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Home My WebLink About213-1277. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-32C Recomplete to Borealis Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-127 50-029-21924-03-00 13525 Conductor Surface Intermediate Liner Liner 8801 80 2632 5196 6345 1978 11327 20" 13-3/8" 9-5/8" 7" 3-1/2" 8480 50 - 130 49 - 2668 47 - 5243 5083 - 11428 11275 - 13523 50 - 130 49 - 2668 47 - 4852 4739 - 8560 8438 - 8802 11900 2670 4760 5410 10530 11327, 11425 5380 6870 7240 10160 9074 - 13427 3-1/2" 9.2# 13cr80, 13cr85 45 - 9006, 11147 - 11279 6711 - 8823 Structural 4-1/2" HES TNT Packer 11171, 8354 8889, 11171 6575, 8354 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Prudhoe Oil / Borealis Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028245, 0028262, 0047450 45 - 6661, 8335 - 8441 ~11327' - 11425'MD in tubing Dump Bail 15-gallons of 17-ppg Cement. 111 38 1571 131 640 1936 950 1100 314 300 324-482 13b. Pools active after work:Borealis Oil Pool 3-1/2" HES TNT Packer 8889, 6575 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:37 pm, Oct 30, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.29 15:52:05 - 08'00' Torin Roschinger (4662) RBDMS JSB 103124 DSR-11/6/24WCB 2-10-2025 ACTIVITY DATE SUMMARY 9/23/2024 T/I/O = 250/0/0 (TFS Unit 1 Assist E-Line with Load & Test) Pressure Test E-Line. Released to return 9-24-2024 Alaska E-Line in control of well upon TFS departure FWHPS = 250/0/0 9/23/2024 *** WELL SI ON ARRIVAL*** (DRIFT, LOAD, PLUG, TEST, CEMENT) MIRU AKEL PT 250 LOW AND 2500 PSI HIGH. FUNCTION TEST WLVS. RUN 2.76" SL SWEDGE DRIFT TO 11500' LAY DOWN FOR THE EVENING *** CONTINUE JOB ON 24-SEPT-24*** 9/24/2024 T/I/O=250/0/0 TFS Unit 1 Assist E-Line (Load and Test) Pumped 140 bbls SW down TBG for load. Pumped 3 bbls 60/40 followed by 20 bbls Crude down TBG for FP. Pumped 3.5 bbls Crude down TBG to pressure test. **PASS** Bled back 2.2 bbls. Alaska E-Line in control of well upon TFS departure FINAL WHPS = 0/0/100 9/24/2024 ***JOB CONTINUED FROM 23-SEPT-24*** (CIBP AND CEMENT DUMP) THUNDERBIRD LOAD AND KILL AND FREEZE PROTECT. PT LUBE TO 250 LOW AND 2500PSI HIGH. CIBP SET AT 11425' MID ELEMENT, CCL STOP DEPTH: 11412' CCL-MID ELEMENT: 13' THUNDERBIRD TESTED TO 3000PSI FOR 30 MINUTES. *** JOB CONTINUED ON 25-SEPT-24*** 9/25/2024 ***JOB CONTINUES FROM 24SEP24 WSR*** (DUMP BAIL CEMENT) RIG UP AKEL PT PCE 300PSI LOW, 3000PSI HIGH FIX U JOINT ON UNIT RIH AND ATTEMPT TO DUMP CEMENT ON PLUG AT 11425', POOH TO SET UP CEMENT IN BAILER RETURN TO SHOP TO CLEAN BAILER ***JOB CONTINUES ON 26SEP24WSR*** 9/26/2024 ***JOB CONTINUES FROM 25SEP24*** RIG UP AKE PT 250 L 3000 H RIH WITH 30' OF 2.5" BAILER DUMP 3 RUNS OF 17 PPG CEMENT (15 GALLONS) ON TOP OF PLUG @ 11425' EST TOC= 11385' JOB COMPLETE ***WELL SHUT IN ON DEPARTURE PAD OP NOTIFIED*** Daily Report of Well Operations PBU Z-32C RIH AND ATTEMPT TO DUMP CEMENT ON PLUG AT 11425', POOH TO SET UP CEMENT IN BAILER Sundry required TOC to be a minimum of 25' MD above the CIBP. TOC is 40' MD above. -WCE CIBP SET AT 11425' MID ELEMENT RIH WITH 30' OF 2.5" BAILER DUMP 3 RUNS OF 17 PPG CEMENT (15 GALLONS) ON TOP OF PLUG @ 11425' EST TOC= 11385' Daily Report of Well Operations PBU Z-32C 10/1/2024 ***WELL S/I ON ARRIVAL*** RAN KJ, 2' x 1-7/8" STEM, 2.50" S. BAILER(msfb) PRE AOGCC WITNESS TAG TOC @ 11325' SLM RAN KJ, 2' x 1-7/8" STEM, 2.50" S. BAILER(msfb), PERFORMED AOGCC WITNESS (BIXBY) TAG TOC @ 11327' SLM LRS PERFORMED PASSING AOGCC WITNESS (BIXBY) PRESSURE TEST 3167 psi ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 10/1/2024 T/I/O = 116/359/91. LRS 72 - Assist Slickline (RWO CAPITAL). AOGCC Brian Bixby MIT-T to 3000 psi. PASSED at 3167 psi (3300 psi max applied). TBG lost 94 psi during the first 15 minutes and 29 psi during the second 15 minutes. TBG lost 123 psi during the 30 minute test. Pumped 2.9 bbls of 50*F diesel to achieve test pressure. Bled back 2.1 bbls to Final T/I/O= 115/360/91. 10/4/2024 ***WELL SHUT IN ON ARRIVAL*** RIG UP AKE PCE FUNCTION TEST WLV'S T/IA/OA=200/300/100 PT 250L 3000H RIH WITH WELL TECH CUTTER CUT TUBING @ 11148 CCL STOP DEPTH=11130 (CCL-CUTTER=18') JOB COMPLETE ***WELL SHUT IN ON DEPARTURE*** PAD OP NOTIFIED 10/5/2024 ***WELL S/I ON ARRIVAL*** (RWO capital) PULLED INT-DGLV AT ST# 1 (11,074' md) ***WELL LEFT S/I ON DEPARTURE*** 10/5/2024 T/I/O= 228/216/86 Attempt to circulate (RWO CAPITAL) Pumped 2.61 BBLS 60/40 down the TBG and pressured up to 2200 psi with slow bled off. Attempt to reverse circulate down IA but pressured up to 2000 psi with 6 bbls of 60/40 and slowly bleeding off. Appears the tbg may have sealed on itself post mechanical cut. RDMO for SL to bottom GLV above the tbg cut. FWHP's 300/274/86 DSO notified of well status. 10/6/2024 T/I/O= 275/259/89 Circ Out (RWO CAPITAL). Pumped 2 bbls 60/40 meth, 100 bbls deepclean followed by,900 bbls 1% KCL down tubing taking returns from IA to Z-30 flowline. Freeze protect T x IA with 140 bbls of diesel to 2000' tvd. Freeze protect Z- 30 FL with 15 bbls 60/40 meth. Bleed WHPs to 0 psi. FWHP 0/0/0 RDMO 10/8/2024 T/I/O=VAC/0/30. Pre CDR rig, Set 4" "H" TWC #436 @125", TWC LTT Passed. Removed Tree at THA. Installed Dry Hole tree. Torqed to Spec PT to 5000 psi. Pass ***Job Complete*** . Final WHPs TWC/0/30. 10/10/2024 RDMO S-119A Staged up on S-Pad to CO 7'' BOPE stack for 13-3/8'' BOPE stack. Move CDR-2 from S-Pad to Z-32C Job Continued to 10/11/2024 T/I/O = 116/359/91. LRS 72 - Assist Slickline (RWO CAPITAL). AOGCC Brian Bixby () MIT-T to 3000 psi. PASSED at 3167 psi (3300 psi max applied) PERFORMED AOGCC( WITNESS (BIXBY) TAG TOC @ 11327' SLM LRS PERFORMED PASSING AOGCC WITNESS (BIXBY) PRESSURE TEST 3167 () @ psi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y Samantha Carlisle at 7:41 am, Apr 05, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< 7,2 6,$VVLVW6/DVGLUHFWHG3(5)25$7,1*3XPSHGEEOV FUXGHGRZQ 7EJIRUORDG3XPSHGEEOVFUXGHZKLOH6/EUXVKHG6/LQFRQWURORIZHOOSHU/56 GHSDUWXUH,$2$ 27* :(//)/2:,1*21$55,9$/ SHUIRUDWLQJ 5$1*$8*(5,1*Z%586+:+,/(/56/2$'('7%*ZEEOV &58'( %586+('/,1(572 6/0:+,/(/563803('ESP '5,)7('Z ['800<*816RDO PD[RG 72 '(9,$7,21# 6/0 :(//6,21'(3$5785(3$'23127,),('72323 :(//)/2:,1*21$55,9$/ -2%6&23(3(5)25$7( 2) *(2 5$=25*81 7%,5'3803)5((=(3527(&7)/2:/,1(Z&58'(%8//+($'%%/6 &58'('2:17%* 581 ; *(25$=25*8163)'HJ3+$6(&255(/$7(726/% 3(5)25$7,1*5(&25''$7(')(% $77(037723(5)25$7(,17(59$/ 3(5)*81','127 ),5(322+72&+(&.722/6 $7685)$&(*81127),5('$33($56'8(723225&211(&7,21 %(7:((1'(7&25' '(721$725 &217,18(-2%21 7,2 7HPS 6,7)6XQLWDVVLVW(/LQH 3XPSHGEEOVRI&UXGHGRZQ)ORZOLQHIRU)UHH]H3URWHFW'62VKXW,*9DQG 3UHVVXUHG)/WRSVL3XPSHGEEOVRI&UXGHGRZQ7%*IRU(/LQH(/LQH LQFRQWURORIZHOOXSRQ7)6'HSDUWXUH &217,1(-2%)520 5,+:&+ *81*$00$ ; *(25$=25*8163)'HJ 3+$6( 3(5)25$7(,17(59$/ 72 &&/727236+27 &&/6723 '(37+ 322+$//6+276),5('5,*'2:1(/,1(81,7 -2%&203/(7(7851:(//29(5723$'2372323 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8=& Daily Report of Well Operations PBU Z-32C 10/11/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap Install 13-5/8'' BOPE stack and move CDR-2 from S-pad to Z-32C. ***Rig Accepted at 17:30*** MIRU CDR-2 on Z-32C. Perform MIRU Checklists. WH Tech Chris on Location. Bled THA Void. Flow Check Well. Remove Tree/THA. Cycle LDS. Cap Control Line. RKB to LDS = 26.35'. Begin NU BOPE. ***Continue WSR to 10/12/2024*** 10/12/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap Continue NU BOPE. Modify and install flow riser and air boots. Function test BOPE stack, and swap a couple hyd hoses for the BOPE stack. MU test equip and test jt. Fluid pack lines and purge all air. Test BOPE Per Sundry, 25/3250 psi, Annular 2500 psi. Tested gas alarm system all passed. Witness Waived by AOGCC Rep Austin McLeod. ***Job Continued to 10/13/2024*** 10/12/2024 T/I/O=0/0/0 Functioned swab and master to be sure there was no trapped psi, bleed void to 0 psi, N/D THA, cut and cap C/L, clean top of hanger, function and retorque each LDS 1 at a time, all were good, C/B 4-1/8", IN 3-1/2", M/U TC-II test sub to pressure test against H-TWCV to 3500/5 mins, pass, bleed off psi, install BX160, RKB from rig floor to upper LDS 26.35 10/13/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap Flow Check Well, Pull TWC. Thread in 4-1/2" TC II Landing Joint into Hanger, 8 RH turns. Rock out diesel FP. 10 bbl Neat Meth Spear down IA. 40 bbl of diesel diverted to Tiger Tank. Circulate 920 bbl down tubing taking returns from IA. No Flow Check. BOLDS. Pull tubing hanger (PUW = 110k). Begin LD 3-1/2" VamTop Completion. D1 KWT Drill with Crew. ***Job Continued to 10/14/2024 *** 10/13/2024 T/I/O = NA/0/NA RWO Pull Tubing Hanger Drain and rinse stack, clean out 4-1/2" TC-II lift thread profile, MU LJ, BOLDS, pull tubing hanger to the rig floor, LD tubing hanger and LJ. Daily Report of Well Operations PBU Z-32C 10/14/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap KWT Drill with Crew. Continue LD 3-1/2" Completion. LD total = 6 x GLMs, 2 x Nip's, 1 x NDPG-C Sapphire Gauge, 342 x 3-1/2" 9.3# L-80 VamTop R2 Jts., 3 x 3-1/2" 10' spacer pups. 351 Cannon Clamps Recovered, 14 half Clamps Recovered. 352 Cannon Clamps listed on Pipe Tally 12/2013. No Indication on the tubing or I-Wire of any missing clamps. Fly out Control line Spooler, 3 super sacks of clamps and McCoy Tongs. RU Slickline, RIH with 6.05" Gauge Ring. ***Job Continued to 10/15/2024 *** 10/14/2024 ***CDR2 RIG ASSIST*** RIG UP ***CONTINUE 10/15/24*** 10/15/2024 ***CONTINUE FROM 10/14/24*** RUN 6.10" GAUGE RING SET SCOOP GUIDE ON TBG STUB @ 11,125' SLM DRIFT TO TOP OF CEMENT w/ 2.70" CENT @ 11,344' SLM REVIEW EHS TOPIC - FALL PROTECTION - WSL ***CDR2 IN CONTROL OF WELL ON DEPARTURE*** 10/15/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap Set down with Gauge Ring 11125' SLM. Drift cut tubing end into Mule Shoe of Scoop Guide, good fit. RIH with NS Scoop Guide on GS. Removed 2 Shear Screws. Couldn't release from Scoop Guide, found GS had sheared but packed with metal shavings. Clean and re-run. 2 new shear screws installed. Scoop guide run #2 set successfully @ 11,125' SLM. RIH with 2.700'' Drift to 11,344'. RD SL. Work 3.5'' JFE Bear completion string in pipe shed. Tally set and approved by OE. Begin Running at 2300. ***Job Continued to 10/16/24*** 10/16/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap. ... Continue WSR from 10/15/2024... Continue running 3-1/2" JFE Bear completion. MU Tbg hanger and land completion. RILDS and test hanger seals to 500 psi. Pump corrosion inhibited 1% KCL followed with clean 1% KCL. ...Continue WSR on 10/17/2024... 10/16/2024 P/U LJ and TBG HGR, M/U to string, drain stack, RIH, Land at confirmed RKB of 26.35'. Verify landed through IA valve. RILDS, fill stack, close bag, test tbg hgr seals to 500 psi/5 min. Pass...cont 10/17.. 10/17/2024 Nabors CDR 2 / RWO / Z-32C, Tubing Swap. ... Continue WSR from 10/16/2024... Drop Wheeled R&B, Set HES TNT PKR, MIT-T TBG to 4500 psi (Pass). MIT-IA to 4000 psi (Pass). Shear SOV in top GLM Sta #5, Verify Circulation. Set 4" H-Type TWC. ND BOPE. NU THA & Tree, pressure test 500 psi Low/ 5000 psi High (Pass). Pull TWC and secure well. Rig Released. ***Job Complete*** P/U LJ and TBG HGR, M/U to string, drain stack, RIH, Land at confirmed RKB ofg 26.35'. Verify landed through IA valve. RILDS Daily Report of Well Operations PBU Z-32C 10/17/2024 S/B for circulate and set packer. Set 4" HTWC. S/B for BOP N/D. Clean void, inspect TBG HGR neck and lift threads. Fill void w/ test oil. Install new BX160. N/U tree. Test void to 500 psi 5 min/ 5,000 psi 30 min. with no loss. PASS/PASS. S/B for tree test. Pull 4" HTWC. 10/18/2024 T/I/O= (RWO EXPENSE) Freeze protected TxIA with 166 bbls of Diesel. U-Tubed for 1 hour. Freeze protected hardline with 2 bbls of 60/40. Pad Op notified of well status upon departure. Valve Positions - SV/MV= Closed, Hardline= Closed, IA/OA= OTG FWHPs= 370/370/62 10/18/2024 ***WELL S/I ON ARRIVAL*** (Rwo capital) RU POLLARD UNIT #60 ***CONTINUED ON 10/19/20 WSR*** 10/19/2024 ***CONTINUED FROM 10/18/24 WSR*** (Rwo capital) SET BAITED PULLING TOOL AS CATCHER ON BALL & ROD @ 8,919' MD PULLED DMY, AND SET FLOW SLEEVE IN STA #1 @ 8838' MD PULLED SOV, AND SET DMY IN STA #5 @ 3023' MD LRS CIRCED OUT 570 BBLS DIESEL PULLED FLOW SLEEVE & DGL'S FROM ST # 1 @ 8,838' MD, ST #4 @ 4,888' MD & ST # 5 @ 3,023' MD SET DGLV , OGLV & LGLV IN ST # 1 @ 8,838' MD, ST #4 @ 4,888' MD & ST #5 @ 3,023' MD MULTIPLE ATTEMPTS AT IA DDT. TBG TRACKING PULLED BAITED PULLING TOOL w/ BALL & ROD FROM 8,919' MD(piece of rubber in catcher) PULLED LGLV @ ST #5 3,023' MD. ***CONTINUED ON 10/20/24 WSR*** 10/19/2024 T/I/O= 505/503/65 ( RWO CAPITAL ) Pumped 570 bbls of Diesel down TBG, up IA, out to open-top tank. SL in control of well upon departure. FWHPs= 0/0/74 10/19/2024 T/I/O = 300/0/0 installed production tree torque to spec PT to 300 PSI and 5000 PSI test good RDMO FWP 300/0/0 10/20/2024 ***CONTINUED FROM 10/19/24 WSR*** (Rwo capital) SET RK-LGLV IN ST # 5 @ 3,023' MD FAILED IA DDT. PULLED & RE-SET RK-OGLV IN ST #4 @ 4,888' MD GOOD IA DDT PULLED RHC FROM 8,919' MD RAN 10' x 2-1/2" DUMMY PERF GUNS TO 9200' MD *** WELL LEFT S/I ON DEPARTURE *** Daily Report of Well Operations PBU Z-32C 10/23/2024 *** WELL S/I ON ARRIVAL*** (ADPERF) MIRU YELLOWJACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION WLVS PERFORATE 9094' - 9104' WITH 2.5" 6SPF 60PHASE HSC W/RAZOR CHARGES CCL TO TOP SHOT 9.3' CCL STOP DEPTH 9084.7'. CONFIRMED SHOTS FIRED PERFORATE 9084' - 9094' WITH 2.5" 6SPF 60PHASE HSC W/RAZOR CHARGES CCL TO TOP SHOT 9.3' CCL STOP DEPTH 9074.7'. CONFIRMED SHOTS FIRED PERFORATE 9074' - 9084' WITH 2.5" 6SPF 60PHASE HSC W/RAZOR CHARGES CCL TO TOP SHOT 9.3' CCL STOP DEPTH 9064.7'. CONFIRMED SHOTS FIRED ALL RUNS CORRELATED TO SLB MWD VISION LOG DATED 14 - DEC - 2013 RDMO YELLOWJACKET E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE PERFORATE 9094' - 9104' PERFORATE 9084' - 9094' PERFORATE 9074' - 9084' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 19 Township: 11N Range: 12E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 13,525 ft MD Lease No.: ADL0028262 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 130 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2668 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 5243 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 11428 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 13523 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 11279 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 11,425 ft 11,327 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result MIT-T Tubing 3290 3196 3167 IA 375 374 374 OA 93 90 91 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Reservoir plug. Required test pressure 3000psi. Pre-Test pressures for MIT-T: Tubing = 116psi; IA = 359psi; OA = 91psi. October 1, 2024 Brian Bixby Well Bore Plug & Abandonment PBU Z-23C Hilcorp North Slope LLC PTD 2131270; Sundry 324-482 none Test Data: P Casing Removal: Chad Kenyon Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1001_Plug_Verification_PBU_Z-23C_bb 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 999 9 9 9 9 9Required test pressure 3000psi MIT-T James B. Regg Digitally signed by James B. Regg Date: 2024.11.13 11:52:29 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 20240920 0853 COA Correction to tag plug with slickline - PTD 213-127 Sundry 324-482 - Z-32C Recomplete RWO Date:Friday, September 20, 2024 8:57:46 AM From: Rixse, Melvin G (OGC) Sent: Friday, September 20, 2024 8:56 AM To: Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: 20240920 0853 COA Correction to tag plug with slickline - PTD 213-127 Sundry 324-482 - Z- 32C Recomplete RWO Tyson, Coil tubing certainly preferred, but that was an incorrect comment I made. Hilcorp will NOT be required to rig up service coil for the tag. Hilcorp is approved to tag with slickline. Coiled tubing is not required. Please keep a record of this email available for AOGCC Inspectors so they know slickline tag is approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors, Torin Roschinger, Aras Worthington From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Friday, September 20, 2024 7:05 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Completed Sundry 324-482 - Z-32C Recomplete RWO is safe. Mel, Looking for some clarification on the approved sundry for the Z-32C Recomplete RWO. In the COA’s it is written in for “State to witness coiled tubing tag of TOC…”. Is there a specific reason this tag be done with coil instead of slickline as detailed in Step 1 under Slickline & Fullbore after the CIBP is set and cement placed on top? Thank you, Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, September 19, 2024 11:07 AM To: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Subject: FW: [EXTERNAL] Completed Sundry 324-482 - Z-32C Recomplete RWO Gents, See attached approved 10-403 for Z-32C Recomplete to Borealis RWO. Note conditions of approval and notes throughout program. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Thursday, September 19, 2024 10:56 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Casey Morse <casey.morse@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed Sundry 324-482 Hello, Attached is the completed Sundry for PBU Z-32C. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Z-32C Recomplete to Borealis Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-127 50-029-21924-03-00 341J / 471 ADL 0028245, 0028262, 0047450 13525 Conductor Surface Intermediate Liner Liner 8801 80 2632 5196 6345 1978 13439 20" 13-3/8" 9-5/8" 7" 3-1/2" 8821 50 - 130 49 - 2668 47 - 5243 5083 - 11428 11275 - 13523 2821 50 - 130 49 - 2668 47 - 4852 4739 - 8560 8438 - 8802 11900 2670 4760 5410 10530 None 5380 6870 7240 10160 11674 - 13427 3-1/2" 9.2# 13cr85 45 - 112798736 - 8823 Structural 3-1/2" HES TNT Packer No SSSV Installed 11171, 8354 Date: Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 9/10/2024 Current Pools: Prudhoe Oil Proposed Pools: Borealis Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:24 pm, Aug 21, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.21 12:57:38 - 08'00' Torin Roschinger (4662) 324-482 Isolate Ivishak X 10-404 MGR19SEP24 2821 * BOPE pressure test to 3250 psi. Annular to 2500 psi. * State to witness coiled tubing tag of TOC and pressure test to 3000 psi of reservoir abandonment plug. TOC to be minimum of 25' MD above the CIBP (11, 400' minimum MD). DSR-8/21/24 Perforate New Pool Recomplete to Borealisp SFD 9/18/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.19 10:32:03 -08'00'09/19/24 RBDMS JSB 092424 RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 Well Name:Z-32C Permit to Drill:213-127 Current Status:Operable, PAL API Number:50-029-21924-03 Estimated Start Date:September 2024 Estimated Duration:6days Regulatory Contact:Abbie Barker Rig:CDR2 First CallEngineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M) Program Revision:0 Current Bottom Hole Pressure:3,701 psi @ 8,800’ TVDss 8.09 ppge| SBHPS 2014 Max Anticipated Surface Pressure:2,821 psi Based on 0.1 psi/ft gas gradient Last SI WHP:2,400 psi 12/24/2023 Min ID:2.813” @ 2,010’ MD 3-1/2” X-nipple Max Angle:103 deg @ 13,425’ MD Brief Well Summary: Z-32C is an Ivishak producer sidetracked in December 2013. The well aimed to drill Zone 4 in a U-shape fashion to target oil-bea ring zones over an ~100’ vertical section between the gas contact and oil-water-contact. There was known risk around sweep in the targeted area and unfortunately, less oil filled sand than predicted was encountered. Between 2016 and 2023, five perf intervals were shot chasing oil lenses along the lateral. The final set of perforations shot in December 2023 have played out and the well is at marginal in the EWE sy stem and is forecasted to be shut-in within the coming month. No other downhole opportunities exist in the Ivishak. When Z-32C was originally drilled, it logged un-swept oil in the Kuparuk reservoir. Minimal injection has taken place in the ar ea (MI only) since 2013 so there is a strong case that the Kuparuk interval in this well is still oil filled. A RWO to pull the existing 3-1 /2” upper completion and run a new 3-1/2” upper completion with the production packer set above the Kuparuk is being proposed. A frac to stimulate th e Kuparuk formation will take place after the RWO. A separate sundry request will be submitted for the fracture stimulation. Objective: Isolate existing Ivishak perforations. Pull existing 3-1/2” tubing. Run new 13Cr, 3-1/2” completion with production packer set above the Kuparuk. Current Status: Operable PAL, online 8/7/2024 Test: 2 IOR, 89 bopd, 556 bwpd, 86% WC, 1.86mm Fgas, 0mm Lgas, 306 psi WHP, 119 deg F WHT, FOC Well Completion Information: Wellhead: McEvoy, 13-5/8” x 4-1/2” tubing hanger TC-II Top/Bottom with 4-1/2” x 3-1/2” TC-II x VamTop tubing pup joint Gauge Wire: Schluberger 1/4”I-wire 7” TOC: Top of cement at 5,083’ MD. 40% excess volume pumped. 28 bbls of excess cement circulated to surface on bottoms up post cement job. 3-1/2” TOC: Top of cement at 11,275’ MD. 30% excess volume pumped. 14 bbls of excess cement circulated to surface on bottoms up post cement job. Recent Integrity: ¾10/02/2022 – Warm TIFL PASSED ¾03/29/2022 – PPPOT-T PASSED ¾04/05/2018 – MIT-IA PASSED to 2,690 psi RWO Procedural Steps: Wellhead 1. PPPOT-T to 5,000 psi (PASSED 03/29/2022), PPPOT-IC to 3,500 psi (PPPOT-IC PASSED 05/03/2013 pre-sidetrack). 2. Function lockdown screws. Slickline & Fullbore 1. Pull live GLVs from ST#s 2, 3, 4, 5 & 6. 2. Replace with dummy valves except St #6. 3. Load IA with 1% KCl/Sewater and crude freeze protect. a. 3-1/2” x 9-5/8” Annulus Vol = 312 bbls b. 3-1/2” x 7” Annulus Vol to St# 2 = 141 bbls Station #2 (see attached email for corrections) - mgr RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 c.Total Annulus Volume = 453 bbls 4. Install dummy valve in St #6. 5. Load tubing with 1% KCL/Seawater and crude freeze protect. a.Tubing Volume to Top Perf = 102 bbls 6. Set plug in X-nipple at 11,264’ MD 7. Perform MIT-IA to 4,000 psi, 4,300 psi applied (confirm 7” x 9-5/8” casing integrity for future frac) a. Hold 2,000 psi of pressure on tubing. 8. Pull TTP. All subsequent work pending sundry approval E-Line & Fullbore 1. Load TBG with 1% KCl/Seawater and crude freeze protect. 2. Set CIBP at 11,630’ MD to isolate Ivishak perforations. a. Utilize PDS, Coil Flag, Dated 18-Dec-2016 for tie-in. 3. Pressure test bridge plug to 3,000 psi (non-AOGCC test). 4. Dump bail 25’ of cement on bridge plug. Slickline & Fullbore 1.AOGCC witnessed tag TOC and 3,000 psi pressure test of cement and CIBP. a. Give 24-hr notice to AOGCC prior to tagging and testing. E-Line & Fullbore 1. Mechanical cut tubing at 11,149’ MD. Targeting to cut middle of 15’ pup joint immediately below the gauge mandrel. Reference existing tubing tally. a. Cut should be below gauge mandrel and above production packer to help facilitate recovery of gauge wire and clamps during RWO. 2. Circulate out well to 1% KCl or equivalent (add Barakleen to brine to help clean pipe) with diesel freeze protect on tubing a nd IA. DHD 1. Bleed WHP’s to 0 psi. Valve Shop 1. Set and test TWC (Cameron Type H 4-1/16”) RWO 1. MIRU workover rig. 2. Nipple down tree and tubing head adapter. Inspect landing threads. 3. NU BOPE configuration top down: Annular, 2-7/8” x 5” VBRs, blind/shear rams and integral flow cross. 4. Test BOPE to 250 psi low / 3,250 psi high, annular to 250 psi low / 2,500 psi high, (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5” VBRs with 3-1/2” test joint. e. Test the annular with 3-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 5. RU and pull TWC. RU lubricator if pressure is expected. 6. RU control line spooler. 7. Rock out diesel freeze protect. 8. MU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up with 1% KCl. a. Expected PU weight in 8.4ppg KCl = 90k lbs b. Tensile strength of 3-1/2”, 9.2# = 207k lbs c. 3-1/2” VamTop Connection Strength = 207k lbs 9. Pull existing 3-1/2” tubing from cut. a. Drilling & Completion report indicates 366 clamps total were installed (352 full cross coupling clamps and 14 mid-joint clamps). Report clamp count in AWGRS. 10. RU Slickline and run ~6.1” gauge ring drift down to top of tubing stump at ~11,149’ MD. a. Confirm with RWO WSS how many clamps were recovered and if any are suspected to be left downhole. If clamps were left downhole, attempt to push clamps behind the 3-1/2” tubing stub x 7” intermediate liner or down inside the 3-1/2” tubing stub. TOC maximum depth less than or equal to 11,400' MD. - mgr Set CIBP 11,425' MD. (within PB confining zone) - mgr Station #2 - mgr RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 11. Set scoop guide on top of 3-1/2” tubing stub. RDMO Slickline. 12. Run 3-1/2” gas lifted tubing string as per draft tally. Confirm final tally with OE prior to running. a. Baker Lok connection below production packer. Torque turn connections. 13. Land hanger and reverse in corrosion inhibited 1% KCl or seawater. 14. Drop ball and rod and pressure up to set packer. 15. Perform MIT-T to 4,500 psi (higher test pressure to confirm integrity for subsequent frac). 16. Bleed off tubing pressure to 2,000 psi and MIT-IA to 4,000 psi for 30 charted minutes. 17. Bleed down IA to 2,500 psi after passing MIT-IA. 18. Once IA is bled down to 2,500 psi, bleed off tubing pressure to shear out valve in the top GLM. FP tubing and IA with diesel to 2,500’ MD. 19. Set TWC and ND BOPE. 20. NU tree and tubing head adapter. 21. Test both tree and tubing hanger void to 500 psi low / 5,000 psi high. 22. RDMO workover rig. Valve Shop 1. Pull TWC. Slickline 1. Pull shear-out valve, run KO GLV design. 2. Pull B&R and RHC profile. 3. Drift for 2.5” perforating guns. E-Line 1. Add Kuparukperforations from 9,074’ – 9,104’ MD with 2.5” perf guns. a. Use Z-32C reference log: SLB, MWD Log, Dated 14-Dec-2013 Portable Testers 1. Post RWO and perforation flowback. Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic x Tie-In Log for CIBP x BOP Schematic x Reference Log for Kuparuk Perforations x Sundry Revision Change Form Add Kuparukperforations from 9,074’ – 9,104’ MD RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 Current Wellbore Schematic: RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 Proposed Wellbore Schematic: 11,425' MD - mgr 11,400' MD - mgr RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 Tie-In Log for CIBP: RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 CIBP to be 11,425' MD per attached Email Tyson Shriver 9/18/2024 08:41 RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 CDR2 BOP Schematic: MASP < 3000 psi. - mgr RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 Reference Log for KuparukPerforations: RWO – Kuparuk UHRC Well: Z-32C PTD: 213-127 RWO – Kuparuk UHRCWell: Z-32CPTD: 213-127Sundry Revision Change Form:Changes to Approved Sundry ProcedureDate:Subject:Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDateProcedure ChangeHNSPreparedBy(Initials)HNSApprovedBy(Initials)AOGCC WrittenApprovalReceived (Personand Date)Approval:Operations Manager DatePrepared:Operations Engineer Date 1 Rixse, Melvin G (OGC) From:Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent:Wednesday, September 18, 2024 8:41 AM To:Rixse, Melvin G (OGC) Cc:Aras Worthington; Joseph Syzdek Subject:RE: [EXTERNAL] PBU Z-32C PTD 213-127 Sundry 324-482 Hello Mel, See my answers to your questions in “red” text. 1. On “Slickline & Fullbore” step 3: It appears like this is more of a lube and bleed then a circulation displacement. Wouldn’t you want to circulate through a deeper gas lift mandrel than station #6? (I may be missing something.) My apologies, in “Slickline & Fullbore” Steps 2 & 4 should read “St #2” NOT “St #6. My volume calculations in step 3 are correct for displacing gas from the inner annulus down to St #2. The last Ʋuid level shot on the inner annulus showed a liquid level at St #2. Displacing through St #2 will liquid pack the inner annulus for the subsequent MIT-IA. 2. On step 5: Is this a bullhead of KWF and freeze protect? (Just curious as to understanding the method of getting KWF and freeze protect on both tubing and IA.) Step 5 is purely being done to liquid pack the tubing so some amount of pressure can be held on this string during the MIT-IA performed in Step 7. A full circ out of both the tubing and IA to KWF and freeze protect will be done after the tubing has been mechanically cut. “E-Line & Fullbore” Step 2: Circulate out well to 1% KCl or equivalent (add Barakleen to brine to help clean pipe) with diesel freeze protect on tubing and IA. 3. I like to see the CIBP set in the PB Oil pool conƱning zones (generally, as near the base of the conƱning zones as possible). The regulations prescribing cement be: if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer does not truly assure that reservoir Ʋuids will remain in place for posterity after casing has corroded above the cement. I am assuming the 7” casing shoe is set at the top of the PB oil pool is that correct? If so, please propose a new depth for the CIBP and the dump bailed cement. You are correct, the 7” casing shoe is set at the top of the PB oil pool, 11,435’ MD (8,566’ TVD). Hilcorp is proposing to adjust the CIBP set depth to 11,425’ MD (8,558’ TVD) which is 10’ above the top of the PB oil pool. A total of 25’ of cement will then be dump bailed on top of the CIBP leaving the TOC at 11,400’ MD (8,538’ TVD). Please let me know if you have any other questions. Thank you, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, September 17, 2024 12:13 PM To: Tyson Shriver <Tyson.Shriver@hilcorp.com> Subject: [EXTERNAL] PBU Z-32C PTD 213-127 Sundry 324-482 Tyson, A few questions/clariƱcations for this RWO sundry: 1. On “Slickline & Fullbore” step 3: It appears like this is more of a lube and bleed then a circulation displacement. Wouldn’t you want to circulate through a deeper gas lift mandrel than station #6? (I may be missing something.) 2. On step 5: Is this a bullhead of KWF and freeze protect? (Just curious as to understanding the method of getting KWF and freeze protect on both tubing and IA.) 3. I like to see the CIBP set in the PB Oil pool conƱning zones (generally, as near the base of the conƱning zones as possible). The regulations prescribing cement be: if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer does not truly assure that reservoir Ʋuids will remain in place for posterity after casing has corroded above the cement. I am assuming the 7” casing shoe is set at the top of the PB oil pool is that correct? If so, please propose a new depth for the CIBP and the dump bailed cement. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-32C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-127 50-029-21924-03-00 13525 Conductor Surface Intermediate Liner Liner 8801 80 2632 5196 6345 1978 13439 20" 13-3/8" 9-5/8" 7" 3-1/2" 8821 50 - 130 49 - 2668 47 - 5243 5083 - 11428 11275 - 13523 50 - 130 49 - 2668 47 - 4852 4739 - 8560 8438 - 8802 11900 2670 4760 5410 10530 None 5380 6870 7240 10160 11674 - 13427 3-1/2" 9.2# 13cr85 45 - 11279 8736 - 8823 Structural 3-1/2" HES TNT Packer 11171, 8354 11171 8354 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028245, 0028262, 0047450 45 - 8441 N/A N/A 79 585 718 16603 368 1065 700 1400 278 430 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.09 14:46:19 -09'00' Torin Roschinger (4662) By Grace Christianson at 3:25 pm, Jan 09, 2024 DSR-1/26/24 RBDMS JSB 011124 WCB 2024-06-24 ACTIVITY DATE SUMMARY 12/22/2023 T/I/O=1500/1100/0 Temp=S/I (TFS UNIT 4 Pre-SlicklineTBG Freeze protect) Pumped 22 BBLS of crude down TBG for freeze protect. SL in control of well upon departure. Final WHPS= 1300/1100/0 12/22/2023 Freeze protect the Flowline for Slickline Pumped 9 BBLS 60/40 to Freeze Protect the Flowline. 12/22/2023 ****WELL FLOWING ON ARRIVAL*** (Perforating) DRIFT w/ 30'x2" DUMMY GUNS (2.16" swell rings) TO 11,809' SLM. ***WELL S/I ON DEPARTURE*** 12/23/2023 OBJECTIVE: PERF 81 FT INTERVAL 11671'-11752' W/ 2" GUNS 6SPF 60 DEG PHASING RIG UP YJ ELINE PT PCE 300 PSI LOW / 3000 PSI HIGH RIH W/1 11/16" GAMMA CCL/ 35' 2" 6SPF 60 DEG PHASING. SHOOT INTERVAL 11717'- 11752' (11720' - 11755' REFERENCE LOG DEPTHS) POOH SWITCHED GUN STRINGS PT 300/3000 RUNNING IN HOLE GAMMA CCL STOPPED WORKING POOH LAID DOWN TOOLS AND LUBRICATOR CONTINUE OPERATIONS TOMORROW. **** WELL SHUT IN WITH NIGHT CAP UPON DEPARTURE**** 12/24/2023 ***WELL SHUT IN UPON ARRIVAL*** INFORM PAD OP OF OUR RTN TO LOCATION RIG UP GAIN CONTROL 9/32' WL 1 11/16" GR/CCL W/35' GUN OF 2" MAXFORCE 6 SPF 60 DEG. PHASE STAB ON WELL PT 300 PSI LOW 3000 PSI HIGH TOOL FAILURE POOH ON SURFACE BLEED DOWN WELL LAYDOWN TOOLS SWITCH OUT TOOLS STAB ON WELL PT W/ QTS TO 3000 PS GAIN CONTROL 9/32" WL WB/2.75 " GR/CCL/35' GUN OF 2" MAXFORCE CHG 6 SPF 60 DEG PHASE. SHOOT INTERVAL 11682'-11717' (11685' - 11720' REFERENCE LOG DEPTH) STAB ON WELL PT W/ QTS TO 3000 PSI GAIN CONTROL 9/32" WL WB/2.75 " GR/CCL/11' GUN OF 2" MAXFORCE CHG 6 SPF 60 DEG PHASE. SHOOT INTERVAL 11671-11682' (11674' - 11685' REFERENCE LOG DEPTH) ON SURFACE SI SWAB BLEED OFF WELL LAYDOWN TOOLS BEGIN RD CINTACT PAD OP CLOSE PERMIT ***WELL SI UPON DEPARTURE*** Daily Report of Well Operations PBU Z-32C Adperfs are correctly shown on the new WBS, below. -WCB SHOOT INTERVAL 11717'- 11752' (11720' - 11755' REFERENCE LOG DEPTHS) SHOOT INTERVAL 11671-11682' (11674' - 11685' REFERENCE LOG DEPTH SHOOT INTERVAL 11682'-11717' (11685' - 11720' REFERENCE LOG DEPTH) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer Z-32C (PTD #2131270) TIFL passed post-OGLV changeout Date:Monday, October 3, 2022 2:55:14 PM Attachments:image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, October 3, 2022 6:26 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer Z-32C (PTD #2131270) TIFL passed post-OGLV changeout Mr. Regg, Slickline replaced the screened orifice on 09/29/22 and DHD performed a passing TIFL on 10/02/22. The passing TIFL indicates two competent well barriers and the well is now classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 26, 2022 6:27 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer Z-32C (PTD #2131270) IA over MOASP, failed TIFL Mr. Regg, Producer Z-32C (PTD # 2131270) was reported to have IA casing pressure above MOASP on 09/23/22. The pressure was 2280 psi. On 09/26/22 DHD performed a failing TIFL. The failing TIFL indicates a failure of a well barrier. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Slickline: Replace GLVs 2. DHD: TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer Z-32C (PTD #2131270) IA over MOASP, failed TIFL Date:Tuesday, September 27, 2022 10:47:12 AM Attachments:image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 26, 2022 6:27 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer Z-32C (PTD #2131270) IA over MOASP, failed TIFL Mr. Regg, Producer Z-32C (PTD # 2131270) was reported to have IA casing pressure above MOASP on 09/23/22. The pressure was 2280 psi. On 09/26/22 DHD performed a failing TIFL. The failing TIFL indicates a failure of a well barrier. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Slickline: Replace GLVs 2. DHD: TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Carlisle, Samantha J (OGC) From:Regg, James B (OGC) Sent:Monday, March 28, 2022 9:37 AM To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer Z-32C (PTD #2131270) sustained IA Pressure above MOASP, failed warm TIFL Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 28, 2022 8:16 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer Z‐32C (PTD #2131270) sustained IA Pressure above MOASP, failed warm TIFL Mr. Regg, Producer Z‐32C (PTD #2131270) was reported to have IA casing pressure above MOASP on 03/26/22 while the well was SI for E‐line perforating work. The IA pressure was reported to be 2,202 psi. On 03/28/22 DHD performed a failing warm TIFL indicating a failure in the primary well barrier. The well is now classified as UNDER EVALUATION and is on the 28‐ day clock for diagnostics. Plan forward: 1.Slickline: Replace screened orifice 2.DHD: TIFL 3.Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer Z-32C (PTD #2131270) passed TIFL post OGLV replacement Date:Monday, April 4, 2022 3:26:42 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, April 4, 2022 2:24 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Producer Z-32C (PTD #2131270) passed TIFL post OGLV replacement Mr. Regg, Producer Z-32C (PTD # 2131270) had the screened orifice replaced on 04/02/22 and DHD performed a passing warm TIFL on 04/03/22. The passing TIFL indicates two competent barriers to formation and the well is now classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 28, 2022 8:16 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer Z-32C (PTD #2131270) sustained IA Pressure above MOASP, failed warm TIFL Mr. Regg, Producer Z-32C (PTD #2131270) was reported to have IA casing pressure above MOASP on 03/26/22 while the well was SI for E-line perforating work. The IA pressure was reported to be 2,202 psi. On 03/28/22 DHD performed a failing warm TIFL indicating a failure in the primary well barrier. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Slickline: Replace screened orifice 2. DHD: TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. David Douglas Hilcorp North Slope Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 02/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL (23-FEB-2022) Folder Contents: Log Print Files, Reports and Digital Data Files: Well API #PTD #Log Company Log Date Log Type Notes: PBU L-207 50029237020000 221081 HALLIBURTON 1/12/2022 PPROF INCLUDES ANALYSIS PBU 04-51 50029235970000 218018 BAKER 11//24/2021 RPM INCLUDES ANALYSIS PBU 09-38 50029219190000 189021 BAKER 12/1/2021 RPM INCLUDES ANALYSIS PBU 09-39 50029221330000 191012 BAKER 12/6/2021 RPM INCLUDES ANALYSIS PBU 18-02C 50029207620300 213009 BAKER 11/25/2021 RPM INCLUDES ANALYSIS PBU 18-03C 50029207760300 211066 BAKER 11/26/2021 RPM INCLUDES ANALYSIS PBU 18-05A 50029215830100 202219 BAKER 12/8/2021 RPM INCLUDES ANALYSIS PBU Z-32C 50029219240300 213127 BAKER 12/10/2021 RPM INCLUDES ANALYSIS Please include current contact information if different from above. 213-127 T36375 PBU Z-32C 50029219240300 213127 BAKER 12/10/2021 RPM INCLUDES ANALYSIS Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.02.25 08:36:20 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-32C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-127 50-029-21924-03-00 13525 Conductor Surface Intermediate Liner Liner 8801 80 2632 5196 6345 1978 13439 20" 13-3/8" 9-5/8" 7" 3-1/2" 8821 50 - 130 49 - 2668 47 - 5243 5083 - 11428 11275 - 13523 50 - 130 49 - 2668 47 - 4852 4739 - 8560 8438 - 8802 11900 2670 4760 5410 10530 None 5380 6870 7240 10160 11791 - 13427 3-1/2" 9.2# 13cr85 45 - 11279 8797 - 8823 Structural 3-1/2" HES TNT Packer 11171 11171 8354 Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028245, 0028262, 0047450 No SSSV Installed 45 - 8441 8354 N/A N/A 26 70 1080 232 380 648 1255 1171 287 284 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 8:23 am, Nov 19, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.19 08:14:18 -09'00' Stan Golis (880) RBDMS HEW 11/19/2021 DSR-11/22/21SFD 11/29/2021MGR29DEC2021 ACTIVITY DATE SUMMARY 10/30/2021 **WELL S/I ON ARRIVAL** DRIFTED w/ 30'x2.5" DMY GUNS(2.78" OD) TO 11558'SLM (unable to work deeper) DRIFTED w/ 20'x2.5" DMY GUNS(2.78" OD) TO 11644'SLM (sd multiple times @ different depths) DRIFTED w/ 10'x2.5" DMY GUNS(2.78" OD) TO 11655'SLM (unable to work deeper) **WELL S/I ON DEPARTURE** 11/7/2021 ***WELL S/I ON ARRIVAL*** (perforating) RAN 3 1/2" BRUSH,2.75" GAUGE RING TO 11,860' SLM WHILE T-BIRD PUMPED 130 BBLS OF CRUDE RAN 20' x 2 1/2" DUMMY GUNS, SAT DOWN @ 11,730' SLM, UNABLE TO PASS W/ T-BIRD ASSISST RAN 10' x 2 1/2" DUMMY GUNS, STOP DUE TO DEVIATION @ 11,880' SLM W/O T-BIRD ASSIST. ***JOB COMPLETE, READY FOR E-LINE*** 11/7/2021 T/I/O= 2600/1650/0 TEMP= SI Assist Sline As Directed. Pumped 150 bbls of 120* crude down TBG while Sline Brushes. Sline in control of well upon departure Pad Op. notified of well status. CV's= OTG FWHP's= 1000/1700/0 11/14/2021 T/I/O = 1720/1700/20. Temp = SI. TBG FL (E-line request). AL SI @ casing valve (1700 psi). TBG FL @ 11828' (top perfs). E-line in control of valves upon departure. 09:20 11/14/2021 ***WELL SHUT IN ON ARRIVAL*** (Adperf) MIRU HES ELINE. LRS LOADED WELL WITH 110 BBLS CRUDE. RIH W/ 2.5" X 10' MILLENIUM GUN #1. PERFORATE INTERVAL 11811' - 11821'. RIH W/ 2.5" X 10' MILLENIUM GUN #2. PERFORATE INTERVAL 11801' - 11811'. LAY DOWN FOR THE NIGHT. ***CONTINUE JOB ON 11/15/21*** 11/14/2021 T/I/O=1600/1400/0 Assist E-line ( Perf ) Load tbg w/110 bbls crude FWHPs=700/1700/0 11/15/2021 ***JOB CONTINUED FROM 14-NOV-2021*** (HES E-Line Perforate) PERFORATE 11791' - 11801' w/ 2.5", 6 SPF, 60 DEG PHASE HSC W/ MILLENNIUM HMX CHARGES. ALL LOGS CORRELATED TO SLB GR/CCL PERFORATING RECORD DATED 2- FEB-2018. ***JOB COMPLETE ON 15-NOV-2021*** Daily Report of Well Operations PBU Z-32C 11811' - 11821' 11801' - 11811'. 11791' - 11801' 11811 SFD 11/29/2021 11/15/21 ,, STATE OF ALASKA RE , • ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPERA NS CEIVE{� Q 1. Operations Performed MAR 2 3 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate H Other Stimulate ❑ Alter Casing 0 ChaAO-GIGGI ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 213-127 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21924-03-00 7. Property Designation(Lease Number): ADL 047450 8. Well Name and Number: PBU Z-32C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13525 feet Plugs measured None feet true vertical 8801 feet Junk measured 11900 feet Effective Depth: measured 13439 feet Packer measured 11171 feet true vertical 8821 feet Packer true vertical 8354 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 50-130 50-130 1533 515 Surface 2632 13-3/8" 49-2681 49-2681 5380 2670 Intermediate 5196 9-5/8" 47-5243 47-4852 6870 4760 ' Liner 6345 • 7" 5084-11428 4740-8561 72d(3'"`" 5410 ' Liner 2248 3-1/2" 11275-13523 8437-8802 10159 10533 Perforation Depth: Measured depth: 11828-13427 feet True vertical depth: 8813-8823 feet SCANNED ,, Tubing(size,grade,measured and true vertical depth) 3-1/2",9.3#,13Cr85 45-11279 45-8441 Packers and SSSV(type,measured and 3-1/2"HES TNT Packer 11171 8354 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): �y Treatment descriptions including volumes used and final pressure: R,BDM � U 4 LU$ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 268 1183 192 1085 258 Subsequent to operation: No Test Available 2075 560 14.Attachments:(required per 20 AAC 25.070 25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development I J Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Iv7 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleum En.,4 er Contact Email: Cale.Peru@bp.com Authorized Signature: , ' Date: 3/2'91/� Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 1/77- 112471/t, Submit Original Only A i1/2r/41 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 22, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU Z-32C, PTD #213-127. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 22, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU Z-32C, PTD #213-127. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Daily Report of Well Operations PBU Z-32C ACTIVITYDATE SUMMARY ***JOB STARTED 15-SEP-2017*** (ELINE DRIFT/RPM) WELL FLOWING ON ARRIVAL. MIRU, SI WELL. INITIAL T/I/O = 1300/1200/0. MU TOOLS, SAFETY MEETING WITH WSL. FT WLVS, LPT/HPT= PASS. 9/15/2017 ***JOB CONTINUED 16-SEP-2017*** ***JOB CONTINUED FROM 15-SEP-2017*** (SLB ELINE DRIFT/RPM/PERF) RIH W/HEAD/ERS/EQF-46/ROLLERS/JAR/UPCT/ROLLERS/(3)2.5"x10' DUMMY GUNS/ROLLERS. OAL= 57'; MAX OD =2.7"; OAW=460 LBS. DRIFTED TO DEVIATION AT 11,893', 102'ABOVE TARGE DEPTH. POOH TO TRY LOADING THE WELL FOR A PUMP-DOWN. AT SURFACE DISCOVER THE BOTTOM TWO DUMMY GUNS & ROLLER STEM HAVE SWIVELLED OFF. ESTIMATED TOP OF FISH = 11893', OAL=25.05', OAW= 180 LBS, MAX O.D. =2.7", 1.375" FN. RDMO. WELL S/I ON DEPARTURE. FINAL T/I/O= 1600/1400/0 9/16/2017 ***JOB SUSPENDED AFTER FAILED DRIFT*** T/I/O= 1570/1460/0 Temp= S/I (LRS Unit 42-Assist Eline: Freeze Protect Tubing &Flowline) Pumped 2 bbls of 60/40 followed by 22 bbls of crude down TBG to freeze protect it due to E-Line tool still in hole. Pumped 8 bbls of 60/40 meth down flowline, had Pad-Op shut in inlet valve and pressured FL up to 1000 psi per Pad-OP. SV,WV,SSV= Closed IA.OA= Open to gauge MV=Open Hung FP tags 9/16/2017 FWHP= 1215/1460/0 ***WELL S/I ON ARRIVAL***(perforating). PULLED DUMMY GUN FISH FROM 11,817' SLM (2 pins on roller stem wobbled out and bent down) DRIFTED W/2.50" GAUGE RING &2-1/2" BRUSH TO DEVIATION @ 11,778' SLM DRIFTED W/30' x 2.50" DUMMY GUNS TO DOG LEGS @ 11,672' SLM (unable to get deeper) 9/24/2017 ***JOB IN PROGRESS, CONTINUED ON 09-25-17 WSR*** ***CONTINUED FROM 09-24-17***(perforating) DRIFTED W/20'x 2.50" DUMMY GUNS TO DOG LEGS @ 11,818' SLM DRIFTED W/ 10'x 2.50" DUMMY GUN TO DEVIATION @ 11,886' SLM (71*) 9/25/2017 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** ***WELL SHUT IN ON ARRIVAL***(Perforating) MIRU SWCP 4518 & LRS TO DRIFT FOR ELINE 11/17/2017 ***CONT. ON 11/18/17 WSR*** T/I/0=1901/1930/13 Temp=ambient. (LRS Unit 72-Assist Slickline: Pump Down Toolstring) Spot 11/17/2017 Unit, Rig Up.. ***job continued 11/18/2017*** ***WSR continued from 11/17/2017. (LRS Unit 72-Assist Slickline: Pump Toolstring) Pumped 11 bbls 60/40 meth to FP F/L. Pressured up to 1000 psi. Tag hung. Pumped 110 bbls of ambient crude to load TBG for SL. Pumped an additional 48 bbls crude to pump S-Line down Hole. S-Line on location upon departure 11/18/2017 FWHP=930/1690/10 ***CONT. FROM 11/17/17 WSR***(Perforating) RUN 3FT 1-7/8" R. STEM W/2.6"WHEELS, 20'x 2.50" DMY GUN, 3FT 1-7/8" R. STEM W/2.6" WHEELS, SD DUE TO DEVIATION@ 11,977' SLM TAKE CORRECTION OFF X NIPPLE @ 11,264' MD W/3-1/2"X CATCHER(11,233' SLM). RUN 3FT 1-7/8" R. STEM W/2.2"WHEELS, 20'x 2.0" DMY GUNS, 3FT 1-7/8" R. STEM W/2.2" WHEELS, SD DUE TO DEV @ 12,039' SLM (LRS ASSIST IN MAKING DEPTH AT 3 BPM). 11/18/2017 ***WELL TURNED OVER TO DSO*** WHP: Temp= S/I (LRS Unit 46-Assist Eline: RPM Log) Arrived to location, Standby for E.Line 2/26/2018 *****Job continued on 02/27/18****** - - i • Daily Report of Well Operations PBU Z-32C ***WELL FLOWING ON ARRIVAL*** (SLB ELINE- RPM/PERFORATE) INITIAL T/I/O =400/1300/100. MIRU SLB ELINE. 2/26/2018 ***JOB CONTINUED 27-FEBRUARY-2018*** ****Job continued from 02-27-18**** T/I/O= 1480/1267/13 Temp = S/I (LRS Unit 46-Assist Eline: RPM Log) Freeze Protect Flowline with 10 BBLS of 60/40. Pumped a total of 10 BBLS of 60/40 down TBG, and 609 BBLS of 1% KCL, and 20 BBLS of Crude. 2/27/2018 ****Job continued on 02-28-18**** ***JOB CONTINUED FROM 26-FEB-2018***(SLB ELINE- RPM/PERFORATE) FINISH R/U. LPT/HPT= PASS. LRS RU/PT, FP FLOW LINE, LOAD TBG W/ 150 BBL 1%KCL RIH W/MH22/ERS/SWIVEU2.58" ROLLER/1-11/16"X 5'WB(x2)/2.58" ROLLER/BKR RPM. OAL = 57'. OAW= 350 LBS. MAX OD =2.58". DEVIATE OUT @ 12070'. LRS PUMPING 0.5 BPM DURING LOG. LOG TWO SIGMA PASSES @ 10 FPM FROM 12070'TO 11320' LOG THREE C/O PASSES @ 2 FPM FROM 12070'TO 11650' LRS FP TBG W/20 BBL'S CRUDE AND 2 BBL'S DSL. 2/27/2018 ***JOB CONTINUED ON 28-FEB-2018*** ***JOB CONTINUED FROM 27-FEB-2018***(SLB ELINE- RPM/PERF) RUN 1: RIH W/20'X 2-1/2" POWERJET OMEGA HSD, 6 SPF, 60 DEG PHASE. PERFORATED INTERVAL= 11838'- 11858'. RUN 2: RIH W/ 10'X 2-1/2" POWERJET OMEGA HSD, 6 SPF, 60 DEG PHASE. LRS RELOAD TUBING W/ 125 BBL KCL, FP W/ 10 BBL CRUDE, 16 BBL, 60/40. PERFORATED INTERVAL= 11828'- 11838'. BOTH RUNS TIED INTO PDS COIL FLAG DATED 16-DEC-2016. LRS PERFORM INJECTIVITY TEST AND FP TBG. WELL S/I ON DEPARTURE. FINAL T/I/O= 800/1630/20 2/28/2018 ***JOB COMPLETE 28-FEB-2018*** Fluids Summary Bbls Type 81 60/40 Methanol/Water 225 Crude 4 Diesel 797 1% KCL TFC . aw4-1/8'5000 Wali EAD NCEVOY S ACTUATOR= HYDRAULIC PREVIOUS WELLBORES NOT SHOWN•** IVAL KB.ELE 91.5' I I *"CHROME TBG&LNR"• BF.ELEV= 54.95 KOP= 2889' ' ' 2010' —13-112"HES X W 0=2.813" H Max Angle= 1030 @ 13425 20"OO —110 Datum MD= 12226' Datum TVD= 8800'SS GAS LET MANDRaS 13-3/8°CSG,72#,L-80,D=12.347" —I 2668' ST M.) TVD DEV TY FE VLV LATCH PITT I TE 6 2985 2985 4 KG82 DONE INT 16 0 /04/17 9-5/8"X 7"BKR I-RD-E ZXPN PKR,D=6.140" —{ 5083' 5 5103 4753 45 KG82 DONE INT 16 0 /04/17 w/11"TE ACK SLV,D=7.360" 4 7783 5997 65 KGB2 DONE INT 16 0 /04/17 .7! 3 9456 6994 42 KGB2 DOW NT 16 0 /04/17 [9-5/8"X 7^BKR FLEX LOCK LM‘R HGR,D=6.200" H 6099' 7 2 10438 7762 36 KGB2 DOME NT 16 0 104/17 9-518"W-FSTOOC(11/27/13) H 5243' 4 . 1 11074 8276 36 KGB2 SO NT 24 0 /04/17 9-5/8"CSG,47#,NT-80S NSCC, —5243' ' .0732 bpf,D=8.681" .1 9-518'MLLOUT WINDOW(Z-32C) 5243'-5260' 4 1 4 , I 11110' —13-1/2"I-ES N?D x N =2.813" 114 Minimum ID =2.813" @ 2010' 411141' J3-1/2'NDPG SAPFHIREGAUGE,D=2.86r 3-1/2" HES X NIPPLE 4 �� 11171' _17"X 3-1/2"I-ES TMT PIR,El=2.949" ' 11201' y-3-1/2"I-ESX NP,D=2.813" "NOT BAKER-LOKED 4 11264' —3-12"HES XN�',D=2.813" 3-1/2"TBG,9.2#,13CR 86 VAM TOP, H 11265' 4 ' .0087 bpi,D=2.992" 4 11265' —13-1/2*X 4-12"XO,ID=2.99Y 4 11275' —7'X 5"BKR FRO-E ZXP LTP,D=4.350" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, — 11279' - �_ w/11'TESK,D=5.25" .0152 bpf,D=3.958" j!(( �r 1,-. *� 11279' --i4-112"VVLEG,ID=3.958" —ELM)IT NOT LOGGED 4 ♦4,40 41, V. 11298' —7'X 5"BKR FLEX-LOCK LIR HCP,D=4.300" I7"LNR,26#,L-80 VAMTOP,.0383 bpf.D=6.276" --I 11428'j : 1131 ' H5"X 3-1/2'XO BUSHWIG,D=2.890' . PERFORATION SUlANARY AI NI REF LOG:SLB VISION LOG 12/14/13 I ANGLE AT TOP FERE:66°(11828' II Note:Refer to Production DB for histo'mat per data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ lk, —11900' I--FSH:SHEAR RING LOST FROM 2-12" 6 11828-11858 0 02/28/18ill. __. STA#1 (01/03/17) 1 2" 6 11995-12020 0 04/08/14 2-12" 6 13175-13205 0 12/19/16 # '�'r 2" 6 13190-13220 0 02/13/14 2-12" 6 13270-13290 0 12/19/16 11* 2-12" 6 13290-13320 0 12/18/16 'M 2-1/2" 6 13351-13371 0 12/18/16 II 2-112" 6 13371-13401 0 12/17/16 2-1/2" 6 13397-13427 0 12/17/16 fv I► PBTD — 13439' .�,,��►► , 3-12"LM,9.2#,13CR-tib HY DRL 511, —I 13523' /61 06, .0087 bpf,D=2.992' DATE REV BY CONINBJTS DATE REV BY CONVENTS RU)HOE BAY UNT 04/17189 ALAI 1 FNITIAL COMPLETION '09/19/17 MS/JND SET FISH(09119/17) WELL: Z-32C 06131/93 SIDETRACK(Z-32A) 09/28/17_JGIJJND PULLED FISH(09/24/17) PERMT No:' 131270 04/25/9T N2E8 SIDETRACK ML(Z-32 6/811) 03/05/18 FOC JM)ADF ERRS(02/28/18) API No: 50-029-21924-03 12/19113 PKR 273_SI ETRACK(Z-32C) SIC 19,1-11N,R12E,713'FM.& 1253'PM. 01/12/17 CJNJND GLV CM&FISH(01/04/17) 02/20/17 JCf/JMJ ADPBIFS(12/17-19/16) BP Exploration(Alaska) • 21 3127 BA UGHES PRINT DISTRIBUTION LIST 2 8 1 7 1 a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 WELL NAME Z-32C 900 E.Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD PRUDHOE BAY UNIT to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D BHI DISTRICT Alaska LOG DATE February 27,2018 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizaresbhge.com TODAYS DATE April 25,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD ' FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX LOGS _ CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF F'KIN IS #OF COPIES #OF COPIES #OF rrCOPIES v v v L 1 BP North Slope. 0 1 1 0 LOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil 900 E.Benson Blvd. Y 0 2 Z O i a Anchorage,Alaska 99508 A I 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99501 3 ExxonMobil,Alaska 0 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 R E ``v E I V ED Anchorage,AK 99503 V 4 State of Alaska -AOGCC 0 1 1 , APR026 201$ Attn:Makana Bender 333 W.7th Ave,Suite 100 AOGCC Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 0 1 0 Attn:Garret Brown 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 **Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,1R2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Gerardo Cedillo TOTALS FOR THIS PAGE: 0 2 5 0 0 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 8, 2018 8:41 AM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK,OPS Prod Controllers;AK, OPS Well Pad Z;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Peru, Cale; Rupert,C. Ryan; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer Z-32C (PTD#2131270)Well barriers confirmed with passing MIT- IA All, Producer Z-32C(PTD#2131270)was made under evaluation on 3/11/18 for having sustained inner annulus casing pressure above NOL. On 4/5/18 slickline set dummy gas lift valves and performed a passing MIT-IA to 2,690psi. The passing pressure test confirms two competent well barriers have been restored. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 Sat4tan WO From: AK, GWO = Integrity Engineer Sent: Sunday, March 1 , • 8 3:58 PM To: AK, OPS EOC Specialists; A . GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; A , •. Prod Controllers; AK, OPS Well Pad Z; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEO • 'eru, Cale; Rupert, C. Ryan Cc: AK, GWO Completions Well Integrity; AK, GWO DHD - - rity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF '- 4 is Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Ja • i Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver -I •-I, Joshua; Worthington, 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, March 12, 2018 5:52 AM To: Regg,James B (DOA) Cc: Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer Z-32C (PTD#2131270) Sustained inner annulus casing pressure above NOL Attachments: Z-32C.pdf All, Producer Z-32C(PTD#2131270)was reported to have sustained inner annulus casing pressure above NOL on 3/8/18. The pressures were confirmed to be T/l/0=2540/2470/Opsi. The well passed a subsequent TIFL on 3/9/18 but later exceeded NOL a second time on 3/11/18. The IA repressurization above NOL indicated a loss of one or more barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 501001 Cell: 907-341-9068 WO 1 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI ION , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 213-127 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21924-03-00 7. Property Designation(Lease Number): ADL 0047450 8. Well Name and Number: PBU Z-32C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13525 feet Plugs measured feet RECEIVED true vertical 8801 feet Junk measured feet Effective Depth: measured 13439 feet Packer measured 11171 feet JAN 11 2017 true vertical 8821 feet Packer true vertical 8354.13 feet AOGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#A-53 50-130 50-130 1533 515 Surface 2632 13-3/8"72#L-80 49-2681 49-2681 4930 2670 Intermediate 5196 9-5/8"47#NT-80 47-5243 47-4852 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11995 12020 feet 13175-13190 feet 13190-13205 feet 13205-13220 feet 13270-13290 feet 13290-13320 feet 13351-13371 feet 13371-13397 feet 13397-13401 feet 13401-13427 feet True vertical depth: 8867-8873 feet feet 8874-8871 feet 8871-8868 feet 8868-8865 feet 8856-8852 feet 8852-8846 feet 8840-8835 feet 8835-8830 feet 8830-8829 feet 8829-8823 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#13Cr85 45-11279 45-8441 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAR 0 8 2017; 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: 91 0 192 1046 251 Subsequent to operation: 135 77 168 1197 266 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil I 1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A Phone +1 907 564 4424 Date 1/11/17 Form 10404 Revised 8/2015 //6 L JAN 2 5 2017 Submit Original Only • • a) ooc) oo O O Nin0 0 0 U co co co co O Ca NrCO CNA c O O O Nt C•1 MO (NCOCe) (OOOOO � N d' CO CO CO O I I I I O 1- CO M O It O V' CO CO cU .=• M cO (00 N d- M LON N rN � cY) cY) r- CCIC.) — 1 1 1 1 1 1 1 Z N LA O) cov = Q vco � v m H W O c� co ao co U Q J Z O M J co C o c9 • 0J *k � N =N (f) N N M RS LL v r - tt CO O U rn N a b N (V MIT cej CO M 4 NCOcn NI- NI- �O M O O vt ch co co N . N O (0 N I- I- LLI F- • 0 7) 00w • ww co Cau_ CeCertlYZ ZWWWW m ODF- ZZZ5 UZ J J J • Packers and SSV's Attachment PRUDHOE BAY UNIT Z-32C SW Name Type MD ND Depscription Z-32C PACKER 5094.55 4747.35 7" Baker ZXP Top Packer Z-32C TBG PACKER 11171.19 8354.13 3-1/2" HES TNT Packer Z-32C PACKER 11288.71 8448.67 5" Baker ZXP Top Packer * = b) au'i * 3 .o _ - a) 0 o .� 0 (.) i' _sc c E 'o_Q a) ac) z Q co �� f0 0 LO N = Y ca c CI w Ta 10 _J r a)• ° CO.5 r 0 (0 W Y -O N .- E - 0 3 C N cn > •U a) -9Q _0 c •Nca a) * a' to g L.6 N a) -0 Z O0 7 * Q L _ ?� > 0 -) •-•-• c M N * +. 0 _m -0 Q C o_ Ta O F- 0 N ate) _c a `n• 0_ co O Q Z N 0 O a) E N CO la ZZ w - S' t0a o .0 0 ) O 03 _1 Q o _= E ° ~ E N 0 � U) >- W m -) '= cc , -p 2 �.� - of m 0 Q Z N-O 00 O - m 0 0 M ate) LL CO F- al '+-. 0 -O a) 1- (OjQ M M C) Y _ -01 � Q O p ZD o N of —I � co cn co E m U C o = c' (DO Y c�i � V Z -, > U .� QO co i_ cn c cCC NF- 0tp. 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N 0I,- eD0 a CX a 't -C Q •N CO a Q 2 C Y ° o_ 3 3 a) I-- N 0 •-co C 'C N O O p O (') 0 my co m o N O o a o C c C c - = o o IZ N T ai, CD 7 aT O CO •C ++ C •cri m ' ,- N M C C 0 co r- U _ > -as •- 3 O N- 7 . a )O O tZ rn1astit ca a) - c t o E E o 2 m O O - FE N M (0= +. (`o p a 0 p g c) .0 -O C 3 3 -ccN\i • '"� c`i .6 0o Q § m v'°? v m a) 2 AD ..cE . , " a (oO E0 2 o 't � o o :a a Q N II 3 C .. .E - O M Qtco oa � 2v oCa� °I03 '' m O1XQ o 2 0 co N co cot _ 22a 3 o goao s ns -CO0 0 E (o3 ani C a ccn .5 cc O o 0 o.. o m O n c � s am wM a) wco aC CCC a°i 0 o `~ ° coa ~ '' CM o• M m o Z O U V ° a) Y E °O .1 co a C 0)M a •c Q ° QOaaO .. a, ca � .� � � u -in a) all M 2 N a°i o 'En c o 'C = - N to o m N N aa)) E a) G1 N ct � Q t vi «. rn ° a) �N ca c w s c cn a a a) = co o) O-'t 3 3 E .. CL H C a) co- ° Y o o C c a) X o o (o '3 a cn O (p C C 0 Q a) o a 0 c coa co 32Cs lE • wM °-p LL rn a) C a I- co N CO C 30 as O) o) 2 3 (p +- 7 .E Q o.N O O .*- m c oa cco O O o 6 o aa)) I � 6M - rn_C co QU c * = cn 3 O O a) Fe •3 = u) Qc� CO o° - f0a 3i° E * ° ° ° 2o O D N = p 0 �(M N 0) 2 0 0- t o)� S Y a Cl) N a ° M co •gym H = 0 3 .0 rn C N 't° (cum a) >i It 'c0 o _ Oc� rna- MY rn� U E o. ° `t CLCO 'to TN E Oc Q ,- -C as 0MoC a) • oca) °-m a) a) oat CM2 •` 3a 0 - a '3 o m oco0 O vo � m � >C co 03 0 D - a) c- = H O • a oa 2N ' 0 ai 0 w c - ai o 0.O co - , ° C Q 1'- N N C a) .- E c• J r V M � M N Q CO C � � d �,N auj ` �- •§ c r '•> N � C �-c 2 E ▪ Y rn I a) =I- M _• H QV a = 3 3O 2O0 m co w c .(1) 00 20 � O Y a o 0 0 o O a 3 o � 0 0 (C I- o mom `a) F- co rn0 - v = o« _o co " 2 QIz'ta * •- o c �- c -) co Tr 5 Ua2ocnro) .- m -I * O -) U �smcooa ncco : U oa rn� N rn: aI Omcnd CO CO CO r e--• .- a 0 0 N N N N ,- 1.0 CNI r. m to a0 N N N TREE= - GW4-1/8"5000 , WELLHEAD= MCEVOY Z-32 _32 C rill/SAFETY NOTES:W ELL ANGLE>-70°@ 11876' ACTUATOR= HYDRAULIC *PREVIOUS WELLBORES NOTSHOWN***I M L KB.ELE 91.5' I ( 'CHROM E TBG 8 LNR"** BF.ELEV= 54.95' 01 KOP= 2889' ' ' 2010' -i3-112"HES X NP,D=2.$13" Max Angle= 103°@ 13425' 20"CONDUCTOR ^110 Datum MD= 12226' Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,ID=12.347" H 2668' ST MD TVD DEV TYPE VLV LATCH FORT LATE 6 2985 2985 4 KGB2 DOME FIT 16 01/25/14 9-5/8"X 7"BKR HRD-E ZXPN PKR,D=6.140" —{ 5083' 5 5103 4753 45 KGB2 SO M 20 01/25/14 w/11"TEBACK SLV,D=7.360" _ 4 7783 5997 65 KGB2 DM( INT 0 12/18/13 3 9456 6994 42 KGB2 DMY NT 0 12/18113 9-5/8"X 7"BKR FLEX LOCK LNR HGR,17.)-=6.200" H 5099' 2 10438 7762 36 KGB2 DMY INT 0 12/18/13 9-5/8"WHIPSTOCK(11/27/13) J 5243' 1 11074 8276 36 KGB2 DMY INT 0 12/18/13 9-5/8"CSG,47#,NT-80S NSCC, — —5243' 0732 bpf,D=8.681" 9-5/8'MLLOUT WINDOW(Z-32C) 5243'-5260' 11110'•-13-1/2"HES X NP,D=2.813" Minimum ID =2.813" @ 2010' 11141' ____I 3-1/2"NDPG SAPPHIRE GAUGE,D=2.867" 3-1/2" HES X NIPPLE 11171 JJ 7-X 3-1/2"HES TNT PKR,D=2.949" 11201' —3-1/2"HES XNP,D=2.813" 'NOT BAKER-LOKED I ' 11264' —13-1/2"HES X NP,D=2.813" 3-1/2"TBG,9.2#,13CR 85 VAM TOP, H 11265' 11265' —13-10"X 4-1/2"X0,113=2.992" .0087 bpf,D=2.992" 11275' —7'X 5"BKR HRD-E ZXP LTP,D=4.350" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 11279' '`r, .*, w/11'TEBK,D=5.25" 0152 bpf,ID=3.958" ) 11279' H4-1/2"WLEG,D=3.958" H ELMD TT NOT LOGGED 4 11298'JH 7'X 5"BKR FLEX-LOCK LNR HGR,D=4.300" 7"LNR,26#,L-80 VAMTOP,.0383 bpf.D=6.276" H 11428' 11308'J-15"X 3-1/2"XO BUSHING,D=2.890' PERFORATION SUI MARY REF LOG:SLB VISION LOG 12/14/13 ANGLE AT TOP PERF:75°@ 11995' ' Note:Refer to Production DB for historical per data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 11995-12020 0 04/08/14 2" 6 13190-13220 0 02/13/14 1 PBTD - 13439' 3-1/2"LNR,9.2#,13CR-85 HYDRL 511, J 13523' .0087 bpf,ID=2.992" [SATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/17/89 AUDI 1 INTIAL COMPLETION 01!31/14 JG/JMD GLV CIO(01/25/14) WELL: Z-32C 08/31/93 SIDETRACK(Z-32A) 02/17/14 SET/JMD ADPERFS(02/13/14) PERMT No: 2131270 04/25/97 N2ES SIDETRACK ML(Z-32 B/BL1) 04/09/14 GW/JMD ADPERFS(04/08/14) API No: 50-029-21924-03 12/19/13 PKR 273 SIDETRACK(Z-32C) SEC 19,T11N,,R12E,713'FNL 8 1253'FWL 12/23/13 JMD DRLG HD CORRECTIONS 01/02/14 JUJMD FINAL ODE APPROVAL BP Exploration(Alaska)