 03:00 0.50 RIGMNT RSRV CMPL TN 03:00 - 10:30 7.50 CMPL TN TRIP CMPL TN 10:30 - 11 :00 0.50 CMPL TN OTHR CMPL TN 11 :00 - 16:00 5.00 CMPL TN TRIP CMPL TN 9/8/2003 16:00 - 16:30 0.50 CMPL TN RURD CMPL TN 16:30 - 18:30 2.00 CMPL TN OTHR CMPL TN 18:30 - 19:30 1.00 RIGMNT RSRV CMPL TN 19:30 - 00:00 4.50 CMPL TN TRIP CMPL TN 00:00 - 00:30 0.50 CMPL TN RURD CMPL TN 00:30 - 02:00 1.50 CMPL TN RURD CMPL TN 02:00 - 12:30 10.50 CMPL TN RUNT CMPL TN 12:30 - 13:15 0.75 CMPLTN RUNT CMPL TN 13:15 - 14:00 0.75 CMPLTN RUNT CMPL TN 14:00 - 14:30 0.50 CMPL TN RUNT CMPL TN 14:30 - 15:00 0.50 CMPL TN RUNT CMPL TN 15:00·16:00 1.00 CMPL TN RUNT CMPL TN 16:00 - 17:30 1.50 CMPL TN DEQT CMPL TN 17:30 - 20:00 2.50 CMPL TN DEQT CMPL TN 20:00 - 21 :ÒO 1.00' CMPL TN NUND CMPL TN 21 :00 - 21 :30 0.50 CMPL TN DEQT CMPL TN 21 :30 - 22:00 0.50 CMPL TN DEQT CMPL TN 22:00 - 23:00 1.00 CMPL TN DEQT CMPL TN 23:00 - 00:00 1.00 CMPL TN FRZP CMPL TN 00:00 . 02:30 2.50 CMPL TN FRZP CMPL TN 02:30 - 03:30 1.00 CMPL TN RURD CMPL TN 03:30 - 04:00 0.50 CMPL TN OTHR CMPL TN 9/9/2003 Page 10 of 10 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: .... . . Description of Op~rations Printed: 10/10/2003 1 :22:00 PM .....- - . . . .. = ~URVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. Page of 2 .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT ,,.,.. a:Q Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name Definitive Survey BHI Rep. C MILCHAK I D BALLOU WELL DATA TargetTVD (F1) Target Coord. N/S Slot Coord. N/S -501 .00 Grid Correction 0.000 Depths Measured From: RKB~ MSLD SSD Target Description Target Coord. EIW Slot Coord. EIW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT] (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 15-AUG-03 GSS 148.00 0.00 0.00 148.00 148.00 0.00 0.00 0.00 0.00 0.00 .- 15-AUG-03 GSS 168.00 0.50 265.00 20.00 168.00 0.01 -0.01 -0.09 2.50 2.50 15-AUG-03 GSS 258.00 0.30 138.00 90.00 258.00 -0.16 -0.22 -0.32 0.80 -0.22 16-AUG-03 GSS 349.00 1.00 117.00 91.00 348.99 -0.84 -0.75 0.55 0.80 0.77 16-AUG-03 GSS 440.00 2.35 112.00 91.00 439.95 -2.32 -1.81 2.98 1.49 1.48 16-AUG-03 GSS 563.39 6.85 119.66 123.39 562.91 -8.40 -6.41 11.73 3.67 3.65 6.21 MWD SURVEY 16-AUG-03 GSS 621.00 10.00 108.00 57.61 619.90 -12.98 -9.65 19.47 6.19 5.47 -20.24 16-AUG-03 GSS 712.00 11.00 121 .00 91.00 709.39 -22.47 -16.57 34.43 2.82 1.10 14.29 16-AUG-03 MWD 837.57 13.12 131.49 125.57 832.19 -41.58 -32.18 55.38 2.42 1.69 8.35 16-AUG-03 MWD 925.27 15.31 127.51 87.70 917.20 -57.99 -45.83 72.02 2.73 2.50 -4.54 16-AUG-03 MWD 1016.16 15.45 126.76 90.89 1004.84 -75.75 -60.38 91.24 0.27 0.15 -0.83 16-AUG-03 MWD 1107.80 18.46 126.46 91.64 1092.49 -95.26 -76.31 112.69 3.29 3.28 -0.33 16-AUG-03 MWD 1201 .39 23.44 119.78 93.59 1179.87 -118.07 -94.37 140.79 5.89 5.32 -7.14 16-AUG-03 MWD 1294.27 26.13 113.42 92.88 1264.21 -141.34 -111.69 175.60 4.07 2.90 -6.85 -- 16-AUG-03 MWD 1387.43 30.33 108.76 93.16 1346.28 -164.18 -127.41 216.72 5.09 4.51 -5.00 16-AUG-03 MWD 1482.04 35.74 106.11 94.61 1425.57 -188.11 -142.77 265.93 5.92 5.72 -2.80 16-AUG-03 MWD 1572.07 40.47 106.48 90.03 1496.39 -213.00 -158.37 319.24 5.26 5.25 0.41 16-AUG-03 MWD 1665.65 44.78 104.97 93.58 1565.23 -240.78 -175.51 380.23 4.73 4.61 -1.61 16-AUG-03 MWD 1759.13 50.16 103.96 93.48 1628.40 -269.63 -192.68 446.91 5.81 5.76 -1.08 16-AUG-03 MWD 1852.25 56.45 103.71 93.12 1684.02 -300.16 -210.52 519.38 6.76 6.75 -0.27 16-AUG-03 MWD 1943.90 62.40 104.00 91.65 1730.61 -332.46 -229.41 595.95 6.50 6.49 0.32 16-AUG-03 MWD 2036.74 67.03 103.29 92.84 1770.26 -366.54 -249.20 677.51 5.03 4.99 -0.76 16-AUG-03 MWD 2128.73 64.06 105.29 91.99 1808.34 -401 .39 -269.85 758.64 3.79 -3.23 2.17 ,a. ~~.- . ---- ~ ---- --- II---..! L--J L---' 1----1 L A A. = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. Page 2 of 2 .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name Definitive Survey BHI Rep. C MILCHAK I D BALLOU '''''.eQ WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501 .00 Grid Correction 0.000 Depths Measured From: RKB g] MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 16-AUG-03 MWD 2221.73 65.24 104.16 93.00 1848.16 -436.97 -291 .21 839.93 1.68 1.27 -1.22 16-AUG-03 MWD 2314.82 65.03 104.75 93.09 1887.30 -472.36 -312.29 921.71 0.62 -0.23 0.63 . 16-AUG-03 MWD 2407.31 67.35 104.33 92.49 1924.64 -507.93 -333.53 1003.62 2.54 2.51 -0.45 16-AUG-03 MWD 2500.51 66.03 102.82 93.20 1961.52 -542.60 -353.62 1086.81 2.05 -1.42 -1.62 17-AUG-03 MWD 2593.98 64.42 104.13 93.47 2000.69 -576.83 -373.39 1169.34 2.14 -1.72 1.40 17 -AUG-03 MWD 2685.77 66.61 105.27 91.79 2038.73 -612.17 -394.59 1250.13 2.64 2.39 1.24 17-AUG-03 MWD 2779.01 67.08 102.24 93.24 2075.40 -647.13 -414.97 1333.39 3.03 0.50 -3.25 17-AUG-03 MWD 2872.58 64.99 103.46 93.57 2113.40 -680.76 -433.98 1416.75 2.53 -2.23 1.30 17 -AUG-03 MWD 2965.21 64.45 103.42 92.63 2152.96 -714.51 -453.45 1498.21 0.58 -0.58 -0.04 17-AUG-03 MWD 3035.64 64.75 104.23 70.43 2183.17 -740.53 -468.65 1559.99 1.12 0.43 1.15 17-AUG-03 MWD 3090.00 64.75 104.23 54.36 2206.36 -760.96 -480.74 1607.65 0.00 0.00 0.00 Projected Data - NO SURVEY e- - L-.J L.J LJ L-.t L-JI ------- --ÍI -----II --- ----Ii ii ¡jf,ì ~ ii1 jÎ.. = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 1 of 5 - - . I . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name 1 B-101 MWD BHI Rep. C MILCHAK I D BALLOU 'Iv.~ WELL DATA Target rvD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLD ssD Target Description Target Coord. E/W Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) I S(-) E(+) IW(-) DL Buifd (+) Right (+) Comment Type (FT) (DO) (DO) (F1) (F1) (F1) (F1) (Per 100 F1) Drop (-) Left (-) MWD 1665.65 44.78 104.97 1565.23 -241.09 -175.51 380.23 TIE IN POINT 17-AUG-03 MWD 1754.06 47.03 105.17 88.41 1626.75 -268.01 -192.02 441.54 2.55 2.54 0.23 -= 17-AUG-03 MWD 1847.26 50.32 105.02 93.20 1688.28 -298.05 -210.24 509.10 3.53 3.53 -0.16 17-AUG-03 MWD 1940.41 60.71 105.20 93.15 1740.95 -330.98 -230.24 583.13 11.16 11.15 0.19 17-AUG-03 MWD 2033.97 64.01 105.01 93.56 1784.35 -366.55 -251.83 663.14 3.53 3.53 -0.20 17-AUG-03 MWD 2126.17 68.86 104.62 92.20 1821 .20 -402.43 -273.43 744.81 5.27 5.26 -0.42 17-AUG-03 MWD 2219.38 67.11 105.09 93.21 1856.13 -439.19 -295.58 8213.34 1.93 -1.88 0.50 17-AUG-03 MWD 2310.95 65.81 105.52 91.57 1892.71 -475.50 -317.74 909.31 1.48 -1.42 0.47 18-AUG-03 MWD 2404.74 68.27 103.21 93.79 1929.29 -511.54 -339.14 992.96 3.47 2.62 -2.46 18-AUG-03 MWD 2497.75 66.63 103.84 93.01 1964.96 -546.26 -359.23 1076.47 1.87 -1.76 0.68 18-AUG-03 MWD 2590.79 66.30 102.99 93.04 2002.11 -580.60 -379.02 1159.44 0.91 -0.35 -0.91 18-AUG-03 MWD 2683.61 66.99 103.64 92.82 2038.91 -614.76 -398.65 1242.37 0.98 0.74 0.70 18-AUG-03 MWD 2776.37 66.60 103.57 92.76 2075.46 -649.34 -418.70 1325.23 0.43 -0.42 -0.08 18-AUG-03 MWD 2869.85 66.25 103.76 93.48 2112.85 -684.16 -438.94 1408.48 0.42 -0.37 0.20 -= 18-AUG-03 MWD 2962.17 65.25 104.36 92.32 2150.76 -718.91 -459.39 1490.13 1.23 -1.08 0.65 18-AUG-03 MWD 3031.87 65.67 105.65 69.70 2179.71 -746.03 -475.80 1551.37 1.79 0.60 1.85 20-AUG-03 MWD 3157.37 65.42 102.02 125.50 2231.68 -792.77 -503.12 1662.27 2.64 -0.20 -2.89 20-AUG-03 MWD 3250.88 65.26 103.03 93.51 2270.70 -825.76 -521.55 1745.23 1.00 -0.17 1.08 2O-AUG-03 MWD 3343.91 65.26 103.35 93.03 2309.63 -859.47 -540.83 1827.49 0.31 0.00 0.34 20-AUG-03 MWD 3436.84 65.38 103.71 92.93 2348.43 -893.61 -560.58 1909.59 0.37 0.13 0.39 20-AUG-03 MWD 3529.84 65.28 103.50 93.00 2387.25 -927.88 -580.46 1991.73 0.23 -0.11 -0.23 2a-AUG-03 MWD 3622.71 65.65 102.50 92.87 2425.82 -961 .33 -599.47 2074.05 1.06 0.40 -1.08 21-AUG-03 MWD 3715.15 67.63 101.12 92.44 2462.47 -993.29 -616.82 2157.11 2.54 2.14 -1.49 21-AUG-03 MWD 3807.83 68.92 97.53 92.68 2496.78 -1022.21 -630.76 2242.05 3.86 1.39 -3.87 . ~ & & I A l . I I l = = L J I L..J LJ ~ L-J LA . t J -~ = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 2 of 5 - - .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name 1 B-1 01 MWD BHI Rep. C MILcHAK I D BALLOU IIV.~ WELL DATA TargetTVD (Fl) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. EIW Slot Coord. EIW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) 21-AUG-03 MWD 3901.55 70.07 95.89 93.72 2529.62 -1047.92 -641 .01 2329.23 2.05 1.23 -1.75 . 21-AUG-03 MWD 4011.56 69.24 93.36 110.01 2567.87 -1074.52 -649.33 2432.03 2.28 -0.75 -2.30 21-AUG-03 MWD 4087.41 66.47 91.60 75.85 2596.46 -1090.09 -652.38 2502.21 4.24 -3.65 -2.32 21-AUG-03 MWD 4179.85 64.95 91.81 92.44 2634.48 -1107.65 -654.89 2586.42 1.66 -1.64 0.23 21-AUG-03 MWD 4272.29 63.82 91.03 92.44 2674.45 -1124.61 -656.96 2669.75 1.44 -1.22 -0.84 21-AUG-03 MWD 4365.85 63.85 90.92 93.56 2715.70 -1141.06 -658.39 2753.71 0.11 0.03 -0.12 21-AUG-03 MWD 4458.58 63.70 91.04 92.73 2756.68 -1157.35 -659.81 2836.88 0.20 -0.16 0.13 21-AUG-03 MWD 4551.52 63.79 91.54 92.94 2797.79 -1174.13 -661.69 2920.21 0.49 0.10 0.54 21-AUG-03 MWD 4644.14 63.72 90.51 92.62 2838.75 -1190.47 -663.17 3003.27 1.00 -0.08 -1.11 21-AUG-03 MWD 4736.00 65.36 90.53 91.86 2878.24 -1206.07 -663.93 3086.20 1.79 1.79 0.02 21-AUG-03 MWD 4829.07 65.26 91.37 93.07 2917.12 -1222.59 -665.33 3170.75 0.83 -0.11 0.90 21-AUG-03 MWD 4922.07 65.33 90.29 93.00 2955.99 -1238.93 -666.55 3255.23 1.06 0.08 -1.16 21-AUG-03 MWD 5015.20 65.18 89.87 93.13 2994.97 -1254.20 -666.67 3339.81 0.44 -0.16 -0.45 e- 21-AUG-03 MWD 5108.07 65.13 91.21 92.87 3033.99 -1270.08 -667.46 3424.08 1.31 -0.05 1.44 21-AUG-03 MWD 5200.58 65.20 90.17 92.51 3072.85 -1286.11 -668.47 3508.02 1.02 0.08 -1.12 21-AUG-03 MWD 5293.56 65.18 84.99 92.98 3111.88 -1297.71 -664.91 3592.31 5.06 -0.02 -5.57 21-AUG-03 MWD 5386.89 65.35 79.79 93.33 3150.96 -1301.71 -653.69 3676.29 5.06 0.18 -5.57 21-AUG-03 MWD 5479.69 65.36 74.68 92.80 3189.68 -1298.11 -635.06 3758.51 5.00 0.01 -5.51 21-AUG-03 MWD 5572.67 65.30 69.89 92.98 3228.50 -1287.24 -609.36 3838.97 4.68 -0.06 -5.15 22-AUG-03 MWD 5665.76 65.29 65.20 93.09 3267.43 -1269.47 -577.07 3917.10 4.58 -0.01 -5.04 22-AUG-03 MWD 5758.28 65.23 63.02 92.52 3306.15 -1246.92 -540.38 3992.69 2.14 -0.06 -2.36 22-AUG-03 MWD 5852.25 66.83 59.47 93.97 3344.34 -1219.76 -499.07 4067.94 3.85 1.70 -3.78 22-AUG-03 MWD 5944.37 67.86 53.89 92.12 3379.84 -1186.54 -452.39 4138.93 5.70 1.12 -6.06 22-AUG-03 MWD 6037.15 68.93 46.66 92.78 3414.04 -1144.21 -397.29 4205.21 7.34 1.15 -7.79 a-......! i. . . l I I L-I 1.-1 L.J \......J 1.-..1 ~ ì",~ .~ ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 3 of 5 - .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 18/101 PB1 I 101 I 101 L 1 Survey Section Name 1 B-101 MWD BHI Rep. C MILCHAK I D BALLOU IIV.Æ:Q WELL DATA TargetTVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. EIW Slot Coord. EIW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 22-AUG-03 MWD 6130.11 68.71 42.45 92.96 3447.64 -1094.35 -335.54 4266.00 4.23 -0.24 -4.53 22-AUG-03 MWD 6223.24 69.77 38.65 93.13 3480.66 -1039.40 -269.38 4322.60 3.98 1.14 -4.08 .- 22-AUG-03 MWD 6316.17 72.38 36.02 92.93 3510.81 -980.19 -199.49 4375.89 3.88 2.81 -2.83 22-AUG-03 MWD 6408.78 73.01 31.38 92.61 3538.37 -916.62 -125.95 4424.92 4.83 0.68 -5.01 22-AUG-03 MWD 6501.72 74.14 25.66 92.94 3564.67 -847.21 -47.65 4467.46 6.03 1.22 -6.15 22-AUG-03 MWD 6594.39 74.86 18.00 92.67 3589.47 -771.67 35.17 4500.62 8.00 0.78 -8.27 22-AUG-03 MWD 6687.40 74.67 10.49 93.01 3613.94 -690.11 122.08 4522.69 7.79 -0.20 -8.07 22-AUG-03 MWD 6780.53 74.97 3.28 93.13 3638.36 -604.32 211 .25 4533.45 7.48 0.32 -7.74 22-AUG-03 MWD 6846.60 75.52 2.67 66.07 3655.18 -542.14 275.06 4536.77 1.22 0.83 -0.92 22-AUG-03 MWD 6873.19 75.66 2.52 26.59 3661 .80 -517.04 300.78 4537.94 0.76 0.53 -0.56 22-AUG-03 MWD 6965.66 75.89 1.63 92.47 3684.52 -429.50 390.36 4541.18 0.97 0.25 -0.96 22-AUG-03 MWD 7059.15 80.64 358.95 93.49 3703.54 -339.56 481.86 4541.63 5.80 5.08 -2.87 22-AUG-03 MWD 7151.73 84.61 355.82 92.58 3715.42 -248.60 573.54 4537.43 5.44 4.29 -3.38 22-AUG-03 MWD 7244.69 86.83 351.96 92.96 3722.36 -156.17 665.69 4527.56 4.78 2.39 -4.15 -= 23-AUG-03 MWD 7337.24 86.74 347.23 92.55 3727.55 -63.79 756.55 4510.87 5.10 -0.10 -5.11 26-AUG-03 MWD 7415.39 87.46 351.42 78.15 3731.51 14.24 833.24 4496.42 5.43 0.92 5.36 26-AUG-03 MWD 7510.61 87.45 349.68 95.22 3735.74 109.35 927.07 4480.80 1.83 -0.01 -1.83 26-AUG-03 MWD 7608.73 90.06 348.80 98.12 3737.87 207.43 1023.43 4462.49 2.81 2.66 -0.90 26-AUG-03 MWD 7705.93 91.81 350.10 97.20 3736.28 304.61 1118.97 4444.70 2.24 1.80 1.34 26-AUG-03 MWD 7803.29 92.86 349.45 97.36 3732.32 401 .89 1214.70 4427.43 . 1.27 1.08 -0.67 26-AUG-03 MWD 7852.43 91.63 349.00 49.14 3730.39 450.99 1262.94 4418.25 2.67 -2.50 -0.92 26-AUG-03 MWD 7898.79 92.83 349.23 46.36 3728.59 497.31 1308.43 4409.50 2.64 2.59 0.50 26-AUG-03 MWD 7950.79 91.01 350.10 52.00 3726.85 549.28 1359.55 4400.18 3.88 -3.50 1.67 26-AUG-03 MWD 7995.95 90.98 350.59 45.16 3726.06 594.43 1404.06 4392.60 1.09 -0.07 1.09 , L- J L~~j Lc",J L.J L-J I....-J . I I I . . ~ I.....J l-,.;..I ~ i---A \.;...-I ~ ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 4 of 5 .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name 1 B-1 01 MWD BHI Rep. C MILCHAK I D BALLOU IIV.~ WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. EIW Slot Coord. EIW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 26-AUG-03 MWD 8050.69 90.52 350.36 54.74 3725.34 649.16 1458.04 4383.55 0.94 -0.84 -0.42 26-AUG-03 MWD 8110.33 90.77 350.79 59.64 3724.67 708.79 1516.88 4373.78 0.83 0.42 0.72 .- 26-AUG-03 MWD 8157.49 90.25 350.19 47.16 3724.25 755.94 1563.39 4365.99 1.68 -1.10 -1.27 26-AUG-03 MWD 8188.92 90.00 349.91 31.43 3724.19 787.37 1594.34 4360.56 1.19 -0.80 -0.89 26-AUG-03 MWD 8285.54 90.06 349.39 96.62 3724.13 883.99 1689.39 4343.20 0.54 0.06 -0.54 26-AUG-03 MWD 8382.65 88.59 349.09 97.11 3725.28 981.09 1784.78 4325.07 1.54 -1.51 -0.31 26-AUG-03 MWD 8478.05 89.66 347.11 95.40 3726.74 1076.43 1878.12 4305.40 2.36 1.12 -2.08 26-AUG-03 MWD 8576.30 88.68 351.88 98.25 3728.16 1174.64 1974.68 4287.50 4.96 -1.00 4.85 27-AUG-03 MWD 8673.39 88.53 353.85 97.09 3730.52 1271.55 2070.98 4275.44 2.03 -0.15 2.03 27-AUG-03 MWD 8769.17 89.60 354.55 95.78 3732.09 1367.02 2166.26 4265.76 1.33 1.12 0.73 27-AUG-03 MWD 8866.57 89.85 351.95 97.40 3732.55 1464.22 2262.98 4254.32 2.68 0.26 -2.67 27 -AUG-03 MWD 8962.31 89.08 349.43 95.74 3733.45 1559.93 2357.44 4238.83 2.75 -0.80 -2.63 27 -AUG-03 MWD 9060.31 90.77 349.67 98.00 3733.58 1657.93 2453.81 4221 .06 1.74 1.72 0.24 27-AUG-03 MWD 9156.90 90.77 349.59 96.59 3732.28 1754.51 2548.82 4203.67 0.08 0.00 -0.08 -= 27-AUG-03 MWD 9254.22 90.67 349.46 97.32 3731.06 1851.82 2644.51 4185.98 0.17 -0.10 -0.13 27-AUG-03 MWD 9351.48 90.89 348.75 97.26 3729.73 1949.07 2740.00 4167.60 0.76 0.23 -0.73 27-AUG-03 MWD 9447.77 91.14 349.01 96.29 3728.03 2045.33 2834.47 4149.03 0.37 0.26 0.27 27-AUG-03 MWD 9544.41 91.53 348.64 96.64 3725.77 2141.93 2929.25 4130.31 0.56 0.40 -0.38 27-AUG-03 MWD 9641.38 90.55 348.76 96.97 3724.01 2238.87 3024.33 4111.31 1.02 -1.01 0.12 27-AUG-03 MWD 9736.33 90.86 347.79 94.95 3722.85 2333.79 3117.29 4092.01 1.07 0.33 -1.02 27-AUG-03 MWD 9833.98 90.12 346.97 97.65 3722.01 2431.35 3212.57 4070.68 1.13 -0.76 -0.84 27-AUG-03 MWD 9930.97 91.13 346.62 96.99 3720.95 2528.21 3306.99 4048.53 1.10 1.04 -0.36 27-AUG-03 MWD 10028.47 91.08 348.65 97.50 3719.07 2625.63 3402.21 4027.65 2.08 -0.05 2.08 27-AUG-03 MWD 10124.56 92.11 348.11 96.09 3716.40 2721.65 3496.29 4008.31 1.21 1.07 -0.56 L.J. L....I I f L.J i Ii ¡¡~ ~ 1;;., ----... , '~ =¡ a, ", I ..1 .J !IJ.. ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 5 of 5 - .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1 1101 1101 L1 Survey Section Name 1 B-1 01 MWD BHI Rep. C MILCHAK I D BALLOU INìEG1 WELL DATA TargetTVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. Ef'N Slot Coord. Ef'N -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) 27-AUG-03 MWD 10221.29 91.35 349.91 96.73 3713.48 2818.33 3591.20 3989.87 2.02 -0.79 1.86 27-AUG-03 MWD 10317.86 90.40 348.57 96.57 3712.00 2914.88 3686.06 3971.85 1.70 -0.98 -1.39 -= 27-AUG-03 MWD 10414.50 89.54 349.16 96.64 3712.05 3011.51 3780.87 3953.19 1.08 -0.89 0.61 27-AUG-03 MWD 10511.39 90.15 349.16 96.89 3712.32 3108.39 3876.03 3934.96 0.63 0.63 0.00 28-AUG-03 MWD 10609.17 90.03 350.51 97.78 3712.16 3206.17 3972.28 3917.71 1.39 -0.12 1.38 28-AUG-03 MWD 10705.21 89.63 350.55 96.04 3712.45 3302.20 4067.01 3901 .91 0.42 -0.42 0.04 28-AUG-03 MWD 10801.37 88.62 351.45 96.16 3713.92 3398.32 4161.97 3886.86 1.41 -1.05 0.94 28-AUG-03 MWD 10897.48 88.43 351.31 96.11 3716.39 3494.36 4256.96 3872.46 0.25 -0.20 -0.15 28-AUG-03 MWD 10995.81 90.12 351.25 98.33 3717.63 3592.64 4354.15 3857.56 1.72 1.72 -0.06 28-AUG-03 MWD 11091.08 91.17 351.17 95.27 3716.56 3687.87 4448.29 3843.00 1.11 1.10 -0.08 28-AUG-03 MWD 11188.88 90.25 351.80 97.80 3715.35 3785.61 4545.00 3828.52 1.14 -0.94 0.64 28-AUG-03 MWD 11284.98 90.55 352.83 96.10 3714.68 3881.60 4640.24 3815.67 1.12 0.31 1.07 28-AUG-03 MWD 11379.55 91.69 351.43 94.57 3712.83 3976.06 4733.89 3802.72 1.91 1.21 -1.48 28-AUG-03 MWD 11477.60 90.86 351.01 98.05 3710.65 4074.05 4830.77 3787.76 0.95 -0.85 -0.43 -- 28-AUG-03 MWD 11574.66 90.21 350.67 97.06 3709.74 4171.09 4926.59 3772.31 0.76 -0.67 -0.35 28-AUG-03 MWD 11670.79 89.79 350.63 96.13 3709.74 4267.20 5021 .44 3756.69 0.44 -0.44 -0.04 28-AUG-03 MWD 11767.94 89.75 349.92 97.15 3710.13 4364.35 5117.19 3740.28 0.73 -0.04 -0.73 28-AUG-03 MWD 11864.35 88.74 349.45 96.41 3711 .40 4460.75 5212.03 3723.02 1.16 -1.05 -0.49 28-AUG-03 MWD 11959.92 87.73 348.65 95.57 3714.35 4556.27 5305.82 3704.88 1.35 -1.06 -0.84 28-AUG-03 MWD 12037.99 89.51 349.50 78.07 3716.23 4634.31 5382.45 3690.09 2.53 2.28 1.09 28-AUG-03 MWD 12135.38 91.32 350.08 97.39 3715.52 4731.69 5478.29 3672.82 1.95 1.86 0.60 28-AUG-03 MWD 12176.49 91.66 350.62 41.11 3714.45 4772.78 5518.80 3665.94 1.55 0.83 1.31 28-AUG-03 MWD 12230.00 91.66 350.62 53.51 3712.90 4826.26 5571.57 3657.22 0.00 0.00 0.00 Projected Data - NO SURVEY ¡ Conoc6Phillips ConocoPhimps Alask c.,Slot #101 Pad 1 B, Kuparuk River Unit, North Slope, Alaska SURVEY LI Page 1 Well bore: 101 Wellpath: MWD w/lFR<1754·12230'> Date Printed: 11·Nov·2003 Name 101 I Cr¡;¡ated, 20-AuQ-2003 I L<;ìst Revised 1-0ct-2003 Name 101 l Govemmer¡t ¡D [Li',st ReVl&t;!d 22-Jul-20ÇJ;3 Nç¡me Pad 1B I E¡3$Ìlno NQrttli£1Q I COQrd Sy~t~ N~lT\e INOrth Alionrn\'!ot 550434.958 5970149.712 AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6664.66 Feet on azimuth 33.28 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc~illips ConocoPhillips Alask c.,Slot #101 Pad 1 B, Kuparuk River Unit,North Slope, Alaska SURVEY U Page 2 Wellbore: 101 Wellpath: MWD w/lFR<1754·12230'> Date Printed: 11·Nov·2003 INTEQ Q.OO o.QO O,OQ O.OQ Q.OON O.OQE O.QO O.QC 5SQ228.31 5969Q47.3! 148.0C O.OQ O.OQ 148.QC O.OON O.OOE 0.00 O.QC 5i;i0~28.3~ (59Q9647 J! 168.0C 0.50 265.0C 168.0C O.o1S 0.09W 2.50' 0.01 550228.2! 5969647.3~ 258.Q( 0.30 138.QC 2S8,OC 0.22$ 0.';'2W 9.1;\0 -O.1!j S50228.0~ 59691;)47.1 , 349.0( 1.00 117.0C 348.9~ O.7SS 0.5(51=. 0,80 -Q.84 ;;50228.g1 9969646.6' 440.0C 2.35 112.0C 439.9E 1.81S 2.98E 1.49 -2.32 550231.31 5969645.5' 563·3~ 6.85 11!¡.6Ç. 56~.9t M1& 1J.73E, 3,!j7 -8.40 550240.1: 596Q641.0: 621.0C 10.0C 108.0C 619.9( 9.65S 19.47E. 6.19 -12.9~ 550247.I,\t 5969!j37.8' 712.0C 11.00 121.0C 709.3£ 16.57:: 34.43E 2.82 -22.47 550262.8! 5969631.0: 837.57 13.12 131.4S 832.1~ 32.18::' 55.38E. 2.42 -41.5E 550283.9'- 5969615.Q! 925.27 15.31 127.91 917.2C 45.83E.. 72.Q2f; 2.73 -57.9!=. 550300.6~ 5969602.0: 1016.1E 15.45 126.7f 1004.8L 60.38:: 91.24£ 0.27 -75.n 550319.9! 5969587.61 1107.8C 18.46 126.4E. 1092.4( 76.31:: 112.69E 3.29 -95.2E, 950341.9' 5969971.8' 1201.3( 23.44 119.7E. 1179.8í 94·38E.. 140.79E ;;.89 -118.07 5S03!j9.7t 5969553.9, 1294.2í 26.13 113.4::: 1264.2' 111.69:: 175.60E 4.07 -141.3,:' 550404.61 5969536.81 1387.4; 30.33 1Q8.7f 1346.21 127,41; 21!j.72E 5.Q9 -164.11;: 55044;;.9l 596952M' 1482.QL 3;;.74 10!j.1· 1425.5í 142.71;ì~ 265.93E 5.92 -188.1C S5Q495.2l (5969599.31 1572.0í 40.47 106.41: 1496.3( 158.37:: 319.24E 5.26' -213.0C 550548.6' 5969491.11 1665.9£ 44.78. 104.97 151;)5Z 175.51~ 31,\0.231;, 4.73 -240.7E 550609.7' 59!)9474.4: 1754.0€ 47,03 1Q5.17 1626,7~ 192.01:: 441.Q3E. 2.55 -268.01 550671,1: 5$69458,3: 1847.2€ 50.32 105.0:::- 1688.21 210.24:: 509.10E 3.53- -298.0t 550738.81 5969440.51 1940.4- 60.71 105.2( 1749.9t 23Q.23:: 583.121;. 11.16 -330.97 550812,91 5969421.m 2033,97 64.Q1 1Q5.0b 1784..3t 251.82::' 663.13E 3.5:;1. -366.5~ 550893.Qt 5969400.0' 2126.17 68.86' 104.6::: 1821.2( 273.42:: 744.81E 5.27 -402.42 550974.9l 5969378.91 2219.31. 67.11 105·0£ 1859.1<' 295.57::' 828.33E 1.93- -43g.1E 551058.5t 5999357.3' 2310.9£ 65.81 105·5L. 1892.7' 317·nE.. 909.30E 1.41> -475.4f 951139.6', 5969335.71 2404.7L 68.27 103.2' 1929.3( 339.14:: 992.96E 3.47 -511.5~ 551223.4( 5969314.9' 2497.7; 1;)f.ì.63 103.8< 1964.9{ 359.22::' 1Q7M7E 1.87 -541;).2E, 551307.0t 2590.7( Q6·3Ç 102.9~ 2Q02.1:; 379.01¡:;' 1159.441;. 0,91 -580.5!; 55139Q.1t 2683.6' 66.99 103.6t 2038.9' 398.64::- 1242.36E 0.98 -614.7E 551473.2: 5969257.m 277¡¡.37 ¡¡6..60 103.(57 2075.4{ 41$,69E; 1325.23E Q.4~ -649.3~ 551556.2~ 5!i11;)9237.5! 2869.$£ 66.25 103.('E 2112·8; 438,94::' 14QIM8E Q.42' -684,1€ 551639.61 5969217,9' 2962.17 65.25 104.3E 2150.7í 459.38:: 1490.13E' 1.23 -718.9C 551721.31 5969198.0' 3031.87 65.67 105·6~ 2179.7;- 47Q.80~ 1551.:m 1.79 -746.0, 551782]: 5969182,01 3157.3í 65.42 102.0:;" 2231,61 503.111; 11;)62.27E. 2.64 -792.7€ 551893.7t 5~e9155,4' 3250.8é 65.26 103.0:: 2270.7( 521.54::' 1745.23E 1.00 -825.7E, 551976.8! 5969137.5! 3343.9' 65.26 103.3~ 2309.6~ 540.82~ 1827.4~E 0.31 -~1;i~ .4E 55205\).2' 5969118,8' 3436.1;ìL 65.3a 103.7' 2348-4" 5QO.58~ 19Q$'5$E 0.37 -$93,QC. 552141.4( 9969099.6: 3529.8< 65.28 103.5C 2387.2£ 580.46:: 1991.73E 0.23 -927.8E 552223.7: 5969080.3' 3622.7' 65.65 102.5C 2425.8: q9!;1.46E.. 2074.0$E. 1.06 -961.3:::' 5$23QQ, it !;i969061.~! 3715.1:' 67.63. 101.1:; 2462.4í 616.82:: 2157.11E 2.54 -!;I!;I3.2E. 552389.3~ 596$045.0t 3807 .8~ 68.92 97.53 2496.7~ 630.76:: 2242.05E 3.86- -1022.2' 552474.3! 5969031.6! 3901.5:' 70.07 95.89 2529.&.. 641.01:: 2329.23E.. 2·05 -1047.9' 5525Q1.5t !;i96!;1022,0; 4Q11.5{ 69.24 93.36 21;>67.8í 649.33:: 2432.03E. 2.28 -1Q74.5' 5526!j4.4~ 5969014·3! 4087.4 . 66.47 91.60 2596.4( 652.38:: 2502.20E 4.24 -1090.0é 552734.6: 5969011.8' 4179.8{ q4.$5. 91.81 2634.4( 6Q4.89E.. 2586.42E. 1.1;)6 -11Q7.6L 5521}18.8' 596$009.8' 4272·2~ 63.82 91.03 ;21;)74.4{ 656.$$;' 2669.75E: 1.44 -1. 124.6( 552902. 1 ~ $96$Q98.3f 4365.8£ 63.85- 90.92 2715.7( 658.38:: 2753.71E 0.11 -1141.0~ 552986X 5969007.4! 4458.51. 1;)3.7C 91.Q4 27$6,\31 659.80:: 2836.88E. 0.20 -1157.3:' $53069,3l $969006,6: 4551.5: 63.79 91.54 2797,8C é;>61.68~ 2$20·2R 0.49 -1174.1~ 553152.&> 5!i!69QC5,;3 4644.1L 63.72 90.51 2838.7~ 663.17:: 3003.27E 1.00 -1190.4€- 553235.6! 5969004.31- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 89.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6664.66 Feet on azimuth 33.28 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJPnmips ConocoPhillips Alas c.,Slot #101 Pad 1B, Kuparuk River Unit,North Slope, Alaska SURVEY Page 3 Wellbore: 101 Wellpath: MWD w/lFR<1154-12230'> Date Printed: 11-Nov-2003 4736,0( 48~$.0¡: 4922.Oì 50152(' 5108.Oì 5200.5~ 529~.5( 5386.8~ 5479.6~ 5572.6i 5665.7( 5758.2~ 5852'4~ 5944.~i 6037.1t 61;30.1' 62~3,2, 6316.1i 6401P~ 61;>01.7~ 6594.3~ 6Q87.4( 67a0.5~ 6846.6(' t;;1;ì73·1~ 6965.6( 7059.1t 7151.7~ 7244.t;;Ç 7337.2< 7415.~~ 7510.6' 7608.7(- ((05.9~ 7aQ;3.2Ç 7852.4~ 7898.7Ç 7950.7~ 7995.9t 805Q.t;;~ 8110.3::' 8157.4Ç 8188.Q~ 8285·5< 8382.6t 8478·0~ 857t;;.3( 8673.3~ 8769.n 8896.5;: 8962.3- Q5.36; 6$,26. 65.33 Q5.18. Q5.13 65.20 65.1 e. 65.~q 65.36 65.~Q 65.29 65.23 66.83 67.86 68.93 61;ì.71 69.77' 72.38 73.Q1 ('4.14 74.86 74.67 74W 75.52 75.66. 75.89 80.64 84.61 86.83 86.74 87Aç, 87.4!;) 90.06 91.81 92.86. 91.63. 92.8;3 !;11.01 90.9& 99·52 90·77 9025 90.00 90·0Ei 88.59 89.6ç aM& 88.53 8$.60 89,85 89.08 90.53 91.37 90.29 8$.1;ì7 !¡J1.21 90.17 84.9$ 79.79 74.68 6$.89 65.2Q. 63.02 59.47 53.8$ 46.66 42.45- 38,65 36.02- 31.38 25.66 18.00 10.49 ~·28. 2.67 2.52 1.63' 358.9f ~55.8~ ~51,9E 347.2~ 351.4:2 ~4$.61;. 348.8C 350.1C 349.4~ 349.0C 349,22 350.1C 350.5£' 350.3( 350.7S; 350.1£ 349.g' 349.3t 349.0S 347.1' 351.8€ 353.8~ 354.51;. 3Q1.9~ 349.4:;' 2878.2< ;?917.1~ 2955.9~ 2!)94.9; ;3033.$Ç 3072Æ ~111.8~ ;3150.9t 3189.6~ 3228.5' . 3267.4::' 3306.11: 3~44.3< 3379.8< 3414.0t 3447.¡;It 3480.Qi 3510.8' 3538,3i 3564.6i 3589.4i 3Q13·9< 3638.3( 3655.1i 3661.8( 3684.5::' 3703.5< 3711;>.4~ 3722.3( 3727.5t 3731.þ' 3739.7'- 3737.8i ~73Q.?~ 3732.3~ 3730.3Ç 372M~ 37~¡;I.§~ 3726.0£ 3721;>.3~ 3724.6( 3724.21 3724.1!ó 3724.1< 3725.2( 3726.7< 3728.11 3730.5::' 3732.0~ 3732.5f 3733.4f 663,!)2~ 66!;i.321: 666.551: 6Qq.66~ QE17A6~ 668.471: 684.91E' 653.61;ìE 635.06E- 60!:¡.36~ 577.07'5; 540.381: 499.07¡;' 452.38E. 397.281: 335.541: 269.38~ 199.49~ 125.95E. 47.65~ 35.18!\, 122.0!:¡1\ 211261\ 275.061\ 300.791\ 390.361\ 481.861\ 57;3.51;>1\ 665,701\ 756.561\ 833.241\ 927.071\ 1023.431' 1118.971' 1214.701' 1262.941' 130M3f\ 1;359.5¡;1f\ 1404.071' 1458.051' 1Q16·88f\ 1563.391' 15Ø4.~5f\ 1689.4Qf\ 1784.791' 1878·121' 1974.Q8f\ 2070.991' 2166,2.61' 2262.981' 2357.451' 308E1.20E 3170.75[ 3255.23E ;3~~$.81~ 3424.07E: 3508.02E 3592.31E 3676.29E 3758.51 E' 3838·97( 3!:¡17.10E, 3992.68E, 4067.94E, 4138. 93[ 4205.20E 44'66.00E 4322.5!)E, 4375.89E 44;24.92E 4467.45E 4500.62E 4522.69E. 45~3.4QE 4536.77E 4537.93E. 4Q41.18[ 4541.62E 4537.42[ 4527.1;>6[ 4510.87f> 449M2E 4480.80E 4462.49£ 4444.69E 4427.43E 4418.25E 4409.50E 4400.18E 4392.60E 4383.$5E: 4373.78[ 4365.99E 4360.56E. 4343.20E 4325.07E 4305.40E 4287.4gE. 4275.44E 4265.'(6E 4254.~1E: 4238.83E 1.79 -1206.Qt 0.83 -1;?22.5£ 1.06 -1238.9~ 0.44 -1254.1~ 1.31 -1270.0; 1.02 -1286.1( 5.06 -1;:'97.7( 5.06 -1301.7( 5.00 -1298.1C 4.6e -1287.2~ 4.58 -1269.4( 2.14 -1246.9' 3.85 -1219.n 5.70 -1186.5~ 7.34 -1144.2( 4.73 -1094.3< 3.98 -1039.3t 3.88 -980.1é, 4.83 -916.61 6.03 -847,;2C, 8.0a -771.6E 7.79 -69Q.11 7Aa -604.:;1' 1.22 -542.1 ~ 0.7& -517·0~ 0.97 -429.4E 5.8C -339.5~ 5.44 -248.5!;. 4.7ÇJ. -156.1( 5.1C -63.7E 5.4~ 14.2£ 1.83 10g.3E 2.81 207.4< 2.24 304.Qf 1,27 401.9(. 2.67 451.0C 2.Q4 497,3~ 3.8~ 549.2Ç; 1.09 594.4< Q.94 649.17 0.83; 708.8e. 1.68 755.9£ 1.19 787.3E 0.!?4- 884·0C 1.54. 981.1C 2.36 1076.4< 4,96 1174.6f 2.03 1271.51 1.33 1367.0~ ;2.61;\- 1464.2~ 2.75 1559.9< 553318.Q; 553403, 1 ~ 553487.6<' 553$72.;2' 1;>53656.4t 553740.4: 5538414.6: 553908.5', 553990.6f 5!;i4070.9~ 554148.8~ 554224.1~ 5$4299.1 ~ 554369.8( 554435.7( !;i54496.Qt 5!,¡45!'¡;?2í 554605.0' 554653,5t 554695.1;>t 554728.1! :;;54749.6: 1;>p47:;;9.1;ì< 554762.7: 554 554 554766.2f 1;>Q4761·3t 5Q4750.9( 554733.6' $(54718.6" 554702.4( 554683.41 5(54665.0' 554847.1' 554637.6' 1;>t 8! 554611.0: 5Q4601.6C 1;>54§g1.4' 554583.3' 554577.7' 1;>54$59.7' 554540.91 1;>Q41;>20. Qt $1;>4502, l' 554489.4 ' Ot O( 554450.81- All data is in Feet un!ess otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.00 above mean sea leve! ) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6664.66 Feet on azimuth 33.28 degrees 1Tom Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 1;>969004.1 t 59690P3,3' 5969002.6! 59Q9003.1 ~ 5g69Q02,9( 5969002.4! 5~69006'51- 5969018.3! 5969037.5< 5!;J69Q63.71 59Q9096.5} 5969133.7' 5969175.5~ 5969222.7' 5969278Z 5969340.4: 5969406.9t 5969477.1! 5969551.0! .Q: .6! 1;>969799,7' 9, 7l 5970251.2' 597034:;1,2! 5970434.0: 5íi170510.6( 5970604.3' 5970700.5-< ,9! .5f 5970939.7: 5971080.6f 5971134.51 !'¡971193·3: 5971239.7f 5971270.7( 5971365.6: 5971460.8t 0'. 1;>971 ,5' 5971746.7: 5971&41.9: !;i~7W38.5-< 5972032.9( Conoc;Phillips ConocoPhillips Alask .,Slot #101 Pad 1 S, Kuparuk River Unit,North Slope, Alaska SURVEY Page 4 Wellbore: 101 Wellpath: MWD w/lFR<1754-12230'> Date Printed: 11-Nov-2003 9060.3' 90.77 34$.6r 373;:1.5~ 245q.821' 4221.06E 1.74 1657.9· 5544q2.4: 59721~$,1' $156.9( 90.77 349.1$£. ~732.2~ 254M2 I' 4203,67E. 0.01;! 1754.1$;' 554414.4! 5972224.0' 9254.2~ 90.67 349.4e 3731.0€ 2644.51 I' 4185.98E 0.17 1851.8~ 554396.1: 5972319.5' $$51.4t 90.89 348.7ç 'J7~$.7':.. 2740.011' 41e7.60E. 0.76 1949.0~ 554377.1( 5972414.$: $447.7i 91.14 349.01 372$·0':.. 2ß;J4,461' 4149.Q3E. 0,37 2945.3< 564357.9t 597~50$·:r 9544.4' 91.53 348.6¿ 3725.7~ 2929.261' 4130.30E 0.56 2141.9< 554338.5! 5972603.9' 9641.3~ $Q.QQ 348]1; 3724.0/ 3024.331' 4111.31E 1.02 2231;!,ß~ 1$54318.9' 59n.e96,8! 9736.3~ 9Q.8e. 347.7£. 3722.8~ 3117.291' 4092.01E. 1.07 2333.8( 1$54299.0t 5972791.6: 9833.9~ 90.12 346.97 3722.0' 3212.581' 4070.68E 1.13 2431.3E 554277.0~ 5972886.8( 9$30.9ï 91.13 q46.6:ë 3720.9~ 3307.001' 4048.53E. 1.10 2528.2~ 554254.2( 59729$1.0( 10028.4~ 91·08. 348.6t 3719.0i 3402.21 f'- 4027.65E 2.08 2625·6< 5542~2.7' 5973076·1: 10124.5( 92.11 348.11 3716.4( 3496.291' 4008.30E 1.21 2721.6E 554212.7~ 5973170.0( 10221.2( 91.35 34$.91 3713.4t 3591.201' 3989.87E. 2.02 2818.3< 5!;i4193.7t 5973264.8: 1()317.8t 90.40 34M7 3712.0( 3686·061' 3971.85E. 1.70 2914.8~ 554175.0' 5973359.5( 10414.5( 89.54 349.1E 3712.0f 3780.881' 3953.18E 1.08' 3011.5~ 554155,7! 5973454.2' 10511.3t $0,1~ 34(l1E 3712.q~ 3876.041' 3$34.96E. 0.93 q10e.4( f.i54136.8t 5973549.2: 10609.1', 90.03 3$0,51 3712.H 3972.281' 3$17.71E. 1.39 3206.1~ !;i54118.9t 597~649.3\ 10705.2' 89.63 350.5: 3712.4f 4067.011' 3901.91E 0.42 3302.2' 554102.5( 5973740.0( 1Q801.3: 88.62 351.4: 3713.9¡ 41ß1.91;!1' 3?89.61;\~ 1.41 3398.3':.. 554086.8t 5$73834.8! 108!;J7.41 88.43, 35q1 3719.3( 4256.971' 3872.47E. 0.25 3494.3i 554Q71.8~ 5!;J7~929.7: 10995.8' 90.12 351.2: 3717.6~ 4354.151' 3857.56E. 1.72 3592.6! 554056.2\ 5974026.8( 11091.01 91.17 351.17 371!),5f.. 4448.301' 3843.QOE. 1.11 3687.8( 554Q41.1' 5$74120.e~ 11188.8t 90.25 351.~1C 3715.3{ 4545.\)1 I' 3828,52E 1.14 378!;i.6~ 5$4025.$t 5$74217.4' 11284.91 90.55 352.8:':- 3714.6~ 4640.241' 3815.67E 1.12 3881.6' 554012.5( 5974312.5t 11379.5( 91.1;>$ 351.42 3712.8~ 473;HJOI\ 3802.72E 1.!;J1 3976.0i 553998,9~ 5974406.1, - 11477.6t 90.8t;:. 351.01 371Q.6f 4830.771\ 3787.79E. 0.9!') 4074.0( 553983.3~ 5974502.9( 11574.6( 90.21 350.67 3709.7¿ 4926.59f\. 3772.31E 0.76 4171.1( 553967.2: 5974598.6' 11670.7t 89.79 35Q.€1~ 3709.7¿ 5021.441' 3756.69E. 0.44 4267.~~ 55~9$0.9t 5974693.3' 11767.9~ 8$.7s. :}49.9:ë 3710.1~ Çi117.201\ 374Q.28E 0.73 4364.3€ 553933.!¡¡~ $$74788.9' 11864.3! 88.74 349.4: 3711.4( 5212.041\ 3723.02E 1.16 4460.7€ 553916.0: 5974883.6t 11959.9: 87.12. 348.6E 3714.3f 53Q5.821' 3704.88E. 1,35 4556.2f 5!;i3897.2( 5974977.3<- 120s7.$t 8$,51 349.$' 3716,2~ 5382.451' 3690.09E 2.53 4934.3' 5!;i38I;!1.$l 597505Mf 12135.31 91.32 350.01: 3715.5~ 5478.291' 3672.83E 1.95 4731.7( 553864.0! 5975149$ 12176.4t $1.\3Ç. 350.1;)¿- 3714.4f $518.81~ 366Q.94E 1.55 4772,n 553856.~t $$791$0,() i~2;3Q,0( 91.1;)& 350.6~ S71~,9( 5571.581' ;3997.2ZI; O.O(} 4826.2; P93e47,8~ 597$242,7' All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6664.66 Feet on azimuth 33.28 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc~Phillips ConocoPhillips c.,Slot #101 Pad 18, Kuparuk River Unit, North Slope, Alaska SURVEY U G Page 5 Well bore: 101 Wellpath: MWD w/IFR<1754-12230'> Date Printed: 11-Nov-2003 INTEQ MDfftl 563.3f 166~.6~ 12230.0C TVDfftl Northrftl 562.9" 1565.2: 3712.9C Eas~ftl 6.41$ 175,51E 5571,1:i61\ Çomment 11.73E MWD Survey 380.23E Tie-if! tQ 1B-101 PE;ì1 3657.22EProjecteq D¡;¡,ta - NO $URVEY Start MDfftl 13 ilL- 131/;;; Ii! 7(8 6 3/4 O.Oç 1820.0C 3090.0t 7395,Ot 1!?Q2.55E. 101PB1 1602.55E 101 44~f).6QE. 101 3!?q7.22"- 101 16" CQnductor 103/4" Casinq 7 5/8" Ca¡;;\no 41(2" $lotteÇ\ L\n~ 0.0<: 0.00 O,QO 688;2.0C Q.OO O.OC O,OQ 3663,9f Q,OOf\, 0.001\, Q.QQt\, 30$.311\ Q.OQE O.OOE ÇJ.OOf:, 4ß38,30E 148.0C 3080.0t 738M( 1223Q.ÇJC 148,OÇ 2199.5f 373Q,2f 371;2.9( O.OON 487.11E. 807.221\. 5ß71.58f\ ÇJ,QQE 101PB1 1593.72E 101 450Q.67E 101 3ç1:i7,22E 101 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6664.66 Feet on azimuth 33.28 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocciPnmips ConocoPhi!lips Alas c., Slot #101 Pad 1 B, Kuparuk River Unit, North Slope, Alaska SURVEY Page 1 Well bore: 101PB1 Wellpath: GSS<O-112'>MWD<S31-3090'> Date Printed: 11-Nov-2003 INTEQ Name 101PB1 I Created 17 -Auq-2003 I La$t R~vi$ed 14-0ct-2003 Name 101 I Goyemmel1t ID I Last ReYi¡;ed 22-Jl\I-2Q03 Name Slot #101 I Grid Northinq 5~Q9647.3610 I Grid Eastinq 55022~.3510 I Latitude N70 19 4Q.2457 I Lonqitude W149 3~ 33.5484 I North 501.00S lEast 21Q.00W Name Pad 1B I E~$t¡no I Northìno I CWrd $vstem Name 11'10(111 A!ia,nment 550434.958 5970149.712 AK-4 on NORTH AMERICAN DATUM 1927 datum True Name .K1,JQaruk River Unit I Northina 487754.621 I Coord $vstem N~me If\!9r1t1 Aljanment ¡¡94~985.821 AK-4 On NQRTH AMERICAN DATl,iM 1$27 dç¡tu['(1 Trl,le All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 105.00 degrees Bottom hole distance is 1677.99 Feet on azimuth 106.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJ'"Phillips ConocoPhillips Alask c.,Slot #101 Pad 1 B, Kuparuk River Unit, North Slope, Alaska SURVEY LI Page 2 Well bore: 101pB1 Well path: GSS<0-712'>MWD<837 -3090'> Date Printed: 11-Nov-2003 0.00 0.00 O.oc. O.OQ O.OON O.QOE O.QO O.OC 55022~.3t 591;>!;J647.31 148.0C 0.00 0.00 148.0Ç. o.OPN O.OOE o.PO o.oç. 550248.3t 5999647.31 168.0C 0.50 265.0C 168.0C 0.018 0.09V1i 2.50 -0.08 550228.21 5969647.3t 258.0(. 0.30 138.0C 258.0r 0.22$ 0.32V1i 0.80 -0.25- (550228.0~ 5!;J69647.1 ' ~4$.QC 1.00 117.0C 348.9~ 0,75$ 0,55E 0.$0 0.7<- 55022&.$( 596$646,6' 440.0C 2.35 112.0C. 439.91: 1.81S 2.98E 1.49 3.35 550231.3£ 5969645.5' 563.3~ 6.85 119.6e, 562.91 6.41$. 11.731;. 3.67 1;2.\}!¡, 550240.1í. 591;>;:1641.0: 621.0C 10.0C. 108.0C 619.9(. 9.658 19.47E. Q.19 21.3' 550247.8t 59696~7.8' 712.0C 11.00 121.0C 709.3£ 16.57f:' 34.43E 2.82 37.5E' 550262.8! 5969631.0: 8~7 .57 13.1Z 131.4£ 832.1£ 32.18f:'. 55.38E. 2.4Z 61.84; 550283.9' 5969615.5! 925.27 15.31 127.51 917.2C 45.83:;' 72.02E. 2.73 81.4::' 550300.6', 599;:1602.0; 1016.1( 15.45 126.7E. 1004.8¿ 60.385 91.24E 0.27 103.71'. 550319.9! 5969587.6( 1107.8( 18.46 126.4f;. 1 0!;J2.4~ 76.31:;' 112.69E. 3.2!:f 128.6C (5(50341.5' 5969571.8' 1201.3~ 23.44 11$.71:. 1179·8i !;J4.38~ 140.7!;JE. 5.89- 1¡;¡0.4¡ (550369.7~ 59695ß3·9' 1294.2ï 26.13 113.4:: 1264.2' 111.69f:' 175.60E 4.07 198.5:: 550404.61 5969536.8! 1387.4( 3Q.3~ 108.71'. 1346.2f. 127A1~ 219.72E (5·09 242.3:; 55Q445,9( 5969541.4' 148j2,0¿ 35,74 109,11 1425,(5i 142.78~ 2Qþ,93E 5.;:12 293,$:; 550495.2l 59f;ì9506.31 1572.0i 40.47 106.41: 1496.3! 158.375 319.24E 5.26 349.31: 550548.6' 5969491.1 ! 1665.6£ 44,7a 104,97 1595.2~ 175.515 3&0.23E 4.7:1 412.7C. 550609.7' 5999474.4; 1759.1~ 50.1!5 103.91'.. 1f;ì2e,4( 192.685 446.91 E 5.81 481.51;. 55067Ml 5;:1f;ì;:1457.71 1852.2~ 56.45 103.7" 1684.0~ 210.525 519.38E 6.76 556.1ì 550749.0' 5969440.3- 1;143.9C 62.40 1P4.0C 1730.6' ~2!1.41 ;. 595.;:15E 6.50 f;ì35.0;;' 55082;;;,7~ 5969421.9' 20;36.7¿ 67.0::- 103.2:: 1770.21' 249.205 677.51E 5.Q3 718.9" 550907.4, 5969402.7: 2128.7( 64.06 105.2!:: 1808.3¿ 269.855 758.64E. 3.79 802.6<1 550988.7' 5969382.6: 2221.7( 65.24 104.11;; 1848.1f. 291.215 839·931; 1.6& &86.6é ;ï51070.1: 5969361.1;1' 2314.&~ 65·03 104.n 1887.3( 312.29~ 921.71E 0.62 971.1:;' 551152.Q' 5969341.21 2407.3' 67.35 104.32' 1924.6L 333.53f:' 1003.62E 2.54- 1055.7¿ 551234.0f 5969320.5f 2500.5' 66.03 102.82; 1961.5~ 353.625 1086.81E. 2.05 1141.3( 5q1317.4( .01 2593.9~ 64.4Z 104.12 2000.6~ 373.39f:'. 116;:1.341:., 2.14 122Q.1~ 551400.0! .8' 2685.7i 66.61 105.27 2038.7( 394.605 1250.13E 2.64 1309.61' 551480.9: 5969261.11 2779.Q' 67.08 102,2¿ 2.Q75.4( 414.975 1333.39E. 3,03 139Q.3{ 551564,3! 5!iJ~9241 ,3; 2&72,Qf ç4.9!} 1Q3.4(:. 211.3.4( 433.98:3 1416.7$E. 2.53 1480.7~ 551647.8: ;ï$ç9~"2.9~ 2965.2' 64.45 1 03.4:: 2152.91' 453.45:3 1498.21E 0.58 1564.5~ 551729.4; 5969204.0l 3Q35.6¿ 64.75 1Q4.2~ 2183.1ï 4ç6,6():3 1999,99f.. 1,1~ 16¢8.1 ( 551('91.2t 596f1189.2' 3090.0C 64.75 1 04 .2~ 2206.3E 480.74:3 1607.651: 0.00' 1677.2~ 551~39.0; $96$177.4! All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 105.00 degrees Bottom hole distance is 1677.99 Feet on azimuth 106.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocÓÁ1i11ips ConocoPhillips .,Slot #101 SURVEY L Page 3 Wellbore: 101PB1 Well path: GSS<O- 712'>MWD<837 -3090'> Date Printed: 11-Nov-2003 Pad 1 B, Kuparl.lk River Unit, North Slope, Alaska MDrm ~TVDrft1 I N9rthrftl 563.3 562.9 6.41 3090.0 2206.3~ 4eO.74 16" Conductor 103/4" CasinQ 7 5/8" CasinQ 0.00 0.00 0.00 Q.OO 0·00 0.00 Q.OON Q.OQN O.OON. O.QQí=. Q.OOr;: O.OOE 148.Q( :?080.0( 7389.0C 148.0C. 219!;!.5~ 3730.2£ O·OON. 487.11 E. 807.221\ O.OQE 191PB1 1593.721:. 101 4500.67E 101 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 105.00 degrees Bottom hole distance is 1677.99 Feet on azimuth 106.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Transmittal Form INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 ) l Attention: Lisa Weepie Reference: IB-I01 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 523077 Sent By: Glen Horel Received By: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Re: 1 B-1 01, APD Correction. <-- ALL Attachments Have Been Removed . . Subject: Re: 1 B-1 01, APD Correction. <-- ALL Attachments Have Been Removed Date: Tue, 5 Aug 200317:09:14 -0800 From: "Steve McKeever" <Steve.McKeever@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Hello Tom- I've decreased the planned cement volumes for the 10-3/4" casing job on 1 B-1 01. Here are the calculations I used, as well as a corrected page 4 of the 1 B-1 01 Permit It document. Holler if you have any further questions. (See attached file: 1 B-1 01 Permit It Corrected Page 4.pdf) (See attached file: 1B-101 Cement Calcs v2.pdf) Steve McKeever Drilling Engineer ConocoPhillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager steve.mckeever@conocophillips.com "A good time to keep your mouth shut is when you're in deep water." -from The Cowboy's Guide to Life Tom Maunder <tom_maunder@admin.state.ak.us> 08/01/200307:22 AM To: Steve McKeever/PPCO@Phillips cc: Subject: Re: 1 B-1 01, APD Correction. Thanks Steve. Once I got further into the program, that is what it appeared to be to me. Neither Steve Davies or myself found anything else on location confusion with the exception of the lease designation for the 101 well. The lease designation block had 2 leases in it and when the BHL was corrected, one could be removed (25038). I will look forward to what you have on the cement. As you noted as we looked at the 1 of 2 8/6/20037:15 AM Re: 1 B-1 01, APD Correction. <- ALL Attachments Have Been Removed Dowell sheet, the XS factors for th!rmafrost and below the permafrost . were the same. Have a good weekend. Tom Steve McKeever wrote: > Hi Tom, > > Thanks for catching the error in the TO location. I double checked it, and > yes, it was just a "cut & paste" error on my part. > > Attached is a corrected page 2 of the document. > > 1'1/ double check the cement early next week. > > Steve McKeever > > Drilling Engineer > ConocoPhillips Alaska, Inc. > 907.265.6826 office > 907.265.1535 fax > 907.275.0369 pager > steve.mckeever@conocophillips.com > > '~ good time to keep your mouth shut is when you're in deep water." > -from The Cowboy's Guide to Ufe > > (See attached file: 18-101 Permit It Corrected Page 2.pdf) > > ----------------------------------...------------------------------------- > Name: 18-101 Permit It Corrected Page 2.pdf > 18-101 Permit It Corrected Page 2.pdf Type: Acrobat (appl ication/pdt) > Encoding: base64 ~. Name: 18-101 Permit It Corrected Page 4.pdf 018-101 Permit It Corrected Paqe 4. Ddfj Type: Acrobat (apPlication/Pdt). ... . Encoding: base64 . 018-101 Cement Cales Name: 18-101 Cement Cales Type: Acrobat (application/pdt) base64 2of2 8/6/20037:15 AM . rñì Þ ~\- J1 j l1ù -=0 . ~ \..::::.I !® Lr\J FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Re: Kuparuk River Field 1B-101 ConocoPhillips Alaska, Inc. Permit No: 203-133 Surface Location: 501' FNL, 211' FEL, SEC. 9, T11N, RlOE, UM Bottomhole Location: 235' FNL, 1833' FEL, SEC. 3, TllN, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom 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 Alask,~ Administrative Code, or a Commission order, or the terms and conditions of this perm¡¡d'J~Y result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, i~ BY ORDER OF THE COMMISSION DATED this...£. day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end Exploration, Production and Refineries Section Conoc~hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com July 24,2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1B-101 & 1B-101 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "B" and "D" sands. The main bore of the well will be designated 1B-101, and the lateral bore of the well will be designated 1B-101L1 Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1B-101 is August 7,2003. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Sincerely, \~~~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work: Dríl[!l Re-entry[] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrilU 1b. Current Well Class: Stratigraphic Test 0 ExpioratorU ServicO 5. Bond: U Blanket U 59-52-180 Development cI..:!J Multiple ZU Development GO Single Z0 Single Wel 11. Well Name and Number: 1 B-101 12. Field/Pool(s); Kuparuk River Field 6. Proposed Depth: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): 7. Property Designation: ALK 25648 ~¿5þ 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 8/7/2003 Top of Productive Horizon: 9. Acres in Property: 14. Distance to Nearest Property: 235' @ TD 4b. Location of Well (State Base Plane Coordinates): Surface: x- 16. Deviated wells: 10. KB Elevation 15. Distance to Nearest (HeightaboveGL): 88' AMSL feet 17. Anticipated Pressure (see 20 MC 25.035) Well within Pool: 10-103 @ 1030' /' Kickoff depth: fL Maximum Hole Angle: 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 19 Total Depth MD (ft): 5580' PRESENT WEll CONDITION SUMMARY I Total Depth TVD (ft): Plugs (measured) No cement (To be completed for Redrill and Re-Entry Operations) .. " Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Cement Volume MD TVD Liner Perforation Depth MD (ft): 20. Attachments: Fílíng Fee 0 Property Plat 0 BOP Sket<[] Diverter SketeD Time v. Depth 0 Drilling Fluid progr(!] Date: Shallow Hazard Analo 20 MC 25.050 requirem@ Drilling progrf!] Seabed Rep[] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Kuparuk Drilling Team Leader Signature Permit to Drill Number: I API Number: 50- Samples required Hydrogen sulfide measures Commission Use Only I Permit Approval Date: jsee cover letter MY :or other requirements Conditions of approval: Mud log required Directional survey required Other: ~~~ Approved by: Form 10-401 BY ORDER OF THE COMMISSION · .cation for Permit to Drill, Well 1 B·1 01 Revision No.O Saved: 23-Jul-03 Permit It - West Sak Well #1 B-101 Application for Permit to Drill Document Mo)ximizE Well Vglu~ Table of Contents 1. Well N·ame............. ................ ........ ........ .......... .......... ............................ ............ ... ..... 2 Requirements of 20 AAC 25.005 (f)................... ............ ....................... ......................... ....... ..................2 2. Location Sum mary ........ ........ ...... .......... ........ ............ ............................ ........... ..... ... 2 Requirements of 20 AAC 25.005(c)(2) ..................................................... ..................... .........................2 Requirements of 20 AAC 25. 050(b)........................... ............... ... ......... ...... ................................. ........... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ........ ............................................................. ............. ........ ..... .... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ................. .......... .......... ................ ...................... .............. ,........ 3 6. Casing and Cementing ..Program........................................................................... 4 Requirements of 20 AAC 25.005(c)(6) ... ................. ....... ....... ................................................................. 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ........... ........................... ..... ...... ................ ................ ....... ........... 4 8. Dri II i ng FI uid Program ............. ......... .................. ............. ............. .................. ......... 5 Requirements of 20 AAC 25.005(c)(B) ..... ............ ............ ................ .......... ........ .................. .......... ........ 5 Surface Hole Mud Program.............. ...................... ....................................................... ..... .................... 5 Lateral Mud Program ....... ......................................................................................................... ... ........... 5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ....................... ................. ................... ............... ........................ 6 10. Seismic Analysis........... .... .................. .......... ............ ............................. .......... ........ 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ......................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 & ~ 18-101 PERMIT IT.doc Page 10'8 Printed: 23·Jul-03 · .ation for Permit to Drill, Well 1 B-1 01 Revision No.O Saved: 23-Jul-03 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ................................................................................... . 7 Requirements of 20 AAC 25.005 (c)(13) ......................................................................................... ..... 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal............ ......... 8 Requirements of 20 AAC 25.005 (c)(14) ............................................................................... ...............8 15. Attachments ........... .... ....................... ..... ........ ........... ... ........ ...... ......~.. ... .... ..... ........ 8 Attachment 1 Directional Plan..... ............................ ...................................... .............. .................... ..... 8 Attachment 2 Diagrams of the BOP / Diverler System........................... Error! Boo. ark not defined. Attachment 3 Drilling Hazards Summary..... ....................... ....... ............................. ,............ ............ ..... 8 Attachment 4 Cement Loads and CemCADE Summary..................................... ...~............................. 8 Attachment 5 Well Schematic.. ........... .................................... .......................... ..... .l.......... ...... ............. 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operata and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche~ each br. nch must similarfy be identified by a unique name and API number by adding a suffix to the name designated for the well by the 'Perator and to the number asSigned to the well by the commission. The well for which this Application is submitted will 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompani r each of the following Item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's wners and showing (A)the coordinates of the proposed location of the ell at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of Je well at the sUlfac~ referenced to the state plane coordinate system for this state as maintained by the National Geodetic lIrvey in the National Oceanic and Atmospheric AdminiStration; (C) the proposed depth of the well at the to' of each objective formation and at total depth; Location at Surface NGS Coordinates / Northings: 5,969,647 Eastin SOl' FNL, 211' FEL, Section 9, T11N, R1PE, UM ' / I RKB Elevation I 88.4' AMSL 550,229 Pad Elevation! 60.4' AMSL Location at Top of Productive Interval (West Sak "8" Sand NGS Coordinates Northings: 5,970,0 8 Eastings: 554,771 83' FNL, 945' FEL, Section 10, T11N, Rl0E, UM ./ Location at otal Depth NGS Coordin 'eS Northin : 5,975,218 Eastings: 553,837 Measured Depth, RKB: 7,003 Total Vertical Depth, RKB: 3,692 Total Vertical Depth, 55: 3,603 '3 'TII Â ,/.Sf) 235' FNL, 1833' FEL, Section , Rl0E, UM ,,/' Measu/1 Depth, RKB: 12,210 Total Vertical Depth, RKB: 3,722 Total Vertical Depth, 55: 3,633 / / 18-101 PERMIT IT.doc Page 2 of 8 Printed: 23-Jul-03 . . Application for Permit to Drill, We1l1B-101 Revision No.O Saved: 31-Jul-03 Requirements of 20 AAC 25.005 (c)(12)............................. .................................................................... 6 13. Proposed Drilling Program ................................................... ...................................7 Requirements of 20 AAC 25.005 (c)(13)................................................................................................. 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14).................................................................................................8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan............................................................................................... ..... ............8 Attachment 2 Diagrams of the BOP / Diverter System.......................... Error! Bookmark not defined. Attachment 3 Drilling Hazards Summary...... .......................................................................................... 8 Attachment 4 Cement Loads and CemCADE Summary .......................................................................8 Attachment 5 Well Schematic ...... ................. ................. ................... ........................... ................. ......... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must simiÏarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 16-10l. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,969,647 Eastings: 550,229 SOl' FNL, 211' FEL, Section 9, T11N, Rl0E, UM I RKB Elevation I 8804' AMSL Pad Elevation 6004' AMSL Location at Top of Productive Interval (West Sak "8" Sand) NGS Coordinates Northings: 5,970,098 83' FNL, 945' FEL, Section 10, T11N, Rl0E, UM Eastings: 554,771 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7,003 3,692 3,603 Location at Total Depth NGS Coordinates Northings: 5,975,218 Eastings: 553,837 235' FNL, 1833' FEL, Section 3, T11N, Rl0E, UM Measured Depth, RKB: 12,210 Total Vertical Depth, RKB: 3,722 Total Vertical Depth, 55: 3,633 18-101 PERMIT IT.doc Page 2 of 8 Printed: 31-Jul-03 · aation for Permit to Drill, Well 1 B-1 01 Revision No.O Saved: 23-Jul-03 and (D) other information required by 20 MC 25.050(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatfft the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a sUItable scale, showing the path of the proposed wellbore, Including all adjacent wellbores within 200 feet of any portion of the PIVPOSed wel¿" Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mail/ or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to On/I must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 MC 25.03(i or 20 MC 25.03~ as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete weIl1B-101.. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pemlit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (4) information on milling hazard~ including (A) the maximum downhole pressure that may be encountere4 cnteria used to determine if:., and maximum potential surface pressure based on a methane gradienf:.," The expected reservoir pressures in the West Sak sands in the 1B-101 area vary from 0.50 to 0.52 psi/ft, or 9.6 to 9.8 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. 4--- The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1513 psi, calculated thusly: MPSP =(3691 ft)(0.52 - 0.11 psi/ft) =1513 psi / (8) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data conceming potential causes of hole problems such as abnormally geo-preS6"Ured strata, lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mllst be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tes~ as required under 20 MC 25.030(f); 18-101 PERMIT IT. doc Page 3 of 8 Printed: 23-Jul-03 · .cation for Permit to Drill, We1l1B-101 " Revision No.O Saved: 23-Jul-03 IB-I01 will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on tile commission and ¡dentitied In the application: (6) a complete proposed casing and cementing program as required by 2.. O~2S.03~ and a description of any slott perforated liner, or screen to be Installed; C'\ ." S ~Q' c..eèJc:r Casing and Cementing Program I c¿;-:( ç See also Attachment 3: Cement Summary - Hole Top Size Weight Length MDfTVO (in) (Iblft) Grade Connection (ft) (ft) 24 62.5 H-40 Welded 110 28 / 28 CsglTbg 00 (in) 16 Cement Program Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 730 sx AS Lite Lead, 680 sx Class G Tail Cement Top planned @ 4500' MD / 2800' lVD. Cemented w/ 663 sx Class G Slotted- no cement 10-3/4 13-1/2 45.5 L-80 BTC 872 900 /895 10-3/4 13-1/2 40 J-55 BTC 2182 3082 / 2200 7-5/8 9-7/8 29.7 L-80 BTCM 28 / 28 7103 / 3700 6-3/4" Lower Lateral (lB-I0l) 6-3/4" Upper Lateral (lB-I0l Ll) 7. Diverter Syste Information Requirements of 0 AAC 25.005(c)(7) An application for Permit to Drill must be accompanied by each of the following Items; except for an item already on tile with the commission an 'dentitied in the application: (7) a diagra nd description of the dlverter system as required by 20 MC 25.03~ unless this requirement is waived by the commissio under 20 MC 25.035(h)(2); 4-1/2 slotted / 4-1/2 slotted 12.6 L-80 6630/ 3630 5580 12210/3722 12.6 NSCT 6603/ 3625 12197 / 3663 Slotted- no cement 5594 A -1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the IlIing of IB-I01. Please see diagrams of the Doyon 141 diverter system on file with the Commission. ORf 18-101 PERMIT IT. doc Page 4 of 8 Printed: 23-Jul-03 Application for Permit to Drill, Well 1 B-1 01 Revision No.O Saved: 5-Aug-03 18-101 will be completed with 7-5/8" surface casing landed in the West Sak 8-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top 8tm CsglTbg Size Weight Length MDITVD MDITVD OD (in) (in) (/blft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 110 28 / 28 148/148 Cemented to surface with 260 cf ArcticCRETE 10-3/4 13-1/2 45.5 L-80 8TC 872 28 / 28 900 /895 Cemented to Surface with 10-3/4 13-1/2 40 J-55 8TC 2182 900 /895 3082 / 2200 605 sx ASLite Leadl 290 sx Class G Tail 7-5/8 9-7/8 29.7 L-80 8TCM 7075 28 / 28 7103/3700 Cement Top planned @ 45001 MD / 2800' TVD. Cemented w/ 663 sx Class G 4-1/2 6-3/4" 12.6 L-80 NSCT 5580 6630/ 3630 12210/ 3722 Slotted- no slotted Lower cement Lateral (18-101) 4-1/2 6-3/4" 12.6 L-80 NSCT 5594 6603/ 3625 12197/3663 Slotted- no slotted Upper cement Lateral (18-101 Ll) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) be A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 16-101.. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 18-101 PERM/TlT.doc Page 4 of 8 Printed: 5-Aug-03 · .ation for Permit to Drill, Well 1 B-1 01 Revision No.O Saved: 23-Jul-03 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and descripffon of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.5 s9.4 Funnel Viscosity 150-200 150-200 (seconds) Yield Point 30-60 30-60 (cP) Plastic Viscostiy 8-15 11-22 (1b/100 sf) 10 second Gel 10-30 10-25 Strength (lb/100 sf) 10 minute Gel 25-55 25-55 Strength (lb/100 sf) pH 8-9.5 8-9.5 API Filtrate 8-15 <8 (cc /30 min)) Solids (% Vol) 5-8 5-8 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (extended bentonite) 10-3/4" Casing Shoe to 7-5/8" Casing Point Initial Value Final Value s9.2* 9.8 150 45-55 20-40 18-30 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (1b/1 00 sf) 10 second Gel Strength (lbl100 sf) 10 minute Gel Strength (lb/100 sf) pH API Filtrate (cc /30 min)) Solids (% Vol) 12-30 12-24 10-25 10-25 20-40 20-40 8-9.5 8-9.5 <6 <5.5 5-8 6-11 *9.6 ppg if hydrates are encountered Lateral Mud Program (MI FlowPro NT) BID sand laterals Initial Value Final Value 9.8 9.8 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Base of Permafrost to 10-3/4" Casing Point Initial Value Final Value s9.4* 9.6 150 65-75 20-40 18-30 12-30 12-24 10-25 10-25 20-40 20-40 8-9.5 8-9.5 <8 <6 5-8 6-10 18-101 PERMIT IT. doc Page 5 of 8 Printed: 23-Jul-03 Yield Point (eP) Plastic Viseostiy (/b1100 sf) Tau 0 Chlorides (mgll) pH API filtrate (ee I 30 min) **HTHP filtrate (ee 130 min) MBT (/b I gal) ***Solids (% Vol) ** HTHP to be run at 800 F . .ation for Permitto Drill, Well 18-101 . Revision No.O Saved: 23-Jul-03 BID sand laterals Initial Value Final Value 22-30 22-30 8-12 8-12 4-7 1 00-11 OK 8-9.5 <6 4-7 100-110K 8-9.5 <6 <10 <10 <5 <6 <5 <6 *** The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (e)(9) An application for a Perrmt to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commis..çion and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or refiection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (e)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, moblïe bottom-founded structure, jack-up riÇh or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (e)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (12) eVidence showing that the requirements of 20 MC 25.025 {Bonding}have been me~' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 18-101 PERMIT IT. doc Page 6 of 8 Printed: 23-Jul-03 · .ation for Permit to Drill, We1l1B-101 Revision No.O Saved: 23-Jul-03 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 148' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 3082' MD / 2200' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 40# J55 x 45.5# L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. - "c\.'ì~ AeløCc.. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular:tt--.~~ðo~5:~? preventer to 3500 psi) Notify AOGCC 24 hrs before test.,.:!o\} ~~tJi~ 6. PU 9-7/8" Bit and 6-1/4" drilling assembly, with MWD and L~. RIH, clean out cement to top of float ~ equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. {,\ \ 7. Drill out cement and between 20' and 50' of new hole. Perform FIT to 12.0 ppg EMW, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 7103 MD / 3700' TVD. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud and, pressure test casing to 3000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. L µ"Þ.- 11. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out rptf?- RES .,(HH..... cement to top of float equipment. Re-test casing if cement is ta9Qëd more than 100 feet above the float S"ðo' a...~~ collar 1/ U.ð"-~ +0 12. Drill out cement and between 20' and 50' of new hole. Perform FIT to 12.5 ppg EMW, recording results. --r':J;>. (ECD's modeled to be less than 11.8 ppg) "tÞ 13. Directionally drill 6-3/4" hole to TD at +/- 12,210' MD /3,722' TVD as per directional plan. 7.30-0'3 14. POOH, back reaming out of lateral. POOH. 15. PU and run 4-1/2" slotted liner. 16. Land liner, set liner hanger @ +/- 6630' MD /3,630'. POOH. Note: Remaining operations are covered under the lB-l0l Ll Application for Permit to Drill, and are provided here for information only. 17. Run and set Baker WindowMaster whipstock system, at window point of 6603' MD / 3625' TVD, just into the top of the D sand. 18. Mill window. POOH. 19. Pick up 6-3/4" drilling assembly with LWD and MWD. RIH. 20. Change over to clean FloPro NT drilling mud. 21. Drill to TD of D sand lateral at 12,197' MD / 3,663' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH 18-101 PERMIT IT.doc Page 70t8 Printed: 23-Jul-03 · eation for Permit to Drill, We1l1B-101 Revision No.O Saved: 23-Jul-03 24. PU and run 4-1/2" slotted Liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH, laying down drill pipe as required. 27. Make up tubing tail and completion equipment as required and RIH to depth. 28. Drop RHC plug and pump down to nipple below packer. Pressure tubing and set packer. Shear seal assembly from PBR, space out and land tubing in well head 29. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV. Test tubing to 3,500 psi for 10 minutes, recording results. Holding 1000 psi pressure on tubing, pressure test annulus to 3000 psi for 10 minutes, recording results. Continue to pressure annulus up and shear RP shear valve in top gas lift mandrel. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 30. Set BPV and move rig off. 31. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in top mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). 32. Pull RHC plug from nipple below packer. Open CMU sliding sleeve. Set Weatherford jet pump in CMU profile. Set sub-surface safety valve. Rig down wire line unit. 33. Initiate production and clean up well to tanks. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following item~ except for an item already on file witll the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids - into a permitted annulus on 1B Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1B Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillipsAløskadoes notiotend to request authorization for the use of this weU.for annular disposal - operations. 15. Attachments Attachment 1 Directional Plan (13 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (5 pages) 0, R' Ie ...'.i 18-101 PERMIT IT. doc Page 8 of 8 Printed: 23-Jul-03 Created by bmichael For: S McKeever Dote plotted: 16-Jul-2003 Plot Reference is 18-101 V5 B-LAT VERIO.E. Coordinates ore in feet reference slot #101. True Vertical Depths are reference Est. RKS"B9'. .--- ....... -- INTI!:() 400 400 800 Estim'd SURFACE LOCATION: 501' FNL. 211' FEL SEC. 9, T11 N, R1 DE . 1200 1600 . ConocoPhillips Alaska, Inc. Structure: Pod 1 B Well: 101 . ConocoPhillips Field : Kuporuk River Unit Locoiion: North Slope, East (feet) -> 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 00 ,f' "Lì\o~o \ 'f.O~6f\~0'f',f' "'/\00 cl'OS .¡ 'i?,,~{ò~\Ò 'ò e "e'I'<' -26' "oloc n'v" 'ò 'iÞ-c'<- A ,\OY '1-/ \ c;0'<' ''l.<; ,\0" ,,b. A.Z ::;\0 D-Lot TO LOCATION: 244' FNL, 1882' FEL SEC. 3. T11 N, R1 DE I B-Lot TD LOCATION: 235' FNL. 1833' FEL SEC. 3. T11 N. R10E It TO. 4 1/2 Liner PI. 7-5/8" CASING LOCATION: 17' FSL, 949' FEL SEC. 3, T11 N. R1 DE EGC. 7 5/8 CSG PT. Drop 3/100' ( End 10/100 Bid/Turn ~ Top B Sand Top C KOfo; Jhigs~~I~~dF~~~e Top West Sok D Base Whipstock Face 92.02 AZ To Top Ugnu Top Bid/?' p Ugnu e A gnu',!!n 5/700 6000 6400 - 6400 - 6000 - 5600 - 5200 - 4800 - 4400 - 4000 - 3600 A - 3200 I Z - 2800 0 , -+- :r ......... - 2400 ....., m m -+- '-" - 2000 - 1600 - 1200 - 800 - 400 o - 400 - 800 - 1200 300 - 600 - 900 - .---.. -+- OJ 1200 - OJ - '-" ..c 1500 c -+- 0.. OJ 0 1800 - 0 U -+- 2100 - L OJ > OJ 2400 - ::¡ L f- I 2700 - V 3000 - 3300 - 3600 " 3900 - Created by bmichael Døte plotted: 16-Ju!-2003 Plot Reference js 18-101 V5 8-LAT VER#O.E. Coordinates are in feet reference slot ff101. True Vertical Depths are reference Est. RKB=89'. lIIRiI -=- rNTEQ o - .. Est'd RKB Elevatian: 89' KOP . 2.00 . 4.00 6.00 8.00 Bid/Turn 3/100 12.79 15.84 Bid/Turn 4/100 19.58 Bid/Turn 5/100 24.37 29.32 34.28 Build 5/100 40.00 45.00 50.00 60.00 DlS: 2.00 deg per 100 It ConocoPhillips Alaska, Inc. ......./ ConocoPhillips Structure: Pad 1 B Well : 101 Field : Kuparuk River Unit location: North Slope, 82.05 AZIMUTH 4569' (TO 7 5/8" CSG PT) ***Plane of Proposal*** DlS: 5.00 deg per 100 It DlS: 5.00 deg per 100 It Base Permafrost EOC Top T-3 TANGENT ANGLE 65 DEG 300 o 300 600 900 1200 Top K-15 ~ 103/4 SURFACE Top Ugnu C Bid/Turn 5/100 64.6164.35 DlS: 5.00 deg per 100 It 64.92 TOPT~&n~g~U A 66.31 68.43 K13 71.20 76.34 Top West Sak D Tafa~ B Sand 7 5/8 CSG PT. 1500 1800 2100 2400 2700 3000 3300 3600 3900 Vertical Section (feet) -> Azimuth 82.05 with reference 0.00 N, 0.00 E from slot #101 4200 4500 4800 5100 5400 5700 6000 . e 6300 6600 Created by bmichael Date plotted: 17-Jul-2003 Plot Reference is 18-101 V5 8~LAT VER#O.E. Coordinates are in feet reference slot #101. Vertical Depths are .¡nce Est. -=-..:.s TNTEQ so¥- \) ~e"'c ,09 ~ ~oc~oc~~e ._," >oc¥- c¥- ê -<0(\ _ 3300 - W",' ,,'co ~\\\~êl ' ~'(\'I\'(\t(\ê 0 'i) _ ,o~o"~ /01\0/\00 '(-,0 ê \ " Ì7ôì\ '-(\ ,,(o<?~ OG 3600-~ v I:- ~'...''''1.*;w . ?,~,G' GSG "",-,-'- 1 'il~\) 'i)/ ?-,-'-O ,-OG. 4200 .r; ã. " c õ ~ " > " 2 I- 3900 - I V 900 600 300 o i ConocoPhillips Alaska, Inc. Structure : Pad 18 Well : 101 Field: Kuparuk River Unit Location: North Slope, Alaska ,,/\00 ,0(\ 'i)\ê{oG #--.. "I\O~O~ 1,0(\ 'i)\ê 300 600 900 ,,/ \00 1"\0(\ 'i)\êi¿OG ......... ** *' ,,/\0'toG /,0(\ 'i)0\\ê 1200 1500 1800 2100 2400 2700 3000 3300 Azimuth 349.68 with reference 0.00 N, 0.00 E from slot #101 Vertico I Section (feet) - > '¡¡../"" ConocóPhillips ß ~ .(\e( ']. '-\ t'< \ I ,\), 3600 3900 4200 4500 4800 . e 5100 5400 Page I of 4 B Lateral Grid Lat Long . . ConocoPhillips Alaska, Inc. Pad 1B 101 slot #101 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License 1B-101 V5 B-LAT VER#O.E prop5467 Date printed Date created Last revised 17-Jul-2003 9-Jun-2003 17-Jul-2003 Field is centred on n70 16 18.576,wlSO 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.246,w149 35 33.548 Slot Grid coordinates are N 5969647.361, E 550228.351 Slot local coordinates are 501.00 S 210.00 W --- Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North I J 41 . Page 2 of 4 B Lateral Grid Lat Long ConocoPhil1ips Alaska, Inc. PROP05AL LI5TING Page 1 Pad 1B.101 Your ref 1B-101 V5 B-LAT VERfO.E Kuparuk River Unit,North Slope, Alaska Last revised : 17 -Jul-2003 Measured Inclin Azimuth True Vert R E C TAN GULAR G RID COO R D 5 G E 0 GRAPH I C Depth Degrees Degrees Depth C 0 0 R DIN ATE 5 Easting Northing C 0 0 R DIN A T E 5 e· 0.00 0.00 180.00 0.00 O.OON O.OOE 550228.35 5969647.36 n70 19 40.25 w149 35 33.55 - 300.00 0.00 180.00 300.00 O.OON O.OOE 550228.35 5969647.36 n70 19 40.25 w149 35 33.55 400.00 2.00 125.00 399.98 1. 005 1. 43E 550229.79 5969646.37 n70 19 40.24 w149 35 33.51 500.00 4.00 125.00 499.84 4.005 5.72E 550234.09 5969643.40 n70 19 40.21 w149 35 33.38 600.00 6.00 125.00 599.45 9.005 12.86E 550241.27 5969638.45 n70 19 40.16 w149 35 33.17 700.00 8.00 125.00 698.70 15.995 22.84E 550251.29 5969631. 53 n70 19 40.09 w149 35 32.88 800.00 10.00 125.00 797.47 24.965 35.65E 550264.17 5969622.64 n70 19 40.00 w149 35 32.51 900.00 12.79 119.40 895.49 35.385 52 . 41E 550281. 00 5969612.34 n70 19 39.90 w149 35 32.02 977 .16 15.00 116.50 970.38 44.035 68.79E 550297.43 5969603.80 n70 19 39.81 w149 35 31. 54 1000.00 15.84 115.11 992.40 46.675 74.26E 550302.92 5969601.19 n70 19 39.79 w149 35 31.38 1100.00 19.58 110.42 1087.65 58.315 102.33E 550331. 06 5969589.75 n70 19 39.67 w149 35 30.56 1111 .18 20.00 110.00 1098.18 59.625 105.88E 550334.62 5969588.46 n70 19 39.66 w149 35 30.46 1200.00 24.37 107.95 1180.40 70.475 137.60E 550366.41 5969577 . 83 n70 19 39.55 w149 35 29.53 -1300.00 29.32 106.33 1269.59 83.725 180.76E 550409.65 5969564.87 n70 19 39.42 w149 35 28.27 1400.00 34.28 105.15 1354.56 97.975 231.47E 550460.45 5969550.96 n70 19 39.28 w149 35 26.79 1414.47 35.00 105.00 1366.46 100.115 239.41E 550468.41 5969548.88 n70 19 39.26 w149 35 26.56 1514.47 40.00 105.00 1445.77 115.865 298.20E 550527.29 5969533.52 n70 19 39.11 w149 35 24.84 1614.47 45.00 105.00 1519.48 133.345 363.43E 550592.64 5969516.48 n70 19 38.93 w149 35 22.94 - 1714.47 50.00 105.00 1587.01 152.415 434.62E 550663.95 5969497.89 n70 19 38.75 w149 35 20.86 1814.47 55.00 105.00 1647.87 172.945 511.23E 550740.68 5969477.88 n70 19 38.54 w149 35 18.62 1850.37 56.80 105.00 1668.00 180.635 539.95E 550769.45 5969470.38 n70 19 38.47 w149 35 17.79 1914.47 60.00 105.00 1701. 58 194.765 592.67E 550822.26 5969456.61 n70 19 38.33 w149 35 16.25 _ 2013.47 64.95 105.00 1747.32 217.485 677 .45E 550907.18 5969434.46 n70 19 38.11 w149 35 13.77 2057.59 64.95 105.00 1766.00 227.825 716.05E 550945.85 5969424.38 n70 19 38.00 w149 35 12.65 2500.00 64.95 105.00 1953.32 331. 565 1103.20E 551333.64 5969323.26 n70 19 36.98 w149 35 01.34 2747.23 64.95 105.00 2058.00 389.525 1319.54E 551550.35 5969266.75 n70 19 36.41 w149 34 55.03 3000.00 64.95 105.00 2165.03 448.795 1540.73E 551771.91 5969208.98 n70 19 35.83 w149 34 48.57 3082.60 64.95 105.00 2200.00 468.165 1613.01E 551844.32 5969190.10 n70 19 35.64 w149 34 46.46 3500.00 64.95 105.00 2376.73 566.035 1978.27E 552210.18 5969094.70 n70 19 34.68 w149 34 35.80 ~3590.38 64.95 105.00 2415.00 587.225 2057.36E 552289.41 5969074.04 n70 19 34.47 w149 34 33.49 3600.00 64.94 104.68 2419.07 589.455 2065.78E 552297.84 5969071. 86 n70 19 34.45 w149 34 33.25 3700.00 64.85 101. 37 2461. 51 609.865 2153.98E 552386.18 5969052.05 n70 19 34.25 w149 34 30.67 3800.00 64.83 98.06 2504.03 625.135 2243.18E 552475.47 5969037.39 n70 19 34.09 w149 34 28.07 3900.00 64.89 94.74 2546.52 635.225 2333.13E 552565.47 5969027.90 n70 19 34.00 w149 34 25.44 , 3982.39 65.00 92.02 2581. 42 639.615 2407.63E 552639.99 5969024.01 n70 19 33.95 w149 34 23.27 4000.00 65.00 92.02 2588.86 640.185 2423.58E 552655.94 5969023.55 n70 19 33.95 w149 34 22.80 4500.00 65.00 92.02 2800.18 656.125 2876.45E 553108.86 5969010.65 n70 19 33.79 w149 34 09.58 5000.00 65.00 92.02 3011.51 672.065 3329.31E 553561. 78 5968997.76 n70 19 33.63 w149 33 56.37 5039.02 65.00 92.02 3028.00 673.315 3364.65E 553597.13 5968996.75 n70 19 33.62 w149 33 55.33 ~ 5209.37 65.00 92.02 3100.00 678.745 3518.95E 553751. 44 5968992 .36 n70 19 33.56 w149 33 50.83 5300.00 64.61 87.02 3138.60 678.065 3600.91E 553833.39 5968993.59 n70 19 33.57 w149 33 48.44 5400.00 64.37 81.48 3181.70 669.035 3690.66E 553923.07 5969003.22 n70 19 33.66 w149 33 45.82 5500.00 64.35 75.93 3224.99 651.395 3779.02E 554011.30 5969021.45 n70 19 33.83 w149 33 43.24 5600.00 64.53 70.39 3268.17 625.275 3865.32E 554097.41 5969048.15 n70 19 34.09 w149 33 40.72 5646.25 64.69 67.83 3288.00 610.375 3904.35E 554136.34 5969063.31 n70 19 34.23 w149 33 39.58 5700.00 64.92 64.87 3310.89 590.875 3948.90E 554180.75 5969083.11 n70 19 34.43 w149 33 38.28 - 5778.77 65.38 60.56 3344.00 558.115 4012.40E 554244.02 5969116.29 n70 19 34.75 w149 33 36.42 5800.00 65.52 59.40 3352.82 548.455 4029.12E 554260.68 5969126.06 n70 19 34.84 w149 33 35.94 5900.00 66.31 53.99 3393.66 498.335 4105.37E 554336.58 5969176.69 n70 19 35.33 w149 33 33.71 6000.00 67.28 48.65 3433.09 440.905 4177 . 08E 554407.89 5969234.59 n70 19 35.90 w149 33 31. 62 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #101 and TVD from Est. RKB=89 , (89.00 Ft above mean sea level). Bottom hole distance is 6637.99 on azimuth 33.32 degrees from wellhead. Total Dogleg for wellpath is 179.31 degrees. Vertical section is from wellhead on azimuth 82.05 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . Page 3 of 4 B Lateral Grid Lat Long ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1B.101 Your ref 1B-101 V5 B-LAT VERtO.E Kuparuk River Unit, North Slope, Alaska Last revised : 17-Jul-2003 Measured Inclin Az imu th True Vert R E CTANGULAR G RID C o 0 R D S G E o G RAP H I C Depth Degrees Degrees Depth C 0 o R D I N ATE S Easting Northing C 0 o R DIN A T E S 6100.00 68.43 43.39 3470.80 376.60S 4243.68E 554474.06 5969299.33 n70 19 36.53 w149 33 29.67 6200.00 69.74 38.22 3506.52 305.91S 4304.68E 554534.58 5969370.42 n70 19 37.23 w149 33 27.89 ~ 6233.54 70.22 36.51 3518.00 280.86S 4323.81E 554553.53 5969395.60 n70 19 37.47 w149 33 27.33 6300.00 71.20 33.14 3539.96 229.38S 4359.62E 554588.99 5969447.32 n70 19 37.98 w149 33 26.28 6400.00 72.80 28.15 3570.88 147.58S 4408.06E 554636.87 5969529.43 n70 19 38.78 w149 33 24.87 6500.00 74.51 23.25 3599.03 61.14S 4449.65E 554677 . 88 5969616.14 n70 19 39.63 w149 33 23.65 6600.00 76.34 18.44 3624.21 29.28N 4484.06E 554711. 68 5969706.78 n70 19 40.52 w149 33 22.65 "6603.35 76.40 18.28 3625.00 32.37N 4485.08E 554712.68 5969709.87 n70 19 40.55 w149 33 22.62 6700.00 78.25 13.70 3646.22 122.99N 4511. 03E 554738.02 5969800.66 n70 19 41. 44 w149 33 21. 86 6800.00 80.24 9.02 3664.89 219.28N 4530.37E 554756.70 5969897.06 n70 19 42.39 w149 33 21. 29 6824.86 80.74 7.87 3669.00 243.52N 4533.97E 554760.14 5969921.33 n70 19 42.63 w149 33 21.19 6900.00 82.29 4.41 3680.09 317.41N 4541. 91E 554767.59 5969995.26 n70 19 43.36 w149 33 20.95 7000.00 84.39 359.84 3691.69 416.63N 4545.58E 554770.58 5970094.50 n70 19 44.33 w149 33 20.84 7003.21 84.46 359.69 3692.00 419.83N 4545.56E 554770.55 5970097.69 n70 19 44.36 w149 33 20.84 7100.00 86.53 355.30 3699.61 516.20N 4541. 34E 554765.68 5970194.02 n70 19 45.31 w149 33 20.97 -7103.21 86.60 355.15 3699.80 519.39N 4541. 07E 554765.39 5970197.21 n70 19 45.34 w149 33 20.97 7200.00 88.69 350.78 3703.78 615.34N 4529.23E 554752.90 5970293.07 n70 19 46.29 w149 33 21. 32 7217.41 89.07 349.99 3704.12 632.50N 4526.32E 554749.88 5970310.21 n70 19 46.45 w149 33 21. 40 7500.00 89.07 349.99 3708.73 910.75N 4477 .22E 554698.91 5970588.10 n70 19 49.19 w149 33 22.83 8000.00 89.07 349.99 3716.89 1403.08N 4390.33E 554608.73 5971079.78 n70 19 54.03 w149 33 25.36 8497.49 89.07 349.99 3725.00 1892.94N 4303.89E 554519.00 5971569.00 n70 19 58.85 w149 33 27.88 8500.00 89.14 350.00 3725.04 1895. UN 4303.45E 554518.55 5971571.47 n70 19 58.88 w149 33 27.89 8518.10 89.68 350.04 3725.23 1913.23N 4300.32E 554515.29 5971589.27 n70 19 59.05 w149 33 27.98 9000.00 89.68 350.04 3727.90 2387.85N 4216.93E 554428.72 5972063.28 n70 20 03.72 w149 33 30.41 9500.00 89.68 350.04 3730.67 2880.30N 4130.41E 554338.90 5972555.08 n70 20 08.56 w149 33 32.93 9738.83 89.68 350.04 3732.00 3115.53N 4089.08E 554296.00 5972790.00 n70 20 10.88 w149 33 34.13 9760.74 90.23 349.68 3732.02 3137.10N 4085.22E 554292.00 5972811.55 n70 20 11. 09 w149 33 34.24 10000.00 90.23 349.68 3731.04 3372.48N 4042.35E 554247.55 5973046.61 n70 20 13 .40 w149 33 35.49 10500.00 90.23 349.68 3728.99 3864.39N 3952.77E 554154.67 5973537.85 n70 20 18.24 w149 33 38.10 11000.00 90.23 349.68 3726.95 4356.29N 3863.18E 554061. 79 5974029.10 n70 20 23.08 w149 33 40.71 11500.00 90.23 349.68 3724.90 4848.20N 3773.60E 553968.91 5974520.34 n70 20 27.92 w149 33 43.32 12000.00 90.23 349.68 3722.86 5340.10N 3684. OlE 553876.03 5975011. 59 n70 20 32.76 w149 33 45.93 12210.09 90.23 349.68 3722.00 , 5546.79N 3646.37E 553837.00 5975218.00 n70 20 34.79 w149 33 47.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #101 and TVD from Est. RKB=89, (89.00 Ft above mean sea level). Bottom hole distance is 6637.99 on azimuth 33.32 degrees from wellhead. Total Dogleg for wellpath is 179.31 degrees. Vertical section is from wellhead on azimuth 82.05 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . Page 4 of 4 B Lateral Grid Lat Long ConocoPhillips Alaska, Inc. Pad 1B.101 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 1B-101 V5 B-LAT VER#O.E Last revised: 17-Jul-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Caords. Comment - - - - - - - - - - -- -- - -- - - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 300.00 300.00 O.OON O.OOE KOP 800.00 797 .47 24.96S 35.65E BId/Turn 31100 977 .16 970.38 44.03S 68.79E Bld/Turn 4/100 1111.18 1098.18 59.62S 105.88E Bld/Turn 5/100 1414.47 1366.46 100.11S 239.41E Build 5/100 1850.37 1668.00 180.63S 539.95E Base Permafrost 2013.47 1747.32 217.48S 677 .45E EOC 2057.59 1766.00 227.82S 716.05E Top T- 3 2747.23 2058.00 389.52S 1319.54E Top K-15 3082.60 2200.00 468.16S 1613 . OlE 10 3/4 SURFACE '3590.38 2415.00 587.22S 2057.36E BId/Turn 3/100 3982.39 2581. 42 639.61S 2407.63E EOC 5039.02 3028.00 673.31S 3364.65E Top Ugnu C 5209.37 3100.00 678.74S 3518.95E Bld/Turn 5/100 5646.25 3288.00 610.37S 3904.35E Top Ugnu B .5778.77 3344.00 558.11S 4012.40E Top Ugnu A 6233.54 3518.00 280.86S 4323.81E K13 '6603.35 3625.00 32.37N 4485.08E Top West Sak D 6824.86 3669.00 243.52N 4533.97E Top C 7003.21 3692.00 419.83N 4545.56E Top B Sand "7103.21 3699.80 519.39N 4541. 07E 7 5/8 CSG PT. 7217.41 3704.12 632. SON 4526.32E WS V5 RLOC'D B-HEEL RVSD9JUL03 8497.49 3725.00 1892.94N 4303.89E WS V5 B-QRT TGT 09 JUL 03 8518.10 3725.23 1913.23N 4300.32E EOC 9738.83 3732.00 3115.53N 4089.08E WS V5 B MIDPT TGT RVSD 08JUL03 9760.74 3732.02 3137.10N 4085.22E EOC 12210.09 3722.00 5546.79N 3646.37E WS V5 B-TOE RVSD 08 JUL 03 -' Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE 3082.60 O.OOE 7103.21 O.OOE 12210.10 2200.00 3699.80 3722.00 468.16S 519.39N 5546.79N 1613.01E 103/4 SURFACE 4541.07E 7 5/8 INT 3646.37E 4 1/2 Liner Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - -- - - - -- - - - - - - - -- - - - - -- WS V5 RLOC' D B- HEEL WS V5 B-QRT TGT 09 J WS V5 B MIDPT TGT RV WS V5 B-TOE RVSD 08 554519.000.5971569.000,2.0000 554296.000.5972790.000.0.0000 553837.000.5975218.000,0.0000 3704.12 3725.00 3732.00 3722.00 632.50N 1892.94N 3115.53N 5546.79N 4526.32E 4303.89E 4089.08E 3646.37E 2-Jul-2003 9-Jul-2003 9-Jun-2003 10-Apr-2002 , . . ConocoPhillips Alaska, Inc. Structure : Pad 18 Well : 101 .~ ConocoPhillips Created by bmichcel For: S Date plotted : 17-Jul-2003 Plot Reference is 18-101 V5 a-tAT VERl/a.E. Coordinates ore in feet reference slot 1101. Vertical Depths ore reference Est. RK8=89'. ....:r:.d ~ Field: Kuparuk River Unit Location: North Slope. Alaska INTI!;Q TRUE NORTH fiJ ~_ cI ~ 10~ ~ [=:J * 80 ~.. ~~".. ;b 5D 0 ~~ 3~4-o,. I " 20 ". \ 330 /.,."" \ 1600 1800 ..,.....,\ 2 1 0 30 ~ '''':920 \ 40 '", 400" \. 400 " 310 ". 50 Ga:ì" ". 300 60 2 9 0 0JJ--- 70 f$ 280 /" . .'::~......_- 80 .'.'-'" 270 90 260 100 250 110 240 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well . . Baker Hughes Incorporated Anticollision Report ---.-...- .._....._~- Company: Field: .Reference Site:... Reference Well:· Reference Well path: --_.._--_._~._-_..~-~-- ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 B 101 1B-101 B-LatVersÔ.E Date: 7/1712003: Time: 1q:41:45 Page: Co-ordinate(N E) Reference: .. .vertical (TVD) Reference:· Well:J01, True North "Yellhead(89')89~0 Db: . Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 12210.07 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 7/2/2003 Validated: No Planned From To Survey ft ft 0.00 12210.07 Planned: 1B-101 B-Lat VersO.E Version: 2 Toolcode Tool Name MWD+SAG MWD + Sag correction Casing Points MD TVD Diameter Hole Size Name ft ft in in --_.~.. --- 3082.60 2200.00 10.750 13.500 1 0-314" 7103.21 3699.71 7.625 9.875 7-5/8" 12210.09 3722.00 4.500 6.750 41/2" Summary < Offset Wellpath .::" > Reference Offset ,.Ctr-Ctr No-Go Allowable' Site Well Well path MD MD ::. Distance Area . Deviation Warning ft ft ft ft ft _... _.. _._.". ______ __h_O. .-. Pad 1B 101 1B-101 D-Lat VersOe VO 5550.00 5550.00 1.09 353.70 -348.72 FAIL: Major Risk Pad 1 B 10 1B-10GI VO 338.14 350.00 1089.41 5.55 1083.87 Pass: Major Risk Pad 1 B 102 1B-102 Version#1 V6 PI 400.52 400.00 20,86 7.27 13.61 Pass: Major Risk Pad 1 B 11 1B-11GIV1 918.21 1150.00 936.93 17.63 919.63 Pass: Major Risk Pad 1 B 1 1 B-01 VO 341.01 350.00 767.95 5.60 762.35 Pass: Major Risk Pad 1 B 12 1B-12 VO 652.84 650.00 32.04 11.03 21.12 Pass: Major Risk Pad 1 B 13 1B-13 VO 322.48 325.00 390.95 5.51 385.45 Pass: Major Risk Pad 1 B 14 1B-14 VO 368.84 375.00 314.41 6.30 308.11 Pass: Major Risk Pad 1 B 15 1B-15 VO 323.20 325.00 271.81 5.53 266.30 Pass: Major Risk Pad 1B 16 1B-16 VO 374.22 375.00 29.90 6.63 23.28 Pass: Major Risk Pad 1 B 17 1B-17 V2 878.47 875.00 23.70 16.05 7.74 Pass: Major Risk Pad 1B 18 1B-18 VO 348.95 350.00 76.83 5.95 70.87 Pass: Major Risk Pad 1 B 19 1B-19 VO 299.97 300.00 140.89 5.19 135.70 Pass: Major Risk Pad 1 B 20 1 B-20 V1 321.28 325.00 609.81 5.70 604.11 Pass: Major Risk Pad 1 B 2 1 B-02 VO 342.20 350.00 647.61 5.67 641.94 Pass: Major Risk Pad 1 B 3 1 B-03 VO 343.46 350.00 527.87 5.70 522.18 Pass: Major Risk Pad 1 B 4 1 B-04 VO 344.78 350.00 408.46 5.72 402.74 Pass: Major Risk Pad 1 B 5 1 B-05 VO 369.31 375.00 287.90 6.12 281.78 Pass: Major Risk Pad 1 B 6 1 B-06 VO 347.72 350.00 168.01 5.76 162.25 Pass: Major Risk Pad 1 B 7 1 B-07 VO 349.34 350.00 47.93 5.72 42.21 Pass: Major Risk Pad 1 B 8 1 B-08 VO 929.56 925.00 34.60 17.31 17.41 Pass: Major Risk Pad 1 B 8 1 B-08A VO 929.56 925.00 34.60 17.31 17.41 Pass: Major Risk Pad 1 B 9 1B-09GI VO 336.86 350.00 1248.05 5.53 1242.52 Pass: Major Risk Pad 1 B CPF-1A CPF-1A VO 1032.56 875.00 1498.32 19.99 1478.79 Pass: Major Risk Pad 1 B WS-10 WS-10 VO 356.19 375.00 1060.99 5.85 1055.14 Pass: Major Risk Pad 1 B WS-11 WS-11 VO 318.40 325.00 1141.24 5.22 1136.02 Pass: Major Risk Pad 1 B WS-1 WS-01 VO 396.89 400.00 179.38 6.51 172.87 Pass: Major Risk Pad 1 B WS-2 WS-2 VO 347.29 350.00 194.05 5.69 188.36 Pass: Major Risk Pad 1 B WS-3 WS-03 VO 369.84 375.00 221.76 6.06 215.69 Pass: Major Risk Pad 1 B WS-4 WS-04 VO 345.80 350.00 264.94 5.67 259.28 Pass: Major Risk Pad 1 B WS-5 WS-05 VO 345.09 350.00 311.94 5.66 306.28 Pass: Major Risk Pad 1 B WS-6 WS-06 VO 344.39 350.00 363.33 5.65 357.68 Pass: Major Risk Pad 1 B WS-7 WS-7 VO 321.84 325.00 416.93 5.28 411.65 Pass: Major Risk Pad 1 B WS-8 WS-08 VO 343.10 350.00 469.72 5.63 464.10 Pass: Major Risk Pad 1 B WS-9 WS-09 VO 357.18 375.00 981.51 5.87 975.65 Pass: Major Risk Pad 1C 01 1C-01 V2 Out of range Pad 1C 02 1 C-02 VO Out of range Pad 1C 03 1 C-03 VO 6300.00 7550.00 4712.32 234.77 4477.39 Pass: Major Risk Pad 1C 04 1 C-04 VO Out of range Pad 1C 05 1 C-05 VO Out of range Pad 1 C 06 1 C-06 VO Out of range Pad 1 C 07 1C-07 VO Out of range Pad 1C 08 1 C-08 VO 7329.45 7925.00 3389.71 162.68 3251.18 Pass: Major Risk e . Baker Hughes Incorporated Anticollision Report ComJ.IIIII)': Field: J.{dercllec SUe: J.{den~lIee Well: J.{efcn~lIee Wcllpath: Summary ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 B 101 1B-101 B-Lat VersO.E . .... ..._.. - ""'0..".._. _____ . .".._ .. .. ... ...... __ .... < Site Offs~t ~~lIpath : . ::.... ::: ~. Well'· :;. :: >:;'Y~Upath . Pad 1C 09 Pad 1C 10 Pad 1C 102 Pad 1C 102 Pad 1C 104 Pad 1C 104 Pad 1C 104 Pad 1C 109 Pad 1C 109 Pad 1C 111 Pad 1C 11 Pad 1C 113 Pad 1C 117 Pad 1C 119 Pad 1C 121 Pad 1C 12 Pad 1C 123 Pad 1C 125 Pad 1C 127 Pad 1C 131 Pad 1C 13 Pad 1C 133 Pad 1C 135 Pad1C 14 Pad 1C 15 Pad 1C 15 Pad 1C 16 Pad 1C 170 Pad 1C 170 Pad 1C 17 Pad 1C 172 Pad 1C 174 Pad 1C 178 Pad 1C 178 Pad 1C 178 Pad 1C 18 Pad 1C 184 Pad 1C 190 Pad 1C 19 Pad 1C 22 Pad 1C 23 Pad 1C 23 Pad 1C 24 Pad 1C 25 Pad 1C 26 Pad 1C 27 Pad 1 C SWPT1 Pad 1C WS-1 Pad 1 C WS-24 Pad lO(lncomplete) 103 1 C-09 VO 1C-10VO 1C-102 V6 1C-102L1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1C-109L1 VO 1C-111 VO 1C-11VO 1C-113 VO Plan: 1C-113 1C-117VO 1C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14V1 1C-15 V2 Plan: 1C-15L 1 1C-15L1 VO 1C-16 VO 1C-170 VO 1C-170PB1 V14 1C-17 VO 1C-172V14 1C-174 V24 1C-178 V13 1C-178L1 V1 1C-178PB1 V1 1C-18 VO 1C-184 V10 1C-190 V8 1C-19 V6 1C-22 V3 1C-23A V2 1 C-23PB 1 V1 1 C-24 VO 1 C-25 VO 1 C-26 V2 1 C-27 V1 WSSWPT1 V4 WS1 V1 WS-24 VO 10-103 V1 Uatc: 7/17/2003 Timc: 10:41:45 )'a¡:e: 2 Co-ordillaU~('Œ) I{cfercllce: Well: 101, True North Vcrtical (T\'U) I{efcrcllce: Wellhead(89') 89.0 . ... --.--... . aerèrence 1\1D ft 7000.00 7000.00 6747.05 6800.00 6747.05 7516.78 6800.00 6700.00 6300.00 6054.19 12208.44 8669.69 11070.79 6900.00 12192.48 12187.58 12204.73 7440.57 Offset J\U> ft Ctr-Ctr No-Go: Distance Area ft ft AUoW'able Deviation fL·'· 6425.00 3809.41 173.19 3636.51 6425.00 3812.16 171.72 3640.78 7400.00 1934.24 140.87 1804.08 7275.00 1933.97 128.49 1811.03 7400.00 1934.24 141.00 1803.95 6875.00 3218.30 254.58 2967.56 4975.00 4967.81 121.30 4854.51 6575.00 2888.78 165.50 2741.56 6200.00 3746.31 283.83 3477.55 6500.00 4839.69 341.95 4504.39 10900.00 7325.00 9225.00 7575.00 10950.00 12375.00 12400.00 7625.00 4282.32 445.29 4510.75 267.40 4167.47 501.03 4196.91 161.66 3309.41 588.66 2225.68 498.97 2273.70 431.18 2168.33 208.42 3856.40 4250.89 3697.29 4035.47 2721.23 1745.31 1860.18 1962.31 6800.00 3650.00 4259.90 103.64 4164.59 10597.10 3700.00 2940.49 247.66 2708.24 7100.00 13675.00 1031.34 370.35 661.50 Db: Oracle Warning Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Com pan,,: Field: Rdl.'renee Site: 1~l.'ferenl.'e WI.'II: Refl.'renel.' Wellpath: . . Baker Hughes Incorporated Anticollision Report ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 B 101 1B-101 B-Lat VersO.E .. -. - --- ,_. .......... - ... ....,. --. -..... ... . Date: 7/28/2003 Time: 08:34:42 Co-ordinale(;o.;E) Rderence: Vertical (TVD) f~eference: Well: 101, True North Wellhead(89') 89.0 ...---.-.......... ... . '-'''1 Page: NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 20.00 ft Depth Range: 7000.00 to 12210.07 ft Maximum Radius: 1500.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle ¡ ... ---=.=-:.:-:=":::.:.~ Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing .---..-.--. ..... ... ... - ..-----.... -.. - - . -- .,..-. . Survey Program for Definitive Wellpath Date: 7/2/2003 Validated: No Planned From To Survey ft ft 0.00 12210.07 Planned: 18-101 B-Lat VersO.E Casing Points Version: 2 Toolcode Tool Name MWD+SAG MWD + Sag correction MIJ TV!) Uialllell.'r 11011.' Size ~ame ft ft in in .-. -" -. .....- ." --.. _ ..-.---- - .-- ... 3082.60 2200.00 10.750 13.500 10-3/4" 7103.21 3699.71 7.625 9.875 7-5/8" 12210.09 3722.00 4.500 6.750 41/2" Summary ..... ... .... _. . n.,.. .._... . . .. .... ..__.... ........ .... _. .......... ....._.....__._.___n '--"-1 .----.. ,.... . .. . ...... . ....---..,--.... . .. ... ...,.,...-...--..-..... : <---------------- Orrsl,1 \\\'111'3111 ---------------..:> ¡ Site WI~II Wellpath un ...._.__. Pad 1 B Pad 1B Pad 1B Pad 1 B Pad 1 B Pad 1B Pad 18 Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 18 Pad 1 B Pad 1 B Pad 18 Pad 1 B Pad 1 B Pad 18 Pad 1 B Pad 1B Pad 1 B Pad 18 Pad 1 B Pad 1B Pad 18 Pad 18 Pad 1B Pad 1B Pad 1B Pad 1B Pad 1 B Pad 18 Pad 1 B Pad 1 B Pad 1 B Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1 C Pad 1 C ....._ n_ . .. .._ 101 10 102 11 1 12 13 14 15 16 17 18 19 20 2 3 4 5 6 7 8 8 9 CPF-1A WS-1Q WS-11 WS-1 WS-2 WS-3 WS-4 WS-5 WS-6 WS-7 WS-8 WS-9 01 02 03 04 05 06 07 08 Refel'ence 1\11) ft __. __.. n. . 18-101 D-Lat VersOe VO 12193.33 1B-10GI VO 1B-102 Version#1 V6 PI 7000.00 1B-11GIV1 18-01 VO 1B-12VO 1 B-13 VO 18-14 VO 1B-15 VO 1B-16 VO 1B-17 V2 1B-18 VO 18-19 VO 18-20 V5 1 B-02 VO 18-03 VO 18-04 VO 1 B-05 VO 1 B-06 VO 1B-07 VO 1 B-08 VO 18-08A VO 1 B-09GI VO CPF-1A VO WS-10 VO WS-11 VO WS-01 VO WS-2 VO WS-03 VO WS-04 VO WS-05 VO WS-06 VO WS-7 VO WS-08 VO WS-09 VO 1 C-01 V2 1 C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1 C-07 VO 1C-08 VO Offset :\II> ft 12180.00 Or-Or :"Io-Go Distance Area ft ft . .--.,-. .. 77.33 474.50 ,\lIowable I>evialion ft -249.21 6740.00 661.53 114.90 551.43 o~ f .i;a¡¡ . . n'_._'._'._._._.._, Warnillg FAIL: Major Risk Out of range Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range . . Baker Hughes Incorporated Anticollision Report . -. -.---.-- -- .---.---.--..-------.. ..... .--------_....... .. .' ..'..""'.".".". Com pan)': I:ield: Reference Site: Reference Well: I~eference Wellpath: ConocoPhillips Alaska. Inc. Kuparuk River Unit Pad 1B 101 1B-101 B-Lat VersO.E I)ate: 7/28/2003 Time: 08:34:42 Co-ordinah~(""'~) I{eference: Vertical (l'VU) Reference: Well: 101, True North Wellhead(89') 89.0 ..... .. ...... ..,,-.-..---. ........... ....-..--. - .,. -.. _..._.. .__u . ... ... .....-..---.. --, . .. ... ..... ..--..-.- - .. Summary ...-- .."......-....--,-...... ... ... <---------------- ()fr~et WellJatll --------------.> Site Well Wellpalb ..------.--.-----. ......... .. ()rr~et :\1f) ft Clr-Ctr ;'\io-Go J)j~tanee Area ft ft Allowable I)eviation Warning ft I~eferenee \.II) ft ... ......-.-... . ........-,-..---.-. ........-.---. .. Pad 1C 09 Pad 1C 10 Pad 1C 102 Pad 1C 102 Pad 1C 104 Pad 1C 104 Pad 1C 104 Pad 1C 109 Pad 1C 109 Pad 1C 111 Pad1C 11 Pad 1C 113 Pad 1C 117 Pad1C 119 Pad 1C 121 Pad 1C 12 Pad 1C 123 Pad 1C 125 Pad 1C 127 Pad 1C 131 Pad 1C 13 Pad 1C 133 Pad 1C 135 Pad 1C 14 Pad 1C 15 Pad 1C 15 Pad 1C 16 Pad 1C 170 Pad 1C 170 Pad1C 17 Pad 1C 172 Pad 1C 174 Pad 1C 178 Pad 1C 178 Pad 1C 178 Pad 1C 178 Pad 1C 18 Pad 1C 184 Pad 1C 190 Pad 1C 19 Pad 1C 22 Pad 1C 23 Pad 1C 23 Pad 1C 24 Pad 1C 25 Pad 1C 26 Pad 1C 27 Pad 1 C SWPT1 Pad 1C WS-1 Pad 1 C WS-24 Pad lO(lncomplete) 103 1 C-09 VO 1C-10 VO 1C-102 V6 1C-102L1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1C-109L 1 VO 1C-111 VO 1C-11VO 1C-113 VO Plan: 1C-113 1C-117VO 1C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 V1 1C-15 V2 Plan: 1C-15L1 1C-15L1 VO 1C-16 VO 1C-170 VO 1C-170PB1 V14 1C-17 VO 1C-172 V14 1C-174 V24 1C-178 V13 1C-178L 1 V1 1C-178PB1 V1 1C-178PB2 V2 1C-18 VO 1C-184 V10 1C-190 V8 1C-19 V6 1 C-22 V3 1 C-23A V2 1C-23PB1 V1 1C-24 VO 1 C-25 VO 1C-26 V2 1C-27 V1 WSSWPT1 V4 WS1 V1 WS-24 VO 10-103 V1 7100.00 13660.00 1029.94 370.09 659.99 AD ...~'dI\L ~.~ rit \vi .rf ii-~.. I'age: 2 ])h: Oracle . .. .......--... .--...... ....-.--. ..--1 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk ,.-..., +- Q) Q) '+- .......... ..c +- :J o (.f) I V ConocoPhillips Alaska, Inc. Created by bmichael Dote plotted: 16-JuJ-2003 ~ Plot Reference is 18-101 V5 B-LAT VERNo.E. i Coordinates are in feet reference slot #101. ¡True Vertical Depths are reference Est. RKB=89'. Rill! ... Structure: Pad 1 B Well: 101 './ ConocoPhillips Field : Kuparuk River Unit Location: North Slope, ",,- "- , \ "- '. " \,1300 , , "- , \ " , , , , , \ , , , , \ , \ '~ " " "- " '".",\ '\.., \ """, \ "'" '\ '.....",...., \ 3900 "'" 1 700 % """""Q) ¡ I I 1 60 180 200 East (feet) - > fNTF-Q 0Y 20 I POD ì ...·700 40 ~ ~@~~~~ ., " "- "- "- "- "- " "" .. 500 . .......9{)ü/ 1 300 e.. "'" e ¡õ:¡/ ...-'too BõQ9 ;/-;>«.2S00 - " 50~, "'500 "500".>-- . 230B" ... '-... "',',' ~ 900 - / ~ 2700 '" 70~, .~ 1100 /2100 \ " ",_ .. 130r1 900 \.. 2900 .... " ',-" \ 1 ß.OO ... " '" V 1700 "\ " 900:: ....",,<~~900 V100 ~" ' , >.......~, _11 oci"\3300 ',- ...... '-'-., .... ,........ ., \ -, ""~ ---- "",;,. ----- \ '~QO - ,\'......... '\ '-', ""''-, "', "',', " ",. " '-" "".... '''.. 2100 " " ", ., '" '---......" '"'''''''' ,."", ", " , '......,., ", "'~ o -Cò...~ 90Ô"" '. -""... ", "- 1100" 20 40 - 60 - 80 - 100- 120- 140~~ "... 1 900 , " , , , \ \ , , \ \ \ \ \ \ \ \. \ \ \ \~ 160 - 180 - 200- 220 - I 40 I 20 I o I 20 I 40 I 60 I 80 I 100 I 120 ----..@ ......HncY ..--,.-- 1500 1700 .........,-..........- ..-..-...-....- 1900 - - -...1}OO , \~700 \ \ \ \ I 140 I 220 I 240 I 260 I 280 I 300 ....-..--... - -. -. ...-.1200 I 320 I I 340 360 e .....@) --1$) e I I 380 400 200 - ~ - "~300 300 - «) ,21 6Öc"-_ "'*"""" '......~~-...... - "'''- 230'ò~:"',.2500 " ì~:~r""" "'" ...,...... " "-" '" 2500 ""'-,2700 .....,'......., ...,............,...... "'" """"'- 2 9 00 '",- 2700'-", '...'-'...... '.......,............. 31 00 ...,...... .......,....... "'" "",,-,3300 ",,",,2900 ',.,_, """"'.........., 8 -, -', " ",. '-".. 31 00 ""'" """"', "'.. 3300 " " '., '-,...... , ""''«J Created by bmichce! Dote plotted: 16-Ju!-2003 Plot Reference is 18-101 V5 B-LAT VER#O.£' Coordinates are in feet reference slot #101. Vertical Depths are reference Est. ø4': rNTEQ 100 - /@ ~:. J 500.. 1700 o -']D-- -...-;¡,1_~o._ -----"'_":300 100 - 'I§D _ _ -_..._?~PO - - - -__1J00 .--:¡::- 'Q) Q) 4- '+--" .J::. :is ""0 VJ 400 - 500 600 ~ \. 4700 \\ __6" \ 'U \~900 \, \ \, 2906\ \ '.5100 \ \. \ \ "\ \\\ \ , \\ \,5300 \. 310t\ \\ \\ \ \ \ \" 5500 \, \\ '\ \ \\ \\ " 330~ 5699.99 ~<ð v 700 800 - 900 - 1000 - 1100 - 1200- 300 500 400 600 700 ConocoPhillips Alaska, Inc. ./ ConocoPhillips Structure: Pad 1 B Well : 101 Field : Kuparuk River Unit Location: North Slope. Alaska 1900 2100 2300 [@) e ----"'-??9,0, --.~- --"'_? 9 00 -'--"" -......- -'-....... ------'-,-...,:3,~,~,~___,_.,"_ - - - ..1 ~OO ---...?~O~ ~"""'''''' '''-... "-,-",,~-:~~ - - - .. áò~-------,...-;l_~_o.o ------...:3.7.90 -25~;-=-=-:-::-'::3.:-~0~___- --@D 4 ~-;;~~ e 800 900 1000 1300 1100 1200 1400 1700 1500 1600 1800 1900 2000 2100 2400 2200 2300 2500 East (feet) -> . Created by bmichoel For: S Date plotted: 16-Jul-2003 Plot Reference is 18-101 V5 B-LAT VERBo.E. Coordinates ore 1n feet reference slot #101. Vertical Depths ore reference Est. -. ~ ~ ConoeoPhillips Alaska, rne. Structure: Pad 1 B Well: 101 Field: Kuparuk River Unit Location: North Slope, Alaska East (teet) -> 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 '® / [§~ ;\ ;\ I I ,\ I \\/' II ..4500 ;\ // ,v ;( /6~OO / '.1 ;¡(5~00 " '. / ,I / ,I /-ti600 , '. /5300 '. ;( I .,,5000 I I L 'I '4700 ,I /' '.~ ~(400 . I / \ / I /4100 '. / / \ ,(3800 '. ø ... ....~ ,~ JJl] \9 ,)ç65ÔC)6800 _...-62d,q ......-5900 I ...,5600 \ .....-5300 '. ....-5ÓOO \ .....47Ó0 I .,..-4~00 I ...-4100 I ....3'800 I ,...<35dO I .....3200 Ij. .~éJo ,i /'" E l'f ~----32ÕO ;: ~ -~ ," I I I 1JD,--_ /' @j). _.:.---~_3200 //3500 - - -~ """ - - -:;; --.. 3500 2600 ~ ' 2300- - :. :::-:::."'_ _ _ _ _ _ _ 2900 320.,9- - -...____ ill- - _ _ _ __... 4100 -------'f§D 4700 ~O .l~500 ,,' 6200 /5900 ø )3 /?,,~800 . II2D .... 2000 2300 ... 2900.. .".. " ," 2600 ..... 5200 n rïõ31 ¡/ 350.0= I W @ 5600 ,1 1\ \ ~0~500 \\ '-.,. 6200 \\ " 8:~,\. ,~900 " '",,~6._.00 \\ " \ ''Q)- ". 3200.. - }_~~i:,~500 ~_ .// .....,'.... ""~- ~ . 6000 \~ \\ 1\ " \; \\ \\ ~ \ ,\ i\ \\ \ ~ \\ 1\ \, i\ i\ ~ \3800 8\ \\\ ø ~....-'" """ ConocoPhillips 6400 6800 7200 7600 4 ; /2 ' L~r~; , _ 6000 7 c·' ì~\ 6500 os'rg (\~ 6200 - 5600 \ ~\ 5900 , 5600\, <0 - 5200 - 4800 ~ð03800 100\ 000 \ - 4400 , \ - 4000 - 3600 \\\ i\\ \11 j'¡\ , , \ ^ I z o ..., ..... ::r - 3200 Ii; \1 \,\ \\ \\ ~ - 2800 - 2400 - 2000 ~ ..... <D <D ..... '-" - 1600 - 1200 800 400 / / i o f\ i¡ ! \ - 400 ~.J8%L.- p--" -~ BOO . . 18-101 Drillina Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole /10-3/4" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Low Low Moderate Moderate Mitigation Strategy Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Trip speeds, Proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Running Sands and Gravels Stuck Pipe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Moderate Low Low Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low .... Low Low Moderate Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out ,/," ,[, ~ \,~",J~ 18-101 Drilling Hazards Summary. doc prepared by Steve McKeever 7/21/2003 2:15 PM ~ :~' Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/22/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com I < Toe at Surface Previous Csg. < 16",65.# casing at 148' MD < Base of Permafrost at 1,735' MD (1,600' rvD) < Top of Tail at 2,500' MD I < 103/4", 45.5# casing in 13 1/2" OH TD at 3,082' MD (2,200' TVD) Mark of Schlumberger . 1 B-1 01 CemCADE'· Preliminary job Design 103/4" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 250% excess below the permafrost. The top of the tail slurry is designed to be at 2,500' MD. Lead Slurry Minimum pump time: 250 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk '"" ;, 3 0.6381 ft 1ft x (148') x 1.00 (no excess) = 0.3637 ft3/ft x (1735' - 148') x 3.50 (250% excess) = 3 0.3637 ft 1ft x (2500' - 1735') x 3.50 (250% excess) = 94.4 ft3 + 2020.2 ft3+ 973.8 ft3 = 3088.4 ft3 14.28 ft3/sk = Round up to 730 sks Have 280 sks of additional Lead 94. 0.2 ft3 973.8 ft3 3088.4 ft3 (\ 721.6 sks I~ location ,:: ;';';~~~~lf.c:;~. . Tail Slurry Minimum pump ti : 170 min. (pump time plus 90 min.) <:¡;;-!~ 15.8 ppg Class G + 2.0% ,O.2%D46, 0.3%D65, 0.4%0167 - 1.16 ft3/sk 3 0.3637 ft 1ft x (308' 2500') x 3.50 (250% excess) = 0.5400 ft3/ft x 80' hoe Joint) = 740.9 ft3 + 43 ft3 = 784.1 ft31 . 7 ft3/sk = Roun p to 680 sks 740.9 ft3 43.2 ft3 784.1 ft3 670.2 sks ST = 46°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 40 8.0 20.0 Drop Bottom Plug 5.0 25.0 MudPUSH " 6 50 8.3 33.3 Lead Slurry 7 556 79.4 112.7 Tail Slurry 7 142 20.3 133.0 Drop Top Plug 5.0 138.0 Water Displacement 5.0 20 4.0 142.0 Switch to rig 5.0 147.0 Rig Displacement 7 248 35.4 182.4 Slow Rate 3 20.7 6.9 189.3 MUD REMOVAL Recommended Mud Properties: 9 ppg. Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II. Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. --- -- ----------------------------------------------------------------------------------------------------------------------------1 1 B..1 01 Cement Cales v2.xls 10.75 Surface 250..35 Excess LEAD Inside Conductor Permafrost Below Permafrost Hole Diameter Pipe Diameter % Excess Top of Cement Base of Cement Footage 148 1702 650 Hole Diameter with excess 15.25 18.68 14.34 bbl/ft 0.1137 0.2267 0.0875 Totals Bbls 16.82 385.91 56.85 459.58 Bbls cf 94.45 2,166.88 319.19 2,580.53 cf cy 3.50 80.25 11.82 Yield Sacks of cement 22.07 506.28 74.58 602.93 Sacks of cement TAIL Tail Shoe Track Hole Diameter Pipe Diameter % Excess Top of Cement Base of Cement Foota~e 582 80 0 Hole Diameter with excess 14.34 10.05 0.00 bbl/ft 0.0875 0.0981 0.0000 - Bbls 50.90 7.85 58.75 Bbls cf 285.80 44.07 329.88 cf cy 10.59 1.63 Yield Sacks of cement 246.38 38.00 284.38 Sacks of cement prepared by Steve McKeever 8/5/2003 Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/23/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 emaH: martin13@slb.com r Î /() % fI Previous Csg. < a ¡j.~in "'( ~Eing at 3,082' MD . 1 B-1 01 .+ Cerfì'CADE" Pr;j:}Jiminary Job De: 7-5/8" Intermediate Casing . Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 35% excess. Tail slurry is designed for 4500' MO TOC - (2603' MO annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.5%S1, 0.2%046, 0.3%065, 0.4%D167 - 1.16 ft3/sk 3 0.2148ft 1ft x 2603' x 1.35 (35% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 754.8 ft3 + 20.6 ft3 = 775.4 ft31 1.17 ft3/sk = Round up to 670 sks 754.8 ft3 20.6 ft3 775.4 ft3 662.7sks BHST = 83°F, Estimated BHCT = 72°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 40 8.0 20.0 Drop Bottom Plug 5.0 25.0 MudPUSH II 6 50 8.3 33.3 Tail Slurry 6 140 23.3 56.6 Drop top plug 5.0 61.6 Water Displace 5 20 4.0 65.6 < Top of Tail at Switch to rig 3.0 68.6 4,500' MD Displacement 7 200 28.6 97.2 Slow rate - ECD 5 80 16.0 113.2 Slow rate - ECO, 2.5 22.5 9.0 122.2 bump ~ < 75/8",29.7# casing in 9 7/8" OH TD at 7,103' MD (3,700' TVD) MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 20, Ty < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 2 per shoe joint, 115 per joint on bottom 500 and 1 per joint to TOC to aid in mud removal for good cement placement ~ . ..... / ¡t s 1B-101 As Built: Eastings; 550.229.19 Northings: 5,969,646.86 Pad Elevation: 60.4' AMSL Doyon Rig 141 RKB @ 0' Elevation: 88.4' AMSL Vetco Gray Tubing Head, API 11" , 5 ksi flange up 10-3/4",45.5#, L-80, BTC Surface to +/- 900' MD I 895' TVD 45.5#, L80 to ''', J55 / Change at +/- 900' MD Running Order (1) Float Shoe Joint, Weatherford Model 303 Float Shoe made up on a joint of 1 O-W, 40#, J55, BTC casing. (CPAI1054-2052) Vetco Gray Landing Ring (1) Joint Thread Locked Casing, 10-%",40#, J-55, 3TC. Conductor Casing Shoe @ 138', 16", 62.5#, API 5L Grade B (1) Float Collar Joint, Weatherford Model 402 Float Collar made up on a joint of 1 O-W, 40#, J55, BTC casing. (x) Joints Casing, 10-%",40#, J55, BTC. (1054-2510) (x) Joints Casing, 10-%",45.5#, L80, BTC. (1054-2532) (1) Casing Hanger, Vetco Gray, 10-%",45.5# (1) Landing Joint, 10-W, 45.5#, L80, BTC. with Vetco Gray MCA Thread on bottom Centralization: Weatherford 10-3/4" x 15-7/8" Bowspring Centralizers (1) held in place on stop collars 10 feet above shoe (0) No centralizer on next joint above shoe joint (1) per joint on next 15 joints, placed on a stop collar Jlaced 10' above the pin of each joint. 10-3/4",40#, J-55, BTC Casing Shoe @ 3,082' MD I 2,200' TVD Set @ 65 degrees TD 13-1/2" hole ConocJ'Phillips West Sak Production Well 1 B-1 01 Planned Completion Schematic Sheet 1N ~,;"SUrfaC~çrSing Details 2' -:.'i '~;'1 '''''.' __,. prepared by Steve McKeever 18-101 Permit Schematic_s1. vsd 7í21í2003 ..... . ''"' ~ pef \Ç sçþetc' Vetco Gray Tubing Head, ./ API 11" ,5 ksi flange up / Vetco Gray Pack Off J l Running Order (1) Float Shoe Joint, (1052-7839) Weatherford Model 303 Float Shoe made up on a joint of casing. (1) Joint Thread Locked Casing,(1052-7841) 7-5/8", 29.7#, L-80, STCM. (1) Float Collar Joint, (1052-7840) Weatherford lJIodel 402 Float Collar made up on a joint of casing. 10-3/4",45.5#, L-80 x 40.5#, J-55, BTC Casing Shoe @ +1- 3,082' MD 1 2,200' TVD Set @ 65 degrees TD 13-1/2" hole :x) Pup Joints Casing, 7-5/8", 29.7#, L-80, STCM, as leeded to space out window joint (x) Joints Casing, (1052-7838) 7-5/8", 29.7#, L-80, 3TCM (1) Casing Hanger, Vetco Gray, 7-5/8" :1) Landing Joint, 7-5/8",29.7#, with Vetco Gray IJICA Thread on bottom Proposed Window Depth: At top of "D" Sand, 6,603' MD I 3,625' TVD MD ~ 7-5/8",29.7#, L-80, BTCM Casing Shoe @ 7,103' MD 13,700' TVD Set @ 87 degrees TD 9-7/8" hole Conoc6Pt,illips West Sak Production Well 1 B-1 01 Planned Completion Schematic Sheet 2 of 5: Intermediate Casing Details prepared by Steve McKeever 18-101 PermitSchematic_s2.vsd 7/21/2003 n I ,~ Running Order: (1) Guide shoe, No Float, (PESI). 12.6#, IBT box, OD=5.2' with eccentric nose, 4-1/2' Ray Oil Tools Silver Bullet (CPAI) 12.6#, L-80, NSCT Box x IBT pin 4-1/2' (1) Crossover Joint blank liner, (Baker) 12.6#, L-80, NSCT Box x pin 4-1/2' (1) Pack off Bushng, (CPAI) NSCT, with sixteen 0.25" x 2" slots per foot. 12.6#, L-80, 4-1/2' (x) Joints slotted liner, sc"etnat"'C alternating every other joint to the surface casing shoe with (CPAI 1052-7842) NSCT. 12.6#, L-80, (x) Joints blank liner, 4-1/2' 6' J o 8 \)~ :T -. - - -. i ~- (CPAI 1052-7842) inside the surface casing L -80, NSCT, 12.6# , (x) Joints blank liner, 4-1/2' (CPAI) NSCT 12.6#, L-80, ID mill-able profile, 4-1/2' "Tattletale" Locator sub, 3-V2' (1) (CPAI) (CPAI) (1) Packer Assembly, Baker, consisiting of: ~1~ Crossover Sub, 5-1/2", 17#, SLHT Box x 4-1/2" 12.6# NSCT Pin 1 Mill Out Extension, Baker, 3' Long, 5-1/2", 17# SLHT pin x pin 1 Packer, Baker Model'SC1-R' (76B2-40), 7-5/8", 24-29.7#, w/ 5-1/2' Minimum ID = 4.00 in (CPAI 1063-3571) 17 #. SLHT box down with 3-'/2 IF Box up (1) Liner Running Tool Assembly, Baker, Top of Whipstock to be @ +1-6,603' MD I 3,625' TVD ) 10ft above the shoe, on the remainder of the liner in open hole, with 12.6#, L-80, NSCT. (3) Joints blank liner, 4-1/2' placed centralizer on the shoe joint Centralization: Run (1) 4-1/2" x 6-1/4" Weatherford SpiraGlider held in place with stop collars. Run (0) NO centralizer on the joint above the shoe joint. Run (1) 4-1/2" x 6-1/4" Weatherford Spira Glider per join NO stop collars. Lower Liner Top Set @ +1-6,630' MD I 3,630' TVD See Sheet 1 for Casing Details ~o CD 0 CD j -(') n~ w CD ::E ,.:,) 0 ~ CD ....OUl C1I - noen ï3D) 0-0" :eCD"::E CD ~ CD ,..,0- ~ï j - -. .. ,-_ j en III CD (') I ..,:r" CCDo CD 3 .. Dr!.. U;' ñ' D ------ ------ ------ ------ ------ 6-3/4" Open Hole TD: +1-12,210' MD 13,722' TVD ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ Surface I Production Casing 7-5/S" 29.7# L-SO STC Mod Set @ 7,103' MD 13,700' TVD ïp ..... <::> ..... i ::;: en en 9- iD <1> c...C¡'t) :3 !:.:s:~~ ~ 0 -g 10 . ::>;; ~ !II I\)*o..~ 2C¡I:)-1j¡ (,) .... '<: 0.. b' Running order: (1) Guide shoe (no float), Ray Oil Tools Silver Bullet with eccentric nose, 3-1/2 in, 9.2#, IBT box, OD=4.250" (PESI) J 0 (1) Bent Pup Joint, 18.5 ft length, 3-1/2 in. 9.2#, L-80, IBT. (CPAl) 8 (1) Crossover, 4-W' 12.6# NSCT Box x 3-1/2 in, 9.2#, IBT pin (CPAI). ~, (1) Blank joint liner, 4-W' 12.6# L80 NSCT (CPAI) (i) Pack off Bushing Sub, 4-W' 12.6# NSCT Box x Pin (Baker) '''c -- sebert'· , (x) Joints slotted liner, 4-1/2 in, 12.6#, L-80, NSCT, with sixteen 0.25 in x 2.5 in slots per foot. (CPAI). - - -- alternating every other joint with i (x) Joints blank liner, 4-1/2 in, 12.6#, L-80, NSCT. (CPAI) ~t as required to reach: Ch" (2) Joints blank liner, 4-1/2 in, 12.6#, L-80, NSCT. (CPAI) ':j'- ø s» (1) Crossover, 4-1/2 in, 11.6#, BTC Box x 4-1/2 in, 12.6#, NSCT Pin (CPAI) ø ::J ....::J::e ~þ .þ. ø (1) Swivel Sub, Baker, 4-1/2 in, 11.6#, Casing BTC Box x Pin (CPAI component of 1063-7668) ~ 0 c. ø ....O~ See Sheet 1 (1) Liner Hanger, (1063-7668) Baker Flanged Hook Hanger, Model B, Size 7-5/8 in x 4-1/2 in, 4-1/2 in 11.6#, BTC Pin -. ~o{J) 3 s» for Casing Down (BOT) )c"C" Details (1) Liner Running Tool Assembly, Baker with 3-1/2 IF Box up ">. .:g i" ::e 'ø ~ ø .. -. 0 = r-::J..,J¡, Top of Window at \.~ :; Ch OJ ~ ø a .:.a. +1- 6603' MD, Centralization: -.':j'o 3625' TVD C(l)..,J¡, Run (1) 4-1/2 in x 6-1/4 in Weatherford SpiraGlìder per joint above the packoff bushing, with NO stop collars. ~t ø 3 S"æ.. -------- -- -- C;;a ,~?? ------ ------ ------ l D ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ..... 6-3/4" Open Hole TD: tp +1-12,197' MD I 3,663' TVD ..... Production Casing 0 ..... 7-5/S" 29.7# L-SO BTC Mod ~ ~ ~t @ 710;~:~~;~~:====~==~1 3 ;:;: CI) See Sheet 2 CI) g. ib' (1) ------------- for Lower ~ì§'t)~ ------------- -~Ii:::!: Lower Liner Top Set @ Lateral Liner ~oã:t Details - 2\ Ii '" +1- 6630' MD I 3630' TVD ~æQ.='" oì§o-¡:¡ W..,'<; Q. Casing I Tubing Head Assy Vetco Gray, 11" API 5M flange up. -TUbing Hanger, Vetco Gray Gen la, 4-1/2", wI 4.90.A Top Connection; 4-1/2",12.6#, L-80 IBT-Mod box down, drilled for Tree Assy, TEC wire & two SSSV control lines. , Vetco Gray "Producer" (x) Joints Tubing 9-718" Hole Sail Angle: 65 degrees (1) Nipple (1061-9229) for Sub Surface Safety Valve, Schlumberger (Camco) Model BP-6i, with 3.813" Camco 'DB' profile (3.813"ID Packing bore). IBT-Mod, set at +1- 2700' MD I l. 2000' TVD. Run with isolation sleeve (x.xxx" ID) installed, and 10' pups top and bottom. with (1) Cameo Model WRDP-2 valve installed after rig release (X) Joints Tubing (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with DCK shear valve installed, pinned to shear when annular pressure is 2500 psi greater than tubing pressure, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups. top and bottom. set at +1- 2400 ft TVD, (+1- 3530' MD) (x) Joints Tubing (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with BK-2 dummy valve installed, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. (1) Joint Tubing (1) Handling pup, 10 ft long (1) Profile Nipple, Camco DB, 3.75" Packing Bore (1) Relief Groove Sub, Baker with (1) Jet Pump installed after rig release. (1) Sliding Sleeve, 3.S13 CMU Weatherford, x" Reverse Circulation, #xx Nozzle, #xx (1) Relief Groove Sub, Baker Throat, with topXOto CAMCO 3.75 Lock. (1) Polished Bore Sub, 3.750" ID polished bore, 24 inshes long. (1) Handling pup, 10 ft long J 10-3/4".45.5#. L-80 x 40.5#. J-55, BTC Casing Shoe @ +/- 3.082' MD /2,200' TVD Tubing String: 4-1/2", 12.6 #, L-80, IBT,AB Modiifed (1054-2463) ef 3(\Ç Sçbe«' (1) Joint Tubing (1) Pressure Gauge, Internal Tubing, Baker Gaurdian (2) Joints Tubing (1) PBR with Seal Assembly, 17 ft Baker Model 80-47, 4-11 2" L-80 IBT- Mod, 6 ft handling pups installed on top & bottom. (1) Packer I Miliout Assembly, Baker Model 7-518 x 4- 112" 'S3'. (ID 3.875), 4-1/2" IBTM, 6 ft handling pup installed on top. (1) Profile Nipple, 4-'h Camco DB, 3.687" ID packing bore, 4-1/2" L-80 IBT-Mod Box, set at 70 deg maximum inclination. With RHC Plug installed for use with ball and rod. With 10ft handling pups. Top @ 6200' MD I 350S' TVD Control Line I TEC wire for / Gaurdian Gauges, held in place with ~ Canon Clamps on every coupling (x) Joints Tubing and tubing pups (1) Wire line Entry Guide, 4-1/2" L-80 IBT-Mod Box, to be spaced out +1- 15' above hook hanger Hook Hanger, Baker Model ....--. B, 7 -5/S" x 4- W', _____________ Main Bore Drift = 5.315" Lateral Bore Drift = 3.875" ~:::> "::::: Lower Liner Top Set @ +/-6,630' MD I 3,630' TVD ~------II ------- ------ ------- ------ ------- ~ Window @ 6603' MD / 3625' rvD Intermediate Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,103' MD I 3,700' TVD I:r=-=-=¡,J rs___¡ ConocJ'Phillips West Sak Production Wel/1 B-1 01 Planned Completion Schematic Sheet 5 of 5: Tubing Details or ~'. prepared by Steve McKeever 18-101 Permit Schematic_s5.vsd Monday, July 21.2003 . . I ; I 1057 04",25.J~ 2a:>þ".,,,,,, ~~Ò:' . 'if/Ire or AUl-sPJ / II--o:ac¡:; I $/=_ cv .----~ Lc:LJ cltt:; ~~)~-rJrJLLARS fD e~::~ ~... C H ASE Chase Manha..an Sank USA. N.A. Valid Up To 5000 Dollars U.· 200 White Clay Center Dr., Newark, DE 19711 ...0 {Þ -10 ,_Lh-L-ßd. I: 0 ~ ¡. ¡. 0 0 ¡. ~ ~ I: 2 ¡. BODO 0 ~ 2 7 2 5 7111 ¡. 0 5 7 I Bl ì S. K. ALLSUP-DRAKE CONOCOPHILLlPS 711 G STREET - AT01530 ANCHORAGE AK 99501 UNlVERSA~ ¡' . . TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡¿12t{ 18-/ðj PTD# 203-/3-3 CHECK WHAT APPLŒS ADD-ONS (OPTIONS) MlJL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECK.LIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 18-101 Program DEV Well bore seg D PTD#: 2031330 Company CONOCOPHILLlPS ALASKA INC Initial Class/Type DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D Administration 1 Permittee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease-"Umber_appropriale_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _Entire_we.ILwjIUiejnADLQ25648;corfßctioomadelo_10-.401. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 3 Unique weltname_aod oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJlJocated in_a_ d_efìned pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 We.llJocated proper _distançe_ from driJling unit boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 We.llJocated properdistaoçe from otber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_ufficient acreage_ayailable in_drilJiog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jfdeviated, js_ weJlbore plaUnc]uded _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 Operator only affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 Operator basappr.opriateJlond inJorce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ 11 Permit cao be issued wjtbout co_nservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permitcao be issued wjt/)Qut ad_ministrati\(e_appr.ovaJ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 7/30/2003 13 _C_ao permjtÞe approved before J5-day_ waJt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 14 We.llJocated within area and_strata authorized bylojecti.oo Order # (puUO# in_commeotst(For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 15 _AJlwells_withinJl4 l11ileare.a of reyiew ideotified (F.orservjœwelJo nly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-producediojeçtor; duratiQn_ofpre-productionless_than_3months(Forservicewellon]y) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 17 ACMP_F.indingof Consi'sleocy_h_as beenJssuedJort/)is proiect _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ We] drilled frQm exjstiog pad, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering Appr Date 4~~: Geology Appr SFD Date 7/30/2003 Geologic Commissioner: IJvS 18 _G.oodu_clor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urfaœ_casingprotecìs.allknown_USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _AIIaquife.rs exempted 40 CfB.:147.t021b){3). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 20 _CMTvoladequateto circutate_on_cond_uctor_& surfcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMT_votadequatetotie-inJQngstriogtosudcsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _Ceme.ntbe.ightmeetsregulations._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 _CMT will coyeraJl koown -p(o_ductiYe borizon_s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No Slotte_d Jioercompletioos planned. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23G.asiog desigos adeQua_te. f.or C,_T~ B _&_p_ermafrost _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _Adequale_tan_kage orre_serve pit _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ßigjs_e_quippedwithßteel_pits._Noresel'\'epjtplanoe_d, Wastetoanapproyed_annulusordisposatweJI. _ _ _ _ __ 25 Jfare-drill~ bas a 10A03 fQr abandon_ment beeo approved _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequølewellbore_separatjonproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _J::>f9ximityanalysispe.rf.orme_d, Cloßeapproache_sjd_entjfied.TraveJiogcyUnerploUnc]uded.Gyros.likely. 27 Jfdiverter required, dQeß jtmeel reguJaJions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ Diyerter waiver has_b_een granted JuJy_28Jor_this well. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 DrilJiog fluid program schematic&_ equip Jistadequale _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ BI-IF' expected betwe_eo 9._6 to 9.8 ppg EMW, Plaooe.dMW for WS 9.8 minimum. 29 .BOPEs, dO they meetJeguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 .BOPEpre.ssratiogappropriate;JesHo(putpsigin_comments) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _M.A.SJ::>estimatedatt5J3psi._3500psiappropri_ate.J::>J::>CQlikelytotestto_500Qpsi. _ _ _ _ _ _ _ _ _ _ __ 31G.hokel11anifold compJies w/.A.Pt RF'-53 (May 84)_ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will .occur with.outoperation _sbutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js preseoce of H2S gas_ prob_able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecba_nicaLcondJtiooof we.lIs within.A.Oß yerified (For service wel] only) _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Steve McKee\(er,CPA, 3-25-03: no H2S known .In WSak oil; rig equipped_ with _sens.orslalarms, ßçayenger availaÞt _ _ _ Yes _ _ _ _ _ _ Expectedrese.l'\'ojr pre'ssure iß _9,6_- _9,8_ppg _EMW; wHLbedrilled wjtb 9.8 ppg mud. _ _ _ _ 35 Permit cao be issued w/o hydrogen_ s_ulfide measures _ _ _ _ _ _ _ _ _ _ _ _ 36 _Datapresel)ted on pote_ntial .oveJPres_sun~zones_ 37 _Seismicanalysjs of ßbaJlow gasz.ol)e.s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _Seabed _condjti.ol) survey (if off-sh.ore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Contact namelphoneJor_weekly pr.ogress_reports [exploratory _ooly] _ NA _ __________ _ _NA _ _ _ _ _ _ _ _ _ _ _ __ NA - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: ~ß/3 Engineering Commissioner: Date Public Commissioner Date ~~~ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. .' . . (103,- )33 **** REEL HEADER **** LDWG 03/09/25 AWS 01 I ~l ~ 1-- **** TAPE HEADER **** LDWG 03/09/25 01 *** LIS COMMENT RECORD *** ! ! !!! !!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1B-101 500292317300 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 25-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. MEYER F. HERBERT MWD RUN 4 4 C. MEYER F. HERBERT MWD RUN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 llN 10E 88.40 60.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 10.750 3080.0 9.875 7.625 7388.0 STRING 6.750 12230.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 40.246" LONG: W149 DEG 35' 33.548" ~~~'\\.~ ~ L~EASURED FROM D.F. AT 88.4 FT. AB4IIÞPERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Directional Only service from 148 - 3090 feet MD (148 - 2206' TVD). (2) Baker Hughes INTEQ run 3 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity & Gamma Ray services from 3090 - 7395 feet MD (3) Baker Hughes INTEQ run 4 utilized a Multiple Propagation Resistivity (MPR) service along with a Navi II Annular Pressure sub from 7395 - 12230 feet MD (3731 - 3713' TVD). (4) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) The interval from 148 - 3090 feet MD (148 - 2206' TVD) was drilled with directional tools. No formation evaluation logging was done in this interval. (2) Depth of 10 3/4" Casing Shoe-Logger: 3080 feet MD (2200' TVD) Depth of 10 3/4" Casing Shoe-Driller: 3080 feet MD (2200' TVD) (3) The interval from 7364 to 7395 feet MD (3729-3731' TVD) was logged up to 75.7 hours after being drilled due to a trip for the 7 5/8" casing run. (4) Depth of 7 5/8" Casing Shoe-Logger: 7388 feet MD (3730' TVD) Depth of 7 5/8" Casing Shoe-Driller: 7388 feet MD (3730' TVD) * Please note that due to the change in resistivity tools at the 7 5/8" casing point, from RNT to MPR, that the presentation goes from 2 phase resistivity curves to 4 phase resistivity curves. (5) The interval from 12199 to 12230 feet MD (3714 - 3713' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 90 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !! !!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3030.0 STOP DEPTH 12230.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- " BASELINE DEP4IIÞ $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ . BIT RUN NO 3 4 MERGE TOP 3030.0 7395.0 MERGE BASE 7395.0 12230.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Please note that due to the change in resistivity tool type at the 7 5/8" casing point, the presentation goes from 2 resistivity curves (RPD, RPS) to 4 resistivity curves (RPD, RPM. RPS, RPX). RPM & RPX data above 7395' contains null values. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT Ibl0l 5.xtf 150 ConocoPhillips Alaska, Inc. IB-I0l Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 8 FET MWD MTEM MWD . 68 1 1 HR DEGF 4 4 4 4 . ------- 32 Total Data Records: 658 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3030.000000 12230.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 706 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 3 .2500 START DEPTH 3030.0 STOP DEPTH 7364.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 23-AUG-03 MSB 18704 6.75 ATK MEMORY 7395.0 3030.0 7364.0 o 63.3 86.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL TOOL NUMBER SHE 17834 RNT 20099 RNT 20099 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3080.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): LSND 9.40 MUD VISCO. (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . 150 .0 .000 .000 .000 .000 118.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 3) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT Ibl01..xtf 150 ConocoPhillips Alaska, I IB-I0l Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0..* F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM: 4.: 4 3 RPCH MWD 68 :1 OHMM: 4 4 4 RACL MWD 68 1 OHMM: 4 4 5 RACH MWD 68 1 OHMM: 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 620 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3030.000000 7364.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 710 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!! !!!!!! ! !!! LDWG File Version 1.000 !!!!!!!! !!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 4 .2500 START DEPTH 7364.0 STOP DEPTH 12230.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: 28-AUG-03 MSB 18704 4.75 MPR MEMORY 12230.0 7364.0 12230.0 o 86.4 MAXIMUM A: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIS. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 9. TOOL NUMBER SDS 1363 MPR 54694 SRIG 58019 6.750 7388.0 Flo-Pro 9.60 .0 .0 72000 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 4 (MWD Run 4). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT Ibl01. xtf 150 ConocoPhillips Alaska, I IB-IOl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAM ---------------------------------------------------- GRAM GRAM 0.0 RPCL RPCL· .,RPD 0.0 . RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACS.LM \ \ /~'/': ':~". , 0.0 1::- RACH RACH >';MS', 9·8 ,,) RASH RASH RACSHM , 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= C) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1025 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7364.000000 12230.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1124 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/09/25 01 . **** REEL TRAILER **** LDWG 03/09/25 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: . 2 records... 132 bytes .132 .byte~ . ~ ,,, " ; ~ 't ,.1> ..,.. ',' "