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Home My WebLink About203-122MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-102 KUPARUK RIV U WSAK 1B-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 1B-102 50-029-23167-00-00 203-122-0 W SPT 3608 2031220 1500 684 685 685 685 0 0 0 0 4YRTST P Guy Cook 6/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1B-102 Inspection Date: Tubing OA Packer Depth 1575 2300 2250 2240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612102230 BBL Pumped:0.3 BBL Returned:0.3 Tuesday, July 22, 2025 Page 1 of 1              CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1B-102 (PTD 203-122) Report of High IA Pressure Date:Friday, January 31, 2025 9:32:21 AM Attachments:1B-102 90 day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, January 31, 2025 8:29 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1B-102 (PTD 203-122) Report of High IA Pressure Chris, KRU 1B-102 (PTD 203-122) was reported by operations yesterday 1/30/25 to have an IA pressure of 2125 psi. The 7” 26 lb/ft, L-80 has a burst rating of 7240 psi (45% burst rating = 3258 psi). The IA was bled with well pressures currently at T/I/O = 695/1250/0. 1B-102 experienced a temperature and injection rate spike due to recent pigging operations that caused an IA thermal response. CPAI does not have diagnostics planned at this time. Any future suspect annular communication will be reported if and when it is observed. 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-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Open Sliding Sleeve for Cement Job & Pulled Hex 1B-102 12/2/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 8/31/2003 osborl 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 28.0 148.0 148.0 62.50 H-40 WELDED GRAVEL SCAB LINER 13 3/8 12.41 27.4 520.9 517.5 68.00 L-80 BTC SURFACE 9 5/8 8.83 26.9 7,795.9 3,653.2 40.00 L-80 BTC Tie-Back String 7 6.28 27.2 7,653.0 3,616.3 26.00 L-80 HYD563 SLOTTED LINER 5 1/2 4.95 7,620.0 14,036.4 3,777.0 15.50 L-80 HYDRIL 511 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 20.8 Set Depth … 7,476.2 Set Depth … 3,568.0 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L80 Top Connection Blue 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) 20.8 20.8 0.00 HANGER 10.850 11" StreamFlo FBD Hanger w/ 4" LTC top thread (4" H BPV) Streamfl o FBD 3.900 2,652.1 2,008.0 70.37 Nipple - X 4.996 Halliburton 3.813" X-Nipple Halliburt on X-nipple 3.813 7,346.0 3,528.7 71.52 Mandrel – GAS LIFT 5.987 4-1/2" x 1" KBG-2, GLM SLB KBG-2 3.860 7,405.9 3,547.3 72.37 Nipple - X 4.999 Halliburton 3.813" X-Nipple Halliburt on X-nipple 3.813 7,454.9 3,561.8 72.98 Locator 5.210 Baker GBH 192-47 Locator Sub (5.21" OD) Baker 192-47 Locator 3.890 7,455.7 3,562.1 72.99 Seal Assembly 4.720 Baker GBH 192-47 Seal Assembly (4' from fully located) Baker 192-47 Seal Assembl y 3.900 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) 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435.0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608.0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 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) 7,346.0 3,528.7 71.52 1 GAS LIFT DMY BK 1 0.0 11/29/2023 SLB KBG-2 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) 7,455.5 3,562.0 72.99 XO Reducing 7.000 7" 26# L-80 HYD563 Box x 5 1/2" HYD563 Pin Pup w/ Crossover 6.220 7,480.3 3,569.2 73.27 XO Reducing 6.040 5 1/2" HYD563 Box x 4 1/2" Blue Pin Crossover 3.930 7,528.4 3,582.9 73.83 Sleeve - Frac 5.500 4 1/2" NCS HP2 Sleeve (CYCLED OPEN FOR CEMENT JOB AND CLOSED 12/2/2023)) 12.6# L-80, Blue BxP (PN#: 0050970) NCS HP2 Multi- Cycle 3.870 7,586.4 3,598.7 74.48 Nipple 4.500 3.813" X-Nipple, Blue Box x Pin (SN#: 0004915658-10) HES X-Nipple 3.813 7,634.4 3,611.4 74.77 XO Threads 4.500 4 1/2" 12.6# L-80 Blue x 4 1/2" 12.6# L-80 HYD563 Pup w/ Crossover 3.940 7,643.8 3,613.9 74.79 Locator 5.210 Baker GBH 192-47 Locator 3.890 7,620.0 3,607.6 74.73 PACKER 8.240 BAKER ZXP PACKER 7.490 7,633.6 3,611.2 74.76 NIPPLE 8.010 RS NIPPLE 6.188 7,645.4 3,614.3 74.80 XO THREAD 5.500 4.950 7,647.6 3,614.9 74.80 SBR 6.250 BAKER CASING SEAL BORE RECEPTACLE 4.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.0 10,528.0 3,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR 4/29/2009 1B-102, 12/3/2023 7:01:19 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 Tie-Back String; 27.3-7,653.0 Seal Assembly; 7,455.7 Locator; 7,454.9 Mandrel – GAS LIFT; 7,346.0 Annular Fluid - Seawater; 2,000.0-7,455.7; 11/6/2023 Surface String Cement; 0.0 ftKB Nipple - X; 2,652.1 Annular Fluid - Diesel; 27.3- 2,000.0; 11/5/2023 Annular Fluid - Diesel; 20.8- 2,000.0; 11/7/2023 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 20.8 KUP INJ KB-Grd (ft) 35.00 RR Date 8/15/2003 Other Elev… 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE1B-102 Annotation Last WO: End Date 11/7/2023 H2S (ppm) DateComment SSSV: NONE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-102 KUPARUK RIV U WSAK 1B-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/22/2024 1B-102 50-029-23167-00-00 203-122-0 W SPT 3608 2031220 1500 636 636 637 637 0 0 0 0 INITAL P Kam StJohn 12/31/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1B-102 Inspection Date: Tubing OA Packer Depth 1570 2500 2470 2470IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS231231104736 BBL Pumped:1 BBL Returned:0.7 Monday, January 22, 2024 Page 1 of 1          RWO (Sundry 323-535) to repair well; MIT post-injection 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 14044'feet 10608'feet true vertical 3778' feet 9287'feet Effective Depth measured 10435'feet 7620'feet true vertical 3717' feet 3608'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2"L-80 7476' 3568' Packers and SSSV (type, measured and true vertical depth)7620' 3608' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk 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: 323-535 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 SSSV: None Sydney Long sydney.long@conocophillips.com (907) 265-6312 7923-13948', 10523-10528' 3684-3769', 3723-3723' 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 measured TVD 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-122 50-029-23167-00-00 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: ADL0025639, ADL0025648, ADL0025649 Kuparuk River Field/ West Sak Oil Pool KRU 1B-102 Plugs Junk measured Length 494' 148'Conductor Gravel Scab Liner Surface 16" 13-3/8" 120' Tie-Back Slotted Liner 7769' 7618' Casing 3653' 3616' 7796' 7653' 6416' 5-1/2" 14036' 3777' 521' 518' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Senior RWO/CTD Engineer By Grace Christianson at 12:25 pm, Dec 05, 2023 Page 1/7 1B-102 Report Printed: 11/28/2023 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) 10/28/2023 17:00 10/28/2023 23:30 6.50 MIRU, MOVE MOB P Back rig off mats and stage on 1H. M/U Test Spool to BOP stack. Pickup cellar pit liner. Load rig mats. Haul to 1B for staging. Clean up 1H-101 tree, cellar, and pad. Haul Support equipment to 1B. Secure rig for move. 10/28/2023 23:30 10/29/2023 00:00 0.50 MIRU, MOVE MOB P Start rig move from 1H to 1B. 10/29/2023 00:00 10/29/2023 02:00 2.00 MIRU, MOVE MOB P Continue rig move from 1H to 1B. Arrive on pad @ 02:00. 10/29/2023 02:00 10/29/2023 08:00 6.00 MIRU, MOVE MOB P Lay T mats and double mats @ 1B-102. Lay cellar pit liner. Stage wellhead equipment behind well. Hang tree. 10/29/2023 08:00 10/29/2023 10:00 2.00 MIRU, MOVE MOB P Spot sub over well. Level rig over well. 10/29/2023 10:00 10/29/2023 11:30 1.50 MIRU, MOVE MOB P Measure RKB. Spot cuttings box and align auger chute. Spot Tiger and OT tanks. Build lay down area. Gather Initial Pressures. T/IA = 25 psi / 250 psi. Begin taking on 9.6# Brine into Pits. Complete Rig Acceptance Checklist. Accept rig @ 11:30. 10/29/2023 11:30 10/29/2023 14:45 3.25 MIRU, WELCTL COND P Continue loading pits w/ 9.6# brine. Build 40 Bbls deep clean pill. R/U Circ manifold. RU hardline to tanks. 10/29/2023 14:45 10/29/2023 15:15 0.50 MIRU, WELCTL RURD P Blow air through flow path to confirm clear to tanks. Send 10 bbls to Tiger Tank to flood lines. Shut In. PT to 2,500 psi. 10/29/2023 15:15 10/29/2023 15:45 0.50 MIRU, WELCTL PRTS P PJSM for well kill. 10/29/2023 15:45 10/29/2023 20:00 4.25 MIRU, WELCTL KLWL P Bleed free gas off of IA & TBG. Nothing on TBG, IA bled F/ 185 T/ 0 quickly. Pump 36 Bbls deep clean pill @ 4 BPM, followed by 775 Bbls of 9.6# brine down tubing taking returns out IA. SD pumps. Blowdown lines. 10/29/2023 20:00 10/29/2023 20:45 0.75 MIRU, WELCTL OWFF P OWFF. IA static. Bleed small amount of diesel from Tubing. Tubing and IA static. 0 psi. Monitor to see if flow slows down. 10/29/2023 20:45 10/29/2023 21:15 0.50 MIRU, WELCTL MPSP P PU T-Bar and set BPV. 10/29/2023 21:15 10/29/2023 21:30 0.25 MIRU, WELCTL PRTS P Test BPV to 1,000 psi from below. Monitor tubing side through bleeder. Pass. Blowdown lines. 10/29/2023 21:30 10/30/2023 00:00 2.50 MIRU, WHDBOP NUND P Clean up cellar area. R/D circulating hoses. N/D tree. Hanger neck threads are in good condition. Function LDS's. Install test dart. Lift old tree out of cellar. 10/30/2023 00:00 10/30/2023 04:30 4.50 MIRU, WHDBOP NUND P Cont. L/D old tree outside Cellar. MU 11" 5M x 13 5/8" 5M DSA. N/U BOP's. Torque DSA and BOP flanges. M/U choke and kill lines. Rig temporarily lost power during genset sync. Cont to load 3 1/2" DP on ODS pipe elevators. Load 4.909" MCA Landing Joint (32.6' long) into pipe shed 10/30/2023 04:30 10/30/2023 06:30 2.00 MIRU, WHDBOP RURD P Finish processing 3 1/2" DP. R/U testing equipment. Fill stack and surface lines. Purge air from system. Electrician onsite to troubleshoot SCR issue. SCR's operational. Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 2/7 1B-102 Report Printed: 11/28/2023 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) 10/30/2023 06:30 10/30/2023 16:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBRs w/ 4 ½ & 3 1/2" Test joint. Test LPR w/ 7" test joint. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ & 4 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam Stjohn. 10/30/2023 16:30 10/31/2023 00:00 7.50 MIRU, WHDBOP BOPE T Blinds failed initial test, were inspected and passed retest. Annular piston seals leaking. Pulled element and piston. 10/31/2023 00:00 10/31/2023 11:45 11.75 MIRU, WHDBOP BOPE T Replaced seals. Installed piston and element. Cont w/ Initial BOP test. Tested annular w/ 3 1/2" and 7" test joints. Test manual and HCR choke valves. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3,000 PSI, after closure=1,650 PSI, 200 PSI attained =20 sec, full recovery attained =117 sec. UVBR's= 4.6 sec, LVBRs= 4.6 sec. Annular= 14 sec. Simulated blinds= 4.6 sec. HCR choke & kill= 1.2 sec each. 4 back up nitrogen bottles average =1,950 PSI. Witness waived by AOGCC rep Kam Stjohn. Finished BOPE test w/ 2 Fail/Passes total (Blinds and Annular). 0.0 0.0 10/31/2023 11:45 10/31/2023 12:45 1.00 MIRU, WHDBOP MPSP P R/D testing equipment. Pull BPV and test dart. 0.0 0.0 10/31/2023 12:45 10/31/2023 14:00 1.25 COMPZN, RPCOMP PULD P Set Iso-Sleeve. P/U 4.909" MCA Landing Joint (short nose). Screw into landing joint with Top Drive. Set 10K down. BOLDS. Pull 175K to unseat hanger. Pull hanger to rig floor @ 93K. 0.0 7,615.0 10/31/2023 14:00 10/31/2023 14:15 0.25 COMPZN, RPCOMP OWFF P OWFF for 15-min. 7,589.0 7,589.0 10/31/2023 14:15 10/31/2023 15:00 0.75 COMPZN, RPCOMP PULD P L/D Tubing Hanger and pup. M/U Floor Valve. Screw in w/ Top Drive. 7,589.0 7,589.0 10/31/2023 15:00 10/31/2023 16:30 1.50 COMPZN, RPCOMP CIRC P Circ. BU to clear diesel cap from the well. 4 BPM @ 80 psi. 7,589.0 7,589.0 10/31/2023 16:30 10/31/2023 17:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. No Flow 7,589.0 7,589.0 10/31/2023 17:00 11/1/2023 00:00 7.00 COMPZN, RPCOMP PULL P Pull 4 1/2" Tubing from pre-rig cut 7,615'. PUW=93K. Observed minor pin corrosion on GLM pup 3535'. Pull to 2113' Midnight 7,589.0 2,113.0 11/1/2023 00:00 11/1/2023 03:00 3.00 COMPZN, RPCOMP PULL P Continue to pull old completion from 2113'. Recovered 243 Full Joints and one partial cut joint #244 @ 15.27'. 2,113.0 0.0 11/1/2023 03:00 11/1/2023 04:00 1.00 COMPZN, RPCOMP CLEN P Clean and clear pipe shed and rig floor. 0.0 0.0 11/1/2023 04:00 11/1/2023 06:30 2.50 COMPZN, RPCOMP RURD P R/D tubing handling equipment. Load BHA #1 (4 1/2" Tubing Overshot) into pipe shed. R/U DP handling equipment. Set wear ring. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 3/7 1B-102 Report Printed: 11/28/2023 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) 11/1/2023 06:30 11/1/2023 08:30 2.00 COMPZN, RPCOMP BHAH P Perform derrick inspection. Pull wear ring. 7.75" ID of wear ring < 8.125" OD of Overshot. M/U BHA #1 (4 1/2" Tubing Overshot). 0.0 223.0 11/1/2023 08:30 11/1/2023 15:45 7.25 COMPZN, RPCOMP PULD P TIH w/ BHA #1 to just above top of fish. 223.0 7,531.0 11/1/2023 15:45 11/1/2023 18:00 2.25 COMPZN, RPCOMP SLPC P Slip and Cut Drill Line. 7,531.0 7,531.0 11/1/2023 18:00 11/1/2023 20:00 2.00 COMPZN, RPCOMP FISH P Obtain Parameters. PUW = 102K. SOW = 75K. Pump Rate = 4 BPM @ 725 psi. Set down @ 7613'. No Latch. Hard solid setdown. Try rotating to work down. Multiple speeds. Dry. Never observed any pump pressure increase. Set down never changed. Discuss options with town. 7,531.0 7,613.0 11/1/2023 20:00 11/1/2023 23:30 3.50 COMPZN, RPCOMP TRIP P TOOH racking back 3 1/2" DP. 7,613.0 223.0 11/1/2023 23:30 11/2/2023 00:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 (4 1/2" Overshot) 223.0 0.0 11/2/2023 00:00 11/2/2023 00:30 0.50 COMPZN, RPCOMP BHAH P Continue to lay down BHA #1 - No fish. Cut lip guide necked down 7.75 233.0 0.0 11/2/2023 00:30 11/2/2023 03:00 2.50 COMPZN, RPCOMP BHAH P M/U BHA #2, 5.875" Overshot. 0.0 220.7 11/2/2023 03:00 11/2/2023 07:00 4.00 COMPZN, RPCOMP TRIP P TIH w/ Overshot to TOF @ 7,613'. 220.7 7,613.0 11/2/2023 07:00 11/2/2023 07:30 0.50 COMPZN, RPCOMP FISH P Obtain Parameters. PUW = 103K, SOW = 76K. 2 BPM @ 194 psi. Cont. TIH to find top of fish @ 7,614'. 3-5K bobble. Rotate @ 3 RPM to capture fish. Pressure spiked to 280 psi @ 7,616' (fish in grapple). Set 10K down. PU to confirm latch. Minimal overpull. Kicked pumps back onlinet @ 2 BPM to confirm fish latched. Pressured up to 393 psi. Indicated we are over the fish. TIH and stack 20K to confirm fish is fully swapped in Overshot. PUH out of SBR and confirm top of SBR @ 7,596'. 7,613.0 7,616.0 11/2/2023 07:30 11/2/2023 08:45 1.25 COMPZN, RPCOMP CIRC P PUH to 7,572'. Circ BU. 7,616.0 7,572.0 11/2/2023 08:45 11/2/2023 09:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30-min. No Flow 7,572.0 7,572.0 11/2/2023 09:15 11/2/2023 13:30 4.25 COMPZN, RPCOMP TRIP P TOOH standing back 3 1/2" DP. 7,572.0 220.7 11/2/2023 13:30 11/2/2023 14:30 1.00 COMPZN, RPCOMP BHAH P L/D BHA #2. Fish on. 15.1' partial joint + 5.75' Pup + 20.32' Seal Assembly. 220.7 0.0 11/2/2023 14:30 11/2/2023 15:30 1.00 COMPZN, RPCOMP BHAH P Load out fishing tools - Load storm packer 0.0 0.0 11/2/2023 15:30 11/2/2023 16:30 1.00 COMPZN, RPCOMP BHAH P Hang off 2 stands DC and 18 stands of 3 1/2" DP. M/U BHA #3 (Storm Packer). 0.0 20.7 11/2/2023 16:30 11/2/2023 17:00 0.50 COMPZN, RPCOMP TRIP P TIH to approx. 51' (middle of 1st full joint of 9 5/8" Casing). 20.7 51.0 11/2/2023 17:00 11/2/2023 17:30 0.50 COMPZN, RPCOMP MPSP P Set Storm Packer @ 51'. TOOH. 51.0 51.0 11/2/2023 17:30 11/2/2023 19:30 2.00 COMPZN, RPCOMP PRTS P PT Storm Packer for 30-min. Charted. Unable to get test. Lost 1000 PSI 30 min. Bump back up loose 1000 PSI 20 minutes. Observe fluid coming out of 9 5/8" X conductor pipe up through hanger flutes. Consult town team 51.0 51.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 4/7 1B-102 Report Printed: 11/28/2023 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) 11/2/2023 19:30 11/2/2023 22:00 2.50 COMPZN, RPCOMP PULL P Descission made to pull storm packer 10' uphole and retest. Attempt to straight pull storm packer in 10K LB incriments to 42K. Did not release. Attempt packer release with RH turns. Will not release. Continue with straight pulls up to 42K over. Will not release. 51.0 51.0 11/2/2023 22:00 11/2/2023 22:30 0.50 COMPZN, RPCOMP RURD P Load YJ fishing tools back on rig. M/U jars and bumper sub 51.0 51.0 11/2/2023 22:30 11/3/2023 00:00 1.50 COMPZN, RPCOMP P Make up jars and bumper sub. Start light jarring @ 30K over. working up 51.0 11/3/2023 00:00 11/3/2023 01:00 1.00 COMPZN, RPCOMP PULL P Continue jarring on storm packer 51.0 51.0 11/3/2023 01:00 11/3/2023 02:30 1.50 COMPZN, RPCOMP TRIP P Back off of packer, Broke @ 4 1/2 EUE on top of packer. Relocate jars to top of packer. P/U single DC. RBIH screw in 51.0 51.0 11/3/2023 02:30 11/3/2023 03:30 1.00 COMPZN, RPCOMP PULL P Start jarring on packer. Came free on 4th hit. Move uphole. Hung up @ 31.11 top of packer. Small jar hit with RH torque worked free. Continue out of hole. 51.0 25.0 11/3/2023 03:30 11/3/2023 04:30 1.00 COMPZN, RPCOMP BHAH P Start breaking down BHA. Packer in between set and release 25.0 0.0 11/3/2023 04:30 11/3/2023 07:00 2.50 COMPZN, RPCOMP BHAH P Lay down / load out Yellow Jacket tools & Plugs. L/D Drill collars and DP stands. Cont. Processing 7" casing and loading GBR casing running equipment. 0.0 0.0 11/3/2023 07:00 11/3/2023 11:15 4.25 COMPZN, RPCOMP WAIT P Wait on Baker Tools coming out of Deadhorse. G-Plug, Test Packer, and Storm Valve. 0.0 0.0 11/3/2023 11:15 11/3/2023 12:00 0.75 COMPZN, RPCOMP BHAH P Load and M/U BHA #4 (G-Plug) 0.0 30.0 11/3/2023 12:00 11/3/2023 12:15 0.25 COMPZN, RPCOMP TRIP P TIH placing G-plug mid element @ 30' RKB (middle of 2' pup below 9 5/8" casing hanger). 30.0 30.0 11/3/2023 12:15 11/3/2023 12:30 0.25 COMPZN, RPCOMP MPSP P Set G-Plug @ 30' RKB. 30.0 30.0 11/3/2023 12:30 11/3/2023 14:00 1.50 COMPZN, RPCOMP PRTS P PT G-Plug to 1,000 psi low. Check for leaks @ 9 5/8" casing fluted hanger. No Leak @ 1,000 psi. Pressure up to 2,000 psi (61 strokes) and started to leak. Bled off pressure. Pump strokes indicated higher volume than expected to pressure up indicating G-Plug elements not holding. 30.0 30.0 11/3/2023 14:00 11/3/2023 14:30 0.50 COMPZN, RPCOMP TRIP P Drain Stack. Pull G-Plug. Inspect. Remeasure RKB ULDS and LLDS to verify accurate set depths. Founds LLD to be approx 3' off. 30.0 0.0 11/3/2023 14:30 11/3/2023 15:00 0.50 COMPZN, RPCOMP MPSP P Re-set plug @ 32.5'. 0.0 32.5 11/3/2023 15:00 11/3/2023 15:30 0.50 COMPZN, RPCOMP PRTS P PT G-Plug to 2,000 psi. Pump Stroked to build pressure = 41. Check fluted hanger for leak. Started to leak @ 1300 psi. 32.5 32.5 11/3/2023 15:30 11/3/2023 16:30 1.00 COMPZN, RPCOMP TRIP P Bleed off. Drain Stack. Pull G-Plug. 32.5 0.0 11/3/2023 16:30 11/3/2023 17:30 1.00 COMPZN, RPCOMP BHAH P M/U BHA #5 (Test Packer). 0.0 18.0 11/3/2023 17:30 11/3/2023 17:54 0.40 COMPZN, RPCOMP TRIP P TIH w/ Test Packer to 199'. 18.0 105.0 11/3/2023 17:54 11/3/2023 18:00 0.10 COMPZN, RPCOMP MPSP P Set Test Packer @ 100', COE'. 105.0 105.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 5/7 1B-102 Report Printed: 11/28/2023 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) 11/3/2023 18:00 11/3/2023 19:00 1.00 COMPZN, RPCOMP PRTS P PT Test Packer, Casing, and HEX Plug to 2,000 psi. / 30 Min 105.0 105.0 11/3/2023 19:00 11/3/2023 20:00 1.00 COMPZN, RPCOMP MPSP P Bleed off pressure, release test packer. Rack back stand, Lay down packer 105.0 0.0 11/3/2023 20:00 11/4/2023 00:00 4.00 COMPZN, RPCOMP WAIT P Wait on spool to be ported, B/D top drive, choke & kill lines. Drain stack. Prep for stack nipple down. Complete processing 7" completion. Bring in 4 1/2 seal assembly A and B. 7" pup package. Spool on location with port 0.0 0.0 11/4/2023 00:00 11/4/2023 03:00 3.00 COMPZN, RPCOMP NUND P Nipple down BOP stack and rack back. Nipple down Vault hanger 0.0 0.0 11/4/2023 03:00 11/4/2023 04:30 1.50 COMPZN, RPCOMP NUND P Nipple up StreamFlo. Test base flange through test port. 5K for 10 minutes. Nipple up casing head 0.0 0.0 11/4/2023 04:30 11/4/2023 13:00 8.50 COMPZN, RPCOMP NUND P Stage riser. Set BOP stack. Remove Dutch Riser lockdown flange for additional cellar clearance. Cont NU BOPE, choke and kill lines. Install riser. Air up boots. Have enough clearance to keep Test Spool on stack. 0.0 0.0 11/4/2023 13:00 11/4/2023 16:00 3.00 COMPZN, RPCOMP PRTS P GBR on location to start RU pipe handling equipment. Set Test Plug. Test BOP break to 250/2500 psi for 5- min low / 5-min high. Chart. 0.0 0.0 11/4/2023 16:00 11/4/2023 18:30 2.50 COMPZN, RPCOMP PRTS T Found leak on Kill and Choke side during low. Tighten and re-test. Failed. Swap Greylock on Choke side. Retest. 0.0 0.0 11/4/2023 18:30 11/4/2023 19:00 0.50 COMPZN, RPCOMP PRTS P Shell test, No leaks from grayloc connection. Blinds leaking 0.0 0.0 11/4/2023 19:00 11/4/2023 22:00 3.00 COMPZN, RPCOMP P Drain stack, Change out blind rams, Fuction test, Shell test to 250 / 2500 PSI 0.0 0.0 11/4/2023 22:00 11/4/2023 23:30 1.50 COMPZN, RPCOMP RURD P Verify 7" Tieback jewelry run order and tally. Prep rig floor to run tieback.Trouble shoot torque turn. Measure lower seal assembly. Verify sliding sleeve is closed 0.0 0.0 11/4/2023 23:30 11/5/2023 00:00 0.50 COMPZN, RPCOMP SFTY P PJSM to pick up Intermediate casing per talley 0.0 0.0 11/5/2023 00:00 11/5/2023 04:00 4.00 COMPZN, RPCOMP PUTB P Run 7" Intermediate casing a per tally. 0.0 3,275.0 11/5/2023 04:00 11/5/2023 11:00 7.00 COMPZN, RPCOMP PUTB P Stop and drain trip tank, PUW=100K, SOW=75K Continue in hole with 7" intermediate. Start processing 4 1/2" Blue Tubing @ 09:00. TIH on Joint #181. Saw 5K set down @ 7,619' (approx. 30' shallow). PUH to 7,555'. L/D Joint #181 to M/U drive sub and 3 1/2" IF pup. 3,275.0 7,555.0 11/5/2023 11:00 11/5/2023 13:15 2.25 COMPZN, RPCOMP WASH P PU Joint #181. Screw in Top Drive. Establish Circuation. 1 BPM @ 55 psi. Cont TIH w/ pumps @ 1 BPM. PUW = 180K. SOW = 70K. Set down @ 7,619'. 6K down. No pressure spike. Setting down on Liner Top Packer. Rotate 1/2 turn and work torque down. Reattempt to get past Liner Top Packer. Made it past. See 200 psi pressure spike @ 7,646' (Top of SBR). SD Pumps. Open Bleeder. M/U 3 1/2" working joint. Cont. TIH and fully locate @ 7,653.4'. 7,555.0 7,653.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 6/7 1B-102 Report Printed: 11/28/2023 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) 11/5/2023 13:15 11/5/2023 15:15 2.00 COMPZN, RPCOMP HOSO P Space out 2'. Mark pipe. L/D Joint #181 and Joint #180. Calculate required space out pups. Need 21.13' space out pups. M/U Space out Pups (9.52', 9.83', 1.78'). M/U Joint #180, Casing Hanger, Landing Joint. 7,653.0 7,552.0 11/5/2023 15:15 11/5/2023 18:00 2.75 COMPZN, RPCOMP THGR P TIH to position Casing Hanger and Running Tool below the bag. Close bag. Reverse circulate 165 BBLS of 9.6# CI Brine down the backside. RU LRS to OA. Pump 57 BBLS diesel Freeze Protect down new OA. R/D LRS. Strip in hole and land casing hanger. PT Tubing to 500 psi to confirm casing integrity. Set pack-off. RILDS. PT packoffs to 5,000 psi. 7,552.0 7,653.0 11/5/2023 18:00 11/5/2023 19:00 1.00 COMPZN, RPCOMP WWSP P Pull 7" landing joint, Drain stack prep to run packoff 7,653.0 0.0 11/5/2023 19:00 11/5/2023 20:30 1.50 COMPZN, RPCOMP WWSP P Set pack off w/ 3.5 Drill Pipe, PT Packoff to 5K 0.0 0.0 11/5/2023 20:30 11/5/2023 21:30 1.00 COMPZN, RPCOMP PRTS P Pressure test 7" intermediate casing, 2000PSI / 30 Min Good test 0.0 0.0 11/5/2023 21:30 11/6/2023 00:00 2.50 COMPZN, RPCOMP RURD P R/U GBR to handle 4.5" tubing, Continue processing 4.5 tubing 0.0 0.0 11/6/2023 00:00 11/6/2023 06:45 6.75 COMPZN, RPCOMP OTHR P Continue processing 4.5" Blue Tubing. Verify Jewelry run order and tally. 0.0 0.0 11/6/2023 06:45 11/6/2023 07:15 0.50 COMPZN, RPCOMP PRTS P PJSM for running tubing. 0.0 0.0 11/6/2023 07:15 11/6/2023 21:00 13.75 COMPZN, RPCOMP PUTB P Run 4 1/2" Completions as per Tally to 7,441'. 0.0 7,441.0 11/6/2023 21:00 11/6/2023 21:45 0.75 COMPZN, RPCOMP WASH P Obtain Parameters. PUW = 100K. SOW = 60K. Pump rate 0.5 BPM at 62 psi. TIH on Joint #182 + 10' pup. Find top of SBR @ 7,464'. Saw 150 psi pressure indicator. SD Pumps. Open Bleeder. TIH and fully locate @ 7,483' on 10' pup. PU 4'. Mark Pipe @ 7,479'. 7,441.0 7,483.0 11/6/2023 21:45 11/6/2023 22:30 0.75 COMPZN, RPCOMP HOSO P Calculate space out pups required (3.86', 1.85'). L/D 10' Pup and 35.8' of Joint #182. L/D Joint #181. M/U Space out pups. M/U Joint #181, Tubing Hanger, and Landing Joint. 7,483.0 7,445.0 11/6/2023 22:30 11/6/2023 23:45 1.25 COMPZN, RPCOMP CIRC P Screw Topdrive into Landing Joint. Line up to pump down the tubing. Pump 115 bbls of CI 9.6# Brine. Displace to backside with 113 bbls of neat 9.6# brine. SD Pumps. 7,445.0 7,445.0 11/6/2023 23:45 11/7/2023 00:00 0.25 COMPZN, RPCOMP THGR P Land Tubing Hanger. 7,445.0 7,445.0 11/7/2023 00:00 11/7/2023 03:18 3.30 COMPZN, RPCOMP PRTS P RILDS. PT hanger void to 5,000 psi. R/U PT equipment on floor and in cellar. PT Tubing to 2,000 psi. Chart. While holding 2,000 psi on Tubing, PT IA to 3,000 psi. Chart. Dump Tubing pressure. Shear SOV. Pump 10 bbls to confirm flow path. 1 BPM @ 250PSI. SD Pumps. 0.0 0.0 11/7/2023 03:18 11/7/2023 04:00 0.70 COMPZN, RPCOMP MPSP P Back out Landing Joint. Set BPV. PT BPV from below to 1,000 psi for 10-min. Chart. 0.0 0.0 11/7/2023 04:00 11/7/2023 04:30 0.50 COMPZN, WHDBOP RURD P Blow down lines / Rig down hoses 0.0 0.0 11/7/2023 04:30 11/7/2023 06:00 1.50 COMPZN, WHDBOP NUND P Pull flow riser, Nipple down flow riser 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 7/7 1B-102 Report Printed: 11/28/2023 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) 11/7/2023 06:00 11/7/2023 12:00 6.00 COMPZN, WHDBOP NUND P N/D BOP. Break 13 5/8" X 11" spool. Move over one bolt hole for better stack alignment. Clear out 4 1/2 joints and pups. Down load wear rings, setting tools, and test plugs. Off load centralizers. Flush pits with deep clean. Off load pits, 0.0 0.0 11/7/2023 12:00 11/7/2023 13:30 1.50 COMPZN, WHDBOP NUND P Install test dart. N/U Tubing Head Adapter. 0.0 0.0 11/7/2023 13:30 11/7/2023 14:00 0.50 COMPZN, WHDBOP PRTS P PT hanger void T/ 5,000 psi. For 15 Min. 0.0 11/7/2023 14:00 11/7/2023 16:30 2.50 COMPZN, WHDBOP NUND P N/U tree. Pump open SSV. Install integral flange on production valve. 0.0 11/7/2023 16:30 11/7/2023 18:00 1.50 COMPZN, WHDBOP PRTS P R/U LRS. PT Tee T/ 5000 PSI for 10 Min. PT tiger tank line T/ 2500 PSI. 0.0 0.0 11/7/2023 18:00 11/7/2023 19:00 1.00 COMPZN, WHDBOP MPSP P Pull test dart and BPV. 0.0 0.0 11/7/2023 19:00 11/7/2023 21:30 2.50 COMPZN, WHDBOP FRZP P LRS pump 68 bbls of Diesel FP down the IA. Taking returns up tubing @ 2 BPM, ICP=1100 FCP=1700 U-Tube from IA to Tubing for 1-hour. 0.0 0.0 11/7/2023 21:30 11/7/2023 23:00 1.50 COMPZN, WHDBOP RURD P B/D, R/D squeeze manifold. Secure tree and cellar. Secure and prep rig for move to 1B-101. Final pressures T/IA/OA = 300/250/200 0.0 0.0 11/7/2023 23:00 11/8/2023 00:00 1.00 DEMOB, MOVE DMOB P Remove auxiliary equipment away from rig. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/8/2023 Page 1/2 1B-102 Report Printed: 12/5/2023 Well Service Daily Summary - No Costs Job Contacts Contact Name Job: OPTIMIZE WELL Start Date 12/1/2023 End Date Objective AFE / RFE / Maint.# Rig: SLB COILED TUBING CTU 6 Rig Accept Date 12/1/2023 07:30 Rig Release Date 12/1/2023 23:59 Rig Supervisor CONDIO, JOHN,Wells Supervisor Comment Daily Operations Report Start Date 12/1/2023 07:30 Report End Date 12/1/2023 23:59 General Remarks Last 24hr Summary RUN NCS SHIFT/FRAC/CLOSE TOOL SET NCS PACKER @ 2750' CTMD, PT TBG X CT ANNULUS TO 500 PSI FOR SHALLOW TEST, PER NCS. LOCATE NCS SLEEVE @ 7520' CTMD / 7529' RKB, SHIFT OPEN, PUMP 290 BBLS OF 15.2 CLASS G CEMENT DOWN COIL & UP OA TO SURFACE. CLOSE SLEEVE, DROP DOWN TO 7550' CTMD & CIRCULATE BOTTOMS UP. Report Contacts Supervisor Title Company CAMDEN, DANNY,Coil Tubing Supervisor Coil Tubing Supervisor SLB HORWATH, CHARLIE,Coil Tubing Supervisor Coil Tubing Supervisor SLB Time Log Start Time End Time Dur (hr) Operation 07:30 09:15 1.75 TRAVEL FROM 2P-PAD TO 1B PAD. 09:15 10:00 0.75 ARRIVE ON 1B-PAD, SPOT UNIT, MANLIFT, SUPPORT EQUIP 10:00 14:15 4.25 MIRU, CHANGE PACK OFFS, BOP'S ON WELL, STACK UP LUB, MU CTC, 40K PULL TEST, MU MHA, PT 3500, MU NCS TOOLS 14:15 15:00 0.75 GO TO WELL, STAB ON, RESPOT BLEED TANK, FLUID PACK, CALIBRATE IN / OUT MM, PT LOW 250/ HIGH 4200 15:00 15:30 0.50 READY TO OPEN SWAB, CALL DSO TO OPEN SSV HES CEMENTERS SPOT EQUIP, RU 15:30 17:30 2.00 SWAB OPEN, RIH TO 2750', WT CK= 15K, STOP AT 2715' FOR SHALLOW FUNTION TEST, SET NCS PACKER, PRESURE UP DWN CT TO 500 PSI ON TBG X CT ANNULUS, 2 MIN TEST, GOOD TEST, PU TO 20K, RELEASE PACKER, CONTINUE RIH DOWN TO 7560'. LOCATE SLEEVE @ 7520', SHIFT OPEN, AND PULL UP TO 7500' CTMD. RIH DOWN TO 7505' SIT DOWN (FUNTIONS J-LATCH), PUH TO 7470' W/ NO OVER PULL. RBIH DOWN TO 7500', PICK UP TO 7490', RIH & SIT DOWN @ 7495'. PICK UP TO 25K (J LATCH FUNCTIONED), RBIH TO 7560'. PUH @ 20 FPM AND LOCATE SLEEVE @ 7520', RIH & SIT DOWN @ 7524' CTMD. CLOSE CHOKE COME ONLINE DOWN COIL TO SHIFT OPEN SLEEVE & PRESSURE UP TBG/COIL UP TO 2000 PSI. BLEED DOWN TO 1000 PSI. PICK UP INTO TENSION & RIH DOWN TO 7540', PUH ENGAGE SLEEVE @ 7520', SIT DOWN & STACK OUT TO -10K. BRING PUMP ONLINE DOWN COIL AND PRESSURE UP TO 2800 PSI (SLEEVE SHIFTS & PRESSUER DROPS TO 1100 PSI) STACK BACK OUT TO -8K 7526 CTMD, 17:30 18:00 0.50 OPEN OA AND SET UP TO CONFIRM CIRCULATION.13 BBLS DIESEL DOWN COIL, UP OA, & OUT TO TANKS (COIL MM 1.5 / CHOKE MM 1.4). 18:00 18:45 0.75 FLUSH LINE & HOLD FOR CHANGEOUT AND HOLD SAFETY MEETING WITH HES. 18:45 19:30 0.75 PUSH 5 BBLS OF DIESEL TO HES CEMENTERS, HES PT LINE, PUMP 5 BBL FW SPACER. 19:30 22:50 3.34 ONLINE PUMPING CEMENT DOWN COIL 2-2.25 BPM. COIL FULL OF CEMENT PUMPING @ 2 BPM @ 3700 PSI (COIL VOLUME20 BBLS / OA VOLUME 220. 50 BBLS CEMENT AWAY @ 2 BPM CIRC PSI=3800 TBG=700 IA=867 OA=0 75 BBLS CEMENT AWAY @ 2 BPM CIRC PSI =3800 TBG=800 IA=942 OA=0 100 BBLS CEMENT AWAY @ 1.9 BPM CIRC PSI=3800 TBG=860 IA=1000 OA=0 125 BBLS CEMENT AWAY @ 1.9 BPM CIRC PSI-3700 TBG=958 IA= 1094 OA=0 150 BBLS CEMENT AWAY @ 1.8 BPM CIRC PSI-3700 TBG=1111 IA=1199 OA=0 175 BBLS CEMENT AWAY @ 1.7 BPM CIRC PSI-3500 TBG=1222 IA=1324 OA=0 200 BBLS CEMENT AWAY @ 1.8 BPM CIRC PSI-3600 TBG=1400 IA=1419 OA=0 225 BBLS CEMENT AWAY@ 1.7 BPM CIRC PSI-3500 TBG=1675 IA=1568 OA=0 (SWAP RETURNS TO TANK VIS PILL) 235 BBLS CEMENT AWAY HES PUMP CAVITATES ALLOWING PUMP RATE TO DROP TO 1.4-1.8 BPM. 239 BBLS CEMENT AWAY WITH CEMENT RETURNS AT SURFACE WEIGHING 13.7. 271 BBLS CEMENT AWAY (WIEGHING 14.6) 282 BBLS AWAY WITH CEMENT WEIGHING 14.9 LBS. RATE CUT BACK TO .5 BPM W/ CIRC PSI @ 470 PSI. CONTINUE PUMPING CEMENT UNTIL CEMENT IS WEIGHED @ 15.2 LBS. 290 BBLS AWAY WITH 15.1 LBS AT SURFACE SWAPPING TO WATER FOR 5 BBLS. SWITCH OVER TO COIL PUMP PUMP 10 BBL GEL PILL (MM @ 298) FOLLOWED BY 5 BBLS OF DIESEL. CEMENT OUT COIL AND CEMENT WEIGHING 15.2 AT SURFACE. ((1:1 FOR ENTIRE PUMPING)) Job: OPTIMIZE WELL Report Date: 12/1/2023 Rig: SLB COILED TUBING CTU 6 Page 2/2 1B-102 Report Printed: 12/5/2023 Well Service Daily Summary - No Costs Time Log Start Time End Time Dur (hr) Operation 22:50 23:20 0.50 7526' & PICK UP CT TO 7505 WITH NO OVER PULL. RBIH TO 7530 AND PICK UP TO 7508 WITH NO OVER PULL RBIH TO TO CYCLE J LATCH AND RIH TO 7540'. PICK UP TO 7518', RIH STACK OUT TO -5 @ 7522', PICK UP ENGAGE SLEEVE @ 7519' PULL TO 32K , PRESSURE UP TBG TO 2300 (SLEEVE CLOSED) & RIH TO 7550' W/ OA STILL @ 0 PSI. BLEED TUBING DOWN TO 300 PSI AND SWEEP SURFACE LINE COMING OFF OA TO TANKS (5 BBLS DIESEL). 23:20 23:59 0.65 CT @ 7550' CIRCULATE ACROSS SLEEVE & BOTTOMS UP. Well Fluids Fluid To (bbl) From (bbl) Non-recov (bbl) Note CEMENT 290.0 DIESEL 60.0 GEL 10.0 WATER 10.0 Discharges Disch Type Oil Sheen? Material Note Safety Incidents Date Type Subtype Com Job: OPTIMIZE WELL Report Date: 12/1/2023 Rig: SLB COILED TUBING CTU 6 Page 1/2 1B-102 Report Printed: 12/5/2023 Well Service Daily Summary - No Costs Job Contacts Contact Name Job: OPTIMIZE WELL Start Date 12/1/2023 End Date Objective AFE / RFE / Maint.# Rig: SLB COILED TUBING CTU 6 Rig Accept Date 12/2/2023 00:00 Rig Release Date 12/2/2023 18:45 Rig Supervisor CONDIO, JOHN,Wells Supervisor Comment Daily Operations Report Start Date 12/2/2023 00:00 Report End Date 12/2/2023 18:45 General Remarks Last 24hr Summary SET NCS PACKER @ 7535' CTMD BELOW SLEEVE & MITT TO 3500 PSI (PASS AFTER SEVERAL ATTEMPTS). BLEED TBG TO ZERO & MONITOR PERFORM 10 MIN. NO FLOW (PASS). PULLED HEX PLUG FROM 7680' RKB, ALL SLIPS AND ELEMENT RECOVERED. JOB COMPLETE Report Contacts Supervisor Title Company CAMDEN, DANNY,Coil Tubing Supervisor Coil Tubing Supervisor SLB HORWATH, CHARLIE,Coil Tubing Supervisor Coil Tubing Supervisor SLB Time Log Start Time End Time Dur (hr) Operation 00:00 00:30 0.50 CT @ 7550' CTMD FINISH CIRCULATION UNTIL CLEAN DIESEL @ SURFACE (140 BBLS OF DIESEL) 00:30 03:30 3.00 WORK J-LATCH & SET NCS PACKER BELOW SLEEVE @ 7535' CTMD. SET UP TO MITT. INITIAL T/I/0= 200/1300/-17 TEST 3500/1650/-17 15 MIN 3300/1609/-17 RETEST 3568/1600/-16 15 MIN. 3456/1587/-16 30 MIN. 3396/1556/-15 (FAIL) RETEST TO 3564/1566/-15 15 MIN. 3507/1539/-15 30 MIN 3474/1530/-15 (FAIL) RETEST TO 3587/1539/-15 15 MIN. 3541/1517/-6 30 MIN. 3516/1500/-7 (FAIL) RETEST TO 3517/1498/-6 15 MIN. 3496/1483/-4 30 MI. 3483/1477/-3 (FAIL) RETEST TO 3609/1481/0 15 MIN 3575/1464/1 30 MIN 3558/1455/4 (PASS) 03:30 05:30 2.00 BLEED TBG DOWN TO ZERO PSI AND MONITOR AT TRIP TANK FOR NO FLOW 10 MIN (PASS). PICK UP COIL, RELEASE PACKER, POOH WHILE CIRCULATING @ .7 BPM. (57 BBLS) 05:30 07:00 1.50 SWAB CLOSED, BLOW DOWN LUBRICATOR, OFF WELL, CHANGE TO NOZ, GO TO WELL, JET STACK W/ 15 BBLS S. DSL, BLOW DOWN, OFF WELL. 07:00 07:30 0.50 MU BHA TO PULL HEX PLUG, ON WELL, QTS TO 4200, GOOD TEST. 07:30 09:06 1.60 SWAB OPEN, RIH TO 7000' CTMD, WT CK=19K, 7525' CTMD, WT CK= 20.3K, RIH WT= 6K 09:06 10:00 0.90 DRY TAG AT 7671', 6K DWN, PU CLEAN. REPEAT 2X WASH DWN, 1.7 BPM, F/ 7635' T/ 7671', PUMPS OFF DRY TAG 4X, PULL 30K (10K OVER), PULL UP TO 7650', WAIT 30 MINUTES 10:00 11:42 1.70 PUH TO 7645', 7K OVERPULL, RBIH 2X, TAG AT 7672', POOH TO CHECK BHA 11:42 12:00 0.30 SWAB CLOSED, BLOW DOWN, POP OFF, NO PLUG, INSPECT TOOLS, GS IN CATCH POSITION BUT LOCKED UP, SMALL AMOUNT OF METAL SHAVINGS, GREEN CEMENT, PIPE DOPE. SWAP GS, ON WELL, QTS GOOD. 12:00 14:30 2.50 OPEN SWAB, RIH TO 7610', ONLINE, 2.1 BPM, WT CK= 17K, CATCH PRESSURE JET DOWN F/ 7591', SIT DWN AT 7670', JET UP TO 7625', 20K, JET DWN TO 7670' 2X, SET DWN TO -10K, PUMPS OFF PULL 31K, BROKE BACK, RIH TO 7675', WAIT 30 MIN. 14:30 16:00 1.50 POOH DRY, 23.8K, EXTRA 3K, SLOW DOWN AT SBE, 7450' 16:00 16:45 0.75 SWAB CLOSED. BLOW DOWN, OFF WELL, HEX PLUG W/ ALL SLIPS AND ELEMENT RECOVERED, BREAK DOWN BHA. Job: OPTIMIZE WELL Report Date: 12/2/2023 Rig: SLB COILED TUBING CTU 6 Page 2/2 1B-102 Report Printed: 12/5/2023 Well Service Daily Summary - No Costs Time Log Start Time End Time Dur (hr) Operation 16:45 18:45 2.00 STACK DOWN LUB, RD UNIT AND EQUIPMENT. LEAVE LOCATION Well Fluids Fluid To (bbl) From (bbl) Non-recov (bbl) Note DIESEL 290.0 BHA-1 DIESEL 150.0 BHA-2 Discharges Disch Type Oil Sheen? Material Note Safety Incidents Date Type Subtype Com Job: OPTIMIZE WELL Report Date: 12/2/2023 Rig: SLB COILED TUBING CTU 6 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1B-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added HEX plug & Welltec tubing cut 1B-102 10/27/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 8/31/2003 osborl 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 28.0 148.0 148.0 62.50 H-40 WELDED GRAVEL SCAB LINER 13 3/8 12.41 27.4 520.9 517.5 68.00 L-80 BTC SURFACE 9 5/8 8.83 26.9 7,795.9 3,653.2 40.00 L-80 BTC Tie-Back String 7 6.28 27.2 7,653.0 3,616.3 26.00 L-80 HYD563 SLOTTED LINER 5 1/2 4.95 7,620.0 14,036.4 3,777.0 15.50 L-80 HYDRIL 511 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 20.8 Set Depth 7,476.2 String Max No 4 1/2 Set Depth 3,568.0 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L80 Top Connection Blue 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) 20.8 20.8 0.00 Hanger 10.850 11" StreamFlo FBD Hanger w/ 4" LTC top thread (4" H BPV) Streamfl o FBD 3.900 2,652.1 2,008.0 70.37 Nipple - X 4.996 Halliburton 3.813" X-Nipple Halliburt on X-nipple 3.813 7,346.0 3,528.7 71.52 Mandrel GAS LIFT 5.987 4-1/2" x 1" KBG-2, GLM SLB KBG-2 3.860 7,405.9 3,547.3 72.37 Nipple - X 4.999 Halliburton 3.813" X-Nipple Halliburt on X-nipple 3.813 7,454.9 3,561.8 72.98 Locator 5.210 Baker GBH 192-47 Locator Sub (5.21" OD) Baker 192-47 Locator 3.890 7,455.7 3,562.1 72.99 Seal Assembly 4.720 Baker GBH 192-47 Seal Assembly (4' from fully located) Baker 192-47 Seal Assembl y 3.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,679.1 3,623.1 74.89 TUBING PLUG 280-550 HEX PLUG W/ MOE @ 7684' RKB, OAL= 9.15' INTERW ELL HEX 44697 9 10/26/2023 0.000 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435.0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608.0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 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) 7,346.0 3,528.7 71.52 1 SOV BEK 1 11/7/2023 SOV is shear ed out. SLB KBG-2 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,455.5 3,562.0 72.99 XO Reducing 7.000 7" 26# L-80 HYD563 Box x 5 1/2" HYD563 Pin Pup w/ Crossover 6.220 7,480.3 3,569.2 73.27 XO Reducing 6.040 5 1/2" HYD563 Box x 4 1/2" Blue Pin Crossover 3.930 7,528.4 3,582.9 73.83 Sleeve - Frac 5.500 4 1/2" NCS HP2 Sleeve (Closed) 12.6# L-80, Blue BxP (PN#: 0050970) NCS HP2 Multi- Cycle 3.870 7,586.4 3,598.7 74.48 Nipple 4.500 3.813" X-Nipple, Blue Box x Pin (SN#: 0004915658-10) HES X-Nipple 3.813 7,634.4 3,611.4 74.77 XO Threads 4.500 4 1/2" 12.6# L-80 Blue x 4 1/2" 12.6# L-80 HYD563 Pup w/ Crossover 3.940 7,643.8 3,613.9 74.79 Locator 5.210 Baker GBH 192-47 Locator 3.890 7,620.0 3,607.6 74.73 PACKER 8.240 BAKER ZXP PACKER 7.490 7,633.6 3,611.2 74.76 NIPPLE 8.010 RS NIPPLE 6.188 7,645.4 3,614.3 74.80 XO THREAD 5.500 4.950 7,647.6 3,614.9 74.80 SBR 6.250 BAKER CASING SEAL BORE RECEPTACLE 4.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.0 10,528.0 3,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 1B-102, 11/28/2023 9:34:29 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 TUBING PLUG; 7,679.1 Tie-Back String; 27.3-7,653.0 Seal Assembly; 7,455.7 Nipple - X; 7,405.9 Mandrel GAS LIFT; 7,346.0 Nipple - X; 2,652.1 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 Hanger; 20.8 KUP INJ KB-Grd (ft) 35.00 RR Date 8/15/2003 Other Elev 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE1B-102 Annotation Last WO: End Date 11/7/2023 H2S (ppm) DateComment SSSV: NONE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR 4/29/2009 1B-102, 11/28/2023 9:34:29 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 TUBING PLUG; 7,679.1 Tie-Back String; 27.3-7,653.0 Seal Assembly; 7,455.7 Nipple - X; 7,405.9 Mandrel GAS LIFT; 7,346.0 Nipple - X; 2,652.1 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 Hanger; 20.8 KUP INJ 1B-102 ... WELLNAME WELLBORE1B-102 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 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? Yes No 9. Property Designation (Lease Number): 10. Field: West Sak Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14044'1429 10608' 9287' Casing Collapse Conductor Surface Scab Liner Slotted 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:Sydney Long Contact Email: Contact Phone: 907-265-6312 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 1B-102 Other: Replace Tubing N/A Kuparuk River Field sydney.long@conocophillips.com CTD/RWO Drilling Engineer Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 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: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 7620'MD/3608'TVD Packer: 552'MD/548'TVD Packer: 7647'MD/3615'TVD SSSV: None Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025639, ADL0025648, ADL0025649 203-122 P.O. Box 100360, Anchorage, AK 99510 50-029-23167-00-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: West Sak Oil Pool 3778' Plugs (MD): L-80 TVD Burst 7660' MD 148' 3653' 148' 7796' 16" 9-5/8" 120' 7769' 7923-13948' 10523-10528' 494' 5-1/2" 3684-3769' 3723-3723' 517'13-3/8" 10435' 3717' 11/1/2023 14036'6416' 4-1/2" 3777' Packer: Baker ZXP Packer Packer: Paragon II Packer Packer: paragon II Packer SSSV: None 521' Perforation Depth MD (ft): Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:48 pm, Sep 28, 2023 X VTL 10/4/2023 DSR-9/28/23 BOP test to 2500 psig Annular preventer test to 2500 psig X 10-404 X SFD 10/6/2023*&:JLC 10/6/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.06 10:25:02 -08'00'10/06/23 RBDMS JSB 101023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. requests a change from the Approved Sundry #323-268 pertaining to the upcoming workover on the well 1B-102 (APD #203-122) to include an updated completion design. The original approved sundry included pulling and replacing the tubing of the injector to repair Tubing by IA communication. It is requested that, in addition to changing the tubing, a 7” tieback casing can be run to surface and cemented in place. The tieback will be run on rig with a sliding sleeve and a new 4-1/2” completion will be run inside. The 9-5/8” x 7” annulus will be cemented to surface by service coil, via this sleeve, after Nordic 3 has moved off the well. If you have any questions or require any further information, please contact me at 907-265-6321. Sydney Long Senior Rig Workover Engineer CPAI Drilling and Wells 1B-102 West Sak Injector Run Tieback and Replace Tubing Procedure PTD: 203-122 Page 1 of 2 PPre-Rig Work 1. Pull A1 injection valve at 523’ RKB 2. Set plug at 7,647’ RKB 3. Pull coil patch at 552’ RKB 4. CMI-TxIA to 2,500 PSI. 5. DDT-T-IA 6. T-PPPOT and T-POT tests. 7. Cut the tubing at ~7,600’ RKB in the middle of the first full joint above the packer. 8. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1B-102. No BPV set for MIRU due to N3 internal risk assessment. 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. Circulate KWF as needed. Verify well is dead. 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 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to the pre-rig cut at ~7,600’ RKB. 6. TIH with DP and fish tubing stub and seals 7. Perform a cleanout run - if necessary. Change Wellhead to StreamFlo and Stack Casing Spool 8. TIH and set storm packer ~50’. Test from above to 3,500 PSI to confirm as barrier for ND of BOPE and casing spool. 9. ND BOPE and perform wellhead conversion with stacked spool. 10. NU BOPE and test break. Install 7” Tieback 1. MU and RIH with 4-1/2” seals and cementing sleeve crossed over to 7” casing. 2. Once on depth, space out as needed. 3. Land casing hanger, RILDS, PT packoffs. Install 4-1/2” Completion 4. MU and RIH with 4-1/2” completion with a GLM, nipples, and seal assembly. 5. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 6. Land tubing hanger, RILDS, PT packoffs and set packer. 7. Pressure test tubing to 3,500 PSI for 30 minutes. 8. Pressure test IA to 3,000 PSI for 30 minutes on chart. ND BOP, NU Tree 9. Confirm pressure tests, then shear out SOV with pressure differential. 10. Install BPV and test. ND BOPE. NU tree. 1B-102 West Sak Injector Run Tieback and Replace Tubing Procedure PTD: 203-122 Page 2 of 2 11. Pull BPV and freeze protect well. 12. RDMO. PPost-Rig Work Cement 7” x 9-5/8” Annulus with Coil 1. RU Coiled tubing and cementers 2. RIH and shift open sleeve 3. Pump ±250 bbls of cement, taking returns up the OA 4. Once good returns are seen at surface, cut cement and shift sleeve closed 5. POOH and circulate tubing clean, ensuring no cement is left in the tubing 6. MIT-T to 2000 psi to ensure sleeve closure Slickline - Prepare Well for Service 7. Dummy GML. 8. Pull any plugs used. General Well Information: Estimated Start Date: 11/1/2023. Current Operations: Water Injection (Currently SI) Well Type: Injector Wellhead Type: VetcoGray Horizontal 4-1/16” 5M changing to StreamFlo Vertical 4-1/16” 5M BOP Configuration: Annular / Pipe Rams / Blind Rams Static BHP: 1,749 PSI (per 465 PSI Wellhead Pressure) on 9/6/2023 MPSP: 1,429 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4-1/2” completion to a pre-rig cut and fish seals. Change wellhead and run 7” tieback to surface. Run 4-1/2” completion and engage seals. Cement 7” x 9-5/8” annulus with coil post rig. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Intervention Engineer: Katherine O’Connor (263-3718 / Katherine.OConnor@conocophillips.com) Reservoir Surv. Engineer: Marina Krysinski Production Engineer: Will Parker Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1B-102 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed new CT patch assembly. Set A-1 injection valve. 1B-102 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 148.0 Set Depth (TVD)… 148.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description GRAVEL SCAB LINER OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 27.4 Set Depth (ftKB) 520.9 Set Depth (TVD)… 517.5 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.9 Set Depth (ftKB) 7,795.9 Set Depth (TVD)… 3,653.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description SLOTTED LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 7,620.0 Set Depth (ftKB) 14,036.4 Set Depth (TVD)… 3,777.0 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,620.03,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 7,636.13,611.8 74.77 HANGER BAKER FLEX LOCK HYDR. LINER HANGER 6.290 7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 7,660.8 Set Depth (TVD) (… 3,618.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.222.20.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.7 520.212.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.812 7,313.13,518.1 71.15 NIPPLE CAMCO 3.750 DB NIPPLE 3.750 7,636.63,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 523.0 519.5 12.99 A-1 Injection Valve 3.812" DB Lock w/ A-1 Injection Valve (1.18" Bean) 10/13/2020 1.180 552.2547.912.98 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE (Set Mid-element @ 555.2' RKB) 10/8/2020 2.000 556.5 552.1 12.98 Patch (HANG OFF XO 3.27" OD, 2.0" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.8'') ( EXTERNAL CC 2.69" OD, 1.92" ID, 0.74'') ( 2" COIL .190" WALL THICKNESS 1.62" ID 7064.52') ( EXTERNAL CC 2..7" OD, 1.95" ID, 0.91') ( BLANK PUP 2.07" OD, 1.59" ID, 9.78') ( XO 2.7" OD, 1.61" ID,0.38') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, 0.9') ( SPACER TUBE ASSEMBLY 2.67" OD, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 10/8/2020 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.0 2,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,647.0 3,614.7 74.80 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 2730 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* (Set Mid-element @ 7650' RKB) 10/7/2020 1.250 9,287.03,699.191.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435. 0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608. 0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.010,528.03,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,524.82,295.5 CAMCO MMG1 1/2GAS LIFT DMY RK 0.000 0.09/18/2003 3:00 1B-102, 10/14/2020 7:16:24 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 8/15/2003 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Notes: General & Safety End Date Annotation 8/31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 1B-102, 10/14/2020 7:16:27 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ 1B-102 ... WELLNAME WELLBORE 1B-102 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 Scab Liner 521 517 13-3/8 12.41 68 L-80 BTC BTC Surface 7796 3653 9-5/8 8.83 40 L-80 BTC BTC Liner 14063 3777 5-1/2 4.95 15.5 L-80 Hyd 511 Hyd-511 Tieback 7661 3610 7 6.28 26#L-80 Hyd 563 Hyd 563 Tubing 7661 3618 4-1/2 3.96 12.6 L-80 Blue Blue 7" 26# L-80 Hyd563 Casing to Cemented to Surface Post Rig PROPOSED COMPLETION 4-1/2" 12.6# L-80 TS-Blue Tubing to Surface 4-1/2 X Nipple at ~520' RKB 4-1/2" Gas Lift Mandrel @ TBD 4-1/2" Sliding Sleeve 4-1/2" Seal Assembly 4-1/2" Cementing Sleeve REMAINING COMPLETION LEFT IN HOLE Baker ZXP Permanent Packer @ 7,620' RKB (7.49" ID) RS Nipple @ 7,634' RKB (6.188" ID) Baker Flex Lock Liner Hanger @ 7,636' RKB (6.29" ID) Baker Seal Bore Receptacle @ 7,647' RKB (4.75" ID) Gravel Scab Liner 521' RKB Surface Casing 7,796' RKB Conductor CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1B-102 (PTD 203-122) Report of failed MITIA Date:Tuesday, July 18, 2023 8:21:48 AM Attachments:1B-102.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, July 17, 2023 3:49 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 1B-102 (PTD 203-122) Report of failed MITIA Chris— An update on KRU 1B-102 (PTD 203-122). Since the notification below, we have progressed work to secure the well. Thus far, we’ve pumped a surfactant to ensure a clean profile for the pump-down plug, drifted the coil patch with slickline to the seating depth, and displaced the tubing to a known fluid column to determine an accurate reservoir pressure for fluid weighting. With the well shut-in the reservoir pressure seems to be declining materially. Because of the limited ID in the coiled tubing patch the only means to set a mechanical plug is a pump-down plug that seats in the lower packer of the patch. Once this is done we will not be able to pull the plug until the patch itself is pulled. In order to accurately monitor the reservoir pressure and thus load the well with an appropriate weight fluid above the plug we intend to continue to monitor the well and observe pressure fall-off prior to pumping down the plug. When we believe we adequately understand the pressure stabilization, we will complete the secure. Any required paperwork for corrective action or continued injection will be submitted as needed. Please let me know if you disagree or have any questions with the plan. Travis Smith (in for Jan Byrne) From: Byrne, Jan Sent: Friday, June 23, 2023 7:10 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1B-102 (PTD 203-122) Report of failed MITIA Chris, KRU 1B-102 (PTD 203-122) failed a diagnostic MITIA yesterday due to fluid leaking out of the conductor at the end of the test. The well was shut in and freeze protected and de-pressurized. The plan is for Slickline to secure the well after which a plan forward will be formulated. Any required paperwork for corrective action or continued injection will be submitted as needed. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1B-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled A-1 injection valve. 1B-102 6/23/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 8/31/2003 osborl 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 28.0 148.0 148.0 62.50 H-40 WELDED GRAVEL SCAB LINER 13 3/8 12.41 27.4 520.9 517.5 68.00 L-80 BTC SURFACE 9 5/8 8.83 26.9 7,795.9 3,653.2 40.00 L-80 BTC SLOTTED LINER 5 1/2 4.95 7,620.0 14,036.4 3,777.0 15.50 L-80 HYDRIL 511 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.2 Set Depth … 7,660.8 Set Depth … 3,618.3 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT 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) 22.2 22.2 0.00 HANGER 10.800 VETCO GRAY TUBING HANGER 4.500 523.7 520.2 12.99 NIPPLE 5.220 CAMCO 3.812 DB NIPPLE 3.812 3,524.8 2,295.5 72.15 GAS LIFT 5.968 CAMCO MMG 3.865 7,313.1 3,518.1 71.15 NIPPLE 5.055 CAMCO 3.750 DB NIPPLE 3.750 7,636.6 3,612.0 74.77 SEAL ASSY 4.500 BAKER GBH-22 SEAL ASSEMBLY 3.880 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) 552.2 547.9 12.98 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE (Set Mid-element @ 555.2' RKB) 10/8/2020 2.000 556.5 552.1 12.98 PATCH (HANG OFF XO 3.27" OD, 2.0" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.8'') ( EXTERNAL CC 2.69" OD, 1.92" ID, 0.74'') ( 2" COIL .190" WALL THICKNESS 1.62" ID 7064.52') ( EXTERNAL CC 2..7" OD, 1.95" ID, 0.91') ( BLANK PUP 2.07" OD, 1.59" ID, 9.78') ( XO 2.7" OD, 1.61" ID,0.38') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, 0.9') ( SPACER TUBE ASSEMBLY 2.67" OD, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 10/8/2020 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.0 2,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,647.0 3,614.7 74.80 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 2730 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* (Set Mid- element @ 7650' RKB) 10/7/2020 1.250 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435.0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608.0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 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) 3,524.8 2,295.5 72.15 1 GAS LIFT DMY RK 1 1/2 0.0 9/18/2003 3:00 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) 7,620.0 3,607.6 74.73 PACKER 8.240 BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE 8.010 RS NIPPLE 6.188 7,645.4 3,614.3 74.80 XO THREAD 5.500 4.950 1B-102, 7/14/2023 11:25:38 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 PATCH; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 KUP INJ KB-Grd (ft) 35.00 RR Date 8/15/2003 Other Elev… 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE1B-102 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,647.6 3,614.9 74.80 SBR 6.250 BAKER CASING SEAL BORE RECEPTACLE 4.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.0 10,528.0 3,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR 4/29/2009 1B-102, 7/14/2023 11:25:39 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 PATCH; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 KUP INJ 1B-102 ... WELLNAME WELLBORE1B-102 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1B-102 (PTD 203-122) Report of failed MITIA Date:Wednesday, June 28, 2023 10:31:12 AM Attachments:AnnComm Surveillance TIO for 1B-102.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Friday, June 23, 2023 7:10 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1B-102 (PTD 203-122) Report of failed MITIA Chris, KRU 1B-102 (PTD 203-122) failed a diagnostic MITIA yesterday due to fluid leaking out of the conductor at the end of the test. The well was shut in and freeze protected and de-pressurized. The plan is for Slickline to secure the well after which a plan forward will be formulated. Any required paperwork for corrective action or continued injection will be submitted as needed. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 1B-102 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1B-102 2023-06-22 250 1 -249 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 1B-102 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed new CT patch assembly. Set A-1 injection valve. 1B-102 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 148.0 Set Depth (TVD) … 148.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description GRAVEL SCAB LINER OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 27.4 Set Depth (ftKB) 520.9 Set Depth (TVD) … 517.5 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.9 Set Depth (ftKB) 7,795.9 Set Depth (TVD) … 3,653.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description SLOTTED LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 7,620.0 Set Depth (ftKB) 14,036.4 Set Depth (TVD) … 3,777.0 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,620.0 3,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 7,636.1 3,611.8 74.77 HANGER BAKER FLEX LOCK HYDR. LINER HANGER 6.290 7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 7,660.8 Set Depth (TVD) (… 3,618.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.2 22.2 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.7 520.2 12.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.812 7,313.1 3,518.1 71.15 NIPPLE CAMCO 3.750 DB NIPPLE 3.750 7,636.6 3,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 523.0 519.5 12.99 A-1 Injection Valve 3.812" DB Lock w/ A-1 Injection Valve (1.18" Bean) 10/13/2020 1.180 552.2 547.9 12.98 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE (Set Mid-element @ 555.2' RKB) 10/8/2020 2.000 556.5 552.1 12.98 Patch (HANG OFF XO 3.27" OD, 2.0" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.8'') ( EXTERNAL CC 2.69" OD, 1.92" ID, 0.74'') ( 2" COIL .190" WALL THICKNESS 1.62" ID 7064.52') ( EXTERNAL CC 2..7" OD, 1.95" ID, 0.91') ( BLANK PUP 2.07" OD, 1.59" ID, 9.78') ( XO 2.7" OD, 1.61" ID,0.38') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, 0.9') ( SPACER TUBE ASSEMBLY 2.67" OD, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 10/8/2020 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.0 2,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,647.0 3,614.7 74.80 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 2730 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* (Set Mid-element @ 7650' RKB) 10/7/2020 1.250 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435. 0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608. 0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.0 10,528.0 3,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,524.8 2,295.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/18/2003 3:00 1B-102, 10/14/2020 7:16:24 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 8/15/2003 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE1B-102 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Notes: General & Safety End Date Annotation 8/31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 1B-102, 10/14/2020 7:16:27 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ 1B-102 ... WELLNAME WELLBORE1B-102 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): 14044'9287' Casing Collapse Structural Conductor Surface Scab Liner Slotted 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 7923-13948', 10523-10528' 6416' 3684'-3769', 3723'-3723'4-1/2" 5-1/2" 16" 9-5/8"" 120' 7769' Perforation Depth MD (ft): 13-3/8"494' MD 148' 3653' 517' 148' 7796' 3777'14036' 521' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 3778'10435'3717'993 10608' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025639, ADL0025648, ADL0025649 203-122 P.O. Box 100360, Anchorage, AK 99510 50-029-23167-00-00 ConocoPhillips Alaska, Inc. KRU 1B-102 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Tubing Grade:Tubing MD (ft): 7620' MD and 3608' TVD 552' MD and 548' TVD 7647' MD and 3615' TVD N/A Perforation Depth TVD (ft):Tubing Size: L-80 766' 8/1/2023 Packer: BakerZXP Packer Packer: Paragon II Packer Packer: Paragon II Packer 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 Sydney Long sydney.long@conocophillips.com (907) 265-6312 m n s 66 t c Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov RWO/CTD Engineer 323-268 By Kayla Junke at 9:27 am, May 05, 2023 DSR-5/9/23 Packer depth variance allowed to place packer ~ 400 feet above the top perforation per 20 AAC 25.412(b) X MDG 6/9/2023 10-404 VTL 6/22/2023 BOP test to 2500 psig Annular preventer to 2500 psig X X GCW 06/22/2023 06/23/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 08:56:09 -08'00' RBDMS JSB 062723 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 4, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over 1B-102 (PTD# 203- 122). Well 1B-102 was drilled and completed in August of 2003 by Doyon 141 as an Injector in the West Sak B, C and D Sands. The well has experienced Tubing by IA communication, due to multiple tubing leaks, and a coil string patch was installed in 2020. It is our intent to replace the tubing. The existing 4-1/2” upper completion will be pulled from a pre-rig cut above the packer. It will be replaced with 4-1/2” tubing and associated completion jewelry, including a non-sealing overshot and a stacked packer. If you have any questions or require any further information, please contact me at 907-265-6321. Sydney Long Rig Workover Engineer CPAI Drilling and Wells 1B-102 West Sak Injector Pull and Replace Tubing Procedure PTD: 203-122 Page 1 of 2 PPre-Rig Work 1. Pull A1 injection valve at 523’ RKB 2. Pull coil patch at 552’ RKB 3. SBHP 4. Set plug at ~7,647’ RKB 5. CMI-TxIA to 2,500 PSI. 6. DDT-T-IA 7. T-PPPOT and T-POT tests. 8. Cut the tubing at ~7,600’ RKB in the middle of the first full joint above the packer. 9. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1B-102. No BPV set for MIRU due to N3 internal risk assessment. 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. Circulate KWF as needed. Verify well is dead. 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 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to the pre-rig cut at ~7,600’ RKB. Cleanout Run 6. Perform a cleanout run, based on tubing condition, and dress off 4-1/2” tubing stub - if necessary. Install 4-1/2” Completion with Stacked Packer 7. MU and RIH with 4-1/2” completion with a GLM, nipples, packer, and overshot. 8. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 9. Land tubing hanger, RILDS, PT packoffs and set packer. 10. Pressure test tubing to 3,500 PSI for 30 minutes. 11. Pressure test IA to 3,000 PSI for 30 minutes on chart. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV with pressure differential. 13. Install BPV and test. ND BOPE. NU tree. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Run GLD 2. Pull any plugs or ball/rod used for setting packer. 1B-102 West Sak Injector Pull and Replace Tubing Procedure PTD: 203-122 Page 2 of 2 GGeneral Well Information: Estimated Start Date: 8/1/2023. Current Operations: Water Injection Well Type: Injector Wellhead Type: VetcoGray Horizontal 4-1/16” 5M BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 1,354 psi / 3,610’ TVD measured 4/5/2019 MPSP: 993 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4-1/2” completion to a pre-rig cut directly above the top packer, install a new 4-1/2” completion and stacked packer. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Reservoir Surveillance Engineer: Marina Krysinski Production Engineer: Will Parker Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1B-102 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed new CT patch assembly. Set A-1 injection valve. 1B-102 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 148.0 Set Depth (TVD)… 148.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description GRAVEL SCAB LINER OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 27.4 Set Depth (ftKB) 520.9 Set Depth (TVD)… 517.5 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.9 Set Depth (ftKB) 7,795.9 Set Depth (TVD)… 3,653.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description SLOTTED LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 7,620.0 Set Depth (ftKB) 14,036.4 Set Depth (TVD)… 3,777.0 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,620.03,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 7,636.13,611.8 74.77 HANGER BAKER FLEX LOCK HYDR. LINER HANGER 6.290 7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 7,660.8 Set Depth (TVD) (… 3,618.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.222.20.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.7 520.212.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.812 7,313.13,518.1 71.15 NIPPLE CAMCO 3.750 DB NIPPLE 3.750 7,636.63,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 523.0 519.5 12.99 A-1 Injection Valve 3.812" DB Lock w/ A-1 Injection Valve (1.18" Bean) 10/13/2020 1.180 552.2547.912.98 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE (Set Mid-element @ 555.2' RKB) 10/8/2020 2.000 556.5 552.1 12.98 Patch (HANG OFF XO 3.27" OD, 2.0" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.8'') ( EXTERNAL CC 2.69" OD, 1.92" ID, 0.74'') ( 2" COIL .190" WALL THICKNESS 1.62" ID 7064.52') ( EXTERNAL CC 2..7" OD, 1.95" ID, 0.91') ( BLANK PUP 2.07" OD, 1.59" ID, 9.78') ( XO 2.7" OD, 1.61" ID,0.38') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, 0.9') ( SPACER TUBE ASSEMBLY 2.67" OD, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 10/8/2020 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.0 2,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,647.0 3,614.7 74.80 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 2730 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* (Set Mid-element @ 7650' RKB) 10/7/2020 1.250 9,287.03,699.191.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/2018 3.600 10,435. 0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608. 0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.010,528.03,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,524.82,295.5 CAMCO MMG1 1/2GAS LIFT DMY RK 0.000 0.09/18/2003 3:00 1B-102, 10/14/2020 7:16:24 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 8/15/2003 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Notes: General & Safety End Date Annotation 8/31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 1B-102, 10/14/2020 7:16:27 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ 1B-102 ... WELLNAME WELLBORE 1B-102 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 Scab Liner 521 517 13-3/8 12.41 68 L-80 BTC BTC Surface 7796 3653 9-5/8 8.83 40 L-80 BTC BTC Liner 14063 3777 5-1/2 4.95 15.5 L-80 Hyd 511 Hyd-511 Tubing 7661 3618 4-1/2 3.96 12.6 L-80 Blue Blue PROPOSED COMPLETION 4-1/2" 12.6# L-80 TS-Blue Tubing to Surface 4-1/2 X Nipple at ~520' RKB 4-1/2" Gas Lift Mandrel @ TBD 4-1/2" 9-5/8" Packer at ~7530' RKB 4-1/2 X Landing Nipple at ~7595' RKB 4-1/2" Poor Boy Overshot REMAINING COMPLETION LEFT IN HOLE Baker ZXP Permanent Packer @ 7,620' RKB (7.49" ID) RS Nipple @ 7,634' RKB (6.188" ID) Baker Flex Lock Liner Hanger @ 7,636' RKB (6.29" ID) Baker Seal Bore Receptacle @ 7,647' RKB (4.75" ID) Gravel Scab Liner 521' RKB Surface Casing 7,796' RKB Conductor MEMORANDUM 'TO: Jim Regg P.I. Supervisor �� Z( liz FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, tire. IB -102 KUPARUK RIV U WSAK IB -102 Sre: Inspector Well Name KUPARUK RIV U WSAK IB -102 API Well Number 50-029-23167-00-00 Inspector Name: -Jeff -Jones Insp Num: mit.1,I210701132248 Permit Number: 203-122-0 Inspection Date: 6/30/2021 i Rel Insp Num: Wednesday, August 11, 2021 Page 1 of 1 Packer Depth Pretest Initial l5 Min 30 Min 45 Min 60 Min Well IB -102 Type [nj W TVD 3608 Tubing' 670 670 670 670 PTD 2031220 _ . Type 'fest SPT .. Test psi!, i - -- 1500 - -- IA 430 I, 1800- - — 1740 - 1730 BBL Pumped: 36 - BBL Returned:3.4 OA I Interval Fol1I'Year Cycle P/F Pass Notes: I well inspected, no exceptions noted. Monobore injector; no OA. Previous MIT early (Apr 2017) due to water header modifications in May ' 2017. Wednesday, August 11, 2021 Page 1 of 1 Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 2031220 E-Set: 34408 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1B-102 KUPARUK RIV U WSAK IB -102 Sre: Inspector Reviewed By: P.I. Supry _ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IB -102 API Well Number 50-029-23167-00-00 Inspector Name' Brian Bixby Permit Number: 203-122-0 Inspection Date: 11/3/2020 ' Insp Num: mitBDB201103121229 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB -102 Type Inj W `TVD 3608 Tubing saa saa 545 sas PTD 2031220 Type Test SPT jTest psi 1500 IA 1260 2000 1960 1950 ' BBL Pumped: 1.8 ."B Returned: 1.8 OA Interval OTHER IP/F P _ - Notes' MIT -IA as per SUNDRY 320-279, No OA - Monobore Completion CL Tuesday, November 3, 2020 Page I of 1 ! " # " $ % &' ( )*! + (% ,- !. /"!! 0- ,- 12132+.2 4, . " ( % & % 5 6 , 788 . 9 6, (8 . !"# !$%&''( ! !$%&''( ! )*) ) ) 1 :7 ( * , . ) ; : 3" 9 % ( " &' ( - ( )" 9 < "%- & % < <*!= > ->< (!!4 &' ! & ? ,02+.1)3#)2;/ & & +!,- 7! " 7 " & " %../, - - &$-0 7 ) ) +/!+12 !31 .45 ,-*1.%%. ,1&$ =9 ) +*( ( (9 ) 16 3 % !1 ! ! ; @" A"9 ) @ ,: 12132+28132+8$131/;. ) < #5 )) 7 &-B -B*-!%<!& 6*!55**! **37)85*'*) ) #A 9 ) % ( *C % A'22;)2 8B0032 ) 98* "*!="< ) " #A 2#@2@ ;41212 " ;2( % By Samantha Carlisle at 2:31 pm, Nov 04, 2020 Stefan Weingarth Digitally signed by Stefan Weingarth Date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ast Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1B-102 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed new CT patch assembly. Set A-1 injection valve. 1B-102 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 148.0 Set Depth (TVD)… 148.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description GRAVEL SCAB LINER OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 27.4 Set Depth (ftKB) 520.9 Set Depth (TVD)… 517.5 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.9 Set Depth (ftKB) 7,795.9 Set Depth (TVD)… 3,653.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description SLOTTED LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 7,620.0 Set Depth (ftKB) 14,036.4 Set Depth (TVD)… 3,777.0 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,620.03,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 7,636.13,611.8 74.77 HANGER BAKER FLEX LOCK HYDR. LINER HANGER 6.290 7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 7,660.8 Set Depth (TVD) (… 3,618.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.222.20.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.7 520.212.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.812 7,313.13,518.1 71.15 NIPPLE CAMCO 3.750 DB NIPPLE 3.750 7,636.63,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 523.0 519.5 12.99 A-1 Injection Valve 3.812" DB Lock w/ A-1 Injection Valve (1.18" Bean) 10/13/2020 1.180 552.2547.912.98 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE (Set Mid-element @ 555.2' RKB) 10/8/2020 2.000 556.5 552.1 12.98 Patch (HANG OFF XO 3.27" OD, 2.0" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.8'') ( EXTERNAL CC 2.69" OD, 1.92" ID, 0.74'') ( 2" COIL .190" WALL THICKNESS 1.62" ID 7064.52') ( EXTERNAL CC 2..7" OD, 1.95" ID, 0.91') ( BLANK PUP 2.07" OD, 1.59" ID, 9.78') ( XO 2.7" OD, 1.61" ID,0.38') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, 0.9') ( SPACER TUBE ASSEMBLY 2.67" OD, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 10/8/2020 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.0 2,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,647.0 3,614.7 74.80 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 2730 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* (Set Mid-element @ 7650' RKB) 10/7/2020 1.250 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/20183.600 10,435. 0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608. 0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.010,528.03,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com 10,435.0 10,608.0 3,717.5 3,727.6 CMT SQZ PUMPED 24 BBLS OF CMT THROUGH RTNR ,5 BBLS ON TOP OF RTNR Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 3,524.82,295.5 CAMCO MMG1 1/2GAS LIFT DMY RK 0.000 0.09/18/2003 3:00 1B-102, 10/22/2020 8:37:54 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 8/15/2003 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Notes: General & Safety End Date Annotation 8/31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 1B-102, 10/22/2020 8:37:56 AM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,647.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 556.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 552.2 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ 1B-102 ... WELLNAME WELLBORE ! " # $! % " & " '$("" )*$ +,*# - #./$ 0/ 1$$ " ## ! 2 $& ,2 3 $ 4* 56 $78&5 7 * 9*5 7 * :*5 7 + #* 9* + #* :* 95 7 59*7;<59*7 < :< :9*5 7:*5 7 ' -" !< * =< +, *# # (+ * ) !< " /6 /$;*6 .:#*>>> 6?> " #>/$; ! + 54807'.)%.8-1 * " #$ " #! $ /= 9 / 6" //@9/ A23 $ +, 23 $ :+*=3 # "99//$+ B+"99//$ * " " + > + !" # C$ > 9*5 7 $%&$%'$$&$$ * :*5 7 C ()"" *+" ,* !-)# +6D 6D/6$*>"$+ :/$"99//$ -(( -* .)! ,)#-(()/- '8"')'18 -,0%$'-,0%'-,0% $ $& =,88-.8E E <44)8 0&&$%&& " <E/ 1 2 3)!4& 3 5)6.7+ 5( $$0 & */,4 %% , $%0$ 0 % 0&78 %8 &078 $&$78 % &78 $% * 9*5 7 0 $&$'0$&0 %%$ (- 3")94-3"):;((- 3") (- 3")9(-)-< (- 3") (- 3")9(-)-< (- 3") /9 " C 0/ # ! # ! !# C 707 > F "$ "+ " % %,'$%*/, ,'%*/, %,'$%*/, 7- 8%(8- # -&'8'8 -6 6 = 1=1 6 > By Samantha Carlisle at 1:12 pm, Jun 30, 2020 320-279 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2020.06.30 10:30:07 -08'00' 10-404 X X VTL 7/13/20 SFD 6/30/2020 DSR-6/30/2020" 7/13/2020 dts 7/13/2020 JLC 7/13/2020 RBDMS HEW 7/16/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 30, 2020 Commissioner Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Price: Please find the enclosed sundry application from ConocoPhillips Alaska, Inc. for GKA well 1B-102 (PTD# 203-122) proposing to retrieve and replace an existing coiled tubing patch. Please contact Stefan Weingarth at (907) 265-6038 if you have any questions. Sincerely, Stefan Weingarth Wells Engineer ConocoPhillips Alaska, Inc. *+, 899:; < := .3 % ! *+,$ ! ) *+, -./0 ,+,,1 > ) 3 & & & 3 % 2 % 3 ( ' & % & ( % ' && 3 3 3 & & % ( % &% ' ) ) > ( ? & %)$ (/% & % > ( ,(: > ( (% %-1 & % & ( @(/& ) ) ) %( ) 3 & ) !< ) && & & : % && & & % % ) 3( #(/% ) (A && ) & 3 (,#A &&( 4( (A && ) & 3 - & % 1 (,#A &&( ( BC ,A ( 5(: ) & *7 D + & 3( "( & ) & *7 D + & 3( (:'? ) & ,A BC & ( (3 *7 && & 3( ,(% & 3)+ & ( ( > ( @(% % ( #(. ) & 3 > ( State witnessed MIT-IA required after stabilized injection. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1B-102 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed A-1 Injection Valve 6/10/2019 1B-102 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 148.0 Set Depth (TVD)… 148.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description GRAVEL SCAB LINER OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 27.4 Set Depth (ftKB) 520.9 Set Depth (TVD)… 517.5 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.9 Set Depth (ftKB) 7,795.9 Set Depth (TVD)… 3,653.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description SLOTTED LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 7,620.0 Set Depth (ftKB) 14,036.4 Set Depth (TVD)… 3,777.0 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 7,620.0 3,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 7,636.1 3,611.8 74.77 HANGER BAKER FLEX LOCK HYDR. LINER HANGER 6.290 7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.2 Set Depth (ft… 7,660.8 Set Depth (TVD) (… 3,618.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.2 22.2 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.7 520.2 12.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.812 7,313.1 3,518.1 71.15 NIPPLE CAMCO 3.750 DB NIPPLE 3.750 7,636.6 3,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 523.0 519.5 12.99 A-1 Injection Valve 3.812" DB Lock w/ A-1 Injection Valve (1.18" Bean) 6/10/2019 1.180 780.0 769.3 14.96 PATCH- UPPER PKR (ME) 4.5" PARAGON II PACKER, 5,000PSI, DIFFERENTIAL RATING 7200# SHEAR RELEASE 6/8/2019 2.000 780.5 769.8 14.97 Patch (HANG OFF XO 3.72" OD, 1.94" ID, .41') ( SEALED TUBING SWIVEL 3.31" OD, 1.93" ID, 1.72') ( EXTERNAL CC 2.88" OD, 1.66" ID, 1.67') ( 2" COIL .190" WALL THICKNESS 1.62" ID 6,284') ( EXTERNAL CC 2.88" OD, 1.66" ID, 1.67') (XO 2.7" OS, 1.63" ID, .62') ( BLANK PUP 2.063" OD, 1.625" ID, 9.75') ( XO 2.875" OD, 1.62" ID, .71') ( LOCATOR ASSEMBLY 2.88" OD, 1.92" ID, .34') ( SPACER TUBE ASSEMBLY 2.67" OS, 1.92" ID, .34') ( SEAL BORE EXTENSION 3.5" OD, 2.688" ID, 10.29') ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.688" OD, 1.92" ID, 1') ( HALF MULE SHOE 2.67" OD, 1.92" ID, .33') ( XO 3.5" OD, 1.98" ID, .32') ( 4.5" ANCHOR LATCH SEAL ASSEMBLY 3.65" OD, 1.98" ID, .41') 6/8/2019 1.620 5,654.0 2,974.7 71.30 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,692.02,987.1 70.69 TUBING LEAK SUSPECTED TUBING LEAK 11/7/2018 3.990 5,715.0 2,994.7 70.33 TUBING LEAK TUBING LEAK CONFIRMED BY LDL 3/27/2016 3.990 7,644.03,613.9 74.79 PATCH - LWR PKR (ME) 4-1/2" P2P WITH 10' EXTENSION AND DUAL BARRIER BLOW OUT PLUG SET TO SHEAR AT 3120 PSI DP ********* BLOW OUT PLUGS HAVE BEEN SHEARED********* 5/22/2019 1.250 9,287.0 3,699.1 91.91 Fish Brass 4.5" PRS pin retainer. slightly larger than paper thin brass band. 12/26/20183.600 10,435. 0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608. 0 3,727.6 86.66 PLUG 3.5" TTS IBP 4/27/2009 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D, WS C, WS B, 1B-102 8/14/2003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, 208 slots/ft w/3' of blank pipe on each end of 40' joint; 10,523.010,528.03,722.7 3,722.9 WS C, 1B-102 4/28/2009 5.0 APERF CEMENT OFF 4/29/2009 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 10,435.0 10,608.0 3,717.5 3,727.6 Cement SQZ 4/29/2009 24 bbls pumped through retainer Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Ty pe Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 3,524.8 2,295.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/18/2003 3:00 1B-102, 6/29/2020 5:53:55 PM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,644.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 780.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 780.0 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ KB-Grd (ft) 35.00 Rig Release Date 8/15/2003 1B-102 ... TD Act Btm (ftKB) 14,044.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292316700 Wellbore Status INJ Max Angle & MD Incl (°) 95.13 MD (ftKB) 12,113.16 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Notes: General & Safety End Date Annotation 8/31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 1B-102, 6/29/2020 5:53:57 PM Vertical schematic (actual) SLOTTED LINER; 7,620.0- 14,036.4 IPERF; 7,923.0-13,948.0 PLUG; 10,608.0 APERF; 10,523.0-10,528.0 CMT Retainer; 10,435.0 CMT SQZ; 10,435.0 ftKB Fish; 9,287.0 SURFACE; 26.9-7,795.9 PATCH - LWR PKR (ME); 7,644.0 SEAL ASSY; 7,636.6 NIPPLE; 7,313.1 TUBING LEAK; 5,715.0 TUBING LEAK; 5,692.0 TUBING LEAK; 5,654.0 Patch; 780.5 GAS LIFT; 3,524.8 PATCH- UPPER PKR (ME); 780.0 A-1 Injection Valve; 523.0 NIPPLE; 523.7 GRAVEL SCAB LINER; 27.4- 520.9 CONDUCTOR; 28.0-148.0 HANGER; 22.2 KUP INJ 1B-102 ... WELLNAME WELLBORE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 2 8 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operation t Performed: Suspend E] Perforate E] Other Stimulate E] Alter Casing E] Change Approved rogram Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Coil Tubing Patch 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service 7] 203-122 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number 99510 50-029-23167-00-00 7. Property Designation (Lease Number): e. Well Name and Number: KRU 1 B-102 AKL 25639, ADL 25648, ADL 25649 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,044 feet Plugs measured 10608 feet We venical 3,778 feet Junk measured None feet Effective Depth measured 10,435 feet Packer measured 780, 7644 feet true vertical 3,717 feet true vertical 9,287 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 feet 16 148' MD 148' TVD EL SCAB LINER 494 feet 13 3/8 " 521' MD 517' TVD SURFACE 7,769 feet 95/8" 7,796' MD 3653' TVD LOTTED LINER 6,416 feet 5 1/2 " 14,036' MD 3777' TVD Perforation depth: Measured depth: 7923-13948, 10523-10528 feet True Vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 7,661' MD 3,618' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- PARAGON II PKR (upper patch) 780' MD 769' TVD PACKER - BAKER ZXP PACKER 7,620' MD 3,608' TVD PACKER - P2P PKR (lower patch) 7,644' MD 3,614' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcr Water -Bbl Casing Pressure Tubing Pressure Prior to well operefion: SHUT-IN e e 840psi 651p1i Subsequent to operation: 1e e 800 1300psi 642psi 14. Attachments (required per 20 MC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development ❑ Service 71 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: . Contact NameTyson Wiese Authorized Name: Tyson Wiese Contact Email: Tyson.M.Wiese@cop.com Authorized Title: Staff Wells Engineer Contact Phone (907) 265-6093 Authorized Signature Date: Form 10-404 Revised 4/2017 �� RBDMS.I*JJUN 2 8 2019 Submit Original Only Q 1 B-102 COIL TUBING PATCH DTTMSTJOBTYP SUMMARYOPS 6/7/19 ANNCOMM RIH, TAG TOP OF SBE @ 7623' CTMD, 7630' RKB FOR DEPTH CORRECTION, PUH 780', STOP, PAINT WHITE FLAG @ 6849.8' RKB, THIS WILL BE ARE CUT AT SURFACE FLAG. LAID IN 72 BBL'S OF 9.2 PPG CORR, INH, BRINE FOLLOWED WITH 45 BBLS OF DIESEL FOR FREEZE PROTECT. JOB IN PROGRESS. 6/8/19 ANNCOMM RIH WITH BONDED SEAL'S ON BOTTOM OF COIL RIH 50' PAST FLAG, PU TO FLAG AT 6855' CTMD, SET SLIP/PIPES ON BOP'S, HOT TAP COIL, CUT COIL AT SURFACE, MAKE UP CC ON STUB STICKING OUT OF WELL, MAKE UP CC ON END OF COIL, PULL TEST TO 30K, GO TO WELL ATTACH LOWER CC TO UPPER CC. PULL TEST LOWER CC TO 30K, BREAK CONNECTORS, MAKE UP UPPER PACKER ASSEMBLY, GO TO WELL MAKE UP CONNECTORS. STRIP BACK DOWN TO ATTACH LUBRICATOR. OPEN SLIPS ON BOP'S, RIH SET UPPER PACKER @780' RKB. LEAVING A TOTAL OF 6824' OF COIL IN THE HOLE. JOB COMPLETE. 6/9/19 ANNCOMM (AC EVAL) POST PATCH MITIA PASSED TO 2500 PSI. 6/10/19 ANNCOMM BRUSH n' FLUSHED DB NIPPLE @ 524' RKB; SET 3.812" DB LOCK W/ 4.5" A-1 INJ VALVE (1.18" BEAN) @ 524' RKB; OBTAIN GOOD CLOSURE TEST. JOB COMPLETE. 6/16/19 ANNCOMM (SW) BRIAN BIXBY MITIA PASSED TO 2400 PSI. KUP INJ WELLNAME 1B-102 WELLBORE 1B-102 Well Attributes Max Angle & MD TD ''I,�� Fwrp Name We lI APP W¢Ilbo,e 4lNui ncl rt III A.Mo MR.) Ani UtC. IWESTEAK IMOA2316700 IIN.1 ,11 t2 nate lanae NONE 1618$. Yffi'N194',1DW PM Last Tag Vxtrsla•Jr„epc (srnnp Anosation aepq lM(01 Entl Bah Wellbore 1 LasI MOG By ........_.................... --- .... ......... ..__. _-_............._._ Last Tag: 1B-102 IgBRUi HPIBGER. ,j Last Rev Reason Annohtkn End Base I WNlbare Lasa Motl By Rev Reason Installed A-1 lnjeBBon Valve 611612619 I D-102 zembael Casing Strings CONBucTonimalu.a I Calling Desnisn" Bo (In) tram) TovMKB) sporom MrcB) Ser Bepm H,GL.. WBLen B. Grace TOP Testae CONDUCTOR 16 15.06 280 148.0 1486 62.50 H40 WELDED BRAVELSWBLINER: 3l6 1 Casing 0eacriWv, Go B.) IIHG Top Me) .Moth IM1K01 6""PIn ITVDI... WbLm 6... Grade Ti GRAVEL SCAB LINER 1338 12.41 274 520.9 S1Z5 68.00 L-80 BTC NIPPLE; v21.E wuRlN.mn vak aaD Casing Dexcriptian oo (In) to in) Tap BMB) $N 000111 (XK01 Bet CeCN(TVBI... WNRn II... Grade TRP Theater SURFACE OSIS 8.I 26.9 J795.9 3,653.2 40.00 L40 BTC Gaxinp Ckwnpaon OD (in) mlm) TIPI-01 BH Dtpm 1-51 BN URPM ITVo1...-Len B. Wase Top Tlvtae BLOTTED LINER 512 4.95 ],fi200 14,0364 3,7A.0 15.50 L$0 HYDRIL 511 al UPPER PKR (ME): Ned. Liner lie}alle Top (CBS) To Nominal lr plrvo,607 Topindr) I@mres (qm sin) CAS uET-. BEE..e ].620.0 3,80). 74A PACKER BAKER ZXP PACKER )490 "a" Ad ],633] 3, 112 7476 NIPPLE RS NIPPLE 5.188 TUBING LEAK SWR ],636.1 3611.8 74.A HANGER BAKER FLEX LOCK HYDE. LINER HANGER 6290 TDmgo tFAKas9x.o 7,6426 3614.9 1 ]4.80 SBR BAKER CASING R1.1 BORE RECEPTgCLE 4750 TUBING LEAK 6 715 01 Tubing Strings NIPPLEIZ3fa.1 BepM OepM 1TVr11-��WIIIpY6 Grace Top Cannmibn Tubing oemnplion Slnnp Me... IDfn) ToP (1IXB) 1510 TUBING 4112 J.96 22.2 ],660.8 3,6183 1260 L-80 NSCT Completion Details Top lrvD) Too I lrvommal TOpdNi MKB) IT Fail Co. B18n) SEA -Rion"... PATCH -MR PM (ME), 22.2 2 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 523.] 5202 12.99 NIPPLE CAMCO 3.812 DB NIPPLE 3.Bt2 T,e44.o ],313.1 3,518.1 71 15 NIPPLE AM J50G6NI P- 3150 7,636.6 36120 7477 SEAL ABBY BAKER GBH -22 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, Rah, etc.) SURVVDE.MB7.7al Top TVD) Topinil Tap Plugs) Me) (°I Dee Com Run Dees Win) 523.0 519.5 12.99 A-1 Injection 3812'DBLockw/A-11njMion Valve(1.18"Bean) 611012019 1.180 Valve )80.0 )693 14.96 PATCH- 5"PARA ON II A P I, DIFFERENTIAL 682019 2.000 UPPER PKR RATING 7200# SHEAR RELEASE (ME) 780.5 7698 1497 Patch HANG OFF X03.7Z 00. IN"ID,.41') (SEALED 6( 12019 1.6211 TUBING BWIVEL 331"OD, 1.93- ID, 1,72) (EXTERNAL CC 2SIF OD, 1.66- ID, 1.67) (2" COIL .190' WALL THICKNESS 162" ID 6,284) ( EXTERNAL CC 2.88" OD, 1.61D ID, 1.67) (XO 27" OS, 1.63' ID, .62) (BLANK PUP 2.063" 00, 1.62F ii 935) (XO 2.875' O1 ID, .71.1(LOCATOR ASSEMBLY 2.88" OD, 1.92' ID, .34') ( SPACER TUBE ASSEMBLY Eian', ean.o 2.67' OS, 1.92' ID, .347 ( SEAL BORE EXTENSION 3.5" OD, 2.888" ID, 10.29) ( BONDED SEAL UNIT ASSEMBLY 4 OF THEM 2.6118" OD,1.92" ID, 1) ( HALF MULE SHOE 2.67" OD,1.92' IDi (XO 3.S OD, 1.98" ID, 32) (45" ANCHOR CATCH SEAL ASSEMBLY 3.65" CO. 1.98" D_41') 5,6540 2,9]4] 71.30 TUBING LEAK SUSPECTED TUBING LEAK 1102018 3.990 5,6920 298)1 ]0.69 TUBINGLEAK SUSPECTED TUBING LEAK 1102018 =9 5,715.0 2,994.] 70.33 TUBINGLEAK TUBINGLEAK CONFIRMED BY LDL 32]12016 3.990 C. s.: meso got CMT Ralahan 104as.0 ],6440 3,6139 ]4.79 PATO - WR PKR(ME) 4- N 1 NAND DUAL 12 BARRIER BLOW OUT PLUG SET TO SHEAR AT 31M PSI DP •""-"• BLOW OUT PLUGS HAVE BEEN 512212019 1250 SHEARED"""^'"'" APERN 1a.52i.OAQUB.B� 9,2820 3,699.1 91.91 Fish Bras64.5"PRS pan retainer. sligh6y larger Man paper 1 1 1 3600 ,.;,....a Nin brass ba1M. 8 10,4358 3,717 5 86 33 MITRaWmer SET CEMENT RETAINER 412912009 4.580 10,608.0 3,727.6 86.66 PLUG 3.5" TTS IBP 4127/2009 0000 IPERE,].BD.613WOa Perforations &, Slots Bhot Top(Itl{B) Btm IXNB) Top Irv.) MKBt Ber"D) (We) LinkM Eone date Ben Isnnhln ) Type Com 7.923.0 13,9480 36845 3,769. ,W 811411 WU BEEF 5.5"linerwun. Wx . "L WS B,18-102 slots, 208 Sit w13' of blank pipe on each end of 40 -joint; 10,523.0 10,5280 ]7a75 3,722. WS 418-102 412812009 5.0 APERF CEMENT OFF 412912009 Cement Squeezes TOP(rvD) Bim lrvW fop (W<el eMn 111rce1 InrcBl BIKE) Des sMn Dare CRm t0A350 10,6080 37125 3,72]6 Cemem SOZ 4292009 24 MIS pumped Ini retainer Mandrel Inserts :n Topgets) NJ TOpINo) (aKe) Made MWeI 0j S. VaM Lahl, Typt PorIBW (In) Tied Run apse gun Oa4 Com 1 ,5248 2,295.5 AMCO MMG 1 GAS LIFT DMY RK 0000 0.0 911812003 300 Notes: General & Safety Enc oeh Anmdron 8131/2003 NOTE. GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE, NO PROD CSG fl820 NOTE'. View Schematic wl Alaska SMematic. SLOTTED LINER; 7.620 1a al K2ct l P - I&z Regg, James B (CED) P1'�N 2�31ZZo From: NSK West Salk Prod Engr <n1638@conocophillips.com> Sent: Monday, June 24, 2019 3:04 PM 2�1 , To: Regg, James B (CED) Cc: Fox, Pete B; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1 &2 Ops Supt Subject: LPP/SSV Returned to Service on CPAI Well 1 B-102 Jim, The low pressure pilot (LPP) on well 1B-102 (PTD# 203-122) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 6/24/2019, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 780 BWPD at 625 psi wellhead pressure. The LPP had been defeated on 6/11/2019 after the well was returned to service after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, July I, 2019 Jim Regg I P.I. Supervisor { S It� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IB -102 FROM: Brian Bixby KUPARUK RIV U WSAK IB -102 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprvls—rz— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IB -102 API Well Number 50-029-23167-00-00 Inspector Name: Brian Bixby Permit Number: 203-122-0 Inspection Date: 6/16/2019 Insp Num: MitBDB190619113947 Rel Insp Num: Monday, July I, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB -102 - Type lnj w. TVD 3608 Tubing 424 425 17 -_421 - PTD zzo Type Test I leao 2400 2355 _ zsso __–. B Pumped: 8BL Returned 16OABBI Interval OTHER P/F I' —14 Notes: MITIA Post Coil Patch Job Sundry 319-019. This is a monobore completion so there is no OA ✓ Monday, July I, 2019 Page 1 of I Jim, The low pressure pilot (LPP) on well 1B-102 (PTD# 203-122) was defeated today, 6/11/2019, after the well was brought online after an extended shut-in period. The well is currently injecting at 542 BWPD with a wellhead pressure of 212 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001" Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 K2c1 I i�- � av 703Iuo Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> 6�I z/o Sent: Tuesday, June 11, 2019 1:59 PM ! To: Regg, James B (CED) Cc: Fox, Pete B; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Mowrey, Andrew F Subject: LPP/SSV Defeated on CPAI Well 1B-102 on 6/11/2019 Jim, The low pressure pilot (LPP) on well 1B-102 (PTD# 203-122) was defeated today, 6/11/2019, after the well was brought online after an extended shut-in period. The well is currently injecting at 542 BWPD with a wellhead pressure of 212 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001" Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 WELL LOG TRANSMITTAL #905255170 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Leak Detect Log: 1B-102 FEB 0 5 2019 Run Date: 11/7/2018 AO G CC 203122 30333 January 8, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-102 Digital Data in LAS format, Digital Log file 50-029-23167-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: ozw# y Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Tyson Wiese Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1B-102 Permit to Drill Number: 203-122 Sundry Number: 319-019 Dear Mr. Wiese: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 3d day of January, 2019. 12BDMS<,DjFB ° 1 "" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ]AN 16 2019 t� GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Progmm❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil Tubing Patch❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli S Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service [2, • 203-122 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23167-00_--Xll 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 B-102 ' Will planned perforations require a spacing exception? Yes ❑ No [21 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25639, ADL 25648, ADL 25649 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): n 14,044' - 3,778' - 10435 3717 1310psi 10608 9287 Casing Length Size MD TVD Burst Collapse Conductor 120' 16" 148' 148' Surface 7,769' 9 518 7,796' 3,653' Scab Liner 494' 133/8 521' 517' Slotted Liner 6,416' 51/2 1 14,036' 3,777' Perforation Depth MD (it) jPerforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7923-13048,10523-10528 3684.3769, 3723.3723 4.500" L40 7,661' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER ZXP PACKER 7620 MD and 3608 TVD SSSV: = NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 17 ' 14. Estimated Date for 2/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ [] ' WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Tyson Wiese Contact Name: Tyson Wiese Authorized Title: Staff. Wells Engineer Contact Email: Tyson.M.Wiese@cop.com (, +] �� Contact Phone: (907) 265093 Authorized Signature: Date V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,.,,/ Plug Integrity E] SOP Test E] Mechanical Integrity Test LT Location Clearance ❑ Other: f Post Initial Injection MIT Req'd? Yes YJ No ❑ �p Spacing Exception Required? Yes ❑ No d Subsequent Form Required: !0 — 4-0 APPROVED BY Approved by: 412f COMMISSIONER THE COMMISSION Date: V77- 11041117 'O?Form 10-403 Revised 4/2017 �r "'UUUU 0 R i G I NAL RBDMS SEB 0 12019 Submit Form and Attachmen s in Duplicate it ��1e 7Z 7 77 t�q. Approved application is valid for 12 months from the date of approval. 1 B-102 Injection String Install Permit to Drill #: 203-122 The objective of the proposed 113-102 Coiled Tubing Injection String is to isolate the multiple known tubing leaks (5,654', 5,692', 5,715'), as well as sections of the tubing string that exhibit high levels of internal wall loss and pitting due to low side corrosion. This CT injection string will allow the well to be returned to injection service and provide offset injection support to 1 B-101 and 1 C-178, both of which are at risk of being shut-in due to lack of support and MBE risk. CT Injection String Summary: Slickline: (Obtain Updated SBHP) RIH with gauges and obtain updated SBHP. Perform 30 minutes station stop as deep as possible. Note: Last SBHP data was gathered on 4/21/2016. Coil Tubing: (Pre -Patch F&S) RIH and perform F&S to as deep as possible within the 5 1/2" liner, or down to the cement retainer @ 10,435' KB. Note: Last liner drift was performed on 1/9/2018. Digital Slickline (or E -line) / LRS: (B&F / Set Lower Packer / C -MIT) 1. RIH and B&F the seal assembly from 7,637 - 7,661' KB, targeting CT patch packer set depths as well as any tight spots (ID restrictions) identified on recent caliper log. 2. RIH with lower 3.66" OD injection string packer (with 3,000 psi shear out plug and 1 '/4" nipple profile). Set the lower packer assembly @ approx. 7,644' KB (8' into the 19.6' seal assembly just above the 5'/z" liner). Note: 2019 Caliper log indicated that the seal assembly is in better condition than the 4 %" tubing above. Do not exceed 1,000 psi injection pressure if pump assist is needed. 3. Perform C -MIT (TxIA) to 2,000 psi to test lower packer. Bleed Tubing and IA to 0 psi. Note: Do not exceed 2,000 psi. With a Res. Press. of 1,344 psi and the well loaded with 6.8# diesel, the differential pressure at the plug during C -MIT is approx. 1, 934 psi. 4. RIH with Snap Latch / PBR assembly and latch into lower packer @ approx. 7,644' KB. RDMO. Ready for Injection String Install. TW 2" Coil Tubina: (Install 2" Coiled Tubing Injection String) 1. Ensure that the AOGCC 10-403 Sundry has been approved prior to scheduling the work. 2. Spool on a 2" Coil string with at least 8,500' of 0.190" wall pipe. 3. MU pump through tag BHA (no-go centralizer w/ DJN) to tag the top of the PBR. RIH and lightly tag the top of the PBR @ approx. 7,634' KB. 4. PU to neutral weight and Paint 1st Flag @ reel. Record hanging and PU weight. 5. Circulate the well over to 10.7# Corrosion Inhibited Brine (MI recipe) and Diesel Freeze Protect. Taking T x CT backside returns, pump the following: a. 29 bbls of diesel (Backside FP) b. 72 bbls of 10.7# Corr. Inh. Brine (loads backside and Coil) c. 7 bbls diesel Note: Max backside (WH) pressure is 1,000 psi during circ. out to prevent mitigate potential to shear out downhole shear out plug. PUH to x,xxx' KB (A length between Tag BHA and Seal Assembly/Pup Joint BHA — Length of Upper Packer assembly — 795' KB), and Paint Flag #2 @ reel. This 2nd flag will be used to determine where to perform the coil cut at surface. 7. POOH and MU the 10' Seal Assembly with 10' pup joint above. 8. RIH to Flag #2. Record WHP, CT hanging weight, and RIH/PU weights. 9. Close lower BOP pipe/slip rams. Perform pull test and 30 min no -flow test. Repeat the for the upper pipe/slip rams. Note: Barriers: 1.) KWF 2.) Shear out Plug in lower packer. 10. With Tubing, IA, and CT pressure bled to 0 psi, break riser at the quick test sub and raise the injector to create the work window. 11. Perform coil cut. Install and PT the CTC on end of coil protruding up through the BOP's. 12. On the back deck of the Coil unit, MU/PT the CTC, and MU the Upper Packer assembly with setting tools and swivel. 13. Lift the Upper Packer Assembly into the lubricator. Position the injector/lubricator over the well, and MU the upper assembly to the CTC protruding from the well. 14. Pull test the assembly to 25,000# (or a minimum of 5,000# over the PU weight recorded during deeper PBR tag run), against the BOP slip rams. 15. MU the riser, and pressure test lubricator using QTS. TW 16. Open both sets of pipe/slip rams. Once weights and pressures have stabilized, RIH @ 30 FPM. When close, slow to 10 FPM and sting seals into/no-go out on the PBR assembly @ approx. 7,634' KB. Note: Do not circulate or pump while RIH, as inhibited brine and diesel (KWF) was circulated in previously. 17. Once stung in, shut in the choke, and Perform a C -MIT (T x CT annulus) to 2,000 psi. Record Results. Note: This will provide confirmation that we are successfully stung into the PBR and have integrity. This will also confirm that the anchor latch has integrity. 18. PU to neutral weight and prepare to set the Upper Packer. 19. Set the Upper Packer per Tool Rep. instructions @ approx. 795' KB, following the recommended practices. Drop ball, bring pump online, and pressure up as needed. 20. After setting tool has released, set down 1,000# to confirm the packer is set and holding. 21. Perform MIT -T to 2,000 psi (against the 3,000 psi shear disc in the lower packer). 22. Pressure up to 3,000 psi (+/-) to shear the disc in the lower packer. 23. RDMO. Turn well over to Operations. IIM Current Schematic: KUP INJ WELLNAME 7B-102 WELLBORE 16-102 Conoc&hilllps a0 Mbinubf as wJ.P d AlaKk.IOC. w P ww s 1 n WEST SAK $CD292316JC0 INJ'me reru $l3 12,111}816 lO.D1i.O KB1 K2BiPpm1 II- .d on68tl mr SSSV'NONE WO' 35.DD BIl5ROD3 D last Tag vwwy x/Isnwc lmnwl AmodBm SNIP- o gntnKel mwrLas1 tCnpuCIOR ID.oIUO c2xv¢i %TJBL NwAi[' u>_7 w u.l. s.sl..e wwiF: 1111 11 s/-i.L A9B v. i.OBB S16eGE, Ma/.7868 1 dT6oc IDe3epnlm CxT M1rreer. lnufn A%W:1e.en.ola9700-, PLuc �A.. np.Ie', >.u4.6 �;M.0 6LOTlEDLeK0.1i.61Y LastRev Reason EM DeY wWleene Rev B on: ImbllaO ]. S DBP LONt 0.5' GBpil-Sun w/Prong. 8 1 JMnsenbe ng L(1VD1 i LLL FB } r ..q DeT.. (Inl II . 1. IIIKBI 0.MIldB1 sn 0.M U... Green T CONDUCTOR 16 15 D6 20.0 5<a0 1.18.0 62.50 HNO WELDED vsq ovecryeon COOnI to (Inl g111KB1 0.MIIeLB1 Y10.W�RYo1... nn ll...TPPT GMVEL SCAB LINER 1;318 1291 2S< S2n9 51]_5 60.Op L-60 BTC NYe --II PP -"e- DD PnI In Onl Tq De(BI BCWMInKBI BM WM (TVOI--wtllen ll... GIMe Tep Twee! SURFACE 958 EB3 28.9 ].]95.9 3.6$3.2 IO DO L -8D BTC LLKu R CO llnl I g 1eKe1 w J-1 0^ DeM RYDI- - 'TEP ll... SLOTTED LINER sl/2 •95 ]62D.0 1603.A ],]]SO 1550 L-. NYDRIL 511 Liner DAWN g1eKB1 eP llwllrxer Y.. <3 iwYi 1IS T ~ 7,6200 38076 7473 PACKER BAKER SJtP PACKER J.690 7.6253 7 3. 11.2 NIPPLE RS NIPPL J.636.1 3.611,8 74 J] RANGER BAKER FLEK LOCK HYDE. LINER HANGER 6.290 7,6176 ]6149 7<.. 58R BAKER CASING 5 =K.PE CJ50 Tubnq BEMga anpnm svNp K.... O mN W mrel s« Dplx m_ m mol L m Imlil ron 4 1UBING 1/2 A. 222 76608 36183 126D L,60 NSCT cavRiplati.. D ts 1p(TVD, I NNKL _ w p22 Iwiel n('Irc w0^I OCO 1UWGERw VETCO GRAY TUBING NANGER� P. SAP s23.72D.2 12.83 NI E 2 NIPPLE 3812 7.313.1 3,$161 71.15 NIPPLE CAMCO 3.750 D8 NIPPLE 3.750 l i1NY2O181nsd.. 311 DBP.Lcc k.pYp pu]y9.S GLal flop pmrg OAL-aP .6 6 361 .0 7,i EALPS Y BAKER GBFFY25EAJL ASSEMBLY '. OWar In Nolo IlaBle103e raVlaeaDN pMsga, valves, ValnPs. flan. st�I T mn De. Dm eP O.KB TIKZ n T IO J35.0 ].]175 86.10 CMTRWirer SET CEMENT RETAINER if292C09 n.590 10.6980 ].]2JG 8666 PWG 35'77$ IBP �7/2W9 Mrforalbns 8 s1o[s 11-1 T- rolw[N Bun lDNel 1 DaLe> 1 u.idaiere pd IMI TJw Cw 79230 139480 3880.5 3.J69.2 WSO.WSC, WE8-102 8i1{2p03 99U (PERE SSS urn M. 02nNx1.SL x .208 abisfi w(iA, nleMpipe aneaM mW of AO' jdnl. 1D523.D 1D.52B0 3.]22.J 3.7229 WS C.16102 V28T2009 SO APER, CEMENT OF E 429/2009 DaaRea' ap 01Ke1 BI.S.e1 T(nKBI ., T10A350 Ben B DI 1 1 Dw s D C 10806.0 3.J1].5 3�37fi Ceman1502 42YIW9 24 nD1[pun�Pee lnloupn nblre/ ManETel IMOEIn -I-W T'DI TlnKel co lYl P 0^I IAP, _ 3.5290 2.295.5 CAMMG I12 MCO GAS LIFT OMY O.OPo O 9/1n82003 300 xMw: Buural l Beauty 8131 RON NOTE: GPAVEL SCAB LINERET TO LD BACK GRAL FALLING INTO WELLBORE NO PROD CSG B9'A l0 NOTE: Vlev Shcenutic wl AlaYa 5tla1M1[9D Proposed Schematic: 1B-102 CT Injection String Well Diagram ConocoPhillips Alaska Cool,=,. IT 62.50# HAD 148' KB7TVD Gravel 8r"b Lner: 13 318' 68# L-80, OTC 521' KB! 518' TVD Production Tubina 4 V. 12 60# L-80 NSCT 7.660' KB 13.618' ND CT Inlettlon Suino 2' OD • 0.190' all Coe T,lbng 795' KB - 7.65a KB .e.✓9rn Caslm 9 "'409 L-80 BTC 1 1 1 1 7.796'KB 11653'TVD 1 1 1 I l l l l l l IIIIIII 4-1/2" Vetco Gray Tubing Hanger 1111111 1111111 -FIT-1 -FI—F slotted uner: 15.50# L40 Hybll 511 3 7 -62W -UAW KB I I I I I I I TW 10 Item Depth - tops )KB) 1 4-1/2" Vetco Gray Tubing Hanger 22' 2 Camco "DB" Nipple (3.875" No -Go) 524' 3 1.5" MMG with Dummy Valve 3,525' 4 Camco "DB" Nipple (3.75" No -Go) 7,313- 5 14 1/2" Tubing GBH -22 Seal Assembly 7,641' 6 5 1/2" Cement Retainer in Slotted Liner 10,435' 7 3.76" OD PIIP (Inj. String Upper Packer) 795' 8 10' PBR Seal Assembly w/ Anchor Latch 7,634' 9 3.66" OD PIIP (Inj String Lower Packer) 7,644- 10 Shear out Plug w/ 1.25" Nipple Profile 7,646' 10 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99SIS (907) 273-1700main (907)273-4760fax Delivered to: rt AOGCC •. \ ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 +wft Anchorage, AK 99501 20 1071 i i TRANSMITTALDATE TRANSMITTAL4 WELL NAME 16-102 ,. # 50.029-23167-00 ORDERSERVICE EOSH•00015 FIELD NAME DESCRIPTION KUPARUK RIVER WL DELIVERABLE DESCRIPTION Caliper Vert DATA FINAL FIELD DATE 1 -Jan -19 r 1 U-10 1H-119 3H -31A 50-029-23010-00 50-029-23591-00 50-103-20205-01 EOSH-00017 EOSH-00018 EOSH-00019 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL Caliper (PROF LDL FINAL FIELD FINAL FIELD FINAL FIELD 17Jan-19 18 -Jan -19 19 -Jan -19 1 1 1 3M-19 1H-116 1C-117 50-029-21737-00 50-029-23594-00 50-029.23027.00 EOSH-00020 EOSH-00021 EOSH-00022 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL LDL (PROF RST-WFL FINAL FIELD FINAL FIELD FINAL FIELD 20 -Jan -19 21 -Jan -19 22 -Jan -19 1 1 1 RE IAN 3 7 t j ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X 4( package have been verified to match the media noted above. P nt Signature Date specific content ofthe CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please retusign/scan and email a copy t Sc lumberger and OPAL point. AlaskaPTSP-rintCenter@slb.com m Tom Osterkarn2a�conocoohil los com SLB Auditor - Schlumberger -Private C •,�. 30 °�5�p,� sch �b�3�70�3 w�te J �ne s 30 �ti/ yediipd 2v pn�fr �yC/i4 o m4 d 010 Co�pBryY,V , cO cOo 1 on FieldN 4'ellAl �ophflll D$te to e. x Vi e: "J -,(o 41ask, nc 4'011 aeev. 17,j R& Sen'tce��. SO 029 `�N2p19 erg. 2301 EOSy 0.00 00017 Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician II r Alaska Oil & Gas Conservation Commision ` * 333 W. 7th Ave, Suite 100 —%j Anchorage, AK 99501 Lp31LL I TRANSMITTAL DATE TRANSMITTAL# WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's ® i N:.� i r is50-029-20266-00 Omni Traitt I Receipt �X t A Transmittal Receipt signature confirms that a package (box, / / envelope, etc.) has been received and the contents of the v t package have been verified to match the media noted above. Printdame- Sig nat re Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy tolumberger and OPAL point. Schlumberger -Private THE STATE ALASKA GOVERNOR BILL WALKER Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1B-102 Permit to Drill Number: 203-122 Sundry Number: 318-475 Dear Mr. Byrne: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Mainz 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this LS day of October, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Qts lot 25t /8 1. Type of Request: Abandon Ll Plug Perforations Ll Fracture Stimulate Li Repair Wellto Zb' Jib Operations shutdown Ll Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing patch❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑' 203-122 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 500292316700-oD 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No Q KRU IB -102 9. Property Designation (Lease Number): / 10. Field/Pool(s): ADL0025639 ADL00256461ADL0025649 I Kuparuk River Field / West Sak Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 14,044' 3,778' 10,435' 3717' Casing Length Size MD ND Burst Collapse Structural Conductor 120' 16" 148' Surface 7,769' 12" 7,796' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (k): 7923'- 13,948' 3685' - 3769' 4.500" L-80 7,637' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER - SHALLOW PATCH LOWER PACKER (SER #CPP45001, OD -3.756", ID -2", MD= 5738 ND= 3003 OAL-4.88') MD= 5946 ND= 3069 12. Attachments: Proposal Summary Q Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigmphic ❑ Development ❑ Service ❑✓ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10-26-18 OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jan Byrne Contact Name: Jan Byrne / Kelly Lyons Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: Date: 10-21-18 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r 315- I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [� Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes SN' ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY C Approved by: COMMISSIONER THE COMMISSION Date: i i% ZS ll I. C%� �& V7L'°'z¢"� URIGINAL ,a 1�ror 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. �b ' V' Submit Form and �o flA achments in Duplicate l ft-4,wi-dib ConoeoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 21, 2018 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 113-102 (PTD 203-122). The request is for approval to set a tubing patch extension to regain tubing integrity. If you need additional information, please contact myself or Kelly Lyons at 659-7224. Regards, Jan e fyrne Well Integrity Supervisor IB -102 DESCRIPTION SUMMARY IB -102 was reported fora failed MITIA on 10-14-18. The well was shut in and freeze protected. Slickline ;diagnostics indicate that the upper patch is the source of the leak. This proposal is to install a new upper :section of the upper patch with an extension. :1. RIH with 4.5", —37.5' (an extension of 3.3' over the previous upper patch assembly) upper patch assembly ;and sting into the existing lower packer at 5738'. :2. Perform MITIA. :3. Bring well on injection and allow to stabilize. :4. Perform SW MITIA. ;5. Submitt 10-404. ------------------------------------------------------------------------------------------------------ •-------------------------- KUP INJ WELLNAME 1B-102 WELLBORE 18-102 Conwi Attributes Max Angle&MD TO f"IIIIIIpS%01REdN...Well Alaska, Irlc.WEST TSA WeIISme MI11V WgIWe SMus('1 12,113.1 h,044.0 O) SAK 500292316)00 INJ 5.13 1$113.16 18044.0 SSSVeNONE H24Ippm) Gate Last WO7 les"Dale 35,00 ep 81152003 Daze Is102n0rmma87or 17AM Last Tag Inr9Namercnnwp MnManun DepMIRK01 1 End bale I Geellmre I Ia:t Mod By .. __.. last Tag: I 1&102 junnodbor IUNGER:2z2 Last Rev Reason M5 End Data WeI1Wre uBy Rev Reason: Pulled InIeC6on Valve 8 Upper PiSpettr Pipe Assembly Urbl 1011912018 18-102 xemba, j do Casing Strings corvOVcroR. Za.o-laeo Casing Geacnplion oo pnl to(l.) ToPlnleel Set Depth(ME) SM Depth IND-_ VALen p... Grade Top Thread CONDUCTOR 16 15.06 28.0 148.0 1480 fi2.50 H-00 WELDED GMVEL S<AB LINER: P.a s...a Casing Dccrl,,-OOlin) IDlin) Top(hN01 9albeoM MET Ser Oeplh GBM) WOl p... GP., Top Thrall GRAVEL SCAB LINER 133/8 12.41 D.4 520.9 51].5 68.00 L40 GRBTC NI<PLE: R3.] CUIrq DeunrNm ODllnl IV (an) Tap lnKBl Set DeplM1 (hK81 Sal Depm (TVD-.. "'a en O... G,nae Topm,eaa SURFACE 95/8 883 26.9 ].]95.9 3,653.2 40.00 L-80 BTC Casing Des c,lplion on (in) IV (in) I NP Mel Set -as,, (M1KRI Sel beplF liVOI.. Wuren 6... G,aae Top Th -d BLOTTED LINER 51/2 495 ],6200 14,036.4 3]P.0 15.50 L-80 HYDRIL 511 GAS una.ss+e Liner Details N as, to PACKER: S]3do Top (PIKE) Top(ND (kNB iop nU l') Item Ges Com lin) 7,6200 3.60].6 7473 PACKER BAKER ZXP PACKER 7490 PATCH 5g30a 7,6337 3.611.2 ]47fi NIPPLE RS NIPPLE SAM PACKER,$.8 ..6 7,,636.1 3,611.8 ]4. ] -HARI BAKE R FLEX LOCK HYDR. LINER HANGER 6.290 NIPPLE:].31al 7,647.6 3614.9 ]d. 0 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 Tubi. Strings mnmg Decenplton sump M.... mltnl rop(nue) sal Depm lx_sel Depm lrvb (... wlpbnp G,aae Top eonr,ecrwn TUBING 4112 3.50 222 ],660.8 3,6183 1260 L-80 NSCT Completion Details gEALASST: ],638.6 Top LID) Top Ind Nominal rap(flKel (XKB) (°I Ihm Dea Co. 10(a.) 22.2 22,2 0.00 HANGER V RAY TUBING HANGER 4.500 5237 520.2 12.99 NIPPLE BAMCO DB IANDING NIPPLE w/3 a)S NO GO PROFILE 3.812 ]313.1 3,516.1 I 71.15 NIPPLE CAMCO DB NO GO NIPPLE w/375"PROFILE3.]50 SURFACE26.a].MB- 76366 3,612.0 ]477 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY 3.500 Other In Hale (Wireline retrievable plugs, Valves, PURI S, Fish, etc.( top HVol rnpma Topgo.) IMP.) ('I Dee Co. Run Date IOltnl 5738.0 3,002.5 69.97 PACKER SHALLOW PATCH LOWER PACKER (SER /20-2016 2000 9CPP45001, 00.3756",10.2", 01 5,920.0 SENT. )223 PATCH D PPATCH UPPER ABBY (4112- PIIP i6ERk 4/191201 1.995 CPP4500fi1, SPACER PIPE, ANCHOR LATCH SEAL -SER %CPAL45002j; OD -3.65", ID -1.9995", DAL - 27.211 5,946.0 3,068.0 72.16 PACKER 4 VT Pup FOR DEEP PATCH£ 5946'RKB MID 4/18(2016 2.OW ELEMENT)(SERIAL MCPP45004, OAL-4.88') 10,435.0 3,)17.5 86.63 CMT Retainer SET CEMENT RETAINER 4292009 4.580 ID,608.0 3.T1).6 86.66 PLUG 3.5 -TTS IBP 6272009 0.000 Perforations & Slots shot Den Top nTm) Bmn(rvDl lehmsm rap(RKB) BlmiflKBl (KKB) (IIKS) Linked ZOne DaM 1 Type Co. 7,923.0 13,940.0 3,fi84.5 3,7693 WS D. AS C. 81142003 99.0 -PERF 5.5"liner wiM.02'Wx1.5"L WS B,1&102 51.15, 208 51015-8 w,3' of blank pipe on each end of 40 joint; CMT5Oz: lo.dua.KB 10.5230 to.528D 3,722.7 3,722.9 AS C. 18-102 4282009 5.0 1 APERF ICEMENT OFF 4292009 C.T Rarearar,,.acs.. Cement Squeezes op RVD) TIP. elm P"i APERFI.S]]P10,S2aa- Top(tIKS) Bfm l(LKa) (M1Na) (KKR) Dee Slant bate Com 10,435.0 10,608.0 371].5 3111.fi 1emenl1O2 Isi 124 bbl$ pumped through retainer PLUG, lo,mao Mandrel Inserts St au IPERF:].M3 13,8 0- N Top (KKB) Top (WDC (flKe) Meke Model 01)6 Sery Make. Type Catch Type Port St- (in) TRO Run (psp Run... Com 1 3.524.8 2,2955 CAMCO MMG 112 GAS UFT DMY RK 0.000 0.0 911&2003 3:Do Notes: General & Safety Em Dale Annotation &31/2003 NOTE: GRAVEL SCAB LINER SET TO HOLO BACK GRAVEL FALLING INTO WELLBORE; NO PROD CSG 81612010 NOTE:VIew SCM1ematiow/Alaska SCMGV i.9.0 SLOTTED"NE0.].a2.P 11.. 4 Cii • • Isi 3 _c ,_ xOabc Lp 0 cc a, � � ° � o 4- -0 0 (� C7NZ o u N +O+ > 1- Y a C O C >. O Q Y @ a-+ co .0 :.a IIII a0� $ t+.o O ano 7 t U = Q 7 a0 co co CO Co W +' a) 0 CT m f.14 (.7 C9 E +, -c ° n 0 C C C C C ++ L J 10 13 @ @ R 7 . 0 L (B an Wd -) 7 7 7 9 2 1n Hr' 4 1n 1n cocoO 0 @ *'' L C N z g U D 10 O U Z a) > E -0 a) +-' co O ali. +� u co N p „, u ❑ ❑ ❑ ❑ ❑ ❑ C L Q) 0 L J J J J J J Op c ;- U 0 W W W W W W LL LL LL LL LL LL 4_, a) a) a) -C J J J J J J a Q > L 4) ZZZZZZ• u rro0 o a) L O ...v. ` LL LL LL LL LL LL CC L (11 C > C EkL +C-+ a-+ > C (1) N Q- U > ... U _ ' O. c O 10 403 13 0 I— a) ,C U L GF > U a) a.. O ~ c co a 0 0 5: Q a� a c a V ; R:' y4 LL LL d y LL LL it 1+ C O a' a' Q e a' a' ma a v a a O s 0 U 1.13 S .. U u LLA 1v4 g0 m Z ii) tt 611 dt Ct 14L. p .c' w A. N e+ k.l x Lo W 0 ,- 1 -O 2 al W 'r V _ J O J J O C C Lu U o 11".-I'pli:f � 43t cc Er m CC CY CC I 0I W W W W W W 3 V 2j a' a' LY LY Wu O. 1/1 Z! Y Y Y Y Y DDD MD Y _ w' Q Q Q Q Q Q >` O a: a a a a a a a 4-''Ci) °, Y Y Y Y Y Y _.� 2 O c CI d o as u LLIOO W � r Ti. rb O N N CD 0 X N c0 c::$ \� O O O O O O N 0 0 0 0 0 0 0 1v Y RIPON 0 W ;n 0 1 0 a LL LL LL C r� >- aa a a 0 z O x Q N \ 11.1.1 —, <C O 0 - 0 0 0 0 C o co 0 0 0 0 az I cr A O M N N M O L ° 1� co M co O M M 0 U N N N N N N N L IR O T M c' O) Q) a) vl p N N O 0 N N i 01 O O '- r O O 0 i 0 0 0 0 0 0 y,, u0 a) rom 000 C N 1n N N 11') In Q v c aa w Q. ,� I I I I I 1 •d co a) Lo I I 1 I 1 I I t I 1 V L z °� a.) 5 y 1L 0 1•1•1 y lY C c U " Q 0 N L C 'O E- 2. a) ri Q N J O O N N t9 E 7 d Yl Z a+ 1]0 r O N r o r0 ++ 1= 1L to v) 2 h. r• F• I- E 10 L a a < O N J _ 4 N N _ m Z Ill (9 N ,--1 vi U ^p ". �.. fC6 c co to i c E L .0 117 (0 0 CM a Lb Q I- a a Q • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j� DATE: Wednesday,May 03,2017 P.I.Supervisor <-.e16 "5 1`(i 7 SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA INC 1B-102 FROM: Lou Laubenstein KUPARUK RIV U WSAK IB-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry l&' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1B-102 API Well Number 50-029-23167-00-00 Inspector Name: Lou Laubenstein Permit Number: 203-122-0 Inspection Date: 4/22/2017 Insp Num: mitLOL170423072606 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1B-102 Type Inj W TVD 3608 Tubing 840 840 840 840 PTD 2031220 Type Test SPT Test psi 1500 - IA 170 1830 - 1755 - 1740 - BBL Pumped: 4.1 - BBL Returned: 4.1 - OA Interval 4YRTST P/F P v Notes: SCANNED AUG 2 4 NIT Wednesday,May 03,2017 Page 1 of 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations - Fracture Stimulate 1 Pull Tubing r Operations shutdown 1-- Performed:Performed. Suspend fl Perforate fl Other Stimulate la Alter Casing Change Approved Program ja- Rug for Redrill - Perforate New Pool nRepair Well 1 Re-enter Susp Well FOther: tbg patches 5 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1- Exploratory E 203-122 3.Address: 6.API Number: Stratigraphic fl Service 17, P. O. Box 100360,Anchorage,Alaska 99510 50-029-23167-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639/25648/25649 KRU WSAK 1B-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,044 feet Plugs(measured) none true vertical 3850 feet Junk(measured) none Effective Depth measured 10435 feet Packer(measured) 7620 true vertical 3716 feet (true vertical) 3608 Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 148 148' SURFACE 7769 9.625 7796 3653' ^C RECEIVED `a' k:, JUN 1 3 X16 MAY 0 9 2016 Perforation depth: Measured depth: 7923'-10435' /,,O 3CC True Vertical Depth: 3684'-3717' �l 4.5" TTS retrievable patch from 5707'-5738' Tubing(size,grade,MD,and TVD) 4.5, L-80, 7661 MD, 3612 TVD 4.5" TTS retrievable patch from 5920'-5946' Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DB LANDING NIPPLE w/3.875 NO GO PROFILE @ 524 MD and 520 TVD VALVE-4.5"A-1 INJECTION VALVE (HSS-166)W/ 1.188"BEAN @ 524 MD and 520 TVD SEAL ASSY-BAKER GBH-22 SEAL ASSEMBLY @ 7637 MD and 3612 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.253) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development Service Stratigraphic E Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL 1 Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ F.7 WAG r GINJ 1 SUSP r SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-218 Contact Kelly Lyons/Brent Rogers Email: n1617@cOnocophillips.com Printed Name ��BBBBrent Rogers Title: Problem Wells Supervisor Signature /�C/ A,f fill / Phone:659-7224 Date May 06,2016 7Y(1 � G(/�--7f jVTL 5//o�//G Form 10-404 Revised 5/2015 i� ."/ `�) RBDMS Li-- MAY 1 0 20tubmit Original Only • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 6, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1B-102 (PTD 203-122). The report is for two tubing patches that were set to repair multiple tubing leaks above the seal assembly as per Sundry 316-218. Following the setting of both patches and stabilized injection was achieved, a passing AOGCC witnessed MITIA was performed. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, /11" Brent Rogers Problem Well Supervisor Attachments • 1E1-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/18/16 DRIFT W/3.75"GAUGE RING,TAGGED PRONG @ 7290' SLM.SAW NO RESTRICTIONS. PULLED 2.75" DBP PLUG W/GAUGES FROM 7313' RKB. RAN 3.5" BLB &3.75"GAUGE RING.B&F'D FROM 5600' SLM TO 6000' SLM.ATTEMPTED SETTING DEEP LOWER PACKER @ 5946' RKB.UNSUCCESSFUL DUE TO SOFTWARE ISSUES. JOB IN PROGRESS... 04/19/16 SET 4 1/2" PIIP FOR DEEP PATCH @ 5946' RKB MID ELEMENT). SET TEST TOOL IN SAME. LRS PERFORMED PASSING CMIT TxIA TO 2000#. PULLED TEST TOOL. SET DEEP PATCH UPPER ASSY @ 5920' RKB (MID ELEMENT). *JOB IN PROGRESS LRS PERFROM CMIT TxIA TO 2000#PRE: 250/200 INITIAL: 2025/1925 4 BBLS TO PRESSURE UP. 15 MIN: 1990/1875 30 MIN: 1980/1870 PASS 04/20/16 SET TEST TOOL IN TOP OF DEEP PATCH @ 5920' RKB. LRS PERFORMED PASSING CMIT TxIA TO 2000#. PULLED TEST TOOL. SET LOWER PACKER FOR SHALLOW PATCH @ 5738' RKB (MID ELEMENT). SET TEST TOOL IN TOP OF PACKER @ 5738' RKB. *JOB IN PROGRESS; ***TEST TOOL LEFT IN HOLE*** . LRS PERFORM CMIT TxIA TO 2000#. PRE: 150/110 INITIAL: 2025/1925 5 BBLS TO PRESSURE UP. 15 MIN: 1975/1890 30 MIN: 1960/1875 PASS 04/21/16 LRS PERFORMED PASSING CMIT TxIA TO 2000#. PULLED TEST TOOL FROM TOP OF PACKER @ 5738' RKB. SET UPPER PATCH ASSY @ 5707' RKB (MID ELEMENT). LRS PERFORM PASSING MIT-IA. SET A-1 INJECTION VALVE IN NIPPLE @ 524' RKB. *JOB COMPLETE. **CMIT pass: preTIO=100/50, initial=2000/1900, 15min=1910/1840, 30min=1900/1825. MITIA pass: preTIO=100/50, initial=110/2000, 15min=110/1950, 30min=110/1930** 04/30/16 STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED)TO 1990 PSI. Initial T/I = 600/1250. IA FL @ SF. Pressured IA to 1990 psi w/ 1.7 bbls diesel. Starting T/I =600/1990. 15 min 171 =600/1950. (-40). 30 min T/I =600/1930. (-20). 45 min T/I =600/1930. (-0). (Passed). LRS bled IA to 1100 psi. Final T/I =600/1100. Summary Two 4.5"TTS retrievable patches were set to repair tubing leaks. The lower patch is set from 5920'-5946' (26'element to element). All testing during the patch setting passed. The upper patch is set from 5707'-5738' (31'element to element). All testing during the patch setting passed. A passing MITIA was achieved prior to bringing the well online and then the well was returned to injection. Once the well stabilized, a passing AOGCC witnessed MITIA was performed. • • r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao@alaska.gov: AOGCC.Inspectors(6 alaska.ciov phoebe.brooks@alaska.gov chris.wallace(S alaska.ciov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/ 1B Pad DATE: 04/30/16 OPERATOR REP: Miller/Sumrall AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1B-102 Type Inj. W TVD 3,608' Tubing 600 600 600 600 600 Interval 0 P.T.D. 2031220 Type test P Test psi 1500 Casing 1,250 1,990 1,950 1,930 1,930 P/F P Notes: MITIA post patch per Sundry 316-218 OA N/A N/A N/A N/A N/A Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F - Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing _ Interval_ P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 1B-102 04-30-16.xls a � �� 2_03-t2.2._ EC • • 21,L� MAY 10 20(6, WELL LOG TRANSMITTAL#903212368 A G .a( ; To: Alaska Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5 K D,r. � RRE RE: Multi Finger Caliper(MFC) and Leak Detect Log: 1B-102 Run Date: 3/27/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-102 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23167-00 Leak Detect Log SCAM() 1 Color Log 50-029-23167-00 Multi Finger Caliper log 1 Color Log 50-029-23167-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:1 ,r�t� ur-yrw -� / _.EAk;e ' • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,May 04,2016 Jim Regg `) S 1� P.I.Supervisor I &fc I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-102 FROM: Chuck Scheve KUPARUK RIV U WSAK IB-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1B-102 API Well Number 50-029-23167-00-00 Inspector Name: Chuck Scheve Permit Number: 203-122-0 Inspection Date: 4/30/2016 Insp Num: mitCS160502074250 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1B-102 Type Inj W TVD 3608 - Tubing I 600 - 600 600 600 600 2031220 SPT 1500 ' 1250 1990 _ 1950 1930 1930 PTD� Type Testi Test psi IA Intervalf0THER P/F P OA Notes: Test performed post tubing patch. SCANNED SEP 2 7 2016 Wednesday,May 04,2016 Page 1 of 1 • • SOF T� affr I yy�� THE STATE Alaska Oil and Gas of LASKA Conservation Commission „OMs 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER *,+ Main: 907.279.1433 OF g1i~Q` Fax: 907.276.7542 www.aogcc.alaska.gov Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 it416 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU WSAK 1B-102 Permit to Drill Number: 203-122 Sundry Number: 316-218 Dear Mr. Rogers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, I f Daniel T. Seamount, Jr. Commissioner DATED this G day of April, 2016. RBDMS Li. APR 0 7 2016 • 'DEC• EIVED STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 5 2016 APPLICATION FOR SUNDRY APPROVALS ^('�{"'� 20 AAC 25.280 AOGGC 1.Type of Request: AbandonRugPerforations Fracture Stimulate r r r Repair Well . Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other tbq patches IV. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 203-122 ' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23167-00 , 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A 7 Will planned perforations require spacing exception? Yes r No r 1A.0 WSAK 1B-102- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25639/25648/25649 V Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY iitiotal depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 1466 P+041 37l73%SO 10435' 3716' 3000 none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 148' 148' SURFACE 7769 9.625 7796' 3653' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7923'-10435' - 3684'-3717' 4.5 L-80 7661 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) VALVE-4.5"A-1 INJECTION VALVE(HSS-166)W/1.188"BEAN ON 3.812"DB LOCK, MD=524 TVD=520 BAKER ZXP PACKER - MD=7620 TVD=3608 12.Attachments: Proposal Summary WellBore Schematic J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p r Service For. 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 04/07/16 OIL r WINJ J✓, WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG J`" Commission Representative: GINJ r Op Shutdown r Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Kelly Lyons/Brent Rogers Printed Name Brent Rogers Phone:659-7224 Email: n1617(C7conocophillips.com Title: Problem Wells Supervisor Signature kgrec' Date: 04/03/16 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` \ Rug Integrity r BOP Test r Mechanical Integrity Test Location Gearance r Other: • al--a_ ft- wi fr-,z55rc1 .44 rT- /4- r-e-fei'red u fte' za-a4.-.'lijcJ I,kljrchct,- Post Initial Injection MIT Req'd? Yes Jt" No r Spacing Exception Required? Yes r No V Subsequent Form Required: 0 4.. RBDMS Lt-- APR 0 7 2016 9 / APPROVED BY /�/2ia5) Approved by: COMMISSIONER / THE COMMISSION Date: /Vn. 415714, �, �-(� A�►��bt FfO AAlild/la. y4/ Subbmit Form and Form 10-403 Revised 11/2015 a t v i r 12 months from the date of approval. Attachments in Duplicate • • RECEIVED ConocoPhillips APR 0 5 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 3, 2016 Ms. Cathy Foerster Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1B-102 (PTD 203-122). The request is for approval to patch two tubing leaks above the seal assembly. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • • ConocoPhillips Alaska,Inc. Kuparuk Well 1B-102 (PTD 203-122) SUNDRY NOTICE 10-403 TUBING REPAIR 04/03/16 This Sundry is a request for approval to repair Kuparuk River Unit West Sak Well 1B-102 (PTD 203-122)with two tubing patches. On March 2, 2016,the AOGCC was initially notified of suspected TxIA communication and the well was shut in on that day. An MITIA failed on March 11, 2016 with a follow up leak detect log and tubing caliper run on March 27, 2016. A tubing leak was identified at 5715' MD from the LDL and a second probable hole at 5931' from the caliper. With approval,the plan is to set two retrievable patches over the tubing leaks, conduct an MITIA, and return the well to normal WINJ injection. REPAIR PLAN 1. Set the first 26' 4.5" Statewide Oilfield Services retrievable tubing patch over the probable hole at 5931'. 2. Set the second 31' 4.5" Statewide Oilfield Services retrievable tubing patch over the leak at 5715'. 3. Test both patches for a successful repair prior to bringing the well on injection. 4. MIT as per AOGCC requirements (0.25 x TVD to packer). 5. Submit 10-404 post-repair. NSK Problem Well Supervisor f • KUP INJ 0 1B-102 • ~ ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(`) MD IftKB) 'Act Btm(ftKB) • c..x,comiTkps 500292316700 WESTSAK INJ 95.13 12,113.16 14,044.0 ••• A Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date • iB-102,3/31/20169:35,07 AM SSSV:NIPPLE Last WO: 35.00 8/15/2003 Vert,cal schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;222 I I t ,--1 Last Tag: Rev Reason:Mandrel Orientation lehallf 3/31/2016 __ Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 148.0 148.0 62.50 H-40 WELDED ". auu.Casing Description OD in ID in Top(ftKB Set Depth(ftKB) Set Depth TVD...Wt/Len I...Grade TopThread �. g SCABL 1 ) C) ) P ( ) P l I . GRAVEL LINER 13 3/8 12.415 27.4 520.9 517.5 68.00 L-80 BTC ,� Casing Description OD(in) ID(in) Top(ttK8) Set Depth(ftKB) Set Depth(TVD)...WtlLen I Grade TopThread CONDUCTOR;28.0.148.0 (�� SURFACE 95/8 8.835 26.9 7,795.9 3,653.2 40.00 L-80 BTC GRAVEL SCAB LINER;27,4- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Lenp...Grade Top Thread 5209L] . SLOTTED LINER 51/2 4.950 7,620.0 14,036.4 3,777.0 15,50 L-80 HYDRIL 511 NIPPLE;523.7 VALVE;523.7 Liner Details lEt Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 7,620.0 3,607.6 74.73 PACKER BAKER ZXP PACKER 7.490 IOU: 7,633.7 3,611.2 74.76 NIPPLE RS NIPPLE 6.188 GAS LIFT;3,524.8 , ,•moi 7,636.1 3,611.8 74.77 HANGER BAKER FLEX LOCK HYDR.LINER HANGER 6.290 al7,647.6 3,614.9 74.80 SBR BAKER CASING SEAL BORE RECEPTACLE 4.750 NIPPLE;7,313.1 Tubing Strings Tubing DescriptionString Ma...I0(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING I 41/21 3.5001 22.21 7,660.81 3,618.31 12.601 L-80 1 NSCT Completion Details Nominal ID (l Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) 22.2 22.2 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 SEAL ASSY;7,636.6 523.7 520.2 12.99 NIPPLE CAMCO DB LANDING NIPPLE w/3.875 NO GO 3.812 I PROFILE 7,313.1 3,518.1 71.15 NIPPLE CAMCO DB NO GO NIPPLE w/3.75"PROFILE 3.750 7,636.6 3,612.0 74.77 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY 3.500 SURFACE;269-7795.9-_a Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 523.7 520.2 12.99 VALVE 4.5"A-1 INJECTION VALVE(HSS-166)w/1.188" 7/25/2012 1.188 BEAN ON 3.812"DB LOCK 10,435.0 3,717.5 86.63 CMT Retainer SET CEMENT RETAINER 4/29/2009 4.580 10,608.0 3,727.6 86.66 PLUG 3.5"TTS IBP 4/27/2009 0.000 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) Ishats/f Top(ftKB) Btm(ftKB) (ftKB) (ttKBI Zone Date t) Type Com 7,923.0 13,948.0 3,684.5 3,769.2 WS D,WS C, 8/14/2003 99.0 IPERF 5.5"liner with.02'W x WS B,1B-102 1.5"L slots,208 slots/ft w/3'of blank pipe on each end of 40'joint; 10,523.0 10,528.0 3,722.7 3,722.9 WS C,1B-102 4/28/2009 5.0 APERF CEMENT OFF 1 4/29/2009 Cement Squeezes Top(WD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 10,435.0 10,608.0 3,717.5 3,727.6 Cement SQZ 4/29/2009 24 bbls pumped through retainer Mandrel Inserts • St CMT Retainer;10,435.0 ; Il_- ati on Top(WG) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com APERF;10,523.410.528.0 1 3,524.8 2,295.5 CAMCO MMG 1 1/2 GAS LIFT DAY RK 0.000 0.0 9/18/2003 3:00 Notes:General&Safety PLUG;10,608.0 End Date Annotation 8/31/2003 NOTE:GRAVEL SCAB LINER SET TO HOLD BACK GRAVEL FALLING INTO WELLBORE;NO PROD CSG 8/6/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;7.923.0-13,948.0 • SLOTTED LINER;7,620.4 1 f 14,036.4 111 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, March 12, 2016 8:16 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: Report of IA pressure anomaly West Sak injector 1B-102 (PTD 203-122) Follow up 03-12-16 Chris, The initial diagnostics have been completed. The tubing packoff tests all passed but the MITIA failed. A downhole plug will be set to secure the well and aid in further diagnostics with Slickline and E-Line. Once the leak depth has been identified and the condition of the tubing has been assessed, a plan forward will be developed and the appropriate paperwork will be submitted at that time for repair. Please let me know if you disagree with this plan. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 WELLS TEAM SCAMS, APR 0 4 2016 Carxx nc1 1Lps From: NSK Problem Well Supv Sent: Wednesday, March 02, 2016 1:00 PM To: Wallace, Chris D (DOA) Cc: Sender, . Tyler Subject: Report of IA pressure anomaly West Sak injector 1B-102 (PTD 203-122) 3-2-16 Chris, West Sak Injector 1B-102 (PTD 203-122) xperiencing an IA pressure anomaly. Last night,the IA pressure was discovered to be at 800 psi which was near the . 'ection pressure of 700psi. An attempt to create a dP between the tubing and IA by charging the IA to 1350psi with gas was unsuccessful. This morning the pressure had dropped back down to 800 psi. When bled, the IA came right back up to 80 si. The well also saw an increase in temperature and injection rate recently so this may still be a thermal phenomenon: However, we will be shutting the well in and freeze protecting as soon as possible. After the well has been shut in, initial diagnostics with DHD will be scheduled to include MITIA/drawdown test/packoff testing. A follow-up email will be provided and path forwarded established after the DHD diagnostics results are available. Attached are the 90 day TIO plot and schematic. « File: 1B-102 90 day TIO 3-2-16.1PG >> « File: 1B-102 schematic.pdf» Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, March 02, 2016 1:00 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly West Sak injector 1B-102 (PTD 203-122) 3-2-16 Attachments: 1B-102 schematic.pdf Chris, West Sak Injector 1B-102 (PTD 203-122) is experiencing an IA pressure anomaly. Last night,the IA pressure was discovered to be at 800 psi which was near the injection pressure of 700psi. An attempt to create a dP between the tubing and IA by charging the IA to 1350psi with gas was unsuccessful. This morning the pressure had dropped back down to 800 psi. When bled,the IA came right back up to 800psi. The well also saw an increase in temperature and injection rate recently so this may still be a thermal phenomenon. However, we will be shutting the well in and freeze protecting as soon as possible. After the well has been shut in, initial diagnostics with DHD will be scheduled to include MITIA/drawdown test/packoff testing. A follow-up email will be provided and path forwarded established after the DHD diagnostics results are available. Attached are the 90 day TIO plot and schematic. AUG U 41.Q\ E® 1 • Well Name 1B-102 Notes: Start Date 12/3/2015 Days 90 End Date 3!212016 1e"0C - — — 1E VJHP Annular Communication Surveillance 1-CC - 01- — 1- WHi 12CC Vf***NA.A 12 12 1CCC — 11 ACC „�'\�'� 1C •va COC Cs AC e•CC 70 2CC EC tic.-1E Cec-1E Cec-1E Cec-1E Jan-1C Jan-1A Jan-1c" Jan-1C Feb-1v Feb-16 Mar-1C Mar-1e" s n Noi-1E Cec-1E Dec-15 Dec-15 Jan-16 Jan-16 Jan-1C Jan-16 Feb-16 Feb-16 Mar-16 Mar-16 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 Image p~ject Well History File colr Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable Å direct inspection of the file. ~ Q3 - l~ d- Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 11111111I1111111111 RE~AN vzt' Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: D Other:: Date f ~ qj (lS- Date r d-h / oS' ~ + J I = TOTAL PAGES ló f (Count does not include cover sheet) Date: /51 /51 mf 1111111111111111111 1ŒL BY: ~ Project Proofing BY: <.~ /51 Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: I ():J- (Count does ;nClu~, sheet] Page Count Matches Number in scan~nglr7aration: YES BY: ~ Date: I OJ r ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111/1111111 NO 151 M1P NO BY: Maria Date: 151 111/1111111111 "III Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /51 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • ConocoPhiI Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 -5)1 ED JUL 0 8 2.0L June 27, 2011 Commissioner Dan Seamount Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 f. pro �, +�SSI�t► Anchorage, AK 99501 Commissioner Dan Seamount: a0 3 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 0 • 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" I 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 1B-09 50029206550000 1811340 SF N/A 23" N/A 5 6/20/2011 1B-10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 18-12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 18-101 50029231730000 2031330 _ 3" N/A 22" N/A 1.7 6/21/2011 18-102 50029231670900 2031220 11'2" 0.60 3rd` 6/9/2011 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 15'5" 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 1Q-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 • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophiltips.com] Sent: Saturday, June 05, 2010 7:04 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; Pierson, Chris R; Seitz, Brian; NSK Prod Engr 8~ Optimization Supv Subject: LPP/SSV Returned to Service on 1 B-102, 5-Jun-10 Tom /Jim, The low pressure pilot (LPP) on injector 1 B-102 (PTD 203-1220) was returned to service on 06/05/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 565 psig; injection rate is 580 bwpd. This pilot had been defeated on 04!02110 in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPFl Prod Engr Sent: Sunday, April 04, 2010 7:14 AM To: CPFi Prod Engr; 'Maunder, Thomas E (tom.maunder@alaska.gov)'; 'Regg, James B (jim.regg@alaska.gov)' Cc: CPFi DS Lead Techs; CPFi Prod Supt; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; Pierson, Chris R Subject: LPP/SSV defeated on 16-102, 2-Apr-10 Tom /Jim, The low pressure pilot (LPP} on 1 B-102 (PTD 203-1220) was defeated on April 2, 2010 when the well was returned to injection service. The well had been shut in since August 24, 2010. Current wellhead injection pressure (as of April 4, 2010) is 188 psi at 581 BWPD injection. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Daniel Daniel Bearden /David Lloyd Lagerlef CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 6/7/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Sunday, April 04, 2010 7:14 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; Pierson, Chris R Subject: LPP/SSV defeated on 1 B-102, 2-Apr-10 +; ~ »~~ .w Tom /Jim, The low pressure pilot (LPP) on 1 B-102 (PTD 203-1220) was defeated on April 2, 2010 when the well was returned to injection service. ewe a een s u in since August 24, 2010. Current wellhead injection pressure (as of April 4, 2010) is 188 psi at 581 BWPD injection. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Daniel Bearden /David Lloyd Lagerlef CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 4/5/2010 ~ MEMORANDUM To: Jim Regg ~~ ~~zz~~ ~ P.L Supervisor F1toM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-102 KUPARIJK RIV U WSAK 1B-102 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv y~=~ Comm Well Name: xuP~u~c xrv u ws~c 1s-1o2 Insp Num: miUJ090706091242 Rel Insp Num: API Well Number: 50-029-23157-00-0o Permit Number: 203-122-0 ~ Inspector Name: JeffJones Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~,e~~ is-io2 Type Inj. ~' TVD 3607 ~ IA ioo 2zoo ~ 2i2o zioo ~ P.T.D zo3izzo TypeTest SPT Test psi ~soo ~ OA Interval 4YRTST P~` P ~ Tubing 651 655 653 650 Notes: ~•Z BBLS diesel pumped, monobore injector. 1 well inspected; no exceptions noted. ~ .'~ ~ ~ ~' ~ r •~ R ( i~ <<:' x~~ ~~ .. +.l ~..~ti H:.at,*> ~ _.. Monday, July 06, 2009 Page 1 of 1 A ~~IA1` ,~ ~ ~~~G • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~a~~~ ~If ~ ~8S +' ~-~ c~€7/3~'b f xs~rrif~3Sl7/n REPORT OF SUNDRY WELL OPERATIONS a~nchnr~pc, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations Q ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhlllips Alaska, InC. Development ^ Exploratory ^ 203-122 / 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23167-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' / 89' AMSL 1 B-102 8. Property Designation: 10. Field/Pool(s): ADL 25649 & 25639 ' Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14044' feet true vertical 3850' feet Plugs (measured) 10435', 10608' Effective Depth measured 10435' feet Junk (measured) cmt retainer @ 10435' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 92' 16" 120' 120' SURFACE 493' 13-3/8" 521' 518' PRODUCTION 7767' 9-5/8" 7795' 3653' SLOTTED LINER 6416' 5-1/2" 14036' 3777' Perforation depth: Measured depth: 7923'-13948', 10523'-10528' (Sgz'd off) ~~;~. ~ ~x~~ ~ ~ ~~ ij~~ f's ~ ~ ~;+ - GCtJ : +~ M ~ ~ ... ~ :~-. true vertical depth: 3684'-3769', 3723'-3723' Tubing (size, grade, and measured depth) 4.5", L-80, 7661' MD. ~ Packers & SSSV (type & measured depth) Baker ZXP pkr @ X620' Camco'DB' nipple @ 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10523'-10528' 24 bbls ultra IiteCrete cement Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 1045 ' 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-292 Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer S~ ~ Signature ~ ,~,- ~ Phone: 265-6471 Date zg ©~ .~ Pre are Sharon All u Drake 263-4612 Form 10-404 Revised 04/2 - ti ~ i.;t ~ ~i ~ Submit Originl~} ~~~ F t ~ .~ \\\ ! 14 /` ~ t~. ConocoPhAillips HANGER. 22 CONDUCTOR, 35-146 SURFACE wIGRAVEL -_ __ STRING, 30-521 NIPPLE. 524 VAL VE. 524 GAS LIFT, 3.525 NIPPLE, ],313 PACKER, 7,fi20 NIP, ],633 LINER FOW GER, -- 7.636 SEAL, 7,641 saR ].sae LINER JTS, 7,fi67 PRODUCTK)N, 26-],]95 LINER JTS, 7,963 CMT RTNR, 10 d35 APERF, 10,523-10.528 plug, 10.435 PLUG, 10,606- - IPERF, _______ 7,923-13.948 KU P (bore APVUWI Field Name 500292316700 WEST SAK ment -- ~ N2: 3V: NIPPLE ' 1 B-102 Max M ., -- Well Status Inc! (°) gle $ MD MD (NKB) TD Acl Btm (NKB) - ( INJECTING 95.13 I 12,113.16 14,0440 Annotation End Date 'KB-Grd (N) 'Rig Release Date Last WO: 35.00 8!15!2003 ration Last Mod By Entl Date Reason: CMT SOZ PERFS Imosbor 5/18/2009 ,.a~~~~y .,e~,..,r.~,.~~ CONDUCTOR ...~~~n.,... 16 .,,.~~~e ~.. ... 15.062 ~,.r r~....a 35.0 ..e..,er...~.._ 148.0 ..o..,or...~,..,1... 148 0 .......e ...... 62.50 .......e ._ H-00 .......a ..,. ...... WELD (Casing Description String 0... String ID ... Top (ftK8) _ Set Depth (i... Sat Depth (ND) ... String Wt... String ... String Top Thrd I~iSURFACE 133/8 12.347 29.7 521.0 517.5 68.00 L-80 BTC ~,w/GRAVEL STRING i, ,Casing Description String 0... String ID ... Top (ftK8( Set Depth (t... Set Depth (ND) ... ~i, String WI... ( I String ... String Top Thrd PRODUCTION 95/8 8.697 25.9 7,795.0 3.652.9 . 40.00 L-80 I BTC Casing Description (String 0... String ID ... Top (NKB) Set Depth (t... Set Depth (ND) ..- String WI... ' String ... '. String Top Thrd SLOTTED LINER 5 1/2 4.950 7.628.0 14,044.0 15.50 L-80 Hydril 511 UNDULATING ' Tubing Strings r escri 9 Ption str 9 9 P ~~~ To 1 ~ Str set h ~~~ (String ._String Tov 7hrd (t... set D P ( 9 DI ~~~ Str UBING 4 1/2 3.958 22 0 0 i 3.618 4 1260 I L-80 NSCT ? 661 Top Depth ~ (ND) '' Top Inc! (NKB) (NKB) (°) Description I Comment Run Date ~ID (in) 22 22.0 -2.00 HANGER VETCO GRAY TBG HANGER 8/14/2003 ; 4.500 524 520.5' 12.85 NIPPLE CAMCO'DB' LANDING NIPPLE W/3.875' NO GO PROFILE 8/1 4120 0 3 ". 3.8121 .-_ 524 ._. , 520.5Ii 12.85 VALVE 3.812" A-1 INJECTION VALVE (HSS-166) 1.875" BEAN set 6/9/2008 ~ 187... ~ 6/9/2008 ' 3,525 2,295.6 72.15 GAS LIFT CAMCO/MMGf1.5/DMY/RK///Comment: STA 1 9!1812003 8.958 7,313 3,518.11, 71.15 NIPPLE i CAMCO'DB' NO GO NIPPLE W/3.75" PROFILE 8/14/2003 ~ 3.750 7,620 3,607.6( 74.73 PACKER ; BAKER ZXP PACKER 8(14/2003 ~'~ 7 490 7,633 3,611.0( 74.76 NIP ';S RS NIPPLE 8/14/2003 ~. 6.188 7,641 3,613.1 r 74.79 SEAL BAKER GBH-22 SEAL ASSEMBLY &14/2003 ~ 3.880 7,648 3,614.9 74.81I SBR BAKER CASING SEAL BORE RECEPTACLE 8/14/2003 4.750 10 435 3,717.5 86.61 CMT RTNR SET CEMENT RETAINER 4/29/2009 4.580 I 10 608 3,727.5 86.56 PLUG 3.5" TTS IBP 4/27/2009 0.000 13,948 3,769.2'' 84 93 PACKOFF 'I 8/1412003 Perforations $ Slots --- -- - sha Top (N ~ D) Btm (TVD) Dens Btrn (ftK8) (ftK8) Top (ftK8) (ftK8) Zone Date (sh... Type Commerrt 7,923 13,948 3 684.1 3,769.2 WS D, WS C, 8/1412003 99.0 IPERF 5.5" liner with .02"W x 1.5"L slots, WS B, 16-102 ~~ ~ 208 slots/tt w/3' of blank pipe on each ~. '~ end of 40' joirn; ___ 10,523 10,528 3,722.6 3,722.9 WS C, 1 B-102 4/28/2009 ' - 5.0 'I APERF CEMENT OFF 4!292009 - 4.O4d 1 B-102 Well Work Summary DATE SUMMARY 3/30/09 PULLED 3.812" A-1 INJECTIO~LVE @ 524' RKB. GAUGED TBG TO 3~TO 4250' SLM. TOOLS FALLING @ 50 FPM f/3300' TO 4250' SLM. UD FOR CREW CHANGE. IN PROGRESS. 3/31/09 GAUGED TBG TO 3.71" TO 7650' SLM. MEASURED BHP (c7 7700' SLM: 1393 PSI. COMPLETE. 4/26/09 PERFORM FLUFF & STUFF DOWN TO 10818' CTMD BEFORE REACHING LOCK-UP ON COIL.RECIPROCATED ACROSS SETTING DEPTH FOR BRIDGE PLUG AND CEMENT RETAINER. POOH LAYING IN SAFE LUBE FROM 10818' CTMD TO 7600' CTMD. JOB IN PROGRESS 4/27/09 SET TTS 3.5" OD EXPANDABLE BRIDGE PLUG INSIDE BLANK SECTION OF 5.5" LINER 10608' CTMD.JOB IN-PROGRESS 4/28/09 PERFORATED 5.5 LINER Cad 10523 CTMD TO 10528 CTMD WITH SLB 6 SPF TCP GUNS. RTN IN A.M. FOR CEMENT JOB. 4/29/09 PUMPED 24 BBLS ULTRA LITECRETE CEMENT THROUGH RETAINER SET @ 10435 CTMD, PUT .5 BBLS ON TOP OF RETAINER, SWAPPED TUBING OVER TO DIESEL. LEFT SHUTIN. RE: LPP/SSV no longer defeated on 1B-102 - 17-MAY-09 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 cLDconocophillips.com] Sent: Sunday, May 17, 2009 11:57 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Prod Engr & Optimization Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr Subject: RE: LPP/SSV no longer defeated on 1 B-102 -17-MAY-09 Tom /Jim, The low pressure pilot (LPP) on West Sak water injector 1 B-102 PTD 203-122 is no longer defeated as of 17- MAY-2009. The injection pressure has increased to above 500 psi an t e ,SSV function has been returned to normal (the well is no longer operating with a defeated low pressure pilot). Please let me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 r ty a',1 Vt^~` ~'~ ~~i~ 5/18/2009 LPP/SSV defeated on 1B-102 ~-MAY-09 • Page 1 oft Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Friday, May O8, 2009 9:48 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1 B-102 - 08-MAY-09 Tom /Jim, The low pressure pilot (LPP) on West Sak water injector 1 B-102 (PTD 203-122) was defeated on 08-MAY-2009 when the well was returned to service after being shut in since 26-FEB-2009. Current injection is 500 BWPD at 60 psig wellhead pressure. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 `_.,,~~~ MAC, ~ LD~~ .~ti. From: NSK West Sak Prod Engr Sent: Thursday, February 26, 2009 1:52 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPF1 DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Gangl, Melissa A; Hibler, Kaycee Subject: FW: LPP/SSV no longer defeated on 1B-102 Tom /Jim, West Sak injection 1 B-102 (PTD 203-122) was shut in today, 26-Feb-2009. The well is no longer operating with a defeated low pressure pilot. Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 5/8/2009 LPP/SSV defeated on 1B-102 ~-MAY-09 • Page 2 of 2 From: NSK West Sak Prod Engr Sent: Friday, February 20, 2009 1:01 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPF1 DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Gangl, Melissa A; Hibler, Kaycee Subject: LPP/SSV defeated on 16-102 Tom /Jim, The low pressure pilot (LPP) on West Sak water injector 1 B-102 (PTD 203-122) was defeated on 20-FEB-2009 when the well was returned to service after being shut in since 5-DEC-2008. Current injection is 676 BWPD at 0 psig wellhead pressure. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 4066.001 ". Please let me know if you have any questions. Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 5/8/2009 Re: 1B-102 proposed work sc~evision to approved 10-403 (attached Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 31, 2009 8:39 AM To: 'Peirce, John W' Cc: Kanady, Randall B Subject: RE: 1 B-102 (203-122) proposed work scope revision to approved 10-403 (attached) Page 1 of 1 John and Randy, Thanks for the call and information. I have examined the work plan included with sundry 308-292 and the plans are substantially similar. Nothing further is required. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com] Sent: Monday, March 30, 2009 9:24 AM To: Maunder, Thomas E (DOA) Cc: Kanady, Randall B Subject: Re: 1B-102 proposed work scope revision to approved 10-403 (attached) Tom, Per our discussion Friday 3/27/09 regarding the work scope of 1 B-102 MBE treatment, the approved 10-403 of 8- 21-08 (approval # 308-292) now has a revised work scope. Attached is a summary outline of the work we now propose. If approval is granted for the new proposal, we wish to perform this work as soon as possible. «1 B-102 Cement Plug to Isolate MBE Procedure_3-30-09 to AOGCC.doc» «1 B-102 MBE Repair Documents.pdf» Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office (907)-240-5533 cell 3/31 /2009 . . • 1 B-102 Cement Plug to Isolate West Sak B Sand MBE ~- ~ ~-~~~. 1 B-102 is a horizontal undulating injector (HUI) with 4.5" tubing and 5.5" slotted liner that was completed August 2003. A matrix bypass event (MBE) occurred between 1 B-102 and 1C-178 producer on 11-11-04. A 6-7-08 (PROF shows the MBE exists at _11450' MD in the West Sak B sand. The MBE will be isolated using a cement plug placed above the MBE to halt future injection from entering the MBE. A bridge plug and cement retainer will be used to place the cement plug. No attempts will be made to fill the MBE itself with cement. Objective: Isolate the West Sak B sand MBE at 11450' MD below +/- 200' of cement plug spotted between 10600 - 10900' MD to halt future PWI from entering the MBE. Coil Tubing Procedure for Cement Plug Placement: Run #1: RIH w/2" CT and nozzle to perform a `fluff & stuff' down to 11000' RKB. Circulate out of the hole displacing the wellbore to lubricant solution to surface. This run should clear the tubing and liner of any solids before attempting to run a Bridge Plug to be set at 10865' RKB. Although coil run modeling indicates there should be sufficient WOB to set a plug and retainer, the lubricant will further reduce friction to insure successful run and set of the Plug and Cement Retainer. Run #2: RU 2" CT with 3.5" run OD expandable Bridge Plug, and set the plug at 10865' RKB in the 5.5" liner. POOH with CT. Run #3: RU 2" CT with 5' pert gun with 4 SPF. RIH to +/- 10815' RKB and shoot 5' of squeeze perforations. POOH with CT. Run #4: RU 2" CT with 2.5" inflatable cement retainer and prepare cement batch for cement plug placement. Mix 15 bbls of 8.5 ppg light weight cement for plugback. RIH with inflatable cement retainer, and set the retainer at 10600' RKB. Pump 10 bbls of Diesel through the retainer at 0.5 bpm to verify good infectivity to 5.5" liner x OH annulus via squeeze perfs. After 10 bbls of Diesel is pumped, swap to pumping 15 bbls of 8.5 ppg cement at 0.5 bpm. Displace all 15 bbls of cement through retainer at 0.5 bpm with 1 CT volume of Diesel. Disconnect CT from the cement retainer immediately after all 15 bbls of the cement has passed through the retainer. POOH w/CT slowly while replacing voidage to surface with Diesel. RD CTU. Wait on cement a minimum of 5 days before returning 1 B-102 to water injection. 1 B-102 will be returned to West Sak B and D sand injection above the cement plug. Horizontal standoff from the isolated MBE to the remaining B sand injection interval at the heel of the HUI to be used for future injection will be 3000'. P ~~~~:~ • 18-102 Profiile ConocoPhilli s p Alaska Weil 18-102 HUI Interpreted Measured Depth Profile 3300 ~~ W ell 18-102 Survey Profile 3350 ~OrigonalPlanned Wellbore • ~~Revised (8/5/03) Planned Wellbore 3400 - Top West Sak D-Sand Top West Sak C 3450 ~~`I'op West Sak f3-Sand K-13 Marker Fault; 3T to 39' throw down to north 3500 Revised Planned WeIIbore ~I 3550 x-t3 mate Original Planned Wellbore Fauh Top West Sak D-Sand Top Wort Sale Well 1B-102 Survey Proftle 3600 C-Shale Top West Sak 3650 - - D-Sand 3700 _ Top West Sak • B-Sand A Di 0.49 de ees down N PP• p " S App. Dip -- 0.34 degees down N APP• Dip .19 dogees down N -3750 Est. App..Dp --„0.3 degees 3800 ~ S "~jJ VJi O S 04 tppn ~ ..+ O g~ p~ Q S O ~ ,.r io"~ gW Wp `~ ,'-p, ~ ~ g c7 O O O O S Measured Depth ~_~-_~~~ WSAK North Row Review 1-22- 8 2009 ~~3~~vo9 18-102 Gement Plug Proposal Procedure: 1) CT Set Bridge Plug 2) CTC Perf 5` Interval 3) CT Set Cement Retainer 4) Pump 15 bbls Cement 0.5 bpm 5) Disconnect CT & POOH soon as 15 bbls of cement has exited the nozzle. Volumes (10600 to 10865'): 5.5" Liner = 6.3 bbls Liner x OH = 10.8 bbls Total Cement = 17.1 bbls Suggested Vol = 15 bbls, to avoid cement above retainer WS C Top = 10394' MD WS B Top = 10753' MD Blank 10378 -10503' Slotted 10503 - 10547' Blank 10547 - 10669' Slotted 10669 - 10713' Blank 10713 - 10843' Slotted 10843 - 10885' Blank 10885 - 11015'. 8.5" 5.5" 5.5" Liner fills with cement from 10600 to 10865' (6.3 bbls), then 5.5 x OH fills with 8.7 bbls from perfs at 10815'. Note, 213' of 5.5 x OH annulus fills with cement after total of 15 bbls of cement pumped. Our primary operations( concern is possibile cement getting above the retainer in the annulus and cementing CT in above the retainer. Worst case scenario: Cement cannot travel below 10815' (perfs) in annulus (due to collapsed annulus), so all cement must travel up the annulus. This would put our annular cement top up to the cement retainer but not above it. Cement 5' x 4 spf Bridge Retainer PerFs Plug 10600' 10815' 10865' ,_\ ~; ~onacot'hiilips /11Rght, lix_ Wsllhoro V Common Well ca, ~. ri, . n, MPPLE _,_ -. __-_ - -~-"J _ 'Annolath Last Tq tu~NG ~ ~. !: _ { n ,. GAS LIFT, ~ 3,525 NIPPLE, 7,313 yy fi i PACKER, __ T~ 7,e2o , NW, 7,833 LINEA r HANGER, 7,836 ~+ ~,?~ SEAL, __. ... 7,W3 _ :' Vii: .- SeR, ,. ' I uNER _ ~: JTS, 7.x87 LINER i . 7,863 L•SLi Reason: SEf Status Dens I Shot hot._ Total B-1 35.00 boar with A2'W x t5'L slot sk>tstit wP8 of blank pipe on i end of d0' joi2d; Un0u198n0 SLOTTED LRJER ro, u,oaa FW: LPP/SSV no longer defeated on 1B-102 Page 1 of .-.. Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Thursday, February 26, 2009 1:52 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Gangl, Melissa A; Hibler, Kaycee Subject: FW: LPP/SSV no longer defeated on 1 B-102 Tom /Jim, West Sak injection 1 B-102 {PTD 203-122) was shut in today, 26-Feb-2009. The well is no longer operating with a defeated low pressure pilot. Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~.; ~ cog ~~ 2;10 > From: NSK West Sak Prod Engr Sent: Friday, February 20, 2009 1:01 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Gangl, Melissa A; Hibler, Kaycee Subject: LPP/SSV defeated on 16-102 Tom /Jim, The low pressure pilot (LPP) on West Sak water injector 1 B-102 (PTD 203-122) was defeated on 20-FEB-2009 when the well was returned to service after being shut in since 5-DEC-2008. Current injection is 676 BWPD at 0 psig wellhead pressure. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 2/26/2009 From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Friday, February 20, 2009 1:01 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Gangl, Melissa A; Hibler, Kaycee Subject: LPP/SSV defeated on 1 B-102 Tom /Jim, The low pressure pilot (LPP) on West Sak water injector 1 B-102 (PTD 203-122) was defeated on 20-FEB-2009 when the well was returned to service after being shut in since 5-DEC-2008. Current injection is 676 BWPD at 0 psig wellhead pressure. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~~~~~ ~~~ ~ ZQ~~ 2/20/2009 FW: LPP/SSV no longer def~d on 1B-102 (PTD 203-122) Page 1 of 1 Maunder, Thomas E (DOA) From: N5K West Sak Prod Engr [n1638@conocophillips.com) Sent: Saturday, December 06, 2008 4:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: FW: LPP/SSV no longer defeated on 1 B-102 (PTD 203-122) Tom /Jim, West Sak injector 1 B-102 (PTD 203-122) was shut in on 5-December-2008. The low pressure pilot is no longer defeated. Please let me know if you have any questions. Eric Holler / Hai Hunt West Sak Production Engineer CanocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 from: NSK West Sak Prod Engr Sent: Friday, November 07, 2008 10:58 AM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Ce: CPFi DS Lead Techs; CPFi Prod Supt; Targac, Gary; NSK Problem WeN Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSY defeated on 16-102 Tom /Jim, The low pressure pilot (LPP) on 1 B-102 (PTD 203-122) was defeated on 5-Nov-2008 when the well was returned to service after being shut in for an extended period of time. Current injection is 2700 BWPD at 100 psi. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any questions. Eric Holler / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 12/8/2008 LPP/SSV defeated on 1B-102 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Friday, November 07, 2008 10:58 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1 B-102 Tom /Jim, The low pressure pilot (LPP) on 1 B-102 (PTD 203-122) was defeated on 5-Nov-2008 when the well was returned to service after being shut in for an~en~c ed period of time. Current injection is 2700 BWPD at 100 psi. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 4066.001 ". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 """.~~~~~ ~~~'''` ~ ~ =~~ 11 /7/2008 • ConocoP ' ' hi~lips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~~~~~ ~~~ ~ ~ ~~~$ ems,, ~ ,~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: AUG Z 5 2008 Alaska Oil & Gas Cons, Anchorage Com~;,~;;,ion ao= ~a 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 ~~(~ ~ 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) Kuparuk Field Date Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top c date ft bbls ft 2H-05 185-168 SF N/A SF N/A 2H-17 200.019 6" N/A 6" N/A 2K-27 201-169 10" N/A 10" N/A 2M-03 191-141 16" N/A 16" N/A 1 B-14 194-030 SF N/A SF N/A 1B-18 194-061 9" N/A 9" N/A 1 B-19 194-064 SF N/A SF N/A 1B-20 203-115 21" N/A 21" N/A 1B-101 203-133 3" N/A 3" N/A 1B-102 203-122 4" N/A 4" N/A 1Y-05 183-087 6" N/A 6" N/A 1 Y-07 183-068 6" N/A 6" N/A 1Y-17 193-068 SF N/A SF N/A 1Y-22 193-070 SF N/A SF N/A 1Y-26a 188-116 SF N/A SF N/A 1Y-30 188-090 SF N/A SF NIA 1E-112 204-091 14" N/A 14" N/A 1E-119 204-031 14" N/A 14" N/A 1 E-121 204-246 6" N/A 6" N/A 1E-123 204-074 5" N/A 5" N/A 8/17/2nnR ff Corrosion inhibitor Corrosion inhibitor/ sealant date al 5.10 8/2/2007 1.27 8/2/2007 8.92 8/2/2007 2.13 8/2/2007 1.70 8/13/2008 8.07 8/13/2008 5.10 8/13/2008 5.95 8/13/2008 1.00 8/17/2008 1.00 8/17/2008 1.27 8/13/2008 1.27 8/13/2008 1.27 8/13/2008 2.12 8/13/2008 3.83 8/13/2008 3.83 8/13/2008 .5.95 8/17/2008 4.67 8/17/2008 1.00 8!17/2008 1.00 8/17/2008 • • ,.~~ ~- ~ ~- ~ ~ SARAH PAL/N, GOVERNOR ~,.,.. ~S~A OIL ~ ~~ 333 W. 7th AVENUE, SUITE 100 COATSER~AZ'IOAT COl~'ID'I15SIO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Well Engineer ConocoPhillips Alaska Inc. ~ ~,~~ AU G ~ ~ 2008 ¢~; PO Box 100360 ~h ~' Anchorage, AK 99510 h 1 ~~~ Re: Kuparuk River Field, West Sak Oil Pool, 1B-102 ~,,„~1~ Sundry Number: 308-292 Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.OSOe as the Commission grants for good cause decision, or such further tun shown, a person affected by it may file with the Corrunission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holi dariy or Court unles s rehearing has been a Commission decision to Sup requested. Sincerely, Cath P. Foerster Commissioner DATED thi~~d y of August, 2008 Encl. _- o r c~,,,~ I• STATE OF ALASKA • fem.' ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION/•r ~~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 _ ~~ ~~ - -- 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Alter casin g ^ Re air well Plu Perforations ~ p ^ g ^~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 203-122 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23167-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y@S ^ NO Q 1 B-102 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 i~ 25639 RKB 28' / 89' AMSL Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14044' ~ 3850' 13947- 3841' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 120' 16" 120' 120' SURFACE 493' 13-3/8" 521' 518' PRODUCTION 7767' 9-5/8" 7795' 3653' SLOTTED LINER 6416' 5-1/2" 14036' 3777 Perforation Depth MD (ft): Perforation Depth TVD (ft}: Tubing Size: Tubing Grade: Tubing MD (ft): 7923'-13948' 3684'-3769' 4-1/2" L-80 7661' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP packer @ 7620' Camco 'DB' landing nipple @ 524' 13. Attachments: Description Summary of Proposal ~ 14. Wetl Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 22, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~' WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU Schwartz Title: Wells Engineer Signature Phone 659-6958 Q Date d ~~3'~ ~ y Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~_ ~ ~/ ~ w~r ~S QSS~~`c4 Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~~ ~ ~a~~~ ~~ Other: ` Subsequent Form Required: ~~` APPROVED BY 7 ~~ ~ ~~ Approved by: COMMIS MMISSION Date: C l ~~ Form 10- 3 Revj~ed 06/2006 Submit in Du licate 4Q-, 6 p • • Sundry Request for 1 B-102 MBE Remediation 8-10-2008 Background: West Sak 1 B-102 was drilled as a horizontal undulating injector (HUI) lateral in 2003 (the wellbore undulates between West Sak B and D sands). Initial water injection in 1 B-102 occurred on 11/28/03 at just over 2400 bwpd with a total of 708,636 barrels of cumulative water injected as of 9/30/2007. The MBE (Matrix Breakthough Event) in 1 B-102 occurred while injecting above fracture pressure in November 2004. WHIP was seen to drop sharply while water injection rate climbed to over 8000 bwpd. The hydraulic fracture opened in 1 B-102 closed now that injection stopped. However, the brief high rate injection had established a conductive path that was now within the influence of producer 1 C-178. Producer 1 C-178 remained active for the next two months at a strong pressure drawdown. Continued production enhancing the connection to 1 B-102 resulted in complete MBE failure by January 2005. Diagnostics have identified the MBE breakthrough in the area of 11000'md in the HUI lateral in the B West Sak sand facies. This is in the lower 1/3 of the horizontal wellbore. The most economical method to fix the injector and allow injection again is to abandon the lower third of the wellbore as well as fill the MBE pathway with cement. Thixotropic cement will be pumped after setting an inflatable retainer (IBP) at around 11000' md. Procedure outline: 1. RIH with 1 3/" CT (I-coil) . Perforate liner at 11010'- 11012' and .POOH 2. RIH and Set IBP at 11000'md. 3. Perform diagnostics by pumping HEC gel to size MBE and re-establish MBE event 4. Pump Thixotropic cement . Pull out of IBP. 5. Return well to injection. °~ - ~ ConocoPhillips ~ ,_ w~i conrs r_~ - ~11zu,.~. s~,... ,.. __., HANGER, 2z SURFACE t Y i SSSV, 524 VALVE, 524 GAS LIFT, 3,525 l i NIPPLE, 7,313 PACKER, ~--~--~-- ],fizD ./ NIP, 7,633 LINER HANGER, 7,636 SEAL. 7,641 SBR, 7,648 ' LINER t JTS, ],66] r €t~ ~ DUCTION III I i j I LINER ~, JTS, ],963 `.'. 23-13,948, ~ " I 8/1412003 PACKOFF, 13,948 Untlula8ng SLOTTED LINER TD, 14,044 ~-~ Name Last WO: Annontion Rev Reason: SET INJECTION VLV JP 1B 102 ~a ,, , M4xlmum Incbnabon () lonl Oep1n ifiKdl 95.13 14 044.0 KB-Grd (n) Rig Release Date i 35.00 8115/2003 _ IEnd Date 6/14Y2008 Ling SLOTTED 51/2 i 15.501E-80 4.9501 7,628.01 14,044.0 Hyddl 511 LINER 1 : F ...~ f. t S.'1< ~:r:~ F . a < r:.: . , >t ~ Tuhing Descr ptlon ODlnl Wtlln.fft) Grade ID ni Top (ftKB) Se[Deplh IINB Snl Cleyth IVDI IftN ei Top Thread TUBING 1 ~ _ P`3 0.0 r'~'n 1'.60 L-80 NSCT lop (M(B) Descdptlon Comment Run Dab ID (In) i 22.0 HANGER VETCO GRAY TBG HANGER 8114/2003 4.500 524.0 SSSV NIPPLE CAMCO'DB' LANDING NIPPLE WI3.875' NO GO 8114/2003 3.812 ~ PROFILE I 524.0 VALVE 3.812" A-1 INJECTION VALVE (HSS-166) 1.875" BEAN set 6/912008 6/9/2006 187... 3,525.0 GAS LIFT CAMCOIMMGII.SIDMY/RKII/ Comment: 911612003 8.958 i 7,313.0 NIPPLE CAMCO'DB' NO GO NIPPLE W/3.75" PROFILE 8/14/2003 ; 3.750 7,620.0 PACKER BAKER ZXP PACKER 8114/2003 .7.490 I 7,633.0 NIP RS NIPPLE 811412003 j 6.188 7,636.0 LINER BAKER FLEX LOCK HYDR. LINER HANGER 8174/2003 16.290 HANGER j 7,641.0 SEAL BAKER GBH-22 SEAL ASSEMBLY 8114/2003 13.880 7,648.0 SBR BAKER CASING SEAL BORE RECEPTACLE 8/14/2003 ~ 4.750 7,667.0 LINER JTS SOLID LINER JOINT (ALTERNATES 3 JOINTS SOLID, 1 JOINT SLOTTED 1 811 412 0 03 4.950 LINER) i Top (T1/D) Bim (ND) I ! Dons Shot 9en (TtKB) InKe) 1~g) rvw ~ zone j f:hot... ronl liner with .02"W x 1.5"L slots, slotslft w/3' of blank pipe on 1 end of 40' joint; Tubing Hanger, Vetco Grey Gen ta, 4 1/2' ~16" Conductor -4 i/2" Camco "DB-6" Nipple with 3.81" I.D. 41/2" A-1 SSSV to be installed in Nipple (1) Gas Lift Mandrel, Camco "MMG" 41/2" X 1 1!2" with shearout sub 7i 41/2', 12.6#, L-80, NSCT, tubing Couple OD I.D. Drift 5.2" 3.958 3.833 Collapse Burst Tensile 7500 7700 208 121/4" Hole Size 9 5/8", 40#, Butt Mod, L-80, Casing ~ Couple OD I.D. Drift 18.825 8.835 8.579 Collapse Burst Tensile 3090 5750 947 x-over r, 2s# TKC Pin X Hydrii 511 Box ', Baker 7" X 95/8", 40#, "ZXP" Liner Top Isolation Isolation with 7" BTC pin down and TKC coupling • • 41/2" Camco "DB-6' No-Go Nipple with 3.75' I.fl. w/ 10' pups Not to be set at any angle greater then 70 degrees 8 1/2" Hole Size 51/2",15.5#, L-80, Hydril Liner, every fourth jt. slotted 41/2' Baker GBH-22 Casing Seal Assembly Couple OD I.D. Drift with 15 foot stroke, 41/2` IBT box up Flush Jt. 4.86 4.825 1 jt. 5112' i5.5# Collapse Burst Tensile Torsion Hydtil 51 i perforated 4990 7000 259yc 15,700 Pi • ott_ff ~ . ~ ~'~"\ "'~'~ M ~ ~ 51/2" Silver Bullet Baker 7", 26#, BTC Flex Lock Hanger 82 degrees Baker 17 ft. 4.75' I.D. 80.47 PBR ~ Reamer Shoe with TKC couplings on top and bottom with 51/2' HydriU Pin X Pin ~ ~~b ~ 14,000' MD .~~.~~ s ~ ~~~ ~ ~~ 3~~~ ~ ~`~ ~`' ~~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 ~~~NN~~ JUL ~ 20~$ RE : Cased Hole/Open Hnle/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following IProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1~) Injection Profile 07,Jun-08 18-102 BL / E~ 50029-23;167-00 2) Caliper Report ~j9-Jun-08 2X 19 1 Report / EDE 50-Q29=22618.00 1' r t 1 r/7 `7 Signed : ~ / /~~..-._----------~'" Date Print Name: ;11~, ; ~-~~,~.~ ~~'~~x~:~a~~ PROACTNE DIAGNOSTIC SERVICES, INC., 730 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL b~~a~.~~~°~,~~~ ;~:-;:~~.f?~>>, ~~r~ WESSRE ar. ;~~ ..~ ~°~ ..~ LPI'/5~V returned to normal on 113-102 • Maunder, Thomas E (DOA) 1'abe 1 of 2 From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Friday, June 13, 2008 5:48 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV returned to normal on 1 B-102 Tom /Jim, 1B-102 (PTD 203-122) was shut in on 6/7/2008 after an injection profile was performed. The LPP/SSV function was returned to normal 6/9/2008 while the well was shut in. The well wilt most likely be left shut in until an injection profile modification is planned and executed. Please let me know if you have any questions. Regards, Hai Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~~~NN~~7 JUN z ~ 2008 From: NSK West Sak Prod Engr Sent: Thursday, April 17, 2008 3:12 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; NSK West Sak Prod Engr, Targac, Gary; NSK Problem Well Supv Subject: LPP/SSV defeated on 1B-102 Tom /Jim, The low pressure pilot (LPP) on 1B-102 (PTD 203-122) was defeated on 4/16/2008 when the well was returned to service after being shut in for an extended period of time. Current wellhead pressure is 27 psi; injection rate is 1958 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." It may be several weeks before the wellhead pressure builds back up to the point that ttre LPPs can be returned to service. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Regards, C/14/2008 LPP/SSV defeated an 1B-102 Maunder, Thomas E (DOA) Page 1 of 1 From: NSK West Sak Prod Engr [n1638@conocophiltips.com] Sent: Thursday, April 17, 2008 3:12 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr, Targac, Gary; NSK Problem Well Supv Subject: LPP/SSV defeated on 18-102 Tom /Jim, The low pressure pilot (LPP) ore- E#"2~3-k~2j was defeated on 4/16/2048 when the well was returned to service after being shut in for an extended period of time. Current wellhead pressure is 27 psi; injection rate is 1958 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." It may be several weeks before the wellhead pressure builds back up to the point that the LPPs can be returned to service. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~ APR ~. ~ 2008 4/18/2008 • MICROFILMED 03/01/2008 DO NOT PLACE ~ " ~" , ,.. ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc 1S-~, DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031220 Well Name/No. KUPARUK RIV U WSAK 16-102 Operator~CONOCOPHILLIPS ALASKA INC MD 14044 ~ TVD 3850 ~ Completion Date 8/15/2003 ~ Completion Status _ ~__.._---~ Current Status 1WINJ API No. 50-029-23167-00-00 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med/Fmlt Number Name Scale Media No Start Stop CH Received Comments Log Injection Profile 5 Blu 1 7615 10975 4/28/2005 INJECTION PROFILE W/WELLTEC TRACTOR g Cement Evaluation 5 Col 1 4600 7614 Case 9/28/2003 Ultra Somic Imager- Cement Evaluation Log C Lis 12215 Induction/Resistivity 2-5 2985 14044 C ase 9/15/2003 LDWG edit t-~~ Induction/Resistivity 2-5 2985 14044 ~ • ck~e 9/15/2003 LDWG edit C Pds 12215 InductionlResistivity 25 2-5 530 14044 Case 9/15/2003 Multiple Propagation Resistivity -Gamma Ray ~g Induction/Resistivity 25 Blu 2-5 530 14044 ~ 9/15/2003 Multiple Propagation Resistivity -Gamma Ray ~Rpt Directional Survey 120 14044 11/20/2003 og Injection Profile 15 Blu 1 7800 11900 5/23/2005 TRACTOR-CONVEYED INJECTION PROFILE PSP: PRESS/TEMP/SPINS/DEVI ATION/TTC Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • c: DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031220 Weli Name/No. KUPARUK RIV U WSAK 1 B-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23167-00-00 MD 14044 ND 3850 ADDITIONAL INFORMATION Well Cored? Y Chips Received? '~'7'N~--' Analysis ~- Received? Comments: Completion Date 8/15/2003 Completion Status 1WINJ Current Status 1WINJ UIC Y Daily History Received? ~ N Formation Tops ~/ N Compliance Reviewed By: ~ Date: oC.~~ ~ RR ~l~~c} ~ • r ~ LJ ate.. •. v..~ vuia as fvv..vi u1 1 • u11u11V4 - L Viii./ ~LLL1VV VALV LLJLVLL llili... Subject: RE: West Sak Injector LPP Variance -Temp Variance extension request 1E-112 & 1B-102 From: NSK Problem Well Supv <n1617@conocophillips.com> ~ Date: Mon, 27 Jun 2005 08:07:02 -0800 3~, ~ ~~ ~ ~ a' To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: jim_regg@admin.state.ak.us a-C~~ - ~~, Tom, s~~ =--\-QCl Thanks for the quick response. ~-C~~-~ Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 27, 2005 7:54 AM To: NSK Problem Well Supv Cc: jim_regg@admin.state.ak.us Subject: Re: West Sak Injector LPP Variance -Temp Variance extension request 1E-112 & 1B-102 Marie, We did receive the "request" regarding the LPPs on WS wells and we are nearly finalized with "our" document. With regard to these specific wells, it is acceptable to defeat the LLP due to the low injection pressures. The LPP must be returned to service when the injection pressure reaches 500 psi. A copy of this authorization should be available should the Inspector request it. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Two low wellhead pressure West Sak injectors are planned to be brought on injection for reservoir diagnostics. Our records show the last temp LPP variance expired 6/20/05. CPAI would like to request another temp variance to defeat the LPPs on 1 E-112 and 1 B-102 for 30 days without a 24 hr man watch. 1 E-112 will be brought on injection as soon as an extension is granted. Downhole gauges were installed on 6/25/05 to record data for 30 days in conjunction with surface tiltmeter data gathering. The well has been ready to bring on injection, but operations is waiting on a variance extension. The well has been ', intermittently on injection in the last month with the injection wellhead pressure ranging between 0 to 35 psi. 1 B-102 will be BOI for a week in the next month when a production profile can be scheduled on 1 C-178. 1 B-102 will be BOI a few days prior to the PPROF and SI a few days later. The last time 1 B-102 was on injection for reservoir diagnostics the injection wellhead pressure ranged between 0 to 25 psi. On 6/13/05, Jerry sent a letter to the AOGCC requesting approval to defeat LPPs on West Sak water injectors with low tubing. pressure. Nas the AOGCC had a chance to consider this request? Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of 1 6/27/2005 8:25 AM KRU 1B-102 (PTD 2031220) • • Subject: KRU 1B-102 (PTD 2031220) From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, OS Apr 2005 12:33:47 -0800 To: Thomas Maunder <tom maunder@admn.state.ak.us> Tom, An (PROF has been completed and well 1B-102 has been SI as of 04-04-05. This is in reference to the variance received to inject with a defeated SSV on 1 B-102 due to the low injection pressure. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 1 of 1 4/7/2005 10:14 AM Re: Variance for 1B-102 (PTD 2031220) and 1E-112 (PTD 2040910) Subject: Re: Variance for 1B-102 (PTD 2031220) and 1E-112 (PTD 2040910) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 29 Mar 2005 10:56:02 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> Brad, Jerry, MJ, et al: Brad just sent in another request regarding a WS well operating on vacuum and when I searched for a reply regarding other wells, I was not able to find it. What you propose for 1B-102 and 1E-112 is acceptable. There is not a risk of the wells flowing to surface and avoiding nuisance trips helps prevent damaging the valve. Please keep us advised of the well operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Operations recommend that 300 psi is an adequate amount of pressure on the tubing to re-set the SSV pilots. At this pressure there shouldn't be any nuisance trips of the pilot due to fluctuations in the tubing pressure. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunderCa~admin.state.ak.us] Sent: Tuesday, March 08, 2005 9:19 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: Variance for 1B-102 (PTD 2031220) and 1E-112 (PTD 2040910) Brad/Jerry, Jim has asked me to get back with you. What is the threshold of 300 psi?? Thanks, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Jim, We are requesting a temporary variance from Conservation Order #4066, Rule 6, section b which requires SSVs for water injection wells 1 B-102 and 1 E-112. A temporary variance to operate 1 B-102 and 1 E-112 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Both wells are injecting on a vacuum and the SSV low pressure pilot can 1 of 2 3/29/2005 10:56 AM Re: Variance for 1B-102 (PTD 2031220) and 1E-112 (PTD 2040910) not be placed in service at this time. Neither well will flow to surface at this time. Both wells have a single check valve and an SSV. 30 days is requested to allow these wells to be on injection for reservoir diagnostic work. If the injection pressure increases during this period to at least 300 psi, the SSV will be put back in service. Based on the verbal approval date of 3/04/05, the wells will either be SI or the SSV will be back in service by 4/03/05. Notification will be made to AOGCC when either the well is SI or the SSV has been placed back in service. 1 B-102 has been shut in since 11/7/04 when water injection appeared to communicate directly with production wells. 1 E-112 is a new injector and has been on a vacuum since initial injection due to low bottom hole pressure. A downhole choke was installed to maintain wellhead injection pressure above the SSV pilot trip point. The downhole choke was removed in preparation for reservoir diagnostic work. 1 E-112 water injection appeared to communicate directly with production wells and the injector was shut-in 2/12/05. 1 B-102 was brought back on injection on 3/04/05. 1 E-112 was brought back on injection on 3/02/05. Electric-line injection profile logs are planned for reservoir diagnostics during the week of 3/07/05 for both 1 B-102 and 1 E-112. Once diagnostic work is completed, it is anticipated the wells will be SI while results are evaluated. Please let me know if you have any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 2 of 2 3/29/2005 10:56 AM 1B-102 Question and [Fwd: CD2-51 Approval to comm... Subject: 1B-10? Question and [Fwd: CD2-51 Approval to commence infection] ~r•om: ~~1;}~or~las ~~~aunder <tom maander@admi~l.state.~k.us> D~lte: ti1on, O~ Y)~C ?C)(i3 1 >:39:04-0900 To: Ste~~c Shultz ~Slc~~cn._N1.Shultz@conocophillips.com=> Hey Steve, I talked to Shane and he said that either you or McKeever were the ones to talk to on 1B-102. I just looked at the 407 and it says the well is a WAG. Is the well part of the West Sak FOR project from 1C and 1D?? If this well is not part of that project, it can't be a WAG. The only West Sak wells that have been approved to be WAG are the few involved with the FOR project. All other West Sak injection wells can only be water injectors. Attached is an example of what Cliff Crabtree sends me with regard to new Alpine injectors. He sends this information so I can look at it and do my assessment work with regard to isolation for mechanical integrity. Is it possible for you to send me the same information?? The only other piece of information that is not here is the "1320 plot" which looks at all the penetrations within 1/4 mile radius of the new wellbore. For West Sak wells that could be quite a number of wells given the Kuparuk wells being drilled there as well. For most cases I primarily use where the new well penetrates the producing horizon or maybe in this case the 9-5/8" shoe since it does not appear that the shoe was set into .the West Sak C. It is also important to look at where the new horizontal portion is in relation to other wells. I will find one of the 1320 plots and send it to you as well. Do you think you can provide this information?? Thanks. Tom Maunder, PE AOGCC -------- Original Message -------- Subject: CD2-51 Approval to commence injection Date: Mon, 19 May 2003 16:11:37 -0800 From: Clifford L Crabtree <C.L.Crabtree~conocophillips.corn> To: Winton aubertvadmin.state.ak.us, Tom Maunder <tom maunder~admin.state.ak,us> CC: Christopher J. Alonzo <Chris.Alonzo@conocophillips.com> Winton/Tom Attached you will find a tubing detail and bond log for Alpine Injection well 2-51. This Cement Bond Log indicates good to excellent bond across the interval that was possible to log using conventional e-line 1 of 3 12/8/2003 1:43 PM MEMORAND~ State o~aska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ ~z,l~Jl~ DATE: December 5, 2003 P.I. Su ervisor;~ P FROM: Jeff Jones Petroleum Inspector SUBJECT: Mechanical Integrity Tests Conoco-Phillips Alaska Inc. 1 B Pad 1 B-102 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 16-102 Type Inj. S T.V.D. 3608 Tubing 1200 1150 1150 1000. Interval P.T.D. °2tf3922 Tyape test P Test psi 1500 Casing 200 2000 1980 1980 P/F P Notes: Type INJ. Fluid Codes Type Test Interval F =FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G =GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S =SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N =NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details December 5, 2003: I trammeled to Conoco-Phillips Alaska Inc.'s (CPAI) Kuparuk River Feld to witness an initial MIT on injection well 1B-102. Dennis Sa~ageau was the CPAI representative for the test today, which he performed in a safe and proficient manner. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with the well passing the MIT. Summary: I witnessed a successful initial MIT on CPAI's Kuparuk River Field well 1B-102. M.I.T.'s performed: 1 Number of Failures: 0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT KRU 1 B-102 12-5-03 JJ.xls 12/10/2003 . ConocðPhiUips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 3, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 18-102 (APD # 203-122/303-195) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 18-102. If you have any questions regarding this matter, please contact me at 265-6830 or Shane Cloninger at 265-6829. Sincerely, ~ft~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling RT /skad RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage OR\G\N/~L · STATE OF ALASKA a ALA . OIL AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U ~ ~WDSPL D GINJ D WINJ 2. Operator Name: Plugged D Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 502' FNL, 190' FEL, Sec. 9, T11N, R10E, UM At Top Productive Horizon: 799' FSL, 185' FWL, Sec. 2, T11N, R10E, UM Total Depth: 3731' FNL, 1036' FEL, Sec. 34, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550250 y- TPI: x- 555893 y- Total Depth: x- 554618 ,. y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes, US IT 22. CASING SIZE WT. PER FT. 62.5# 68# 40# 15.5# GRADE H-40 L-80 L-80 L-80 16" 13-318 " 9-518" 5.5" 5969647 5970987 5977008 Zone-4 Zone-4 Zone- 4 Suspended 0 WAG r 20AAC 25.110 Other - 5. Date Comp., Susp., or Aband.: August 15, 2003 6. Date Spudded: July 28, 2003 7. Date TD Reached: August 11, 2003 . 8. KB Elevation (ft): RK6 28' I 89' AMSL 9. Plug Back Depth (MD + TVD): 13947' MD 13841' TVD 10. Total Depth (MD + TVD): 14044' MD 13850' TVD 11. Depth where SSSV set: Land Nipple @ 524' 19. Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 120' Surface 521' Surface 7796' 7620' 14036' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotted liner 26. Date First Production November 28, 2003 Date of Test Hours Tested N/.A Flow Tubing HOLE SIZE 42" 14.75" 12.25" 132 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED 1b. Well Class: Development D Exploratory D Service 0 Stratigraphic Test D 12. Permit to Drill Number. . 203-122/303-195 13. API Number: 50-029-23167-00 14. Well Name and Number. 16-102 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25649 & 25639 17. Land Use Permit: ALK 467 & 464 20. Thickness of Permafrost: 2985' MD 8.5" slotted liner 103 sx AS Lite 900 sx AS III Lite, 430 sx LiteCrete 24. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 7661' PACKER SET (MD) 7620' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL Casing Pressure press. psi 24-Hour Rate -> WATER-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if neces.,.,: '" ,,~t: I \ I ¡;;: 0 Submit core chips; if none, state "none". - - y L.. DEC - 5 2003 ..B.:'/f:. Q;( ;~'¡':""-'..: t: ::.í," ,. _ ',' ,~ ¡ r -, ._~._",.. ,.\."...~.;-...._.,..-..........-.\.;.,,¡....,j Form 10-407 Revised 2/2003 RBDM& BFL DEC NONE ~ 4003 CONTINUED ON REVERSE SIDE u. li~¡~L Alaska Oil & Gas Cons. Commission Anchorage ~ \9 Submit in duplicate 28. 29. . GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 B-1 02 West Sak C 8045' 3750' West Sak C 8724' 3778' West Sak C 10394' 3765' West Sak C 11588' 3791' West Sak C 13540' 3810' West Sak D 7858' 3703' West Sak D 9002' 3758' West Sak D 11 B27' 3773' West Sak D 12B75' 3767' NIA RECEIVED DEC - 5 2003 Alaska Oil & Gas (;ons. 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 Shultz @ 263-4620 Printed Na~ R. Thomas TItle: KUDaruk DriJlinQ Team Leader \ G. l 3 10 "3 Signature \ _C J~..... ·~hone 26S- -6~ SO Date J 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 íníection, 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 Iníection, 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 1 0-407 Revised 2/2003 r.!~'^f c~'" .~ /~ A ...... ConocoPhillips Alaska Page 1 of 7 Operations Summary Report Legal Well Name: 1 B-1 02 Common Well Name: 1 B-1 02 Spud Date: 7/28/2003 Event Name: ROT - DRILLING Start: 7/27/2003 End: 8/15/2003 Contractor Name: n1334@ppco.com Rig Release: 8/15/2003 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours I Code. Sub Phase ..Description of Operations . Code ... - 7/27/2003 16:00 - 16:15 0.25 MOVE SFTY MOVE Held PJSM with Peak drivers and rig crew on moving rig 16:15 - 18:00 1.75 MOVE DM06 MOVE Move & staged rock washer, pipe sheds, pits, pumps, motors and boiler modules 18:00 - 18:30 0.50 MOVE MOVE MOVE Moved sub off 16-20 and moved 630' down pad line and lined up on well 16-102 18:30 - 19:30 1.00 MOVE POSN MOVE Spotted sub over 1 B-1 02 conductor 19:30 - 22:15 2.75 MOVE MOVE MOVE Lay mats for utility modules and spot pits, pumps, mtrs, boilers, rock washer and pipe sheds 22:15 - 23:00 0.75 MOVE RURD RIGUP Fin Rigging up and completed pre-spud check list, ACCEPTED RIG at 23:00 HRS 7/27/03 23:00 - 00:00 1.00 WELCTL NUND RIGUP NU 21 1/4" Divertor and 16" divertor line 7/28/2003 00:00 - 01 :00 1.00 WELCTL NUND RIG UP Finish NU Diverter & line 01 :00 - 03:00 2.00 RIGMNT RSRV RIGUP Changed over top drive saver sub and grabber dies from 4" to 5" 03:00 - 04:00 1.00 RIGMNT RSRV RIG UP Cut & slip 79' of drlg line 04:00 - 04:30 0.50 RIGMNT RSRV RIG UP Serviced Top drive & drawworks 04:30 - 05:00 0.50 WELCTL 60PE RIGUP Performed divertor and accumulator test, NOTE: John Crisp, with AOGCC waived witnessing of test 05:00 - 06:30 1.50 DRILL PULD RIGUP PU 29 jts 5" HWDP & Jars, & stood back 06:30 - 08:00 1.50 DRILL PULD RIGUP MU 14-3/4", 6HA #1 08:00 - 08:15 0.25 DRILL SFTY RIGUP Held PJSM on est Circ, testing lines and spudding well 08:15 - 08:45 0.50 DRILL OTHR RIGUP Filled hole and checked surface lines for leaks, pressure tested surface lines to 3,500 psi & ck ok 08:45 - 09:15 0.50 DRILL RIRD RIGUP RU HES Slickline for Gyro 09:15 - 14:00 4.75 DRILL DRLG COND1 Spud well & drill 14-3/4" hole from 120' to 530' MD/528' TVD, (410') ART -0-, AST 2 hrs, 5-15K wob, 420 gpm at 600 psi, rot wt 57K, pu 57K, dn wt 57K, Gyro survey at 210' & 530' & ck ok. T.D. for gravel string 14:00 - 14:30 0.50 DRILL RIRD COND1 RD HES slickline 14:30 - 18:00 3.50 DRILL REAM COND1 Backreamed hole prior to running 13-318" csg, backreamed from 530' to 1203 times, circ at 550 gpm at 900 psi and 80 rpms 18:00 - 18:45 0.75 DRILL PULD COND1 POOH, stood back flex dc's, LD U6HO sub, MM & bit 18:45 - 20:00 1.25 CASE RURD COND1 RU Doyon's 13-3/8" Csg tools and Franks fill up tool 20:00 - 21 :15 1.25 CASE OTHR COND1 PU landing jt & tightened nipple below hanger and torqued up landing jt, made dummy run with hanger 21:15 - 21:30 0.25 CASE SFTY COND1 Held PJSM with rig crew, Dowell and vac truck drivers on circ & cementing 13 3/8" gravel string 21 :30 - 22:30 1.00 RIGMNT RSRV COND1 Changed out air boot on riser 22:30 - 00:00 1.50 CASE RUNC COND1 MU 133/8" Float shoe on jt #1 and thread locked conn, RIH with 13 318" 68# L-80 BTC csg to 370' 7/29/2003 00:00 - 01 :00 1.00 CASE RUNC COND1 Fin running 13318" csg, MU Vetco Gray hanger and landed csg with float shoe at 521 '. Ran a total of 12 jts, (487.6') of 68# L-80 BTC csg 01 :00 - 01 :45 0.75 CASE RURD COND1 RD Franks fill up tool, MU Dowell cmt head and chained down 01 :45 - 02:00 0.25 CEMEN SFTY COND1 Held PJSM with rig crew, vac truck drivers and Dowell on circ & cementing 13 3/8" csg 02:00 - 03:00 1.00 CEMEN CIRC COND1 Circ & cond mud for cementing, lowered YP from 60 to 10, staged circ rate up to 4 bpm at 90 psi with full returns. Finish condo with 9.0 ppg mud, 10 YP back to surface. Csg landed in hanger, did not reciprocate pipe. 03:00 - 03:30 0.50 CEMEN PUMP COND1 Turned over to Dowell, pumped 5 bbls fresh water, pressure tested lines to 3,500 psi, pumped 5 add bbls FW spacer, dropped btm plug, mixed & pumped 78 bbls, (102 sxs) of ASlite cmt, with additives at 10.7 ppg, 4.28 yield. Pumped at an ave 3 bpm at 100 psi, shut down & dropped top plug. Printed: 10/8/2003 3:54: 13 PM Page 2 of 7 ConocoPhillips Alaska Operations Summary Report 0.75 CEMEN DISP COND1 Dowell pumped 2 bbls cmt and 8 bbls of clean up water on top of plug and tumed over to rig, rig finish displacement with 67 bbls of 9.0 ppg mud, displaced cmt at ave of 2.5 bpm at 100 psi, bumped plug to 600 psi, check floats - held. CIP at 04:15 Hrs, had good retums during job with 25 bbls of 10.7 ppg cmt back at surface. RD Dowell cement head LD landing jt & RD Doyon's csg equipment, changed out elevator bales and cleaned rig floor PU & stood back 231 jts of 5" DP MU BHA #2, 12 1/4" Bit with MWD & Oriented same, TIH with HWDP & tagged cmt on plugs at 517' Drilled out cement, plugs and float shoe at 521', cleaned out to TD at 530' Drill 12 1/4" hole per directional plan, drill, slide & survey from 530' to 1,066' MD/1,042' TVD, (536') ART 1.9 hrs, AST 1.5 hrs, 10-25K wob, 50-60 rpm's, 106 spm, 450 gpm, off btm press 750 psi, on btm 1,000 psi, off btm torque 2K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 89K, dn wt 81K, 9.0 ppg mw 125-200 vis 12.00 DRILL DRLG SURFAC Drill, slide & survey 12 1/4" hole per directional plan from 1,066' to 2,1801 MD/1 ,831' TVD, (1,114') ART 1.6 hrs, AST 5.2 hrs, 5-30K wob, 60-100 rpm's, drilled to 1,995' at 130 spm at 550 gpm, off btm press 1,150 psi, on btm 1,225 psi, increased rate to 160 spm, 670 gpm, off btm press 1,300 psi, on btm 1,475 psi, off btm torque 3K ft-Ibs, on btm 5K, rot wt 91K, pu wt 100K, dn wt 87K, 9.0 ppg mw 170 vis 7.00 DRILL DRLG SURFAC Drill slide & survey from 2,180' to 3,022' MD/2, 132' TVD (842') ART hrs, AST hrs, 5-30K wob, 100 rpm's, 160 spm, off btm press 1,470 psi, on btm 1,600 psi, off btm torque 4K ft-Ibs, on 6K, rot wt 88K, up wt 100K, dn wt 80K, MU ghost reamer in string at 2,180' to assist in cleaning out clay build up Pumped weighted hi vis sweep & circ out, circ add btms up and clean at shakers, circ at 675 gpm at 1,450 psi and 100 rpm's Precautionary backreamed out from 3,022' to 1,720' at 550 gpm 1,200 psi at 100 rpm's, no problems, LD ghost reamer POOH wet to 72', stood back HWDP and flex dc's LD short dc, nm stab, MWD, MM & bit, cleared rig floor PU Baker's 81/4" Autotrak tool & programmed, MU bit #3 & BHA #3, pulse tested tool, TIH to 1,050', retested tool & ck ok "Note" Ghost reamer is in string @ top of HWDP ( 1046' behind bit) TIH from 1,050' to 3,000' with no problems Washed 22' to btm with no problems, downlinked Autotrak tool Drilled 12 1/4" hole from 3,022' to 3,450' MD/2,279' TVD (428') ADT 5.2 hrs, 5-20K wob, 100-150 rpm's, 153 spm, 650 gpm at 1,500 psi, off btm torque 5K, on btm 7K, rot wt 88K, up wt 104K, dn wt 77K, 9.0 ppg mw 12.00 DRILL DRLG SURFAC Drilled from 3,450' to 4,206' MD/2,527' TVD, ADT 7.1 hrs, 10-20K wob, 150 rpms, 153 spm, 650 gpm, off btm press 1,500 psi, on btm 1,560 psi, off btm torque 6K, on btm 7K, rot wt 95K, up wt 115K, dn wt 78K, 9.0 ppg mwand ave 78 vis NOTE: Recieved approval from AOGCC to annular inject on 1 B-20 12.00 DRILL DRLG SURFAC Drilled 12 1/4" hole from 4,206' to 5,057' MD/2,810' TVD, (851') ADT 7.3 hrs, 10-30K wob, 150 rpm's, 153 spm, 650 gpm, 1,725 psi, off btm torque 10K ft-Ibs, on btm 14K ft-Ibs, rot wt 99K, up wt 138K, dn wt 75K, 9.0 ppg mw, 71 vis Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-1 02 1B-102 ROT - DRILLING n1334@ppco.com Doyon 141 Date From - To ¡ Hours! Code ,J~dbe. Phase 7/29/2003 03:30 - 04:15 04:15 - 04:45 0.50 CEMEN PULD COND1 04:45 . 07:30 2.75 CASE RURD COND1 07:30·15:45 8.25 DRILL PULD COND1 15:45 - 18:15 2.50 DRILL PULD COND1 18:15 - 18:30 0.25 CEMEN DSHO COND1 18:30 - 00:00 5.50 DRILL DRLG SURFAC 7/30/2003 00:00 - 12:00 12:00 - 19:00 19:00 - 20:00 1.00 DRILL CIRC SURFAC 20:00 - 21 :30 1.50 DRILL REAM SURFAC 21 :30 - 23:00 1.50 DRILL TRIP SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 7/31/2003 00:00 - 03:00 3.00 DRILL TRIP SURFAC 03:00 - 04:15 1.25 DRILL TRIP SURFAC 04:15 - 04:45 0.50 DRILL REAM SURFAC 04:45 - 12:00 7.25 DRILL DRLG SURFAC 12:00 - 00:00 8/1/2003 00:00 - 12:00 Start: 7/27/2003 Rig Release: 8/15/2003 Rig Number: Spud Date: 7/28/2003 End: 8/15/2003 Group: Description of Operations Printed: 10/8/2003 3:54: 13 PM Page 3 of 7 ConocoPhillips Alaska Operations Summary Report 5.00 DRILL DRLG SURFAC Drilled from 5,057' to 5,320' MD/2,895' TVD (263') ADT 3.6 hrs, 10-30K wob, 150 rpm's, 153 spm, 650 gpm, 1,750 psi, off btm torque 11k ft-Ibs, on btm 13K ft-Ibs, rot wt 100K, up wt 150K, dn wt 65K, decision made to wipe hole due to increase in up wt & drop in dn wt, pumped wt'd hi vis sweep (2# over mw) and had no change in cuttings back from sweep. Precautionary backreamed out (15 stds) from 5,320' to 3,930' with no problems, Circ at 650 gpm at 1,500 psi and 150 rpm's TIH washing 93' to btm with no problems, pumped wt'd hi vis sweep on btm Drilled from 5,320' to 5,598' MD/2,976' TVD, (278') ADT 2 hrs at btms up with wt'd sweep had 75% increase in cuttings back, pumped 2nd sweep and had very little back, drilled at 10-25K wob, 150 rpm's, increased pump rate to 164 spm, 695 gpm at 1,800 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 100K, up wt 155K, dn wt 65K 12.75 DRILL DRLG SURFAC Drilled 12 1/4" hole from 5,598' to 6,770' MD/3,368' TVD, ADT 8 hrs, 1 0-25K wob, 150 rpm's, 64 spm 693 gpm, 2,150 psi, off btm torque 15.5K ft-Ibs, on btm 17K, rot wt 112K, up wt 160K, dn wt 77K, 9.1 ppg mw, 78 vis, Autotrak tool failed Precautionary beackreamed out from 6,770' to 2,815', backreamed at 675 gpm at 1 ,800psi and 150 rpms with no problems POOH on elevators to 1,052' (BHA) Stood back HWDP, & flex dc's, ghost reamer in gauge, LD NM Stab from above Autotrak, stab 75% worn, LD 8 1/2" Autotrak and 12 1/4" PDC bit PU & made dummy run with Vetco Gray 9 5/8" landing jt & hanger & ck ok MU BHA #4, new 121/4" bit #4 on new 8 1/4" Autotrak tool & programmed same, TIH with BHA & 1 std of hwdp Serviced top drive & blocks TIH with BHA #4 and 1 std of 5" dp to 1,144' and pulse tested Autotrak &MWD TIH from 1,144' to 6,436' with no problems Reamed 334' from 6,436' to btm taking check shots w/reaming, no problems reaming, circ at 640 gpm, 2,000 psi at 60 rpm's Drilled 12 1/4" hole from 6,770' to 7,803' MD/3,689' TVD (1,033') 95/8" csg point, ADT 12.5 hrs, 10-30K wob, 150 rpm's, 164 spm, 693 gpm, 2,375 psi, rot wt 112K, up wt 163K, dn wt 80K, torque off btm 12.5K ft-Ibs, on btm 16K ft-Ibs, 9.1 ppg mwand 80 vis. NOTE: While drilling Ugnu "A" sand hit Calcite Concretion section at 7,010' to 7,020' MDI 3,447' to 3,453' TVD that drilled at 2-3'lhr Began precautionary backreaming out 15 stds for wiper trip prior to POOH to run csg, backreaming out from 7,803' to 7,457' at 693 gpm, 2,375 psi at 150 rpms with no problems Precautionary backreamed out for wiper trip from 7,457' to 6,436' with no problems, circ at 693 gpm, 2,300 psi at 150 rpm's TIH, washed 70' to btm with no problems Circ hole clean prior to running csg, circ 2-50 bbl wt'd hi vis sweeps back to back and had less than 10% increase in cuttings back from both sweeps, cont to circ 2 add btms up, clean at shakers after 2nd sweep out, circ at 693 gpm, 2,475 psi at 150 rpm's, rot wt 112K, up wt 160K, dn wt 77K, 9.2 mw in & out with 80 vis (circ total of 4x btms up) 4.50 DRILL TRIP SURFAC Monitored well-static, POOH 20 stds to 5,950' with no problems, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-1 02 1 B-1 02 ROT - DRILLING n 1334@ ppco.com Doyon 141 Date From - To Hours Code. cfouJe phase M _________. 8/1/2003 12:00 - 17:00 17:00 - 19:15 2.25 DRILL REAM SURFAC 19:15 - 20:15 1.00 DRILL TRIP SURFAC 20:15 - 00:00 3.75 DRILL DRLG SURFAC 8/2/2003 00:00 - 12:45 12:45 - 18:30 5.75 DRILL REAM SURFAC 18:30-19:15 0.75 DRILL TRIP SURFAC 19:15 - 21:00 1.75 DRILL PULD SURFAC 21:00 - 21:15 0.25 DRILL OTHR SURFAC 21:15 - 22:45 1.50 DRILL PULD SURFAC 22:45 - 23: 15 0.50 RIGMNT RSRV SURFAC 23:15 - 00:00 0.75 DRILL TRIP SURFAC 8/3/2003 00:00 - 02:00 2.00 DRILL TRIP SURFAC 02:00 - 04:00 2.00 DRILL REAM SURFAC 04:00 - 23:00 19.00 DRILL DRLG SURFAC 23:00 - 00:00 1.00 DRILL REAM SURFAC 8/4/2003 00:00 - 01:15 1.25 DRILL REAM SURFAC 01 :15 - 01 :45 0.50 DRILL TRIP SURFAC 01:45 - 06:15 4.50 DRILL CIRC SURFAC 06:15 - 10:45 Start: 7/27/2003 Rig Release: 8/15/2003 Rig Number: Spud Date: 7/28/2003 End: 8/15/2003 Group: Description of Operations Printed: 10/8/2003 3:54: 13 PM Page 4 of 7 ConocoPhillips Alaska Operations Summary,Report pumped dry job & cont POOH to BHA at 1,052' Monitored well at BHA-static, stood back HWDP, downloaded MWD/Autotrak, LD BHA #4 RU Doyon's 9 5/8' csg equipment, changed out elevator bales and MU franks fill up tool Held PJSM on running of 9 5/8' csg MU 9 5/8' float shoe, 2 jts of 9 5/8" 40# L-80 BTC Csg, float collar, thread locked shoe track and ck fit equip, cont RIH with 72 its 9 5/8' csg to 3,000', installed centralizers per well program. csg up wt 116K, dn wt 70K Circ csg cap at 3,000', staged pump rate up to 8 bpm at 400 psi RIH with additional 63 jts of 9 5/8" (135 total) to 5,688', no problems, csg up wt 215K, dn wt 60K Circ btms up at 5,688', staged pump rate up to 8 bpm at 500 psi, up after btms up 195K, dn 75K, 9.3 ppg mw in & out RIH with additional 15 its of 9 5/8' csg to 6,225', csg up wt 255K, dn wt 60K Continue to run 9-5/8' casing to 7,767' 325K UP 60K DN Make up hanger & Landing joint, Tag landing ring wI hanger wI shoe @ 7796' Circ. & Condo mud, Reciprocate pipe, Stage pump rate up slow fl 2 bpm to 4 bpm @ 490 psi, UP 260K DN 75K (Pumped total of 6250 stks) Lay down Frank's fill up tool & Pick up Dowell cement head. Circ & Cond mud, Reciprocate casing UP 265K, DN 100K, Stage pump rate up to 6.5 bpm @ 300 psi, Start circ = PV 30, YP 42, vis 145, 9.6 ppg. Finish PV 14, YP 15, vis 44,9.3 ppg. 4.50 CEMEN PUMP SURFAC Held PJSM, Rig Dowell, Mix & pump 5 bbls CW100, Test lines to 3000 psi, Mix & pump 45 more bbls of 8.3 ppg CW100 at rate of 6.7 bpm @ 280 psi, Mix & pump 50 bbls MudPUSH wI Red dye added at 10.5 ppg at rate of 5.8 bpm @ 230 psi, Shut down, Drop btm plug, Switch to Lead cmt, Mix & pump 709.4 bbls (900 sxs) of ArcticSet Lite cmt. mixed at 10.7 ppg w/1.5%D79, 1.5%S001, .6%D46, .5%D65, 43.1%D124, 30.0%D53, 9.0%D44 at rate of 7.0 bpm @ 400 psi, Followed by 84.7 bbls LiteCRETE Tail cmt (430 sxs) mixed at 15.8 ppg w/.3%D65, .2%D46, .4%D167, .7%S001 at rate of 6.1 bpm @ 180 psi, Shut down, Drop tpo plug, Displace cmt. wI 20 bbls fresh water followed by total of 565.0 bbls 9.3 ppg mud at rate of 7.0 bpm @ 1400 psi, Had red dye to surface after 242 bbls of displacement, Slowed rate down to 3.0 bpm @ 1400 psi for last 20 bbls of displacement, Bump plug wI 1900 psi, CIP @ 1620 hrs 8/5/03, Had good circ. thru out job, Had 126 bbls cmt returns to surface, Floats held - OK, Worked csg until started pumping tail cmt., Float Shoe @ 7796', Float Collar @ 7706', Tam Port Collar @ 1008'. Rig down cement head, Landing it., casing equip. Nipple down diverter system, Wash out annular Nipple up Vetco Gray Wellhead & test to 1500 psi f/10 min. Nipple up BOPE Change btm pipe rams to 5", Change out bails on top drive Rig to test BOPE Test BOPs - Test all BOPs & Choke Manifold 250psi 10 & 5000 psi high. Test annular 250 psi 10 & 3500 psi high. No failures on any equip. AOGCC rep Chuck Scheeve waived witness test. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1B-102 1 B-1 02 ROT - DRILLING n 1334 @ ppco.com Doyon 141 Date From - To, Hours Code Sub Phase Code 8/4/2003 06:15 - 10:45 4.50 DRILL TRIP SURFAC 10:45 - 13:00 2.25 DRILL PULD SURFAC 13:00 - 14:30 1.50 CASE RURD SURFAC 14:30 - 15:00 0.50 CASE SFTY SURFAC 15:00 - 18:45 3.75 CASE RUNC SURFAC 18:45 - 19:30 0.75 CASE CIRC SURFAC 19:30 - 22:00 2.50 CASE RUNC SURFAC 22:00 - 23:00 1.00 CASE CIRC SURFAC 23:00 - 00:00 1.00 CASE RUNC SURFAC 8/5/2003 00:00 - 01 :30 1.50 CASE RUNC SURFAC 01 :30 - 01 :45 0.25 CASE RUNC SURFAC 01 :45 - 05:00 3.25 CASE CIRC SURFAC 05:00 - 05:30 0.50 CEMEN PULD SURFAC 05:30 - 12:00 6.50 CEMEN CIRC SURFAC 12:00 - 16:30 16:30 - 17:15 0.75 CEMEN PULD SURFAC 17:15 - 19:30 2.25 WELCT NUND SURFAC 19:30 - 20:15 0.75 WELCT NUND SURFAC 20:15 - 22:00 1.75 WELCT NUND SURFAC 22:00 - 23:30 1.50 WELCT NUND SURFAC 23:30 - 00:00 0.50 WELCT BOPE SURFAC 8/6/2003 00:00 - 03:00 3.00 WELCT BOPE SURFAC Start: 7/27/2003 Rig Release: 8/15/2003 Rig Number: Spud Date: 7/28/2003 End: 8/15/2003 Group: Description of Operations Printed: 10/8/2003 3:54:13 PM · .... a ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 B-1 02 Common Well Name: 1 B-1 02 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date ~rom - To Hours Code Sub Phase Code -0 0 8/6/2003 03:00 - 03:30 0.50 WELCTL BOPE SURFAC 03:30 - 12:00 8.50 DRILL PULD SURFAC 12:00 - 14:00 2.00 DRILL TRIP SURFAC 14:00 - 16:30 2.50 DRILL TRIP SURFAC 16:30 - 18:00 1.50 DRILL PULD SURFAC 18:00 - 22:00 4.00 DRILL TRIP SURFAC 22:00 - 23:15 1.25 RIGMNT RSRV SURFAC 23: 15 - 23:45 0.50 DRILL CIRC SURFAC 23:45 - 00:00 0.25 DRILL DEOT SURFAC 8/7/2003 00:00 - 01 :00 1.00 CASE DEOT SURFAC 01 :00 - 02:30 1.50 DRILL DRLG SURFAC 02:30 - 03:00 0.50 DRILL CIRC SURFAC 03:00 - 04:00 1.00 DRILL CIRC SURFAC 04:00 - 05:00 1.00 DRILL FIT SURFAC 05:00 - 12:00 7.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 8/8/2003 00:00 - 01 :00 1.00 DRILL DRLH PROD 01 :00 - 03:00 2.00 DRILL DEOT PROD 03:00 - 04:45 1.75 DRILL TRIP PROD 04:45 - 05:00 0.25 DRILL OBSV PROD 05:00 - 09:30 4.50 DRILL TRIP PROD 09:30 - 12:00 2.50 DRILL PULD PROD 12:00 - 15:30 3.50 DRILL TRIP PROD 15:30 - 16:30 1.00 DRILL REAM PROD 16:30 - 00:00 7.50 DRILL DRLH PROD 8/9/2003 00:00 - 09:00 9.00 DRILL DRLH PROD 09:00 - 10:00 10:00 - 14:00 1.00 RIGMNT RGRP PROD 4.00 DRILL DRLH PROD 14:00 - 15:30 1.50 RIGMNT RGRP PROD Page 5 of 7 Start: 7/27/2003 Rig Release: 8/15/2003 Rig Number: Spud Date: 7/28/2003 End: 8/15/2003 Group: Description of Operations --_. Pull test plug - Install wear bushing TIH picking up 5" DP form pipe shed ( Install 1 Lo Tad roller sub per std) 63 total POOH & Stand back in derrrick Pick up AutoTrak BHA, Make up bit, Pick up & program MWD, RIH w/2 std's HWDP & test MWD tools. Note; 1.5 hrs spent troubleshooting PWD tool, Found problem to be a failed AutoTrak surface power suppy- Unable to communicate with PWD tool- PWD tool not working. RIH to Float collar @ 7706', Rotated thru port collar @ 1008', Fill pipe & test AutoTrak down link @ 4061'. Circ. at 2.5 bpm @ 200 psi while Cut & slip drilling line 97', Service top drive & blocks. Circ. btm's up, 500 gpm @ 1500 psi. Rig up to test 9-5/8" csg. Test 9-518" casing to 1500 psi for 30 min.- OK. Drill out float collar @ 7706', Cement, Float shoe @ 7796' & 20' of new hole to 7823' 3694' TVD Circ btm's up wI 590 gpm @ 2000 psi. Change over to 9.1 ppg FLO-PRO NT Mud Perform FIT to 14.0 ppg EMW wI 944 psi, 9.1 ppg Mud, 3687' TVD Drill wI AutoTrak f/7823' to 8400' 3787' TVD ADT = 5.4 hrs, WOB 5-10, 150 RPM, 600 GPM, 2050 psi, UP 142K, DN 94K, ROT 112K, TO off 7.7 I on 9.2 Drill wI AutoTrak fl 8400' to 9460' (3738' TVD) ADT = 7.6 hrs, WOB 5-15,150 RPM, 600 GPM, 2150 psi, UP 128K, DN 77K, ROT 100K, TO off 7.0 I on 10.5 Drill wI AutoTrak f/9460' to 9594' (3734' TVD) ADT = 08 hrs, WOB 5-15,150 RPM, 600 GPM, 2150 psi, UP 128K, DN 77K, ROT 100K, TO off 7.0 I on 10.5 Resistivity tool failed on LWD, Downlink several times & Trouble shoot same - no good. Back ream out of to shoe @ 7796',500 GPM @ 70 RPM, Open hole in very good shape. Monitor well - OK, Dry pipe POOH, Set back BHA, Lay down AutoTrak Change out Resistivity tool on LWD, Pick up BHA #6, RIH to 420, Pulse test BHA RIH, Rotate by port collar @ 1008', Fill pipe @ 4980', RIH to 9453' - No problems going in hole. Wash & ream f/9453' to 9594' & Make Mad pass for lost interval. Drill wI AutoTrak f/9594' to 10221' (3753' TVD) ADT = 4.7 hrs, WOB 5-15,150 RPM, 600 GPM, 2175 psi, UP 135K, DN 75K, ROT 104K, TO off 9.0 I on 11.0 Drill wI AutoTrak f/10221' to 10991' ADT= 5.0 hrs, WOB 10-15, 150 RPM, 600 GPM, 2450 psi, UP 150K, DN 80K, ROT 108K, TO off 11.0 I on 12.0, ECD's Range f/11.5 to 11.8 ppg, Pump sweep @ 10,600' wI 35% increase of cuttings Repair & Replace Expansion boot on #2 Cat motor. Drill wI AutoTrak f/1 0991' to 11350' ADT = 2.6 hrs, WOB 10-15, 150 RPM, 600 GPM, 2500 psi, UP 150K, DN 80K, ROT 108K, TO off 11.0 I on 12.0, ECD's Range f/11.5 to 11.8 ppg. Lost Rig power due to Engines over heating. Printed: 10/8/2003 3:54:13 PM ..... a ConocoPhillips Alaska Operations Summary Report Legal Well Name: 18-102 Common Well Name: 18-102 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date ~m - To Hours:Code 8/9/2003 15:30 - 00:00 8.50 DRILL .. '~o~ase DRLH PROD 8/10/2003 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 8/11/2003 00:00 - 05:15 5.25 DRILL DRLG PROD 8/12/2003 05:15 - 07:15 2.00 DRILL CIRC PROD 07:15 - 07:30 0.25 DRILL OBSV PROD 07:30 - 08:00 0.50 DRILL CIRC PROD 08:00 - 08:15 0.25 DRILL OBSV PROD 08:15 - 12:00 3.75 DRILL REAM PROD 12:00 - 13:45 1.75 DRILL REAM PROD 13:45 - 14:15 0.50 DRILL CIRC PROD 14:15 -18:45 4.50 DRILL REAM PROD 18:45 - 19:00 0.25 DRILL OBSV PROD 19:00 - 20:45 1.75 DRILL CIRC PROD 20:45 - 21 :30 0.75 DRILL TRIP PROD 21 :30 - 00:00 2.50 DRILL TRIP PROD 00:00 - 01 :30 1.50 DRILL PULD PROD 01 :30 - 03:00 1.50 DRILL PULD PROD 03:00 - 03:30 0.50 CASE OTHR PROD 03:30 - 04:00 0.50 CASE RURD CMPL TN 04:00 - 09:30 5.50 CASE RUNL CMPL TN 09:30 - 10:00 0.50 CASE RURD CMPL TN 10:00 - 17:00 7.00 CASE RUNL CMPL TN 17:00 - 17:30 0.50 CASE RURD CMPL TN 17:30 - 19:00 1.50 CASE RURD CMPL TN 19:00 - 20:30 1.50 CASE RUNL CMPL TN 20:30 - 21 :30 1.00 CASE CIRC CMPL TN 21 :30 - 00:00 2.50 CASE RUNL CMPL TN 00:00 - 04:00 4.00 CASE RUNL CMPL TN 04:00 - 05:00 1.00 CASE CIRC CMPL TN 05:00 - 06:30 1.50 CASE CIRC CMPL TN 8/13/2003 Page 6 of 7 Start: 7/27/2003 Rig Release: 8/15/2003 Rig Number: Spud Date: 7/28/2003 End: 8/15/2003 Group: Description of Operations - - Drill wI AutoTrak f/11350' to 11955' (3762' TVD) ADT= 6.0 hrs, WOB 5-18,150 RPM, 600 GPM, 2600 psi, UP 135K, DN 70K, ROT 99K, TO off 11.0 I on 12.5, ECD's Range f/11.5 to 11.8 ppg, Pump sweep @ 11,700' wI 35% increase of cuttings. Drlg wI AutoTrak f/11 ,955' to 12,822'MD (3763' TVD) ADT 8.3 hrs - RPMs 150, WOB 5-10k, PP 2600 psi, SPM 142, 602 GPM, Up wt 157k, Dn wt 70k, Rot 105k, ECDs 11.87 Drlg wI AutoTrak f/12822' to 13592'MD (3811' TVD) ADT 7.4 hrs- RPMs 150, WOB 5/18k, PP 2725 psi, SPM 140, 592 GPM, Up wt 145k, Dn wt 60k, Rot 100k, ECDs 12.07 - Pump Wt/ hi vis sweeps as needed to maintain clean hole. Avg of every 800' drilled. Drlg wI AutoTrak f/13592' to 14044'MD (3850' TVD) ADT 3.7 hrs- RPMs 150, WOB 5/18k, PP 2800 psi, SPM 140, 592 GPM, Up wt 172k, Dn wt 75k, Rot 114k, Troq on bttm 17.5k, off bttm 14k, ECDs 11.8 - Pump Wt/ hi vis sweeps as needed to maintain clean hole. Circu & Condition - PR 140 spm, PP 2800, 140 RPMs, Recip drrill pipe at all times. Condition mud to run line. MW 9.2 ppg, 51 Vis Check for flow - Slight movement - Suppect system out of balance from conditioning. Circu - System not balanced- MW out 9.3 ppg, MW in 9.2 ppg - Circu to balance system Check for flow - Static Bk ream OOH to 11,275' - Record T & D every 5 stds - Get MWD check shot every 5 stds. Bk Rm @ drilling rates. RPMs 140, PR 130 spm, Pulling rate up 2 min I std. Con't Bk ream OOH to 10,200' - Hole appears to be taking fluid - 10 -15 bbls per ea 5 stds reamed. Circu BU - Condition hole clean Con't Bk ream OOH to 7796' (Shoe)- Fluid losses have stopped - RPMs 150,120 SPM, PP 1850 psi Check for flow @ shoe per CPAI procedure - Well Static Circu BU X2 - Circu & Condition to run liner - Add addititional1% lube in second BU to spot in csg to run liner. Circu total 12,000 stks. TOH on elevators - Std bk remaining stds wI Lo Tad (Total 75 stds 5" DP + 10 stds HWDP wI jars in derrick) TOH - UD 5" DP t/3123' - MI calcu loss of mud 18 bbls ( Pitwatcher found he had a riser leaking into another pit) LD DP. LD BHA. Clear rig floor. PJSM and RU to run liner. Run 5.5" liner. RU inner string tools. PJSM and run inner string. RD running equipment. MU liner assy. TIH to shoe with DP. Circulate BU, 65 spm @ 1000 psi. Continue RIH to 10282. TIH with liner on DP to 14039. Record torque and drag values. PU to 14037, circulate/rotate 15 RPM, pump 5 bpm @ 1090 psi. PJSM, pump 39 bbls #9.2 spacer and displace wI 509 bbls 9.2 brine. 78 spm, 1950 psi, 15 RPM, 13k ft-Ib. (TO dropped to 8K ft-Ib as brine Printed: 10/8/2003 3:54: 13 PM a ..... ConocoPhillips Alaska Page 7 of 7 OperaUons Summary-Report Legal Well Name: 1 B-1 02 Common Well Name: 1 B-1 02 Spud Date: 7/28/2003 Event Name: ROT - DRILLING Start: 7/27/2003 End: 8/15/2003 Contractor Name: n1334@ppco.com Rig Release: 8/15/2003 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub .. Phase Description of Operations CodE! ~.._- -~---_. 8/13/2003 05:00 - 06:30 1.50 CASE CIRC CMPL TN went into open hole?) 06:30 - 07:30 1.00 CASE DEOT CMPL TN Drop setting ball and pressure up to 4400 psi to shear ball seat and release fIIiner, slack off 65k on to set PKR. 07:30 - 08:00 0.50 CASE DEOT CMPL TN PU 5', pressure test liner top PKR to 2500 f/10 min. 08:00 - 10:45 2.75 CASE CIRC CMPL TN Unsting from liner and continue to displace with 9.2 brine. 10:45 - 11 :00 0.25 CASE OTHR CMPL TN Observe well for flow. 11 :00 - 16:00 5.00 CMPL TN TRIP CMPL TN POOH LD LoTad subs, stand back 40 stands DP, LD 65 jts. 16:00 - 16:15 0.25 CMPL TN TRIP CMPL TN TIH (Re-enter liner top @ 7620 to ensure liner was intact, no problem) 16:15 - 17:00 0.75 CMPL TN TRIP CMPL TN POOH, LD remaining 39 jts DP and Lotad subs. 17:00 - 17:45 0.75 CMPL TN TRIP CMPL TN LD liner running tool. 17:45 - 18:00 0.25 CMPL TN SFTY CMPL TN PJSM on light string. Rig up Doyon casing. 18:00 - 23:00 5.00 CMPL TN TRIP CMPL TN LD 201 joints 3.5" inner liner string. 23:00 - 23:15 0.25 CMPL TN RURD CMPL TN RD tubing tools. 23:15 - 23:30 0.25 LOG RURD CMPL TN PJSM E-Line. 23:30 - 00:00 0.50 LOG RURD CMPL TN RU Schlumberger E-Line. 8/14/2003 00:00 - 00:15 0.25 LOG RURD CMPL TN Cont. RU E-line. 00:15 - 04:30 4.25 LOG ELOG CMPL TN Run USIT on wireline/tractor tool. 04:30 - 05:00 0.50 LOG RURD CMPL TN RD US IT and tractor Tools and E-line. 05:00 - 05:30 0.50 CMPL TN OTHR CMPL TN Pull wear bushing. 05:30 - 06:00 0.50 RIGMNT RSRV CMPL TN Lubricatelservice rig. 06:00 - 06:30 0.50 CMPL TN RURD CMPL TN RU completion tubing running equipment. 06:30 - 12:30 6.00 CMPL TN RUNT CMPL TN Run 4.5", 12.6#, 1-80 NSCT tubing to 7645. 12:30 - 13:00 0.50 CMPL TN RUNT CMPL TN Run seals into SBR, 80 psi increase in pressure, tag locator at 7645. 13:00 - 13:15 0.25 CMPL TN DEOT CMPL TN Test seal assy. through annulus, 500 psi. Measure for space out. 13:15 - 13:30 0.25 CMPL TN CIRC CMPL TN PJSM, review displacement detail. Pump 35 bbl vise. spacer. 13:30 - 15:30 2.00 CMPL TN CIRC CMPL TN Displace well at 7630 with clean 9.2 ppg brine. 72 spm, 450 psi, 8200 strokes. 15:30 - 16:30 1.00 CMPL TN SOHO CMPL TN Space out with 3 pups below 1 full joint below the hanger. Land tubing, RILDS. 16:30 - 17:00 0.50 CMPL TN DEOT CMPL TN Test annulus to 1000 psi, RD Doyon casing equipment, LD landing joint, test packoff to 5000 psi. 17:00 - 18:30 1.50 CMPL TN NUND CMPL TN Set BPV, ND BOPE. 18:30 - 20:00 1.50 CMPL TN NUND CMPL TN Orient an NU tree. 20:00 - 20:45 0.75 CMPL TN SEOT CMPL TN Test tree, 250/5000, pull BPV. 20:45 - 21 :45 1.00 CMPL TN SEOT CMPL TN Record annulus test, 2500 psi, 30 min. Shear GLM with 3000 psi. 21 :45 - 00:00 2.25 CMPL TN FRZP CMPL TN Freeze protect with 150 bbl diesel down annulus, u-tube to tubing. Pre-Spud meeting for 1 B 101 well. 8/15/2003 00:00 - 00:30 0.50 CMPL TN FRZP CMPL TN Continue U-tube to balance. 00:30 - 01 :00 0.50 CMPL TN DEOT CMPL TN Check pressures, tbg 20 psi I ann 10 psi, RD circ equip. 01 :00 - 01 :30 0.50 CMPL TN NUND CMPL TN Remove double block valves and install companion flanges. 01 :30 - 02:00 0.50 CMPL TN RURD CMPL TN RU lubricator and install BPV. Secure well. (RIG RELEASED 0200 HRS 8/15/03) Printed: 101812003 3:54: 13 PM -- = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 1 of 7 - - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/1 02 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU 'IVI~ WELL DATA Target TVD (F1) Target Coord. N/S Slot Coord. NIS -502.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10000 30mD 10mD Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Vertical Date Tool Depth Angle Direction Length TVD Section N(+) IS(-) E(+) 1 W(-) DL Build (+) Right (+) Comment Type (F1) (DD) (DD) (F1) (Fi] (Fi] (F1) (Per 100 F1) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 28-JUL-03 GSS 120.00 0.00 0.00 120.00 120.00 0.00 0.00 0.00 0.00 0.00 --- 28-JUL-03 GSS 169.00 1.00 32.00 49.00 169.00 0.32 0.36 0.23 2.04 2.04 28-JUL-03 GSS 351.00 6.10 53.00 182.00 350.59 5.80 7.53 8.80 2.85 2.80 11.54 28-JUL-03 GSS 468.00 13.00 58.00 117.00 465.90 13.40 18.26 24.94 5.93 5.90 4.27 29-J UL -03 MWD 555.93 12.98 67.71 87.93 551.59 19.04 27.25 42.47 2.48 -0.02 11.04 29-JUL-03 MWD 645.99 13.34 65.56 90.06 639.29 23.60 35.38 61.29 0.67 0.40 -2.39 29-JUL-03 MWD 736.33 14.01 62.89 90.34 727.07 29.23 44.68 80.51 1.02 0.74 -2.96 29-JUL-03 MWD 827.51 15.99 65.67 91.18 815.14 35.38 54.88 101.78 2.31 2.17 3.05 29-JUL-03 MWD 916.34 17.56 67.00 88.83 900.18 41.20 65.16 125.26 1.82 1.77 1.50 29-JUL-03 MWD 1007.72 18.37 70.87 91.38 987.11 46.33 75.27 151.56 1.58 0.89 4.24 30-JUL-03 MWD 1101.29 18.55 76.38 93.57 1075.87 49.34 83.60 179.95 1.87 0.19 5.89 30-JUL-03 MWD 1193.84 20.16 82.05 92.55 1163.20 49.42 89.28 210.06 2.67 1.74 6.13 30-JUL-03 MWD 1286.86 23.69 88.65 93.02 1249.49 45.73 91.94 244.64 4.62 3.79 7.10 e- 30-JUL-03 MWD 1378.95 29.08 92.47 92.09 1331.96 37.74 91.41 285.52 6.13 5.85 4.15 30-JUL-03 MWD 1469.62 35.44 94.80 90.67 1408.60 25.83 88.25 333.78 7.15 7.01 2.57 30-JUL-03 MWD 1565.91 40.79 92.97 96.29 1484.33 11.11 84.29 393.06 5.68 5.56 -1.90 30-JUL-03 MWD 1658.06 43.98 92.09 92.15 1552.39 -2.91 81.56 455.11 3.52 3.46 -0.95 30-JUL-03 MWD 1751.32 47.37 91.84 93.26 1617.54 -17.32 79.28 521.78 3.64 3.64 -0.27 30-JUL-03 MWD 1843.71 52.89 92.09 92.39 1676.75 -32.65 76.84 592.62 5.98 5.97 0.27 30-JUL-03 MWD 1935.37 59.17 91.27 91.66 1727.94 -48.69 74.63 668.56 6.89 6.85 -0.89 30-JUL-03 MWD 2029.18 64.03 92.94 93.81 1772.55 -66.75 71.57 750.99 5.41 5.18 1.78 30-JUL-03 MWD 2128.42 64.38 93.43 99.24 1815.73 -87.91 66.61 840.21 0.57 0.35 0.49 30-JUL-03 MWD 2220.45 66.20 94.35 92.03 1854.20 -108.72 60.93 923.61 2.18 1.98 1.00 -" - - ~ ~. ~ ~ ~ ~ ~ ~ -. II!!II!!( - !!!!!!!!!!!!!!. - ~ -' --- = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 2 of 7 - - - Company CONOCOPHILUPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/1 02 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU IN.~ WELL DATA Target lVD (FT) Target Coord. N/S Slot Coord. NIS -502.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length lVD Section N(+) IS(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 F1) Drop (-) Left (-) 30-JUL-03 MWD 2313.60 67.28 91.75 93.15 1890.99 -128.79 56.39 1009.06 2.81 1.16 -2.79 -- 30-JUL-03 MWD 2405.78 70.18 91 .48 92.18 1924.43 -146.85 53.97 1094.92 3.16 3.15 -0.29 30-JUL-03 MWD 2498.75 70.06 92.09 92.97 1956.04 -165.48 51.25 1182.30 0.63 -0.13 0.66 30-JUL-03 MWD 2591 .54 70.21 91.40 92.79 1987.57 -184.02 48.59 1269.53 0.72 0.16 -0.74 3O-JUL-03 MWD 2685.73 70.46 91.62 94.19 2019.27 -202.50 46.25 1358.20 0.34 0.27 0.23 30-JUL-03 MWD 2778.15 69.65 91.76 92.42 2050.79 -220.88 43.69 1445.04 0.89 -0.88 0.15 30-JUL-03 MWD 2869.22 70.87 90.92 91.07 2081.55 -238.49 41.69 1530.73 1.60 1.34 -0.92 30-JUL-03 MWD 2963.22 70.51 90.73 94.00 2112.64 -255.94 40.41 1619.43 0.43 -0.38 -0.20 31-JUL-03 MWD 3055.35 70.47 88.34 92.13 2143.41 -271.10 41.11 1706.26 2.45 -0.04 -2.59 31-JUL-03 MWD 3148.78 70.21 88.99 93.43 2174.84 -285.15 43.17 1794.22 0.71 -0.28 0.70 31-JUL-03 MWD 3240.33 70.25 88.10 91.55 2205.81 -298.72 45.35 1880.34 0.92 0.04 -0.97 31-JUL-03 MWD 3333.27 70.77 85.69 92.94 2236.82 -310.02 50.10 1967.82 2.51 0.56 -2.59 31-JUL-03 MWD 3426.37 70.67 86.91 93.10 2267.56 -320.46 55.77 2055.52 1.24 -0.11 1.31 .- 31-JUL-03 MWD 3519.37 71.80 86.66 93.00 2297.48 -331.66 60.71 2143.43 1.24 1.22 -0.27 31-JUL-03 MWD 3612.34 70.41 89.21 92.97 2327.59 -344.58 63.89 2231.32 2.99 -1.50 2.74 31-JUL-03 MWD 3705.59 69.99 91.05 93.25 2359.18 -360.79 63.69 2319.06 1.91 -0.45 1.97 31-JUL-03 MWD 3798.09 69.98 91.91 92.50 2390.84 -378.86 61 .45 2405.94 0.87 -0.01 0.93 31-JUL-03 MWD 3890.77 70.44 91.39 92.68 2422.22 -397.25 58.94 2493.11 0.72 0.50 -0.56 31-JUL-03 MWD 3984.49 70.95 93.49 93.72 2453.21 -417.08 55.17 2581.47 2.18 0.54 2.24 31-JUL-03 MWD 4077.50 70.43 91.51 93.01 2483.97 -436.86 51.34 2669.16 2.09 -0.56 -2.13 31-JUL-03 MWD 4170.55 70.86 89.23 93.05 2514.81 -453.44 50.77 2756.94 2.36 0.46 -2.45 01-AUG-03 MWD 4262.59 70.57 89.72 92.04 2545.21 -468.52 51.57 2843.81 0.59 -0.32 0.53 01-AUG-03 MWD 4356.22 71.08 88.80 93.63 2575.96 -483.54 52.71 2932.24 1.08 0.54 -0.98 01-AUG-03 MWD 4448.37 70.22 90.88 92.15 2606.50 -499.17 52.96 3019.18 2.33 -0.93 2.26 - - - - - - - = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 3 of 7 - - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/1 02 SUNey Section Name Definitive SUNey BHI Rep. NEWLON - BALLOU 'IV....w WELL DATA Target rvD (FT) Target Coord. N/S Slot Coord. N/S -502.00 Grid Correction 0.000 Depths Measured From: RKB~ MSLD SSD Target Description Target Coord. EIW Slot Coord. EIW -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA SUNey SUNey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 01-AUG-03 MWD 4541.51 69.69 93.82 93.14 2638.43 -518.65 49.38 3106.59 3.02 -0.57 3.16 -- 01-AUG-03 MWD 4633.94 70.44 91.18 92.43 2669.95 -538.22 45.59 3193.39 2.80 0.81 -2.86 01-AUG-03 MWD 4726.67 70.40 94.42 92.73 2701.03 -558.35 41.32 3280.64 3.29 -0.04 3.49 01-AUG-03 MWD 4817.61 71.15 94.97 90.94 2730.97 -580.88 34.29 3366.22 1.00 0.82 0.60 01-AUG-03 MWD 4913.64 71.45 93.89 96.03 2761.76 -604.35 27.27 3456.91 1.11 0.31 -1.12 01-AUG-03 MWD 5005.79 69.83 93.17 92.15 2792.31 -625.46 21.91 3543.68 1.91 -1.76 -0.78 01-AUG-03 MWD 5098.30 71.29 88.72 92.51 2823.11 -642.78 20.49 3630.87 4.80 1.58 -4.81 01-AUG-03 MWD 5191 .44 70.51 85.23 93.14 2853.60 -654.26 25.13 3718.74 3.64 -0.84 -3.75 01-AUG-03 MWD 5284.20 71.73 82.12 92.76 2883.62 -660.67 34.80 3805.96 3.43 1.32 -3.35 01-AUG-03 MWD 5377.20 72.09 80.53 93.00 2912.50 -663.52 48.14 3893.35 1.67 0.39 -1.71 01-AUG-03 MWD 5471.03 73.72 79.64 93.83 2940.08 -664.46 63.58 3981.69 1.96 1.74 -0.95 01-AUG-03 MWD 5562.37 73.79 79.54 91.34 2965.63 -664.63 79.43 4067.94 0.13 0.08 -0.11 01-AUG-03 MWD 5655.14 70.85 76.73 92.77 2993.81 -662.57 97.58 4154.43 4.29 -3.17 -3.03 e- 02-AUG-03 MWD 5747.22 69.40 74.35 92.08 3025.12 -656.63 119.19 4238.27 2.90 -1.57 -2.58 02-AUG-03 MWD 5840.58 71.28 74.05 93.36 3056.52 -648.54 143.13 4322.86 2.04 2.01 -0.32 02-AUG-03 MWD 5933.22 71.89 76.58 92.64 3085.79 -642.16 165.41 4407.88 2.67 0.66 2.73 02-AUG-03 MWD 6025.85 70.76 74.85 92.63 3115.45 -636.40 187.06 4492.91 2.15 -1.22 -1.87 02-AUG-03 MWD 6118.79 69.36 75.23 92.94 3147.15 -629.64 209.61 4577.32 1.55 -1.51 0.41 02-AUG-03 MWD 6212.13 68.90 73.19 93.34 3180.41 -621.63 233.34 4661.24 2.10 -0.49 -2.19 02-AUG-03 MWD 6306.61 71.21 69.33 94.48 3212.64 -608.91 261.88 4745.31 4.55 2.44 -4.09 02-AUG-03 MWD 6398.89 70.41 67.65 92.28 3242.98 -592.30 293.84 4826.39 1.93 -0.87 -1.82 02-AUG-03 MWD 6491.18 71.38 61.97 92.29 3273.21 -570.22 330.95 4905.26 5.91 1.05 -6.15 02-AUG-03 MWD 6583.26 70.05 59.60 92.08 3303.62 -542.37 373.36 4981.11 2.83 -1.44 -2.57 02-AUG-03 MWD 6674.80 70.53 59.37 91.54 3334.49 -512.90 417.11 5055.35 0.58 0.52 -0.25 - - - - . - - - - - - - -, - -:, _1; 0 " ~ ----- ---- = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 4 of 7 - - - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/102 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU ,,...~ WELL DATA Target rvD (FT) Target Coord. NIS Slot Coord. N/S -502.00 Grid Correction 0.000 Depths Measured From: RKB~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.48 Magn. to Map Carr. 0.000 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(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 02-AUG-03 MWD 6733.19 69.76 55.39 58.39 3354.33 -492.25 446.71 5101.60 6.55 -1.32 -6.82 -e- 03-AUG-03 MWD 6861.05 70.27 58.45 127.86 3398.04 -446.16 512.28 5202.27 2.28 0.40 2.39 03-AUG-03 MWD 6952.72 70.54 52.37 91.67 3428.81 -410.96 561.28 5273.32 6.25 0.29 -6.63 03-AUG-03 MWD 7046.46 70.76 48.06 93.74 3459.88 -367.73 617.86 5341.27 4.34 0.23 -4.60 03-AUG-03 MWD 7139.64 70.69 42.09 93.18 3490.66 -318.06 679.94 5403.51 6.05 -0.08 -6.41 03-AUG-03 MWD 7232.22 70.27 35.87 92.58 3521.63 -261 .43 747.73 5458.37 6.35 -0.45 -6.72 03-AUG-03 MWD 7325.32 70.79 32.73 93.10 3552.66 -199.17 820.23 5507.82 3.23 0.56 -3.37 03-AUG-03 MWD 7418.07 72.12 28.12 92.75 3582.18 -132.77 896.03 5552.33 4.93 1.43 -4.97 03-AUG-03 MWD 7510.78 73.20 22.05 92.71 3609.83 -60.85 976.14 5589.81 6.36 1.16 -6.55 03-AUG-03 MWD 7604.00 74.25 15.76 93.22 3635.98 17.05 1060.76 5618.78 6.57 1.13 -6.75 03-AUG-03 MWD 7695.39 74.51 9.34 91.39 3660.61 97.98 1146.62 5637.89 6.77 0.28 -7.02 03-AUG-03 MWD 7766.66 74.70 5.25 71.27 3679.54 163.38 1214.76 5646.61 5.54 0.27 -5.74 07-AUG-03 MWD 7873.73 75.60 1.84 107.07 3706.99 263.76 1318.04 5653.00 3.19 0.84 -3.18 -= 07-AUG-03 MWD 7968.34 75.61 357.74 94.61 3730.52 353.90 1409.65 5652.66 4.20 0.01 -4.33 07-AUG-03 MWD 8064.92 76.83 353.04 96.58 3753.53 447.17 1503.12 5645.12 4.89 1.26 -4.87 07-AUG-03 MWD 8159.96 79.18 350.80 95.04 3773.29 540.04 1595.15 5632.04 3.38 2.47 -2.36 07-AUG-03 MWD 8257.59 83.53 354.72 97.63 3787.96 636.35 1690.86 5619.91 5.97 4.46 4.02 07-AUG-03 MWD 8354.17 86.94 356.18 96.58 3795.99 732.06 1786.78 5612.27 3.64 3.53 1.51 07-AUG-03 MWD 8449.82 92.35 353.31 95.65 3796.58 827.26 1881.98 5603.52 6.40 5.66 -3.00 07-AUG-03 MWD 8545.39 94.29 348.59 95.57 3791.04 922.61 1976.17 5588.52 5.33 2.03 -4.94 07-AUG-03 MWD 8642.00 94.66 344.69 96.61 3783.50 1018.79 2069.87 5566.27 4.04 0.38 -4.04 07-AUG-03 MWD 8738.63 94.63 343.69 96.63 3775.67 1114.69 2162.53 5540.03 1.03 -0.03 -1.03 07-AUG-03 MWD 8835.17 94.07 342.93 96.54 3768.35 1210.39 2254.74 5512.38 0.98 -0.58 -0.79 07-AUG-03 MWD 8931.89 93.83 343.22 96.72 3761.69 1306.28 2347.05 5484.29 0.39 -0.25 0.30 _'I' _II _n ~ - - - II. II. II. II. " , = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 5 of 7 - - - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/1 02 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU IIV.EQ WELL DATA Target rvD (FT) Target Coord. NIS Slot Coord. NIS -502.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO rOmO Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 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(+) 1 S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 07-AUG-03 MWD 9028.41 93.89 343.83 96.52 3755.19 1402.06 2439.40 5456.98 0.63 0.06 0.63 e- 07 -AUG-03 MWD 9124.19 93.89 345.13 95.78 3748.69 1497.26 2531.47 5431.41 1.35 0.00 1.36 07-AUG-03 MWD 9220.66 92.04 344.99 96.47 3743.70 1593.31 2624.55 5406.58 1.92 -1.92 -0.15 07 -AUG-03 MWD 9316.86 91.37 345.02 96.20 3740.84 1689.17 2717.43 5381.70 0.70 -0.70 0.03 07-AUG-03 MWD 9412.98 91.25 343.48 96.12 3738.64 1784.86 2809.92 5355.61 1.61 -0.12 -1.60 08-AUG-03 MWD 9510.54 91.31 341 .43 97.56 3736.46 1881.66 2902.91 5326.21 2.10 0.06 -2.10 08-AUG-03 MWD 9608.01 91.89 342.87 97.47 3733.74 1978.29 2995.65 5296.35 1.59 0.60 1.48 0B-AUG-03 MWD 9704.33 91.71 344.23 96.32 3730.72 2074.04 3087.98 5269.09 1.42 -0.19 1.41 08-AUG-03 MWD 9800.27 91.15 345.47 95.94 3728.32 2169.64 3180.55 5244.02 1.42 -0.58 1.29 08-AUG-03 MWD 9897.55 86.31 344.29 97.28 3730.48 2266.55 3274.41 5218.66 5.12 -4.98 -1.21 08-AUG-03 MWD 9993.95 85.97 342.99 96.40 3736.97 2362.23 3366.70 5191.57 1.39 -0.35 -1.35 08-AUG-03 MWD 10089.79 85.84 343.57 95.84 3743.81 2457.27 3458.25 5164.07 0.62 -0.14 0.61 08-AUG-03 MWD 10185.54 86.15 344.70 95.75 3750.50 2552.37 3550.13 5137.96 1.22 0.32 1.18 -- 09-AUG-03 MWD 10282.80 86.12 345.53 97.26 3757.06 2649.12 3643.91 5113.03 0.85 -0.03 0.85 09-AUG-03 MWD 10378.84 86.27 346.68 96.04 3763.43 2744.78 3736.93 5090.02 1.20 0.16 1.20 09-AUG-03 MWD 10476.06 86.27 347.85 97.22 3769.75 2841.72 3831.56 5068.63 1.20 0.00 1.20 09-AUG-03 MWD 10583.08 86.33 348.23 107.02 3776.66 2948.49 3936.04 5046.50 0.36 0.06 0.36 09-AUG-03 MWD 10668.66 86.24 348.49 85.58 3782.21 3033.87 4019.68 5029.27 0.32 -0.11 0.30 09-AUG-03 MWD 10764.30 86.30 349.11 95.64 3788.43 3129.30 4113.30 5010.73 0.65 0.06 0.65 09-AUG-03 MWD 10860.03 86.52 349.42 95.73 3794.42 3224.84 4207.17 4992.94 0.40 0.23 0.32 09-AUG-03 MWD 10954.47 86.27 348.82 94.44 3800.36 3319.09 4299.73 4975.15 0.69 -0.26 -0.64 09-AUG-03 MWD 11053.30 88.79 349.57 98.83 3804.62 3417.82 4396.71 4956.64 2.66 2.55 0.76 09-AUG-03 MWD 11149.20 88.82 348.61 95.90 3806.62 3513.70 4490.85 4938.49 1.00 0.03 -1.00 09-AUG-03 MWD 11246.23 90.69 347.16 97.03 3807.03 3610.68 4585.71 4918.13 2.44 1.93 -1.49 - - - - - - - - - - - - - - - """' = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 6 of 7 - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/102 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU IIV,LW. WELL DATA Target rvD (Fl) Target Coord. N/S Slot Coord. N/S -502.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLO SSO Target Description Target Coord. EfW Slot Coord. EfW -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical T otaJ Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DD) (Fl) (Fl) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 09-AUG-03 MWD 11342.86 91.80 345.93 96.63 3804.93 3707.16 4679.67 4895.65 1.71 1.15 -1.27 e- 09-AUG-03 MWD 11438.45 93.40 346.83 95.59 3800.60 3802.51 4772.47 4873.17 1.92 1.67 0.94 09-AUG-03 MWD 11534.37 94.25 347.55 95.92 3794.20 3898.13 4865.79 4851 .95 1.16 0.89 0.75 09-AUG-03 MWD 11631.23 94.16 349.20 96.86 3787.10 3994.71 4960.41 4832.48 1.70 -0.09 1.70 09-AUG..Q3 MWD 11724.89 94.10 350.20 93.66 3780.35 4088.13 5052.31 4815.78 1.07 -0.06 1.07 09-AUG-03 MWD 11823.89 94.62 351.06 99.00 3772.82 4186.82 5149.71 4799.71 1.01 0.53 0.87 09-AUG-03 MWD 11919.55 94.34 348.45 95.66 3765.35 4282.18 5243.55 4782.75 2.74 -0.29 -2.73 10-AUG-03 MWD 12016.64 94.40 350.17 97.09 3757.95 4378.98 5338.67 4764.79 1.77 0.06 1.77 1 Q..AUG-03 MWD 12113.17 94.77 350.86 96.53 3750.24 4475.19 5433.58 4748.93 0.81 0.38 0.71 10-AUG-03 MWD 12209.59 93.18 349.98 96.42 3743.55 4571.36 5528.42 4732.92 1.88 -1.65 -0.91 I 10-AUG..Q3 MWD 12305.82 90.54 350.04 96.23 3740.43 4667.53 5623.13 4716.24 2.74 -2.74 0.06 10-AUG-03 MWD 12403.68 88.55 349.34 97.86 3741.21 4765.37 5719.40 4698.73 2.16 -2.03 -0.72 10-AUG-03 MWD 12498.77 88.30 350.57 95.09 3743.82 4860.42 5813.00 4682.15 1.32 -0.26 1.29 10-AUG-03 MWD 12594.55 86.09 349.25 95.78 3748.51 4956.08 5907.18 4665.39 2.69 -2.31 -1.38 10-AUG-03 MWD 12690.93 86.49 349.01 96.38 3754.74 5052.25 6001 .63 4647.25 0.48 0.42 -0.25 10-AUG-03 MWD 12787.24 86.21 349.89 96.31 3760.88 5148.37 6096.12 4629.66 0.96 -0.29 0.91 10-AUG-03 MWD 12881.51 86.31 349.87 94.27 3767.02 5242.43 6188.72 4613.13 0.11 0.11 -0.02 10-AUG-03 MWD 12980.42 86.33 351 .36 98.91 3773.37 5341.12 6286.11 4597.03 1.50 0.02 1.51 10-AUG-03 MWD 13076.03 86.18 350.61 95.61 3779.62 5436.49 6380.33 4582.08 0.80 -0.16 -0.78 10-AUG-03 MWD 13172.37 86.09 351 .61 96.34 3786.11 5532.57 6475.30 4567.23 1.04 -0.09 1.04 10-AUG-03 MWD 13268.37 86.00 349.66 96.00 3792.73 5628.32 6569.79 4551.65 2.03 -0.09 -2.03 10-AUG-03 MWD 13365.70 86.61 349.61 97.33 3799.01 5725.45 6665.33 4534.17 0.63 0.63 -0.05 10-AUG-03 MWD 13462.13 86.86 350.33 96.43 3804.50 5821.72 6760.13 4517.40 0.79 0.26 0.75 10-AUG-03 MWD 13557.78 86.52 349.53 95.65 3810.02 5917.20 6854.15 4500.71 0.91 -0.36 -0.84 II ~ - .-- - - - - _.. - - - _. -~_.,. -. - -. - = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00172 Sidetrack No. Page 7 of 7 - - - Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/1 02 Survey Section Name Definitive Survey BHI Rep. NEWLON - BALLOU IIV.&.Q WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -502.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -190.00 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DLper: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.48 Magn. to Map Corr. 0.000 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(+) 1 S(-) E(+) 1 W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (F1) (F1) (FT) (Per 100 FT) Drop (-) Left (-) 11-AUG-03 MWD 13648.56 86.61 349.70 90.78 3815.46 6007.82 6943.28 4484.37 0.21 0.10 0.19 .- 11-AUG-03 MWD 13739.55 85.72 351.47 90.99 3821.55 6098.58 7032.84 4469.52 2.17 -0.98 1.95 11-AUG-03 MWD 13829.82 84.46 350.74 90.27 3829.27 6188.48 7121.70 4455.62 1.61 -1.40 -0.81 11-AUG-03 MWD 13920.46 84.56 349.74 90.64 3837.95 6278.70 7210.61 4440.32 1.10 0.11 -1.10 11-AUG-03 MWD 14007.80 84.59 350.22 87.34 3846.20 6365.64 7296.24 4425.19 0.55 0.03 0.55 11-AUG-03 MWD 14044.00 84.59 350.22 36.20 3849.62 6401.68 7331.75 4419.07 0.00 0.00 0.00 Projected Data - NO SURVEY .- - - - -: - - - ConocoPhillips AlaJPlnc.,Slot #102 Pad 1 B, Kuparuk River Unit,North Slope, Alaska wellb. 1 02 Wellpath: GSS<0-468'>MWD Rvsd<555-14044 '> Date Printed: 21-0ct-2003 dC)3-1¿)~ .¡. BAKER HUGHES INTEQ ~K We II bore Nam4:!m. 104_____ Creél.t~d i;?¡J:Jul-2003 I Last Revised 14-0ct-2003 -...~--......----,--"---,~---",,,"-- Well Name 102 I Govemment ID ! i Last Revised 22-Jul-2003 Slot Name Slot #102 Latitude N70 19 40.2457 Lon itude W149 35 32.9646 North 501.00S East ! 190.00W Name padJJL . .. __-----==I~astina I Northing 550434,9p8' coorc:Ls\ßt!tI)'LI'J_amL.___ 5Q70149.712 AK-4 on NORTH AMERICAN DAJJ.JM1927 datu Installation -'---_._"-~~~-------.., Field Name Ku aruk River Unit 487754.621 Eastin "-_."--_._~--,, ----_._._--_._-,,----------~-,,--- I Comments -- REC NOV 20 2003 Alaska Oìl &. Gas Con~ Gom.mieeion Ancmonsge 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 349.48 degrees Bottom hole distance is 8569.12 Feet on azimuth 31.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips Alallnc.,Slot #102 Pad 1 B, Kuparuk River Unit, North Slope, Alaska Wellpath (Grid) Report MD[ft] lnC[deg] I Azi[deg] TVD[ft] I North[ft] I East[ft] I I. 1 ~~-----º.,Q[ ~~L~.oo _J)~ .__ O.OON~ O.OOE_ 120.001 0.00 0.00 120.00 O.OON O.OOE f----~~J69.od_~_~Q 169.0Q~_Q,36NI 0.23E ¡ I I 351.0Q 6.1~_!5:tQQ~ 350.5~ 7.53Nj JU30E 468.00 13.00 58.00 465.9Q 18.26N 24.94E __555.9~_ 12.98.~~?j ~~.!5~_27.25NI ~~__ 42.47~L 645.99 13.34 65.56 639.29 35.38NI 61.28E 736.33 14.01' 62.89 727.07: 44.68NI 80.51E 827.511 15.99: 65.67 815.141 54.88NI 101.78E 916.34 17.56 67.00 900.18 65.16NI 125.26E 1007.72 18.371 70.87 987.11: 75.27N1 151.56E -- 1101.29 18.551 76.38 1075.8~ 83.61Nr-179~96E c-_~~.1193.84 _ 20.161 82.0e 116~.2d ._ 89.28N! _ 210.06E _ 1286.8~ 23.69. . 88.6e 1249.49.. 91.94N. 244.63E 1378.9~ 29.0¡:L~J2..A1_j331.96 __ 91.41NI~ª5.52E 1469.62 35.441 94.80 1408.60 88.25N1 333.78E ----.1!565.91140.79r~7 1484.;33 ..-- 84.29Nr-~io6E c-.. 1658.Q6 43.98I..J1.billJ _ 1552.39 ___~5º~_.455.11 E f----J751.32 _._ 47.371----.91.84 W17.54 79.28N' 521]7E 1843.711 52.89 92.09 1676.75 76.84NI 592.62E 1935.3 ~--.Jtl.2} 1727.94 74.63NI' 668.5QE 2029.1f 64.031 92.94 1772.55 71.57N 751.00E 2128.4~ 64.381 93.43 1815.73 66.61NI 840.21E 2220.45 66.201 94.35 1854.20 60.93NI 923.61E 2313.6d 67.281 91.75 1890.99 56.39NI 1009.06E 2405.78 70.181 91.48 1924.43 53.97NI 1094.92E 2498.7e 70.061 92.09 1956.04 51.25N1 1182.30E 2591.~ 70.211 91.~-º_~.5~_1ª.59NI 1269.53E __ 2685. 7< 70.4Q!____~J .62 2019~.. 46.25NI 13_58.20E 2778.1569.65 91.76 205Q.8q .. 43.69Ni 1445,Q1E c-----lª69.2270.871 90.9? 2081.55 .41.69NI 1530.7;3E 2963.2~ 70..!5.L.-_~J!Qn__ 2112.61_10~41N' 1619.43E ~055.3~ 70.921. 88.34 2143.07 41.12N----.1ZQ{L38E 3148.78 70.6~L--88.99 2173.83 43.17N 1794.58E 3240.33 70.681 88.10 2204.15 . 45.37~ 1880.93E 3333.271 71.201 85.69 2234.5d 50.13NI 1968.64E 3426.371 71.101 86.91 2264.58 55.81Ni 2056.56E 3519.37 72.231 86.66 2293.84 60.77NI 2144.70E 3612.34 70.841 89.21 2323.28 63.95NI 2232.82E 3705.59 70.421 91.0<; 2354.22 63.75NI 2320.78E 3798.0~ 7Q.411 91.91 2385.2.4.__Q1,50NI. 2407.90J 3890.7~ 70~ 91.39 2415.95 58.98N' 2495.30E 3984.49 71.38193.49 _ 2446.27,. 55,~_ 2583.90E ¡--_ 4077.50 ~_ 70.86L_-ªJá1~_2476.37.. 51.37"'4---Z671.81E 4170.5~ __ 71.29' _-------.illì.?~_2!506.55 50.80N!____ZZ59.82E c---1~62.5~~~-]1.00 ... 89.72 25:t6~_ 51.60NI 284fìJJ2E f- 4.356.2a. . 71.51~_ª---ªº,----_256. .6.38__.~~Z1:tr=. _2935.57E f---4448.3.1_ 70.65 _------.00..88 2596.27i 52.99NI 30;?2.74E ~~Jo.1f 93.82 2627.54 49.40Ni~1Q.39E 4633.94 70.87, 91.18 2658.411 45.60N 3197.42E 4726.Qlc 70.8L-....~94.42 2688.83 -.---A1.~ 3284.90E wellb. 102 Well path: GSS<0-46S'>MWD Rvsd<555-14044 '> Date Printed: 21-0ct-2003 Dogleg 1 Vertical Easting [dea/100ftl 1 Sectionfftl ..___ 0.00 .0.0.0 0.00 0.00 2.04' 0.32 ~)i!5! 5.80 5.931 13.40 2.48 19.04 0.671 23.60 1.021 29.23 2.311 35.38 1.8i 41.20 L!5!!___ 46.33 1.871 49.34 2.671 _49.4 4.621 45.73 _6~1;3 37.74 7.1!:L. 25.83 5.681 11.11 .--:-:::r------ _ 3.521 -2.90 __ 3.641 -17.32 5.981 -32.65 6.891 ___ -48.69 5.41' -66.74 0.571 -87.91 2.181 -108.7 2.811 -128.7~ 3.161 -146.8< 0.631 -165.4~ 0.721 -184.0~ 0.341 -202.5C Q.-ª~ -220.8~ 1.60L__ -238.4~ 0.431 -255.94 2.491-~271.1~ 0.721 -2ß5.2C 0.921 -298.81 2.511 -310.1e 1.24, -320.61 1.24 -331.8 3.001 -344.7~ 1.921 -361.04 0.8aL_ -379.1€ 0.731 -397.6C 2.191 -417.4~ 2.09 -43.7.31 2.361 -453,94 __ 0.591 -469.0E , 1~ 1.081 __-:184.1 2.331 -499]9 3.031 -519.3~ 2.811 -538.94 3.301 -559.12 - ... -.-- IIi. BAKER HUGHES INTEQ I L~___.-.J 550248.3E_ .~_ 5969647.5C 550248.3e 5969647.5C .. 550248.5ï!59ºJJ-º~Llli 5_!5Q~[LQ~ 5969655.0~ 550273.1 e 5969665.92 550290.63 _.. _._._ 5969675.0~ 550309.39 5969683.2( 550328.5~ 5969692.71 550349.n 5969703.0~ 550373.16 5969713.4~ 550399.3E 5969723.7'¡ -~-55042i:72 5969732~~ 5!5º-157.7~ 5969738JJ 550492.34_~_____5969741.0E 550533.2~ 5969740.8C -- ....._------------¡---------~-_._--'----_.~-----------; ___ 550!2./iL5Q 5969.7.31.9/ 550640.7S 5969734..4~ 550702.8e 5969732.0~ 550769~53 . ----~____..Q9ß~_I3_0.2e 550840.38 5969728.2~ 550916.3j 5969726.55 -- 550998. 7~ 59697'2'4.0S 551088.01 5969719.72 551171.44 5969714.61 551256.91 5969710.6~ 551342]1 5969708.7S 551430.n 5969706.65 5!51517.4~ 59ºJJ.lQ4.5~ 551606.0ï 5969702.ª~ 551692.9~ _ 5969700.8~ 551778.61 5969699.4j _55186L31!5~º.9698. 7 ~ 551954.2~ 5969700.0~ 552042.4~ 5969702.6~ --.. .---;;:;;::;;¡ 552128.75 5969705.4. _ 552216.41 _____. 5969710.8C 552304.29 5969717.01 552392.3E 5969722.6j 552480.4fj 5969726.3~ 552568.42 5969726.7f 552655.54 5969725.11 552742.ge 5969723.1S __ 552831.56.___ 5969720.0_~. __!55291~AL-____ 5969716.7~ 5!53QQL!5C ..!5.969716.Tï 553094.58 59º~718.1~ _ 553183.21 5969719,a~ 553.2l.QcR----~_____ 5969720.7~ 553358.Q3 5969717.7; 553445~O¡------~' 5969714.5C 553532.5~ 59ºJ1ZJQ.81 .--- 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 349.48 degrees Bottom hole distance is 8569.12 Feet on azimuth 31.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips Ala'lnc.,Slot #102 Pad 1 B, Kuparuk River Unit, North Slope, Alaska wellb. 102 Well path: GSS<0-46S'>MWD Rvsd<555-14044 '> Date Printed: 21-0ct-2003 .i. BAKER HUGHES INTEQ Wellpath (Grid) Report ~_. i Inc[deg] ..... II Azi[de..g]..... TVD[ft] .... il North[ft..]. i East[ft] Dogleg I Vertical Easting _ .. .n . _ I... 1 rdea/1 OOfìL._JSectionrftl _~.6Î----.L1,!j¡¡_93.97 2718.1~3'L28N' __ 3370.70E 0.99 -581.72 4913.64 71.88 93.89 2748.27 27.24N 3461.61E n-1.12:-'-605.24 5005.l9: 70·~§i------.i)..3,17 27leJL__ ~1.87N 3548.60E 1.911 -626.40 ... 5098.3Q 71.72L_____lilU2 280e,:31__~º.44NI . 3636.03E 4.81r -643.77 5191.44 70.94' 85.23 2838.13 25.09NI 3724.13E 3:65[- -655.28 _ _5284.2(L __72.16 ~2 _~7.49.~4.79NI 3811.57E 3.44 -661.71 5377.2d 72.52 80.53 2895.71, 48. 16N;--3899. 17E 1.67 =664:56 5471.03 74.151 79.64 2922.62 63.64N 3987.71E 1.96' -665.50 5562.37 74.221 79.54 2947.51' 79.52N 4074.15E 0.13' -665.67 5655.14 71.26 76.73 2975.04 97.71NI 4160.83E 4.311 -663.61 __.9747.22 69.83. ... ~~_ 3005,]11 119.~8NI 4244.89E 2J!.9.. _ -657.65 5840.58 71.71, 74.0f 3036.46 143.38NI 4329.71f 2.04 -649.54 5933.22 72,32L-16.._!5.8~0¡¡~__165.71N_. 4414.94E 2.68, -643.15.- __ 6025.8Q__~_~'; .. 3094.º7_----..1.8L41 N:..............4!500.19E 2.151 -637.37 c-------º-.1Jß....I!L...----.f)9:.1~-]~--_~125.11' 210.03Ni 4584.82L 1.551- -630,513. __ 6212.13 69.33----..1~19 31!5LIlL.........233.83NI _ 4668.98E 2.111 -622.56 __ 6306.611__ 71.64.._......Q9~~ 3189.2L-262.45NI.4753.27E .... _4.561 -609.81 _6.3~.. 70.84' __ 67.65_.__ 3218.95. 294.4eNI 4!!.34.56EL9.3L.. -593.16 _§491.1~ .... 71.81, 61.97.n 3248.53. 33t69NI 4913.64E_!jJ~2_ -571.01 6583.26 70.48' 59.60 3278.29 374.21N 4989.69E 2.83' -543.09 1---6.674.80 70.961 ._~__. 3308.51' 418.º8N 50ß:4.12E 0,5e!. -513.5<; 6733.11 70.191 55.39 3327.911 447.71NI 5110.43E 6.571 -492.8 6861.05 70.70 58.4<; 3370.74 513.50NI 5211.44E 2.291 -446.61 6952.72 70.97 52.37 3400.86 562.63NI 5282.68E 6.27 -411.31 7046.46 71.19' 48.06 3431.21 619.36N' 5350.80E 4.36! -367.99 ,----I139.64 71.121 42.09 3461.39 681.60N' 5413.20E 6.06L -318.19 7232.2:j70.701 35.76 3491.70'~~62~68.14E 6.481 -261.3<; 7325.32 71.2L-1V3 3522.08 822.36NI 5517.66E 3.131 -198.8 7418.07 72. .5~ 28.12 3550.93 8~ 556...2.27E 4.941=-132.30 7510.78- 73.63! 22.0" 3577:92 9ZM.5.Nf__ 5599.85E·' ß.,,31L. -60.21" 7604.00. 74~··15.76 .. 36Q3.4Q . 1063.45N ------s628.8ZE_ 6.59 1U6 c------ZQ9~- .74.94 9.34 3627.36 114.!t49N_5648.02E 6.791 98.96 7766.66 75.13i 5.25 3645.78 1217.77N 5656.76E 5.551 164.49 f--_. 7873.7~. 75.931_ 1.8:4 . 3672.54 .- 1321.22N . 5663.17E 3.171 265ß4 7968.34 75.941 357.74 3695.54 1412.97N 5662.83E 4.201 355.31 8064.92. 77. 1 L-...353.04 3718.011 1506.57f',L 5655.27F 4.901 448.71 8159.96 79.511 350.8C 3737.23-- 1598.71N 5642.18E 3.381' 541.6£ 8257.59 83.861 354.7 3751.35 1694.50N 5630.03E 5.97 638.1C 8354.17 87.27 356.1B 3758.82 1790.47N 5622.40E 3.841 733.85 8449.82 92.68 353.31 3758.86 1885.68N 5613.64E 6.401 829.05 ~5.39 94J¡L-_348.59 .3752.77 1979.e3N 5598.65E . 5.331 924.36 8642.od 94.991 344.69 3744.68 2073.48N 5576.41E 4.041 1020.4~ __8738.63_ 94.961. 343.6.~ 3736...30 2166.10N. 5550.18E.. 1.031 111JL3< -------ªª35.1~9~ 342.9"._ 3728.42. 2258.27N!j522.55E ._ 0.981 1212.01 . 8931.89 94.1L-...M.3.~c---l12J.2º-. 2350.54N 5494.47E 0.39. 1307.8E. _ 9028.411_ 94.221 . 343.8_,. 3714,Ji.---.2.442.85N ..5467.17E. 0.63 1403.6C ~4.19 94~345.1 . 3707.1d.. 2534.88N 5441.61E 1.35 1498.7~ 9220,66 92..:m.............Ù.4...ID',----~3701.5EL.·. 262Ú3N5416.78E_._ 1.921 1594.7.. . 9316.86 91.701 345.0~ 3698.14 2720.80N 5391.91E 0.701 1690.6 9412.98 91.58 343.4f 3695.39 2813.27N 5365.83E 1:"61ì 1786.3C . 9510.54 91.64.. 341.4 3692.65 2906.25N 5336.43E 2.101_. 1883.0~ I Northing I 553618.41 .___J5_969704.3~ 553709.35 5969697.91 553796.3S 5969693.1~ ....Q5ißß3.8d u_ 5969692.2~ 553971.8€ 5969697.51 554059.2:< _.. ......59§Wj)7 .81 554146T 5969721.7E 554235.1 ~ 5969737.8J 554321.4~ 5969754.2~ 554408.0:; 5969773.0E 55449J .9~ 5969795.2$ 554576.57 5969819.8~ 554661.64 5969842,l~ 55414ß.7i. 5969865.01 554831.2C.___.59§9888.2C 554915.1S 5969912.~ .. _ ...5.54999..2.~ 5969941.7 ¡ ... 55..!5!LªQ,a;_ 59699Û.3~ _._55515_9~tt 5970012"o.~ 555234.9~ 5970055.Oi __Q5.~:ill9:,o¡j 5970099.4~ 555355.1€ 5970129.3~ 555455.71 5970195.8J 555526.6:< 5970245.4~ 555594.35 5970302.6~ .~ 555656.33 5970365.2¡ 555710.8i 5970433.6~ 555759.83 5970506.71 555803.93 _._..___~0582.9g -;~::~,¡-~ ;:;~~:~:~l 555887 .9~_n ___5!l70834.6~ __.Q.Q9891i21 5970902J}~ 555901.98 5971006.4~ 555901.03 5971098.2~ 555892.84 5971_1j11,TI ---555879.1-4 5971283.7G 555866.35 5971379.4~ 555858.0] 5971475.4C 555848.6S 5971570.5j 555833.0e. 5971664.5~ 555810.1£ 5971758.0~ 55.5ZI:!.3.35 5971850.5C 555755.1C 5971942::4] 555726.4 i_ 5972034.54 555698.50 5972126.6€ 555672~:r·. 5972216~ 555646.88 5972311.3~ 555621.38 5972404.0~ 555594.6£ 5972496.3E 555564.67 5972589.1 ~ ,..-- ,---.- 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 349.48 degrees Bottom hole distance is 8569.12 Feet on azimuth 31.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips AlallnC.,Slot #102 Pad 1 B, Kuparuk River Unit,North Slope, Alaska Wellpath (Grid) Report MD[ft] ! Inc[deg] I Azi[deg] TVD[~~~ft] I East[ft] _.9608.01! _92~..,:3.~_, 3689.34 .2998.97N 5306.57E . 9704.33 92.07. 344.2'1 3685.71 3091.28N 5279.32E -------.9.!IºQ.2~ 9L!:i1! 34!:i.4 3682.71: 31a3.84N 5254.26E 9897.55 86.67! 344.29 3684.26 3277. 71 N 5Z28.90E 9993.95 86.33r'~~99 3690.'14 3370~03N 5201.79E 10089.79 86.20 343.5 3696.39 3461.63N 5174.28E 10185.54 86.51' 344.70 3702.47 3553.54'~5148~16E 10282.8d 86.48! 345.5 3708.42 3647.36N 5123.22E 10378.84 86.63 346.6E 3714.19 3740.42N 5100.20E 10476.06 86.631 347.8~ 3719.91! 3835.08N 5078.81E 10583.08.86.69' _~~. 3726.11 _ 3939.60N 5056.67E 10668.68 86.60 348.4" 3731.15 4023.28N'-- 5039~43E 10764.3d..~ 86.661 349.11 3736.77 4116.93_~ 50~0.88E 10860.03 86.88 349.4 3742.17. 4210.84N ~3.º8E -------.1Qg54.41 . 86.631 . 348.8 3747.51 4303.431'.{' 4985.2aJ _ ,----11053.30 89.~ 349.5 3751.15 4400.441'.\..._ 4966.L7E 11149.20 89~- 348.61 3752.55 4494.59N 4948.62E 11246:23 91.05 347.16 3752.35 4589.45N 4928.26E 11342.88 92.16! .., 345.9 3749,65 46ë~_4905.78E 11438.48 93.76' 346.8 3744.71! 4776.17N 4883.31E _j1534.3~ 94.61 347.5~ 3737.71 4869.451\1 4862.10E 11631.23 94.52! 349.2C 3730.00 4964.02N 4842.64E 11724.89 94.46 350.20 3722.6~ 5055.88N 4825.95E 11823.8Ç 94.98: 351.06 3714.52 5153.231\1 4809.88E 11919.5~ 94.701 348.45 3706.45 5247.021\ 4792.93E c------1£016.~ 94.76 ~ __. 3698.44 5342.101\ 477!L98E 12113.1 95.13 350.8f 3690.12 5436.951\ 4759.13E 12209.59 93.54 349,9E 3682.83 5531.75N. 4743.13E 12305.82 90.90 350.0 3679,,1 11 5626.44N 4726.45E 12403.68 88~349.34 3679.271 5722.72N 4708.94E 12498.7~ 88,66 350.5 3681.29 5816.32N.. 4692,.36E 12594.55 86.45 349.25 3685.37 59HL~ 4675.60E ~.6~-ª-6.6si 349.01 3691.1~ 6005.01N 4657.45E f~ 86.57 349.89 ;3696.87 6099.52N 4639.85E 12881.51 86.67 349.8 3702.4 6192.171\1 4623.31E ~Z980.4~ ___86.69!. 351.~ 3708.1f 6289.59N 4607.21E 13076.03 86.54! 350.61 3713.8C 6383.85N 4592.26E 13172.37 86.45 351.61 3719.69 6478.85N 4577.40F 13268.3i1 86.36! 349.66 3725.71' 6573.38N 4561.81E 13365.70 86.97! 349.61 3731.371 6668.96N 4544.33E 13462.13 87.22' 350.3 3736.26.6763.801\1 452U>.!;)E 13557.7E 86.92: 349.5~ 3741.15 6857.851\1 4510.85E 13648.5E 86.971 349.7C 3745.99 6947.01N 4494.51E ~9.5~ 86.08 .:351.4 3751.50' 7036.~1'N 4479.65E ~29.8. 84.8R21 350.74 3758.6f 7125.51N. 4465.74E 13920.46 84.92 349.74 3766.7 7214.48N 4450.44E 14007.8d 84~9 350.2~ 3774.4E 7300.15N ~5.30E 14044.00 84.951 350.2~ 3777.66 7335.69~429.18E wellb. 102 Wellpath: GSS<0-468'>MWD Rvsd<555-14044'> Date Printed: 21-0ct-2003 rei. BAKER HUGHES INTEQ I I I Northing ...~ 5.!>5Q34.1 E~_______!:)9n6a.1.64 Dogleg I Vertical Easting I [dea/1 Q.Qf!J 1 Sectionfftl 1.60 1979.7C 1.42' 2075.4 .__L4~L.. 2171.01 5.1L._.Z267.9 1.39! 2363.6~ 0.62 2458.7 1.22' 2553.8 0.85! 2650.6E 1.21! 2746.3f 1.20! 2843.3 0.361 295Q,1' 0.32 3035.5E 0.653J31.0 0.401 3226.6C 0.691 332P,a.~., 2.661 3419~6 1.00, 3515.5 2.44 3612.51 __,l1.:L. 3708.9E 1.92: 3804.3C 1.16L 3899.8E 1.701 3996.41 1.07 4089.7E 1.01! 4188.4 2.731 4283.7 1.77i,4380.4~ 0.811 4476.6' 1.88' 4572.7 2.741 4668.9 . 2.16! 4766.7 1.32 4861.8 2.69] 4957.5 0.32: 5053.7 0.92i 5149.8E 0.111 5243.9f 1.50! 5342.6Ç 0.80 5438. H 1.041 5534.2 2.031 5630.0C 0.631 5727.1 0.791 __!:i823.4 0.89' 5918.9Ç 0.19 6009.6 2.17 6100.4 1.61 6190.3Ç 1.10 6280.66 0.55 6367..6~ 0.001 6403.71 .. 555506.32 555480.65 555454.66 555426.94 555398.82 555372.08 555346.52 555322.8B 555300.8~ 555278.02 555260.22 555241.0~ 555222.62 555204.21 555185.0~ 555166,;1 555145.28 . ·---:=Q!:)SJ22. 1 §. 555099.08 555077 .2~ 555057.16 555039.8~ 555023.14 555005.56 554986.98 554970.5G 554953.86 554936.5~ 554918.3~ '554901.1 ~ 554883.8 , 5.54865.02 554846.7° 554829.64 554812.8~ 554797.3G 554781.81 554765.58 554747.46 5.!:i473_Q,º~ 554712.7~ 554695.7~ 554680.34 554665.8~ 554649.9:3 554634.22 554627.86 ~·m_ ._m" .. .- . . .. 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 349.48 degrees Bottom hole distance is 8569.12 Feet on azimuth 31.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 5972773.7~ .._ ._____5972aº-6,~ 5972959.a~ 5973051.9~ 5973143.3.~ 5973235.08 5973328.7~ 5973421.61 5973516.12 5973620.4~ 5973704.0~ . __.._____Q9L3797 .5~ _..59.Z},891.3~ .__597~9__a;3~ 5974080.6e ------·-5974174.6a 5974269.3~ 5974363.11 5974455.78 5974548.91 5974643.34 5974735.08 5974832.31 5974925.9~ 5975020.9~ 5975115.6~ 5975210.3~ 5975304.90 597s401~ 5975494.5 5975588.62 5975682.9€ 5975777.3~ 5975869.8J _.__p975967.1ì 5976061.32 5976156.21 5976250.61 5976346.08 597~.JI.79 5976534.7~ 5976623.7€ 5976713.2~ 5976802.04 5976890.9~ ------S976976Æ 5977011.9~ .-,.- ConocoPhillips Ala'lnCo,Slot #102 Pad 1 B, Kuparuk River Unit,North Slope, Alaska wellb. 1 02 Well path: GSS<0-468'>MWD Rvsd<555-14044'> Date Printed: 21-0ct-2003 .i. BAKER HUGHES INTEQ Comments MPJf!1___ ! TVP ft 14044.00 3717.6 Ea¡;!Lf!l Comment . ____..._. 44:19.1131; proiected Data - NO $LJR~_ .-- --"----- ~-----_._--~-- Hole Sections Diameter I Start in ¡ MD ft 143/41 121/4 81121 I ____on_oj I Casin s Name ¡Top Top i MQIfl.L..... IY~[f:!L 16"X30" Conducto~_____Q.OO _ 133/8" Casin 0.00 9 5/8" Casing,. ! 0.00 5 1/2" Slotted Lineri 7645.0 Top Shoe ._ MOIft .O~QºE: ......º~ººI; O.OOE 5638.65 ! Shoe Shoe TVDJft] i Nortl]Iftl Eastff!] ,,120.00 O.OON _ 517.5~ 24.04N 3653.2§ 1246.04 3776.96 7327.83 Well bore -..-..-----..........----- 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 349.48 degrees Bottom hole distance is 8569.12 Feet on azimuth 31.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 09/25/03 Scblumbepgel' NO. 2967 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD . 2X-14 " <:~J.j - .M PROD PROFILEIDEFT 09/01/03 1 2A-24 c,::: - eLl PROD PROFILE 09/02103 1 3F-15 5;;:: -)¿ )S ~ INJECTION PROFILE 09105/03 1 3S-24 " "')::. -Q ib INJECTION PROFILE 08/01/03 1 , 3S-09 ~-~-, INJECTION PROFILE 08102103 1 3H-07 -0 -l- C INJECTION PROFILE 08106/03 1 2K-11 ~ .:::¡ SBHP SURVEY 08/07/03 1 1D-103 ,':::' .:3 'C"" (I INJECTION PROFILE 08/20/03 1 1C-174 .~ Y... -LA J~ INJECTION PROFILE 08/23/03 1 1B-102 Nt J- 23432 USIT 08/14/03 1 ~,""'-I"'- ~'),r-'--' ') l~_ Ji '~:I- :\; _~;a · .. ~,-.¡t t="! . rOO ~ '"'1 i U :: 'ì<.'¡"""""""'~o"""- -- ~--------- SIGNED: "\"~\\ ~ ;:", -\ '\ \. 0 Ö'~~~ ~ /"\/"'"\ . '\.. DATE: '~rp ? R :20G~) Ù\I"sÌia Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank yò~~ \ ;:,:¡ Ç/)mmIS5ìCfI .i-\Jìchcr~a ~~~\'(\~ . . dC~3-JCJ~ r'¡_ BAKER MUGHU Transmittal Form iil 1!P&111'i91!-I00-æoBTI1stW '__'U"''';';:;';;;:';~,;;,;;;:~:;__ _ -"" - .. "'. ......'( > ~. ~ ... , .. .... ~.. _". _ -.,( .''1 If!'fIli'' INTEQ ~'.,,"~., ...'">"....w Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: IB-I02 Contains the following: v ¡-'" 1 LDWG Compact Disc V~}9 V (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 512521 Sent By: Glen Borel Received By~~~ , l'<~ ~ ~ C't,.:t--.. C'" /,"'"",,, Date:. Septl~"2oq3,, Date: ,.J 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 ~ .'~ "". :~;~=;;;~~~~~~~~,-~--- .. "' . 1ffÆlTŒ (ill~ fÆ~fÆ~æfÆ . AI4ASIiA. ORAND GAS CONSERVATION COlWlISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 28,2003 Mr. Randy Thomas Ku paruk Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99510 Re: Request for Waiver of Diverter Requirements at 20 MC 25.035 (c) Kuparuk River Unit 1B-102, 1B-101 Dear Mr. Thomas: We have received your request for exception to the Diverter requirements at 20 MC 25.035 (c) for the drilling of two West Sak wells from KRU 1B pad. In support of this request, you have submitted drilling information from your most recent well 1B-20. In addition to the drilling information, you offer that due to the proximity of the Kuparuk Operations Center and CPF-1, that employing the diverter could actually put more people and property at risk than drilling without the diverter. A review of the well files for the 19 previously drilled wells on 1B pad confirms that no shallow gas incidents were experienced. The surface hole of 1B-20 was drilled with "normal" mud weights and the submitted record does not indicate that any problems were encountered. Surface casing was run and cemented successfully with cement circulated to surface. As with most Kuparuk wells, the surface casing of 1B-20 was set below the West Sak. On 1B-102 and 1B- 101, the surface casings will be set above the West Sak. The target West Sak Formation will not be penetrated prior to NU the BOP and no known gas bearing intervals will be penetrated while drilling the surface hole. Returning to a production pad after several years absence to conduct drilling operations has the potential to encounter gas that may have escaped from the production wells. Small casing leaks have been know to allow lift gas to move into unsealed outer annuli and push all fluid into the formations below the surface shoe. According to the well files, all the surface casing annuli on 1B pad were Arctic Packed and the shoes sealed with cement. Regardless of the past drilling history in the area, the operator must be prepared to accommodate drilling hazards that may develop over time. Each well should be carefully monitored to detect any developing drilling hazards, and subsequent operations 4 Mr. Randy Thomas July 28, 2003 Page 2 of 2 . . conducted accordingly. Dialogue with CPA's problem well engineers should be ongoing so that any changes in well integrity are highlighted. Your request to waiver the diverter requirements for KRU IB-I02 and KRU IB- 101 is approved. ~~~p~, Sarah P n Chair TM\SP\jjc . . NOTE TO FILE ConocoPhillips Alaska Diverter Waiver Request KRU 18-102 (203-122) KRU 18-101 (no PTD assigned) ConocoPhillips Alaska (CPA) has applied for an exception to the requirement to have a diverter on the subject wells. The reason for CPA's exception request is the close proximity of the pad to the Kuparuk Operations Center and CPF-1 Production Center. 18 pad is located immediately across the spine road from the facilities. It is CPA's contention that having a diverter in place creates a greater risk to general personal safety if a well control event were to occur. They have also provided information that indicates no shallow gas was encountered drilling 18-20. This document considers CPA's request and recommends approving it. CPA has proposed to drill 3 new wells on 18 pad at Kuparuk. In addition to the 2 listed West Sak wells, CPA is presently drilling 18-20 (203-115) on the drill site. DS 18 is one of the original KRU development pads with the first well (18-05) being drilling in 1977. The original 320-acre development wells (10 wells) were drilled in 1980 - 1981 and 8 additional wells were added in 1993 - 1994. All wells were drilled using diverters and an examination of the well files indicates that all wells were drilled with no recorded shallow gas events. The only unusual events identified were on 18-17 and 18-15 where lost circulation was encountered while cementing the surface casing. It is suspected that thaw bulbs developed from the nearby original producing wells may have developed resulting in the lost circulation. Unstable gravel zones with water present were identified while drilling 1D pad wells and the conductor hole for 18-102 was wet. As on 1D, CPA proposes to set and cement a "gravel" string at about 650' in 18-102 to isolate those potential problems. This response was successful on 1 D pad. CPA did employ a diverter on 18-20, however it was necessary to modify the diverter line so it could be run under the installed flowlines without putting the "stack up" in a bind. CPA did not seek to waive the diverter requirements on that well since it was the first well drilled on this pad in several years. When drilling had not been conducted on a production pad for some time, there is concern that shallow casing leaks could have allowed injection or lift gas to charge formations in the immediate vicinity of the pad. In their application, CPA provided the surface hole drilling reports for 18-20 and there is no indication of any shallow hole problems. Mud weights were as planned with no identified need to "weight up". The surface casing was successfully run and cemented to surface. On drillout the shoe tested to 16.3 ppg EMW without leaking off. In contrast to 18-20, the surface casing of both WS wells will be set above the WS. For 18-102, it is planned to set the 9-5/8" casing about 10' TVD above the WS while in 18- 102 the 10-3/4" surface casing will be set well above the WS. The WS is the only identified hydrocarbon reservoir in this immediate area. There should be little uncertainty regarding the formation depth. 20 AAC 25.035 (h) (2) allows the Commission to approve a variance from the diverter requirements if [...] drilling experience in the near vicinity indicates that a diverter system is not necessary. . . I recommend approval of CPA's request based on the file review conducted, the drilling information presented for 18-20 and that no identified gas bearing zones will be penetrated prior to setting the surface casing. This approval is specifically for 18-102 and 18-101. ~0~~~L Tom Maunder, PE Z_ Sr. Petroleum Engineer July 25, 2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Day TMD Hole Sl, (ft)(in) . QonocoPhillip~ Älaska ·.J'VIÙdSummary i=leport 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 Mud Type' MW . ......(pp Start: 7/10/2003 Rig Release: Rig Number: Vise. i PV , VP I Gels 10s/10m/30m ¡API WL ~THP WlHTHP T (s/qt) . (ep) 1(~~~ott2)1.._._.~.I~!..10Oft2)__J~~~~in)rCc/30m~~ (ep)__! 23 36 17/42/0 13.6 10 10.0 24 49 34/58/66 11.2 24 9.0 30 31 12/24/31 7.2 8 9.0 33 36 14/34/51 5.6 8 9.0 15 22 12/24/31 4.6 7 10.0 19 29 16/35/53 3.6 9.0 22 29 16/26/39 3.6 9.0 12 14 6/11/15 3.8 9.0 14 18 8 /24/38 3.4 8.0 20 27 12/22/30 3.6 10.0 ...---- ..... 1 Spud Mud 192 2 1,259.0 Spud Mud 190 3 4,137.0 12.250 Spud Mud 111 4 5,230.0 12.250 Spud Mud 96 6 5,850.0 8.500 Non-Disp. LS 55 7 7,487.0 8.500 LSND 62 8 8,015.0 8.500 LSND .~ 66 9 8,015.0 8.500 LSND <6\1) 42 10 8,015.0 8.500 LSND ~\C 53 11 8,105.0 7.000 LSND 54 I (1) \ ·.Page 1 of 1 Spud Date: 7/10/2003 End: Sand! TS LGS' MBT ~ Oil ¡Tot. Hard.. Tot. Vol. _~~~~1.___~___º-__L. .~o:o) I (~~.~~I) i__~~1. :. ()... .-.J~~I! 3.00 22.5 3.50 25.0 6.50 22.5 8.00 25.0 7.00 17.5 8.00 22.5 10.00 22.5 9.00 17.5 9.00 17.5 10.00 20.0 3 3 2 1 2 o 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Printed: 7/21/2003 1 :48:36 PM ConocoPhiUips·Älaska .. Casing Report Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: Remarks.. Y··" 1 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: Page 2 of 2 centralizers on every joint for the next 11 joints, Ran to 2955' with no problems and circulated btm's up, Finish running a total of 123 joints to 5221.70', had to work thru tight spot @ 5139', casing had good displacement going in hole, No mud lost while running casing. -~ - ,- --- , ,. (\ v Printed: 7/21/2003 1 :42:46 PM ConocoPhillips Alaska CementlngReport Page 3013 Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: 1 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: .-.-- . ....________. _un. . .._ ___.. ~. __. .. ____.___.___. .....__ .. . . __. . n___. on. .____.___. Trª~_~.?:m~ _._.___. Stage No: 1 Slurry No: 4 of 4 - Additives ···--·----·T··-··-·-······ .. .....-..-. --....--. -.---.-------...- Ty'~__.....L. Ç9f1Centration.l . .._UI~.i~_ ;......J,.!g~id Conc..:_._. 0.8 %BWOC 0.6 %BWOC 0.3 %BWOC ." ... -..-... ~_.._--- ; ; Units --. ------ ..-----......--....--... .-...---.. D65 D46 D79 .. . .. Casing Test ShOè·Test Liner Top Tèst Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: . .. . . . .. ': Log/Survey Evaluation . Interpretation Summary ...-.-.-.....---..-. CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: CementTop: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Held PJSM with all personal. Switch over to Dowell, Mix & Pump 5 bbls CW100, Pressure test lines to 3500 psi, Mix & pump 45 more bbls of 8.3 ppg CW1 00 at rate of 4.5 bpm @ 350 psi, Shut down, Drop btm plug, Mix & pump 50 bbls MudPUSH wI Red dye added at 10.5 ppg at rate of 4.5 bpm @ 280 psi, Switch to Lead cement, Mix & Pump 511.0 bbls (670 sxs) of ArcticSet Lite cmt. mixed at 10.7 ppg w/1.5%D79, 1.5%S001, .6%D46, .5%D65, 43.1 %D124, 30.0%D53, 9.0%D44 at rate of 6.3 bpm @ 300 psi, Followed by 141.0 bbls LiteCRETE Tail cmt (348 sxs) mixed at 12.0 ppg w/.8%D65, .6%D46, .3%D79 at rate of 5 bpm at 250 psi, Pump 2 bbls fresh water, Shut down, Drop top plug, Displace cmt wI 20 bbls fresh water followed by total of 370.5 bbls 9.4 ppg mud at rate of 6.5 bpm @ 400 psi, Had red dye to surface after 94 bbls of displacement, Slowed rate down to 2.6 bpm @ 800 psi for last 20 bbls of displacement, Bumped plug with 1300 psi, CIP @ 2045 hrs 7/14/03, Had good circ. thru out job, Had 191 bbls cement returns to surface, Floats held -OK, Worked casing until started pumping Tail cement. Note; At 120 bbls Lead cement pumped, Dowell's computer system on the cement unit had complete failure. Cement report was manually put in with figures written down on completion of the job. Printed: 7/21/2003 1 :43:07 PM -/3- ... I Pressure pumpif29... Strks psi Test Shut-in Min QSi I Casin Pumpi~ Strks psi t 1450 1450 1450 1450 1450 1450 1450 1450 1425 m5 1400 1400 1400 1400 1400 1400 1400 1400 1400 1375 1375 1375 IÞ 01 Shut-in Miñ psi o 0.25 0.5 1" 1.5 '2 "'2.š 3' 3.5 4' 4.5 5 5.5 ""6 6.5 7 7.5 8 8.5 9 9.5 10 VOlume Bled Back 1.8 Bbls 150 275 400 550 675 775 900 1000 1125 mõ 1400 1450 2 4" '6 "8 10 12 14 16 18 20 22 23 o iO 1 :õ 2-:ã 3 7":"' -0 4 - --0 5 .: 0 6 "'0) 7 - 0 8 3550 9 3550 1 0 3550 15 3400 20 3400 25 3 00 30 3400 Vôfume Pumped "IT. "'B5rs Volume Bled Back 4.7 Bbls 26 1850 28 1950 30 2150 32 2300 34 2450 36 2625 38 2775 40 2925 42 3075 44 3200 46 3350 48 355 - 200 300 500 650 750 870 970 1TIõ 1230 135õ 1500 1700 2 4' 6' ã 10 12 14 16 18 20 22 24 Well Name Drilling Supervisor: Type of Test: Hole Size: IS-1/2' RKB-CHF: 24.9 Ft Casina Size and Description: Casina Test Mud Weight: 9.3 ppg Mud 10 min Gel: 14.0 Lb/100 Ft2 Test Pressure: 3,500 psi Rotating Weight: 131,000 Lbs BlockslTop Drive Weight: 35,000 Lbs Estimates for Test: 4.7 bbls __ _ _ Hole Dee!!!__ _ _ __ 5.250 Ft-MD 4.026 Ft-TVD R PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. ~ Doyon 141 Date: 7/15/2003 Fred Herbert 1 Mike Thornton Pump used: #1 Mud Pump ... J Casing Shoe Test LOT/FIT annulus and DP. ... B-20 1 Pressure IntearìtvT est Mud Weight: 9.3 ppg Mud 10 min Gel: 19.0 Lb/100 Ft2 Rotating Weight: 131,000 Lbs BlockslTop Drive Weight: 35,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 1397 psi 9 bbls ~ I· 1 PIT 15 Second Shut-in Pressure, psi 1450 held - R 1450 0.052"")( 4010' + 9.3 Ft-MD 14010 Ft-TVD) = 16.3 ppg - Lost 150 psi during test 95.8% of test pressure. = = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 5221 4000 EMW t '-. ~ \ 30 20 25 Minutes 5 10 15 Shut-In time, o PIT Point o 6 5 -LEAK-OFF TEST 4 3 Barrels i! 2 --'-CASING TEST , o 3500 3000 2500 2000 500 000 500 o Commenfs: 1 1 UJ 0:: ::::> II') II') UJ 0:: a.. ~ \1 . , n, .~0 '"' ~ru.~ ) ~~""\ II'-. ~ ~ 0..'> "t---~cr~~~cJ o '" ~t) ~(¿ \ \) ~t\ \ ~. \ '1 ~/f> '\ ~ i\ ~ \J ~~' '\ '" \ 'ó' \. \ \0 '\- \ ~ 'I) {~ +.é\ \ s "S(" ~ ,,5"/, 'Jo.J ~ \. \ ~((: '~M~,^,,*eJ +0 ~0\~<:e-.. ,G~~"'>I G> , e e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 18, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West y'h Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval, 1 B-102 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to modify the permit to drill for well 1 B-1 02. ConocoPhillips has installed a conductor on 1 B-1 02, but upon drilling the rat hole we have found water. A 36" pipe was driven to 120' to isolate the water and a 16" X 30" insulated conductor was then cement into place. We are concerned that a thaw bulb may have formed in this area of the pad and as a precaution we would like to request permission for a gravel string to be set. Geology has assured us that the bottom of the coarse problematic gravel is approximately 400' MD, therefore, we would set the 13 3/8" casing at 500' in order to place any surface gravels behind pipe and mitigate any risk of serious wash outs and running gravel in this portion of the hole. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, /<L{. M r. - . . ~c....fð ~o"'"'-<' '1((5(03 R. Thomas Kuparuk Drilling Team Leader CPAI Drilling and Wells RT /skad I oJ OR\G\NAL '" , e e ÅJ tif~ ~ ,1M 1(5 ,. 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Variance 0 Annular Dispos. 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 203-122 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23167-00 7. KB Elevation (ft): 9. Well Name and Number: 89' AMSL 1 B-1 02 8. Property Designation: 10. Field/Pools(s): ADL 25649 & 25639 I ALK 467 & 464 Kuparuk River Field / West Sak Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured) Junk (measured): N/A nla N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft): NIA NIA 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/23/2003 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJD WINJD WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name R. Thomas Title Kuparuk Drilling Team Leader Signature ,(::té Ot.-( t:..,. t2..íl..o.......s Phone 265-6830 Date '71IðÙ~ . COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '" !~~., ..1'5 Plug IntegrityD BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 " Other: <...O,,~\\-"C,,~ o\-c,~~"- \ <>-~\'~~\ ~~\'i Subsequent Form Required: "-O\""-ú\ 4.0 \ ~~ ~~ BY ORDER OF Date: 7/2(lí] Approved by: COMMISSIONER THE COMMISSION I STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RBDMS BFL JUt 2 1 2003 OR\G\NAL SUBMIT IN DUPLICATE Form 10-403 Revised 2/2003 . . v~ / / <Sf -3 ConocriPhillips July 14,2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Waiver Approval on Diverters for 18 Pad Kuparuk Dear Sir or Madam: ConocoPhillips is in the process of drilling 18-20 in the Kuparuk field with two more follow up wells, 18-102 and 18-101 to be drilled next into the West Sak fonnation. Due to the close proximity of8 pad to major production facilities and the additional safety risk a diverter would pose, ConocoPhillips is requesting a waiver to dispense with utilization of a diverter on 18-101 and 18-102. Hazards and Additional Risk Presently, drilling operations on 18 pad presents a dilemma in the fact that the diverter line placement tends to cause more of a risk then not having a diverter at all. 8y observing the "As Staked Survey" attached, one can see that for the rig configuration the diverter line will have to be placed in such a way that it will be pointed directly to the KOC/CPF1 facility and the Spine Road. 18-101 and 18-102 have surface locations side by side and the same criteria applies to each. Due to the proximity of the diverter line in relationship to the CPFlIKOC facilities we feel that there would be a risk in placing more people in hanns way if a well control issue did occur. Recent Historv There has been no problems with hydrates or overpressured zones in the past on 18 pad. Doyon 141 has recently moved to 18 pad and is presently in the process of drilling the 18-20 (Kuparuk producer). The surface hole has been drilled to 5230'MD, 4015' TVD, equating to the bottom of the West Sak formation. No problems with gas hydrates or over pressured sands were encountered while drilling the well. Presently the surface casing is being run on this well. . . Risk Mitigations To help mitigate any risk ofa well control situation both the wells, 1B-101 and lB-102 will have surface casing set above the West Sak. On 1B-102 the 95/8" surface casing is to be set 10' TVD above the West Sak sand, while on 1B-101 a surface string of 10 %" casing is to be set at +/-2500' well above the West Sak formation. Doyon has gas detection equipment present on the rig and as an added precaution ConocoPhillips has placed an additional detector in the possum belly. This should ensure detection of gas in the mud system at the earliest possible moment during drilling if such an incident should occur. Attached are the morning reports for 1B-20, the "As Staked Survey" for lB-101 and 1B-102, and information on the gas detection equipment on Doyon 141 for your review. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ~~~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling DESCRtPllON REV DA 1E BY DESCRIPllON 1"")10 -~+~ ~ GRID NORTH NOT to SCALE '-1 8-17 WS 1. 18-~Õ~ . 18-101 . 8-16 8-7 WS2. 8-18. WS3. 8-19. 8-6. WS 4. WS 5. 8-151 8-5 WS 6. 8-14. WS7. 8-131 8-4 WS8. 8-3. 18-20. 8-2. 8-1. WS 9. 18-11. WS 10. WS 11. 18-10. WS-2. 18-9. l ~ o ~ ~ CL U 40' ~ o N 2\ LEGEND . EXISTING CONDUCTOR o CONDUCTOR STAKED THIS SURVEY NOTES 1. BASIS OF LOCATIONS AND ELEVATIONS ARE MONUMENTS 7 A & 78 PER LHD AND ASSOCIATES. 2. COORDINATES SHOWN ARE NAD27, ZONE 4. 3. ALL ELEVATIONS SHOWN ARE 8.P.M.S.L., ALL DISTANCES SHOWN ARE TRUE. 4. DATE OF SURVEY 7/06/03, F.B. L03-14, pp. 22-24. LOCATED IN SECTION 9, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. A.S.P.s Sec. Line OIS PAD O.G. NO. Y X LA TITUDE LONGITUDE F.N.L. F.E.L. ELEV. ELEV. 18-101 5,969,647.2 550,229.1 70' 19' 40.24" 149' 35' 33.53" 50" 210' 60.4' 54.3' 18-102 5,969,647.2 550,249.1 70' 19' 40.24" 149' 35' 32.94" 50" 190' 60.4' 54.0' Conoc6Phillips Alaska, Inc. CADD FILE NO. / / DRAWING NO: LK6102D24 7 06 03 ~OUNSBURY It ASSOCIATES, INC. , ... INGINEBRS PLAIIIŒRS AREA: 18 MODULE: XXXX UNIT: 01 DS18 WELL CONDUCTORS 18-101 AND 18-102 AS-STAKED LOCATIONS NSK 6.1 02-d24 PAR~01 OF 1 REV: 0 . . Doyon Drilling Rig 141 12 · 1 ea. - PVT display and flow show · 1 ea. - stand pipe and mud pump pressure indicator · 1 ea. - weight indicator, 750,000 # capacity · 1 ea. - Iron Roughneck torque indicator · 1 ea. - tong line pull torque indicator Mud · 1 ea. - detector at the shaker belly, ng and · 1 ea. - H2S detegtorinpit<årea, cellar, · 1 ea. - trip t~nk volume indicator · 1 ea. - H2S / metl'îanealarm controller floor, anqdrillers WELL CONTROL E·CUI.I?MENT BOP Equipment · 1 ea. - Hydril annular diverter BOP, 21 14" x 2000 psi · 1 ea. - Hydril annular BOP with nitrile element, model GK, 13 5/8" x 5000 psi, flanged, NACE trim. · 3 ea. - Hydril single gate, model MPL, 13 5/8" x 5000 psi, flanged, NACE trim with 10" operators. BOP Ramsfor 135/8" x 5m · 1 - set ofHydril blind rams. · 1 - set of Hydril2 7/8" rams. · 1 - set of Hydril 3 1/2" rams. 12 . . "Todd Driskill" ddriskill@doyondrilling.com> 07/14/2003 11 :48 AM To: Steven M Shultz/PPCQ@Phillips cc: Subject: Gas Detection Rig 141 Steve, Rig 141 is equipped with a Shic Sierra Monitor, Model 5000, Digital H2s and Methane Gas Detector System complete with audible and visual flashing light alarms. Methane detector located at Shaker possum belly, cellar, rig floor and drillers console. H2s detector in pit area, cellar, rig floor, drillers console. Thanks, Todd ~ - ..... Page 1 of 1 ConocøPhillips, Alaska Daily' Drilling Report WELL NAME 1 JOB NUMBER I EVE~DC~DE 124 HRS PROG TMD ITVD DFS 1 REPT ~O. DATE 1 8-20 7/10/2003 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD IDAILYTAN~ CUM. TANG Dear! Gladden/Pat Reillv n1334@ppco.co Dovon 141 Kuparuk River 8,635.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD PU DP and workina on diverter modifications. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Complete diverter modification, check svstem for leaks, spud 224,598 224,598 LITHOLOGY JAR HRS OF SERVICE I BHA HRS SINCE INSP 1 LEAKOFF AFE AUTH. 10029900 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST (in) @ (ft) (in) @ (ft) - [pp rECD [MUD DATAIEAii.YCOST [ - .._- DENSITY(ppg) 8.70 0 ; CUM COST 0 --...-. FCIT.SOL OIUWATro/oSandlMBT l--Ph/pM I I I - ~~~IME_~~~_ FV PVNP GELS WUHTHP PflMf CI Ca ----. -...-. 192 23/36 17/42 13.61 31 I [ 122.5 [ 10.01 [ I [ I OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE ! DESCRIPTION - 03:00 03:30 0.50 MOVE P MOVE MOVE Move pipe shed and rock washer. 03:30 04:30 1.00 MOVE P MOVE MOVE Move modules and sub off well. 04:30 07:30 3.00 MOVE P MOVE MOVE Move modules and sub to 18 pad. 07:30 08:30 1.00 MOVE P MOVE MOVE Move sub over well, level and shim. 08:30 10:30 2.00 MOVE P MOVE MOVE Spod modules, level and shim. 10:30 11:30 1.00 MOVE P MOVE MOVE Move pipe shed and rock washer to 1 B pad. 11:30 12:00 0.50 MOVE P MOVE MOVE Spot pipe shed and rock washer. Take on water to pits and nippled up. Rig accepted on 16-20 @ 1200 hrs 7/10/03. 12:00 13:00 1.00 MOVE P RURD RIG UP Spot rock washer and berm around same. (mix spud mud). 13:00 14:00 1.00 MOVE P RURD RIGUP extend diverter line beyond flow lines. Move camp. (mix spud mud) 14:00 18:00 4.00 DRILL P RIRD RIGUP Hook up pipe skate, install riser pipe on stack. (mix spud mud) Go through pre spud check list. 18:00 22:50 4.83 DRILL P PULD RIG UP Load pipe shed w/150 joints 5" DP and PU same. 22:50 23:00 0.17 DRILL P OTHR RIGUP Diverter and koomey test. Witness waived by John Spaulding (AOGCC). 23:00 00:00 1.00 DRILL P PULD RIGUP PU HWDP. 24 HR SUMMARY: Move from 3R to 1 B-20. PU DP. PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS .... ConocoPhillips Company 2 Baker Hughes Inteq 4 Doyon Drilling Inc 29 APC - Alaska Petroleum 2 Doyon Universal Service 5 M- Drilling Fluids 2 -- MATERIALS I CONSUMPTION . ITEM UNITS USAGE .. ON HAND I ITEM UNITS . USAGE ON HAND -- Fuel gals 710 3,690 Water, Drilling bbls 710 -110 Camp Fuel gals 640 2,720 Water, Potable bbls 88 112 Tioga gals Printed: 7/14/2003 8:56:28 AM ConocoPhilUps. Alaska Daily' Drilling Report JOB NUMBER I EVENT CODE 24 HRS PROG TMD ITVD IDFS I ODR 1,259.0 1,259.0 1,253.0 1.00 AELD NAME I OCS NO. AUTH MD DAILY TANG Kuparuk River 8,635.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 138,727 Drill 12-1/4" Surface hole LITHOLOGY ¡JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE I 10029900 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING 7/11/2003 1,203.20 11.660 228.630 I 16.000 (in) @ 138.0(ft) 9.625(in)@ 5,214.0Cft) DENSITY(ppg)- 8.90 I PP-I ECDi lMUD DATAl DAILY COST I 0 FV ! PVNP L - GELS I WLI~:iTHP I FCIT.SOL OILlWAT %Sand/MBT I Ph/pM I PflMf I 190 I 24/49 34/58 I 11.2/ I 31 I I 125.0 I 9.01 I I -..__._ ._._.0- BHA NO. I 2 I BHA I HOLE CONDITIONS I BIT NO. 1 R1 BIT HC MX-CX1 1 1.00 12.250 NAVIDRILL M1C 1 28.15 12.125 SHORT NMDC 1 9.35 7.750 NON-MAG STAB 1 5.37 MWD 1 29.37 NM CROSSOVER 1 1.55 NM FLEX COLLAR 1 28.64 NM FLEX COLLAR 1 30.00 NM FLEX COLLAR 1 28.87 CROSSOVER 1 2.45 HWDP 4 120.31 JARS 1 30.30 HWDP 25 755.02 GHOST REAMER 1 6.00 - WELL NAME 18-20 SUPERVISOR I RIG NAME & NO. Dearl Gladden/Mike Thor I n1334@ppco.co CURRENT STATUS Dovon 141 DrillinQ 12-114" hole @ 1965' 24 HR FORECAST 8.000 7.750 7.875 8.062 7.875 8.000 5.000 6.250 5.000 5.000 ................... ,Page 1 of 2 IREPT NO. DATE 2 7/11/2003 CUM. TANG o CUM INT ANG WI MUD o CUM COST WI MUD 363,325 AUTH. LAST BOP PRES TEST I CUM C()·ST CI C?a I o H2S I LiME I ES I I - 2.810 2.875 2.875 2.875 2.875 2.625 3.000 2.250 3.000 4.281 BITS . BIT I RUN SIZE MANU!':. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 11 1 12.250 HC D 5022494 12/20/20/2011 138.0 7/11/200:: 1-1-NO-A-E+NO-DTF 1R1/ 2 12.250 HC D 5022494 12/20/20/2011 915.0 7/11/200:: O-On...- .. . BIT OPERATIONS BIT I RUN .. WOB I RPM I GPM PRESS PBIT I HRS I 24Hr DI.ST 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP 11 1 15/20 I 60 I 80 I 500 1,250 193 I 4.30 I 777.0 180.70 I 4.30 I 777.0 I 180.70 - .,..... . ...,_. . .__n___.__.._ M.D. ..... 0.00 138.00 283.56 375.01 467.01 556.33 647.90 AZIMUTH -.. 0.000 0.000 322.700 298.600 265.740 226.870 225.590 ._____. ._ .. ...____ SURVE_YJ~AIA_._......._.__..._ T.V.D. NIS CUM EIW CUM SECTION.· M.D. . INCL. ¡ AZIMUTH _ _,..... .._._.. . ..____n...' _.... ..._. ___............ .. 0.00 0.00 0.00 0.00 737.35 3.430 215.750 138.00 0.00 0.00 0.00 829.31 5.820 219.180 283.55 0.90 -0.69 0.23 918.88 8.540 221.390 375.00 1.74 -1.62 0.71 1,010.68 8.570 225.170 466.99 1.99 -2.54 1.43 1,109.04 10.060 228.260 556.30 1.36 -3.59 2.64 1,203.20 11.660 228.630 647.83 -0.52 -5.53 5.21 n... . ..n__. INCL. 0.000 0.000 0.890 0.720 0.520 1.120 2.270 .- T.V.D. I N/S·:ëuMEIW CUM' SEC~~~~.- 737.17 -3.93 -8.36 9.24 828.82 -9.78 -12.92 15.88 917.68 -18.29 -20.18 26.12 1,008.46 -28.23 -29.54 38.86 1,105.52 -39.12 -41.15 54.05 1,197.99 -50.88 -54.43 71.11 Printed: 7/14/2003 8:56:06 AM - ...................... Page 2 of 2 1 B-20 ConocoPhillips,. Alaska. Daily.DrillingReport I JOB NUMBER EVENT CODE 24 HRS PROG I TMD I TVD I DFS I REPT N20. I ODR 1,259.0 I 1,259.0 I 1,253.0 I 1.00 I DATE 7/11/2003 WELL NAME ... NO. .. I . MAKE OF PUMP 1 I Ems~;-" PUMP1HYDRAULlC DATA I STROKE (in) I LINER '(in) .SPM I Q (gpm) I PRESS. (psi) I TOTAL Q I KILL SPM I PRESSURE 1 12.000 1 6~ÕO()- 120 1 507.621 1,250 I .. 507.621 ~~~1._~~ TROÜ~,=-EI OPERATIONS SUMMA~Y-_" ... HOURS CODE SUB PHASE DESCRIPTION -------.--- -----------. 00:00 01:00 1.00 DRILL P PULD SURFAC Pick up HWDP & 1 Stand DC's, Stand back in derrick 01:00 03:00 2.00 DRILL P PULD SURFAC Make up BHA #1 & Oreint same 03:00 03:30 0.50 DRILL P CIRC SURFAC Fill conductor & diverter with mud 03:30 06:00 2.50 DRILL T OTHR SURFAC Observe leak at FMC riser connector & attempt to repair same - No Good, Remove end section of diverter line to modify same. (Note; Riser connector in bind, Due to diverter line going under Pad flow lines.) 06:00 09:00 3.00 DRILL P PULD SURFAC Stand back BHA & Pick up 28 stands drill pipe. (While modifying diverter line) 09:00 09:30 0.50 DRILL Np OTHR SURFAC Wait on orders to proceed by AOGCC Tom Maunder for verble approval on modifcation to diverter line -OK. 09:30 17:45 8.25 DRILL P DRLG SURFAC Spud @ 0930 hrs. Drill f/138' to 915' ART= 2.9 hrs AST = 1.4 hrs 10-15 WOB, 80 RPM, 506 GPM @ 1200 PSI, UP 90K, DN 90K, ROT 90K, TO 2500, MWD Failed @ 915' - Would not switch over from Magnetic to High side. 17:45 19:00 1.25 DRILL Np TRIP SURFAC POOH to MWD 19:00 20:00 1.00 DRILL Np PULD SURFAC Change out MWD, Orient new MWD, Check bit -OK 20:00 20:30 0.50 DRILL Np TRIP SURFAC RIH (Test MWD -OK) to 915' 20:30 00:00 3.50 DRILL P DRLG SURFAC Drill f/915' to 1259' ART = .9 hrs AST = .8 hrs 15-20 WOB, 80 RPM, 506 GPM @ 1250 PSI, UP 90K, DN 90K, ROT 90K, TO 2500. 24 HR SUMMARY: PIU HWDP & BHA, Fill hole- Diverter leaked, Repair same, P/U 28 stands Drill pipe, Spud & drill to 915'- MWD failed, POOH, Change MWD, RIH to 915', Drill to 1259' COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE PERSONNEL DATA NO. HOURS COMPANY .- 4 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO. HOURS 4 2 2 -:--" ... .... .. ............-...------.. .. .. .. ... .................__....MATJ:f:UALS I CONSUMPTION USAGE : ON HAND: ITEM i """'1",915"" î'" 15,100 Ii Water, Drilling I I 3,040 Water, Potable .--- ...-.-.--..-... .......-.-.-.... ITEM UNITS ·T.....· gals I gals ... ...__.._ __....__....... ____.... n. . ..... . _. _. .___..._ _ ... . UNITS USAGE : ON HAND i 'j' . ---- ...-.. i bbls 880 520 I bbls I I 318 -..---.... Fuel Camp Fuel RESERVOIR NAME 1 R-18 I 11 B-20 RESERVOIR AND INTERVAL DATA' ZONE I TOP BASE I I 580 0 I '. COMMENTS .....-- Printed: 7/14/2003 8:56:06 AM WELL NAME 1 B-20 SUPERVISOR [RIG NAME & NO. Dearl Gladden/Mike Thor n1334@ppco.co CURRENT STATUS DrillinQ 12-114" hole @ 4540' Page 1··of 2 ConocoPhillips, Alaska Daily Drilling Report ¡JOB NUMBER 1 EVENT CODE 124 HRS PROG TMD I TVD I DFS 1 ODR 1 2,878.0 4,137.0 I 3,321.0 I 2.00 FIELD NAME I OCS NO. AUTH MD DAILY TANG Kuparuk River 8,635.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 118,469 Doyon 141 24 HR FORECAST T.D. 12-1/4" Surface hole, WiDe hole, Run 9-518" CSQ. LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING 7/12/2003 4,081.37 50.990 249.080 16.000 (in) @ .. .- . . DENS~TY(ppg): 9.30 PP . m .EC?D ....MUD.DATA.. DAILY COST... 0 . ..CUM COST.. 0 ... FV PV/VP· GELS WUHTHP FCIT.SOL: OIUWAT %SandlMBT Ph/pM Pf/Mf CI Ca H2S, LIME· ES 111130/31 [12/241 7.2/" ¡ ·21 I I I·' 122.5·· I 9.01· I I'· ¡ ...... 1 ·-r I..·· i···· -----_..~_._._---_._--_. - .. BHA NO.2·· BHA I HOLE CONDITIONS .·1 BIT NO. 1 R1 . ....... .. . _.~ BHA WT. BELOW JARS STRING WT. UP 1 STRING WT. DN 1 STRING WT . ROT 1 TORQUE I UNITS I BHA LENGTH .... BIT HC MX-CX1 1 1.00 12.250 NAVIDRILL M1C 1 28.15 12.125 SHORT NMDC 1 9.35 7.750 NON-MAG STAB 1 5.37 MWD 1 29.37 NM CROSSOVER 1 1.55 NM FLEX COLLAR 1 28.64 NM FLEX COLLAR 1 30.00 NM FLEX COLLAR 1 28.87 CROSSOVER 1 2.45 HWDP 4 120.31 JARS 1 30.30 HWDP 25 755.02 GHOST REAMER 1 6.00 ._'. . _~iT/RU!L.._~Z~~~NUF. 1 R 1 I 2 r 12.250 ¡¡..¡c- BIT lRUN --'--- 1R1/ 1 WOB _~M' 1 GPM 21 15i~1 80/100 1 590 -,. - - LEAKOFF 138.0 (ft) BITS I TYpe I SERIAL NO. I - JETS OR TFA 1 D 15022494 1 12/20/20/2011 AFE NEXT CASING 9.625 (in) @ 8.000 7.750 7.875 8.062 7.875 8.000 5.000 6.250 5.000 5.000 I REPT NO. DATE I 3 7/12/2003 CUM. TANG o CUM INT ANG WI MUD o CUM COST WI MUD 481,794 AUTH. 10029900 LAST BOP PRES TEST 5,214.0 (ft) -"" ~--",.. .,._-.'. 2.810 2.875 2.875 2.875 2.875 2.625 3.000 2.250 3.000 4.281 I DEPTH IN DATE IN I·· I~C)·D-L.B·G~O.R 1 915. 0 7I11/200~ 0-0...··· .. . .. ..-. .-. .,,- .. .. ......, . _.. . ~URV.~.v DATA NIS CUM EJW CUM SECTION: M.D. M.D. 1,295.83 1,388.74 1,481.78 1,574.22 1,666.51 1,760.19 1,851. 71 1,945.21 2,037.56 2,128.08 2,222.42 ... INC~.: i ~ZIMUTH 13.420 224.140 15.160 225.970 16.450 229.890 18.300 230.890 22.530 232.570 26.870 234.030 30.400 235.910 34.730 237.460 39.080 239.810 42.570 238.060 44.960 239.210 T.V.D. . .. 1,288.41 1 ,378.44 1,467.97 1,556.19 1,642.66 1,727.75 1,808.06 1,886.85 1,960.68 2,029.17 2,097.29 .. -64.78 -80.96 -97.91 -115.50 -135.39 -158.75 -183.88 -211.48 -240.29 -270.84 -304.79 --,. -- -",_.",. BIT OPERATIONS PRESS. P BIT 1 tiÄs-····..· 24Hr DisT 24H;··ROP ~mëUM HRS ¡ ëï.iM DEPTH·:·CUMï~-õp 1,950 281 I 16.6Õ- I 3,222.ÕI194~16.60 ·1- 3,222.öT194:10 . . - -68.94 -85.18 -104.01 -125.28 -150.58 -181.98 -217.90 -259.97 -307.33 -357.99 -413.71 ... 90.22 111.87 136.19 162.98 194.40 232.83 276.1 0 325.98 381.15 440.05 504.98 .-. . 2,314.57 2,407.77 2,502.08 2,595.19 2,687.67 2,778.30 2,871.53 2,963.75 3,057.54 3,148.32 3,242.65 INCL. , 46.450 47.280 49.800 51.110 51.910 51.440 50.490 52.010 50.870 49.630 50.770 ._,... . - .. .. .... ...- .. . .-.--- ---.-. - ..m,... AZIMUTH T.V.D.! NIS CUM EJW CUM SECTION .... .. i _ _ __ 237.680 2,161.65 -339.31 -469.91 570.59 236.510 2,225.37 -376.26 -527.00 638.06 237.440 2,287.81 -414.77 -586.26 708.16 235.590 2,347.09 -454.39 -646.13 779.29 236.630 2,404.65 -494.75 -706.22 850.94 236.820 2,460.85 -533.75 -765.66 921.42 236.700 2,519.57 -573.45 -826.23 993.21 237.230 2,577.29 -612.65 -886.53 1,064.54 238.290 2,635.75 -651.78 -948.55 1,137.40 238.020 2,693.80 -688.60 -1,007.8 1,206.79 237.740 2,754.18 -727.14 -1,069.2 1,278.81 -. Printed: 7/14/2003 8:55:44 AM - - . """"", ...",.,... . , Page '2 of 2 ConocoPhillips, Alaska Daily Drilling Rep()rt WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG TMD ITVD I DFS I REPT ;0. DATE 1 8-20 ODR 2,878.0 4,137.0 3,321.0 2.00 7/12/2003 ..,.,.,,,,,. ...-....---.---. .. n. ... ...__.._____0..._.... ....... ... ...------ ---. .... --..-------.---.-.-.-. -...... - ..-----.... - f---. .... .. ..---.- . . .. . ..-.....---- .... . . . ...§Y.RY.Il:,Y..DATA ..... ......-.. .... . .. ...... .... .....- .-.. ._--,--,-_. .--.... 0.._. . .. .... M.D. INCL. AZIMUTH T.V.D. NIS CUM EIW CUM SECTION:, M.D. INCL. , AZIMUTH T.V.D. ¡ NIS CUM EIW CUM SECTION .. ........ .. --... . .. .... ..". ... ...... .. .--. ..... . ... .. .. 3,336.25 50.870 238.660 2,813.31 -765.37 -1,130.8 1,350.96 3,802.33 50.420 246.000 3,111.89 -931.17 -1,447.3 1,708.03 3,428.51 49.970 237.980 2,872.10 -802.71 -1,191.4 1,421.68 3,893.75 51 .480 246.560 3,169.48 -959.72 -1,512.3 1,778.98 3,522.84 49.760 240.170 2,932.90 -839.77 -1,253.2 1 ,493.49 3,986.29 51.560 248.380 3,227.07 -987.48 -1,579.2 1,851.31 3,617.40 49.490 245.120 2,994.18 -872.86 -1,317.2 1,565.46 4,081.37 50.990 249.080 3,286.55 -1,014.3 -1,648.3 1,925.26 3,709.27 50.980 246.170 3,052.94 -901.97 -1,381.5 1,636.05 ._n...._ . ...-....- n_ ..... .... .__... -...- .... . ".."...... PUMP I HVDRAULlÇ DATA . _ . ..........,..... .. NO. MAKE OF PUMP : STROKE (in) LINER (in) SPM ~ a (gpm) ¡ PRESS. (psi)' TOTAL a KILL SPM I PRESSURE 1'-·" " Emsco .,..... .. . . -,.... j 12.000" r..·.. 6.0001 140 1 592.221 1,800 I 592.221 . . . .. -....---.-. . OPERATIONS SUMMARY FROM ',TO HOURS CODE ¡TROUBLE SUB ! PHASE i DESCRIPTION .. -- 00:00 12:00 12.00 DRILL P DRLG SURFAC Drill f/1259' to 2744' (2438' TVD) AST = 5.5 hrs ART = 2.4 hrs UP 115K DN 96K ROT = 105K, TO ON BTM= 4,000 ftIlb, TO OFF 8TM= 3,000 ftIlb, 590 GPM @ 1600 PSI, WOB 20K, RPM 100 12:00 00:00 12.00 DRILL P DRLG SURFAC Drill f/2744' to 4137' (3321' TVD) AST = 1.8 hrs ART = 5.2 hrs UP 140K DN 105K ROT= 120K, TO ON 8TM= 9,000 ftIlb, TO OFF BTM= 7,000 ftIlb, 590 GPM @ 1800 PSI, W08 25K, RPM 100 24 HR SUMMARY: Drill f/1259' to 4137' - PERSONNEL DATA COMPANY , SERVICE NO. HOURS COMPANY SERVICE NO. HOURS f--- I ----- - "-------- - - ----- ConocoPhillips Company 4 Baker Hughes Inteq 4 Doyon Drilling Inc 29 APC - Alaska Petroleum 2 Doyon Universal Service 5 M-I Drilling Fluids 2 .,.." .._-,. .. _..n.. .. .. ......,.-...,... ... -.. . .--...,. .. ......,... . MATERI~....~.l...ÇONSUMPTION ......-.-.-..-. ... .. ITEM UNITS USAGE : ON HAND ITEM UNITS USAGE ON HAND ... I i I 12,21"Ö'- ""¡[Water, Drilling i I 1,635 u"T . Fuel gals 2,890 bbls 665 Camp Fuel I gals 1 320 I 2,720 Water, Potable I bbls I I 328 -- RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP -,- I COMMENTS ,_~ASE 11 B-2Ö 1 - 1R-18 2030 01 Printed: 7/14/2003 8:55:44 AM Page 1 of2 ConocoPhillips, Alaska Daily"Drilling Report WELL NAME I JOB NUMBER 1 EVENT CODE 124 HRS PROG TMD ITVD IDFS I REPT ~O. DATE 1 B-20 ODR 1.093.0 5.230.0 4.015.0 3.00 7/13/2003 SUPERVISOR .1 RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG Dearl Gladden/Mike Thor n1334@ppco.co Doyon 141 Kuparuk River 8.635.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD Running 9 5/8" surface csg 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Run & CMT 9-5/8" csg. - ND Div I NU & Test BOPs - TIH 111.008 592,802 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. 10029900 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 7/13/2003 5.173.61 51.650 248.600 16.000 (in) @ 138.0 (ft) 9.625 (in) @ 5.214.0 (ft) I F~$OL:IE~~!.~~~:iÞJLV;:}::7 I cUM COST "--..--- DENSITY(ppg) 9.55 PP 0 FV PVNP GELS WUHTHP CI ca~1 H2S I LlMETES oo--T--Š3/36 I 14i3¡-¡-S.61 I I I I -. .. --".. --,,".. --. -.-.". ..-, BHA NO. 2 Bt1.!.'.I HO~.!= COr-J.º.!TIONS BIT NO. 1R1 ....... .. .-..... .......... -,--.-.. .......----- --,... ..... BHA WT. BELOW JARS STRING WT. UP STRING WT. DN STRING WT. ROT TORQUE I UNITS BHA LENGTH ....... ... .. ....... - ,.. .... .,. . --.. . ..-..... ... .-.--. .. -. . 27 155 120 130 10 ft-Ibf 1.076.38 BIT HC MX-CX1 1 1.00 12.250 NAVIDRILL M1C 1 28.15 12.125 SHORT NMDC 1 9.35 7.750 2.810 NON-MAG STAB 1 5.37 MWD 1 29.37 8.000 NM CROSSOVER 1 1.55 7.750 2.875 NM FLEX COLLAR 1 28.64 7.875 2.875 NM FLEX COLLAR 1 30.00 8.062 2.875 NM FLEX COLLAR 1 28.87 7.875 2.875 CROSSOVER 1 2.45 8.000 2.625 HWDP 4 120.31 5.000 3.000 JARS 1 30.30 6.250 2.250 HWDP 25 755.02 5.000 3.000 GHOST REAMER 1 6.00 5.000 4.281 --_.._--_.._~--- --.--..~ --."._- --- -. - .. -.- BITS -- BIT fRUN _I SIZE I MANUF. I TYPE -I SERIAL NO. I JETS OR TFA I DEP1H.IN DATÇIN I-O-D-L-B-G-O-R ---- - -ID - 7/111200~ O-Õ------ .. 1 R11 21 12.250 I HC 15022494 I 12/20/20/2011 I 915.0 --,. _n --..". on _ -.-"... -",. -"'" ..._,_. . -.,-.... . .-... -.. . . .._,.,,_.... .-.. Brr º~.ERATIONS . .....,--.-.. . ..... .-,-..--- . . ...... ..-.....--... ... .-..-.. BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP , CUM HRS CUM DEPTH' CUM ROP .. .. 2 I .. 20 13Õ······ Î 80/1Õ6 i 59Õ···.. i 2.156"····· I 287-··· I -.. r 1.093.Õ······î .... r-·-· 27.6Ö-·······1 .....".... I -.-...... 1R1/ 11.00 99.36 4,315.0 156.34 .....----- ..---- .- --. --- .__.~ SURVEY DATA ..._n .. ..-....... ..... _I AZIMLJ.TH '" - ~.. ."., . M.D. INCL. T.V.D. NIS CUM E/W CUM SECTION: M.D. INCL. AZIMUTH T.V.D. ; N/S CUM E/W CUM SECTION --.. -- .- -- 4.175.20 50.560 247.740 3.345.88 -1,041.1 -1.715.9 1.997.76 4.729.29 50.720 250.880 3.699.85 -1.205.6 -2,108.8 2,423.12 4.267.59 50.240 245.180 3,404.78 -1.069.5 -1.781.2 2.068.88 4.823.27 50.760 250.260 3,759.33 -1.229.8 -2.177.5 2,495.45 4.359.63 50.030 244.370 3,463.78 -1.099.6 -1.845.1 2.139.52 4.914.64 51.130 248.560 3.816.90 -1.254.7 -2.243.9 2.566.12 4,452.08 49.080 246.250 3.523.75 -1.129.0 -1.909.0 2.209.86 5.008.97 51.180 248.410 3.876.06 -1,281.7 -2,312.2 2.639.39 4.546.07 50.800 248.060 3.584.25 -1.156.9 -1.975.3 2.281.70 5,100.54 51.300 249.450 3.933.39 -1.307.3 -2,378.9 2.710.56 4.637.01 51.000 250.500 3.641.60 -1.181.9 -2.041.3 2,352.00 5.173.61 51.650 248.600 3.978.91 -1,327.8 -2.432.2 2.767.53 -. .- --- PUMP I HYDRAULIC ' DATA NO. 1 MAKE OF PUMP I STROKE (In) I LiNER (in) ISPM I Q (gpm) PRESS. (psi) TOTALQI KILL SPM I PRESSURE I Emsco -. I 12.000 I 6.000 I 140 I 592.22 I 1 592.22 2.150 Printed: 7/14/2003 8: 13:50 AM - ~ Page20f 2 ConocoPhillips, Alaska .... ....;... .. Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG jTMD ITVD DFS I REPT ~o. DATE 1 B-20 ODR 1,093.0 5,230.0 4,015.0 3.00 7/13/2003 - OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION . ..-..------.-- -- - ~---_.._-_. --- 00:00 15:15 15.25 DRILL P DRLG SURFAC Drill fl 4137' to 5230' (4014' TVD) AST= 1.9 hrs ART= 9.1 hrs, UP 155K, DN 120K, ROT 132K, 590 GPM @ 2150 PSI, 100 RPM, 20-30K WOB 15:15 16:30 1.25 DRILL P CIRC SURFAC Pump Hi-Vis weighted sweep & circ for wiper trip 16:30 18:00 1.50 DRILL P WIPR SURFAC Precautionary back ream out to 4137', Slight packing off. 18:00 18:30 0.50 DRILL P WIPR SURFAC RIH to 5230' no problems 18:30 21:00 2.50 DRILL P CIRC SURFAC Pump Hi-Vis weighted sweep & Circ hole clean total of 3.5 btm's up, 590 GPM @ 2150 PSI 100 RPM wI 7,000 ftllb TQ 21:00 00:00 3.00 DRILL P TRIP SURFAC POOH to BHA (Hole in very good shape- Pulled 30K over f/1800' to 1700', wiped out very good) 24 HR SUMMARY: Drill f/1259' to 5230' 12-1/4" TD, Circ. clean, Wipe & pump out to 4137', RIH to 5230', Circ. hole clean, POOH to BHA. PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS .....~---._..._.. ----..--- ConocoPhillips Company 3 Baker Hughes Inteq 4 Doyon Drilling Inc 29 APC - Alaska Petroleum 2 Doyon Universal Service 5 M-I Drilling Fluids 2 .-- --.------. MATE~IAL$.LCºNSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND u_". __'n'_h_" __... .... .....-- ."-.- -"~"..._..."'-- ---- Fuel gals 2,420 9,790 Water, Drilling bbls 1 ,420 645 Camp Fuel gals 240 2,480 Water, Potable bbls 59 331 .--. -- ..--..- .- -- ..-- .. _. RESERVOIR AND INTERVAL DATA RESERVOIR NAME 1 ZONE 1 TOP BASE 1 COMMENTS 11 B-20 1 01 ---. 1 R-18 1450 Printed: 7/14/2003 8:13:50 AM . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Field 1B-102 ConocoPhillips Alaska, Inc. Permit No: 203-122 Surface Location: 501' FNL, 191' FEL, SEe. 9, TllN, RlOE, UM Bottomhole Location: 3740' FNL, 1052' FEL, SEC. 34, Tl2N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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, ~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thisH day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc~illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 10, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Permit to Drill, West Sak Injector, 1 B-1 02 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore injection well, an undulating well in the West Sak "B" and "0" sands. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 AAC 25.005. The expected spud date of 1 B-1 02 is July 23, 2003. If you have any questions or require any further information, please contpct Steve Shultz at 263-4620. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad JUL 0 ;1 . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . Á/q PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill [;2] RedrillU 1b. Current Well Class: Exploratory U Development Oil U Multiple Zone D Re-entry D Stratigraphic Test D Service [;2] Development Gas D Single Zone [;2] 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: / ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1B-102 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 13898' / / Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 TVD: 3785' 4a. Location of Well (Govemmental Section): / 7. Property Designation: Surface: 501' FNL, 191' FEL, Sec. 9, T11 N, R10E, UM ALK 25649 & 25639 West Sak Pool / Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4269' FNL, 5266' FEL, Sec. 2, T11N, R1OE, UM/ ADL 467 & 464 7/23/2003 Total Depth: / 9. Acres in Property: 14. Distance to 3740' FNL, 1052' FEL, Sec. 34, T12N, R10E, UM 2560 Nearest Property: 14' at Target 4b. Location of Well (State Base Plane Coordinates): / 10. KB Elevation 15. Distance to Nearest Surface: x- 550248 / 5969647.5 Zone- 4 Well within Pool: 1B-12, 15.7' @ 575' y- (Height above Gl): 89' AMSL 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) ./ 12/,0 ..... /' Maximum Hole Angle: /tAI/D ~"'1 dAe-S Kickoff depth: 300 ft. 94° Max. Downhole Pressure: psig I Max. Surface Pressure: psig 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) 42" 16" 62.5# H-40 Weld 92' 28' 28' 120' 120' Pre-Installed 12.25" 9.625" 40# L-80 BTC 7813' 28' 28' 7841' 3679' 920 sx AS III Lite & 408 sx LiteCrete 8.5" 5.5" 15.5# L-80 Hydril 511 6207' 7691' 3650' 13898' 3785' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (h): Total Depth TVD (h): Plugs (measured) Effective Depth MD (h): Effective Depth TVD (h): Junk (measured) Casing Length Size Cement Volume MD rvD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee [;2] BOP Sketchb,j Drilling Program ~ Timev. Depth Plot 0 Shallow Hazard Analysis I;;J Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program [;2] 20 AAC 25.050 requirements [;2] 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name R. Thomas Title Kuparuk Drilling Team Leader Signature \ .~~~ PhO~S_' -t 3 ð Date 7/"',.fÔ 3 PmnRmd bv ShRron Af/8uD-ÐrRke , Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 20::3,.. f2-2- 50- ()-¿'7- 2. 3 I~ 7- ct::J Date: 7/1'-I/6::) for other requirements Conditions of approval : Samples required DYes ff.No Mud log required H~:;~~~~·· Hydrogen sulfide measures DYes WNO Directional survey required Other: \v\ \T ~ C-CL.IIV\.<L"- \ Q 0~ \' \ \-'1 '--o~ JUL 0 æ-A ß... .~"-~ BY ORDER OF '7/:;¢/òJ Approved by: COMMISSIONER THE COMMISSION Date: '" ,., '1 " . Form 10-401 Revised 3/2003 . OR, , Submit in duplicate ¡"A . . IB-I02 Drilling Hazards Summary 12 1/4" Open Holel 9 5/8" Casing Hazard Risk Level Mitigations Broach of Conductor Low Monitor cellar while drilling surface hole, conductor set @ 120' which is 40 feet deeper then the 80 foot standard of the past Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat Running Sands and Gravels Low Maintain planned mud parameters, weighted mud, viscous sweeps Abnonnal Reservoir Moderate Diverter drills, increased mud weight, flow Pressure checks Lost Circulation Low Reduced pump rates, rheology, LCM Swabbing Moderate Trip speeds, proper hole fill, pumping out 8 1/2" Open Holel 5 ~" Slotted Liner Hazard Risk Level Mitigation Abnonnal Pressure Low Stripping drills, shut-in drills, increased mud weight Stuck Pipe Low Good hole cleaning, backreaming after TD Lost Circulation Low Reduced pump rates, rheology, LCM Hole Swabbing on Trips Low Trip speeds, proper hole fill, pumping out Conoc~iIIiPS . Drill and Complete Procedure West Sak Well #lB-l02 BID Sand Undulating Injector AFC Well Plan SUmmary Horizontal Locations Location at Surface I NGS Coordinates RKB Elevation 89.3' AMSL Northings: 5969647.5 Eastings: 550248.3 Pad Elevation 61.3' AMSL 500.9' FNL, 191.3' FEL, Section 9, T11N/R10E UM Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Measured Depth RKB: 7901' Northings: 5971198 Eastings: 555720 Total Vertical Depth, RKB: 3689' 4268.9' FNL, 5265.6' FEL, Section 2, T11NjR10E UM Total Vertical Depth, 55: 3600 Location at Total Depth I NGS Coordinates Measured Depth RKB: 13898' / Northings: 5976999 Eastings: 554602' Total Vertical Depth RKB: 3785' ;' 3739.6' FNL, 1052.4 FEL, Section 34, T12NjR10E UM Total Vertical Depth 55: 3696 Formation Markers and Directional Waypoints True Measured Vertical True Vertical Depth Depth Depth (SS Description (RKB feet) (RKB feet) feet) Doyon 141 RKB 0 0 -89 Ground Level 28 28 -61 20" Conductor 120 120 59 Base Permafrost 1848 1672 1583 TOD K-15 2897 2067 1978 TOD Uqnu C 5798 3041 2952 TOD Uqnu B 6595 3312 3223 TOD Uqnu A 6760 3370 3281 K-13 Shale 7410 3580 3491 9-5/8" Casinq Point 7841 3679 3590 TOD West Sak "D" 7901 3689 3600 C-1 8197 3731 3642 B-1 8343 3751 3662 B-2 8962 3750 3661 C-2 9279 3727 3638 C-3 10159 3712 3623 B-3 10409 3729 3640 B-4 11516 3729 3640 C-4 11769 3710 3621 C-5 13328 3751 3662 B-5 13613 3768 3679 TD - 5 1/2" Liner Point 13898 3785 3696 Steve Shultz ISSUED, Printed 7/9/2003 11:32 AM Page 1 of 4 o , -"-'* Conoc~illiPS e¡ Drill and Complete Procedure West Sak Well #IB-l02 BID Sand Undulating Injector AFC Surface Hole Mud Program Gel Spud Mud System Surface to 1000' Initial Value Final Value Density (ppg) 8.5 8.5-8.8 / Funnel Viscosity (seconds) 250-300 250-300 Yield Point(cP) 40-60 40-60 Plastic Viscosity (lb/100 sf) 7-15 7-20 10 second Gel Strength (lb/100 20-30 20-30 sf) 10 minute Gel Strength (lb/100 25-60 25-60 sf) pH 8-9 8-9 API R/trate(cc) 8-15 8-15 Solids (%) 3-8 3-8 LSND 500' to 7037' TD Initial Value Base of Final Value Permafrost Value Density (ppg) 9.0 9.2* 9.2 / Funnel Viscosity (seconds) 60-70 45-55 45-55 Yield Point(cP) 30-34 20-25 20-25 Plastic Viscosity (lb/100 SF) 8-13 11-21 15-23 10 second Gel Strength (lb/100 10-15 10-15 10-15 SF) API Filtrate(cc) <10 <6 <6 Lateral Mud Program GEM to (lateral) Initial Value Final Value Density (ppg) 9.0 9.0 ./ Funnel Viscosity (seconds) 45-60 45-60 Yield Point 18-25 18-25 {cP} Plastic Viscostiy (lb/:lOO sf) 8-14 8-14 Tau 0 4-7 4-7 Chlorides 14-16K 14-16K pH 8.5-9.0 8.5-9.0 APr filtrate <6 <6 **HTHP filtrate <10 <10 MDT <12.5 <12.5 Solids(%) 4-7 4-7 Steve Shultz ISSUED, Printed 7/9/2003 11:32 AM Page 2 of 4 Oi1' :,lh I .:~'I"J! Cono~iIIiPS . Drill and Complete Procedure West Sak Well #lB-102 BID Sand Undulating Injector AFC CasinglTubing Program Hole I Casing Csg/Tbg Top Btm Size OD Wt/Ft Grade Conn. Length MD/TVD MD/TVD 12-1/4" OH 9-5/8" 40# L-80 BTCM 7813 Surface 7841/3679 8-1/2" OH 5-1/2" 15.5# L-80 Hydril 511 6207 7691/3650 13898/3785 D/B sand 9-5/8" 4-1/2" 12.6# L-80 NSCT 7663 Surface 7691/3650 Casinq Logging/Formation Evaluation Program 12-1/4" Open Hole Rotary Steerable, MWD Directional, LWD (GRjRES) / Section 8-1/2" Open Hole D B Sand Cased Hole Rotary Steerable MWD (Directional, Pressure while Drilling, At Bit Inclination) LWD GR RES / 9-5/8" bond log to be run once 5 1/2" liner is set if cement operations for the 9 5/8"casing were as planned. If no cement to surface or loss of returns then run the CBL u on com letion of ni lin u the BOPE. Cementin Pro ram Hole Cate 0 Volume T e of Cement Pro erties Surface I 50bbls CW100 Pre-flush Density 8.4 ppg Production 50 bbls MudDush XL Density 10.2 ppg Top of Tail at 700 Bbls Lead Slurrv (AS Lite) 7741' MD / (920 sacks) 3661' TVD Top of West Sak 87 bbls Tail Slurrv D at 7901' MD / ( 408 sacks) "G" Cement 3689' TVD Well Obiectives and Justification 1B-102 is proposed as a 5900' undulating D/B injectO:(HUI) west of the 1C-178 multilateral producer. The lateral portion of the proposed well path will climb 10 to 15 feet structurally from south to north, but a 30' down-to-the-north fault occurs at 4600 feet into the horizontal section from the southern target. 1B-102 crosses this fault to provide pressure support for the toe of 1C-178. The total length of the well has been set to place the toe about 300 feet south of a second fault to the north. Review of oil-water contacts indicate the D and B sands well above the OWC in this area. Steve Shultz ISSUED, Printed 7/9/2003 2:00 PM Page 3 of 5 0" "..., i { ,~n 1'1 " , Con~iIIiPS . Drill and Complete Procedure West Sak Well #lB-102 BID Sand Undulating Injector AFC Reservoir Pressure and Well Control The closest offset well is 1C-178 which is a multilateral into the West Jék "D" and "B" sands. Presently the bottom hole pressure is thought to be 1610 psi at 3500' SS which gives a 8.8 ppg MWE. Although, it is felt that the pressure from 1C- 178 has not migrated to the point of where this well will be intersecting the "D" sand, we will be setting the 9 5/8" casing 10 feet TVD above the "D" sand as a precautionary step to ensure integrity in the event pressure is encountered. All BOPE will be tested a~~~ state regulations with a 250 psi low pressure test and a 5000 psi high pressure test, with the annular tested~;>i. Each component is to be tested to a minimum of 5 minutes. Estimated Maximum Surface Pressure Estimated BHP: 1610 psi - TVD: 3500' Gas Gradient: .1 psi/ft ,/ 1610 psi-(3500')*.1 psi/ft=:1260 psi (Estimated Maximum Surface Pressure) Close Approach and Anti-Collision Risks and Mitiaation All wells pass the major risk category, and no close approach issues exist for this well. \ Q \)~S~~\'--l ~~ a~êll\ \...) 0.."",...:1 \ ~~ a f'- \ ~ , Incidental fluids generated from drilling operations may be hauled to the nearest permitted I we or may be In 9} A pumped down the surface / production casing annulus of a permitted, existing well on Drill te-1C. Poss Ie Class II f'd.L. r- / disposal well is 1R-18. Cement rinsate is not to be injected down any of these dedicated disp ut should be . recycled or held for an open annulus. A request for Well 1B-20 to be placed on annular injection will be made to the state for waste disposal on 1B-102. All waste fluids hauled from 1B-102 must be properly documented and manifested. Any fluids disposed of should be properly recorded and reported to Sharon Allsup-Drake, the Anchorage Drilling Aide. No -' more than 32,000 barrels should be disposed of in any permitted annulus without approval from Drilling Team Leader or Drilling Engineer Waste Drilling Fluids Disposal Procedure Summarv: 1. MIRU Doyon 141 over 1B-102 2. NU 20" diverter on the Vetco Grey Landing Rig and function test 3. MU 12 V4" bit and drill surface hole to 3500' and TFB and rotary steerable assembly 4. Drill remaining 12 V4" hole to 7841'MD/3679'TVD 5. Circulate bottoms up and backream out of hole 6. Run and cement 95/8",40#, L-80, BTC casing with cement to surface a. If there are problems with cement coming to surface then the port collar located at +/- 1000' will be actuated and a stage cementing job will be performed to get cement to surface. b. Close port collar and make cleanout for CBL 7. MU 8 W' bit with rotary steerable system and run in hole, test casing to 3000 psi for 30 minutes 8. Drill out shoe plus 20 feet of new hole 9. Perform an FIT to 12.0 ppg MWE / ~ 10. Drill an 8 W' undulating hole to 13,898' MD/ 3785' TVD 11. Circulated clean and backream to the 9 5/8" casing shoe 12. Circulate bottoms up utilizing sweeps 13. POOH with directional tools and LD same 14. RU and run 5 V2", 15.5#, L-80, Hydril 511 slotted liner with a 3 V2" wash string 15. Run to bottom on 5" drill pipe, set the liner top packer and hanger, release from hanger 16. Displace the 5 W' X 8 V2" annulus to weighted brine, unsting from pack off and displace the entire hole to weighted brine 17. POOH with running tools and LD 5" drill pipe and 3 W' wash string 18. RU and run 4 W' completion 19. Release Doyon #141 Steve Shultz ISSUED, Printed 7/9/2003 1:40 PM '0/. fJ .i! I " r, Page 4 of 5 Créoted by bmÎChoel For: S Shultz Dale plotted: 8-Jul-2003 Plot Reference is 18-102 Ver1J1, Coordinotes are in feet feference.slot-#1D2~ Est. RKB""'89', 7200 6800 6400 6000 5600 5200 4800 4400 ^ I 4000 ~ ....... Q) Q) 3600 - '--' .£ ....... L 3200 0 Z 2800 2400 2000 1600- 1200 800 400 0 400 C-4 Inverted(Base 0) 74.56 AZIMUTH 5669' (TO 9 5/8" CSG PT) ***Plone of ESTIM'Q SURFACE LOCATION: 501' FNL, 191' FEL SEC. 9, T11 N, R10E 1,0° "os\ I"" be s/'OO,?e'«'.g '? ?,v1 tI"\\Ó- tlcsf o? (ÓC 1'.0::1.>* '" " !J~ o 400 800 TRUE ý.;-",s íO? . Q 4: ~70 :0/,00 '1'1 .J í"'" ,,-OC Top 91 AZ 1200 1600 24·00 2800 3200 3600 4000 4400 4800 5200 East (feet) -> Created by bmichaeJ For: S Shultz Date plotted: 8-Ju!-2003 Plot Referance is 18-102 Ver#L Coordinates are in feet reJerenCfJ slot #102. Vertical Depths are r¡;.fereoce Est 0 300 600 ~ "" /'""". - (l) 1200 Q) - "'-" ""j 1800 2100 Q) 2400 :J l- I- I 2700 V 3000 3300 3800 3900 300 0 Estimated RK8: 89' KOP 3.00 6.00 9.00 DLS: 3.00 dog per 100 it 11.80 14.59 17.18 19.84 22.58 DLS: 3.00 deg per 1 25.45 00 28.88 32.43 4.00 deg per 100 it 5/100 ConocoPhillips Alaska, Inc. Structure : Pad 1 B Well : 102 : Kuparuk River Unit Location: North Slope, 74.56 AZIMUTH 5669' (TO 9 51st' CSG PT) ***Plane of Proposal*** T-3 EOC DLS: 5.00 deg per 1 00 it 50.00 Base Permafrost 60,00 Top K-15 TANGENT ANGLE 70.40 DEG DLS: 5.01 deg per 100 it .../ ConocoPhillips 6000 ConocoPhiHips Alaska, Inc. .,/ ConocoPhillips For: S Shultz Date plotted: 8-Ju!-2003 PJot Reference is 1 B-1 02 Ver#1 Coordinates are in feet reference slQt #102. Vertical Depths are· reference Est. Structure : Pad 18 Well: 102 Field: Kuparuk River Unit Location: North Slope, 4: INTE.Q 349.48 AZIMUTH 356' (TO 9 5/8" CSG PT) ***Plane of Proposal*** ~ " ~ ~)? 1'" 1'ì-~<" ,,\'- «" ~oss \>-c \09 \) c:'-:' ~/-:, ~ '0/ Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 82.0 82.50 82.93 85.00 87.50 90.00 90.14 92.50 94.17 94.17 94.17 94.17 94.17 94.17 92.50 90.19 90.00 87.50 86.10 86.10 86.10 86.10 86.10 86.10 86.10 86.10 87.50 90.00 90.14 92.50 94.31 94.31 94.31 94.31 94.31 94.31 92.50 90.1 89.31 87.13 86.81 86.58 86.58 86.58 86.58 86.58 86.58 86.58 86.58 86.58 86.58 86.58 ConocoPhillips Alaska, c. ~ ConocoPhiUips For: S Shultz Dati:: plotted: 8-Jul-20Q3 Plot Reference is 18-102 Ver#1. Coordinates are in feet reference s!ot#102. Vertical Depths ore referi::nce Est. Structure : Pad 1 B Well : 102 Field: Kuparuk River Unit Location: North Slope, ø£ 'N'I'EQ East (feet) -> 70 60 50 40 30 10 o 10 100 60 000 50 ^ 40 Z 0 ..... 30 -+ J 500 20 400 10 300 1400 1500 90 80 For: S Shultz Dote plotted: 8-Jul-20Q3 Plot Reference is 18-102 Ver#1. Coordinates ore feeL ref¡;¡reJlcG slot #102, Vertical Depths are reference Est. 100 200 300 400 Q ~£ 500 600 800 900 nocoPhillips Alaska, Inc. 0../ ConocoPhillips Structure , Pad 1 B Well , 102 : Kuparuk River Unit Location: North Slope. East (feet) -> 1000 1100 1200 1300 1000 -.-*"'--..,------- 500 ^ I 400 300 .--.. "'"" CD CD 200 -+ "--'" 100 102 300 ConocoPhiHips Alaska, ~/ ConocoPhilliDS Ii Inc. Structure : Pad 18 Well: 102 Coordinates are in TJ3et reference slot #102. Vertical Depths are re-ferli:!nce Est. .. ~ Field: Kuparuk River Unit Location: North Slope, East (feet) -> 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 7800 7200 ["'00 6000 L ~ 5400 ^ I 6500 Z 0 ., 6200 ...... ::J 5900 \380~0 Created by· bmichael Dote plotted : Plot Reference is 18-102 VerH1. Coordinates are in feet reference slot #102. Vertical Depths are UE NORTH 10 29 20 210 260 \ \ 200 160 \ 190~ Normal Pia s shown ore 170 All on rence CmnpalR)': Field: Hden'lIce SUe: I{efen'nce \Vl,II: Heren~nce Wcllplllh: 'aker Hughes IncorporaA Anticollision Report .. . . ConocoPhillips Alaska. Inc. Kuparuk River Unit Pad 1 B 102 1B-102 Version#1 ... .. - NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 13897.67 ft Maximum Radius: 5000.00 ft Survey Program for Definitive Wellpath Date: 7/212003 Validated: No Planned From To Survey ft ft 0.00 13897.67 Planned: 1B-102 Version#1 V10 Summary -. j <----- Of[~et Wellpath -~-----> Site Well .' . , 'iWellpath Pad 1 B Pad 1 B Pad 1B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1B Pad 1 B Pad 1 B Pad 1 B Pad 1B Pad 1 B Pad 1 B Pad 1 B Pad 1B Pad 1 B Pad 1 B Pad 1 B Pad 1 B Pad 1B Pad 1B Pad 1 B Pad 1 B Pad 1 B Pad 1B Pad 1 B Pad 1C Pad 1C Pad 1C Pad 1C Pad 1 C Pad 1C Pad 1C Pad 1C Pad 1 C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C Pad 1C ---.- "- 101 10 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 09 10 102 102 104 104 104 109 109 1B-101 B-Lat VersO.c V 1B-10GI VO 1B-11GI V1 1B-01 VO 16-12 VO 1B-13 VO 1B-14 VO 1B-15 VO 1 B-16 VO 1B-17V2 1B-18 VO 1B-19 VO 1 B-20 Vers#1.a VO Plan 1 B-02 VO 1 B-03 VO 1 B-04 VO 1 B-05 VO 1 B-06 VO 1 B-07 VO 1 B-08 VO 1 B-08A VO 1B-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 1C-01 V2 1C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1C-07 VO 1 C-08 VO 1 C-09 VO 1C-10 VO 1C-102 V6 1C-102L 1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1C-109L 1 VO -- Dlllc: 7/8/2003 Cu-ordinal"(:'Œ) Ih''erellcc: Vertical ('1'\'1» H"ferellce: n Version: 4 Toolcode MWD+SAG+IFR Reference MD ft - 399.07 333.86 317.76 337.35 575.48 321.25 343.70 322.20 348.92 626.46 347.97 299.97 339.36 338.86 340.47 342.22 344.15 323.13 348.56 702.65 702.65 332.37 400.00 353.42 317.38 853.28 1323.59 521.07 396.23 417.23 368.78 344.69 365.71 354.78 6900.00 7300.00 8400.00 7800.00 7500.00 7536.11 7200.00 7200.00 7200.00 Offset MD ft 400.00 350.00 325.00 350.00 575.00 325.00 350.00 325.00 350.00 625.00 350.00 300.00 350.00 350.00 350.00 350.00 350.00 325.00 350.00 700.00 700.00 350.00 425.00 375.00 325.00 850.00 1375.00 525.00 400.00 425.00 375.00 350.00 375.00 375.00 n. .... _.. . . . . . _ ..on.. Reference: Error Model: Scan Method: Error Surface: Time: 16:05:33 .. - .,. I'a¡:c: 1 Well: 102. True North Wellhead(89') 89.0 nh: Oracle -.. .. .. - - Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Tool Name MWD+SAG+IFR (AK) Ctr-Ctr So-Go Distance Area ft 20.84 1109.51 954.35 788.06 15.69 410.99 334.26 291.85 49.56 27.26 97.00 160.88 629.07 667.73 548.00 428.59 307.75 187.70 68.11 33.98 33.98 1268.13 1519.16 1080.79 1161.00 156.18 172.83 234.45 280.37 329.40 381.09 435.48 488.53 1001.26 ft --- 6.18 4.53 4.23 4.59 8.96 4.51 4.93 4.54 5.21 9.95 5.01 4.18 5.19 4.68 4.71 4.74 4.77 4.39 4.78 11.46 11.46 4.50 5.74 4.88 4.22 14.65 28.91 7.93 5.65 6.03 5.15 4.72 5.10 4.91 Allowable Deviation. ft 14.68 1104.98 950.12 783.47 6.73 406.48 329.33 287.32 44.36 17.31 91.99 156.71 623.88 663.06 543.29 423.86 302.98 183.31 63.33 22.52 22.52 1263.63 1513.43 1075.91 1156.78 141.53 145.03 226.54 274.73 323.38 375.94 430.77 483.43 996.36 6825.00 4682.20 248.67 4433.61 5600.00 4849.74 161.91 4690.06 6525.00 4617.75 157.68 4467.17 7700.00 2627.31 123.40 2512.64 6275.00 2947.43 170.03 2778.30 6200.00 2936.49 167.66 2769.41 6975.00 1300.34 213.37 1105.63 6975.00 1300.34 213.37 1105.63 6975.00 1300.34 213.37 1105.63 Warning "0__. Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk 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 Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Pass: Major Risk 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 'aker Hughes Incorporalt Anticollision Report , Company: ConocoPhiUips Alaska, Inc. Date: 7/8/2003 Time: 16:05:33 Page: 2 ' Field: Kuparuk River Unit orn~J I Reference Site: Pad 1£3 Co"ordinate(NE) Refererice: Wen: 102, TrueNorth , Reference Well: 102 Vertical (TV D) Reference: Wenhead(89') 89.0 I Reference Well path: 1B-102Version#1 .. Db: L.-- . Summary <~:...._--- Offset Wcllpath -----___.._~C> Reference Offset Ctr~Ctr. No-Go. m Allowable ,l Site Well Wellpath MD MD Distårice . Areå· Deviation ' Warning ft fl ft ft ft Pad 1C 111 1C-111 VO 7856.02 6875.00 2161.92 222.20 1957.39 Pass: Major Risk Pad 1 C 11 1C-11VO Out of range Pad 1C 113 1C-113 VO Plan: 1C-113 Out of range Pad 1C 117 1C-117VO 7400.00 4975.00 4282.26 159.31 4135.13 Pass: Major Risk Pad 1C 119 1C-119VO 7162.35 6575.00 2421.71 253.88 2178.84 Pass: Major Risk Pad 1C 121 1C-121 VO 6800.00 6000.00 3642.74 347.08 3313.38 Pass: Major Risk Pad 1 C 12 1C-12 VO Out of range Pad 1 C 123 1C-123 VO Out of range Pad 1 C 125 1C-125 VO 6700.00 6100.00 4920.80 357.22 4575.24 Pass: Major Risk Pad 1C 127 1C-127 VO Out of range Pad 1C 131 1C-131 VO Out of range Pad 1C 13 1C-13 VO Out of range Pad 1C 133 1C-133 VO Out of range Pad 1 C 135 1C-135 VO Out of range Pad 1 C 14 1C-14 V1 Out of range Pad 1 C 15 1C-15 V2 Plan: 1C-15L1 Out of range Pad 1C 16 1C-16 VO Out of range Pad 1C 170 1C-170 VO 13599.49 12225.00 3098.17 406.71 2691.60 Pass: Major Risk Pad 1C 170 1C-170PB1 V14 8698.55 7325.00 3402.74 225.06 3177.69 Pass: Major Risk Pad 1C 17 1C-17 VO 10958.35 8950.00 3141.70 439.64 2737.61 Pass: Major Risk Pad 1C 172 1C-172 V13 6949.27 10050.00 4610.642580.61 2081.21 Pass: Major Risk Pad 1 C 174 1C-174 V24 13783.85 12475.00 2113.70 631.38 1484.25 Pass: Major Risk - Pad 1 C 178 1C-178 V13 13615.68 13725.00 1128.73 468.91 660.98 Pass: Major Risk --' Pad 1C 178 1C-178L 1 V1 11299.23 11425.00 1130.46 297.22 833.15 Pass: Major Risk Pad 1C 178 1C-178PB1 V1 7725.67 7625.00 1103.13 158.42 951.22 Pass: Major Risk Pad 1C 18 1C-18 VO 7900.00 7725.00 4661.10 205.09 4494.73 Pass: Major Risk Pad 1C 184 1C-184 V10 Out of range Pad 1 C 190 1C-190 V8 Out of range Pad 1 C 19 1C-19 V6 Out of range Pad 1C 22 1C-22 V3 Out of range Pad 1C 23 1 C-23A V2 Out of range Pad 1C 23 1C-23PB1 V1 Out of range Pad 1C 24 1C-24 VO Out of range Pad 1 C 25 1 C-25 VO Out of range Pad 1C 26 1C-26 V2 Out of range Pad 1C 27 1 C-27 V1 Out of range Pad 1C SWPT1 WSSWPT1 V4 7300.00 3550.00 3534.45 145.08 3400.70 Pass: Major Risk Pad 1C WS-1 WS1 V1 10662.78 3725.00 1846.76 172.05 1674.63 Pass: Major Risk Pad 1C WS-24 WS-24 VO Out of range Pad lO(lncomplete) 101 10-101 VO Out of range Pad 1D(lncomplete) 10 10-10 VO Out of range Pad lO(lncomplete) 102 10-102 VO Out of range Pad lO(lncomplete) 102 1O-102L1 VO Out of range Pad lO(lncomplete) 102 1O-102PB1 VO Out of range Pad lO(lncomplete) 102 1O-102PB2 VO Out of range Pad lO(lncomplete) 102 1O-102PB3 VO Out of range - Pad lO(lncomplete) 103 10-103 V1 7411.19 13975.00 231.96 338.34 16.20 Pass: Major Risk Pad lO(lncomplete) 105 10-105 VO Out of range Pad lO(lncomplete) 105 1O-105A VO Out of range Pad lO(lncomplete) 106 10-106 VO Out of range Pad lO(lncomplete) 107 10-107 VO Out of range Pad lO(lncomplete) 108 10-108 VO Out of range Pad lO(lncomplete) 109 10-109 VO Out of range Pad lO(lncomplete) 110 110A VO Out of range Pad lO(lncomplete) 110 10-110 VO Out of range Pad lO(lncomplete) 111 10-111 VO Out of range Pad lO(lncomplete) 11 10-11 VO Out of range Pad lO(lncomplete) 112 10-112 VO Out of range Pad lO(lncomplete) 113 10-113 V1 Out of range Pad lO(lncomplete) 114 10-114 VO Out of range Pad lO(lncomplete) 115 10-115 VO Out of range Pad lO(lncomplete) 116 10-116 V1 Out of range Pad lO(lncomplete) 117 1O-117VO Out of range 'aker Hughes Incorporal. Anticollision Report "'. - -- - ,Company: ConocoPhillips Alaska, Inc. Date: 7/8/2003 Time: 16:05:33 'Page: 3 Field: Kuparuk'River Unit Reference Site: Pad 1 B Co-ordinate(NE) Reference: Wen: 102, True North Reference Well: 102 Vertical (TVD) Reference: Wenhead(89') 89.0 I Reference Wellpath:' 1B-102 Version#1 Db:, Oracle ._._~--- Summary 1<- - __ __~' Offset Wellpath --7'---> Reference Offset Ctr-Ctr' No-Go Allowable, I Site Well Well path MD MD Distance Area Deviation Warning i ft ft ft ft ft I _- f--- - ---- Pad lO(lncomplete) 118 10-118 VO Out of range Pad lO(lncomplete) 119 10-119 VO Out of range Pad lO(lncomplete) 1 10-01 VO Out of range Pad lO(lncomplete) 120 10-120 VO Out of range Pad lO(lncomplete) 121 10-121 VO Out of range Pad lO(lncomplete) 12 1D-12V1 Out of range Pad lO(lncomplete) 122 10-122 VO Out of range Pad lO(lncomplete) 123 10-123 VO Out of range Pad lO(lncomplete) 124 10-124 VO Out of range Pad lO(lncomplete) 125 10-125 V1 Out of range Pad lO(lncomplete) 125 1O-125A VO Out of range Pad lO(lncomplete) 14 10-14 V1 Out of range Pad lO(lncomplete) 2 1 C-02 VO Out of range Pad lO(lncomplete) 30 1 D-30 VO Out of range Pad lO(lncomplete) 3 10-03 VO Out of range Pad 1D(lncomplete) 32 10-32 VO Out of range Pad lO(lncomplete) 34 10-34 VO Out of range Pad lO(lncomplete) 36 10-36 VO Out of range Pad lO(lncomplete) 37 10-37 VO Out of range Pad lO(lncomplete) 38 1 D-38 VO Out of range Pad lO(lncomplete) 39 1 D-39 VO Out of range Pad lO(lncomplete) 40 1 D-40 VO Out of range Pad lO(lncomplete) 40 1O-40A VO Out of range Pad lO(lncomplete) 4 1 D-04 VO Out of range Pad lO(lncomplete) 42 10-42 VO Out of range Pad lO(lncomplete) 5 1 D-05 VO Out of range Pad lO(lncomplete) 6 10-06 VO Out of range Pad lO(lncomplete) 7 1 D-07 VO Out of range Pad lO(lncomplete) 8 10-08 VO Out of range Pad lO(lncomplete) 9 1 D-09 VO Out of range e e ConocoPhillips Alaska, Inc. Pad 1B 102 slot U02 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-102 VerU prop5466 Date printed Date created Last revised 8-Jul-2003 9-Jun-2003 8-Jul-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.246,w149 3E5 35250'294658.349/ Slot Grid coordinates are N 5969647.495,/ Slot local coordinates are 501.00 S 190.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North · e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1B,102 Your ref 1B-102 VerB Kuparuk River Unit, North Slope, Alaska Last revised : 8-Jul-2003 Measured Inclin Azirnuth True Vert R E C TAN GULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 0 R DIN A T E S 0.00 0.00 0.00 0.00 O.OON O.OOE 550248.35 5969647.50 n70 19 40.25 w149 35 32.96 100.00 0.00 55.00 100.00 O.OON o .OOE 550248.35 5969647.50 n70 19 40.25 w149 35 32.96 200.00 0.00 55.00 200.00 O.OON O.OOE 550248.35 5969647.50 n70 19 40.25 w149 35 32.96 300.00 0.00 55.00 300.00/ O.OON O.OOE 550248.35 5969647.50 n70 19 40.25 w149 35 32.96 400.00 3.00 55.00 399.95 1. 50N 2.14E 550250.48 5969649.01 n70 19 40.26 w149 35 32.90 500.00 6.00 55.00 499.63 6.00N 8.57E 550256.88 5969653.55 n70 19 40.30 w149 35 32.71 600.00 9.00 55.00 598.77 13.49N 19.26E 550267.52 5969661.11 n70 19 40.38 w149 35 32.40 633.33 10.00 55.00 631. 64 16.64N 23.77E 550272.00 5969664.30 n70 19 40.41 w149 35 32.27 700.00 11.80 59.65 697.11 23.41N 34.39E 550282.58 5969671.13 n70 19 40.48 w149 35 31. 96 800.00 14.59 64.46 794.46 34.01N 54.58E 550302.70 5969681. 87 n70 19 40.58 w149 35 31.37 814.35 15.00 65.00 808.33 35.57N 57.90E 550306.00 5969683.45 n70 19 40.60 w149 35 31.27 900.00 17.18 69.92 890.63 44.60N 79.83E 550327.87 5969692.63 n70 19 40.68 w149 35 30.63 1000.00 19.84 74.30 985.45 54.27N 110.04E 550358.01 5969702.49 n70 19 40.78 w149 35 29.75 1100.00 22.58 77.66 1078.67 62.96N 145.15E 550393.05 5969711. 43 n70 19 40.86 w149 35 28.73 1186.44 25.00 80.00 1157.76 69.68N 179.36E 550427.22 5969718.38 n70 19 40.93 w149 35 27.73 1200.00 25.45 80.70 1170.03 70.65N 185.05E 550432.90 5969719.38 n70 19 40.94 w149 35 27.56 1300.00 28.88 85.22 1258.99 76.14N 230.34E 550478.15 5969725.17 n70 19 40.99 w149 35 26.24 1400.00 32.43 88.84 1345.01 78.69N 281.24E 550529.03 5969728.07 n70 19 41. 02 w149 35 24.75 1470.84 35.00 91. 00 1403.93 78.72N 320.55E 550568.33 5969728.37 n70 19 41. 02 w149 35 23.61 1570.84 40.00 91. 00 1483.24 77.66N 381. 40E 550629.18 5969727.71 n70 19 41. 01 w149 35 21. 83 1670.84 45.00 91.00 1556.95 76.48N 448.93E 550696.71 5969726.99 n70 19 41.00 w149 35 19.86 1770.84 50.00 91. 00 1624.48 75.20N 522.62E 550770.40 5969726.20 n70 19 40.99 w149 35 17.71 1847.91 53.85 91.00 1672.00 74.14N 583.27E 550831. 05 5969725.55 n70 19 40.97 w149 35 15.94 1870.84 55.00 91. 00 1685.34 73.81N 601.92E 550849.70 5969725.35 n70 19 40.97 w149 35 15.39 1970.84 60.00 91. 00 1739.05 72.34N 686.22E 550934.00 5969724.44 n70 19 40.96 w149 35 12.93 2033.76 63.15 91. 00 1769.00 71.38N 741. 53E 550989.31 5969723.85 n70 19 40.95 w149 35 11.32 2070.84 65.00 91.00 1785.21 70.79N 774.88E 551022.66 5969723.49 n70 19 40.94 w149 35 10.34 2170.84 70.00 91. 00 1823.47 69.18N 867.22E 551115.00 5969722.50 n70 19 40.93 w149 35 07.65 2178.84 70.40 91.00 1826.18 69.05N 874.75E 551122.53 5969722.42 n70 19 40.92 w149 35 07.43 2500.00 70.40 91. 00 1933.91 63.77N 1177 .25E 551425.03 5969719.17 n70 19 40.87 w149 34 58.60 2896.74 70.40 91. 00 2067.00 57.25N 1550.95E 551798.73 5969715.16 n70 19 40.81 w149 34 47.69 3000.00 70.40 91. 00 2101. 64 55.55N 1648.21E 551895.99 5969714.12 n70 19 40.79 w149 34 44.85 3500.00 70.40 91. 00 2269.36 47.33N 2119.17E 552366.94 5969709.06 n70 19 40.71 w149 34 31.10 4000.00 70.40 91. 00 2437.09 39.11N 2590.12E 552837.90 5969704.01 n70 19 40.63 w149 34 17.35 4500.00 70.40 91.00 2604.81 30.89N 3061.08E 553308.85 5969698.96 n70 19 40.54 w149 34 03.60 4852.32 70.40 91. 00 2723.00 25.10N 3392.93E 553640.71 5969695.40 n70 19 40.49 w149 33 53.92 4900.00 70.35 89.48 2739.02 24.91N 3437.84E 553685.61 5969695.51 n70 19 40.48 w149 33 52.60 5000.00 70.28 86.30 2772.71 28.37N 3531.92E 553779.66 5969699.61 n70 19 40.52 w149 33 49.86 5100.00 70.27 83.11 2806.46 37.06N 3625.64E 553873.30 5969708.92 n70 19 40.60 w149 33 47.12 5200.00 70.32 79.92 2840.18 50.95N 3718.74E 553966.30 5969723.43 n70 19 40.74 w149 33 44.40 5281.19 70.40 77 .34 2867.48 66 . 02N 3793.70E 554041.15 5969739.01 n70 19 40.89 w149 33 42.22 5500.00 70.40 77 .34 2940.88 111.20N 3994.81E 554241.94 5969785.54 n70 19 41.33 w149 33 36.34 5798.44 70.40 77 .34 3041. 00 172 . 83N 4269.12E 554515.80 5969849.00 n70 19 41.93 w149 33 28.34 6000.00 70.40 77.34 3108.62 214.45N 4454.38E 554700.76 5969891.86 n70 19 42.34 w149 33 22.93 6272.40 70.40 77 .34 3200.00 270.69N 4704.76E 554950.72 5969949.78 n70 19 42.89 w149 33 15.62 6300.00 70.24 75.88 3209.30 276.71N 4730.04E 554975.96 5969955.97 n70 19 42.95 w149 33 14.88 6400.00 69.76 70.57 3243.52 303.82N 4819.97E 555065.70 5969983.67 n70 19 43.22 w149 33 12.25 6500.00 69.45 65.23 3278.39 339.06N 4906.78E 555152.26 5970019.50 n70 19 43.57 w149 33 09.72 6595.37 69.30 60.13 3312.00 380.01N 4986.05E 555231.25 5970060.98 n70 19 43.97 w149 33 07.40 6600.00 69.30 59.88 3313.63 382.17N 4989.80E 555234.98 5970063.17 n70 19 43.99 w149 33 07.29 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #102 and TVD from Est. RKB=89 , (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. Vertical section is from wellhead on azimuth 74.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e . ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1B,102 Your ref 1B-102 VerB Kuparuk River Unit, North Slope, Alaska Las t revised : 8-Jul-2003 Measured Inclin Az imu th True Vert R E C TANGULAR G RID COO R D S G E 0 G RAP HIe Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 0 R DIN ATE S 6700.00 69.31 54.52 3349.00 432.83N 5068.40E 555313 .23 5970114.34 n70 19 44.49 w149 33 05.00 6759.56 69.40 51. 33 3370.00 466.42N 5112.86E 555357.46 5970148.23 n70 19 44.82 w149 33 03.70 6800.00 69.49 49.17 3384.20 490.64N 5141.97E 555386.40 5970172.64 n70 19 45.06 w149 33 02.85 6900.00 69.84 43.83 3418.97 555.15N 5209.95E 555453.94 5970237.60 n70 19 45.69 w149 33 00.86 7000.00 70.34 38.53 3453.06 625.89N 5271.83E 555515.34 5970308.75 n70 19 46.38 w149 32 59.05 7100.00 71.00 33.26 3486.18 702.30N 5327.12E 555570.11 5970385.52 n70 19 47.14 w149 32 57.44 7200.00 71.80 28.04 3518.10 783.80N 5375.41E 555617.85 5970467.34 n70 19 47.94 w149 32 56.03 7300.00 72.75 22.88 3548.57 869.77N 5416.33E 555658.18 5970553.57 n70 19 48.78 w149 32 54.83 7400.00 73.82 17.76 3577 .35 959.56N 5449.56E 555690.81 5970643.57 n70 19 49.66 w149 32 53.86 7409.54 73.93 17 .28 3580.00 968.29N 5452.32E 555693.51 5970652.32 n70 19 49.75 w149 32 53.78 7500.00 75.02 12.71 3604.23 1052.46N 5474.86E 555715.47 5970736.63 n70 19 50.58 w149 32 53.12 7600.00 76.32 7.71 3628.99 1147.78N 5492.02E 555731.99 5970832.06 n70 19 51. 52 w149 32 52.61 7700.00 77.73 2.78 3651. 46 1244.79N 5500.91E 555740.23 5970929.11 n70 19 52.47 w149 32 52.35 7800.00 79.22 357.89 3671.45 1342.73N 5501. 47E 555740.13 5971027.05 n70 19 53.43 w149 32 52.33 7841. 57 79.86 355.88 3679.00 1383.55N 5499.25E 555737.64 5971067.84 n70 19 53.83 w149 32 52.40 7900.00 80.79 353.06 3688.82 1440.87N 5493.69E 555731.70 5971125.12 n70 19 54.40 w149 32 52.56 7901.11 80.80 353.00 3689.00 1441.96N 5493.56E 555731.56 5971126.21 n70 19 54.41 w149 32 52.56 7974.67 82.00 349.48 3700.00 1513 .83N 5482.48E 555720.00 5971198.00 n70 19 55.12 w149 32 52.89 8000.00 82.00 349.48 3703.53 1538.49N 5477.90E 555715.25 5971222.63 n70 19 55.36 w149 32 53.02 8197.41 82.00 349.48 3731.00 1730.70N 5442.20E 555678.26 5971414.57 n70 19 57.25 w149 32 54.06 8305.93 82.00 349.48 3746.10 1836.35N 5422.57E 555657.93 5971520.08 n70 19 58.29 w149 32 54.63 8325.93 82.50 349.48 3748.80 1855.84N 5418.95E 555654.18 5971539.54 n70 19 58.48 w149 32 54.73 8343.29 82.93 349.48 3751. 00 1872.76N 5415.81E 555650.92 5971556.44 n70 19 58.65 w149 32 54.83 8425.93 85.00 349.48 3759.69 1953.56N 5400.80E 555635.37 5971637.13 n70 19 59.44 w149 32 55.26 8525.93 87.50 349.48 3766.23 2051. 66N 5382.58E 555616.49 5971735.10 n70 20 00.41 w149 32 55.79 8625.93 90.00 349.48 3768.41 2149.95N 5364.32E 555597.58 5971833.25 n70 20 01.37 w149 32 56.32 8631. 53 90.14 349.48 3768.40 2155.46N 5363.30E 555596.52 5971838.75 n70 20 01. 43 w149 32 56.35 8725.93 92.50 349.48 3766.23 2248.24N 5346.06E 555578.66 5971931. 40 n70 20 02.34 w149 32 56.85 8792.73 94.17 349.48 3762.34 2313.80N 5333.89E 555566.04 5971996.87 n70 20 02.98 w149 32 57.21 8962.40 94.17 349.48 3750.00 2480.17N 5302.98E 555534.02 5972163.02 n70 20 04.62 w149 32 58.11 9000.00 94.17 349.48 3747.27 2517.04N 5296.13E 555526.93 5972199.84 n70 20 04.98 w149 32 58.31 9278.70 94.17 349.48 3727.00 2790.33N 5245.37E 555474.33 5972472.75 n70 20 07.67 w149 32 59.78 9500.00 94.17 349.48 3710.91 3007.33N 5205.06E 555432.57 5972689.46 n70 20 09.81 w149 33 00.96 9649.29 94.17 349.48 3700.05 3153.72N 5177 . 87E 555404.40 5972835.64 n70 20 11. 2 5 w149 33 01. 75 9716.09 92.50 349.48 3696.17 3219.28N 5165.69E 555391.78 5972901.12 n70 20 11. 89 w149 33 02.10 9808.49 90.19 349.48 3694.00 3310.10N 5148.82E 555374.30 5972991.81 n70 20 12.78 w149 33 02.59 9816.09 90.00 349.48 3693.99 3317.57N 5147.43E 555372.86 5972999.27 n70 20 12.86 w149 33 02.63 9916.09 87.50 349.48 3696.17 3415.86N 5129.17E 555353.95 5973097.42 n70 20 13.82 w149 33 03.17 9972.09 86.10 349.48 3699.29 3470.83N 5118.96E 555343.37 5973152.32 n70 20 14.37 w149 33 03.46 10000.00 86.10 349.48 3701.19 3498.21N 5113.88E 555338.10 5973179.66 n70 20 14.63 w149 33 03.61 10158.90 86.10 349.48 3712.00 3654.07N 5084.92E 555308.10 5973335.31 n70 20 16.17 w149 33 04.45 10408.90 86.10 349.48 3729.00 3899.30N 5039.37E 555260.91 5973580.20 n70 20 18.58 w149 33 05.78 10438.24 86.10 349.48 3731.00 3928.08N 5034.03E 555255.37 5973608.94 n70 20 18.86 w149 33 05.93 10500.00 86.10 349.48 3735.20 3988.66N 5022.77E 555243.71 5973669.44 n70 20 19.46 w149 33 06.26 10732.29 86.10 349.48 3751. 00 4216.51N 4980.45E 555199.86 5973896.98 n70 20 21. 70 w149 33 07.49 10825.79 86.10 349.48 3757.36 4308.23N 4963.41E 555182.21 5973988.57 n70 20 22.60 w149 33 07.99 10881. 79 87.50 349.48 3760.49 4363.20N 4953.20E 555171.63 5974043.47 n70 20 23.14 w149 33 08.29 10981.79 90.00 349.48 3762.67 4461.49N 4934.94E 555152.71 5974141. 62 n70 20 24.11 w149 33 08.82 10987.39 90.14 349.48 3762.66 4466.99N 4933.92E 555151.65 5974147.12 n70 20 24.16 w149 33 08.85 11081. 79 92.50 349.48 3760.49 4559.77N 4916.69E 555133.80 5974239.77 n70 20 25.08 w149 33 09.35 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #102 and TVD from Est. RKB=89 , (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. vertical section is from wellhead on azimuth 74.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 3 Pad 1B,102 Your ref 1B-102 VerU Kuparuk River Uni t, North Slope, Alaska Last revised : 8-Jul-2003 Measured Inclin Azimuth True Vert R E C TAN GULAR G RID COO R D S G E 0 G RAP HIe Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 0 R D I N ATE S 11154.19 94.31 349.48 3756.19 4630.83N 4903.49E 555120.12 5974310.73 n70 20 25.77 w149 33 09.73 11500.00 94.31 349.48 3730.20 4969.86N 4840.51E 555054.87 5974649.30 n70 20 29.11 w149 33 11. 57 11515.90 94.31 349.48 3729.00 4985.45N 4837.62E 555051.87 5974664.87 n70 20 29.26 w149 33 11. 65 11768.80 94.31 349.48 3710.00 5233.39N 4791.56E 555004.16 5974912.47 n70 20 31. 70 w149 33 12.99 12000.00 94.31 349.48 3692.62 5460.06N 4749.45E 554960.53 5975138.83 n70 20 33.93 w149 33 14.22 12000.16 94.31 349.48 3692.61 5460.22N 4749.43E 554960.50 5975138.99 n70 20 33.93 w149 33 14.22 12072.56 92.50 349.48 3688.31 5531.27N 4736.23E 554946.83 5975209.94 n70 20 34.63 w149 33 14.60 12164.96 90.19 349.48 3686.14 5622.09N 4719.36E 554929.35 5975300.63 n70 20 35.52 w149 33 15.10 12200.00 89.31 349.48 3686.29 5656.54N 4712.96E 554922.72 5975335.04 n70 20 35.86 w149 33 15.28 12287.32 87.13 349.48 3689.00 5742.34N 4697 .02E 554906.21 5975420.72 n70 20 36.71 w149 33 15.75 12300.00 86.81 349.48 3689.67 5754.79N 4694.71E 554903.81 5975433.15 n70 20 36.83 w149 33 15.81 12309.42 86.58 349.48 3690.21 5764.04N 4692.99E 554902.03 5975442.39 n70 20 36.92 w149 33 15.86 12500.00 86.58 349.48 3701. 59 5951.08N 4658.24E 554866.03 5975629.17 n70 20 38.76 w149 33 16.88 12724.80 86.58 349.48 3715.00 6171.70N 4617.25E 554823.56 5975849.49 n70 20 40.93 w149 33 18.07 12992.85 86.58 349.48 3731. 00 6434.77N 4568.38E 554772 .93 5976112.20 n70 20 43.52 w149 33 19.49 13000.00 86.58 349.48 3731.43 6441.79N 4567.07E 554771.57 5976119.21 n70 20 43.59 w149 33 19.53 13327.97 86.58 349.48 3751. 00 6763.66N 4507.28E 554709.62 5976440.65 n70 20 46.75 w149 33 21. 27 13328.00 86.58 349.48 3751. 00 6763.70N 4507.27E 554709.61 5976440.68 n70 20 46.75 w149 33 21. 27 13500.00 86.58 349.48 3761.27 6932.50N 4475.91E 554677 .12 5976609.25 n70 20 48.41 w149 33 22.19 13612.90 86.58 349.48 3768.00 7043.30N 4455.32E 554655.79 5976719.90 n70 20 49.50 w149 33 22.79 13897.65 86.58 349.48 3785.00 7322.76N 4403.41E 554602.00 5976998.98 n70 20 52.25 w149 33 24.30 13897.67 86.58 349.48 3785.00 7322.78N 4403.40E 554602.00 5976999.00 n70 20 52.25 w149 33 24.30 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #102 and TVD from Est. RKB=B9' (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. Vertical section is from wellhead on azimuth 74.56 degrees. . . Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad 1B,102 Kuparuk River Uni t, North Slope, Alaska PROPOSAL LISTING Page 4 Your ref 1B-102 Veril Last revised: 8-Jul-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - --- 300.00 300.00 O.OON o .OOE KOP 1186.44 1157.76 69.68N 179.36E B1d/Trn 41100 1470.84 1403.93 78.72N 320.55E Build 51100 1847.91 1672 .00 74.14N 583.27E Base Permafrost 2033.76 1769.00 71.38N 741. 53E Top T-3 2178.84 1826.18 69.05N 874.75E EOC 2896.74 2067.00 57.25N 1550.95E Top K-15 4852.32 2723.00 25.10N 3392.93E Turn 3/100 5281.19 2867.48 66.02N 3793.70E EOC 5798.44 3041. 00 172.83N 4269.12E Top Ungu C 6272.40 3200.00 270.69N 4704.76E Beg. Final B1d/Trn 6595.37 3312.00 380.01N 4986.05E Top Ugnu B 6759.56 3370.00 466.42N 5112.86E Top Ugnu A 7409.54 3580.00 968.29N 5452.32E K13 7841. 57 3679.00 1383.55N 5499.25E 9 5/8 CSG PT. 7901.11 3689.00 1441.96N 5493.56E Top West Sak D 7974.67 3700.00 1513 .83N 5482.48E WS W6 D-HEEL RVSD 01 JUL 03 8197.41 3731.00 1730.70N 5442.20E C-1 8343.29 3751. 00 1872.76N 5415.81E B-1 8962.40 3750.00 2480.17N 5302.98E B-2 Inverted (Base C) 9278.70 3727.00 2790.33N 5245.37E C-2 Inverted (Base D) 10158.90 3712.00 3654.07N 5084.92E C-3 10408.90 3729.00 3899.30N 5039.37E B-3 11515.90 3729.00 4985.45N 4837.62E B-4 Inverted(Base C) 11768.80 3710.00 5233.39N 4791.56E C-4 Inverted (Base D) 12724.80 3715.00 6171.70N 4617.25E Top D Across Fault 13328.00 3751. 00 6763.70N 4507.27E C-5 13612.90 3768.00 7043.30N 4455.32E B-5 13897.65 3785.00 7322.76N 4403.41E TD, 5 1/2 Liner Pt. 13897 .67 3785.00 7322.78N 4403.40E ws W6 B-TOE RVSD 01 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 O.OON O.OON O.OOE 7841.57 3679.00 O.OOE 13897.70 3785.00 1383.55N 7322.78N 5499.25E 9 5/8 CSG 4403.40E 5 1/2 LINER Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- ws W6 D-HEEL RVSD 01 WS W6 B-TOE RVSD 01 WS W6 D UP FAULT TGT ws W6 D DOWN FAULT T 555720.000,5971198.000,0.0000 554602.000,5976999.000, -2 . 000 554893.000,5975627.000, -2.000 554790.000,5976074.000,0.0000 3700.00 3785.00 3685.00 3721. 00 1513 .83N 7322.78N 5948.72N 6396.45N 5482.48E 4403.40E 4685.20E 4585.20E 10-Apr-2002 10-Apr-2002 9-Jun-2003 10-Jun-2003 . . ConocoPhillips Alaska, Inc. Pad IB 102 slot #102 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 1B-102 Ver#l prop5466 Date printed Date created Last revised 8-Jul-2003 9-Jun-2003 8-Jul-2003 Field is centred on n70 16 18.576,wI50 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.246,w149 35 32.965 Slot Grid coordinates are N 5969647.495, E 550248.349 Slot local coordinates are 501.00 S 190.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . ConocoPhillips Alaska, Inc. Pad 1B,102 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 633.33 700.00 800.00 6.00 9.00 10.00 11.80 14.59 814.35 900.00 1000.00 1100.00 1186.44 15.00 17.18 19.84 22.58 25.00 1200.00 1300.00 1400.00 1470.84 1570.84 25.45 28.88 32.43 35.00 40.00 1670.84 1770.84 1847.91 1870.84 1970.84 45.00 50.00 53.85 55.00 60.00 2033.76 2070.84 2170.84 2178.84 2500.00 63.15 65.00 70.00 70.40 70.40 2896.74 3000.00 3500.00 4000.00 4500.00 70.40 70.40 70.40 70.40 70.40 4852.32 4900.00 5000.00 5100.00 5200.00 70.40 70.35 70.28 70.27 70.32 5281.19 5500.00 5798.44 6000.00 6272.40 70.40 70.40 70.40 70.40 70.40 6300.00 6400.00 6500.00 6595.37 6600.00 70.24 69.76 69.45 69.30 69.30 0.00 0.00 0.00 0.00 3.00 0.00 55.00 55.00 55.00 55.00 0.00 100.00 200.00 300.00 399.95 499.63 598.77 631. 64 697.11 794.46 808.33 890.63 985.45 1078.67 1157.76 1170.03 1258.99 1345.01 1403.93 1483.24 1556.95 1624.48 1672.00 1685.34 1739.05 1769.00 1785.21 1823.47 1826.18 1933.91 2067.00 2101.64 2269.36 2437.09 2604.81 2723.00 2739.02 2772.71 2806.46 2840.18 2867.48 2940.88 3041. 00 3108.62 3200.00 3209.30 3243.52 3278.39 3312.00 3313.63 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.00 N 1.50 N 6.00 N 13.49 N 16.64 N 23.41 N 34.01 N 35.57 N 44.60 N 54.27 N 62.96 N 69.68 N 70.65 N 76.14 N 78.69 N 78.72N 77.66 N 76.48 N 75.20 N 74.14 N 73.81 N 72.34 N 71.38 N 70.79 N 69.18 N 69.05 N 63.77 N 57.25 N 55.55 N 47.33 N 39.11 N 30.89 N 25.10 N 24.91 N 28.37 N 37.06 N 50.95 N 66.02 N 111.20 N 172 . 83 N 214.45 N 270.69 N 276.71 N 303.82 N 339.06 N 380.01 N 382.17 N 0.00 E 0.00 E 0.00 E 0.00 E 2.14 E 8.57 E 19.26 E 23.77 E 34.39 E 54.58 E 57.90 E 79.83 E 110.04 E 145.15 E 179.36 E 185.05 E 230.34 E 281. 24 E 320.55 E 381. 40 E 448.93 E 522 . 62 E 583.27 E 601. 92 E 686.22 E 741. 53 E 774.88 E 867.22 E 874.75 E 1177.25 E 1550.95 E 1648.21 E 2119.17 E 2590.12 E 3061. 08 E 3392.93 E 3437.84 E 3531. 92 E 3625.64 E 3718.74E 3793.70 E 3994.81 E 4269.12 E 4454.38 E 4704.76 E 4730.04 E 4819.97 E 4906.78 E 4986.05 E 4989.80 E Dogleg Deg/100ft . PROPOSAL LISTING Page 1 Your ref 1B-102 Ver#l Last revised 8-Jul-2003 Vert Sect 0.00 0.00 0.00 0.00 3.00 0.00 0.00 0.00 0.00 KOP 2.47 55.00 55.00 55.00 59.65 64.46 65.00 69.92 74.30 77.66 80.00 80.70 85.22 88.84 91.00 91.00 91. 00 91. 00 91. 00 91. 00 91.00 91.00 91.00 91.00 91.00 91. 00 91. 00 91.00 91. 00 91. 00 91. 00 91.00 89.48 86.30 83.11 79.92 77.34 77.34 77.34 77.34 77 .34 75.88 70.57 65.23 60.13 59.88 3.00 3.00 3.00 3.00 3.00 9.86 22.16 27.34 39.38 61.67 3.00 3.00 3.00 3.00 3.00 65.28 88.82 120.52 156.67 191.43 Bld/Trn 4/100 4.00 4.00 4.00 4.00 5.00 197 .18 242.30 292.04 329.94 Build 5/100 388.31 5.00 5.00 5.00 5.00 5.00 453.09 523 .78 581.96 Base Permafrost 599.85 680.72 5.00 5.00 5.00 5.00 0.00 733.78 Top T-3 765.77 854.35 861.57 EOC 1151.76 0.00 0.00 0.00 0.00 0.00 1510.24 Top K-15 1603.54 2055.32 2507.10 2958.88 0.00 3.00 3.00 3.00 3.00 3277.22 Turn 3/100 3320.46 3412.07 3504.72 3598.16 3.00 0.00 0.00 0.00 0.00 3674.43 EOC 3880.31 4161.13 Top Ungu C 4350.79 4607.10 Beg. Final Bld/Trn 5.01 5.01 5.01 5.01 5.01 4633.07 4726.97 4820.03 4907.34 Top Ugnu B 4911. 53 All data is in feet unless otherwise stated. Coordinates from slot #102 and TVD from Est. RKB=89, (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. Vertical section is from wellhead on azimuth 74.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ · ConocoPhillips Alaska, Inc. Pad lB,102 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 6700.00 6759.56 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7409.54 7500.00 7600.00 7700.00 7800.00 7841. 57 7900.00 7901.11 7974.67 8000.00 8197.41 8305.93 8325.93 8343.29 8425.93 8525.93 8625.93 8631. 53 8725.93 8792.73 8962.40 9000.00 9278.70 9500.00 9649.29 9716.09 9808.49 9816.09 9916.09 9972.09 10000.00 10158.90 10408.90 10438.24 10500.00 10732.29 10825.79 10881. 79 10981.79 10987.39 11081.79 69.31 69.40 69.49 69.84 70.34 71.00 71.80 72.75 73.82 73.93 75.02 76.32 77.73 79.22 79.86 80.79 80.80 82.00 82.00 82.00 82.00 82.50 82.93 85.00 87.50 90.00 90.14 92.50 94.17 94.17 94.17 94.17 94.17 94.17 92.50 90.19 90.00 87.50 86.10 86.10 86.10 86.10 86.10 86.10 86.10 86.10 87.50 90.00 90.14 92.50 54.52 51. 33 49.17 43.83 38.53 33.26 28.04 22.88 17.76 17.28 12.71 7.71 2.78 357.89 355.88 353.06 353.00 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 349.48 3349.00 3370.00 3384.20 3418.97 3453.06 3486.18 3518.10 3548.57 3577.35 3580.00 3604.23 3628.99 3651. 46 3671.45 3679.00 3688.82 3689.00 3700.00 3703.53 3731. 00 3746.10 3748.80 3751. 00 3759.69 3766.23 3768.41 3768.40 3766.23 3762.34 3750.00 3747.27 3727.00 3710.91 3700.05 3696.17 3694.00 3693.99 3696.17 3699.29 3701.19 3712.00 3729.00 3731. 00 3735.20 3751.00 3757.36 3760.49 3762.67 3762.66 3760.49 R E C TAN G U L A R COO R DIN ATE S 432.83 N 466.42 N 490.64 N 555.15 N 625.89 N 702.30 N 783.80 N 869.77 N 959.56 N 968.29 N 1052.46 N 1147.78N 1244.79 N 1342.73 N 1383.55 N 1440.87 N 1441.96 N 1513.83 N 1538.49 N 1730.70 N 1836.35 N 1855.84 N 1872.76 N 1953.56 N 2051.66 N 2149.95 N 2155.46 N 2248.24 N 2313.80 N 2480.17 N 2517.04 N 2790.33 N 3007.33 N 3153.72 N 3219.28 N 3310.10 N 3317.57 N 3415.86 N 3470.83 N 3498.21 N 3654.07 N 3899.30 N 3928.08 N 3988.66 N 4216.51 N 4308.23 N 4363.20 N 4461.49 N 4466.99 N 4559.77 N 5068.40 E 5112.86 E 5141.97 E 5209.95 E 5271.83 E 5327.12 E 5375.41 E 5416.33 E 5449.56 E 5452.32 E 5474.86 E 5492.02 E 5500.91 E 5501.47 E 5499.25 E 5493.69 E 5493.56 E 5482.48 E 5477.90E 5442.20 E 5422.57 E 5418.95 E 5415.81 E 5400.80 E 5382.58 E 5364.32 E 5363.30 E 5346.06 E 5333.89 E 5302.98 E 5296.13 E 5245.37 E 5205.06 E 5177.87 E 5165.69 E 5148.82 E 5147.43 E 5129.17 E 5118.96 E 5113.88 E 5084.92 E 5039.37 E 5034.03 E 5022.77 E 4980.45 E 4963.41 E 4953.20 E 4934.94 E 4933.92 E 4916.69 E Dogleg Degll00ft e PROPOSAL LISTING Page 2 Your ref lB-l02 Ver#l Last revised 8-Jul-2003 Vert Sect 5.01 5.01 5.01 5.01 5.01 5000.77 5052.57 Top Ugnu A 5087.08 5169.78 5248.25 5.01 5.01 5.01 5.01 5.01 5321. 89 5390.13 5452.46 5508.39 5513.37 K13 5.01 5.01 5.01 5.01 5.01 5557.49 5599.41 5633.80 5660.41 5669.13 9 5/8 CSG PT. 5.01 5.01 5.01 0.00 0.00 5679.03 5679.19 Top West Sak D 5687.65 WS W6 D-HEEL RVSD 01 JUL 03 5689.79 5706.54 C-l 0.00 2.50 2.50 2.50 2.50 5715.74 5717.44 5718.91 B-1 5725.95 5734.49 2.50 2.50 2.50 2.50 0.00 5743.06 5743.54 5751. 62 5757.33 5771.82 B-2 Inverted(Base C) 0.00 0.00 0.00 0.00 2.50 5775.03 5798.84 C-2 Inverted(Base D) 5817.74 5830.49 5836.20 2.50 2.50 2.50 2.50 0.00 5844.11 5844.76 5853.33 5858.11 5860.50 0.00 0.00 0.00 0.00 0.00 5874.08 C-3 5895.44 B-3 5897.94 5903.22 5923.07 0.00 2.50 2.50 2.50 2.50 5931. 06 5935.85 5944.41 5944.89 5952.97 All data is in feet unless otherwise stated. Coordinates from slot #102 and TVD from Est. RKB=89, (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. Vertical section is from wellhead on azimuth 74.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 3 Pad lB,102 Your ref IB-I02 Ver#l Kuparuk River Unit,North Slope, Alaska Last revised 8-Jul-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/l00ft Sect 11154.19 94.31 349.48 3756.19 4630.83 N 4903.49 E 2.50 5959.16 11500.00 94.31 349.48 3730.20 4969.86 N 4840.51 E 0.00 5988.69 11515.90 94.31 349.48 3729.00 4985.45 N 4837.62 E 0.00 5990.05 B-4 Inverted (Base C) 11768.80 94.31 349.48 3710.00 5233.39 N 4791. 56 E 0.00 6011.65 C-4 Inverted (Base D) 12000.00 94.31 349.48 3692.62 5460.06 N 4749.45 E 0.00 6031. 39 12000.16 94.31 349.48 3692.61 5460.22 N 4749.43 E 0.00 6031. 40 12072.56 92.50 349.48 3688.31 5531. 27 N 4736.23 E 2.50 6037.59 12164.96 90.19 349.48 3686.14 5622.09 N 4719.36 E 2.50 6045.50 12200.00 89.31 349.48 3686.29 5656.54 N 4712.96 E 2.50 6048.51 12287.32 87.13 349.48 3689.00 5742.34 N 4697.02 E 2.50 6055.98 12300.00 86.81 349.48 3689.67 5754.79 N 4694.71 E 2.50 6057.06 12309.42 86.58 349.48 3690.21 5764.04 N 4692.99 E 2.50 6057.87 12500.00 86.58 349.48 3701.59 5951. 08 N 4658.24 E 0.00 6074.16 12724.80 86.58 349.48 3715.00 6171.70 N 4617.25 E 0.00 6093.37 Top D Across Fault 12992.85 86.58 349.48 3731. 00 6434.77 N 4568.38 E 0.00 6116.28 13000.00 86.58 349.48 3731. 43 6441.79 N 4567.07 E 0.00 6116.89 13327.97 86.58 349.48 3751.00 6763.66 N 4507.28 E 0.00 6144.92 13328.00 86.58 349.48 3751.00 6763.70 N 4507.27 E 0.00 6144.92 C-5 13500.00 86.58 349.48 3761. 27 6932.50 N 4475.91 E 0.00 6159.62 13612.90 86.58 349.48 3768.00 7043.30 N 4455.32 E 0.00 6169.27 B-5 13897.65 86.58 349.48 3785.00 7322.76 N 4403.41 E 0.00 6193.60 TD, 5 1/2 Liner Pt. 13897.67 86.58 349.48 3785.00 7322.78 N 4403.40 E 0.00 6193.60 WS W6 B-TOE RVSD 01 JUL 03 All data is in feet unless otherwise stated. Coordinates from slot #102 and TVD from Est. RKB=89, (89.00 Ft above mean sea level). Bottom hole distance is 8544.77 on azimuth 31.02 degrees from wellhead. Total Dogleg for wellpath is 207.74 degrees. Vertical section is from wellhead on azimuth 74.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . ConocoPhi11ips Alaska, Inc. Pad 1B,102 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref 1B-102 Ver#l Last revised: 8-Jul-2003 Comments in we11path -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 1186.44 1157.76 69.68 N 179.36 E B1d/Trn 4/100 1470.84 1403.93 78.72 N 320.55 E Build 5/100 1847.91 1672.00 74.14 N 583.27 E Base Permafrost 2033.76 1769.00 71.38 N 741. 53 E Top T-3 2178.84 1826.18 69.05 N 874.75 E EOC 2896.74 2067.00 57.25 N 1550.95 E Top K-15 4852.32 2723.00 25.10 N 3392.93 E Turn 3/100 5281.19 2867.48 66.02 N 3793.70 E EOC 5798.44 3041. 00 172 . 83 N 4269.12 E Top Ungu C 6272.40 3200.00 270.69 N 4704.76 E Beg. Final B1d/Trn 6595.37 3312.00 380.01 N 4986.05 E Top Ugnu B 6759.56 3370.00 466.42 N 5112.86 E Top Ugnu A 7409.54 3580.00 968.29 N 5452.32 E K13 7841. 57 3679.00 1383.55 N 5499.25 E 9 5/8 CSG PT. 7901.11 3689.00 1441. 96 N 5493.56 E Top West Sak D 7974.67 3700.00 1513 . 83 N 5482.48 E WS W6 D-HEEL RVSD 01 JUL 03 8197.41 3731. 00 1730.70 N 5442.20 E C-1 8343.29 3751. 00 1872.76 N 5415.81 E B-1 8962.40 3750.00 2480.17 N 5302.98 E B-2 Inverted (Base C) 9278.70 3727.00 2790.33 N 5245.37 E C-2 Inverted (Base D) 10158.90 3712.00 3654.07 N 5084.92 E C-3 10408.90 3729.00 3899.30 N 5039.37 E B-3 11515.90 3729.00 4985.45 N 4837.62 E B-4 Inverted(Base C) 11768.80 3710.00 5233.39 N 4791.56 E C-4 Inverted(Base D) 12724.80 3715.00 6171.70 N 4617.25 E Top D Across Fault 13328.00 3751. 00 6763.70 N 4507.27 E C-5 13612.90 3768.00 7043.30 N 4455.32 E B-5 13897.65 3785.00 7322.76 N 4403.41 E TD, 5 1/2 Liner Pt. 13897.67 3785.00 7322.78 N 4403.40 E WS W6 B-TOE RVSD 01 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 O.OON O.OON O.OOE 7841.57 3679.00 O.OOE 13897.70 3785.00 1383.55N 7322.78N 5499.25E 9 5/8 CSG 4403.40E 5 1/2 LINER Targets associated with this we11path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS W6 D-HEEL RVSD 01 WS W6 B-TOE RVSD 01 WS W6 D UP FAULT TGT WS W6 D DOWN FAULT T 555720.000,5971198.000,0.0000 554602.000,5976999.000,-2.000 554893.000,5975627.000,-2.000 554790.000,5976074.000,0.0000 3700.00 3785.00 3685.00 3721.00 1513 . 83N 7322.78N 5948.72N 6396.45N 5482.48E 4403.40E 4685.20E 4585.20E 10-Apr-2002 10-Apr-2002 9-Jun-2003 10-Jun-2003 Tubing Hanger, Vetco Grey Gen 1a, 41/2" 116" Conductor 4 1/2" Cameo "DB-6" Nipple with 3.81" I.D. 41/2" A-1 SSSV to be installed in Nipple (1) Gas Lift Mandrel, Camco "MMG" 4 1/2" X 1 1/2" with shearout sub 41/2", 12.6#, L-80, NSCT, tubing Couple OD I.D. Drift 5.2" 3.958 3.833 Burst Tensile 7700 208 121/4" Hole Size 9 5/8", 40#, Butt Mod, L-80, Casing Couple OD I.D. Drift 18.625 8.835 8.579 Collapse Burst Tensile 3090 5750 947 X-Over 7", 26# TKC Pin X Hydril 511 Box 41/2" Cameo "DB-6" No-Go Nipple with 3.75" I.D. wI 10' pups Not to be set at any angle greater then 70 degrees 4 1/2" Baker GBH-22 Casing Seal Assembly with 15 foot stroke, 4 1/2" IBT box up Baker 7" X 9 5/8", 40#, "ZXP" Liner Top Isolation _ ~ Isolation with 7" BTC pin down and TKC coupling ~ ______ 8100' M Baker 7", 26#, BTC Flex Lock Hanger 82 degrees with TKC couplings on top and bottom 8 1/2" Hole Size 51/2",15.5#, L-80, Hydril Liner, every fourth jt. slotted ¡Couple OD I.D. Drift Flush Jt. 4.86 4.825 Collapse Burst Tensile Torsion 4990 7000 259 15,700 . . 1 jt. 5 1/2" 15.5# Hydril 511 perforated pi e off 5 1/2" Silver Bullet Reamer Shoe 14,000' MD . . MEMO 1:0 ~ . 1.00 . ~ ~I: 2 .80000 ~ 27 PAY TO THE ORDER OF_ ~ Chase Manhattan Bank USA, N.Ä. ZOO White Clay Center Dr., Newark, DE 19711 ,«- . $ ¡OO.OD ç ~ D. '~"""f..".., ~ o() uóLCARS I..!J :;::::'.."" væoC¡;:4,~L 2 5 7111 . 0 5 2 S. K. ALLSUP·DRAKE CONOCOPHILLIPS 711 G STREET - AT01530 ANCHORAGE AK 99501 DATE 2fto3 62-14/311 1052 OIS ~ Date ~ ::::.. . ~ Public C~iSSi~ner rF~ Geologic Commissioner: 35 36 37 38 39 Date: P13rllJit cao be tS~il.!ed wlQ hydr.ogen s.ulfide measures D.ata.pres~mted on. Rote.ntial ove.r¡:¡res.surJ3 .zones. . .S13tsmic.analysjs. Qf sbaJlow gas.zooes S13abed .conditioo survey.(if off-¡¡hoœ) . . . . . . . . Contact nam.elpl1oneJor.weekly progre¡¡s.reRorts [e1<Rloratory .oolYl Engineering Commissioner: Date Y13S Y13$ NA NA .NA We!] proximityJss.ue¡¡ forAOR examjned.. Toe.OH section. of j Cement job for j B- j OZ is critical isolationj¡¡sue. D-.103 oot reJe.vant for AOR Appr SFD Geology Date 7/10/2003 Appr TEM Date 7/11/2003 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 J¡¡ Rre&eoce. of H2S gas. Rrob.able Mecba.niCÇII.cpoditioo o{ wens within AOR verified (For.s.erviCß WJ31) only] t9.(put p¡¡ig in.comments). .Ghoke.manifold CQllJpJie& w/APL R~-53 (May 84>- Work will oCCJJr withoutoperation.sbutdoWJ1 BOPEs.. d9 .they meJ3t reguJa.tion .B.OPE.press ra.tiog appropriate; .test JtdivJ3rter required, does it meet reguJa.tions .Dritliog fluid. RJQQfam schemattc.& equip JistadequatJ3 .CMT v9l adequ.ate. to circul~te .on.conductor. & surf. C$g .CMT v9ladequ.ateJo tie-inJong$triog to.surf ç¡¡g. . . . .CMTwill coyer.all kooWJ1J)ro.ductiye borizon.s. . . . . . C.asiog de.si.QO¡¡ ad.eQuate for C..T~ B .&. Rermafrœt Adequatetan.kage.orre$erye pit. . . . . . . . . . . . . Jta.re-drill~ bas.a. 1.0:403 for abandonment beJ30 approved .Adequate well bore &eparatjon J)ropo¡¡ed .ACMP finding .of Con$i$teocy .h~$ been j&sued. for. this pr91ect .C9odu$::tor strin-9.provided . . . . . .SurfaCß .CÇI&in9-protec.Ì$. alLknown. USQW¡¡ Y13$ NA Y13S .NA No. YJ3$ YJ3S NA YJ3S Y13$ YJ3S Y13S Y13S Y13S Y13S No. Y13S Mud ¡¡hould pœclude. H2.S. o.n Jbe. rig, .Rjg is equjpped with. s.en¡¡Or& andalarm&. Casingsl1Qe$.of 1C-H8.a.nd .1C-.104 -1/4 mile di¡¡tant.. CemenHob¡¡ OK. OH toe. of Steve. McKeeller. .GPA, 3-25-03: no H2S known jll WSak oil; rjg equipped. witl1.sensOlJ>lalarm&. scayengJ3r availabl EXJ)ected fJ3servoir pre$sure i$ .8.8.ppg EMW; wUlbe drilled with 9.0 ppg mud. D-j 03 close Jo 1.B-10.2s!1Qe. MAS!=' e&tim~ted at 1.2.60 P¡¡i. 3500 p$i.apprORri~te, PPCo likelyJo tesUo SOO.OJ)si. EXJ)ected BH~ 6.8 EMW. f>lanned MW for. WS 9..0.ppg. !='roximtty. analysis perf9rmed Surface ca$ing is.the. Rrod.uctjon.CÇI¡¡ing, Sloted tiller completion planned. Rig js.e.quippe.dwith stJ3elJ)it¡¡. Close aRproache$ jd.entifi13d.. Traveliog cytinder:. Riot im:Juded, No rese.rve.pjtJ)laooe.d. Wa$teJo an approved. annulu& or .dispQS~l weJI.. Engineering Appr FD 7/10/2003 Date PTD#: 2031220 Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 All wells witl1in.1l4.mile .are.ª.of review idJ30tified (For ¡¡ervjce well only) Pre-produ.c:ed iojector; duration of pre-productioo I13Ss. than. 3 montbs.(For.ser:.vtc:e well only) .Oper:.ator only affected party .OJ)erator bas. appropriate. b.ood S.ufficient ~creage.aYailable in.driIJiog unit JtdJ3viated. js. weJlbQre plaUoc]uded .LeasJ3 .number ~PRrORriate. u.ntque welL n.amJ3 .aod oumb.er Wen JOCÇIted in.a. d.efined J)ool Well Well .located pr9per .distaoce. from drilliog unitb9und~ry IQC¡¡ted pr9per .dtstaoce. from otbeJ wells Company Field & Pool P13rllJit fee attached CONOCOPHILLlPS ALASKA INC KUPARUK RIVER. WEST SAK OIL 490150 In~ClasslType Yes Y13S Y13S Y13S Yes Yes Y13S Yes Y13S Yes Yes Yes Yes Y13S YJ3S No. NA AIlaQuif13rs.e1<emRted. 40. CFR 1.47.102 (b)(3). We!] driJled from exjstiog KRU pad, in Jorce pJ3(11)it cao be tssued witbout co.nserva.tion order Pe(l1)it cao be tssued wjtbout ad.ministratille.approvaJ .Gao permit.be ¡¡PPJovJ3d before .15-day wajt Well Joc¡¡tJ3d within area alldstrat¡¡ .aut!1ortzed by.lojectioo Order'# (put 10# in.C9mmeots). (For Area Injeçtjo.n.Qrder No..2B KRU jD-j03, KRU1C-176.and KRU .1 C: 176L.1 Well Name: KUPARUK RIV U WSAK SER 11WINJ GeoArea ß90 Unit 6-j02 Program SER 1116Q On/Off Shore ~ Well bore seg Annular Disposal D e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, 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 infonnation. . . d 03--ld~ **** REEL HEADER **** LDWG 03/09/12 AWS 01 **** TAPE HEADER **** LDWG 03/09/12 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!! I!! 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-102 500292316700 conocoPhi11ips Alaska, Inc. BAKER HUGHES INTEQ 12-Sep-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 2 F. WENDLER D. GLADDEN MWD RUN 5 5 F. WENDLER M. THORNTON MWD RUN 3 3 G. SUTING D. GLADDEN MWD RUN MWD RUN 4 4 LABRECQUE D. GLADDEN MWD RUN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 llN 10E 88.90 60.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 14.750 13.375 521. 0 12.250 9.625 7796.0 STRING 8.500 14044.0 # 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 '~~~~\~ T.LIVERY FROM THE WELL SITE. . SURFACE LOCATION: LAT: N 70 DEG 19' 40.246" LONG: W149 DEG 35' 32.965" LOG MEASURED FROM D.F. AT 88.9 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a directional only service from 530 - 3022 feet MD (526 - 2132' TVD). (2) Baker Hughes INTEQ runs 2 and 3 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity and Gamma Ray services from 3022 - 7803 feet MD (2132 - 3689' TVD). (3) Baker Hughes INTEQ runs 4 and 5 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, and Modular Annular Pressure (MAP) services from 7803 - 14044 feet MD (3689 - 3850' TVD). REMARKS: (1) The interval from 530 to 3022 feet MD (526-2132' TVD) was drilled with a directional only service. (2) The interval from 6753 to 6770 feet MD (3361-3367' TVD) was logged up to 15.5 hours after being drilled due to a trip to change out the AutoTrak tool. (3) Depth of 9 5/8" Casing Shoe-Logger: 7796 feet MD (3687' TVD) Depth of 9 5/8" casing Shoe-Driller:7796 feet MD (3687 I TVD) (4) The interval from 9564 to 9594 feet MD (3735-3734' TVD) was logged up to 15.5 hours after being drilled due to a trip to change out the AutoTrak tool. (5) The interval from 14027 to 14044 feet MD (3848 - 3850' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 86 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 2985.0 STOP DEPTH 14044.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE TOOL COD. PBU MWD MWD MWD MWD $ RUN NO MERGE TOP 2985.0 6753.0 7787.0 9564.0 MERGE . 6753.0 7787.0 9564.0 14044.0 BIT 2 2R 3 3R # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1b102 5. xtf 150 ConocoPhillips Alaska, Inc. 1B-102 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPS RPS RPCHM 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: 28 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: 36 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 6 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 RPS MWD 68 1 OHMM 4 4 4 ROP MWD 68 1 FPHR 4 4 5 FET MWD 68 1 HR 4 4 6 MTEM MWD 68 1 DEGF 4 4 ------- 24 Total Data Records: 615 Tape File Start Depth Tape File End Depth Tape File Level Spacing 2985.000000 14044.000000 0.500000 Tape File Depth ~s feet **** FILE TRAILER **** Tape Subfile: 2 658 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: FILEOll.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. 2 .2500 START DEPTH 2185.0 STOP DEPTH 6753.0 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL # 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 02-AUG-03 MSB 18704 8.25 ATK MEMORY 6770.0 3005.0 6753.0 o 69.4 73.8 TOOL NUMBER ASU 29081 RNT 20035 RNT 20035 12.250 521. 0 LSND 9.00 .0 .0 200 .0 .000 .000 .000 .000 92.0 .0 .0 .0 MATRIX: . MATRIX DENSITY: HOLE CORRECTION (IN): .. .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 1 (MWD Run 2) . 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 Ibl02.xtf 150 ConocoPhillips Alaska, I IB-I02 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 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 = 0.250 * 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 . 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: 539 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2985.000000 6753.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 629 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. 2R .2500 START DEPTH 6753.0 STOP DEPTH 7787.0 # 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: 03-AUG-03 MSB 18704 8.25 ATK MEMORY 7803.0 6753.0 7787.0 o 70.0 74.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL TOOL NUMBER ASU 29811 RNT 2011 RNT 2011 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER's4IILING 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): # ..0 LSND 9.10 .0 .0 300 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (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) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1b102.xtf 150 ConocoPhillips Alaska, I 1B-102 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 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:4IIÞ ] Number of frames per record is: 28 One depth per frame (value= 0) Datum specification Block sub-type is: 4IIÞ 1 FRAME SPACE = 0.250 * 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: 148 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6753.000000 7787.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 238 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 7787.0 STOP DEPTH 9564.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 08-AUG-03 MSB 18704 6.75 ATK MEMORY 9594.0 TOP LOG INTE~ (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL # 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): # 710 95 4.0 o 75.1 95.7 TOOL NUMBER ASS 35833 RNT 1119 RNT 1119 8.500 7796.0 LSND 9.05 .0 .0 16000 .0 .000 .000 .000 .000 102.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 4). 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) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1b102.xtf 150 ConocoPhi1lips Alaska, I 1B-102 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAM GRAM . GRAM 0.0 . RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 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 = 0.250 * 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: 254 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7787.000000 9564.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 344 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! !!!!!! !!!!!!!!!!!!! FILE HEADER FILE NUMBER: RAW MWD LDWG File Version 1.000 Extract File: FILE014.HED 5 Curves and l~eader data for each bit run in s~ate files. BIT RUN NO: 3R DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9564.0 14044.0 $ # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL # 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): # REMARKS: 11-AUG-03 MSB 18704 6.75 ATK MEMORY 14044.0 9564.0 14044.0 o 84.6 94.8 TOOL NUMBER ASU 033 RNT 1060 RNT 1060 8.500 7796.0 LSND 9.10 .0 .0 17000 .0 .000 .000 .000 .000 112.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2R (MWD Run 5) . 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 TABtllÞCONS MNEM VALU . -------------------------------- WDFN LCC CN WN FN COUN STAT \ 1b102.xtf 150 conocoPhi11ips Alaska, I 1B-102 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 RaPS RaPS RaPS 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 = 0.250 * 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 RaPS 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: 641 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9564.000000 14044.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 731 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/09/12 . 01 **** REEL TRAILER **** LDWG 03/09/12 AWS 01 Tape Subfile: 7 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes