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Home My WebLink About217-176MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-10A PRUDHOE BAY UNIT 03-10A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 03-10A 50-029-20361-01-00 217-176-0 G SPT 8034 2171760 2008 2937 2940 2941 2937 9 9 9 9 4YRTST P Austin McLeod 7/18/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-10A Inspection Date: Tubing OA Packer Depth 106 2303 2262 2250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220718183130 BBL Pumped:4.2 BBL Returned:4.2 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:19:51 -08'00' Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:217-176 6.50-029-20361-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10422 10386 8657 8399 , 8567 none none 7667 , 8034 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37 - 117 37 - 117 1530 520 Surface 2701 13-3/8" 36 - 2737 36 - 2737 5380 2670 Intermediate 9033 9-5/8" 34 - 9067 34 - 8533 6870 / 8150 4760 / 5080 Liner 535 7" 8745 - 9280 8212 - 8746 8160 7020 Perforation Depth: Measured depth: 9535 - 10382 feet True vertical depth:8965 - 8659 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-12" 12.6# L-80 32 - 8854 32 - 8321 8399 , 8567 7867 , 8034Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker S-3 , 5-1/2" Otis RH Liner 1982 3-1/2" x 3-1/4" x 2- 8440 - 10422 7908 - 8637 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 149110085360 114620 73 0 0 1331 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8637 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028327 PBU 03-10A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:09 am, Jan 28, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.28 07:35:34 -09'00' Bo York MGR18FEB2021 RBDMS HEW 1/29/2021 SFD 1/28/2021DSR-1/28/21 ACTIVITYDATE SUMMARY 1/9/2021 T/I/O=0/0/0 Assist E-Line (Add Perfs) Pump 5 bbls 60/40, 90 bbls 1% kcl w/safelube to assist e-line down hole with guns. Pump 2 bbls neat & 3 bbls 60/40 to freeze protect surface equipment while e-line POOH. Pump 3 bbls 60/40 as e-line neared surface. Pump 2 bbls 60/40 & 58 bbls 1% kcl w/safelube to assist e-line down hole with guns. Pump 2 bbls neat & 58 bbls crude to freeze protect for the night. (Job to continue tomorrow morning) FWHPs=800/0/0 1/9/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line Perforating) PERFORATE 9760' - 9775' W/ 2", 6 SPF, 60 DEG PHASE, MAXFORCE GUN. PERFORATE 9699' - 9730' W/ 2", 6 SPF, 60 DEG PHASE, MAXFORCE GUN. LRS ASSISTED PUMP DOWN AT 2 BPM. ***JOB CONTINUED ON 10-JAN-2021*** 1/10/2021 ***JOB CONTINUED FROM 09-JAN-2021*** (HES E-Line Perforating) PERFORATE 9670' - 9701' W/ 2", 6 SPF, 60 DEG PHASE, MAXFORCE GUN. PERFORATE 9535' - 9566' W/ 2", 6 SPF, 60 DEG PHASE, MAXFORCE GUN. ALL LOGS CORRELATED TO SLB CBL LOG DATED 08-MAY-2018. LRS ASSISTED PUMP DOWN AT 2 BPM. ***JOB COMPLETE ON 10-JAN-2021*** 1/10/2021 Assist ELine (PERFORATING) Pumped 5 bbls 60/40 meth, 138 bbls 120* 1% KCL w/ safelube and 60 bbls crude down Tbg to assist ELine. ELine in control of well per LRS departure. IA,OA=OTG Daily Report of Well Operations PBU 03-10A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nr-ULIVED IAN no 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations ;gli _ ❑ El ❑ Perforate Other Stimulate 0 Alter Casing 11 Change Apfip.•rr►►IBf (t/� � Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mud Acid, HPBD m 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number 217-176 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 21 1 6. API Number: 50-029-20361-01-00 7. Property Designation (Lease Number): ADL 028327 S. Well Name and Number: PBU 03.10A 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 10422 feet Plugs measured None feet true vertical 8637 feet Junk measured None feet Effective Depth: measured 10386 feet Packer measured 8399, 8567 feet true vertical 8657 feet Packer true vertical 7667, 8034 feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37-117 37-117 1530 520 Surface 2701 13-3/8" 36-2737 36-2737 4930 2670 Intermediate 9033 9-5/8" 34-9067 34-8533 6870/8150 4760 / 5080 Liner 535 7" 8745-9280 8212-8746 8160 7020 Liner 1982 3-1/2" x 3-1/4" x 2-7/8" 8440-10422 7908-8637 Perforation Depth. Measured depth. 10231 - 10382 feet True vertical depth'. 8743-8659 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6#, L-80 32-8854 32-8321 5-1/2" Baker S-3 Packer 8399 7867 Packers and SSSV (type, measured and 5-112" Otis RH Packer 8567 8034 true vertical depth) 5-1/2" MCX SSSV 1994 1994 12. Stimulation or cement squeeze summary: Park above TOL Perform Injectivi fy Test with Diesel. At Bag, circulate NH4CI and first HCL stage. Close choke & pump Acid Stim per program reciprocating across parts. Pull above TOL and perform Injectivity test. Over flush with 426 bbls of NH4CL. Tubing left with a column of diesel. Pooh. Intervals treated (measured): 10231 - 10382 Treatment desonptions including volumes used and final pressure: 456 bbls of 3% NH4CI +F103, 46 bbls of 12% HCI, 46 bbls of 9:1 Mud Acid, 5 bbls of OilSeeker, 55 bbls of Diesel. Final Pressures: OA = 0 psi, IA = 0 PSI, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1398 0 0 0 Subsequent to operation: 0 12635 0 0 0 14. Attachments: (required par20 MC 25.070,25.07, a 25.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development ❑ Service 71 Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-329 Authorized Name: Shriver, Tyson Contact Name: Shiiver, Tyson Authorized Tide: Well Intervention Engineer Contact Email: Tyson.Shnver0Mbp.com Authorized Signature: Date: / Contact Phone: +1 9075644133 Form 10.404 Revised 04/2017 At&SLZQK0`1/ RBDMS %A 16 N A n 2019 ��/ Y Submit Original Only Daily Report of Well Operations PBU 03-10A ACTIVITYr1ATF RI IMMARY CTU#8 1.75" CT Job Scope: Acid Stim / Cont Perf MIRU CTU. Standby for Sib pump crew. 12/13/2018 ***Continue Job on 12/14/18 WSR*** CTU#8 1.75" CT Job Scope: Acid Stim / Cont Perf MU & RIH w/ 2.0" JSN. Tag PBTD at 10393' down / 10389' up. Flag pipe at 10385'. Slowly puh & circulate warm 1 % KCL w/ Safelube. Pull heavy at 10230' and become detained. Circulate btms up with safelube. Work pipe to get free. Pooh and inspect injector. Gripper blocks and chains packed with a thick tar substance. Swap out gripper blocks with new from the sib shop, wipe down/inspect chains & change packoffs. 12/14/2018 ***Continue on 12/15/18*** CTU#8 1.75" CT. Job Scope: Acid Stim / Cont Perf MU & Rih w/ Slim BHA w/ 1.75" JSN. Jet Hot Diesel while RIH. Jet down to flag -5' off TD. Reciprocate across perfs jetting diesel. Circulate btms up with diesel. Park above TOL Perform Injectivity Test with Diesel. Pump 0.5bpm until Whp reached 1900psi then shut down. Whp slowly bleeds down, unable to continuously pump. Release LRS & rig up Sib Pumpers. At flag, circulate NH4CI and first HCL stage. Close choke & pump Acid Stim per program reciprocating across perfs. Pull above TOL and perform Injectivity test w/ NH4CL for 10 mins each: 0.5 bpm @ 820 psi, 1 bpm @ 1358 psi, 1.5 bpm @ 1536 psi, 1.8 bpm @ 1657 psi. Over flush with 426 bbls of NH4CL. Tubing left with a column of diesel. Pooh. 12/15/2018 ***Continued on 12/16/18*** CTU#8 1.75" CT Job Scope: Acid Stim / Cont Perf Pooh. LD tools. Change packoffs. RDMOL 12/16/2018 **Job Com lete** ***WELL SA ON ARRIVAL SWCP 4518***(acid) DRIFT W/ 5-1/2" BRUSH & 4.50" G -RING TO X -NIP @ 1981' SLM(1994' MD). SET 5-1/2" MCX(ser#=BP-10, 1" bean) @ 1981' SLM(1994' MD). RAN 5-1/2" CHECK SET TO MCX @ 1981' SLM(1994' MD) GOOD SET. 12/18/2018 —WELL LEFT S/I ON DEPARTURE*** IWE-LHEAD= FMC ACTUATOR= CWSHBOOSTER Off. ELEV = 64' REF ELEV = B4' BF. ELEV = -- 27.77- KOP= 4100' Mm Angie = 126° @ 9906 Datum MD= 9401' Datum TVD= 8800'SS 9-5/8'CSG,1390 L-80 HYD563, 9-5/8" BOWER 1390' EXT CSG PATCH W. L-80 HY D 563 XO TO L-80 TCA 1964' 'CSG, 720, L-80 BTC, D=12.347" 2731' Minimum ID = 2.377" o@ 9410' 3-3116" X 2-7/8" XO TOPOF 3-12" X 3-1/4" X 2-7/8' LNR 5-12' TBG, 17#, L-80 TCI, .0232 bpf, D = 4.892" 5-1/2' 5-112' TBGPC, 17#, L-80..0232 bpf. D = 4.892- TOP OF 7"LNR 4-12' TBG, 12.6#. L-80 BTC, .0152 bpf, D = 3.958' PST TOC 9-5/8" CSG, 47#,N-80, D = 8.681" 3-12' LNR, 9.3#, 13CR-85 STL, .0087 bpf, D = 2 992' 7- LNR. 29#, L-80,.0371 bpf, D = 6.164' 6.6#, 13CR-85 TCI 1, .0079 bpf, D = 2J 2-7/8' LNR, 6.5#, 13CR-85 STUL-80 STL, .0058 bpf, D = 2-441' SAFETY NOTES: WS READINGS AVERAGE 125 03-1 OA ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Ml. WELL ANGLE> 70" @ 9594'. MAX DLS:32A' @ 9755'. -CHROME LNR'•• 1 2338' 1 1 8387' 1 15-12" FB X NP, D = 4.562' 1 9-5/8" LOWER FOC 5-12' HS X NP. ID = 4.567 HES X NP, D = 4.562' B44'-13.70' DEPLOYMENT SLEEVE, D= 3.00' 8466' 3-12" X NP, D=2.812' 8473' PERFORATION SLU ARY OOWAENTS FEF LOG: BKR MAO ON 0228118 6609' ANGLE AT TOP PERF: 124° 0 10231' NDte: Refer to Production DB for his@Drical pert data SIZE SPF INTERVAL OpmW DATE SOZ 2• 6 10231-10251 O 05/10/18 06/06/18 2' 6 10255 - 10283 O 05/09/18 KR'JkD TREE C(O(09/23/18) 2" 6 10329 - 10346 O05/09/18 03/07118 2' 6 10350-10382 O 05/09/18 2-7/8' LNR, 6.5#, 13CR-85 STUL-80 STL, .0058 bpf, D = 2-441' SAFETY NOTES: WS READINGS AVERAGE 125 03-1 OA ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Ml. WELL ANGLE> 70" @ 9594'. MAX DLS:32A' @ 9755'. -CHROME LNR'•• 1 2338' 1 1 8387' 1 15-12" FB X NP, D = 4.562' 1 9-5/8" LOWER FOC 5-12' HS X NP. ID = 4.567 HES X NP, D = 4.562' B44'-13.70' DEPLOYMENT SLEEVE, D= 3.00' 8466' 3-12" X NP, D=2.812' 8473' 5-12' FES XN NIP, D = 4.455' BMND OOWAENTS CUM 6609' 9-5/8' X 5-1/2' UNIQUE OVERSHOT 8636' 5-12' OTIS SBR ASSY, 6661' 9-5/8"X 5-1/2' OTIS Po -1 PKR, D = 4.734' 8666' 5-12' X 4-12" XO, D = 3.958' B746' 9-5/8" X 7" BOT LNR HGR D = ? I 6804- —14-12" OTIS X NP, OJ = 3.813" 1 BEHIND 8849• 4-1/r TT WLEG, D= 3.958• 1 CT LNR 8837' H ELMD TIFLOGO 09/18/86 9162' TOP 7' MKR JOM 917V BOTTOM 7' MKR JOINT MLLOUT WINDOW (0340A) 9280' - 9287' 9410' 3-3/16' X 2-7/8' XO, D = 2.377' DATE REV BY OOWAENTS DATE REV BY COMyBRTS 09107779 R36 ORIGINAL COMPLEnON 03/12/18 RCJJND FNALOOEAPPRDVAL 07127/86 WW1 RWO 05114/18 JCF/JMD INITIAL PERFS 04/04/93 N28E RWO 06/06/18 JNUJMD ADDED REF 8 BF E_EV 04105/08 N4FS RWO 09127/18 KR'JkD TREE C(O(09/23/18) 03/01118 N-CDR2 CTDST(03-1(kA) 03/07118 JAD DRLG HO CORRECPIONS PRDHOE BAY UGIT WELL 03-IQA PE1MT No 217-176 AR ND: 50-029-20361-01 SEC 11, T1 OR R15F 2134' FSL 8 638' FWL RP Ekploration (Alaska)