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Home My WebLink About184-1641. 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 6508'feet None feet true vertical 6320'feet 6179', 6211', 6233', 6328' feet Effective Depth measured 5837'feet 5708', 5825', 6087'feet true vertical 5706'feet 5589', 5695', 5934'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 4-1/2" L-80 J-55 5794' 6108' 5667' 5953' Packers and SSSV (type, measured and true vertical depth)5708' 5825' 6087' 5589' 5695' 5934' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: 325-115 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: SLB Blue Pack Packer: Baker FHL Retrievable Packer: Baker FB-1 Permanent SSSV: None Brian Glasheen brian.glasheen@conocophillips.com (907) 545-1144RWO Engineer 5962-5992', 6002-6044', 6175-6186', 6198-6226' 5820-5847', 5856-5895', 6014-6024', 6035-6060' 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) N/A Gas-Mcf MDSize 115' Shut-In measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-164 50-029-21188-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025645 Kuparuk River Field/ Kuparuk Oil Pool KRU 2X-11 Plugs Junk measured Length Production 6455' Casing 6302'6488' 3086' 115'Conductor Surface 16" 9-5/8" 80' 3121'3121' Burst Collapse Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:32 pm, Jun 17, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen , E=brian.glasheen@conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.17 12:53:47-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen JJL 6/30/25 DSR-6/18/25 Page 1/7 2X-11 Report Printed: 6/17/2025 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) 5/8/2025 00:00 5/8/2025 21:30 21.50 MIRU, MOVE MOB P Mobilize rig from 2N pad to 2X pad 0.0 0.0 5/8/2025 21:30 5/9/2025 00:00 2.50 MIRU, MOVE MOB P Arrive on 2X pad and Lay out matts MIRU 0.0 5/9/2025 00:00 5/9/2025 03:00 3.00 MIRU, MOVE MOB P Cont MIRU lay down mats and herculite hang tree in cellar 0.0 0.0 5/9/2025 03:00 5/9/2025 04:00 1.00 MIRU, MOVE RURD P Berm in cellar. R/U auxillary equipment. Take initial RKB's.. Complete acceptance checklist. Rig accepted @ 03:00 Hrs. 0.0 0.0 5/9/2025 04:00 5/9/2025 05:30 1.50 MIRU, MOVE RURD P Take on seawater to pits. R/U circ equipment in cellar. Take initial pressures T/IA/OA = 400/500/0.R/U hard line. 0.0 0.0 5/9/2025 05:30 5/9/2025 07:00 1.50 MIRU, WELCTL PRTS P Blow down hard line check unions, PT lines 3000 psi 0.0 0.0 5/9/2025 07:00 5/9/2025 09:30 2.50 MIRU, WELCTL DISP P Displace well 8.5# Seawater // 5 bpm @ 750 psi 0.0 0.0 5/9/2025 09:30 5/9/2025 10:00 0.50 MIRU, WELCTL OWFF P OWFF at wellhead // No flow 0.0 0.0 5/9/2025 10:00 5/9/2025 11:00 1.00 MIRU, WELCTL MPSP P Install BPV w/ test dart // Test 1000 psi 10 min good test 0.0 0.0 5/9/2025 11:00 5/9/2025 15:00 4.00 MIRU, WHDBOP NUND P Nipple down production tree, tree adapter stuck on hanger neck due to corrosion, work off with enerpack 0.0 0.0 5/9/2025 15:00 5/9/2025 19:00 4.00 MIRU, WHDBOP NUND P Nipple up BOPs 0.0 5/9/2025 19:00 5/10/2025 00:00 5.00 MIRU, WHDBOP NUND P Perform BWM, BOP Stack Set 7" ram in lower BOP and Upper Rams 2 7/8"X 5 1/2" 5/10/2025 00:00 5/10/2025 01:30 1.50 MIRU, WHDBOP NUND P Perform BWM on BOP Stack Set 7" ram in lower BOP and Upper Rams 2 7/8"X 5 1/2" VBR 0.0 0.0 5/10/2025 01:30 5/10/2025 10:00 8.50 MIRU, WHDBOP BOPE P Initial BOPE test. Test BOPE to 250/3000 PSI for 5 Min each, Tested UVBR's 2 7/8 X 5 1/2" w/ 3 1/2"" test joins. Test LPR w/ 7" test joint. Test annular w/ 3 1/2" & 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 & IBOP. Test 3 1/2" & 7"& 3 1/2" IF FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 2950 PSI, after closure = 1600 PSI, 200 PSI attained = 20 sec, full recovery attained = 124sec. UVBR's = 4 sec, 7" FRB = 5 sec. Annular = 19 sec. Simulated blinds = 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 1925 PSI. Witness waived by AOGCC rep .Adam Earl 0.0 0.0 5/10/2025 10:00 5/10/2025 10:15 0.25 MIRU, WHDBOP RURD P Rig down test equipment 0.0 0.0 5/10/2025 10:15 5/10/2025 10:45 0.50 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 5/10/2025 10:45 5/10/2025 11:15 0.50 COMPZN, RPCOMP RURD P Rig up floor for pulling 3.5" completion, set spooler on floor 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 2/7 2X-11 Report Printed: 6/17/2025 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) 5/10/2025 11:15 5/10/2025 12:15 1.00 COMPZN, RPCOMP THGR P Pick up BHA #1 3.5" tubing spear // Spear tubing set down 10K // BOLDS lose 4K block weight, appear that tubing in compression // Pick up on blocks tubing grew 1.5' // Pull hanger to floor 49K // lay down hanger rig up spooler to control line 1,900.0 1,870.0 5/10/2025 12:15 5/10/2025 15:30 3.25 COMPZN, RPCOMP PULL P Lay down 3.5" completion to pre-rig cut @ 1,900' 1,870.0 0.0 5/10/2025 15:30 5/10/2025 16:30 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor // Send out spooler // 0.0 0.0 5/10/2025 16:30 5/10/2025 18:30 2.00 COMPZN, RPCOMP BHAH P Bring in Baker tools // Process drill collars 0.0 0.0 5/10/2025 18:30 5/10/2025 19:00 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 2 Drift assembly 0.0 5/10/2025 19:00 5/10/2025 20:00 1.00 COMPZN, RPCOMP BHAH P RIH @ 53' No go POOH and L/D BHA #2 5/10/2025 20:00 5/10/2025 21:00 1.00 COMPZN, RPCOMP ELNE P Wait on AK E-line unit 5/10/2025 21:00 5/11/2025 00:00 3.00 COMPZN, RPCOMP ELNE P R/U AK E- line RIH w/ CCL /40 arm MSC T/ 1894' POOH 5/11/2025 00:00 5/11/2025 03:30 3.50 COMPZN, RPCOMP ELOG P Continue w/ CCL /40 arm MSC T/ 1894' POOH L/D MSC and P/U CBL / CCL RIH T/ 1,875' and log t/ Surf 0.0 0.0 5/11/2025 03:30 5/11/2025 04:30 1.00 COMPZN, RPCOMP ELOG P R/D AK E-Line 0.0 0.0 5/11/2025 04:30 5/11/2025 05:00 0.50 COMPZN, RPCOMP BHAH P R/U Baker IBP and M/U IBP 0.0 0.0 5/11/2025 05:00 5/11/2025 09:30 4.50 COMPZN, RPCOMP TRIP P P/U Singles 3 1/2" D.P. 0.0 1,890.0 5/11/2025 09:30 5/11/2025 11:00 1.50 COMPZN, RPCOMP MPSP P Kelly up on jt. Run plug T/ 1,892.47' ( 1,889' COE ), rig up BOP test pump, set IBP 500psi for 5 min pressure up 1100 psi shear off IBP set, PT 1100 psi 10 min good test 1,890.0 1,892.5 5/11/2025 11:00 5/11/2025 12:00 1.00 COMPZN, RPCOMP TRIP T Trip out of hole for grow and stretch 1,892.5 15.0 5/11/2025 12:00 5/11/2025 12:30 0.50 COMPZN, RPCOMP BHAH T IBP failed to set, still attached to drill string, lay down 15.0 0.0 5/11/2025 12:30 5/11/2025 13:00 0.50 COMPZN, RPCOMP SVRG T Service blocks and TD 0.0 0.0 5/11/2025 13:00 5/11/2025 13:30 0.50 COMPZN, RPCOMP BHAH T Pick up Baker G-plug BHA# 4 // G-plug 5.94" OD 0.0 22.0 5/11/2025 13:30 5/11/2025 15:00 1.50 COMPZN, RPCOMP TRIP T TIH w/ G-plug on stands drill pipe, Tag stump @ 1,895'' 22.0 1,895.0 5/11/2025 15:00 5/11/2025 15:30 0.50 COMPZN, RPCOMP MPSP T Set G-plug @ 1883.5 COE // Stack 20K pull 20k good set // trouble releasing from tool 1,895.0 1,875.0 5/11/2025 15:30 5/11/2025 19:00 3.50 COMPZN, RPCOMP PRTS T Test G-plug psi 1200 psi @ 1876' and Test casing T/ 1300 PSI 10 mins All good 1,875.0 1,875.0 5/11/2025 19:00 5/12/2025 00:00 5.00 COMPZN, RPCOMP OTHR P Pull up hole 130' above G-plug and Start Dumping Sand 15-20 mins a sack 1,875.0 1,875.0 5/12/2025 00:00 5/12/2025 02:30 2.50 COMPZN, RPCOMP OTHR P Continue dumping sand on top of G- Plug Tot of 23 sacks RIH Tag sand @ 1831' All Good 1,750.0 1,750.0 5/12/2025 02:30 5/12/2025 04:00 1.50 COMPZN, RPCOMP TRIP P POOH and L/D Baker Running tool 1,750.0 0.0 5/12/2025 04:00 5/12/2025 07:00 3.00 COMPZN, RPCOMP NUND P R/U and Clean up Floor and N/D BOP O.A. open and Dead Well 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 3/7 2X-11 Report Printed: 6/17/2025 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) 5/12/2025 07:00 5/12/2025 13:30 6.50 COMPZN, RPCOMP THGR P Grow and stretch casing, Total Grow= 30 in Let stand 30min(11AM), Pull 50K over ( 105K total hook load ) Total stretch= 14 in ( total for grow and stretch= 44 in ) 0.0 0.0 5/12/2025 13:30 5/12/2025 19:00 5.50 COMPZN, RPCOMP NUND P Cut casing off, install DSA adapter, Nipple up BOPs 0.0 0.0 5/12/2025 19:00 5/12/2025 19:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6 w/ drift w/tandem 6" string mills 0.0 0.0 5/12/2025 19:30 5/12/2025 21:30 2.00 COMPZN, RPCOMP TRIP P P/U 3 1/2" single RIH t/ top of sand @ 1813' All Good (No issue with drift run ) 0.0 1,813.0 5/12/2025 21:30 5/12/2025 22:30 1.00 COMPZN, RPCOMP TRIP P POOH L/D BHA #6 0.0 0.0 5/12/2025 22:30 5/13/2025 00:00 1.50 COMPZN, RPCOMP NUND P N/D BOP install new slips and pack off w/new tubing spool 0.0 0.0 5/13/2025 00:00 5/13/2025 06:00 6.00 COMPZN, RPCOMP WWSP P N/D BOP install new slips and pack off w/new tubing spool N/U BOP test packoffs 3000 psi good test 0.0 0.0 5/13/2025 06:00 5/13/2025 10:00 4.00 COMPZN, RPCOMP NUND P Nipple up BOPs // Get RKBs 0.0 0.0 5/13/2025 10:00 5/13/2025 10:30 0.50 COMPZN, RPCOMP PRTS P Set test plug flood stack, PRTS flange breaks on WH 250/3000 psi 0.0 0.0 5/13/2025 10:30 5/13/2025 11:00 0.50 COMPZN, RPCOMP MPSP P Pull test plug // Set Wear ring 0.0 0.0 5/13/2025 11:00 5/13/2025 11:30 0.50 COMPZN, RPCOMP PRTS P Test Casing to top of sand 1813' 2500 psi 10 min good test 0.0 0.0 5/13/2025 11:30 5/13/2025 12:30 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 7 G-plug retrieval tool 0.0 47.0 5/13/2025 12:30 5/13/2025 14:45 2.25 COMPZN, RPCOMP PUTB P RIH w/ BHA# 7 on singles drill pipe 47.0 1,800.0 5/13/2025 14:45 5/13/2025 15:45 1.00 COMPZN, RPCOMP WASH P Wash down from 1800' to top of plug @ 1865' // Pump 5 bpm @ 350 psi 1,800.0 1,865.0 5/13/2025 15:45 5/13/2025 16:15 0.50 COMPZN, RPCOMP MPSP P Equalize and pull G-plug 1,865.0 1,865.0 5/13/2025 16:15 5/13/2025 19:00 2.75 COMPZN, RPCOMP PRTS P Pressure test casing 2500 psi 30 min All Good Bleed pres to 0 Nordic representative discussed releasing of the rig to both crews 1,865.0 1,860.0 5/13/2025 19:00 5/13/2025 20:30 1.50 COMPZN, RPCOMP TRIP P POOH L/D RBP 1,860.0 5/13/2025 20:30 5/13/2025 21:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA # 8 W/ Baker Spear 1,892.0 5/13/2025 21:00 5/13/2025 23:00 2.00 COMPZN, RPCOMP TRIP P P/U the remainder of the 3 1/2" D.P. 27 jts and Cont RIH F/ Drk 5/13/2025 23:00 5/14/2025 00:00 1.00 COMPZN, RPCOMP FISH P Tag Stub @ 1892' and latch on Fish P/U T/ 110K Fish is Not Free Work String Several times UW 110 T/ 70 DW Just Straight Pull and Circ @ 2 1/2 bbls w/ 950 psi 1,892.0 5/14/2025 00:00 5/14/2025 00:45 0.75 COMPZN, RPCOMP CIRC P Continue CBU @ 2 1/2 bbls min w/ 950 psi and release spear 1,892.0 1,892.0 5/14/2025 00:45 5/14/2025 02:15 1.50 COMPZN, RPCOMP TRIP P POOH 1,892.0 150.0 5/14/2025 02:15 5/14/2025 03:30 1.25 COMPZN, RPCOMP BHAH P L/D BHA #8 M/U BHA #9 w/ Dress off Assy 150.0 150.0 5/14/2025 03:30 5/14/2025 04:30 1.00 COMPZN, RPCOMP TRIP P RIH T/ 1892' 150.0 1,892.0 5/14/2025 04:30 5/14/2025 05:00 0.50 COMPZN, RPCOMP MILL P Dress off tubing stub T/ 1900' // Pump 4 bpm @ 281 psi // Rot 40 rpm @ 850 free tq 1,892.0 1,900.0 5/14/2025 05:00 5/14/2025 05:30 0.50 COMPZN, RPCOMP TRIP P Trip out of hole for overshot 1,900.0 150.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 4/7 2X-11 Report Printed: 6/17/2025 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) 5/14/2025 05:30 5/14/2025 06:30 1.00 COMPZN, RPCOMP BHAH P Lay down BHA# 9 dress off BHA 150.0 0.0 5/14/2025 06:30 5/14/2025 07:00 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 10 Overshot 0.0 30.6 5/14/2025 07:00 5/14/2025 09:30 2.50 COMPZN, RPCOMP TRIP P TIH engage fish 1887' // Pick up 10K over string wt and space out for e-line 30.6 1,887.0 5/14/2025 09:30 5/14/2025 14:00 4.50 COMPZN, RPCOMP ELNE P RIg up E-line run in hole with string shot,unable to pass GLM 4 , pull out of hole install centralizer OAL 41' 1-11/16" OD // RIH could not pass GLM 4 temp detained on centralizer // work tools free, mobilize slick line pull out of hole rig down e-line. / 1,887.0 0.0 5/14/2025 14:00 5/14/2025 14:30 0.50 COMPZN, RPCOMP SVRG P Service rig, Blocks, top drive, draw works, and brake linkage. Service spinners. Lubricate catwork 0.0 0.0 5/14/2025 14:30 5/14/2025 16:00 1.50 COMPZN, RPCOMP BHAH P Continue to process 190 jts 3 1/2" EUE. Clean and clear rig floor 0.0 0.0 5/14/2025 16:00 5/15/2025 00:00 8.00 COMPZN, RPCOMP SLKL P R/U slick RIH # 1 2 1/4" Stem w/1 3/4" Sample catcher POOH L/D 3 cups sand Reverse circ @ 5 bbls min w/850 psi Clean up sand estimate couple gallons of sand. Run # 2 R/U RIH LIB T/5778' POOH L/D LIB (Marks on LIB pictures in report) Run # 3 R/U Bailer RIH T/ 5778 POOH 3 Cups Sand / Rerun #4 Bailer T/ 5778' POOH 0.0 0.0 5/15/2025 00:00 5/15/2025 03:30 3.50 COMPZN, RPCOMP SLKL P Continue t/ POOH W/ Slick line w/Bailer No sand P/U RIH W/ Magnet and Tag @ 5778' POOH L/D same w/ no Metal M/U Bailer RIH Tag @ 5778' POOH No Sand R/D Slick line called out AK-E-line R/U same RIH w/ CCL and log bottom GLM #5 Tag up @ 5790' @ the Old E-line Cut POOH R/D on the side of floor and latch up Top drive and Work pipe 20K t/40K No go R/U E-line RIH w/ Cutter 1,887.0 0.0 5/15/2025 03:30 5/15/2025 08:30 5.00 COMPZN, RPCOMP ELNE P R/U E-line make dummy cutter run to 57900. Run #2 R/U same RIH w/ CCL and log bottom GLM #5 Tag up @ 5790' @ the Old E-line Cut POOH 0.0 0.0 5/15/2025 08:30 5/15/2025 09:00 0.50 COMPZN, RPCOMP PULL P Latch up Top drive and Work pipe 20K t/40K No go 0.0 0.0 5/15/2025 09:00 5/15/2025 12:00 3.00 COMPZN, RPCOMP ELNE P Continue to make up RCT cutter, RIH to 5785'. Make cut. POOH. to surface. L/D RTC cutter. good indications on cutter tool 0.0 0.0 5/15/2025 12:00 5/15/2025 13:00 1.00 COMPZN, RPCOMP PULL P Rack back e-line. M/U elevators to DP. Work fish up to 105K. No go. Release spear from TOF @ 1900' 0.0 0.0 5/15/2025 13:00 5/15/2025 13:30 0.50 COMPZN, RPCOMP OWFF P OWFF. well static 1,900.0 1,900.0 5/15/2025 13:30 5/15/2025 14:00 0.50 COMPZN, RPCOMP TRIP P Trip out of well, Lay down spear and overshot. Recover Jet cutter piece from overshot. 1,900.0 0.0 5/15/2025 14:00 5/15/2025 15:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #10 Jars & bumper sub. Remove grapple from overshot. P/U BHA # 11 Overshot with no grapple 0.0 0.0 5/15/2025 15:00 5/15/2025 16:00 1.00 COMPZN, RPCOMP TRIP P RIH BHA #11 to TOF @ 1900' 0.0 1,900.0 5/15/2025 16:00 5/15/2025 20:30 4.50 COMPZN, RPCOMP OTHR P Well tech on location. Prep cutter to run 1,900.0 5/15/2025 20:30 5/15/2025 22:00 1.50 COMPZN, RPCOMP TRIP P RIH and Tag @ 5786' PU T/5752' And spot cutter Cut Above the GLM #5 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 5/7 2X-11 Report Printed: 6/17/2025 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) 5/15/2025 22:00 5/15/2025 22:30 0.50 COMPZN, RPCOMP OTHR P Cutter @ 5752' & Cut All indications look Good 10 mins Tot Time w/ cutter Release Tool 5/15/2025 22:30 5/16/2025 00:00 1.50 COMPZN, RPCOMP TRIP P POOH /Stand Back 3 1/2" D.P. 5/16/2025 00:00 5/16/2025 00:30 0.50 COMPZN, RPCOMP TRIP P POOH /Stand Back 3 1/2" D.P. 5/16/2025 00:30 5/16/2025 01:30 1.00 COMPZN, RPCOMP BHAH P L/D Baker Dry O.S. and M/U BHA # 12 w/ loaded O.S. 5/16/2025 01:30 5/16/2025 02:30 1.00 COMPZN, RPCOMP TRIP P RIH T/1400' 0.0 1,400.0 5/16/2025 02:30 5/16/2025 04:30 2.00 COMPZN, RPCOMP SLPC P Cut and Slip D.L. 1,400.0 1,400.0 5/16/2025 04:30 5/16/2025 05:00 0.50 COMPZN, RPCOMP TRIP P Cont RIH and Latch up @ 1900' 0.0 1,900.0 5/16/2025 05:00 5/16/2025 05:30 0.50 COMPZN, RPCOMP FISH P Engage fish, Set down 20K. Bleed jars open. Straight pull to 105K. Pulled free 95K.Pull joint. KU 1,900.0 1,870.0 5/16/2025 05:30 5/16/2025 07:30 2.00 COMPZN, RPCOMP CIRC P Circ BU 4 BPM @ 360 PSI 1,870.0 1,870.0 5/16/2025 07:30 5/16/2025 08:00 0.50 COMPZN, RPCOMP OWFF P OWFF, Well static 1,870.0 1,870.0 5/16/2025 08:00 5/16/2025 09:00 1.00 COMPZN, RPCOMP TRIP P Trip out of hole with fish 1,870.0 0.0 5/16/2025 09:00 5/16/2025 10:00 1.00 COMPZN, RPCOMP BHAH P BHA @ surface, Lay down collars, jars, and LBS 0.0 5,752.0 5/16/2025 10:00 5/16/2025 10:30 0.50 COMPZN, RPCOMP BHAH P Re Rig floor equipment for tubing ops 5,752.0 5/16/2025 10:30 5/16/2025 14:30 4.00 COMPZN, RPCOMP PULL P Pull 3 1/2" completion 1900 to 5752. Recover122 Jts, 1 SSSV, 4 GLM's, 1 pup, 1 16.81 cut joint 5,752.0 0.0 5/16/2025 14:30 5/16/2025 15:30 1.00 COMPZN, RPCOMP BHAH P Clean and clear floor. Rig up for DP ops 0.0 0.0 5/16/2025 15:30 5/16/2025 16:30 1.00 COMPZN, RPCOMP BHAH P P/U BHA #13. Full fishing package with overshot 0.0 216.8 5/16/2025 16:30 5/16/2025 18:30 2.00 COMPZN, RPCOMP TRIP P RIH t/5740' 216.8 5,740.0 5/16/2025 18:30 5/16/2025 19:15 0.75 COMPZN, RPCOMP FISH P UW 115K DN 103K circ @ 2 bbls 151 psi Wash down latch up fish @ 5743" P/U w/ 1K over P/U 10' Slack off tag fish 2' high 5,740.0 5,743.0 5/16/2025 19:15 5/16/2025 23:00 3.75 COMPZN, RPCOMP TRIP P POOH 5,743.0 0.0 5/16/2025 23:00 5/17/2025 00:00 1.00 COMPZN, RPCOMP BHAH P L/D Fish Top cut Jt 14.97' GLM 8.20' Bottom cut (9.80' Tot of fish L/D 32.97') Estimate top of fish @ 5776' 0.0 0.0 5/17/2025 00:00 5/17/2025 00:30 0.50 COMPZN, RPCOMP BHAH P Continue L/D Fish and M/U BHA # 14 0.0 0.0 5/17/2025 00:30 5/17/2025 03:30 3.00 COMPZN, RPCOMP TRIP P RIH 0.0 5,774.0 5/17/2025 03:30 5/17/2025 04:30 1.00 COMPZN, RPCOMP FISH P Circ down on Fish UW-120K DW-110K and swallow@ 5771' And Attempt to pull fish free No go 30K over straight pull No go Release O.S. 5,774.0 5,774.0 5/17/2025 04:30 5/17/2025 06:30 2.00 COMPZN, RPCOMP TRIP P POOH to P/U Mill Assy 5,774.0 213.0 5/17/2025 06:30 5/17/2025 07:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA # 14 213.0 0.0 5/17/2025 07:00 5/17/2025 07:30 0.50 COMPZN, RPCOMP BOPE P Perform Bi Weekly BOPE function test 0.0 0.0 5/17/2025 07:30 5/17/2025 09:30 2.00 COMPZN, RPCOMP BHAH P Clean and clear rig floor, Gather and inspect BHA #15. P/U Dress off mill 0.0 284.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 6/7 2X-11 Report Printed: 6/17/2025 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) 5/17/2025 09:30 5/17/2025 10:00 0.50 COMPZN, RPCOMP TRIP P Trip in hole BHA #15 284.0 5,768.0 5/17/2025 10:00 5/17/2025 10:30 0.50 COMPZN, RPCOMP MILL P KU, Obtain perameters, PUW=120K. SOW=110K, 5,768.0 5,768.0 5/17/2025 10:30 5/17/2025 12:00 1.50 COMPZN, RPCOMP MILL P 5768 Set down, PUH 10; RPM=20, FT=1.9K, 4 BPM @ 690 PSI. Get down to 5782. Unable to make headway. PUH 10'. Unable to get back to bottom. Hanging up @ 5777. Unable to get back to bottom. Immediate stall. Try multiple times. No go. 5,768.0 5,777.0 5/17/2025 12:00 5/17/2025 14:30 2.50 COMPZN, RPCOMP CIRC P PUH to 5776' Circ Hi Vis sweep 5 BPM @ 952 PSI. Small amount of fine sand and metal came back with sweep 5,777.0 5,776.0 5/17/2025 14:30 5/17/2025 15:00 0.50 COMPZN, RPCOMP OWFF P Flow check well Static, Blow down top drivr 5,776.0 5,776.0 5/17/2025 15:00 5/17/2025 16:30 1.50 COMPZN, RPCOMP TRIP P Trip out of well, PUW=120K 5,776.0 284.0 5/17/2025 16:30 5/17/2025 17:30 1.00 COMPZN, RPCOMP BHAH P Lay down intensifier, Rack back collars, Have fish in dress off shoe. Twisted up. Confer with town. Rerun dress off mills, Clean magnets and boot baskets 284.0 0.0 5/17/2025 17:30 5/17/2025 19:00 1.50 COMPZN, RPCOMP BHAH P M/U BHA #16 0.0 220.0 5/17/2025 19:00 5/17/2025 21:30 2.50 COMPZN, RPCOMP TRIP P RIH Tag TOP fish @ 5771' 220.0 5,771.0 5/17/2025 21:30 5/17/2025 23:00 1.50 COMPZN, RPCOMP MILL P Polish and mill 3 1/2' of stub W/ 77 sk @ 880 psi WOM 4k-8k Tq 3-4K T/ 5774.5 5,771.0 5,774.0 5/17/2025 23:00 5/18/2025 00:00 1.00 COMPZN, RPCOMP CIRC P Pump 30 BBls Sweep Around Clean up Hole. 5,770.0 5,770.0 5/18/2025 00:00 5/18/2025 00:30 0.50 COMPZN, RPCOMP CIRC P Continue CBU All Good 5,770.0 5,770.0 5/18/2025 00:30 5/18/2025 02:00 1.50 COMPZN, RPCOMP TRIP P POOH to 1500' F/Surf 5,770.0 1,500.0 5/18/2025 02:00 5/18/2025 03:00 1.00 COMPZN, RPCOMP SVRG P Trpuble shoot / service rig 1,500.0 1,500.0 5/18/2025 03:00 5/18/2025 05:00 2.00 COMPZN, RPCOMP RGRP T Hydraulics for the Rig floor unit the cooling fan is not working the Nordic electrician has been called out to troubleshoot the unit, Replace motor on cooling unit fan 1,500.0 1,500.0 5/18/2025 05:00 5/18/2025 06:00 1.00 COMPZN, RPCOMP TRIP P Continue out of well, BHA #16 1,500.0 220.0 5/18/2025 06:00 5/18/2025 07:30 1.50 COMPZN, RPCOMP BHAH P Lay down collars, Lay down BHA #16. Good wear pattern on inner mill and outer mill 220.0 0.0 5/18/2025 07:30 5/18/2025 08:00 0.50 COMPZN, RPCOMP BHAH P P/U Blank overshot, Shuffle out collars 0.0 3.0 5/18/2025 08:00 5/18/2025 09:30 1.50 COMPZN, RPCOMP TRIP P Trip in well BHA #17, PUW=115, SOW=105K, Set down on stump. Set slips 3.0 5,778.0 5/18/2025 09:30 5/18/2025 14:00 4.50 COMPZN, RPCOMP SLKL P MIRU HES Slickline 046. Run 2.25 drive down bailer with ball bottom. Operator felt top of stump was at 5782. Hard setdown @ 5802. Came back with mostly metal. Could not identify any rocks or sand. P/U pump bailer and flapper bottom. RIH, See 5782' area as top of stump. Set down 5802. Got to 5805' POOH. Same type of material from previous run. R/D slick line 5,778.0 5,778.0 5/18/2025 14:00 5/18/2025 19:30 5.50 COMPZN, RPCOMP PULD P POOH laying down DP/ L/D O.S R/D Foor 5,778.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Page 7/7 2X-11 Report Printed: 6/17/2025 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) 5/18/2025 19:30 5/18/2025 22:30 3.00 COMPZN, RPCOMP CLEN P R/U T/ Run 3 1/2" Completion String W/ power tongs Pulled W.R Bushing and Load Completion jewelry in pipe shed 0.0 0.0 5/18/2025 22:30 5/19/2025 00:00 1.50 COMPZN, RPCOMP PULD P M/U 3 1/2" # 9.3 eue Completion String W/ Baker PB Overshot and Continue P/U Completion String by Plan 0.0 313.0 5/19/2025 00:00 5/19/2025 05:30 5.50 COMPZN, RPCOMP PUTB P Continue P/U 3 1/2" #9.3 EUE Tubing Completion String by Plan 313.0 4,042.0 5/19/2025 05:30 5/19/2025 06:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 4,042.0 4,042.0 5/19/2025 06:00 5/19/2025 09:30 3.50 COMPZN, RPCOMP PUTB P Continue running 3 1/2" completion 4,042.0 5,783.0 5/19/2025 09:30 5/19/2025 11:30 2.00 COMPZN, RPCOMP PUTB P Set down @ 5783', See pins in overshot shear @ 14K down. Continue in to bottom @ 5786. Pick up 2". Mark pipe lay down joint. Calculate space out. P/U 25.67' space out pups 24.8. Land hanger 5,783.0 5,786.0 5/19/2025 11:30 5/19/2025 12:00 0.50 COMPZN, RPCOMP RURD P R/U to circulate CI brine down back side. Pick up completion 8' 5,786.0 5,786.0 5/19/2025 12:00 5/19/2025 13:00 1.00 COMPZN, RPCOMP DISP P Line up down back side. Close annular. Displace to CI brine. 3 BPM @ 157 PSI 5,786.0 5,786.0 5/19/2025 13:00 5/19/2025 14:30 1.50 COMPZN, RPCOMP PACK P Land hanger. Run in LDS's, Drop ball and rod. Rig up to PT tubing & IA 5,786.0 5,786.0 5/19/2025 14:30 5/19/2025 17:00 2.50 COMPZN, RPCOMP PRTS P Pressure up to 500 PSI down tubing. S/D pump. Check for leaks. Pressure up to 3800 PSI. S/I for PT. After 15 minutes developed drip @ head pin. Consult SLB folks. Bleed off tubing. Tighten head pin. Start retest 5,786.0 5,786.0 5/19/2025 17:00 5/19/2025 20:00 3.00 COMPZN, RPCOMP PRTS P Goot test. Bleed tubing down to 1500 PSI, Pressure up IA to 2500 PSI. Hold and chart 30 minutes Bleed down t/0 and S.O.V All good and Pump down IA 6 bbls all good Release All pres and R/D and Blow Bown all lines L/D landing jt Install BPV and Test same 1000 psi All good 5,786.0 0.0 5/19/2025 20:00 5/20/2025 00:00 4.00 COMPZN, RPCOMP NUND P C/O Bottom set Rams F/ 7" T/ 3 1/2 X 5 1/2" VBR ND BOP and N/U Cameron Tree 0.0 0.0 5/20/2025 00:00 5/20/2025 02:00 2.00 DEMOB, RURD NUND P Continue N/U Tree and Test same T/5000 PSI All good Pull Test Plug 0.0 0.0 5/20/2025 02:00 5/20/2025 05:30 3.50 DEMOB, RURD CIRC P R/U LRS pump 75 bbls diesel freeze protect IA and tubing and allow the well u-tub All Good 0.0 0.0 5/20/2025 05:30 5/20/2025 06:00 0.50 DEMOB, RURD RURD P R/D freeze protect U tube lines 0.0 0.0 5/20/2025 06:00 5/20/2025 10:00 4.00 DEMOB, RURD RURD P Rig down TT lines, Cuttings box, Clear pits. Warm up moving system. Secure tree and cellar, 0.0 0.0 5/20/2025 10:00 5/20/2025 12:00 2.00 DEMOB, RURD MOB P PJSM, Jack up rig, Pull off well. Release rig @ 12:00 Noon 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 5/20/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 5,837.0 2X-11 6/4/2025 condijw Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull catcher and HEX Plug 2X-11 6/15/2025 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: Lower completion left after 2025 RWO actually 3.5" tubing (just the blast rings are 4.5" OD) 6/7/2025 spilch NOTE: Surface CSG patch, welded 14" of 16"X.375" wall conductor pipe 4/14/2010 lmosbor NOTE: WAIVERED WELL: IA X OA COMMUNICATION 1/20/2003 WV5.3 Conversio n 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 35.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,121.2 3,120.8 36.00 J-55 BTC PRODUCTION 7 6.28 32.8 6,487.9 6,301.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.5 Set Depth … 5,794.0 String Max No… 3 1/2 Set Depth … 5,666.9 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.5 30.5 0.05 Hanger 7.100 Cameron CXS 7 1/16" x 3 1/2" Tubing Hanger. EUE top threads Camero n CXS 2.950 2,823.8 2,823.4 1.07 Mandrel – GAS LIFT 5.970 3.5" x 1.5" Camco MMG, GLM SLB MMG 2.920 4,864.4 4,827.4 25.19 Mandrel – GAS LIFT 5.970 3.5" x 1.5" Camco MMG, GLM SLB MMG 2.920 5,647.7 5,534.1 25.07 Mandrel – GAS LIFT 5.969 3.5" x 1.5" Camco MMG, GLM SLB MMG 2.920 5,707.9 5,588.6 24.78 Packer 6.276 SLB 3.5" x 7" BluePack MAX RH Packer, SLB BluePac k Max RH 2.885 5,765.2 5,640.7 24.50 Nipple - X 4.539 3.5" x 2.813", X-Nipple Halliburt on X Nipple 2.813 5,787.1 5,660.7 24.39 Overshot 6.000 3.5" x 7" Baker PB Overshot ( 6.48' swallow. 2' from fully located) Baker PB Oversho t 3.540 Top (ftKB) 5,790.0 Set Depth … 6,107.9 String Max No… 4 1/2 Set Depth … 5,952.5 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,811.3 5,682.7 24.31 PBR 5.000 BAKER PBR 3.000 5,825.0 5,695.2 24.28 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.937 5,863.7 5,730.5 24.22 PRODUCTION 5.960 CAMCO MMG-2 2.907 5,933.7 5,794.3 24.41 PRODUCTION 5.960 CAMCO MMG-2 2.907 5,941.9 5,801.8 24.47 BLAST RINGS 4.500 BLAST RINGS (4) 2.992 6,068.0 5,916.2 24.82 PRODUCTION 5.960 CAMCO MMG-2 2.907 6,086.3 5,932.9 24.80 SEAL ASSY 4.500 BAKER LOCATOR SEAL ASSEMBLY 3.000 6,087.2 5,933.7 24.80 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 6,090.5 5,936.7 24.79 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,101.6 5,946.7 24.77 NIPPLE 4.540 CAMCO D NIPPLE NO GO W/(1.81" Nipple Profile) 1.810 6,107.1 5,951.7 24.72 WLEG 4.570 BAKER WIRELINE RE-ENTRY GUIDE, ELMD TTL @ 6095 ON SWS SBHP 6/29/08 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,790.0 5,663.3 24.38 CUT 2" RTC 5/15/2025 2.992 5,918.0 5,780.0 24.29 PATCH 2.72" PARAGON II PACKER w/UPPER AND LOWER PACKER 9/22/2015 1.630 6,046.5 5,896.8 24.85 PATCH 2.71" HES OWENS OVER GLM #8 9/21/2015 2.250 6,101.6 5,946.8 24.77 NIPPLE REDUCER 2.75" NIPPLE REDUCER (1.81" D-NIPPLE PROFILE) 9/21/2015 1.810 6,179.0 6,017.2 24.06 FISH 1 1/2" OV Downhole; Note on Schematic, No WSR to verify (2/19/97) 2/19/1997 0.000 6,211.0 6,046.5 23.76 FISH 1" X 18' Prong & 1 1/2" CV Downhole (8/28/92) 8/28/1992 0.000 6,233.0 6,066.7 23.53 FISH 1 1/2" CV Downhole (11/25/92) 11/25/1992 0.000 6,328.0 6,154.1 22.77 FISH 1" DMY Found empty pocket; fell to rathole. (5/18/90) 5/18/1990 0.000 2X-11, 6/17/2025 10:51:15 AM Vertical schematic (actual) PRODUCTION; 32.8-6,487.9 FISH; 6,328.0 FISH; 6,233.0 FISH; 6,211.0 IPERF; 6,198.0-6,226.0 IPERF; 6,175.0-6,186.0 FISH; 6,179.0 NIPPLE REDUCER; 6,101.6 PACKER; 6,087.2 PRODUCTION; 6,068.0 PATCH; 6,046.5 IPERF; 6,012.0-6,044.0 IPERF; 6,002.0-6,012.0 IPERF; 5,982.0-5,992.0 IPERF; 5,962.0-5,982.0 PRODUCTION; 5,933.7 PATCH; 5,918.0 PRODUCTION; 5,863.7 PACKER; 5,825.0 CUT; 5,790.0 Nipple - X; 5,765.2 Packer; 5,707.9 Mandrel – GAS LIFT; 5,647.7 Mandrel – GAS LIFT; 4,864.4 SURFACE; 35.0-3,121.2 Mandrel – GAS LIFT; 2,823.8 CONDUCTOR; 35.0-115.0 Hanger; 30.5 KUP PROD KB-Grd (ft) 40.08 RR Date 11/29/198 4 Other Elev… 2X-11 ... TD Act Btm (ftKB) 6,508.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292118800 Wellbore Status PROD Max Angle & MD Incl (°) 26.45 MD (ftKB) 5,200.00 WELLNAME WELLBORE2X-11 Annotation Last WO: End DateH2S (ppm) 190 Date 10/29/2014 Comment SSSV: LOCKED OUT Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,823.8 2,823.4 1.07 1 GLV RK 1 1/2 1,268.0 5/25/2025 SLB MMG 0.250 4,864.4 4,827.4 25.19 2 GLV RK 1 1/2 1,242.0 5/25/2025 SLB MMG 0.250 5,647.7 5,534.1 25.07 3 OV RK 1 1/2 5/26/2025 SLB MMG 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,962.0 5,982.0 5,820.1 5,838.2 C-4, 2X-11 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase 5,982.0 5,992.0 5,838.2 5,847.3 C-4, 2X-11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,002.0 6,012.0 5,856.4 5,865.5 C-4, 2X-11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,012.0 6,044.0 5,865.5 5,894.5 C-4, C-3, C-1, 2X-11 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,175.0 6,186.0 6,013.6 6,023.6 A-4, 2X-11 1/19/1985 4.0 IPERF GO 4" Expnd Gun; 120 deg phase 6,198.0 6,226.0 6,034.6 6,060.2 A-3, 2X-11 1/19/1985 4.0 IPERF GO 4" Csg Gun; 120 deg phase 2X-11, 6/17/2025 10:51:15 AM Vertical schematic (actual) PRODUCTION; 32.8-6,487.9 FISH; 6,328.0 FISH; 6,233.0 FISH; 6,211.0 IPERF; 6,198.0-6,226.0 IPERF; 6,175.0-6,186.0 FISH; 6,179.0 NIPPLE REDUCER; 6,101.6 PACKER; 6,087.2 PRODUCTION; 6,068.0 PATCH; 6,046.5 IPERF; 6,012.0-6,044.0 IPERF; 6,002.0-6,012.0 IPERF; 5,982.0-5,992.0 IPERF; 5,962.0-5,982.0 PRODUCTION; 5,933.7 PATCH; 5,918.0 PRODUCTION; 5,863.7 PACKER; 5,825.0 CUT; 5,790.0 Nipple - X; 5,765.2 Packer; 5,707.9 Mandrel – GAS LIFT; 5,647.7 Mandrel – GAS LIFT; 4,864.4 SURFACE; 35.0-3,121.2 Mandrel – GAS LIFT; 2,823.8 CONDUCTOR; 35.0-115.0 Hanger; 30.5 KUP PROD 2X-11 ... WELLNAME WELLBORE2X-11 ORIGINATED TRANSMITTAL DATE: 5/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5450 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5450 2X-11 50029211880000 Tubing Cut Record 14-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 184-164 T40506 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:10:00 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 5/31/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5445 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5445 2X-11 50029211880000 Caliper Survey 10-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 184-164 T40506 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:09:32 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6508'2445 6179', 6211', 6233', 6328' Casing Collapse Conductor Surface Production 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: 907-545-1144 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 5850' 9-5/8" 80' Baker FHL Retrievable Packer Baker FB-1 Permanent Packer SSSV: Baker FVL 6320 5850'5718' 7" 16" KRU 2X-11 5962-5992' 6002-6044' 6175-6186' 6198-6226' 6455' 5820-5847' 5856-5895' 6014-6024' 6035-6060' 3086' 6488' Perforation Depth MD (ft): 115" 4/15/2025 3-1/2" 115" 3121' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025645 184-164 P.O. Box 100360, Anchorage, AK 99510 50-029-21188-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 5825'MD/5695'TVD 6087'MD/5934'TVD 1907'MD/1907'TVD 6108' Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3121' Burst Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6302' Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-115 By Gavin Gluyas at 1:02 pm, Feb 28, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.02.28 12:39:57-09'00' Foxit PDF Editor Version: 13.0.0 Brian Glasheen *AOGCC Witnessed BOP and Annular Test to 2500 psi. *Ensure BOP is equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collar. *Ensure packer is set at a depth within cemented portion of the production casing. JJL 3/12/25 10-404 SFD 4/4/2025 X DSR-2/28/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.07 15:21:54 -08'00'04/07/25 RBDMS JSB 040825 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 27, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2X-11 (PTD# 184-164). Well 2X-11 was drilled and completed in November 1984 as a gas lift Kuparuk producer . The well is showing signs of subsidence and is a candidate for preventative subsidence repair to address the subsidence risk. If you have any questions or require any further information, please contact me at +907-545-1144 The 3-1/2” upper completion will be pulled from a pre-rig cut above the SSSV. The 7” casing will be grown and stretched, and drift will be verified. If drift is not possible, the damaged 7” casing will be cut above SSSV, then new 7” casing will be run and the OA will be cemented to surface. Once the subsidence damage is repaired, a 3-1/2” completion including a new gas lift design, a non-sealing overshot and a stacked packer will be installed. 2X-11 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 184-164 x-11Page 1 of 2 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. Set Catcher on top of TTP at 5849’ 3. DMY all GLM and leave lowest GLM open for circulating 4. CMIT-TXIA 2500 psi 5. Tubing cut at ~1900’ RKB above the SSSV and at ~5790’ RKB above the upper packer. 6. CMIT-2500 psi/DDT-TxIA 7. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 2X-11. 2. Record shut-in pressures on the T & IA. If pressure is observed, bleed off 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 3-1/2” tubing down to the pre-rig cut. 6. Attempt to drift 7” casing with mill prior to attempting to pull tubing section with SSSV. a. If drift is achieved, RIH and engage tubing stub and pull remaining tubing down to pre- rig cut above packer. b. If drift is not achieved, proceed with 7” Casing Subsidence Repair section. 7” Casing Subsidence Repair 7. Set storm packer or plug above SSSV. PT to confirm plug is set. Dump sand on top of plug. 8. ND BOPE. ND old tubing head. Grow casing as needed. Pull casing in tension and land in slips. NU BOPE to casing head. a. Test break as soon as practical once test plug can be installed. b. Attempt to drift 7” casing with mill after grow/stretch. If enough drift is obtained to pull SSSV, RIH and engage tubing stub and pull remaining tubing down to lower pre-rig cut. 9. RU E-Line and log 7” casing from tubing stub to surface to verify free pipe. a. Estimated top of cement is 1800’ RKB. 10. RIH and cut 7” casing. Circulate out Arctic Pack diesel/slurry. 11. Pull 7” casing from cut. a. Make additional cuts in 7” casing to remove in sections if necessary. 12. RIH with mills to ensure drift for overshot casing patch and cementer. a. Bore out 9-5/8” casing to create drift as necessary. 13. MU and RIH with overshot casing patch, cementer, and new 7” casing. Engage overshot and PT casing to 2500 psi. 14. Cement 7” x 9-5/8” annulus to surface. 15. ND BOPE, set casing slips, cut excess 7” casing and install packoffs. NU new tubing head and BOPE. Test breaks to 250/2500 psi. 2X-11 Kuparuk Producer Tubing Swap with Subsidence Repair PTD: 184-164 x-11Page 2 of 2 16. RIH and mill up cement and plugs in cementer. Perform additional cleanout runs if necessary. 17. RIH and wash sand from top of RBP. Retrieve RBP. 18. Pull remaining completion. Install 3-1/2” Completion with Stacked Packer 19. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 20. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 21. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 22. Land tubing hanger, RILDS, PT packoffs and set packer. 23. Pressure test tubing to 2,500 PSI. 24. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 25. Shear out SOV with pressure differential. 26. Install BPV and test. ND BOPE. NU tree. 27. Pull BPV and freeze protect well. 28. RDMO. PPost-Rig Work 1. Run GLD. 2. Pull any plugs and ball/rod used for setting packer. General Well Information: Estimated Start Date: 04/15/2025 Current Operations: Shut-In, secured with plug below packer Well Type: Producer Wellhead Type: CIW Gen IV, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3065 psi / 6200 TVD measured on 10/1/023 MPSP: 2,445 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut above the SSSV, run a CBL, cut and pull 7” casing, replace casing with overshot casing patch and cement up OA. Install a new 3-1/2” completion and stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,205.0 2X-11 7/22/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added HEX plug w/ MOE @ 5853' RKB 2X-11 12/29/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Drift issues in upper 900'. Able to drift with 1.80 HEX plug DMY drift. 7/22/2023 rogerba NOTE: Surface CSG patch, welded 14" of 16"X.375" wall conductor pipe 4/14/2010 lmosbor NOTE: WAIVER TO USE RKP LATCHES (FLOW THRU) FOR STA. 7 & 8 10/25/2006 lmosbor NOTE: WAIVERED WELL: IA X OA COMMUNICATION 1/20/2003 WV5.3 Conversio n 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 35.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,121.2 3,120.8 36.00 J-55 BTC PRODUCTION 7 6.28 32.8 6,487.9 6,301.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.5 Set Depth … 6,107.9 Set Depth … 5,952.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.5 30.5 0.05 HANGER 8.000 CIW TUBING HANGER 3.500 1,907.3 1,907.2 1.13 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 3/21/88) 2.810 1,962.8 1,962.6 1.36 GAS LIFT 5.312 MMH FMHO 2.937 3,376.3 3,375.9 0.42 GAS LIFT 5.312 MMH FMHO 2.937 4,512.1 4,502.7 18.04 GAS LIFT 5.312 MMH FMHO 2.937 5,412.4 5,321.7 25.84 GAS LIFT 5.312 MMH FMHO 2.937 5,767.2 5,642.5 24.49 GAS LIFT 5.960 CAMCO MMG-2 2.907 5,811.3 5,682.7 24.31 PBR 5.000 BAKER PBR 3.000 5,825.0 5,695.2 24.28 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.937 5,863.7 5,730.5 24.22 PRODUCTION 5.960 CAMCO MMG-2 2.907 5,933.7 5,794.3 24.41 PRODUCTION 5.960 CAMCO MMG-2 2.907 5,941.9 5,801.8 24.47 BLAST RINGS 4.500 BLAST RINGS (4) 2.992 6,068.0 5,916.2 24.82 PRODUCTION 5.960 CAMCO MMG-2 2.907 6,086.3 5,932.9 24.80 SEAL ASSY 4.500 BAKER LOCATOR SEAL ASSEMBLY 3.000 6,087.2 5,933.7 24.80 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 6,090.5 5,936.7 24.79 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,101.6 5,946.7 24.77 NIPPLE 4.540 CAMCO D NIPPLE NO GO W/(1.81" Nipple Profile) 1.810 6,107.1 5,951.7 24.72 WLEG 4.570 BAKER WIRELINE RE-ENTRY GUIDE, ELMD TTL @ 6095 ON SWS SBHP 6/29/08 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,849.8 5,717.8 24.24 PLUG 180-350 INTERWELL HEX PLUG MID-ELEMENT SET AT 5853' RKB, MAX OD 1.80", OAL 5.83', OAW 34 LBS, FISHNECK 1.5" GS INTERW ELL 180-350 HEX 23440 5 12/29/2023 0.000 5,918.0 5,780.0 24.29 PATCH 2.72" PARAGON II PACKER w/UPPER AND LOWER PACKER 9/22/2015 1.630 6,046.5 5,896.8 24.85 PATCH 2.71" HES OWENS OVER GLM #8 9/21/2015 2.250 6,101.6 5,946.8 24.77 NIPPLE REDUCER 2.75" NIPPLE REDUCER (1.81" D-NIPPLE PROFILE) 9/21/2015 1.810 6,179.0 6,017.2 24.06 FISH 1 1/2" OV Downhole; Note on Schematic, No WSR to verify (2/19/97) 2/19/1997 0.000 6,211.0 6,046.5 23.76 FISH 1" X 18' Prong & 1 1/2" CV Downhole (8/28/92) 8/28/1992 0.000 6,233.0 6,066.7 23.53 FISH 1 1/2" CV Downhole (11/25/92) 11/25/1992 0.000 6,328.0 6,154.1 22.77 FISH 1" DMY Found empty pocket; fell to rathole. (5/18/90) 5/18/1990 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) 1,962.8 1,962.6 1.36 1 GAS LIFT GLV INT 1 1,301.0 11/17/2021 12:00 MMH FMHO 0.156 3,376.3 3,375.9 0.42 2 GAS LIFT GLV INT 1 1,336.0 11/17/2021 9:00 MMH FMHO 0.188 4,512.1 4,502.7 18.04 3 GAS LIFT GLV INT 1 1,328.0 11/16/2021 1:00 MMH FMHO 0.188 5,412.4 5,321.7 25.84 4 GAS LIFT GLV INT 1 1,319.0 11/17/2021 3:00 MMH FMHO 0.188 5,767.2 5,642.5 24.49 5 GAS LIFT OPEN 1 1/2 0.0 10/30/2023 12:00 CAMCO MMG-2 0.000 5,863.7 5,730.5 24.22 6 PROD DMY RK 1 1/2 0.0 1/10/2001 7:00 CAMCO 0.000 2X-11, 12/29/2023 3:27:52 PM Vertical schematic (actual) PRODUCTION; 32.8-6,487.9 FLOAT SHOE; 6,486.0-6,487.9 FLOAT COLLAR; 6,402.8- 6,404.5 FISH; 6,328.0 FISH; 6,233.0 FISH; 6,211.0 IPERF; 6,198.0-6,226.0 IPERF; 6,175.0-6,186.0 FISH; 6,179.0 WLEG; 6,107.1 NIPPLE REDUCER; 6,101.6 NIPPLE; 6,101.6 SBE; 6,090.5 PACKER; 6,087.2 SEAL ASSY; 6,086.3 PRODUCTION; 6,068.0 PATCH; 6,046.5 IPERF; 6,012.0-6,044.0 IPERF; 6,002.0-6,012.0 IPERF; 5,982.0-5,992.0 IPERF; 5,962.0-5,982.0 PRODUCTION; 5,933.7 PATCH; 5,918.0 PRODUCTION; 5,863.7 PLUG; 5,849.8 PACKER; 5,825.0 PBR; 5,811.3 GAS LIFT; 5,767.2 GAS LIFT; 5,412.4 GAS LIFT; 4,512.1 GAS LIFT; 3,376.3 SURFACE; 35.0-3,121.2 FLOAT SHOE; 3,119.4-3,121.2 FLOAT COLLAR; 3,038.8- 3,040.4 GAS LIFT; 1,962.8 SAFETY VLV; 1,907.3 CONDUCTOR; 35.0-115.0 HANGER; 35.0-39.4 HANGER; 30.5 KUP PROD KB-Grd (ft) 40.08 RR Date 11/29/198 4 Other Elev… 2X-11 ... TD Act Btm (ftKB) 6,508.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292118800 Wellbore Status PROD Max Angle & MD Incl (°) 26.45 MD (ftKB) 5,200.00 WELLNAME WELLBORE2X-11 Annotation Last WO: End DateH2S (ppm) 190 Date 10/29/2014 Comment SSSV: LOCKED OUT 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) 5,933.7 5,794.3 24.41 7 PROD DPHF CV RKP 1 1/2 0.0 11/26/2014 4:00 CAMCO 0.000 6,068.0 5,916.2 24.82 8 PROD DPHF CV RKP 1 1/2 0.0 11/26/2014 2:00 CAMCO 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,962.0 5,982.0 5,820.1 5,838.2 C-4, 2X-11 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase 5,982.0 5,992.0 5,838.2 5,847.3 C-4, 2X-11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,002.0 6,012.0 5,856.4 5,865.5 C-4, 2X-11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,012.0 6,044.0 5,865.5 5,894.5 C-4, C-3, C-1, 2X-11 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,175.0 6,186.0 6,013.6 6,023.6 A-4, 2X-11 1/19/1985 4.0 IPERF GO 4" Expnd Gun; 120 deg phase 6,198.0 6,226.0 6,034.6 6,060.2 A-3, 2X-11 1/19/1985 4.0 IPERF GO 4" Csg Gun; 120 deg phase 2X-11, 12/29/2023 3:27:53 PM Vertical schematic (actual) PRODUCTION; 32.8-6,487.9 FLOAT SHOE; 6,486.0-6,487.9 FLOAT COLLAR; 6,402.8- 6,404.5 FISH; 6,328.0 FISH; 6,233.0 FISH; 6,211.0 IPERF; 6,198.0-6,226.0 IPERF; 6,175.0-6,186.0 FISH; 6,179.0 WLEG; 6,107.1 NIPPLE REDUCER; 6,101.6 NIPPLE; 6,101.6 SBE; 6,090.5 PACKER; 6,087.2 SEAL ASSY; 6,086.3 PRODUCTION; 6,068.0 PATCH; 6,046.5 IPERF; 6,012.0-6,044.0 IPERF; 6,002.0-6,012.0 IPERF; 5,982.0-5,992.0 IPERF; 5,962.0-5,982.0 PRODUCTION; 5,933.7 PATCH; 5,918.0 PRODUCTION; 5,863.7 PLUG; 5,849.8 PACKER; 5,825.0 PBR; 5,811.3 GAS LIFT; 5,767.2 GAS LIFT; 5,412.4 GAS LIFT; 4,512.1 GAS LIFT; 3,376.3 SURFACE; 35.0-3,121.2 FLOAT SHOE; 3,119.4-3,121.2 FLOAT COLLAR; 3,038.8- 3,040.4 GAS LIFT; 1,962.8 SAFETY VLV; 1,907.3 CONDUCTOR; 35.0-115.0 HANGER; 35.0-39.4 HANGER; 30.5 KUP PROD 2X-11 ... WELLNAME WELLBORE2X-11 2X-11 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 115 115 16 1506 62.5 H-40 Surface 3121 3121 9-5/8 8.92 36 J-55 BTC BTC Production 6488 6302 7 6.28 26 J-55 BTC BTC Tubing 6108 5953 3-1/2 2.99 9.3 J-55 EUEM EUEM PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD Cut to Release Packer @ ~5690' RKB 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" non-sealing Overshot ~5790' RKB REMAINING COMPLETION LEFT IN HOLE 3-1/2" Tubing Stub @ XXXX' RKB Baker PBR @ 5811' RKB Baker FHL Packer @ 5825' RKB 3-1/2" Camco MMG-2 GLM @ 5863' RKB 3-1/2" Camco MMG-2 GLM @ 5933' RKB 3-1/2" 9.2# J-55 FL4S tbg with tungsten carbide blast rings @ 5942' - 6049' RKB 3-1/2" Camco MMG-2 GLM @ 6068' RKB Baker FB-1 Permanent Packer @ 6087' RKB (4" ID) Baker SBE @ 6091' RKB (4.0" ID) Camco D nipple @ 6102' RKB (2.75" ID) -Has 1.81" D-nipple reducer installed Surface Casing Production Casing Conductor A-sand perfs 6175' - 6226' RKB 2.72" Paragon II Packer w/upper & lower packer 5918' - 5941' RKB (1.63" C-Sand Perfs 5962' - 6044' RKB Blast Rings Tungsten Carbide Blast Joint Rings 5942' - 6049' RKB 2.71" HES Owens Over GLM 6046' - 6068' RKB (2.25" ID) HEX plug at 5853' RKB 7" tie-back cemented to surface est. TOC @ ~1800' TOC 1984 CBL 4600' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 184-164/ C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-22_22550_KRU_2X-11_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22550 KRU 2X-11 50-029-21188-00 Caliper Survey w/ Log Data 22-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 184-164 T37880 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.28 14:00:11 -08'00' STATE OF ALASKA AL/11A OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations fl Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well Other:Se atct''7 (0 Re-enter Susp Well �' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 184-164 3.Address: 6.API Number: Stratigraphic J Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21188-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645 KRU 2X-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6508 feet Plugs(measured) none true vertical 6320 feet Junk(measured) 6179,6211,6233,6328 Effective Depth measured 6403 feet Packer(measured) 5825,6087 true vertical 6223 feet (true vertical) 5695, 5934 J Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 3086 9.625 3121 3121 PRODUCTION 6455 7 6488 6302 ccosED NOV 2 42015 VED CT152015 Perforation depth: Measured depth: 5962-5992,6002-6044, 6175-6186,6198-6226 True Vertical Depth: 5820-5847,5856-5895, 6014-6024,6035-6060 Tubing(size,grade,MD,and TVD) 3.5,J-55,6108 MD, 5953 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 5825 MD and 5695 TVD PACKER-BAKER FB-1 PERMANENT PACKER @ 6087 MD and 5934 TVD SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 3/21/88)@ 1907 MD and 1907 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development 7 Service Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Tyson Wiese Cad 263-4250 Email Tyson.M.Wiese(c�conocophillips.com Printed Name Tyso WI e Title Wells Engineer 1 Signature Phone:263-4250 Date MN/1,015 VTL 10/ 1/15---- g/ AiO7g--0 RBDMS OCT 212015 Form 10-404 Revised 5/2015 Submit Original Only 46X-11 WELL SUMMARY • DATE SUMMARY 5/9/2015 Unable to perform FCO due to erratic weight swings down to 3,000' CTMD. Weight was over 38k at 3,000'. Jetting on walls of TBG had little effect. Conferred with Town Engineer and decision made to POOH and wait for the recent caliper log to be reviewed for a plan forward. Well freeze protected. 5/22/2015 PUMPED 20 BBLS OF DIESEL DOWN THE TUBING FOR FREEZE PROTECT. JOB COMPLETE. 5/28/2015 PERFORM STATIC BOTTOM HOLE PRESSURE SURVEY WITH 30 MINUTE STOP COUNT AT 6090' AND 15 MINUTE STOP COUNT AT 5980'. PERFORM PRE AND POST JOB SURFACE STATION STOPS. 5/29/2015 RAN GYRO DATA SURVEY FROM TUBING TAIL AT 6125' TO SURFACE. PERFORMED STATION SURVEYS @ 50', 2000', 4100', 4300', 4800' AND 6125'. READY FOR PATCH PORTION OF PROCEDURE. 6/16/2015 GAUGE TBG TO 2.8" TO 6101' RKB, DRIFT TBG w/2.78" WRP DRIFT TO 6101' RKB. JOB COMPLETE 7/1/2015 SET BAITED HOLEFINDER BELOW PACKER @ 5810' SLM; PULL OV (BAD CHECK) & REPLACE IN KIND; MITT (PASS); PULLED HOLEFINDER. JOB COMPLETE. 7/2/2015 (AC EVAL) SI TIFL (PASS). 7/3/2015 (SUB): MIT OA TO 1800 PSI. (PASSED). 8/21/2015 DRIFT TBG W/2.76" GAUGE RING TO D-NIP @ 6101' RKB; BRUSH PATCH INTERVAL &TAG TD @ 6182' SLM; DRIFT W/ 2.72"X 25' DMY PATCH DOWN TO 6100' RKB. READY FOR PATCH. IN PROGRESS. 9/21/2015 SET 2.75" x 1.81" NIPPLE REDUCER IN 2.75" D NIP @ 6101' RKB. SET 2.71 x 22' HES OWEN'S PERMANENT PATCH (2.25" ID) OVER PROD GLM#8 @ 6056' RKB. TOP ELEMENT @ 6046.5', LOWER ELEMENT @ 6068.1' RKB. *DEPTHS CORRELATED TO P-PROF 10-13-09. *JOB IN PROGRESS. 9/22/2015 RAN LDL (POOR-BOY) THRU OWEN'S PATCH OVER PROD GLM#8. NO SPINNER RESPONSE IDENTIFIED ABOVE OR BELOW PATCH. LRS PUMPED 110 BBL DIESEL, FLOW SEEN ENTERING PROD GLM#7. SET LOWER 3 1/2" PARAGON II PACKER (SN -CPP35015) (2.72" OD, 1.63" ID, 4' LIH) @ 5938' RKB. ATTEMPTED TO SET UPPER PARAGON II PATCH OVER PROD GLM#7, LOST TOOL COMMUNICATION. *JOB IN PROGRESS. 9/23/2015 SET UPPER 2.72" PARAGON II PATCH (SN CPP35025) (PIIP PACKER, SPACER, SNAP LATCH, 1.63" ID, 22' OAL) SECTION INTO LOWER PACKER @ 5938' RKB. UPPER PACKER SET @ 5918' RKB. PATCH COVERS LEAKING PROD GLM#7. SET TTS TEST TOOL INTO TOP OF PATCH @ 5918' RKB. MIT-T TO 2500# FAILED W/ 1 BPM+ LLR. RAN LDL TO TOP OF PATCH, LEAK SHOWN @ TEST TOOL/PATCH. JARRED DOWN ON TEST TOOL; MIT-T TO 2500# PASSED. PULLED TEST TOOL. *JOB IN PROGRESS. 9/24/2015 DEPLOYED 2.80" CATCHER. PULLED ST#5 RK-GLV, ST#4 INT-DGLV W/ EXT PKG, ST#3 INT-GLV(NO BTM LATCH), ST#2 INT-GLV. & ST#1 BK-GLV. SET ST#1 BK-GLV, & ST#2 INT-GLV. *JOB IN PROGRESS. 9/25/2015 SET ST#3 INT-GLV, ST#4 INT-GLV(HIGH SEAL PKG), & ST#5 RK-ON. PULLED CATCHER. TURN OVER TO DSO. JOB COMPLETE. KUP PROD 6,,,s, 2X-11 COnOCOPhilliPS 1" qp_,,, ,, „A Well Attributes Max Angle&MD TD 10%0 Alaska,irlc. .. v Wellbore API/UWI Field Name Wellbore Status nd(°) MD(ftKB) Act Btm(ftKB) N 500292118800 KUPARUK RIVER UNIT PROD 2645 5,200.00 6,508.0 cor,.44-ItMcc . •-• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 25-11,9/30/2015 7:5716 AM SSSV:LOCKED OUT _ 190 10/29/2014 Last WO: 40.08 11/29/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,182.0 8/21/2015 Rev Reason:GLV C/O,TAG,PATCH's pproven 9/30/2015 ift: HANGER 30 5 II Casing Strings OD(in)16 ID 01%062 Top(ftK3B6.0 Set Depth(ftK1131)6.0 Set Depth(T71.76...6 Wt/Le6n2(I66.GHlia4d0e TvvoLLTDhrEeDad , Casing Description i ,; tg _CONDUCTOR. 111 35.0 \ 3,121.2 3,120& 36.00 J-55 BTC , I csausRmFgADCeEscription OD 089)5/8 ID(in)8.621 Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Casing Description PRODUCTION OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread 7 6.276 32.8 \ 6,487.9 6,301& 26.00 J-55 BTC -'°' 350-1150-.' ! Tubing Strings Tubing Description !String Ma...I ID(in) 'Top(ftKB) ISot Depth(ft.. Depth(TVD)(...11Nt(Iblft) IGrade 'Top Connection TUBING 1 31)21 2.992 30.5 6,107.9 5,952.5 9.30 J-55 EUE 8RD SAFETY VLV;1907.3 rtp completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Corn (in) 305 30.5 0.05 HANGER CIW TUBING HANGER 3 500 GAS LIFT,1962.8 1,907.3 1,907.2 1.13 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 3)21/88) 2810 5,811.3 5,682.7 24.31 PBR BAKER PBR 3.000 5,825.0 5,695.2 24.28 PACKER BAKER FHL RETRIEVABLE PACKER 2.937 5,941.9 5,801.8 24 47 BLAST RINGS BLAST RINGS(4) 2.992 i I SURFACE;35.0-3,121.2-/'ti : ti) 6,086.3 5,932.9 24.80 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;33763 6,087.2 5,933.7 24.80 PACKER BAKER FB-1 PERMANENT PACKER 4.000 f 6,090.5 5,936.7 24.79 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT;4,512 1 - 6,101.6 5,946.7 24.77 NIPPLE CAMCO D NIPPLE NO GO W/(1.81"Nipple Profi(e) 1.810 6,107.1 5,951.7 24.72 WLEG BAKER WIRELINE RE-ENTRY GU(DE,ELMD TTL @ 3.015 6095 ON SWS SBHP 6/29/08 GAS LIFT;5,412 4 1r Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5Top(TVD) Top Inc!,767.2 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 5,918.0- 5,780.0 24.29 Patch 2.72"PARAGON II PACKER w)UPPER AND 9/22/2015 1.630 LOWER PACKER x PER;5,811.3 1 6,046.5 5,896.8 24.85 PATCH 2.71"HES OWENS OVER GLM#8 9/21/2015 2.250 PACKER;5,825 0 6,101.6 5,946.8 24.77 NIPPLE 2.75"NIPPLE REDUCER(1.81"0-NIPPLE 9/21/2015 1.810 REDUCER PROFILE) 6,179.0 6,017.2 24.06 FISH 1 1/2"OV Downhole;Note on Schematic,No WSR to 2/19/1997 0.000 PRODUCTION;5,863.7 . verify(2)19/97) 6,211.0 6,0465 23.76 FISH 1"X 18'Prong&1 1/2"CV Downhole(8)28/92) 8/28/1992 0.000 'I Patch;5,918.0 6,233.0 6,066.7 23.53 FISH 11)2"CV Downhole(11/25/92) 11/25/1992 0.000' PRODUCTION 55337 6,328.0 6,154.1 22.77 FISH 1"DMY Found empty pocket;(0910 rathole.(5/18/90) 5/18/1990 0.000 1 - Perforations&Slots - .at chaShnost IPERF;596205682 0--- - - a- Top(TVD) Btm(TVD) (shots/f IPERF,5,982 0-5,992.0---- / Top(ftKB) Btm(ftKB) , (ftKB) (ftKB) Zone Date t) Type Com - - 5,962.0 5,982.0 5,820.1 5,838.2 C-4,2X-11 1)19/1985 12.0 IPERF GO 5"Expnd Gun;120 - deg phase IPERF;6,002.0-6,012.0- : 5,982.0 5,992.0 5,838.2 5,847.3 C-4,2X-11 1/19/1985 24.0 IPERF GO 5"Expnd Gun;120 deg phase IPERF;6,012 0-6,044 0-- , 6,002.0 6,012.0 5,856.4 5,865.5 C-4,2X-11 1/19/1985 24.0 IPERF GO 5"Expnd Gun;120 deg phase PATCH;6,046.5 i a 6,012.0 6,044.0 5,865.5 5,894.5 2C,(-4-1,C.1-3,C-1, 1/19/1985 12.0 IPERF GO 5"Expnd Gun;120 deg phase 1 6,175.0 6,186.0. 6,013.6 6,023.6 A-4,2X-11 1/19/1985 4.0 IPERF G04"Expnd Gun;120 L _ PRODUCTION,6,068.0 deg phase . 6,198.0 6,226.0 6,034.6 6,060.2 A-3,2X-11 1/19/1985 4.0 IPERF GO 4"Csg Gun;120 deg '111 phase .., SEAL ASSY 6,066.3 Mandrel Inserts PACKER;6,087.2 St ati SBE;6,090.5 /a- on Top(TVD) Valve Latch Port Si. TRO Run 1111 N Top(ftKB) (ftKB) Make Model OD(in) Serf Type Type (in) (psi) Run Date Corn a 1 1,962.8 1,962.6 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,293.0 9/24/2015 1200 2 3,376.3 3,375.9 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,291.0 9/24/2015 900 NIPPLE,6,101.6 1 r; 3 4,512.1 4,502.7 MMH FMHO 1 GAS LIFT GLV BK 0.250 1,2860 9/25/2015 1:00 NIPPLE REDUCER 6,1016 ll 4 5,412.4 5,321.7 MMH "FMHO 1 GAS LIFT GLV BK 0.188 1,317.0 9/25/2015 High la VVLEG;6,107.1 IR Seal Pkg- 3:00 5 5,767.2 5,642.5 OTIS LBX 1 1/2 GAS LIFT OV RDO- 0.188 0.0 9/25/2015 1200. 20 FISH,6,179.0-111 6 5,863.7 5,730.5 OTIS LBX 1 1/2 PROD DMY RK 0 000 0.0 010/2001 Close IPERF,6,175.0-6,186.0---i- d; 7:00 7 5,933.7 5,794.3 OTIS 'LBX 11)2 PROD DPHF RKP 0.000 0.0 11/26/2014 4:00 CV 8 6,068.0 5,9162 OTIS LBX 11/2 PROD DPHF RKP 0.000 0.0 11/26/2014 2:00 CV IPERF;6,198 0-6226 0----• FISH,6,211 0 Notes:General&Safety End Date Annotation 4/20/2000 NOTE:Tubing pressure test(02600 psi-GOOD FISH,6,233.0-4 1/20/2003 NOTE:WAIVERED WELL:IA X OA COMMUNICATION 10/25/2006 NOTE:WAIVER TO USE RKP LATCHES(FLOW THRU)FOR STA.7&8 FISH,6328.0-f 4/14/2010 NOTE:Surface CSG patch,welded 14"of 16"X.375"wall conductor pipe 12/27/2010 NOTE:View Schematic w/Alaska Schematic9 0 PRODUCTION,32.8-6,487.9---• 25913 WELL LOG TRANSMITTAL DATA LOGGED Z 9/2015 K BENDER To: Alaska Oil and Gas Conservation Comm. June 3, 2015 Attn.: Makana Bender EIVW 333 West 7th Avenue, Suite 100 R �. Anchorage, Alaska 99501 U N 18 2U1', \OGC" r�_ RE: Static Bottom Hole Pressure and Temperature Survey: 2X-11 Run Date: 5/28/2015 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 2X-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21188-00 Static Bottom Hole Pressure and Temperature Survey (Field Print) 1 Color Log 50-029-21188-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating I�i L Attn: Fanny Sari C�� 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAILL4e..7/) 6.e.k.eat 2-51941 WELL LOG TRANSMITTAL DATA__�LL OGED rj 2i/2015 M BENDER To: Alaska Oil and Gas Conservation Comm. April 29, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 R EC E I V E D MAY 062015 AOGCC RE: Multi Finger Caliper(MFC) : 2X-11 Run Date: 4/24/2015 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 2X-11 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21188-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton SCANNED J U N 1 5 2015 Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: SignedMALL42114-#) 25355 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 3, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 Z�5/2015 Anchorage, Alaska 99501 K BEND€R ‘RECEIVED FF_F_s 0 5 2015 RE: Production Profile: 2X-11 Run Date: 1/2/2015 AOGCC 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 2X-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21188-00 Production Profile Log 1 Color Log 50-029-21188-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LE F 1'ER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 'SCANNED 9' 9 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAzizet~.4) 6e...eat Page 1 of 1 e James B DOA 99, ( DOA ) 104-164 - From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, December 20, 2010 10:53 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2X -11 (PTD 1841640) Report of failed TIFL Attachments: 2X -11 schematic.pdf Tom, Guy, Jim Kuparuk gas lifted producer 2X -11 (PTD 1841640) failed a diagnostic TIFL on 12/17/10. The TIO prior to the test was 200/1150/1150. A leaking GLV is susp ected. is ine wi rou es oo and repair if possible. Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 X e 1(? I 12/20/2010 KRU 2X -11 PTD 1841640 12/19/2010 TIO Pressures Plot RN -A N L ANNULUS PRESSURE TRENDS TRtLANYih T W T _ . _ .... . 5110. WELL NAME WLKRU2X -11 3000. 3 0 0 0200. 3000. 3000. 2700 3000. Ll!in 2400 - - ---- - -- . -. ._ 3000. • 2100. __ -. _. _ ... _ _ _... .._ _ -. - _ _ _. _..._. _.. - -- 1800 ------------ ------ -------------------- --- - 1500 ----------- ----- - --- - ._.. -.._. - _ .. _ _.._ _. .. ..... ... 1200 -... _ Y- i- - - -- 900 - 0. 600 --- _----- ,__.- 0. 0. __ 0. 300 ----- _ -__ --- ----- ._._._._ .- --_ --_-- - .- --- .__._-- .- -- --..._._- 0. ------------------------------------------------------------------------------ --- ------- ----- -- ---- --- - - - - -- -- ---------- ------- -- - --- ------- - -- - -' 0` PLOT START TIME MINOR TIME �N 20- SEP -10 12:40 MAJOR TIME WEEK +02160:00:00 1(-9-- DF.0 -10 11:90', PICK TINE: .- SC TAG NAME DESCRIPTION P - VALUE LATEST DRILLSITE WELL pw WL2X -11 -CHORE FLOW TUBING CHOKE ? ? ? ? ? ?? PREV WELL pw SCRATCH 75 FLOW TUBING PRESSURE ? ? ? ? ? ?? 2x ll- SCRATCH _75 FLOW TUBING TEMP 77777 NEXT WELL pw AI- P2X5002 -11 GL CASING PRESSURE 77?7 ? ?? ?7777?? ENTRY TYPE OPERATOR ? ? ? ?77? OPERATOR VERIFIED pw SCRATCH INNER ANNULUS PRES ?? ? ? ? ?? SYSTEM AUTO ENTRY SCRATCH OUTER ANNULUS PRES ? ? ? ? ? ?? ( BOTH • KUP 2X -11 Conoco fps � a t�iAt�r� '�` _,� � . r � 4. ntiax �n � MCA " Wellbore API /uwi Field Name Well Status Incl ( °) MD IRKS) Act Btm (ftKB) 500292118800 KUPARUK RIVER UNIT PROD 26.45 5,200.00 6,508.0 .......... - " "" - "- ' ----- - Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date - 2X 11 d!1 a a tt a3;3Aru1 SSSV: LOCKED OUT 165 1/13/2010 40.08 11/29/1984 Last Mad ,1 =ematm • A f Annotation Depth (ftKB) End Date Annotation ey End Date Last Tag: SLM 6,185.0. 10/10/2009 Rev Reason: Pull WRP /Catcher, GLV C/O Imo sbor 4 /1 912 0 10 �r =i \? String DD String ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR, - I Casing Description (in) (In) Top (ftKB) (ftKB) (ftKB) (lbs/ft) Grade String Top Thrd 115 CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H -40 SAFETY VLV, SURFACE 95/8 8.765 0.0 3,121.0 3,120.6 36.00 J -55 1s07 PRODUCTION 7 6.151 0.0 6,488.0 6,301.7 26.00 J -55 i lam_._-. v _ -ikr poi - - h�4 GAS LIFT String OD String ID Set Depth Set Depth (TVD) String Wt String 1,963 Tubing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibslft) Grade String Top Third TUBING 1 31/21 2.9921 0.0 6,108.0 5,952.6 9.30 J-55 8RD EUE SURFACE, Q1f$Tl Ht II Jewel ;'Ubi� et I3�1 3,121 Top Depth (TVD) Top Incl GAS LIFT, Top (ftKB) (ftKB) (°) Description Comment Run Date 10 (in) 3,376 1,907 1,906.9 1.13 SAFETY VLV Baker'FVL' (Locked Out 3/21/88) 11/5/1997 2.810 1,963 1,962.9 1.36 GAS LIFT MMH /FMHO/l/GLV/BK/.156/1251/ Comment: STA 1 12/11/2006 2.937 GAS LIFT, 3 ,376 3,375.6 0.40 GAS LIFT MMH /FMH0/l /GLV /BTM/.188/1306/ Comment: STA 2 11/3/2009 2.937 4,512 4,512 4,502.6 18.03 GAS LIFT MMH /FMHO /1 /0V /INT /.25// Comment:Running Neck STA3 4/1/2010 2.937 5,412 5,321.4 25.86 GAS LIFT MMH /FMHO /l /DMY /BTM/// Comment: Ext Pkg STA 4 11/2/2009 2.937 GAS LIFT, 5 ,767 5,642.4 24.49 GAS LIFT CAMCO /3.5 x 1.5/1.5 /DMY /RK/ // Comment: STA 5 12/10/2006 2.907 5,412 5,811 5,682.0 23.46 PBR Baker PBR 1/20/1985 3.000 5,825 5,694.9 23.57 PACKER Baker'FHL' PACKER 1/20/1985 3.000 GAS LIFT, 5 ,864 5,730.7 23.87 PRODUCTION CAMCO /3.5x1.5/1.5 /DMY /RK/ // Comment: CLOSED STA 6 1/10/2001 2.907 5,767 5,933 5,793.7 24.40 PRODUCTION CAMCO /3.5 x 1.5/1.5 /DPHFCV /RKP /// Comment: STA 7 11/3/2009 2.907 6,068 5,916.3 25.07 PRODUCTION CAMCO /3.5 x 1.5/1.5 /DPHFCV /RKP /// Comment: STA 8 11/3/2009 2.907 PBR, 5,811 6,087 5,933.5 24.90 PACKER Baker'FB -1' PACKER 1/20/1985 4.000 6,101 5,946.2 24.77 NIPPLE Camco'D' Nipple NO GO 1/20/1985 L 2.7 6,107 5,951.7 24.72 SOS Baker 1/20/1985 PACKER, 5,825 6,108 5,952.6 24.71 TTL 1/20/1985 r_ U 1 6,179 6,017.3 24.06 FISH 1 1/2" OV Downhole; Note on Schematic, No WSR to verify 2/19/1997 (2/19/97) PRODUCTION. - 6 ,211 6,046.3 23.03 FISH 1" X 18' Prong & 1 1/2" CV Downhole (8/28/92) 8/28/1992 5,864 6,2331 6,066.6 22.98 FISH 11 1/2" CV Downhole (11/25/92) 11/25/ 99 2 6,3281 6,154.1 22.77 FISH 1" DMY Found empty pocket; fell to rathole. (5/18/90) 5/18/1990 PRODUCTION, i= _ .. r• I a. 5,933 Shot Top (TVD) Btm (TVD) Dens IPERF, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 5,962 - 5,982 5,962 5,982 5,820.0 5,838.2 C -4, 2X -11 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase IPERF, 5 ,982 5,992 5,838.2 5,847.3 C-4, 2X -11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 5,982 -5,992 6,002 6,012 5,857.0 5,865.9 C-4, 2X -11 1/19/1985 24.0 IPERF GO 5" Expnd Gun; 120 deg phase 6,012 6,044 5,865.9 5,894.7 C -4, C -3, C -1, 1/19/1985 12.0 IPERF GO 5" Expnd Gun; 120 deg phase IPERF, .....: 2X -1 1 6,002 - 6,012 IPERF, 6 ,175 6,186 6,013.6 6,023.6 A -4, 2X -11 1/19/1985 4.0 IPERF GO 4" Expnd Gun; 120 deg phase 6,012 -6,044 - 6,198 6,226 6,034.6 6,060.1 A -3, 2X -11 1/19/1985 4.0 IPERF GO 4" Csg Gun; 120 deg phase OtF?8' ".S'ri3t�eTe11� $c J�A@ ¢ �s o .. End Date " Annotation PRODUCTION, - 4/20/2000 NOTE: Tubing pressure test to 2600 psi - GOOD 6,068 1/20/2003 NOTE: WAIVERED WELL: IA X OA COMMUNICATION i� : 10/25/2006 NOTE: WAIVER TO USE RKP LATCHES (FLOW THRU) FOR STA. 7 & 8 PACKER, 6,087 - - - rte _ 4/14/2010 NOTE: Surface CSG patch, welded 14" of 16 "X.375" wall conductor pipe - i NIPPLE, 6,101 SOS, 6,107 TTL, 6,108 _ FISH, 6,179 IPERF, 6,175 -6,186 IPERF, 6,198 -6,226 FISH, 6,211 i FISH, 6,233 FISH, 6,328 PRODUCTION, 6,488 TD, 6,508 ~c~co hillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: • ,.~ L~ .. APR 2 '~ 201Q ''aka (711 ~ Gas Cans, CammissiA, ~ncharaa Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIn. 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 cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Peny Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid 4/17/2010 2B. 2E. 2G. 2H. 2K. 2M. 2V. 2W. 2X_ 2Z & 3S PAD's Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 26-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF n/a n/a Na 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF Na 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF Na 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/15/2010 2M-28 50103201740000 1920700 SF n/a 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF Na 19" n/a 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF n/a 37" Na 4.2 4/16/2010 2X 11 50029211880000 1841640 SF Na 1T' Na 6 4/17!2010 2Z-11 50029213790000 1851380 SF Na 19" n/a 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF n/a 19" Na 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF Na 16" Na 2.1 4/15/2010 3S-09 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 ,~.,. ~. • • ConocoPhillps P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri122, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2X-11 PTD 184-164 Sundry 310-102 for a conductor extension. Please call Perry Klein or MJ Loveland at 659-7043 if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor Enclosures t • f ~` r .~ t+t +~ l'T' '1 Ada ,r ~~,. 'tea"` s ~ r. f, ,~. ~-~ 0` Nl: ,. r ^. . J - !. ~sC; ' r .. ~ .,,,... e °t .. C~Conac®~'h~ll~ps ~ ;,~~~ A ~ ~w .~ _ This ~~~~ p~ ~;~r~ ~;x~,~~~. µ. .p .4~~ ,ate +1 a~~ ~~nnot b~r~i~~ z ~~ ~. '~" w g.,; Y, T ~T j ~ ~ p 1 ~~ I yy ,_ ~C h aF ~~: 6 r ~2E~~I V ~® STATE OF ALASKA S ALASKA O~AND GAS CONSERVATION COMMISSION APR 2 '~ 2010 REPORT OF SUNDRY WELL OPERATIONS ~. operat'on Performe : ~ Repairwell ~ Plu Perforations Stimulate Other Extend conductor ti0fi15~ t+vu~ 9 ~ ~ ~' ~t~ ~ r ~~~~;asing [ Pull Tubing [ Perforate New Pbol ~? Waiver [ Time Extension Change Approved Program ~ Operat. Shutdow n C F~rforate ~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Ex lorato [ P rY C 184-164 3. Address: Stratigraphic [' Service ["" ~. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21188-00 7. Property Des nation: 8. Well Name and Nuq~ber: ADL 25645 ALK 2576 \ 2X-11 9. Field/Pool(s): \ Kuparuk River Field !Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 6508 feet Plugs (measured) None true vertical 6320 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5825, 6087 true vertical 0 feet (true vertucal) 5695, 5933 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 0 0 SURFACE 3121 9.625 3121 3120 0 0 PRODUCTION 6488 7 6488 6301 0 0 Conductor Extension 14" 16 Perforation depth: Measured depth: 5962-5992, 6002-6044, 6175-6186, 6198-6226 '' True Vertical Depth: 5820-5847, 5857-5894, 6013-6023, 6034-6060 Tubing (size, grade, MD, and TVD) 3.5, J-55, 6108 MD, 5953 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER'FHL' PACKER @ 5825 MD and 5695 TVD PACKER -BAKER 'FB-1' PACKER @ 6087 MD and 5933 TVD LOCKED OUT - BAKER'FVL' (LOCKED OUT 3/21/88) PULLED WRDP 12/4/97 @ 1907 MD and 1907 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 4. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~ Development ~; Service X .Well Status after work: Oil ~? Gas [~? WDSPL Daily Report of Well Operations GSTOR ["" WAG ~ GASINJ ~ WINJ ~ SPLUG ("' 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 310-102 contact MJ Loveland/Perry Klein Printed Name Perry Klein Title WI Project Supervisor Signature Phone: 659-7043 Date ..~~,ms arK 2 710 Y~zyw Form 10-404 Revised 7/2009 j~ Y' Z~ `O Submit Original Only • 2X-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/19/10 03/25/10 04/14/10 Drilled 4 pilot holes for cutting conductor windows. While cutting windows surface casing rose ~9", independent of conductor casing. Suspended job until further notice. T/I/O = . 180/1275/1250. Cut and removed upper and lower section of conductor. Cleaned small area on outer parts and marked pieces as "A" and "B".Stored in two separate boxes for shipping for further analysis, ready to install conductor extension. Welded 14" of 16" X .375 wall conductor pipe. Initial T/I/O = 140/1250/460. TOC @ 17". Final T/I/O = 140/1250/460. .: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2X-11 Run Date: 3/27/2010 April 2, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2X-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21188-00 [qty{;~~ !~ ~ S V ifi PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b " opt Date: '~~~ ~ ~~~'' ~ _ ~CvL~ --j ~-~l ~ d~ Signed: • u ~~GI~~ Ofd a~a~~{a l~.ow.E.~~~a~. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~ ~(~. P.O. Box 100360 ~' -[ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2X-11 ~r Sundry Number: 310-102 Dear Ms. Loveland: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~k ~~~~K ~ ~ ~ ~ Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2010. Encl. LJ ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri13, `2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: RECEIVED APR 0 6 2010 a0N8GasCan~011 Anchara7B Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we112X-11 PTD 184-164 for a conductor extension. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, , /T. ~~~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~~~,~~EL~ STATE OF ALASKA ~~~0 ~`~ ~ ALAS~IL AND GAS CONSERVATION COMMISS~ a~ ~ ~~~@ APR 0 6 2010°-PPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type ~& Plug for Redrill ~" Perforate New Pbol r Repair well r -- Change Approved Frogram [` r Plug Perforations r Rerforate r PUII Tubing r Time Extension r Operational Shutdow n r Re-enter Susp. Well r Stimulate r ARer casing Other: Extend conductor r . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebpment r' ` Exploratory r 184-164 ' 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21188-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ~ No r 2X-11 f 9. Property Designation: 10. Field/Pool(s): ADL 25645 ALK 2576 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (tt): Plugs (measured): Junk (measured): 6508 6320 Casing Length Slze MD ND Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 3121 9.625 3121' 3120' PRODUCTION 6488 7 6488' 6301' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5962-5992, 6002-6044, 6175-6186, 6198-6226 5820-5847, 5857-5894, 6013-6023, 6034-6060 3.5 J-55 6108 Packers and SSSV Type: Packers and SSSV MD (tt) and ND (ft) PACKER - BAKER'FHL' PACKER MD= 5825 ND= 5695 PACKER -BAKER 'FB-1' PACKER MD= 6087 ND= 5933 LOCKED OUT - BAKER'FVL' (LOCKED OUT 3/21/88) PULLED WRDP 12!4/97 MD= 1907 ND= 1907 12. Attachments: Description Sumrrrary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ~" Exploratory ~ Development .! ~ Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/15/2010 y Oil r Gas r WDSPL r Plugged r 16. Verbal Approval: Date: WINJ ~ GINJ ~ WAG ~ Abandoned r Commission Representative: GSTOR [~ SPLUG [- 17. I hereby certify that the foregoing is true and correct tot est of my knowledge. Contact: MJ Loveland/Pent' Klein Printed Name MJ Loveland ~ Title: ~. WI Project Supervisor Signature ~~ ,~ Phone: 659-7043 Date ~ ~ i Sundry Number: ~ O .~ ~ ~a, Conditions of approval: Notify Commission so that a representative may witness Location Clearance r Plug Integrity (- BOP Test [ Mechanical IntegrityTest r L Other. ~ DO G.u..~ /'G ~ u-K- w.; '~. ~ ~ s Subsequent Form Required: / V . / ~~ APPROVED BY ~ ~ Approved by: COMMISSIONER THE COMMISSION / Date: •~ 1~4~1 rr Form 10-403 1~82~ ~y~ ~ ~ y~ L ~~`~ Submit in puplicate ORIGINAL ~~©./~~~~ ConocoPhillips Alaska, Inc. Kuparuk Well 2X-11 (PTD 184-164) SUNDRY NOTICE 10-403 APPROVAL REQUEST Apri13, 2010 This application for Sundry approval for Kuparuk we112X-11 is to extend the conductor to original height so as to prevent water entrance and corrosion to the surface casing. This is a gas lifted producer that was completed in 1984 and is currently on line. Stored energy from subsidence or thermal expansion caused the conductor to separate from the tanko head and move the tree up or the conductor down about nine inches. With approval, the conductor extension will require the following general steps: 1. Square up the remaining conductor stub removing additional conductor if needed 2. Examine SC below the conductor stub for any corrosion damage. 3. Extend the conductor to the starting head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnlcen 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2X-11 Run Date: 10% 13/2009 r~ ~.J November 9, 2009 The technical data listed below is being submitted herewith. Please address any. problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2X-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21188-00 Production Profile Log ~~~~ ~~1~ ~ =~ ~~ ~ 1 Color Log 50-029-21188-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-327 Fax: 907-273-3535 rafael.barreto@hallibLU-ton.com ~~~ -~~~( ~~~~~ ~1 ~' YI ~ '/I ~ `~ i Date: - Signed: j k ;~~ ~ Regg, James B (DOA) • Page 1 of 2 ~f~ I ~i 4 ° ~l~~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, November 01, 2009 1:10 PM 1~~~~ ~~~~~~~ To: Maunder, Thomas E(DOA); Regg, James B(DOA); Schwartz, Guy L(DOA) Cc: NSK Problem Well Supv Subject: 2X-11 (PTD 184-164) Report of TxIA communication Attachments: 2X-11 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 2X-11 (PTD 184-164) had TxIA communication identified during well work on 10/30/09. The TIO was 1300/1275/680. A leaking GLV is suspected. Slickline will continue to troubleshoot the ~ leak and repair if possible. -~ Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~`'" ,'~~%~~~> t`~`t'x~ ~~ ~~?~~' +:s+ 11 /4/2009 KRU 2X-11 PTD 184-164 1 1 / 1 /2009 TIO Pressures rRr~ann~ ~ n i r 200~ 300Q~ 3000!~ 3000~ 0. 0. o. 0. 0_ 0. ~. ~ ~ ~ ~ ~ ~ ~ SC 3000 2700 2400 2100 1800 1500 izoo 900 600 300 n ANNULUS PRESSURE TRENDS WELL NAM1~ WLKRU2X-11:;~ ---- _ --- -- - - -- ----- _ _ - _ - - - _ - - ----- _- - - -- -- _ - - -~_ ~4 - i i i _ . _ - ~ ~'ti ~ ' ;-~ik- *~~at a ft --- - :i~ t~ r-~ f:+-t,~* ati-tis ~r ~ - tt -- - - -- - - - -- - - _ l r } '~ _ ~ { _1_ . ~ ~~. _ _ , ~ ill I ' ~i i "--"--""""""'..._..""""""""'-""""'-"""-""---"'-"'-"""-'-"--"--'--"""""""""-'--------""'-""""------------'-----"--'---------- - --------------------------------------------------. ~ PLOT "ak.T TTME 03-AUG-09 06:14 TAG N3ME WL2X-11-CHOKE SCRATCH 46 SCRATCH_46 AI-P2X5002-11 SCRATCH_96 SCRATCH_46 MINOR TIME MAJOR I'IME WEE1C PICK TIME DESCRIPTZON £LOW NHING CHOICE FLOW T[THING PRESSURE FLOW TITHING TEMP dL CASIN(3 PRESSURE INNER ANt7[JLUS PRES OUTER ANNULUS PRES +~,,r~:~ .u ~~;~, ~i 1 (~t4 ~ ~ .;~C ;.'=ii ~1~iidE +02160:00:00 gRS O1-NOV-09 06:14 9 16:17:0 4 ~~~~~~ ~~~~ ~ r;_ . h I.P:f ~.-A-1'EST ~~~~~~~ ~ PREV WELL DRILLSITE WELL ?7?77?? 2X 11 ??????? ~ NEXT WELL ?77???? ??????? F.NTRY TypE OPERATOR ??????? ~ OPERATOR VERIFIED ??????~ ~ SYSTEM AUTO ENTRY ??77?77 ~ BOTH • • / ,~ ~'%` ,.- ~ ___. ~~%" ~~i~1~1116~~~ NO. 4775 I r'~ !~?./ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth e'~~t'Yd51i11~~ ~U~ ~ ~ 2uuo Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE j 06/24/08 1 1 i L-20A 10215099 PRODUCTION PROFILE JQU s 06/26/08 1 1 1 G-05 12080389 LDL ~p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE "I' C. / - 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 1J-109 12080390 SBHP SURVEY "~ / f 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ '~- ~ 06/28/08 1 1 2X-15 f2080392 SBHP SURVEY ~ ~- 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - j 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY E(- ~ 06/29/08 1 1 i G-09 12080401 INJECTION PROFILE (,~ -- l j~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY L"~.-- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY '- j 06/30/08 1 1 1D-07 12080398 SBHP SURVEY -~! - 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ~ p 06/30/08 1 1 3C-15 11982441 USIT - (~ / (a 07/04/08 1 1 2VII-10 11982445 INJECTION PROFILE `~$ - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE 1 0- 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • c- 04/20/07 Schlumberger NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth D I~i{-Ifo« Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~1AY 0 4 toOl ~ Oil ¡j, Cüns. Çürmn\$~!!KI SGANNED MAY 0 7 Z007 Field: Kuparuk Well BL CD Color Job# Log Description Date 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE ' tt112!i/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. rO . . Re: 2G-I6, 2X-II e e SuþjechRe~,2X-IL ...... F{oft: "NSK Problem WeltSupv" <n1617@ppco.com> Dat~: .Fri, 25 Oct 2002 12:13:2'2.,0800 1j)~~Tòm'" .' r <tomJaWtdet@å&mî#~§~te.ak. us> \CZsL\ . Cåt:t':;;" ... i.. ..- \tiij'Õ' ....... x:~. Cf .~. Tom: 20 1(; is a ¡.rP.O ·..ell 51'1 §B.ß injcc . 3500 psi, so there is 1000 psi differential. The b shows about one bleed per month on the lA, wh' ere near our problem frequency of 2 times per we e operating criteria I inherited, up to 3000 owed on an MI injector on the IA. On water service this must be reduood to 199Q tg.~ ~oon rc; 2X-11 also requires a bleed once a month or so on the OA, but in general maintains a good differential between the IA and OA. I will put this on the list to check out the packoffs. The following is a six month trend of the wellhead pressures (pink is lA, white is OA, yellow is tubing). Please call if you have more questions. (Embedded image moved to file: pic20485.pcx) Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tom maunder@admin.state.ak.us> 10/25/2002 11:08 AM ffB 0 ~rl.ÐDÞ To: NSK Problem Well Supv/PPCO@Phillips cc: Jim Regg <Jim regg@admin.state.ak.us>, Mike Bill <mike bill@admin.state.ak.us> mmmmmmmmmmmmSUbJemct; 2 G - 16, 2 X - 11 Jerry and Pete, I was just looking at Chuck's SSV reports for 2G and 2X pads. I'd appreciate your looking into the pressure history of the 2 wells I have noted. 2G-16 is a WAG well that according to the pressure values Chuck recorded shows an IA pressure of 2500 psi. That seems high to me. Is there any communication problem?? No "internal waiver is noted". On 2X-11 the IA and OA pressures are nearly equal. No "internal waiver is noted". Thanks in advance for looking into the history of these wells. Tom Maunder, PE AOGCC (See attached file: tom_maunder.vcf) Iof2 ~"\-o.\~ ~" ~ ttc.cmJ 2/9/20068:02 AM '~..'-'¡'-.[..' " I I ! f ¡! i. [::11 ¡ l' ¡ ¡, 1J b ) .:¡'·'"':"r.J! ~ i ! ''';] tf ) I'-,i: I I I I I ! \', ¡-~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 9, 2005 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 ¡04-10l? dJ-'- \ , Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2X ("KRU 2X") pad on October 7, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Cornn'lission approved fail-safe automatic surtàce SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a íàilure rate exceeds 10 percent. Effective October 7,2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, /" ') TJ '~L6~ißfb, I" ¿..elf James B. Regg Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors ~NEr NO\i 1 7 2DD5 " . Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: KRlJ_2X Insp Ot 10/7/2005 Inspected by John Spaulding Interval 90 Days InspNo svslSOSJ0072I3641 Field Name KUPARUK RrVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Noble Related Insp: Reason 180-Day Src: Inspector . We/l~~~~___.. __~~ l~-=:~~_:_~!!~~;¿~_=~_ 8~Sr/[~~~~/l/~11lDtL iE~1 !ypiT_ W~/!~~!~~I~~~__ r_~~~~1(~!~e!t~~--~-~C~!1~~~~_--_--=_:~_~J Well Permit Separ Set LIP Test Test Test Date SI OiJ,WAG,GfNJ, Inner Outer Tubing Numbu Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI YeslNo YeslNo ~~:~~ :::::~~l:: ~~ :~ :: ; ~_. f _.-.~ r=::~:~ -I :~~~- :~~ u_=t~r-·_~::-= f~: .1_ 2X-II '-ï84Ì&iÒ"- T96' 70 70 P P u_-=t --I -J-OJL~- --¡-J2-S0 1200-ISÕ-- Yes--nt---Yes 2X-13 1841740 96 70 55T-p P I -r- J-OlL-- -----1050-- 700 J50_u Yes-lon-uNo 2X-14 __!_84~~~? ____ 96 -+- 70 50 .!_.___~__ __ ~__ ¡___!~~~_ __ -L3~~-_.9~--J __180______~e~___J- No 2X-IS J 84 J 760 96 1 70 J 0 J P i I-OIL _ 1000 900 200 Yes i No retested tripped at 65psi ok .___. _____ _____ _._____ ___.__________ _+__u _. n'___.______ ----T---no._--- ____nn ________\ _______ _ .____ _ ____n.__.______________· ~~~:~ '}:;+~f~---- ~~ ~~ ~~ ~ ~ --1 ---n:-óit-----~i~ó-- 16:000--~~-6ÒH-~-- ~~- j__~o__-I--- ----- _~ _-_~x~~Æ- _--- _-1~?~6~9.__ _~6 _~-.7~ __60-=--_~_=_-~df--~=-_:J=-~~=~~L=J~ib_~_ --1~~5~~__~~----= 200------- y;: - -;~~ _nl~ n=~~_-__~=_-__ j . ----.---- - - i ------j -- ------ - -' Comments Performance -------.-- ------- ~----~--- ---- --------~ 2-12a wing leaked -unable 10 tesl, requested repairs prior to testing again Wells Components FaiJures Failure Rate 9 18 . ------ ---- __£____ _JLLL~__ -- '-' ( o ifj! í-- y Wednesday, November 09, 2005 , ) ) ~71~,r ':} /Æ:~~'~/Æ / AI.ASIiA. OIL AND GAS / CONSERVATION COMMISSION / October 25, 2004 ~.Lt~ ,,~4' FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 J\nchorage,AI( 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SYS) at~~~~~/R:ìverlJriìt 2X ("KRU 2X") pad on October 15, 2004. Attached is a copy of the InspecfionReport. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SYS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial'lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. J\n SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 100/0 failure threshold. Also noted during the Commission's inspection were unsupported flow piping and pilots on KRU 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provide ~ortu' 0 witness the SVS test. : IÎ Smcerely, ÇíJ~¿/,~ Daniel T. Seamount, Jr. Commissioner. SCANNE[ì (I. ".~ ) 0 [IlL ,~O] '? Ij '....... ; i Attach. copy by email: Bob Fleckenstein; AOGCC Inspectors SCANNED NOV 0 3 2004 Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv..:Jß£.. \DZsIO+ Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by Jeff Jones Interval 90 Days InspNo svsJJ041019163228 Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason ISO-Day Src: Inspector ..,oc-.,- . .._-,_..J._.,- . -~ Well Permit Separ Set UP Test Test Test Date SI Oil, WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS, CYCLE, SI PSI PSI PSI YeslNo YeslNo 2X-03 1831090 I 2700 I 2000 1900 I P I P I W AGIN Flow piping & pilot not supported properly; loose & wobbly. 2X-08 1831140 2700 2000 1750 P P W AGIN 2X-09 1841620 98 70 50 P P I-OIL Flow piping & pilot not supported properly; loose & wobbly. ~ 2X-I0 1841630 98 70 60 P P I-OIL 2X- I I 1841640 98 70 65 P 4 I-OIL 750 900 175 No Yes IA x OA communication 2X-12A 1951760 98 70 65 P P I-OIL wing valve leaks. 2X-13 1841740 98 70 44 3 P I-OIL 2X-14 1841750 98 70 75 P P I-OIL 2X-lS 1841760 98 70 55 P 7 I-OIL wing & pit valves leak. 2X-16 1841720 98 70 52 P P I-OIL 2X-17 1951710 98 70 50 P P I-OIL 2X-18 1951600 98 70 55 P P I-OIL Comments Performance The SSV on well2X-l1 failed the pressure test & will require repair. The pilot on weIl2X-13 tripped Wells Components Failures Failure Rate low & was cycled & passed a re-test. Both the wing and pit valves leaked on weJl2X-15 and the SSV could not be tested. I inspected 12 well houses. 12 24 3 12.5% --/ Monday, October 25, 2004 Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: 8eth 7/1-7 09/24/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color ~ 'f -O&{ 2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 =1S -OS, 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 18{" 9'38 28-12 10802934 INJECTION PROFILE 09/10/04 1 ~¥- I ~4 I 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 l~l- ~5 18-10 10922467 PRODUCTION PROFILE 09/21/04 1 ()". "5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 r~-OZ ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 J ~'t - ({ 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 ,~:z. -'~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 J .2 - tf 1 H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2 -Dto 1A-14 10802938 INJECTION PROFILE 09/13/04 1 ( Aí-070.2H-03 10802945 INJECTION PROFILE 09/18/04 1 lß~"054f 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 o~... olf'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H ~ 3H-09 10922468 INJECTION PROFILE 09/22/04 1 I 'il6-/tf/ 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 'tit) - / r,(p1 A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~. ~ Sl€;~ I. kl'ÁÁ#./ul"'- ~CANNED NOV 0 8 2004 DATE: /f jk¿ Please sign and returle copy of this transm ittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, 0~-~ Commissioner ,..~'/./~/~ ,~. DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor John H Spaulding~,/~- ~,'~. Petroleum Inspector FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX 1E - 8 wells, 16 components, 1 failure,~9 % failure rate, 12 well house insp. :.:~2X~ -10 wells~.20:compnents, 1 failure, 5 % failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupamk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE lC-02 1800500 91 70 65 P P OIL lC-03 1800560 SI lC-05 1800580 lC-06 1800780 SI lC-07 1800800 91 60~ 55 P P OIL 1 E- 10 1820360 lC-11 1820510 lC-12 1820600 SI 1 E- 14 1820790~ lC-18 1830160 91 60 46 ' P P OIL lC-19 1830170 lC-20 1830050 91 60 48 P P OIL lC-21 1830020 1E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [~ 90 var Remarks: 8/7/00 Page 1 of 1 svs kupamk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kuparuk/Kuparuk R./2X Separator psi: LPS 96 HPS 22~Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 2X-02 1831030 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-10 1841630 96 70 65 P P OIL 2X-11- 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X-15 1841760 96 70 70 P P OIL 2X- 16 1841720 2X-17 1951710 96 60 50~ p P OILi 2X-18 1951600 96 60 50: p p OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [] oo Day Remarks: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, DATE: THRU: CommissiOner T°m Maunder, P. I. SupervisOr \(-z,c.~ ~. Chuck Scheve; SUBJECT: Petroleum InspectOr FROM: January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday,'January 25, 2001' I traveled to the Kuparuk River Field. and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AoGcC Safety Valve SYstem Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve. On Well 2X-14 had a sloW leak when pressure tested. This valve was serviced and I witnessed a succeSsful retest on 1-26-01. . Earnie Barndt COnducted the testing today he demonstrated good test procedure and was a pleasure to work with ~ ' - All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witneSsed the 90,day SVS testing at 2X Pad in the Kuparuk River Field.. -- ~--~J~,,~k'~ ~~k,,e -~o ~-~,~'~ ~-~ \%L~ KRU 2X Pad, .12 wells, 24 components, I failure 4.1% failure rate 15 wellhouse inspections Attachment: SVS KRU 2X Pad 1'25-01 CS X unclassified Confidential (Unclassified if doc. Removed) SVS KRu 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve , , Submitted By: ~'hu'ck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2X Pad Separator psi: LPS_ 99 HPS 1/25/01 ...... i: :SV: S$$V Well. TyPe ' -' .... ~ .... ~ - i' ~ · :-: .... '--' .... : -"-~---. :~ ':;' "''~: .: "'--' ; ' ;' : "-''....'.::2. ' ' . ::2:: . : ::. Well Pemit Separ Set ~ T~t T~t Test Date Oil, WAG, G~J, Number Number ,. pSI PSI Trip. . C~de Code Code Passed ,GAS or CYO.~ 2X-01 1830840~ ~2X-02 1831030 3750 " 2000 1800 P ' 'P "' WAG , , 2X-03 1831090 2X-04 1831180 3750 2000 2000 P P WAG ,, , ,, , , 2X-05 1831070 , , 2X-06 1831100 2X-07 ' 1~31130 "37~0 2000 2000 P P WAG , , , ~ , , , ,. , 2X-08 1831140 , , ,, ,, 2X-09 1841620 99! 60 60 P P OIL , , , , , 2X-10 1841630 2~-11 .1841~6 99 60 '50 ' P P '" OIL 2X-12A 1951760 99 60 ' '5~ 'P P OIL , ,, , 2X-13 1841740 99 60 55 P P OIL 2X-14 1841750 99 60~ 55 P 4 ' 1)26/01 OIL 2X-15 184'1760 99 60~ 55 P P ' OIL , , , , , ,. 2X-16 1841720 99 60 55 P P OIL , ,, , , 2X-17 1951710 99 60 60 P P OIL }~-18 19'51600 99 60 60 P P ' 0IL · , , , , , , 2X-19 1951750 ,, , Wells: , , ,12 Components: 24 Failures: 1 Failure Rate: 4. ~7% Elgo my Remarks: Surfa ,ce Safety on well 2X-14 had v, ery slow leak when pressure tested, valve to be serviced and retested by,operator. RJF 1/16/01 Page 1 of 1 SVS KRU 2X Pad 1-25-01 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development X, Explor.atory _ Stratigraphic _ Service 4. Location of well at surface 1170' FSL, 598' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1292' FSL, 1250' FEL, Sec. 4, T11N, R9E, UM At effective depth 1328' FSL, 1426' FEL, Sec. 4, T11N, R9E, UM At total depth 1337' FSL, 1465' FEL, Sec. 4, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 112 feet 7. unit or Property name Kuparuk River Unit 8. Well number 2X-11 9. Permit number/approval number 84-1 64 10. APl number 50-029-21 188-00 11. Field/Pool Kuparuk River Field/Oil Pool 6508 feet Plugs (measured) None 6 32 0 feet Effective depth: measured 6 4 0 3 feet true vertical 6223 feet Junk (measured) Prong & 2 CV's in rathole Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 213 SX CS II 99' 99' Surface 3086' 9-5/8" 700 SX CS III & 31 21' 31 21' Intermediate 600 SX CS II Production 6455' 7" 306 SX Class G & 6 4 8 8' 6 3 01 ' Liner 250 Sx CS I Perforation depth: measured . 5962'-5992', 6012'-6044', 6175'-6186', 6198'-6226' · true verbcal 5819'-5847', 5865'-5894', 6013'-6023', 6034'-60,~' Tubing (size grade and measured depth) 3.5", 9.3#/ft., J-55 @ 6108 Packers and SSSV (type and measured depth) Pkr's: Baker FHL @ 5825' & Baker FB-1 @ 6087'; SSSV: Baker FVL @ 1895' 13. Stimulation or cement squeeze summary Refracture "A" sands on 7/12/96 Intervals treated (measured) 6175'-6186', 6198'-6226' Treatment description including volumes used and final pressure Pumped 194.8 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 6150 psi. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 839 619 100 749 144 Subsequent to operation 1 0 3 4 804 945 787 149 15. Attachments Copies ~)f Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~!~,r)'__~. ~ ,2'1~ Form 10'-404 (--¢lev 06/15~88 Title Wells Superintendent Date 4-0-97 SUBMIT IN DUPLICA ~ E ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2X-11(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-11 FRAC, FRAC SUPPORT 0708961600.5 DATE DAILY WORK UNIT NUMBER 07/1 2/96 "A" SAND FRAC cou,, I succ ssfu, k.Y P .SO SU . WSO. 1 (~ Yes O NoI ~ Yes O No DS-GALLEGOS CHARY ,. FIE~ AF~ C~ DAILY COST ACCUM COST S~n~ ~/ ES~MATE KM 1395 230DS28XL $133,458 $138,834 ~.-" ~.~. ~..~ Initial Tb, Press Final Tb, Pre. Initial Inner Ann Final Inner Ann I Initial ON(er Ann I Final Oute~ 575 PSI 1500 PSI 525 PSI 500 PSI! 16°° PSI /700 PSI DAILY SUMMARY "A" SAND FRAC FLUSHED TO COMPLETION. PROP PUMPED 194814 LBS W113 PPA OF #10/14 @ PERPS. 1386 LBS OF PROP IN WELLBORE, TOP @ APP: 6250'. SLURRY VOLUME WAS 1770 LBS. MAX PSI WAS 6150 PSI. WELL FREEZE PROTECTED W/DIESEL DOWN TO 2900'. TIME 07:00 09:00 09:45 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC PUMP TRK, AND VAC TRK. HELD SAFETY MTG (15 ON LOCATION) PT'D BACKSIDE LINES AND PRESSURED UP 7" CSG. SET TREESAVER. PT'D HI-PRESSURE LINES TO 6500 PSI. PUMP BREAKDOWN 40# DELAYED XL GW @ 30 - 20 BPM, 390 BBLS VOLUME PUMPED. USED 5939 LBS OF #20/40 PROP. MAX PSI WAS 6150 PSI AND ENDING PSi WAS 4000 PSI. S/D ISIP 2156 PSI. PULSED FOR CLOSURE AND MONITORED PSI. 11:00 PUMP DATAFRAC 40# DELAYED XL GW @ 5 - 20 BPM, 210 BBLS VOLUME PUMPED. MAX AND ENDING PSI 3450 PSI. S/D ISIP 2078 PSI. STOODBY FOR CLOSURE AND MONITORED PSI. 12:40 PUMP FRAC 40# DELAYED XL GW @ 5 - 20 BPM, 1170 BBLS VOLUME PUMPED. USED 188875 LBS OF PROP. MAX AND ENDING PSI 4450 PSI. FLUSHED TO COMPLETION. S/D AND MONITORED PSI FOR 15 MINS. 14:05 14:30 15:30 STARTED TO P,/D. DEPRESSURED THE 7" CSG AND RELEASED THE APC PUMP TRK. TOTAL PROPPANT PUMPED WAS 194814 LBS (17857 LBS OF #20/40, 158082 LBS OF #12/18, AND 18875 LBS OF #10/14) W/13 PPA OF #10/14 @ PERF'S. LEFT 1386 LBS OF PROP IN WELLBORE. TOP OF SAND SHOULD BE FOUND @ APP: 6250' MID 'A' '.-'AND PERF'S. TOTAL SLURRY VOLUME WAS 1770 LBS. MAX PSI WAS 6150 PSI. FREEZE PROTECTED WELL DOWN TO 2900'. PULLED TREESAVER (ALL CUPS RETURNED) VACED ALL LINES AND TANKS, CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. SECURED WELL AND NOTIFIED DSO OF STATUS. SERVICE" COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $159.00 APC $6,800.00 $8,924.00 ARCO $315.00 $315.00 DOWELL $126,343.00 $12.6.,,3..4.3..00 HALLIBURTON $0.00 $3,093.00 TOTAL FIELD ESTIMATE $133,458.00 $138,834.00 · ~. STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI;::~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate m Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~X ARCO Alaska, Inc. Exploratory _ 112' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1170' FSL, 598' FEL, Sec. 4, T11N, R9E, UM 2X-11 At top of productive interval 9. Permit number/approval number 1292' FSL, 1250' FEL, Sec. 4, T11N, R9E, UM 84-164 At effective depth 10. APl number 1327' FSL, 1425' FEL, Sec. 4, T11N, R9E, UM 50-029-21188 At total depth 11. Field/Pool 1337' FSL, 1465' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6 5 0 8' feet Plugs (measured) true vertical 6320' feet Effective depth: measured 6 4 0 3' feet Junk (measured) true vertical 6223' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 9 9' I 6" 213 Sx CS I 9 9' 9 9' Surface 31 21' 9 5/8" 700 Sx CS III & 31 21 ' 31 21 ' Intermediate 650 Sx CS II Production 6 4 8 8 7" 306 Sx Class G & 6 4 8 8' 6 3 0 2' Liner 250 Sx CS I Perforation depth: measured ..,, ~."~'~ ! I I I , , , ,w~ 5962-5992, 6012-6044, 61 75 -61 86, 61 98-6226 ~,,. .~ true vertical -~.,~ ~t 5819'-5847', 5865'-5894', 6013'-6023', 6034'-6060' ..v//.~ L-~ Tubing (size, ,grade' and measured depth) , .~,., (~2_,~1,,~,.., 3 1/2' 9.3#/FT J-55 EUE ABMOD IPC, SET @ 6108 '~,,~ ~ Packers and SSSV (type and measured depth) '/O,~,~'~[~&?. SSSV: OTIS FXE @ 1895', Packers: Baker FHL @ 5813', Baker FB-1 @ 6075' '~ 13. Stimulation or cement squeeze summary Hydraulically fractured the A Sand with crosslinked gelled water and 16/20 Mesh Carbo-Lite. Intervals treated (measured) Treatment description including volumes used and final pressure Pumped 62,260 # 16/20 Mesh Carbo-Lite and 697 bbl gelled water. Final treating pressure = 3860 psi i14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) 356 223 - 0 - 2300 1 40 Subsequent to operation (producing) 1 0 6 3 6 6 8 1 0 0 5 0 0 1 6 6 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector Daily Report of Well Operations X Oil ;~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned '"'~~~~' ~ Title Senoir Operations Engineer Date(~'/5'''~ --orm 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ARCO Alaska, Inc,~) Subsidiary of Atlantic Richfield Company WELL IPBDT .,~JNTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT - STATE IOPERATION AT REPORT TIME IDAY~ 1DATE knots REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pr~Job Safety Meeting AFE . TOTAL FIELD ESTIMATE ~ ARCO Alaska, Inc Post Office ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2X-11 Stimulate May, 1990 2V-12 Stimulate May, 1990 3K-04 Stimulate May, 1 990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichHeldOom~ar',y ~-'" STATE OF ALASKA -/4¢/ ~ OIL AND GAS CONSERVATION ~MlSSlON ~ / APPLICATION FOR SUNDRY APPROVALS ~£~/ , 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_' Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _~. Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory _ RKB 112 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1170' FSL, 598' FEL, Sec. 4, T11N, R9E, UM 2X-1 1 At top of productive interval 9. Permit number 1292' FSL, 1250' FEL, Sec. 4, T11N, R9E, UM 84-1 64 At effective depth 10. APl number 1327' FSL, 1425' FEL, Sec. 4, T11N, R9E, UM so-029-21188 At total depth 11. Field/Pool Kuparuk River Field 1337' FSL, 1465' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6508' feet Plugs (measured) true vertical 63 2 0' feet None ~' ~" ~" ]919 Effective depth: measured 6403' feet Junk (measured) ~J~, 0 ~/~. ' true vertical 6 2 2 3 feet None ~,-,~f., o , Casing Length Size Cemented Measured depth ~rj~l~0~t~{~tiocal depth Structural Conductor 9 9' 1 6" 213 Sx CS I 9 9' 9 9' Surface 31 21' 9 5/8" 700 Sx CS III & 31 21' 31 21 ' Intermediate 650 Sx Class II Production 6 4 8 8' 7" 306 Sx Class G& 6 4 8 8' 6 3 0 2' Liner 250 SX CS I Perforation depth' measured 5962'-5992', 6012'-6044' 12 SPF 120° phasing 6175'-6186', 6198'-6226' 4 SPF 120° phasing true vertical 5819'-5847', 5865'-5894', 6013'-6023', 6034'-6060' TVD Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 6108' Packers and SSSV (type and measured depth) Baker FHL @ 5813', Baker FB-1 @ 6075', Otis FXE @ 1895' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch _ Fracture stimulate A Sand with approximately 710 bbls c. ailed water and 55~700 lbs of proppant. 14. Estimated date for commencing operation 15. Status of well classification as: May 4, 1990 Oil ~ Gas ~ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereli~ certify t~)the ~s true and correct to the best of mY knowledge. Si~Ined ~9(~ o Title Sr. Operations En~inner Date 5 /-- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprov I o Plug integrity __ BOP Test Location clearance I..., 7~ (--'" ~'~- Mechanical Integrity Test _ Subsequent form require 10-Z}(~§ Approved by ,he order Commission Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE S. Pavlas / J. Hardy 4/27/90 Page 3 Kuparuk Well 2X-11 'A' Sand Re-Fracture Procedure Charge Code: K80968 1. Obtain a 24 hour well test. NOTE: Steps 2 through 4 should be completed well in advance of the refrac job, but step 5 should be deferred until the day prior to pumping. 2. MIRU Slickline unit. RIH with gauge ring. Tag fill. . Replace GLV's and CV's in mandrels at 1951', 3364', 4500', 5400', 5755', 5852', 5922', and 6056' RKB with DV's. Fill annulus with diesel and pressure test. 4. Set standing valve in D nipple at 6089' RKB. Pressure test tubing. 5. Pull DV from GLM at 6056' RKB. Run 1.5" Petredat gauge in GLM at 6056' RKB. Pressure test tubing. Pull standing valve from D nipple at 6098' RKB. NOTE: Petredat gauge should be set as follows (assuming gauge is run 20 hrs prior to frac): Press. Period Press. Rate # of Press. Delta Time Temp. Rate min/Sample Samples/hr Measurements This Rate (start) Samples/hr 60.00 1.00 2 0 20.00 (00.03) 1.00 30.00 2.00 6 3.00 (20.03) 2.00 0.25 240.00 2400 10.00 (23.03) 24.00 60.00 1.00 1 44 144.00 (33.03) 1.00 6. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. 7. Obtain two 24 hour A Sand only well tests. = . 10. Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Install "Tree Saver" with maximum mandrel I.D. Hold 3500 psi on the annulus during the entire job. Pump fracture treatment per the attached schedule. Recommended maximum surface treating pressure is 6000 psi. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: S. Pavlas / J. Hardy 4/27/90 'Page 4 WHTPE = 4000 psig Fracture Gradient -- 0.70 psi/ft Tubing Friction = 300 psi/1000 ft (5994' TVD) (6753' MD) @25 BPM * If initial pump in pressure exceeds 6000 psi, shut down job and confer with Engineering. 1 1. Rig down frac equipment. Leave well shut in over night. 12. MIRU slickline unit. 13. Pull Petredat gauge from GLM at 6056' RKB. Install DV at 6056' RKB. Tag fill with blind box. 14. RDMO slickline unit. 1 5. Follow attached flowback schedule. 16. After well has completed flowback, obtain 24 hour well test. If gaslift is required to aid in flowback/clean up of the load fluid a separate recommendation will follow. No workover fluids are required. No BOP's are required. The estimated bottomhole presure is 2600 psi. STAGE FLUID DESCRIPTION KUPARUK WELL 2X-ll 'A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 4/19/90 CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME BBLS BPM PPG DESCRIPTION LBS STG/CUM HIT PERFS BBLS NOTES: GW PRE-PAD 150.0 2 5 ............................................... SHUT GW PAD 390.0 2 5 GW w/2 PPG 32.2 25 GW w/4 PPG 34.0 2 5 GW w/6 PPG 35.6 25 GW w/8 PPG 40.6 2 5 GW w/10 PPG 31.2 25 GW w/12 PPG 22.9 2 5 SLICK DIESEL FLUSH 53.0 +SV 25 TOTAL GELLED WATER = TOTAL DIESEL = TOTAL SLICK DIESEL = 706.2 BBLS 30.3 BBLS 53.0 BBLS +SV Stages I through 8 are Gelled Water. DOWN 0 -- 0 150/ 150 FOR ISIP ....................................................... 0 16/20 M CARBO-LITE 0 390~ 540 2 16/20 M CARBO-LITE 2702 35/ 575 4 16/20 M CARBO-LITE 5712 40/ 615 6 16/20 M CARBO-LITE 8966 4 5 / 660 8 16/20 M CARBO-LITE 13658 55! 715 10 16/20 M CARBO-LITE 13113 45/ 760 12 16/20 M CARBO-LITE 11532 35/ 795 0 - - 0 53 / 848 16/20 M CARBO-LITE = 55682 LBS Stages 1&2 are Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stages 3 through 8 are Gelled Water with 6 hour breaker and without silica flour. Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should include a volume adjustment for surface equipment between the wellhead and densitometer. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained between 90-100° F on the surface. Recommended maximum surface treating pressure is 6000 psi with 3500 psi on the annulus. If surface pressure increases, reduce treating rate to determine cause of pressure increase. Maintain reduced rate if necessary. 45 195 585 620 660 705 760 8O5 84O ARCO Alaska, Inc. Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 14, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate is a Report of Sundry Well Well: Well 2X-ll Operations on Kuparuk Action Stimulate If you have any questions, please call me at 265-6840. Sincerely, ~. B.vSmallwood Senior Operations Engineer GBS'pg-O038 Attachment cc' File KOE1.4-9 ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI,.~,SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing 99510 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK . Stimulate Plugging Perforate Repair well Pull tubing 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ Other Location of well at surface 170' FSL, 598' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1292' FSL, 1250' FEL, Sec. 4, T11N, R9E, UM At effective depth 1333' FSL, 1446' FEL, Sec. 4, T11N, R9E, UM At total depth 1337' FSL, 1465' FEL, Sec. 4, T11N, R9E, UM 12. 6. Datum elevation (DF or KB) 112' RKB 7. Unit or Property name Kuparuk River Unit feet Present well condition summary Total Depth: measured 71 0 0' true vertical 6173' 8. Well number 2X-ll 9. Permit number/approval number 84-164 / verbal by L. Smith 10. APl number 5o-029-211 87 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet Effective depth: measured 6 9 9 7' true vertical 6091 ' feet Junk (measured) feet Casing Length Size Structural Conductor 6 8' 1 6" Surface 3 0 9 0' 9 5/8" Intermediate Production 64 5 6' 7" Liner Perforation depth: measured 5962'-5992', true vertical 5819'-5847', Cemented Measured depth True vertical depth 213 Sx CS II 99' 99' 700 Sx CS III & 31 21' 31 21' 600 Sx CS II 306 Sx Class "G" & 6 4 8 8' 6 3 0 2° 250 Sx CS I 6012'-6044', 5865'-5894', 6175'-6186', 6198'-6226' 6013'-6023', 6034'-6060' Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 6108' MD RKB Packers and SSSV (type and measured depth) Otis FXE WRDP SSSV @ 1895'; Baker FHL @ 5813', Baker FB-1 @ 6075' RECEIVED 13. Stimulation or cement squeeze summary 1,~ LJ Intervals treated (measured) · ' 5962'-5992', 6012'-6044' AiaS~-30il& Treatment description including volumes used and final pressure scale inhibitor squeeze treatmen't',nch°~'a~ 28 bbls diesel w/ solvent, 94 bbls "SOC" scale inhibitor, 365 bbl sea water, final pressure 2000 psi. 14. Representative Daily Average Prod~Jction or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1500 800 1900 1200 155 Subsequent to operation (est) 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 1500 800 1900 1200 155 16. Status of well classification as: Oil X Gas Suspended Service , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S'~lned ~1/0.4~04~Re~~jForm - 06/1 ~5~88 --~/~ _/..JTitle Senior Operations Engineer Date SUBMIT IN DUPLICATE ARCOAlaska, Inc Subsidiary of Atlantic Richfield Company WELL PBDT CONTRACTOR ~... .MARKS !FIELD - DISTRICT - STATE OPERATION AT REPORT TIME WELL SERVICE REPORT [DAYS DATE /o 33 6 Do 3.0 3,0 /3" ~O 3,0 ~ d 3.0 ~ o [o r./ ~ 1'../oo 3 ,,e b'"' O /o ~/& I ~ 5'0 :7. o 7 0 Io ~'~, /~ ~ o 9'../ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp.°F I Chill Factor I Visibility. °F miles i ! Wind Vel.~ knots iSigned ~. " ?~'" STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION cOMMISSION W,=LL COMPL,=TION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well ~1~ REVISED OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-164 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 9951 0-0360 50- 029-21188 4. Location of well at surface 9. Unit or Lease Name 1170' FSL, 598' FEL, Sec. 4, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1292' FSL, 1250' FEL, Sec. 4, T11N, R9E, UM 2X-ll At Total Depth 11. Field and Pool 1337' FSL, 1465' FEL, Sec. 4, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 112' ADL 25645 ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/23/84 11/27/84 11/29/84'I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6508'MD, 6320'TVD 6403'MD, 6223'TVD YES [~ NO []I 1907 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/Cal/FDC/CNL, GR/SP/DIL, CBL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED -iO~ 6Z.5# H-40 Surf 99' 24" 213 sx CS II 9-5/8" 36.0# J-55 Surf 3121' 12-1/4" 700 sx CS Ill & 600 s; CS II 7" 26.0# J-55 Surf 6488' 8-1/2" 306 sx Class G & 250 ~x CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBI NG R ECOR D interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 3-1/2" 6108' 6087' & 5825' 5962 ' -5992 'MD 5819 ' -5847 'TVD 6012'-6044~MD 5865'-5894 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIN'DoF MATERIAL USED Perforated w/4 spf, 120° phasing .See attached Addend,m~ dated 12/29/87~ 6175'-6186'MD 6013'-6023'TVD for fracture d lta. 6198 ' -6226 'MD 6034 ' -6060 'TVD . 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours TeSted PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ OILoBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) · Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,~. ~C~IV~ FEY *Note: Well was perforated and tubing ran on 1/20/85. Fractured well 9/22/85. Form 10-407 Rc.v. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ,. 29. .- 30. GEOLOGIC MARKERS 'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 5961 ' 5819' N/A 'Base Upper Sand 6046' $896' Top- Lower Sand 6157 ' 5997 ' Base Lower Sand 6287' 6116' 31. LIST OF ATTACHMENTS Addendum (dated 9/22/85 & 12/29/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L~_/~._/~_._~. ]_/~/_~.._j Title Associate Engineer Date ['2~'~:0~ 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 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27-: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "nOne''. ADDENDUM WELL' 9/22/85 2X-ll Frac Kuparuk "A" sand perfs 6175'-6186' and 6198'-6226' in 7 stages per procedure dated 9/9/85 as follows' Stage 1: 40 bbls 130° diesel w/5% Musol @ 5 BPM, 5100 psi Stage 2: 50 bbls gelled diesel @ 20 BPM, 5100 psi Stage 3: 36 bbls gelled diesel 100 Mesh @ 20 BPM, 4300 psi Stage 4: 30 bbls gelled diesel spacer pad @ 20 BPM, 3800 psi Stage 5: 27 bbls gelled Uiesel 3# 20/40 @ 20 BPM, 3790 psi Stage 6: 49 bbls gelled diesel 8# 20/40 @ 20 BPM, 4300 psi Stage 7.: 45 bbls gelled diesel flush, 2840 psi Load to recover: 277 bbls diesel Pumped 700# 100 Mesh & 12,500# 20/40 in formation leaving 2600# in casing. '- Dril~hg' Supervis WELL: 12/i0/84 12/11/84 9/22/85 ADDENDUM 2X-11 Arctic Pak w/250 sx CS I, followed by 53.5 bbls Arctic Pak. 6403' PBTD Rn CBL f/6370'-3100'. Rn gyro f/6350'-surf. AFE 304301 Frac well w/277 bbls diesel, 700# 100 mesh, & 12,500# 20/40 sand at avg rate of 20 BPM, 4800 psi. Pressured out 10 bbls early. D riliin~g S~perintendent Date ?" STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM.,.,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] StimulateY~] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage. AK 99510 4. Location of well at surface 1170' FSL, 598' FEL, Sec. 4, T11N, RgE, UH 5. Datum elevation (DF or KB) RKB 112' Pad 77' 6. Unit or Property name . Kuparuk River Unit 7. Well number 2X-ll Feet At top of productive interval 1292' FSL, 1250' FEL, Sec. 4 At effective depth 1327' FSL, 1417' FEL, Sec. 4 At total d~:~t~ , 1337' , 1465 FEL, Sec. 4 , T11N, R9E, UM , T11N, R9E, UM , T11N, R9E, UM 8. Approval number N/A 9. APl number 50-- 029-21188 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 6508 true vertical 6320 feet Plugs (measured) feet None Effective depth: measured 6386 true vertical 6207 feet feet Junk (measured) None Casing Structural Conductor Surface X X )~t~:i~e Production xx ~m%~xxxx x Perforation depth: Length 80' 3091' 6458' measured Size Cemented Measured depth True Vertical depth 16" 213SX CS-II 110' MD 110' TVD 9-5/8" 700SX CS-III 3121320' MD 600SX CS-II 7" 306SX Class G6488' MD 250SX CS-1 5962'-5992' MD, 6012'-6044' MD, 6175'-6186' MD, 6198'-6226' MD true vertical 5789'-5817' TVD, 5865'-5894' TVD, 6013'-6023' TVD, 6035'-6061' 12. Tubing (size, grade and measured depth) 3.5", J-55, 9.3# W/Tail @ 6096' MD Packers and SSSV (J. yp.e and measured dep. th) Baker FHL pkr e 5813'/Baker FB-1 pkr @ 6075'/Baker FVL SSSV @ 1895' MD "C:: Sand Acid job 3/i8/86 Stimulation or cement squeeze summary 5962' - 5992' MD 6012' - 6044' MD Intervals treated (measured) 11.8% HCL 91 BBLS @ 875 psi WHP Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 3901 3037 29 600 165 4347 2779 223 500 195 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge .~-.~-~ -~.~--'~ VD Form 10-404 Rev. Title Sr. Operations Engineer Date /~ *] Submit in Dupficate ARCO Alaska, inc~-'~''' Subsidiary of Atlantic Richfield Company WELL WELL SERVICE REPORT ,,' "x- ' ONTRACTOR REMARKS .,4,ec 7-'/c c.. 7"- FIELD- DISTRICT- STATE /<~f,~,euy OPERATION AT REPORT TIME DAYS I DATE 66 s7".' ~3570z CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: 7-0 FA c ,/<,.- · : ~ ,N ~ c £ ,.. CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING DESCRIPTION DALLY z~/37 ACCUM. TOTAL FRACMASTER q ~-~ 3 : B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE TOTAL F;ELD ESTIMATE 3570z- ISigned . .~ ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 25, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate Kuparuk River Field: Well is an intent Action notice on the following Anticipated Start Date 2X-11 Stimulation March 3, 1986 If you have any questions, please call me at 265-6840. Sincerely, well Senior Operations Engineer GBS: pg: 0009 Attachment cc: File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc 84-164 3. Address 8. APl Number P. O. Box 100360, Anchorage_, Alaska 99510 50- 029-21188 9. Unit or Lease Name KIJPARUK RIVER UNIT OTHER [] 4. Location of Well SURFACE LOCATION: 1170' FSL, 598' FEL, SEC. 4, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 82' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25645, ALK 2576 10. Well Number 2X-ll 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "C" Sand in Kuparuk Well 2X-11 be acidized to improve production. The treatment will consist of 4100 gals of 12% HCL. ANTICIPATED START DATE: March 3, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . The space below 'For Commission use Title Kup~k Date Sr. Operations Engr. Conditions of Approval, if any: Approved by ,~ the Commission Date ......... ~ Form 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc,..~ Post Offic,. )x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-22-85 TtG~NSMITTAL NO: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING kECORDS CLERK ATO-1115B -.. P.O. BOX 100360 . ANCHORAGE, AK 99-51U .- TRANSMITTED HEREWITH 'AKE T~+~ FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF EACH CEMENT. BOND LOG/ 'w33-8 06-06-85 ~ q2X-15 11-07-.84 "~2X-13 11-17-84 ~2X-12 12-08-84 ~2X-ll 12-08-84 ~X-10 12-21-84 ~ 2X-9 12'20-84 '~ 2W-6 . 11-25-85 '~2V-16 06-06-85 '~ 2V-15 06-07-85 '~2V-131 . 06-03-85 -~2U-8 :~ ~i ¥~_ 04-02-85 VAKIABLE RUN #1 RUN ~1 *{UN %1 RUN %1 RUN #1 kUN #1 RUN ~t RUN ~1 · kUN ~1 RUN %1 .-: RUN %1 · RUN. %1- 'c~2U-7'::-!i:'2 04-01-85 -' SUN' ~'" 2U-6 ?'-~: 03-31-85 -' I~UN 04-01-85 03- 02- 851;: I:;I: 'RUN 12-19-84 12-18-84 11-03-84 06-17-85 06-08-~5 06-08-85 11-05-84 05-27-85 04-17-85 kUN RUN RUN ~UN RUN RUN RUN RUN RUN ~ %CPF- lA 12-21-84 RUN CEMENT EVALUATION TOOL '~ 1F-'16 . '- 03-12-85 RUN · ~iR-5 06-26-85 ' ' RUN ~ ~,lR-5 ':i~'~.-06-27-85- }(UN '~2U-2-':?;:'; 03-25-85' ~ i~UN '~2U-15:,. 03-07-85 . RUN "~33-9 '~.'--'~ 06-30-85 RUN _ ' ~3C-11 ii 06-29-~ 85 RUN ~3C~12' 06-29-85.- RUN ~ RECEIPT ACKNOWLEDGED: %1! .... . #1 %1 LoUS/ #1 _#2 #1 PLgA$~ ACKNOWLEDGE DENSITY " 5850-8369 5900-8258 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-6938 '-- 0070-B122 '- :' ' ' 5600-8107-- - - ".i:'i-i -'~' ' 5994-9161 :- ~ . 6284-7850: 5200-74~9 - · 3285-6454 -- 5693-6652 5987-8324 430~-7028 6950-8628 4883-6600 · 6490-7566 . 897~-10744 " 2200-3856 · CIk4ENT EVALUATION LOGS 8269-8712 · 6974-8~44 8254-8532 - 5790-9450 -' 6400-7002 6000-8246 6500-8726 5400-7457 W. PAShEK EXXON P~ILLIps OIL J.- RATH~IELL' ' BPAE " 'i: -.- DRILLIN~*BL B.. CURRIER _ L. JOHNSTON_ CHEVRON . . ~4OB I L · .. D & M ~ NSK CLE~K*DL -_ · . · · ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany 3 RETUi~I9 TO: ARCO Alaska, Inc. Post Office B,.... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT]:: 10-0 2-8 5 TRANSMITTAL NO: 5376 ARCO ALASKA, iNC. KUPARUK OPERATIONS ENGINEERING i~ECO biDS CLERK ATO-1il5B P.O. BOX 100360 ANChOPd~.GE, AK 995 ! 0 ~:~-~-:~o~-:=l .._~:D HEI~B;.~iTll ARs 'X'iiL FOLLO%fiNG ITEi4S. PLLASn ACKNO%;LEDGE t~ECEIuq'~ . AHD l',u~''~U~,~'~''; ONE SIGNLD COPY OF 'ig-iiS TRANS~4ITTAL. 2.~-Z~ jA~S32'~D yF, ESSUkE BUILD-UP 08-24-85 KEPAkUK ~-2L~ Pi<ESSURE REPORT Ez~VELOPE 'EACES-ONE COPY 3C-7 03- 29-85 STATIC 'A' SAND OTIS 3C-~ 08-28-85 STATIC 'A' SAND OTiS ~Z-lu 09-0~-h~b STATIC 'A' SmjD OTIS 9';:-9 0cl-au-oA ,.:c;~zr, ':~' SA~'4D zX-I! UU-28-85 PBU 'A' SAND OTiS iQ-12 09-04-85 .... 'C' SAND CAMCO i~-5 08-17-85 PBU 'A' SAND BAKER/LYNES ....... ~v ~ S~D BAKER/LYNES =~-~ 08-1~-~D PBV 'A~C' SAND B2:~KER/LYNES RECEIPT ACKNO:-~LEDGED: DiST-q!SdTION: BPAE* DRILLING ¥~'. PAS!iER b. C6_-~klh!< L. JOHi',STON EXXON ~--':~"/:~0:~~ i,~O;~IL ~ PR" !LLIPS OIL* D & .~,~-~: NSK CLERK j. RATHMELLe DATE STA'£E OF ;~AoKA~ '"'" SOt,ilO* UNION* K'. TULIN/VAULT RETURN TO: ARCO Alaska, Inc Post Offi?'-~:ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. DATE:09-05-85 TRANSMITTAL NO:5332A **CONTINUATION KUPARUK OPEP, ATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HER5%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUR/~ ONE SIGNED COPY OF THIS TRANShITTAL. EVENTS FROM WELL SERVICE i{EPORTS/PRESSURE DATA SEQUENCE OF 2G-9 f PBU 08-22-85 2G-9r'- PBU 08-21-85 2G- 11-'" PBU 08-19-85 2G-16 -~ SB}~P 08-19-85 2h-l'- PBU 08-25-85 2h-l-' PBU 08-24-85 2U-l'" 'C' SAND PBU 08-23-85 2U-1'~ END 'C' SAND PBU & ~iISC'. 08-24-85 2W-7 "'. 'C' iSAiqD PBU 08-17-85 2W-7/ 'C' SAND PBU 08-23-85 2W-7-J~ 'C' SAND PSU 08-22-85 2X-11 ~ PBU 08-24-85 2X-ll 'C' SAND PBU 08-25-85 2X-ll/ 'C' SAND PBU 0U-26-85 3C-5 -~ BhP & M1SC. 08-29-85 3C-7-'~ BHP & MISC. 08-3 0-85 3C-8 / BHP & MISC. 08-31-85 3C-9/'- BHP & MISC. 08-09-85 3C-10 ,/'BHP & MISC. 08-10-85 KUPARUK WELL PRESSURE REPORT ENVELOPE FACES: 3C-12/ STATIC 'A' SAND 07-24-85 CAMCO 3C-10~ STATIC 'A' SAND 08-10-85 OTIS 3C-9 / STATIC 'A' SAND 08-09-85 OTIS 2Z-16-- 07-21-85 OTIS 2Z-15" STATIC 'A' SAND 07-17'85 OTIS 2Z-14-~ STATIC 07-2 0-8 5 OTIS 2Z-13" STATIC 'A' SAND 07-17-85 OTIS 2X-4'~ PBU 08-12- 85 CALICO 2X- 4~' PBU 08-13- 85 CAMCO 2U-1t 08-24-85 OTIS 2A- 13'~ STATIC 08-25- 85 CAMCO 1R-10~- STATIC 'A' SAND 08-15-85 CALICO 1R-9 / STATIC 'A' SAND 0~-14-85 CAMCO ~ECEIPT ACKNOWLEDGED: DISTRIBUTION: SPAE* DRILLING W. PAShEE B. CURRIER L.. JOHNSTON EXXON CHEVRON* ~IOBIL* PHILLIPS OIL* ~ & M* NSK CLEI{K J. RATMMELL* , ~.. ,,_- ~' ~.. / -~ DATE: ,q/,~.~e -... X ' 2.{'?.' ~ .'3.~,F, ?.. S%'AT~ OF ~ASKA* ..... v.~,.. ,,. . uf,,C./?.,.. ' -,;c "3;: SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary o1' AtlanticRichfieldCompany ARCO Alaska. Ir~ Post Offi~,%,..~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO: 5331 ttETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLE k/< ATO-1115B P.O. B~X 100360 ANCHOR3~GE, AK 99510 ENGINEEt{ING ~'KANSMITTED HERE~ITH AKL rx'HL FOLLOWING I'i'EMb. P~,EASE ACKNO%~LEDGE RECEIPT AND RETUkI~ ON~ SIGNED COPY OF THIS TkANSHITTAL. PRESSURE FINALS/ASSORTED VENDERS CAMCO 1C-4 / STAT.IC GRADILN~' 04-25-85 ' 2G-1 ~ PI{ESS UKE BUILD-UP 04-17-85 OTIb 2X-.') / FLO~ING PRESSURE 07-09-85 TOH~2UE TURN 2D-2&'/' 24 HOUR PBU 04-21/22-~5 GUAGE ~63137 LYNES / 2X-4 w' PRESSURE RE'PONT 08-12-85 DRESSER ATLAS lA-5/ PRESSURE SURVEY 08-13-85 lB-2 PRESSURE SURVEY 08-05/06-85 1Y- 2 '"" PRESSURE SURVEY 08-07-85 2C-8// PRESSURE SURVEY 08-16-85 2G-9~' PRESSURE SURVEY 08-22-85 2H-l~ PRESSURE SURVEY 08-24-85 2W-7 P~ESSURE SURVEY 08-22-85 2X-ll-/ P}{ESSURE bURVEY 0~-25-85 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE* DRILLING ~. PASHEK B. CURRIER L. JOHNSTON EXXON CHEVRON* MOBIL* PHILLIPS OIL* D & M* NSK CLERK J. RATHMELL* DATE: STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany ARCO Alaska, Inc. Post Office Boa 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 :1: l"l::: H ,S.' ,. I" L. I= ¢..~ a- E. A C I( N O W L E: D G ['£ T H 1,7 -T I':.'. A N ~: i'-'i: T' 'T A L ~ RUN RUN RUN I:;:UN I:~'. IJ N F,' U N F: LIN :::: I.'.--. C, E I F:"F A C !( N 0 k,' I... l::,r.) [; !;7 I): :,:> :l : ,:-:: ' r ,: :.: :... :".: ,5 ': .......................... .? F' A E: .r:, F;: :!: I... I... I. ~ ,...,- F'A ,: I"I i'"'" :":':E','I... I,,.J, '" E: r: I I I'::,r.;: T '"' '"' .......... ~.-,'~. I... lot ?.l ', ...... .".1 ....... , I,-.,.:. ~ (.)~,: I::XXON ,i.:'t~ .. :, I:;,'~'i~,~ ..... '-: i"iO ]'.'.'{ :~l~lCO Alaska. Inc. is a Subsidiary o, A,,i~lr[[[i[hh~;[~]~'p~[~ :[ I... t ~ ?~' BllISheffleld, IILA$~A ~lt ,4RD ~A$ ~,t~#$~lirAl'l~lW.~,DfffMl$$11~ff soo~ ~oflcUel~E DnlVE · /ELEPIIOt~E (O01t 'to,_ 4 _'A. LA- 'X}I Z/VC. RE~ I~e ~fel~ to brtn§ to your ~tlaentton that the Cor~le~lon yet received tl,e follo.t.g required ttem~ on tim ~ubJeet ~ell ~i,tch our reeord~ t'ndte~ted .~ completed .//,~_.2 ^rttcle 536(b) of Title 20~ Chapter 25, fil~ska fidmtnt~tr~ttve (Jode, ~ttpul~te~ that this m~terte! 8hall be filed ~tthtn 30 da78 ~£ter completion of a drilled.well. Please .ubmtt the above mi..trig material. Chairman lc~C.02~ ARCO Alaska, Inc. Post Office B~'~' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-11 Dear Mr. Chatterton' Enclosed is a copy of the 2X-11 Well History (Completion Details) to include with the Well Completion Report, dated 02/05/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L86 Enclosure xc' 2X-11 Well File RECEIVED APR 5 1985 AlasKa Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary ct AtlanticRichfieldCompany ARCO Alaskal Inc. .... Post Office B,., 360 '" Anchorage, Alaska 99510 907 277 5637 Telephone ,flT'T'i',l' REC, DF~:I....~)J;' CI...E:I::;K~- · i '.5 'i "", '-':-:' o. i · . ARCO Alaska, Inc Post. Office- Jx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 I:." ...: i "" '"" I. .. :" ', I I", ,.'., I:'. ,"1,-- i'i "1" 'r ::' .... I. 14' ,1'7 E: I"1 F:' '" .ti", H F:' C) "~" ]I .S' "',..T:"'.' H i::' () T .i.T ,.:'"" F;' IZ .... I:;; ' ~i'-' '"";'"' ~i'" L. '-. ..~ :.:', rl"f' "' ':" · ~ .... i. ,.':. ,?.P I"1 F'" (3 'F i!i ,?..: ,!';' ;({', I"I I':' C} l" Z ,'~; "I':': H F:' . C! 'F :[ ,'!';' ,i';' i:.: I'-I F:' :" "' -. ,.., :? B I"l F:' ,.:. I':~,'", F:' ;'~ :., '1" .,. v ,.:. ::' ,'i'.," Ii',' I"1F:' ,ii.' Ii: I'-! :" .E: I'i F:' C) T.~'" ,:.':" .? I}: I'i F:' ,"i) "f' .11,7..' ,'? E', I.-I F' C..' 'F :I: ;}7 ,? I}: I.-I F:' 0 ')" ]: ,!i.' ARCO Alaska, Inc. Post Office B~3k'""l~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 6, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-ll Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I haven't received a copy of the well history summarizing the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944.' Sincerely, d. Gruber Associate Engineer JG/tw GRU4/L130 Enclosures REC'EIVED FEB 0 8 AJaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~..~- AND GAS CONSERVATION CC~.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-164 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21188 4. Location of well at surface 9. Unit or Lease Name "r- ........... ? Kuparuk River Unit 1170' FSL, 598' FEL, Sec.4, T11N, R9E, UM iLCC/..-FiC;,jSI At Top Producing Interval i VEi~i?i~_~ ~ 10. Well Number 1292' FSL, 1250' FEL, Sec.4, TllN, R9E, UM !Surf ..... ~ ! 2X-ll I At Total Depth i B.H. ~/ i 11. Field and Pool 1337' FSL, 1465' FEL, Sec.4, TllN, R9E, UM ~ -~"J Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 112' RKB ADL 25645 ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/23/84 11/27/84 11/29/84* N/Afeet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6508'MD,6320'TVD 6403'MD,6223'TVD YES []X NO [] 1907 feet MDI 1500. (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL, GR/SP/DI L, CBL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 99' 24" 213 sx CS II 9-5/8" 36.0# J-55 Surf 3121' 12-1/4" 700 sx CS Ill & 600 sx CS II 7" 26.0# J-55 Surf 6488' 8-1/2" 306 sx Glass G & 250 s~ CS I - 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6226' - 6198' w/4 spf, 120° phasing 3-1/2" 6108' 6087' & 5825' 6186' - 6175' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6044' - 6012' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5992' - 5962' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCr WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED. Alaska Oil & i~as Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 * Tubing was run and the well perforated 01/20/85. GRU3/WC68 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30.. . · GEOLOGIC MARKERS ' ' ' "FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 5961' 5819' N/A Base Upper Sand 6046' 5896' Top Lower Sand 6157' 5997' · Base Lower Sand 6287' 6116' 31. LIST OF ATTACHMENTS We!! History (including ~_ddend,Jm)~ nyrn~rnpi~ ~,,rv~y (2 ~_npi~__~) 32. I hereby ceFtif¥ that the foregoing is tFUe and COFFeCt tO the best of my knowledge Signed ~ ~ ~~L~ Title Associ ate Engi neet Date 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 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wedrtesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submilted also when o0eralions are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Spudded or W.O. begun Complete 1/18/85 Accounting cost center code Districl County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit Well no. Kuparuk River ADL #25645 gX-11 Auth. or W.O. no. T t e AFB 304301 Completion Roll'N #4 API 50-029-21188 Operator I A.R.Co. W.I. ARCO Alaska, Inc. 56.24% I Date Date and depth as of 8:00 a,m. 1/17/85 1/18/85 1/19/85 thru 1/21/85 Did TD :Complete record for each day reported Released rig I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prior status if a W.O. 0000 hrs. I 7" @ 6488' 6403' PBTD, 6508' TD, Wait on weather 10.0 ppg NaC1/NaBr Standby w/crews. Wait on weather. 7"@ 6488' 6403' PBTD, 6508' TD, NU shooting flange ~ ~.--~.~ 10.0 ppg NaC1/NaBr ~¥'...~ Accept ri~ @ 0000 hrs, 1/18/85. ND wellhead, NU & tst BOPE. Instl adapter flange on annular preventer. 7" @ 6488' 6403' PBTD, 6508' TD, RR 7.2 Crude oil Perf'd w/4" guns, 4 SPF, 120° phasing f/6226'-6198', 6186'-6175'. Perf'd w/5" guns, 12 SPF, 120°, phasing 6044'-5962'. RIH w/pkr & tailpipe assy. RIH w/3½" EUE, 9.3#, J-55 tbg & ind. Set pkr, set BPV, ND BOP, NU tree & tst. Displ well over to crude oil. Tst SSSV, set BPV. RR @ 1030 a.m., 1/20/85. Rig on standby-w/crews, waiting on weather. FB-1 pkr @ 6087' - D-Nipple @ 6101.39' - TT @ 6108' (186 jts, 3½" rn) New TD Date 6508' PB Depth Kind of rig 6403' PBTD 1030 a.m. 1/20/85 Rotary Type completion (single, dual, etc.) Classifications (oil, gas, etc.)Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potenlial test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and di-st;i'~u~on, see Procedures Manual, Section 10, Driltlng, Pages 86 and 8~. Drilling Superintendent 1 ARCO 011 and Gas Company ,~, Well History - Initial Report - Daily procare end ~ubmlt the ?.lnlfll.I ~,~.?-.rt" on the .first. Wed~.~iday after a well is spudded or workover operations are started. Inlln~elioaa.' Dally won prior to alxlaa ng anoula De summarizes on the form giving inclusive dates only. District ICounty. parish or borough Alaska I North Slope Borough Field I Lease or Unit Kuparuk River I ADL Auth. or W.O. no. ITItle AFE 304301 I Drill IState Alaska IWell no. 2X-11 Nabors 26-E API 50-029-21188 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnSpUdded IDate 11/23/84 IH°ur 0030 hrs IPri°rstatusifaw'°' Date and depth aa of 8:00 a.m. 11/26/84 11/27/84 11/28/84 11/29/84 RECEIVED FEB 0 8 1985 Alaska Oil & Gas Cons. C0mmk A n r, h r~ ~.,.-, ~ ,-, 56.24% Complete record for each day reported sion 9 5/8" @ 3121' 4875' (1725') Drlg : Wt 9.2, Pv 12, Yp 13, Ph 10.5, W1 10.8, Sol 9 Move rig to 2X-11. NU diverier. Accept Rig 1830 hrs 11/22/84 PU BHA & test diverter -OK. Spud 0030 hrs 11/23/84 Drld 99'-3140'. 16 STD st. C&C. POH. RU & run 78 jts 9 5/8" 36# J-55 HFERW BTC 686 w/FS @ 3121' & FC @ 3039: C&C. CMT w/700 sx coldset III @ 12.2 ppg & 600 sx coldset II @ 15.3 ppg. displ w/230 bbls mud. Bump plug w/1500 psi OK. CIP 1030 hrs 11/24/84. ND Diverter. NU csg head & BOPE. Test BOPE, OK. PU BHA & GIH, TAG FL @ 3038'. TEst csg to 1500 psi OK. Drld FC, FS & form to 3150'. Perform LOT+12.9 ppg EMW. Drld 3150' - 3650'. Trip for new BHA & Navl drill drld 3650'- 4875'. 800' 0.8° 1984' 1.5° 3100' 1.0° 4108' 5.1° 4296' 11.6° 4483' 17.2° 4576' 20.8° 4795' 25.6° N62.5W 4107.86TVD 4.62VS 2.22N 4.26W N71.5W 4293.41TVD 33.67VS 13.23N 31.68W N73.5W 4474.82TVD 78.42VS 27.11N 74.53W N76.5W 4562.74TVD 108.63VS 34.94N 103.77W N78.5W 4763.89TVD 195.05VS 54.26N 188.03W 9 5/8" @ 3121' 6160' (1285') Drlg Wt I0.0, Pv 21, Yp 11, Ph 9.0, WI 5.4, Sol 10 Drld 4875'-5905' trip for new BHA wash 5870'-5905' 5299 26.1° N80.5W 5219.07TVD 411.40VS 5820 24.5° N84.5W 5689.78TVD 634.24VS Drld 5905'-PD. 99.22N 399.68W 129.16N 620.92W 9-5/8" @ 3121' 6508' TD, (348'), Rm'g Wt 10.0, PV 16, YP 11, PH 10.5, WL 5.4, Sol 10 Drl 6160'-6508', circ,.12 std short trip, POH. RU & log GR/SP/DIL/SFL f/6472'-3118', CAL/FDC/CNL f/6472'-5700' & 5100'-4000'. Stage in hole, precautionary rm 6225'-6351' 7" @ 6488' 6403' PBTD, (0'), Tst'g packoff 10.0 NaC1/NaBr Rm to 6508', POH, LD DP. RU & rn 158 its, 7", 26#, J-55 HF-ERW BTC csg w/FC @ 6403', FS @ 6488'. C&C. Cmt w/306 sx Cl "G" w/3% KCl, 0.7% D-19, .3% D-31 & .1% D-6 @ 15.9 ppg. Displ w/10.0 ppg brine. Bump plug w/3000 psi; OK. CIP @ 2330 hrs, 11/28/84. PU BOP & set slips. Cut csg. ND BOPE. Instl packoff. NU tbg spool & tree & tst. Signature For fo~m preparation an~'~dlstrlbutlon, see Procedures Manual, ~ectlon 10, Drilling, Pages 88 and 87. ~,:~_ ~___.j~ Date J Title 12/04/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Finel Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation it space is available. North Slope Borough IAccounting cost center code State Alaska District I County or Parish Alaska Field Ihease or Unit Kuparuk River I ADL Auth. or W.O. no. I Title AFE 304301 I Drill Nabors 26-E API 50-029-21188 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 11/23/84 11/30/84 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this Well our . I Prior status if a W.O. 0030 hrs Date and depth as of 8:00 a.m. 7" @ 6488' (0') 6403' PBTD, ()'), RR 10.0 NaC1/NaBr ADC: $617,981 Fin tst'g pack-off & tree to 3000 psi; OK. 11/29/84. Old TD INew TO 6508 ' Released rig I Date 0700 hrs 11/29/84 Type completion (single, dual. etc.) Classifications (oil, gas, etc.) Oil RR @ 0700 hrs, P'£C£1V£o Alaska Oil & ~ Gas Cons. Cornrnissin. ~nchorago -.. PB Depth 6403' PBTD l Kmd of ~g Rotary Single Producing method Official rese~oir name(s) Flowing Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production __ Oil on test Gas per day _ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature /~ [Date ~,J~,,~/~.~~ _JV't.~)~l 12/04/84 F~r form pro~ar;tiodand distribution, ~" ' see Procedures Man~al, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 12/10/84 12/11/84 2X-11 Arctic Pak w/250 sx CS I, followed by 53.5 bbls Arctic Pak. 6403' PBTD Rn CBL f/6370'-3100'. Rn gyro f/6350'-surf. Drilling Superintendent RECEIVED Alaska Oil & Gas Cons. Commission A/~chorage · Date $ UB-$ URFA CE DIRECTIONAL SURVEY F-~ UIDANCE · ~'~ ONTINUOUS Company ATLANTIC RICHFIELD COMPANY Well Name 2X-11 (1170' FSL, 598' FEL, S4, T11N, R9E, UM_)_ Field/Location 'KUPARUK. NORTH SLOPE. ALASKA Job Reference No. 69988 Lo::ed By: LES~!IE REC£1v£b P E ~ 0 8 ~985 Oil - &,Gas Cons. Commission ~nChorao~ Date 25-JAN-85 CompUted By: STEVENS GCT ,,.31'RECTII;NAL SURVEY CUSTD~ER LZSTZNG F~R ARgO ALASKAe, INC. 2X-11 KUPARUK NORTH SLi:JPE~p ALASKA, SURVEY DATE::' g-DE'C-8~. ENGINEER: LESN[E NETHOD$ OF COMPUTATION TOOL LOCATION: TANGENTZAL- AVERAGED DEVXATXON AND AZXH,UTH INTERPDLATZDN: LZNEAR VERTICAL SECTION: HO.RIZ. DZSTo PROJECTED ONTO A TARGET AZZNUTH .OF NORTH.:'7~ DEG 59 HZN WEST ,RCO ALASKAs ZNC. LX-11 ;UPARUK I~RTH SLOPEs ALASKA TRUE SUB-SEA COURSE ~ASURED VERTICAL VERT.KCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MXN DEG MZN COMPUTATION DATE: 23-JAN-8'5 PAGE 1 DATE OF SURVEY: 9-DEC-ti4 KELLY BUSHING ELEVATION:~ ,112.00 FT . ENGZNEER: ZNTERPOLATED VALUES FOR EVEN ~OO FEET OF MEASURED DEPTH ~ERTZCAL DOGLEG RECTANGULAR CgOROZNAT~S ~gRZZ. OEPAR~URE SECZZON SEVERITY NORTH/SQUTH EASIJWEST OIST. FEET OEG/~O0 FEET FEEZ FEET DEG 0000 0.00 -112000 0 0 N 0 0 100.00 100.00 -1 ?.. O0 0 10 S 7 3 200°00 200.00 88.00 0 13 S 3 7 E 300.00 300.00 188.00 0 10 S 400°00 400.00 288.00 0 22 S 54 30 id 500000 499.99 387.99 0 36 $ 600.00 599.99 487.99 0 35 S 32 41 700.00 699.98 587.98 0 34 S 36 52 id 800.00 799.98 687.98 0 39 S 48 56 bi 900000 899.9'7 787.97 0 48 S 47 43 id 0 54 S 45 0 56 S 46 41 id 0 46 $ 51 30 id 0 ¢5 $ 53 34 id 0 43 S 59 47. Id 0 34 S 63 56 id 0 27 S 7.0 O id 0 8 S 37 10 E I 12 N 71 18 E I 6 a 73 41 E L000000 999096 987.96 1100.00 1099.94 987.96 LZO0. O0 1199.93 1087.93 L30.0o00 1299.92 1187.92 14'00.00.. 1399.91 1287.91 1500.00 1499.91 1387091 t600.O0 1599.90 1487.9:0 1700.00 1699090 1587.90 L800.00 1799.89 1687.8'9 L900000 1899.87 1787.87 N 80 53 E S ~8 32 E S 75 10 E S 65' 47 ~ S 64 SZ E S 66 35 E S 68 68 ~ S 71 49 E S 78 /,8 E S 72 37 E ?. O00. O0 1999.85 la87o85 I 31 1100'00 2099.81 1987081 I 62 2200o00 2199.77 2087.77 I 7 13:00.00 2.299075 2187.75 I 6 ~:400..00 2399°73 2287.73 I 9 2500000 2699071 2387.71 I 1.3 Z600.O0 2599o69 2687069. i 22 1700000 Z699.66 2587.66 ! 10 :~8~00.00 2799o64 2687.64 I 5 ~900.00 2:899.63 2787.63 I I O 59 0 52 0 35 0 29 0 24 0 23 0 29 0 37 0 36 0 39 $ 72 5,8 E S 1'8 16 E S 61'42 E S 66 4~1 E S 43 35 E S 37 36 E S 42 37 E 520 8 E S 11 5~ E S 4 53 id 3000.00 2:999.61 2887.61 3100.00 3099.60 2987.60 3200.00 319'9o59 3087.59 3300.00 3,?.99.58 318'7.58 3400.00 3399.5a 3287.58 3500'00 3699.58 3387058 3600.00 3599.58 3487058 3700000 3699.5'7 3587.57 3800.00 3799.57 3687.57 3900000 3899056 3787.56 0000 0000 0.00 N 0.00 ~, -0.02 0.11 0.11 S 0.00 W -0o10 0.10 0049 S 0.01 E -O.ZO 0.22 0086 S 0.03 E -0.01 0.30 1.14 S 0.12 id 0054 0.10 1.77 S 0.89 .id 1.03 0.07 2.60 S 1.56 g 1.41 0.22 3.47 S 2.11 id 1.96 0.20 4.20 S 2.82 w 2077 0.16 5..06 S 3.81 W 3.63 0.09 6.10 S 4.56 0.08 7020 S 5.47 0.30 8023 S 6033 0.36 900.6 S ?o23 0.12 9.73 S 8.11 0.22 I0.27 S 8.92 0066 10071 S 9023 0.52 10094 S 8028 0.49 10.69 S 6.~4 0.04 10.05. S 4.49 0.91 9.44 $ 1.61 '0.32 9.35 S -0064 0.:64 9.61 S -2.72 0.30 10.27 S -4.65 0o34 11.12 S -6069 0.10' 11.98 5 -8085 0039 12082 S -11.15 0.40 13.59 S -13009 0.46 14.08 S -14.89 0.12 14052 S -16.60 0.13 15010 S -18.22 0.05 15-54 $. -19.52 0.14 15'86 S' -20.41 0.78 16.31 S -21002 0.12 1.6o79 S -21.58 0.17 17.26 S -22015 0027 17.86 S -22075 0.31 1.8.61 S -23.30 0.83 19067'S -23 °48 0o17 20.7'9 S 4089 W 6..05 W 7.1t' id 8.,7.2 d' 9.26 W 11.17 id 11.53 W 10.52 W 8.61 W 6'o42 W. 3.46 W, 1.02. W 2.57' E 4.49 E 6.52 E 8-71 E 10.60 E 12.33 ~ 13097 15~5'3 16.80 17,62 18.14 18.63 19.,0 9 19.56 19.91 19.8Z' E 0.11'-.,.S .0 1"/ W lo16 :~S I0 45 W 1.9'8 $ Z6 47 3.03 S 30 55 id 4.06 5.0,6' S 33 49 6.33 708Z S 38 41 W 9~41 S 40 I w 1.0o. 92 S 41 4 W 12.23 S 42 12 W 13.43 S 43 3~ W 14.52 .S 44 $'8W 15.47 S. 46 12'W 15.89 S 46 31 W 15.,00 S 46 31'W 13o, 23 S 40 36 .W 11.42 $ 34 II W. 9.96 S ZO 18 W 9.66 S 6 2 w lO.3o s 4 12 ~ 11.42 s 13 0 E 12.7~. s 2o 3t,~ 14.36' s 26; 5'8 E 16".15 s 32 39 ~'/ 17.62 S 36 58 ~k~ ~-o.~' s 4o t3 E 2°.5; s 4z 47 ~ Z1.97 S 44 59 E 23.z0 s 46 38 E' z4.0t s 4'z tz ~ 24.72 S 47 22 E': ,z6,.~4 s ~6 55 ~:' 27.,o0 s 46 25 ~ 27".99 S 45 Zl E COHPUTA'TZgN DATE= Z3-JAN-85 PAGE ARCO ALASKAt ZNC. ZX-ll KUPARUK NORTH SLOPEr ALASKA DATE OF SURVEY= 9-DEC-84 KELL~ BUSHZhiG ELEVATZON: ENGINEER= LESN[E' 112.00 FT_. XNTERPOLATED VALUES FOR EVEhi 100 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE EASURED VERTZCAL VERTZCAL DEVZATZON AZIMUTH DEPTH DEPTH DEPTH DEG HZN DEG HZN VERTTCAL DOGLEG RECTAhiGULAR CI3DRDXNATES H~3R:[Z.,, DEPARTURE SECTZON SEVERXT¥ NORTHISOUTH EAST/WEST DZST. AZZHUTfl FEET DEG/IO0 FEET FEET FEET OEG NZN 4000°00 399'9.55 3887055 0 36 4100.00 4099°48 3987.48 3 56 4200°00 4198077 4086.77 8 59 4300.00 429T.12 4185.12 11 20 4400.00 4394079 4282.79 13 41 4500.00 4490094 4378.94 17 38 4600°00 4585.13 4473.13 21 0 4700000 4677.82 456508Z 23 31 .4800000 ~768.79 4656079 25 13 4900000 4859.18 4747.18 25 11 S 6 I W -23.68 1.17 N 66 4 W -20.89 4.27 N 64 48 W -9.67 4.02 N 69 7 b 8°03 2086 N 71 24 W 29.26 4.83 N 71 59 b 56.36 4.72 N 74 19 W 89.74 2.06 N 74 57 M 127.18 3020 N 76 18 W 168060 lo69 N 7? 8 W 211.34 0.7'9 21.95 S 19.85 E 29°59 .....S &Z 7 E 21047 S 17.10 E 27o4~ ':;$ 38 32 E 1b.45 S 6.65' E 17074' ~ 22 I E 9.47 S 10002 id 13.T9 S 46 36 N 2.54 S 30.31 ~ 30.42 S 85 12 ~ 6.55 M 56.I4 M 56.52 N 83 20 , 16.03 N 88.30 b 89.74 N 79 42 b 25.86 N 124.53 ~ 12T-19 N 7~ 1~~ ~ 36.45 ~ 164.b7 ~ 168066 N 77 31 46.07 M 206.3~ d 211.42 N 77 24 W 5000000 4949.78 4837.78 24 59 5100.00 5040.41 4928041 24 57 5200.00 5130.56 501a.5,6 26 27 5300.0.0 5220.14 5108.14 26 6 5400000 5310.02 5198002 25 52 5500.00 5400.13 5288013 25 36 5600°00 5490.43 5378043 25 18 5700.00 5581.01 5469.01 24 49 5800.00 5671094 5559094 24 20 5900.00 5763011 5651.11 24 '9 253.66 0.21 295.88 0.19 339014 1.02 383.57 0.54 427.39 0.58 470.73 0.49 513.66 0.34 555.9g 0 . 6i 597.55 0.49 638054 0.5{) 55.52 N 247.62 id 253*77 hi 77 64.91' hi 288.79 Id 296.01 N. 7~' 19 Id 73061 N 331.18 d 33g.26 N IrT Z8 id 81.00 N 375.00 id 38.3.65 N 7T' 48 id , 88.10 N 418.26 i~' 42T.44 N T~ 6 W' 94.96 N 461.08 . 4T0.,76 N 78 21 Id 101.43 'N 503.56 a 513.67 N 78 36 W 107.49 N 5,~5.50 W 555.99 N 7~. 5I W. 113.19 N 566.75 W 591'.55 N 79 4 W 118.64 N 627.43 W 638055 N 1'9 17 W 6000°00 5854010 5742.10 24 55 ~6100.00 5944.76 5832.76 24 47 6200°00 60,35.86 5923066 23 52 6300.00 6127.62 6015,.,62 22 50 6400.00 6219091 6107091 22 36 6500000 6312.22 62'00.22 22 36 65.08000 6319061 6207.61 22 36 N 79 25 W N 79 35 W N 78 39 W N 77 23 W hi 76 28 Id N 7626 W .N 76 28 w 67'9.99 0.62 722019 0.67 763.42 0.,.91 a03.16 1.72 841.65 0.00 880.06 0.00 ,683.13 0.00 125.2~ N 668.3~ W 680.01 N 79 22 id, 133002. N 709'.86 W 722.21 N 79 23 W' 140.74 ,N, 750.35 id 763.44 # 79 22 b 148.77 a 789-26 W 803.,2Z N 79 X9 W 15"7.68 N 826.75 W 841.65 N 79 X2 ~ 166.6'7' N 864.13 W 880.06 N. ~'~ 4 W Z6~.39 N 867.22 ~ 883.25 N ~9. · ~ ( ~RCO ALASKAt INC. IX-11 ~UPARUK WORTH SLOPEr ALASKA COHPUTATZQN DATE: 23-'JAN-S5 DATE OF SURVEY:' g-DEC-.~4 KELLY BUSHING ELEVAT[ON:~ ENGLNEEE: LESNIE INTERPOLATED VALUES FOR EVEN 1000 FEET OF HEASUREO OEPT PAGE TRUE SUa-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG HZN DEG M~N 112.00 FT 0.00 0.00 -112.00 0 0 1000.00 999.96 887.96 0 ZO00..O0 1999o85 1887.85 3000.00 2999.61 2887.61 0 59 4000.00 3999.55 3887,,55 0 36 $000o00 4949.76 4837.78 2.4 59 6000°00 5854.10 5742o10 24 55 6508.00 6319.61 6207o61 22 36 VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET D.£G ~ZN N 0 0 E 0.00 0.00 S 45. I sd 3,.63 0.09 N 80 53 E 4.49 0.91 S 72 58 E -16.60 0.13 S 6 ! W -23.68 1.17 N 77 7 W 253.66 N 79 Z5 id 679°99 0.62 N 76 28 ~ B83.13 0.'00 0.00 N 0.00 E O.O0,-,# 0 0 E 6.10 $ 4.89 sd 1'.8Z':, S 38 41 bt 9.44 S 6.42 ~ 11.,~2 ',,.S 34 11 ~1 15.10 ,5 13.97 E Z0..51~ '"$ ~2 47 E 21.95 S 19.85 E 29.,$9 S ,~Z 7 E :~5.5Z N 247o6Z kl 2.53.77 I~ ~7 21 ~1 1,?.5.28 M 668.36 ~ 680.01 N 79 22 ~ 167.39 f~ 867.12 ~ 883.13 N *~:9 4 ~[ CDHPUTATTON DATE.: ,?.3-JAN-85 PA, G£ 4 " ARCO ALASKA. INC. 2X-11 KUPARUK NORTH SLOPE. ALASKA DATE DF SURVEY: 9-DEC-84 KELLY 8USHZNG ELEVATION: ENGINEER: LESNIE 112.00 ~T.. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUS-SEA DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTZCAL DEVIATXON AZINUTH DEPTH DEPTH DEPTH OEO NZN D~G VERT£CAL DOGLEG RECTANGULAR CI30RO_TNATES HDRXZ. DEPARTURE: SECTXON SEVERITY NORTH/SOUTH EAST/MEST DIST, AZZHUTtl FEET DEGY'IO0 FEET FEET FEET OEO 0.00 0.00 -112.00 0 0 N 0 0 E 12.00 12.00 -100.00 0 I N 33 55 E 112.00 112..00 0.00 0 11 S 8 5 E Z1Z.O0 212.00 lO0.O0 0 13 S 3 49 i 312.00 312.00 200.00 0 9 S 12 35 ii 4.12.00 4.12.00 300.00 0 25 S 52 57 id 512.01 512.00 400.00 0 36 S 41 5¢ ii 612.01 612.00 500.00 0 35 S 32 5 id 712.02 712.00 600.00 0 33 S 38 3¢ Id 812.02 812.00 ]'00.00 0 40 S 49 38 ii 0.00 O.O0 0.00 0.00 0.02 0.00 N 0.00 E -0.03 0,,12 0.15 S 0.01 E -0.11 0.09 0.54 S 0.01 E -0.20 0.2.4 0.90 S 0.03 E 0.05 0.49 1.18 S 0.28 Id 0.60 0.10 1.86 S '0.98 1.08 0.09 2.70 S 1.62 W 1.46 0.14 3.56 S 2.18 Id 2.05 0.16 4029 S Z.9Z rd 0.00, 0.00. 001~ ** $ Z' 5 E O. 54 0.90 S I 4,4 E 1.22 S I3 24 2.10 S 3.I5 S' 30 58 ~. 18 S 3~ 32 5.I9 S 34 13 912.03 912.00 800.00 1012.05 1012.00 900.00 1112.06 1112.00 1000o00 1212.07 1212.00 1100000 1312.08 1312.00 1200.00 1412.09 1412.00 1300.00 1512'09 1512.00 1400.00 1612.10 1612.00 1500.00 1712.10 1712.00 1600.00 1812.11 1812.00 1700.0'0 056 S 47 5 W 0 46 S 52 3 N 0 43 S 55 4'1 Id 0 44 S 60 9 Id 0 35 S 63 4.7 W 0 2;, S 72 Z Id 0 10 S 60 15 ~ i 13 N 70 23 E 2.87 0.16 5.17 S 3.93 ld 3.74 0.13 6.2.4 S 5.02 Id 4.68 0.,10 7.34 S 6.20 id 5.58 0.12 8.33 S i'o30 Id 6.44 0.33 9.15 S 8.34 Id '3~.35 0.06 9.81 S 9.39 ii 8.21 0.24 10.32 S 10.3~ ii 8.99 0.38 10.73 S 11.25 il 9.21 0.91 10.95 S 11.51 ii 8.05 0.23 10.,61 S 10.27 W 6.50' S 37 13 ii 8.01 S 38, 5:0'W 9o. 61 S 4,0 10 .rd 11.08 S 41 I4 W , 12.38 $ 42 2,2,W 13..58 S 4.3 45 rd 14.63 S 45 8 W 15.55 S 46 ZO ii 15.89 S 46 25 W 1,4.,)'6: S 44 4 W 1912.o13 1912.00 1800.00 2012.16 2012.00 1900.00 2112020 2112.00 2000.00 2212.23 2212o00 ZXO0.O0 2312.25 2312.00 ZZO0.O0 2412.27 2412.00 2300.00 25,12029 2512.00 2400.00 2612.32 2612.00 2500.00 2712.34 271'2.00 2600.00 2812.3:6 2812.00 2700.00 I 8 N 73 5 E I 36 N 84 31 1 38 S 88 10 I 5: S 73 3 I 7 S 6522. 1 11 S 65 28 I 12 S 66 35 1 ZZ S 69 66 I 8 S 72 30 I 3 S 17 33 6.33 0.43 9.98 S ,4.18 1.22 9.40 S 1.25 0.75 9.35 S -1.07 0.53 9.67 S -2.95 0.19 10.37 S --4.89 0.24 11.23 S -6.95 0.14 12..08: $ -9.15 0.31 12.93 S .11.40 0.16 13.67 S -13.33 0.84 14.12 S 8.39 W 6.09 W 3,.10 td 0.79 :W 0.99 E 2.80 E 4.72, E 6.80 E 8.95 E 10.83 E 13.04 5 40 .2 W 11.20 S 32 56' W' 9.85 S 9...70, S 4. .40 W 10.41 S 5 2.6 E 11.,,57 S 13 59 2912.38 1912o00 2800.00 3012o39 3012.00 2900.00 3112o4*0:3112.00 3000.00 3212o4.1 3212.00 3100.0'0 3312.42 3312.00 3200.00 3412.42 3412.00 3300.00 3812.4*2 3512.00 3600.00 3612.4.2 3612.00 3500.00 3712o%3 3712.00 3600.00 3812.44 3812.00 3700.00 I 1 S 72 40 E 0 5,8 S 72 47 i .0 52 S 78 19 E 0 26 S 57 56 E 0 24 S 44 23 E 0 24 S 36 4 E 0 30 S 46 33 ~ 0 37 S 20 57 E 0 36 S ,3 40 E -1~oll 0.12 14.64 -16.82 0.25 15016 -18.41 0.12 15.57 -19.64 0.35 15.92 -20.51 1.19 16.35 -21.09 0.11 16.85 -21.64 0.09 17.33 -22.24 0.3'~ 17093 -22.83 0.27 18.74 -23.35 0.94 14,18 15.72 16..9! 17.*/1 18.20 18.68 19.61 19.19 S, 19.93 E I9.2,5 S 4,0' 35 E. 2'2..13 S .45 ~5: E 23-23 S 46 43 24.1:0 S 4IL' 17 i 24o81 S. 4*Z' 12 E 25.4& S 47 ~ E 26*25 S 46 5,4 E 27,.1'2 S 46 17 E 28.09 $ 45 11 E ARCO ALASKAt ZNC. 2X-ll KUPARUK NORTH SLOPEs ALASKA CDMPUTATTON DATE:' 23-JAN-85 DATE OF SURVEY: 9-DEC-84 KELLY aUSH[NG ELEVATION: ENGINEER: VALUES FOR EVEN ~00 FEET OF SU~-SEA DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DE¥IATION AZZNUTH DEPTH DEPTH DEPTH OEG gin DEG HZN 3912o44 3912.00 3aO0oO0 0 40 4012.45 4012o00 3900000 O 34 4112.54 4112.00 4000000 4 29 4213.40 4212.00 4100000. 9 33 4315.19 4312000 4200000 11 42 4417074 ~412000 4300.00 14 38 4522o16 4512o00 4400.00" 18 38 4628.82 4612.00 4500000 21 31 4737044 4712.00 4600.00 24 18 4847.80 4812.00 4700000 25 19 S 5 8 111 S 24 7 id N 64 33 id N 65 35 id N 69 52 id hi 70 44 id N 77 ,~ id 49580]0 4912.00 4600.00 25 3 5068.65. 5012000 4900.00 25 0 5179.27 5112.00 5000000 26 12 5290.93 5212.00 5100.00 26 9 5402°20 5312000 5200.00 25 51 5513017 5412000 5300,000 25 33 5623085 5512.00 5400000 ZS 11 5734o13 5612.00 5500000 24 40 5843.96 5712000 5600000 24 26 5953°63 5812.00 5700.00 24 32 PAGE 112o00 FT. 6063°88 5912.00 5600.00 24 57 6173088 6012o00 5900000 24 7 6283°04 6112.00 6000.00 23 3 6391o44 62120'00 6100o00' 22 36 ,6499.o76' 6312.00 62:00000 22 36 6508°00 6319.61 6207,61 22 36 N 79 28 id N 78 52 id ld 77 52 ~d N 76 28 e N 76 28 id N 76 26 ~ VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY laORTH/SOUTH EAST/gEST DZSTo AZIMUTH FgET OEO/lO0 FEET FEET FEET DEG PIZla -23.49 0.25 20093 S 19086 -23068 2.18 ZZ.07 S 19.&3 -ZO.O0 ~.61 21o08 S 16027 -7.58 4.67 ' 15.54 S 4.70 11.02 3.2! 8.41 S 12.87 33.50 6.45 1.18 S 34.36 63°20 4.94 8.60 N 62072 100.15 1.66 142.39 1.58 189.01 0.42 18082 N 98.37' id 100015. N 79 10 29.83 N 139o26 id 142042 41.09 N 184.56 W 189.08 236.02 0.31 282065 0.31 329,92 2.37 379.58 0.65 42a.35 o.59 476.42 0.51 ~23.83 0.69 570.25 0.45 615059 0032 660057 2.00 706.99 .0.33 752.a0 1.03 796.55 1.64 838.36 0.00 879.96 ,0.00 a.83.13 0.00 130.26 N 694°90 ~ 707.00 N' 79 ZZ~ 138.6~ N 739.94 id 752.,,82 N 19 23 ~ 147.36 N 762.82 ~ 796.56' N 79 20' ~ 156.91 ~ 823.55 ~ 838.36. N Z'9 ~2 ~ ~RCO ALASKAt INC. ZX-11 KUPARUK NORTH SLOPEr ALASKA HARKER TOP UPPER SAND BASE UPPER SAND TOP LONER SAND BASE LOklER SAND PBTO TOTAL DEPTH COMPUTATZDN DATE: PAGE DATE OF SURVEY.' ~ELL¥ BUSHiNg ELEVATION: llZ.O0 F~., ENGINEER: LESNZE INTERPOLATED VALUES FOR CHOSEN HORIZONS HEASUREO DEPTH BELO~ KB SURFACE LOCATZO~ ~T" ORIGZN= llTOa FSLt 5~8' FEL~ SEC ~e TZ~ R~.E, UM ~VO R~CTANGULAR COORDZ#ATE S FROM KB SUB-SEA NORTH/SOUTH -,,EA$1t'MEST 5961.00 60~6.00 615T.00 6287.00 6A03.00 6508.00 5818o70 5'/06.70 5895o'1'9 5783.79 5996°60 5884.°60 6i1.$o65 6003.65 6Z22. o68 6~,1.0o6~ 63~.9,61 6202.61. 137.3~ N ~33o14 ~ ~47.68 N ~84.33 ~ 167.39 N 86~'o12 a ,." ARCO ALASKA. INC. 2X-11 KUPAR~K NORTH SLOPEr ALASKA MARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOMER SAND PBTO TOTAL DEPTH COMPUTA'T[ON DATE: 23-JAN-~5 PAGE 1' DATE OF SURVEY: 9.-DEC-84 KELLY 8USHXNG ELEVATXDN:~ FI'.. ENGINEER: LESNIE ************ STRATIGRAPHXC MEASURED DEPTH BELOW KB 5961.00 6046.00 6157.00 6287.00 6403°00 6508.00 SURFACE LDCA'TION ORIGIN= 1170' FSLp 598' FEL'. SEC 4. T11Nm, Rg~s UN TVD RECTANGULAR COQIID,XNAT ES FROM KB SUB-SEA NO RT Ht SO UT N:, :,i ~; E~$t~fIE ST 5818o~0 5706.70 122.38 N 5895.79 5763.79 128.87 Pi 5996.60 5884.60 137.34 N 6115.65 6003.65 1~7.68 N 6222.68 6110.66 157.95 N 827.87 6319.61 6207.61 167.39 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6,508.00 6319.61 6207.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 883.13 N 79 * ~ SCHLUMBERGER ARCO ALASKA, INC. P'X- il 1 KUPARUK NORTH SLOPE, ALASKA DECEMBER 9, !984 TVN PLOT FROM OCT DATA JOB REFERENCE 69988 SE WELL: 2X-11 o SURFACE LOCATION: 1170' FSL, .598' FEL,-S4, T11N, RgE, UM VERTICAL PROJECTION -600 -400 -21:10 0 0 200 400 600 800 -i-'-:. i i ~ ~ ;" I .~ ~ .~ ..'!-:'!-'f,- ~ ! i i 1 ~ i i i i ~ ~ ..' ~ .: ~ ~71~-1-..~.?-%~-f.-?-?~-F-f~1-:~?~`1~T~1~?~-T~T~T~?~?-?~:~ ..... I-'!'"T"?'"T'"I"T"T"! 4--4~ ~ i t ~ ~ ~ ~ I ; ~ ~ ~ , i '.. i i' ~ ' : i ~ '~i f I ~ i i !.~'.. lfi~' -'- ~ ~' ' ~+--+-e~i-:~+-1.-i-~+~+-~-~+~+~;~?`+~-~:~+~+~+~e-e~-1~--:~+~:~ .--+-..+-.-t---~;: :1 ..... ~'+";~'"" · -..~-e-,:-.-.~ ;- :. -.'- :- -~.~.+~ : i i i '.; :: :. :.-+-~-.~~--~.~-+-+-. -.'--++'-+-~-'+-.~:-+-'"~-+"':'":-1'-~--':"'*."1 ...... ':-'.~'".~"'~'" ";f'",~"+"?' ...... :"Z'+".~'" -.;*+i ! !i i i. {i i i, i ii i i i, ....... -~r-- ~--.?"--~.. '..~ :-I-~:' --~.-'t' i il i i i i ii i [~.- --F.'~---'~: : : :'T--~.--?'"I-I'""~.-"'t-%'I-"~F:'~:'-I'":~'' "I-?--T'"T'"i-T"~'~-T ...... T-T"?"'I"'""T-'I"T"T ....... 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Reports and Materials to be received by: Required Date Received Remarks · ~ , · · ....' · Well History Yes 6:~-~r'-~r "./~,..,/-/-~ · _Samples . ' _ ,., h,a--P~ - xr/¥ . "ua · Core Chips '' /~d~' " ' ' .... ~ K ' · , ,.. _ · Core Description ~d~' ........ --__ ((,~ -'-' · . Registered Survey Plat Inclination Survey , _ · ~Directi°nalSurvey y~.-'PI ~2 -dg -¢.r~ r ,/_~.?L.,~. -- Drill Stem Test Reports ,, , Digitized Data · · , · Post Office B"", 360 Anchorage, ~,..,~ka 99510 Telephone 907 277 5637 Date: 1/03/85 Transmittal No: 4949 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ' ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ... OH LIS .Schlu~:beTg~K- · -.~ ,. _. · #69826 2W-9 '~ 12/01/84 3522 - 7935.5. o. Run 1 #69827 2D-14~/'11/30/84 Run 1 3871.5-8314 #69823 2X-11~/il/28/84 Run 1 3078.5-6492.5 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Date: ~. ~ ~?,a .yillfng W. Pasher .. 'State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary ot AllanticRichfieldCompany ARCO Alaska, I Post Offi'~'e~Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 11, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the November monthly reports for the following wells' 2D-14 2W-5 2X-11 2D-15 2W-6 2X-12 2D-16 2W-7 2X-13 2E-14 2W-8 15-9 2E-15 2W-9 Also enclosed is a Well Completion Report for 2B-14. any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer If you have JG/tw GRU3/L03 Enclosures RECEIVED AJaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary ol AtlanllcRichfieldCompany STATE OF ALASKA ' ALASKA O,.~AND GAS CONSERVATION COk_.ilSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-164 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21188 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 1180' FSL, 601' FEL, Sec.4, T11N, ReE, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 112' RKB, 77' PadI ADL 25645 For the Month of November ,19 84 10. Well No. 2X-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0030 hfs, 11/23/84. Drld 12-1/4" hole to 3140'. Ran 9-5/8" csg. Drld 8-1/2" hole to 6508'. Ran OH logs. Ran 7" csg. Secured well & RR @ 0700 hrs, 11/29/84. 13. Casing or liner rgn and quantities of cement, results of pressure tests 9-5/8" 36.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 3121'. Cmtd w/700 sx CS III & 600 sx CS II. 7" 26.0#/ft, J-55, HF-ERW BTC csg w/FS @ 6488'. Cmtd w/306 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/SP/Cal/FDC/CNL f/6472' GR/SP/DIL f/6472' - 3118'. - 5700' & f/5100' - 4000'. 6. DSTdata, perforatingdata, showsofH2S, miscellaneousdata NONE C YED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· ?t~,.S~,.~ O~i ~ 033 Ar, ch0mge SIGNED. ~'~' TITLE ,,~ S sec! a+e~ Engl ne:r DATE NOT~-~ep~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 DRN/MR84 Submit in duplicate MEMORANDUM State-of Alaska ALASKA OIL AND GAS CONSERVATION CO[~ISSION C. V rton Chaii~ah / ' THRU: Lonnie C. Smith Commissioner FROM: ~~._..~ SUBJECT: Edgar W. S~pple, Jr Porroleum Inspector DATE: November 26, 1984 FILE NO: 105/U TELEPHONE NO: Witness BOPE Test On ARCO' s Kuparuk 2X-11 Sec. 4, TI1 N, R9E, UM, Permit No. 84-164, Nabors Rig 26E. Saturday, November 24, 1984: I traveled this date from AR'CO's Kupa~uk' 2E-'14, S~bj~ct of another report, to /~RCO's Kuparuk 2X-11, Nabors Rig 26E, to witness a BOPE test. The drilling contractor was in the process of finishing the hole. The BOPE test commenced at 8:00 p.m. and was concluded at 9:40 p.m. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 2X-11, Nabors Rig 26E. Attachment 02-O01A(Rev. 10/79) : : : ' O&G #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator / Location: Sec ~ Drilling Contractor Location, General Rig General Housekeeping 0 ~ Reserve Pit O/~i Mud Systems Visual Well Sign~2~ Rig Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Ann~3zar Preventer Pip~Rams Blind Rams / CR~e Line Valves H.C.R. Valve Kill Lihe Valves Audio Check Valve Test Results: Failures Test Pressure Date //-- ~ .~ ~ Representative .~",' ~,~ Permit # ~_ / ~ Representative ~, ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psi~ Full.~ Charge. (~ P~sure~taine'd:_. __ psig psig / 9 7~--- ~ min~/ sec. ~ rain ~ sec. psig. '' Controls: Master Remote Kelly and Floor Safety, Valves Upper Kelly ~"~ Test Pressure Lower Kelly ~ Test Pressure Ball Type ~ -~est Pressure Inside BOP ~ ~'~est Pressure Choke Manifold ~ Test Pressure No. Valves /~ No. flanges~ Adjustable Chokes ~' ~v~ Hydrauically operated choke Test Time / hrs. ~/~ Repair or Replacement of failed equipment to be made within, days and Inspector/ Commission, ~ice notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~~~~// ARCO Alaska, Post Ofh-~-~ Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Revised Conductor As-Built Location Plat - 2X Pad Wells 9-16 Dear Elaine, Enclosed is a revised as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU2/L25 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - ' '-'---'- ....... ~'~' - 'CTO-S DRILL .SITE 2iX CONDU N AS-BUILT LOCATIONS ___ ~=======.,=~----~--- WELL 9 y = 5,971,0§2.9~? Lot. ?0 [ X: 518,5~'9.196 Lo~g. 149°50'58.918§~ ILT 16 WELL I O , , · ' WELLS 9 Thru ~ ~ ' · ' O,B. Elev. 72.0 Pad Elev, 76.~ i !/l il ! ,,- i Ii I0~4 i/ I ! ,o. ! II I.,s I/ ' O G Elev 719 Pad [tev. 76.~ WELL I · , I X= 518,889.157 Long. le~ O.G. Elev. 7~.1 Pad Elev. 77.0 X- 5t ~ ~89 054 LOng 14 9°50'48.4057¥~! ~. ~ x = ~8,~89j40 Lon~ 149~50'4~.407S~ . - / ' O,G. Elev. 73.4 Pad Elev. 77.0 ~ to / ~,o~e' FSL ~3~' ~EL ASE [ - EXISTING J Elevot,ons Adde ~_~,,, LOC ........ ~- ~ - U~,AT ~S../ ~': TOWNSHIP 11 H, .~.u~ - -, / ~.~.~ _ NO SCALE / · ASI$ NOTE. B .... TO PRACTICE LAND .SURVEYING IN THE STATE ~ ~ [ ~ ~l L .~ ~ ARCO Alaska, Inc. . !! P ,o~ ) I 1 ,,~~1 I P ~~ [~ Kuporuk ~ ! ~ ! J/~ ! ~11 '[~ CONDUCTOR AS-BUILT PHASE Tr WELLS 9 AS-BUILT Thru I~%. II 14 ,o o I I I° '~ 9 . I0 I - EXISTING WELLS I Thru 8 LOCATED IN PROTRACTED SECTION 4 TOWNSHIP 11 N, RANGE 9 E, UMIAT MER. NO SCALE NOTE' BASIS OF BEARING IS MONUMENTATION 2X-NORTH AND 2X MIDDLE PER LHD ~ ASSOCl ATES. j · THIS SURVEY' . I DRI~.~ SITE 2X -~_~ - BUILT WELL 9 CONDUCTORS LOCATIONS WELL I 0 WELL II Y = 5,97 1,052.927 X: 518,529.196 I,O50' FSL Y :5,971,112.911 X: 51 8,529.180 I,I IO' FSL Lot. ?0° 19'55.499' Lon~. 149°50'58.$15' 599' FEL Lat. 70° 19'56.089' Long. 149°50'58.915" ! 598 FEL WELL 12 WELL 1:5 WELL 14 Y :5,971 ,172.955 X-' 518,529.084 !, 170' FS L Y :5,97 I ,232.789 X: 518,529.168 2,230' FSL Y: 5,971,233. ! 14 X: 518,889. 151 I, 229' FSL Lot. 70° 19'56.680" Long. 149 °50'58.91.~' 598' FEL Lot. 700 19'57.268' Long. 149050'58.908.- 598' FEL Lot. ?0° I 9'57.263' Long. 149°50'48.394'' 238' F EL WELL 15 WELL 16 Y:5,971,173.080 Lot. 70°19'56.672- X: 518,889.137 Long. 149050'48.399- I, I 69' FSL 238' FEL Y :5,971 ,I ! 3.138 X= 51 8,889.054 I, IO9' FSL Y:5,971 ,053.154 X: 518,889.140 I ,049' FSL Lot. ? 0 019'56.083' Long. 14 9050'48.406" 2:38' F EL Lot. 70°19'55.495" Long. 149°50'48.407" 239' FEL I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED 8~ L!CE-NSEO TO PRACTICE LAND SURVEYING-IN THE STATE OF ALASKA 8~ THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION I~ THAT ALL DETAILS ARE CORRECT AS OF SEPTEMBER ?_1, 1984. ,_, ~,.J=,-~ ARCO Alaska, Inc. - Kuparuk FYoject North Slope Drilling / .-' '. DRILL SITE 2X ~~II ;~'~'~' CONDUCTOR AS-BUILT :. LOCATIONS "~3~ J~J~B"'i Dote:. $£PT. 30,1984 Scale; AS SHOWN ............ , ..... , Drought sman: HZ D~,cj. no.: ~K 9.05.224 d 2 · ]~. --.-- . , _ - September 13, 1984 ~ir. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re ~ Kuparuk River b~it 2X-il ARCO Alaska, Inc. Permit No. 84-164 Sur. Loc. ll80'FSL, 601'FEL, Sec~ 4, TllN, RgE, UM. Btmhole Loc. 1351'FSL, 1478'FEL, Sec. 4, TllN, R9E, .UM. Dear Mr. Kewin: mL~cto~ed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems.have been classified as important ior the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska A~inlstrattve Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify thi-s office 24 hours prior ;to commencing installation of the blowout prevention ~-~r. Jeffrey B. Kewin Kuparuk River Unit 2X- ! 1 ~ embe 1 9 ~ 4 -~- Sept r 13, _ ,~ equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very ~ruly yp~urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~fMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office b--~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 27, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2X-11 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2X-11, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on October 22, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. in Area Drilling Engineer dBr/d~/tw ~RUl/k08 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED S E P 0 4 1984 Alaska 0il & Gas Cons. Commission Anchorage la. Type of work. STATE OF ALASKA ALASKA'--~L AND GAS CONSERVATION C(-~i'MISSION PERMIT TO DRILL DRILL [~X REDRILL [] DEEPEN [] 2O AAC 25.OO5 lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] ~ STRATIG~,~¢~tlC I_~ SINGLE ZONE~ o ~ '~ . 9. Unit or lease name Kuparuk River Unit 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1180' FSL, 601' FEL, Sec. 4, T11N, R9E, UN (Approx.) At top of proposed producing interval 1306' FSL, 1246' FEL, Sec. 4, T11N, R9E, UN At total depth 1351' FSL, 1478' FEL, Sec. 4, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 112' PAD 77' I ADL 25645 ALK 2576 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 10. Well number 2X-ll 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. ProPosed depth(MD & TVD) 6505' MD, 6318' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 4000 feet. 21 14. Distance to nearest property or lease line miles 3802' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 25 ° (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 2X-10well 60' ~ surface feet 1'8. Approximate spud date 10/22/84 2752 3159 psig@ 80°F Surface psig@ 6137 ft. TD (TVD) SIZE Hole Casing Weight 24" 16" 62.5# 12-1/4" 9-5/8" 36.0# !8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I Coupling/ Length m Welq 80' H-40 HFIERW J-55 J-55 HFIERW BTC/ 6471' SETTING DEPTH MD TOP TVD 35' I 35' 1 35' 35' I I 34' I 34' MD BOTTOM TVD 115' 115' 2972' I 2972' 6505' I 6318' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 700 sx Cold Set III & 500 sx Cold Set II 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6505'MD (6318' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2752 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2X-11 will be 60' away from 2X-lO at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby cert/i~ that the foregoing is true and correct to the best of my knowledge SIGNED /~/)/~// ~..~" TITLE Area Drilling Engineer The space ,~ow f~r ~om/ssion us~ CONDITIONS OF APPROVAL Samples required I--lYES [~,NO Permit number Form 10-401 GRU1/PD05 Mud log required I Directional Survey required I APl number DYES [~NO I [::~-Y~ES •NO I 50-- ~'~"'ff - ?.,-i / ~ g Approval date ' ,COMMiSSiONER by order of the Commission SEE COVER LETTER FOR OTHER REQUIREMENTS DATE September 13, 1984 Submit in triplicate Permit to Drill 2X-ll interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. / / · . , [ t - · '-I .... [ .... ' ........ i ............. ..... +'' ' . ' [ f ~ .... :_ I _ ::. ..... '. .... TOP: UGNU SNDS:. TVD,,1887/::.: :-[-_'-:.-:': ' :2~nn:_ . '. ..~ ; ,, '""~- ~ ..... '' · ' ~ ~ ' : ' ' ' : ' ,,~. , ....... ~ . . + ............. : ............ : ........... : - ' t. ..... : ' ~ ..... K-12 TVD-2922 ....... ~ .... { '- -! .......... : "! '' : '-' '" 31:i1~1~ ~s13: PT. TVD-.P~7'2 ' - : : ' ~'' i ..... ,. : , '~ -! .... - :- : ' .. :i- :i ... ii ........... :. j ._ : .Frl -; .............. T ............. =3 : : .':: ..... ~ ......................... --.J ... ; ...... 4 ........... t ,-, · ' .... i .... C) . ~ . . . , ........... ~ , . . . . ~ ...... t , .... .-. 4000_ ~.jP T ~3 THO=, ;nnl3 DI='P=O .... : .... BUILD..3 DEG ...... i ............ ! - t ...... + ' + · 9 ' ' - PER- 100 FT .... . .- ~ ............... : -' t ....... "-tS-':'--- ------f---'----+ ' ..'K-5 TV1:)--4672 IflD=4687' DEP=I 22 ..... t .... · ; F ? .... :---~ ..... : f' i '' ~', EOC TVD-481 . , ; · -, - ~ : , : _ I ..... ! , , , , , : · ~i'" iAVERAGE ANGLE -:..Xi:':-:t-25..iDECjtg.:HIN:i-:: .:: ...... :--i': ........ X .... 7-1-' . . .t.. i ~ , ,, ~ ; , . i- - ; .,- ; ,.~ 1- · :.X ..1.-. : - I -- : .... t - .. t - , : I ..... ' e ~ - ~OP 'uP:PR .SleDS ' :VD=58'J7' THD=595~- DEP=657 t~ --8~~ m: X ' ~. '~tTARG;ET CN~R TVD=59~ TMD=61 i........ : X BAsE KUP[ SNDS! ' /VD:=61 .:.: ::. :, '.TD~-(LOB¢ING.PT), ' TvD=6318-T~D=650,5 DE,~894.: ....... · . , - , . _ I ..... i: .... ...... I ....... { , j - ': t r~'r ~-'~,,r~f~ ,. , .- - . ,: ,. ! '713nlD'l ' : - ! . · I .... :-:.~ :-1.- ; ........ t , h ; ._. ooo. I ':- '1-' '..'I.':::_:':F-:'.~::.: ..... , .... ~ ' t - -,,--.,r,~-,.,-n,--~;,.,, .,.,.,.- : 1 I . I. ' 'i'::: . [:: 'i . ..I.. :..! ' . ; ........ I ...... ~ - J l, , * ' ~ ' ~ { i %LE~ 11 IN'' I ! '' ' ~:::::: ~ ........._~i :.:._:' i. :: :.i::_-::_: i ::. _: .... i ...... ~ - - , . - - i - - - : - - i ' ~ - i ' ' : i - : ' - ' ..... , .... .. PROP SED'~ : ~ SLOPE. -ALASKA: ,/ ~- -~ ...... i 'J · ' ~. i-.. RRCO ALASKa, [NC- ' ~-' '''' PAD 2X WELL'NO,'11- .i ......... KUPARUK-F[ELD,.NORTH ~ ~ ~ASTMAN WH[PSTOCK~' I '' i f ! ' l 2000 _ 2000 :~ i TAROET LI:X~ATION, ! ......... III - i~ ' ' ' sl I I t I · · i- j , ......................... , ......... I .... · · ; i - j · I · .................. ; ........ I ..... -' ...... ! ........ ~--: ..... ~ .... , ........ J ......;~ ........... ; ......~ ........... ! ................': ,' ................ t i ........... t ~ ......... -t ~ ........ ~ .... i-\ .......... 4 .~ ......~. -.-: .... ; i ~ . - I .1 ................... ~ ..... .~ ........... , ....... ~. ......... .-~ ........; ..... , ........~..--, --.-~ ........... ~,__ . J .......· ..... - · ', ! , / j : ,.~ I I ; ' ' , ' ' ? .... ~ : ' I ", ........ ; ..............., .~ ...... .~ .... , ....... t ......; ...... .I ......: ............ !~i ! ~ ............. t ' ................... l ....... , ................................... t J : ...... -~ .......... ' · ' ' - ; ~ I , I ' ~ : ~' ' · - I , _ . . . j. ......... , . ' ............ ? - - · ~ ..... ; ......... l ......... t ..... .~ ......... t ................ , .... "~_DO' .... ,. :, ...... ,! .I .......... ! '" ''Jl '~ j ', ' ........... ...... :'~. .......... ! .............. ............... ...... ..... '"'-: ..... '~~" ..... ! ............ .................... 4 .............. - ................. ~. .......... ; ......... ~ .......... J , ~ -'""--~.-'" '~ ..... ] . ......-4~ . i ---, .~"...--...~-'-"- ' .; .......i ..... ~ ......... ~ ......_; .... -~ .,...:./J._ J ,~J~-._4 .... ,, ........... ~..- .~ ~; ..... ~' . .-I . ~ ....... 1 ......4 ......-, .~c~, .... ~--- ........ ,. ~ ~ I I ,j ' i - ' ~-- i ......... j . .... ' ' ~ -.-.-.J . . -~ 477'7 ,-- . ~ ~ ., - ' ......... I · i .... ~ · · I . . ' ; ..... : - I-'''-I J '" ~ I : "l~_O__. ~ , ,.I, , ..,J ' , , ! j r ..... ....... : . · I ............................. ................ ARCO.-ALASKtA, .... INC.---: ....... ; ..... · .I.-~- ........ /;n ' :" '/j ..... '. ................ P.~:l~ ax.. UELL;..0 ..b--~ 0-~-~ 2 . PROPOSEDt ........ ~- ... !: ......... !..-. i ...... :' · ~,UF~RUK:-F't.F_L-I),--NOR'T-H-St=OPE-;'- -^LmSK'A .... : , ' ' 1 ...... 1' ', ~.'-.-].- '-..i.-~;, ,. ............ -E,~ST:I'I^N' WHIPSTOCKJ.' INCL ........ · ' , · ' ! ~ I ' ' - ' · .... :NOTE, ~ELL PATHS! EXTEND· BE'rOND THIS t ' ' ' .... 1 ' : i ........ ~IEWING WINDOW--: ......... · I .o . J · , · ' t ? i i -! Surface Diverter Svst~, 16"-2000 psi Tenkco starting heed. lenkco qu(ck connect essy. 16" X 20" 2~X)O psi Ooubie studded adapter. 20" 2000 psi drilling spool w/lO" side outlets. lO" bell vetves~ hydraulically actuated, ,/lO" lines to reserve pi t. Vel vet to open auto,ti cai ly upon closure of annul er preventer. 20" 2000 psi annular preventer, 20" bell nipple. Heintenence & Omeration 1. Upon initial installation close annular p~eventer and verify Ghat bail valves have opened properly. 2. Close annular preventer end blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid fl~ to surface is OetecteU. If necessery~ ~nuelty override and clo~e bell valve to upwind diverter line. Do not shut in ~ll under any circumstances. 1 6" Conductor RECEIVED Alaska Oil & (]as Cons. Commission Anc,horage F PRE¥£NI'~'R t 8 f BLI.,X~ ~ .> C -- SPOOL _ __ D;AGRAH dl 13-5/g' 50DO PS: R$~RA BOP STACK 3. 1!' - ZOO0 esi x !3-5/8' - 5ODD psi smacer smool 4. i3-5/8' - 5DOD psi x 13-S/8' -SDDO psi oriiiin¢ 5. !3-5/2' - 5DOD psi pipe rmms lines o !3-5/B' - 5DOD psi Dime rmms 8. !)-)/B' - 5000 psi blin~ rmms !2-5/8' - 5000 psi ~nnuiar A?.'J.".'JL.ATOR CAPAC~,"Y TEST '!. CHECK AND FiLL ACCUHULATO~ RESERY01~ TD LEVEL WiTH HYDRAULIC FLUID. 2.ASSURE THAT ACCUMULATOR c~ Rr !S ... o~00 PS! DOwNSTAEJ~ OF THE REGULATOr. ......... .I P,U~TAN:DU.~ v 3. O~qr~VK T~=~ THEN CLOSE ALL UNITS ~ " ' '~'. AND ~ECDKD THE Tl~E AND PRESSURE RE?rAINiNG AFTER ALL UNITS A~E CLOSE~) WiTlq, CHARGING PUMP OFF. 4. RECD[D ON NADC REPORT. THE ACCEPTABLE LOWE~ IS a5 SECONDS CLOSING T]~E AND i200 PSi PRESSURE. :3-5/~' BOP STACX TES' I _ ._ ~.. .riLL BOP STACK AND ~b',~IFOLD WiTH ARC'TiC D!~E:-. 2. CHECK CHAT ALL HOLD DOwN SCREWS ARE rn, ~v R?FP, ACT- - KD. pRKD,,rTE.:P~HINE DEPTH THAT TEST PLUG WiLL S~? AND SEAT IN WF.L'LHE.AD. RUN IN LOCK DOWN SCREW-~ lit .~. CLOSE AN,ULA~ PREVE~,--E~. A~D ~,:"~I'~S LTP~.=~H OF CHO}~_S. DOh~T TEST. AGkINST CLOSI:_D i. Tr..ST ALL CD~PONEh"FS T0 250 PS: AKD HOLD 'FO~ lO 5. INCREASE PRESSURE TO lSOO PS] AND ~OkE FOR !0 H!NUTES. BLE'~D TO ZERO PSi. 6. OPEN ANNULAr, PREVENTER AND CLOSE TOP SET,'OF 7. iNCRE,kSE PRESSURE TO 3000 PS; AND MOLD FO~ ~. ~~'Pi~SSbi~ ])O'~,NST~kx~ OF CI-gI,t~ :SOLATIO~ 'v'y~L.I.~S. TD ZERO PS'-' TO TEST VALVES. · V,d.V.. iF ANY TEST EEHA!)~ING U)~TESTr-D KA~;IFOLD ,. rq, WiTH :DOD PS] UPSTREt~, OF VALVE AND ZERO PS] DOWNSTRE~.K. BLEED :~q-'"~- TD ZERO PSi .:. OPEN TOP SET DF PiPE RZ, P-~ ' '~ r, mcr :~Oi'TDP., .E'F, OF PIPE RA~. 10. ]NCRF..ASE PRESSURE TO 3000 PS~ AND HOLD FD~ ~INUTES BLEED TO ZERO PSi. 11. OPEN BOq'tON SET OF PIPE P. AP~. BACK OFF RUNNING JOINT AND PULL Ob~ OF HOLE. CLOSE BLIND R,%~S TEST TO 3000 PSI FOR I0 ~INUTES. BLEND TO ZERO PSi. 12. OPEN BLIND i~J AND RECOVE~ TEST PLUG. HAKE SUrE I,~NIFOLD AND LINES ARE FULL OF ARCTIC D:ES~.. AND ~L, VALVES i~E SE'F ]N D~ILLiNG 13. TEST STANDPIPE VALVES TD 3000 PS]. REC ~" i '~'E D1'' TEST KELLY CDC)CS AND INSIDE BOP TO SDOO PS: KOOk, NY PUMP. to.. sl N AND SEND To DRi'--'.:NG SUP:RV:SO . 8EPo 4 1984 ~. ~ER~o~. C~PL~ Bo~E ,-,.ST O,CE ~ .EE~ A,~ ru,c- Alaska Oil & Gas Cons. CommissionT;ONALLY OPEA$,TE BOPE DAILY. Anchora0e CHECK LIST FOR NEW WELL PERMITS /CA U~ ~.)~-~// ITEM APPROVE DATE (1) Fee (2) Loc thru 8) '(8) ' '_ (3) Admin ~D~.- 9~'~ (9z thru 11) (10 and 11) (4) Casg ~2 thru ~'~--~'~ Company ~.~..~ Lease & Well No. (21 thrd 24) YES NO (6) Add: .~ ~"'"~'"~¢ 1. Is the permit fee attached ................................ 2. Is well to be-located in a 22f}~e2 ~2o~ o 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ... 7. Is operator the only affected party ............................... .. 8. Can permit be approved before ten-day wait,. .............. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force .................................. ~z~-~.. Is a conservation order needed ...................................... ~ , Is administrative approval needed ................................... ~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons .............. Will surface casing protect fresh water zones .. .i i..i. ii~i .... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ........... , Is adequate well bore separation proposed ........................... is a diverter system required ....................................... /~ Are necessary, diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ...~-~ psig .. s pl /API (F 78) Doe the choke manifold com y w RP-53 ab ................... Additional requirements ............................................. Additional Remarks:~/£ZZ ,,.,d..Y'-/! REMARKS TV/O, , r'/l,E',e~ tlR~ ~Z .Geology: Engineering: /' LCS M~f~ ~EW WVAHWK ~~3H ~ rev: 12/08/83 6. CKLT ' INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS' ARE; NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS TAPE VP 010.HOZ VERIFICATION LISTING ,PAGE I :* REEL HE&DE;R ~* ERVICE NAME. :EDIT. ATE :B5/03/i5 R.IGIN : EEL NAME :135025 DNTINU~TIDN ~ :01 REViODS REEL : OMMENTS ::LI~:RARY TAPE :*'TAPE HEADER .E R'V I.C E N A M E : E D I T ATE :85/03/I5 ~RIGIN 'APE NAME ' : ONTIN~ATI~N ': ~ 'REVIOUS ' T,AP~ : ,OMMENTS ::LIBRARY TAPE :* FiLE HEADER~..'~ :ILE NAME :EDIT. ;ERVICE NAME :' ~ERSI.ON ~ ~ATE : ~AXIM.UM LENGTH : 1024 :ILE TYPE ~REVIOUS FILE :~ INFDR'MATION RECORDS INEM CONTENTS ;N : ARCO ALSKA, iNC. ~N : KUPARUK 2X-l[ :N : KUPARUK RIVER ~ANG: gE .tOWN: iECT: 'OWN: .NO~TH SLOPE ~TAT: ALASKA ;TR¥: CNEM CONTENTS ~RES: ~ COMMENTS '~* UNIT UNiT TYP~ 000 000 000 000 000 CO0 OOO OOO 000 TYPE 000 CATE 00'0 000 000 0 O0 0 O0 000 000 000 000 CATE 000 SIZE 016 014 014 004 002 012 006 SIZE 001 CODE 055 065 055 055 055 065 VP 010.HOZ VE.RIFIgAT~ON LISTING PA~E Z SCHLUMBERGER ALASKA DIVISIaN CgMPUTING CENTER COMPANY = ARCO ALASKA WELL = FIELD = KUP'AR~K RIVER COUNTY = N.SLOPE STATE = ALASK, SECTION = · TO.WNSM~P = RANGE = 'TAPE DENSITY = BOO BPI. JOB # &9'@Z3 SASE. LOG: Dig , RUN e L DATE LOGGED 28 NOV 8~ ~OTTOM LOG INTERVAL TOP LOG INTERVAL CASI~G'L~GGER TYPE HOLE FLUI. 2 ~4 74 FT.. = 3118, Fl'. = 9. 625 IN. : 8.5'00 IN.. XC POLY @ 312! FT'. VP 010,.HOZ VERI~ICA'TION LISTING PAGE DE N S IT ¥ VISCOSITY PH FL UI'D LOSS RM @ ME,AS. TEM, P. RMF ~ ME~$,. TEMPo RMC ~ MEAS. TEMP. RM ~, MATR IX 10. O0 4½.00 10'5'0 5.40 l,.5~0 .@ 58 F 1.55,0 @ 6:8 F 1.60'0 ~ 68 F 0.839 ~ 135 F SA NDSTON'~E LOP: T HALSTEAD DATA FORMAT RECORD NTR¥ BL.O'C~S TYPE SIZE REPR CgDE E~TRY 2 ~ 66 O 8 4 T3 60 9 4 6S olIN 0 1 66 0 IATUM SPECIFICATION B,LO,CKS I'NEM SER¥IgE SERVICE UNIT A'PI AP[ ID ORDER ~ LOG TYPE CLASS IEPT FT O0 000 O0 ;FLU OIL griMM O0 220 O1 :LO OIL OHMM 0.0 120 46 :L'M OIL OHM.M O0 1,20 ;P OIL MY O0 010 O1 ;R OIL GAPI O0 .510 O1 ;FLU PS~ OHMM O0 220 'LO PSI OHMM. O0 ~20 :LM PS1 OH. MM O0 1ZO ;P PS1 MV O0 010 01 ;R PS1 GAP1 O0 310 01 ;FLU PS2 OHMM O0 ZZO :LO PS2 OHMM O0 ZZ~ :LM ~,SZ OHMM O0 ~20 ;P PS2 MV O0 OlO Ol API FILE SI/..f:. SPL REPR PRF. iCESS C ODE, C OCT,AL) 1 58 OOO OOOO0'OOO00'O 1 68 000000,00000008 1 6:8 O00000000000Q'O I 66 O000000OO0000~ 1 68 O000000000000O 1 58 O00000OO000000 1 6,8 00'0000'00~000000 1 58 1 68 OO00000OO0000,~' 1 58 Or 0000 O 00000 O0 ~ I ,~'8 000000.0000000~' 1 58 0000000000000',~ 1 58 O0000OO000000~ 1 b8 0000000000000~ 1 68 00000000000000 VP OiO.HOZ VERIFICATION LISTING PA6E ~ R P S Z R F O hi A L I F'D hi · H08 FDN RHO FDN ,RAT FDN :NRA :FDN IPHI FDhi ~CNL FD~ :CNL ',ALI PSt :HO~ PSS ~R HO PSL IR~T PS1 ',N R A P S 1 iP ~ I P S ~ tC~L PSS :CNL PSI ;R PS2 ',ALI 'PS2 ~HO~ IRAT PSZ ~NRA P,S2 ~PHI PS2 ~CNL PS2 ~CNL PS2 }EPT ;P :LD ;R QRAT :£NL )RHO 4CNL ~HDB ~PHI )EPT ;P ELM ~RAT :CNL )RHO ~CNL ~HDB GAP I GAPI IN G/C3 G/C 3 PU CPS CPS GAPI IN G/C 3 G/C 3 PU CPS CPS GAPI iN G/C3 G/C3 PU 00 3 ! 0 00 310 00 2.80 O0 350 O0 356 00 ,~20 00 00 0 O0 B 90 O0 330 00 330 0.0 3 ~ 0 00 28 ~0 O0 35~ 0 0 356 O0 62.0 00 000 00 8:90 O0 330 00 330 0.0 310 00 2 80 O0 35O O0 356 0'0 620 O0 0~00 0 0 890 O0 330 00 330 0 t O1 Oi 02 01: O1 O0 O0 31 30 ,0~ O1 02 O0 O0 30 01 O1 02 00 O0 31 30 6692.5000 S :F L U -14.0000 -G R 2~, 7463 SP -999. 2500 ,1.10.8750 CALI 2.9512 RNRA 703..5000 0.2632 NRAT 2311.5000 FCNL -~g9.2500 ORHO -999,2500 NCNL 6600,0000 SFLU -2~.7500 GR 2,7522 SP 2.6652 ILM 100,3750 CALI 3.232~ RNRA · $1~.0000 GR 2051,5000 ~CNL 2,5002 DRH~ '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 ,0 0 0 0 0 0 3. 0527 ZLD !10,8750 3FLU -i61.0625 ~.R -999,2500 SP 8.5000 3.1953 NP~.I 129,8125 CALI 2.8069 RNRA 760.3125 GR -~gg. ZSO0 NR~T -999.2500 FC~L 3..3496 [LD .lO0. 3750 SFLU -65.9727 FaR 2.756l SP 8. Z3,~4 RH'3B 3.3203 NP~I 109.6668 CALI 3,287~ RNRA $79.31Z5 GR 0.0~62 NR~T 0 0 0 0 0 0 0 0 0 0 0 0 0 O, 0 0 0 0 0 0 0 0 0 .0 0 0 0 2000.0000 3.5995 129.8125 -999.2.500 2. 5352 33.1543 8.5020 B.0393 -9g~,.~$00 2.,. 6211 3.3674 i09. ~+668 -10.9590 2. % 883 37. 939~ 8.. 8535 3.5393 110,5273 3,3186 1 1 1 1 1 i 1 i ! 1 I 1 1 1 1 l 1 68 O0000000000OO0 68 00000000000000 68 O00000000000O:O 68. 000000.00000000 68 0000000000000,~ ~,8 O0.O00000OOOOO0 ~8:000,000000000-00,~ 5~ O000,O00000000O 68 0000,000000000~ 68 O0000000000OO~ 58 0000000000,0000 68 00000000000000 68 0000000000000~ 68 'O0,O0000OO0000~ 58 0000,00000000,0'0 68 0000.000000000~ 68 0000000'0000000 68 O000000000OO00 ~8' O000OO00.O00000 63 000000000.0000~ 68 0000000000000~ 68 OOO000,O000OO0~ 5-8 ,00000000000000 68 O0000OO0000000 58 0000000000000~ 68 OO00OO00'O0000O 68 0000000000,0000 0000'0000000000 ILM 2.5 9L B ,[LO 3.78 76 SFLU -999.25.00 GR -9 99.2. 50'0 OReO 0.2202 NCNL ZZ6S. 0000 RHOB Z,~I82 NPHI 3t.0059 CALl -999. 2500 RNRA -999.2~00 I.'LM Z.Z695 ILO 2.5663 SFLU 3.3499 GR 110.5273 DRHO 0,0669 NCNL 2043.0000 RHOB Zo~78B NP~I 38.7695 CALl 8,7676 RNRA 'VP glO.HOZ VERIFICA'TiDN LISTING .PA~E ~ PMi 39.. 45,5! NCNL EP T P LM R 'R ~T CNL C NL EPT iR~T :C NL ~ iR ICNL, ~PHI tE PT, ~R JRAT :C NL IRHO :HOB IPHI ~EPT ;P ,R iR~T :CNL ICNL IPHI tEPT 6300:. DO00 -30. Z 500 3,' 0706 2.. 8Bll g½. 9375 526. 0000 O. 0405 2 ~37.6875 Z. 4534 3 5.132:8 6Z00. OOOO -49. 750,0 17. :0 Z 05 1,½o 3535 4,4,. 03 :iL 3 2.773z, 853' 0000 0.042.0 ~ Z 3. 50:0'0 2.2913 31 o 00 59 6/00o0000 -40.2500 5. 7898 5- 6609 87.3125 Z. 9160 787.0000 0-0308 234 g. 5000 2.4104 30.3213 SFLU GR SP ;rL M C A L l ~NRA GR N R AT FCNL O R ~ 0 NC NL GR SP ILM CA LI RN RA GR NR AT F'C NL, ,D, RH8 NC N,L ' S FLU G R SP ILM CALl RNRA NRAT FC NL DRHO NCNL 6000'.0000 SFLU -71.2500 GR 67.1523 SP 9&.g648 ILM 50.7813 CALI 3.4375 RNRA &40.O000 GR O.030B NR~T 1171.5000 FCNL 2.~866 DRHO 40.9180 NCNL 5900.0000 SFLU -37.5000 ~R 1.4366 SP 1.2939 ILM 5000 FCNL 4.1250 ,IL, D 94, .. 93'75 S F L U -74. ~'717 3.0706 SP 8. 7969 RHDB 3. 3145 N.P ~11 95.2773 CAL, I 3.3t 08 RN ~ A 569.31Z5 0.0493 NR.AT 1953..a875 FC~L 49. 000'0 ZLD 44.0313 SFLU -99,4727 ER 1'7,, ,:5611 SP 8.5625 RH~}B 3.0098 NP~I 43.1680 CALl 2.8713 RNgA 0.0630 NR~T 1~47= 5,000 F:CNL llB.ZSO0 iLO' 50.7813 SFLU -144.1875 GR 61.9180 SP 8.7109 RHO~ 3.4803 NPHI 54o5117 CA~I 3.~307 RNRA 634.3125 GR -0.0024 ~RAT 1163.5000 F£NL 1.724.6 ILD '111.8115 SFLU -98.4727 &R 1.4531 SP i,. 90&2 4.0164 95 ' 277,3 -15.3701 3.8. i348 ~. 9.138 3. ~784 9 7. 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