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Home My WebLink About181-180Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250813 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 24-06RD 50133204990100 206013 4/2/2025 YELLOWJACKET GPT-PERF MPB-24 50029226420000 196009 7/9/2025 READ CaliperSurvey MPB-34 50029235690000 216139 7/7/2025 READ CaliperSurvey MPF-45 50029225560000 195058 7/30/2025 READ CaliperSurvey ODSK-41 50703205850000 208147 8/9/2025 READ CaliperSurvey ODSN-25 50703206560000 212030 6/22/2025 READ CaliperSurvey ODSN-31 50703205650000 208003 8/11/2025 READ CaliperSurvey PBU 06-11A 50029204280100 225042 7/13/2025 BAKER MRPM PBU 13-19 50029206900000 181180 6/4/2025 HALLIBURTON WFL-TMD3D PBU 14-18C 50029205510300 225040 6/24/2025 BAKER MRPM PBU 14-43A 50029222960100 225041 7/30/2025 BAKER MRPM PBU C-01B 50029201210200 212053 7/19/2025 BAKER MRPM SD-07 50133205940000 211050 7/27/2025 YELLOWJACKET SCBL SP 12-S3 50629235130000 214067 7/18/2025 YELLOWJACKET PERF Please include current contact information if different from above. T40771 T40772 T40773 T40774 T40775 T40776 T40777 T40778 T40779 T40780 T40781 T40782 T40783 T40784 PBU 13-19 50029206900000 181180 6/4/2025 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.15 10:11:56 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 13-19 50-029-20690-00-00 181-180-0 W SPT 8338 1811800 2250 985 983 982 982 39 97 97 96 OTHER P Bob Noble 6/5/2025 2 yeaar MIT-IA to 2250 psi per CO 736 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 13-19 Inspection Date: Tubing OA Packer Depth 214 2494 2401 2371IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250616213454 BBL Pumped:3.1 BBL Returned:2.8 Thursday, July 24, 2025 Page 1 of 1           IA remedial cement   MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 13-19 50-029-20690-00-00 181-180-0 N SPT 8338 1811800 2250 483 2498 2429 2405 0 0 0 0 REQVAR P Adam Earl 5/12/2025 MIT-T tested as per CO 736 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 13-19 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250514073305 BBL Pumped:2 BBL Returned:2 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 ,QMHFWRU,$UHPHGLDOFHPHQW James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 15:36:09 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/19/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230719 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 07-20C 50029209020300 218036 6/8/2023 HALLIBURTON RBT PBU 13-19 50029206900000 181180 6/8/232 HALLIBURTON WFL-RMT3D PBU 18-29C 50029223160300 209055 6/13/2023 HALLIBURTON CAST-CBL PBU L-213 50029233080000 206053 6/12/2023 HALLIBURTON IPROF PBU M-205 50029237330000 222127 6/6/2023 HALLIBURTON IPROF PBU S-17c 50029211480300 202007 5/29/2023 HALLIBURTON RBT Please include current contact information if different from above. T37859 T37860 T37861 T37862 T37863 T37864 PBU 13-19 50029206900000 181180 6/8/232 HALLIBURTON WFL-RMT3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.19 13:22:09 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 13-19 50-029-20690-00-00 181-180-0 W SPT 8338 1811800 2250 1063 1063 1061 1055 472 689 680 672 OTHER P Kam StJohn 6/3/2023 2 Year MIT-IA per CO 736 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 13-19 Inspection Date: Tubing OA Packer Depth 288 2499 2354 2326IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230603104026 BBL Pumped:2.9 BBL Returned:2.7 Tuesday, July 25, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 :$*LQMHFWRU,$UHPHGLDOFHPHQW 9 9 2 Year MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 11:42:02 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 13-19 50-029-20690-00-00 181-180-0 N SPT 8338 1811800 2084 163 2505 2427 2392 0 0 0 0 REQVAR P Guy Cook 5/19/2023 2 year MIT-T per CO 736. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 13-19 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230519111711 BBL Pumped:2 BBL Returned:2 Friday, June 16, 2023 Page 1 of 1          WAG injector; IA remedial cement    MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 7, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Src: Inspector Reviewed By:/ P.I. Supry J Comm Well Name PRUDHOE BAY UNIT 13-19 API Well Number 50-029-20690-00-00 Inspector Name: Austin McLeod Permit Number: 181-180-0 Inspection Date: 6/13/2021 Insp Num: mitSAM210613193240 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I3-19 - 'Type Ind W - TVD 8338 'Tubing' 953 946 947 947 PTD 1811800 Type Test SPT 'Test psi 2084 IA 72 2343 2240 2214 ' BBL Pumped: 2.2-11313L Returned: 2.2 OA 166 221 221 _ 219 Interval OTHER - p/F P - Notes: MITIA. 2 year. CO 736. IA cemented above packer. Wednesday, July 7, 2021 Page I of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:181-180 6.50-029-20690-00-00 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 10246 9100 8378 9058 9696 8338 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 38 - 118 38 - 118 1490 470 Surface 2434 13-3/8" 38 - 2472 38 - 2472 5380 2670 Intermediate 9403 9-5/8" 36 - 9439 36 - 8695 6870 / 8150 4760 / 5080 Production Perforation Depth: Measured depth: 9460 - 9778 feet True vertical depth:8715 - 9012 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-1/2" 12.6#34 - 9131 34 - 8407 9058 8338Packers and SSSV (type, measured and true vertical depth) 5-1/2" BOT 3-H Packer Liner 1123 7" 9116 - 10239 8392 - 9442 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 055100 56760 566 0 0 863 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: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4763 Treatment descriptions including volumes used and final pressure: 13. Sr 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 measured9448 Sundry Number or N/A if C.O. Exempt: 319-426 Junk Packer Printed and Electronic Fracture Stimulation Data 5 IA Squeeze Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028315, ADL 0028311 PBU 13-19 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 9:18 am, Jun 22, 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: 2021.06.21 15:29:33 -08'00' Bo York RBDMS HEW 6/28/2021DSR-6/24/21MGR30JUL2021 SFD 6/23/2021 ACTIVITYDATE SUMMARY 2/22/2020 ***WELL S/I ON ARRIVAL*** (Pull Plug) RIG UP HES UNIT 046 ***CONT JOB ON 2/23/20 WSR*** 2/23/2020 ***CONT JOB FROM 2/22/20 WSR*** PULLED PRONG FROM DB LOCK @ 9079' SLM PULLED DB PLUG FROM DB-5 NIP @ 9100' MD DRIFTED TO 9069' MD FOR CBP W/ (x2) 4.50" CENTRALIZERS DRIFTED TO HEX PLUG @ 9696' MD W/ 3.80" CENT, 3" SAMPLE BAILER (no return) ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 10/1/2020 ...Well shut in on arrival... (HES Eline - CBP, Punch, Retainer) SET HES 5-1/2" OBSIDIAN CBP AT 9,000'. PUNCH TUBING FROM 8,990' - 8,995' WITH 5' x 2" 4SPF 0 PHASE HSC. ...Well shut in overnight, will return in the morning... 10/1/2020 T/I/O= 100/525/0. LRS unit 72 Assist E-Line (CEMENT SQUEEZE) Pressure test plug to 2500 psi. *PASSED* at 2469 psi. Lost 40 psi during the 5 minute test. Sharp TP drop with rapid IAP increase confirm punch hole communication. Final T/I/O= 500/1000/0 10/2/2020 T/I/O= 380/490/0. LRS unit 72 Assist E-Line (CEMENT SQUEEZE). Circ well to tanks. Pumped 630 bbls of 34* F diesel into the TBG while taking IA returns to tanks. No losses were noted during circ out. FWHPs=10/520/0 10/2/2020 ...Continued from 01-OCT-20... (HES Eline - Set Cement Retainer, IA cement job) LRS CIRCULATED THE WELL TO DIESEL. SET NORTHERN SOLUTIONS 5-1/2" MAGNUM POPPET STYLE CEMENT RETAINER AT 8,979'. ***Job Complete.*** Well shut in on departure. 10/16/2020 HES Cementing Services Objective: IA cement squeeze. HES pumped the following down the tbg taking returns from the IA, 3 bbls of 60/40, 10 bbls of surfactant wash and mutual solvent, 222 bbls of 15.8 ppg Class G cement, 2 bbl of fresh water. Launch 2.125" phenalic ball & (2) 7" foam wiper balls, 5 bbs of fresh water. Chase cement with 203 bbls of diesel when ball landed on seat. Attempt to bleed tubing pressure but appears poppet may be washed out. Trap 2000 psi on tubing.. Grease crew service tree. RDMOL EST TOC in IA: Top= 4078'' Bottom = 8995' 12/21/2020 T/I/O = 1020/Vac/0. Temp = SI. TBG & IA FL (OE request). TBG FL @ surface (Thick grey substance). IA FL @ 300' (13.1 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:45 12/22/2020 T/I/O = 1090/Vac/0. Temp = SI. MIT IA PASSED to 2582 psi (Post IA cement). IA FL @ 300' (13.1 bbls). Used 14.25 bbls amb Diesel to pressure IA to 2750 psi. IAP decreased 121 psi in the 1st 15 min and 47 psi in the second 15 min for a total of 168 psi in 30 min. Bled IAP to 0 psi (2.3 bbls). Hung tags. Final WHPs = 1090/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:20 5/3/2021 ***WELL S/I ON ARRIVAL*** SPOT EQUIPMENT ***WSR CONTINUED ON 5-4-21*** Daily Report of Well Operations PBU 13-19 Daily Report of Well Operations PBU 13-19 5/4/2021 ***WSR CONTINUED FROM 5-3-21***(cbl) DRIFTED/TAG TO TOC 8910' SLM. LOG SCMT FROM 8910' SLM TO SURFACE. ***WELL S/I UPON DEPARTURE*** 5/11/2021 MIT-T & MIT-IA Post Cement Job (CEMENT SQUEEZE (OA/IA DWNSQZ) MIT-T to 2272 psi ***PASS*** MIT-IA to 2273 psi ***PASS*** Pumped 2.8 bbls to take Tbg to 2419 psi. Tbg lost 109 psi in 1st 15 mins and 38 in 2nd 15 mins for a total loss of 147 psi in 30 min test. **PASS*** Ble Tbg to 15 psi and got back ~2.5 bbls. Pumped 4.9 bbls to take IA to 2452 psi. IA lost 136 psi in 1st 15 mins and 43 psi in 2nd 15 mins for a total loss of 179 psi in 30 min test. ***PASS*** Bled IA to 0 psi and got back ~4.6 bbls. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OT=OTG *Tags hung on MV and IA 5/13/2021 AOGGG MIT-T & MIT-IA (CEMENT SQUEEZE (OA/IA DWNSQZ)) AOGCC MIT-T to 2277 psi ***PASS*** AOGCC MIT-IA to 2234 psi ***PASS*** Pumped 2.6 bbls down Tbg for AOGCC MIT-T and took pressure to 2432 psi. Tbg lost 121 psi in 1st 15 mins and 34 psi in 2nd 15 psi for a total loss of 155 psi in 30 min test. Bled Tbg to 118 psi and got back ~2.5 bbls. Pumped 2.5 bbls down IA for AOGCC MIT-IA and took pressure to 2449 psi. IA lost 149 psi in 1st 15 mins and 39 psi in 2nd 15 psi for a total loss of 188 psi in 30 min test. Bled IA to 30 psi and got back ~2.5 bbls. Tests Witnessed by State Rep Guy and WSS Nicholson ***Tags hung on MV and IA 5/30/2021 CTU #9 - 1.75" Coil Job Objective: Mill Cement Retainer and CBP MIRU CTU. Make up Milling BHA with 2-7/8" motor and 4.55" Junk Mill, RIH. Tag cement at 8906' CTMD and mill trhough retain and CBP and then push to 4-1/2" X-O at 9069' MD. Pump gel sweep and chase OOH at 80%. Make up Milling BHA with 2- 7/8" motor and 3.80" 4- bladed junk mill, RIH. ...Continued on WSR 5-31-21...***CP 5/31/2021 CTU #9 - 1.75" Coil ***Continued from WSR 5-30-21*** Job Objective: Mill Cement Retainer and CBP RIH wit 3.80" junk mill and mil through CBP remnants and push past the tubing tail. Drift to 9175' CTMD. POOH and perform injectivity test of 714 psi @ 2.0 bpm, 890 psi @ 3.0 bpm. FP Coil and well while POOH. RDMO CTU. ***Job Complete***CP ***Note: There was an issue with the quarter turn valves on the Dowland-Bach SSV panel in the wellhouse when connected to the "wireline" port. To prevent pressure from bleeding off we had to tie-in directly to the SSV actuator, bypassing the panel. 6/12/2021 T/I/O = 1250/780/150 . Temp = 128*. IA FL ( pre AOGCC MIT). On PW. IA FL @ surface. SV = C. WV, SSV, MV = O. IA & OA = OTG. 08:00. Daily Report of Well Operations PBU 13-19 6/13/2021 AOGCC MIT-IA (CEMENT SQUEEZE (OA/IA DWNSQZ) AOGCC MIT-IA to 2214 psi ***PASS*** Pumped 2.2 bbls DSL down IA to take pressure to 2343 psi for AOGCC MIT-IA. IA lost 103 psi in 1st 15 mins and 26 psi in 2nd 15 mins for a total loss of 129 psi in 30 min test. Bled back to 725 psi and got back 2.2 bbls. Test Witness by WSS Ogg and State Rep Austin **Tag hun on IA 6/17/2021 ***WELL INJECTING ON ARRIVAL*** LOG WATERFLOW STATION STOPS AT GENERATOR DEPTHS OF 9000', 8500', AND 8000'. NO UPFLOW OBSERVED SHUT WELL IN AND LOG BASELINE TEMPERATURE PASS FROM 9000' - 7000' LOG 1 HOUR AND 2 HOUR WARM BACK PASSES FROM 9000' - 7000' ***JOB COMPLETE, WELL TURNED OVER TO DSO TO BRING ON INJECTION*** MEMORANDUM TO: Jim Regg !Q % P.I. Supervisor I� e qI �(J�(�Zi FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-19 Insp Num: mitSAM210613193240 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Nonh Slope, LLC 13-19 PRUDHOE BAY UNIT 13-19 Ste: Inspector Reviewed By: P.1. Supry Comm API Well Number 50-029-20690-00-00 Inspector Name: Austin McLeod Permit Number: 181-180-0 Inspection Date: 6/13/2021 Notes: MITIA. 2 year. CO 736. IA cemented above packer. ,, Wednesday, June 16, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-19 ' -Type Inj %k' 'TVD 8338 - Tubing 953 946 947 947 " PTD 1811800 - Type Test s"I Test psi 3054 ' IA 51 2343 2240 2214 - BBL Pumped: z.z BBL Returned: 2.2 - OA_ 16� 221 221 219 - Interval I REQVAR _ _P/F ..- P 4 -- - — -,. Notes: MITIA. 2 year. CO 736. IA cemented above packer. ,, Wednesday, June 16, 2021 Page I of I David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 09-05B 500292021502 219001 5/7/2021 SCMT SCHLUMBERGER 13-19 500292069000 181180 5/4/2021 SCMT SCHLUMBERGER C-29B 500292147202 214049 1/26/2021 SCMT SCHLUMBERGER E-17A 500292047001 204204 4/28/2021 SCMT SCHLUMBERGER E-34A 500292243701 214096 5/3/2021 SCMT SCHLUMBERGER L-106 500292305500 201223 6/5/2021 PPROF SCHLUMBERGER V-109 500292312000 202202 6/11/2021 PPROF SCHLUMBERGER Z-34 500292346900 212061 5/22/2021 SCMT SCHLUMBERGER Z-35 500292288400 198093 5/23/2021 SCMT SCHLUMBERGER Please include current contact information if different from above. 06/14/2021 Received By: 37' (6HW By Abby Bell at 3:24 pm, Jun 14, 2021 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Sent: Thursday, June 10, 2021 10:24 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Oliver Sternicki; Aras Worthington; John Condio - (C); Leslie Reavis Subject: OPERABLE: Injector 13-19 (PTD #1811800) PC leak remedied. Needs online AOGCC MIT - IA --' Mr. Wallace, Injector 13-19 (PTD #181180) remained Not Operable after an LDL found a Production Casing leak on 08/19/2020. On 10/16/20 fullbore performed an IA cement squeeze in accordance with Sundry #319-426. On 05/13/21 an AOGCC witnessed offline MIT -T & CMIT-TxIA passed. The well will now be classified as OPERBALE. When the well is online and thermally stable, an AOGCC MIT -IA and waterflow log will be conducted. 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: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, April 29, 2019 2:35 PM To: 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead@bp.com>; Ak, OPS FS3 Facility PTL <AKOPSFS3FacilityPTL@bp.com>; Ak, OPS FS3 Field PTL <AKOPSFS3Field PTL@bp.com>; AK, OPS FS3 OSM <AKOPSFS30SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Brown, Don L. <browd2@BP.com>; De la Cruz, Paulina <paulina.meixueiro@bp.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Vandergon, Mark A <Mark.Vandergon@bp.com>; Vohra, Prachi <Prachi.Vohra@bp.com> Cc: 'Regg, lames B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras 1 <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector 13-19 (PTD #1811800) will lapse on AOGCC witnessed MIT -IA All, MEMORANDUM State of Alaska N -TVD Alaska Oil and Gas Conservation Commission TO: Jim Regg 51u(�u DATE: Tuesday, May 18, 2021 P.I. Supervisorcif l SUBJECT: Mechanical Integrity Tests (, Hilcorp North Slope, LLC Notes: MITT post cement job per Sundry 319-426. Te 13-19 FROM: Guy Cook PRUDHOE BAY UNIT 13-19 Petroleum Inspector Src: Inspector Reviewed Byry:� P.I. SuprvJe.=R NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-19 [asp Num: mitODC210513162530 Rel Insp Num: API Well Number 50-029-20690-00-00 Inspector Name: Guy Cook Permit Number: 181-180-0 Inspection Date: 5/13/2021 Packer well Ii -19 Typelnj N -TVD PTD 1811800 1 Type Test SPT -Test ps BBL Pumped: 2.6 -BBL Returned: Interval OTHER P/B Notes: MITT post cement job per Sundry 319-426. Te Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min a33a 8338 Tubing Tubing na - [i173 2432-P9 zm - l - 2.5 OA 0 o0 P completed with a Little Red Services pump truck and calibrated gauges. Tuesday, May 18, 2021 Page I of 1 MEMORANDUM State of Alaska Pretest Initial Alaska Oil and Gas Conservation Commission 9338 DATE: Tuesday, May 18, 2021 TO: Jim Regg � P.I. Supervisor 1 SUBJECT: Mechanical Integrity Tests i Hilcorp North Slope, LLC 13-19 FROM: Guy Cook PRUDHOE BAY UNIT 13-19 Petroleum Inspector 2261 - Ste: Inspector 2.4 Reviewed By: 0 P.I. Son" NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-19 Insp Num: mitGDC210513062611 Rel Insp Num: API Well Number 50-029-20690-00-00 Inspector Name: Guy Cook Permit Number: 181-180-0 Inspection Date: 5/13/2021 . Packer Well 13-19 Typelnj N TVD PTD 1 1811800 IType Test I sPT Test psi BBL Pumped: 2.5 ' BBL Returned: Interval OTHER P� Notes: MIT -IA post cementjob per Sundry 319-026? Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 9338 " Tubing 175 - 318 351 . 364, — - _--- 2084 IA 28 2449. 2300 - 2261 - 2.4 OA 0 0 0 0 P with a Little Red Services pump track and calibrated gauges. Tuesday, May 18, 2021 Page I of I > i %l l TDO From: Schwartz, Guy L (CED) Sent: Thursday, November 7, 2019 2:01 PM To: Lopez, Raymundo; Rixse, Melvin G (CED) Cc: Worthington, Aras J; Daniel, Ryan Subject: RE: 13-19 IA Cement Procedure for Sundry Ray, You have approval to modify the sundry as outlined in your updated procedure. The IA TOC is now targeted to be roughly 4000 ft and. Still meeting CO 736 requirements. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guv schwarfz@olaska aov). From: Lopez, Raymundo <Raymundo. Lopez@bp.com> Sent: Monday, November 4, 2019 2:40 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Worthington, Aras J <Aras.Worthington@bp.com>; Daniel, Ryan <Ryan.Daniel@bp.com> Subject: RE: 13-19 IA Cement Procedure for Sundry All, Here is the updated Job Scope for 13-19 following today's meeting with Guy from the AOGCC. Regards, Ray From: Lopez, Raymundo Sent: Monday, November 4, 2019 10:21 AM To: guy. schwa rtz@alas ka.eov; melvin.rixse@alaska.gov Cc: Worthington, ArasJ <Aras.Worthineton bp.com>; Daniel, Ryan <Rvan.Daniel@bp.com> Subject: 13-19 IA Cement Procedure for Sundry All, I have attached the revised IA cement job, along with the previously approved Sundry Number: 319-426. Let me know if you have any further questions. Thanks, IA Cement Squeeze Integrity Engineer Raymundo Lopez (907) 564-5265 Production Engineer Don Brown (907) 564-4675 Expected Start date: December 5, 2019 History Well: 13-19 Well 13-19 is a WAG injector that was completed in 1982. The last time it was on MI was March of 1997. A caliper from 2015 shows that the tubing has wall penetration values ranging from 55-61% between 1,188'- 8,971' MD. An AOGCC compliant MIT -IA was inconclusive on 4/11/19, resulting in 13-19 becoming Not Operable. Another MIT -IA failed with a LLR of 13.7 GPM at 1,250 psi (4/14/19). An MIT -OA was soon conducted to 1,145 psi and passed (4/18/19). The well head's annuli voids passed a PPPOT-IC (4/19/19). A DBP plug was set in the DB -5 nipple at 9,100' MD (8/11/19), and an MIT -T passed, showing the integrity of the plug. An LDL was run with E -line showing a temperature anomaly at 7,880' MD (8/19/19). The results show a PC leak at 7,865' MD while pumping at a rate of 0.45 bpm and maintaining 1,500 psi on the IA. The purpose of this program is to return 13-19 to "operable" status by remediating the PC leak. Current Status The well is classified as "Not Operable." Objective Repair the production casing leak at 7,865' MD with an IA cement job. Cement the IA to cover the PC leak at 7,865' MD by meeting the regulatory criteria (Conservation Order 736). Cement will be circulated down the tubing and up the IA through the tubing punch at —8,992' MD. This proposed TOC in the IA is 4,078' MD which is 1,500' TVD deeper than the surface casing shoe and 492' MD shallower than the estimated top of UG4. Post job Evaluation o MIT -T and MIT -IA o SCMT to confirm the Top of Cement (TOC) Long -Tenn Integrity Monitoring o Biennial MIT -T's and MIT4As for injectors o Record WHPs and Injection rate daily o AOGCC Required Waterflow Logs Procedure: Slickline 1. Pull 4-1/2" DBP Plug from 9,100' MD. 2. Drift 5-1/2" tubing for CBP/CMT Retainer. 3. Drift & Tag with sample bailer to HEX -Plug @ 9,696' MD; confirm plug. E -Line & Fullbore 1. Set 5-1/2" CBP at 9,012' MD in the middle of the first full joint of tubing above the packer (Packer depth from tubing tally attached used as reference). a. Fullbore: Perform MIT -T to 2000 psi to verify CBP set. 2. Punch 5' of tubing in the middle of the first collar above the CBP @ —8,992' MD. 3. Set 5-1/2" Fasdrill SVB cement retainer at in the middle of the second full joint of tubing above the packer. a. Fullbore: Perform MIT -T to 2000 psi to verify cement retainer set. Coiled Tubing 1. Sting into CMT RET. 2. Pressure up CTxTubing annulus to —500 psi & maintain through job to reduce collapse risk. Pumping down coil, establish returns up the IA and pump the following schedule: a. 10 bbl surfactant wash b. 2 bbl FW spacer c. 219 bbl Class G cement d. 5 bbl FW spacer e. CT volume of displacement 3. With 1 bbl of cement remaining in coil, unsting from retainer and lay the last 1 bbl of cement on the retainer. 4. Wait for cement to gain 500 psi of compressive strength and RIH with milling BHA. a. Mill the retainer, cement, and CBP from the 5-1/2" tubing. Slickline & Fullbore 1. Set DBP plug in the CAM DB -5 NIP at 9,100' MD. 2. Log Memory SCMT from just above the plug at 9,100' MD to surface to identify TOC. 3. Conduct AOGCC witnessed MIT -T and MIT -IA. Ensure 24-hour notice provided for AOGCC to witness. Proposed Cement Blend Parameters Cement Type /Weight: Unislurry Class G 15.8 ppg mixed on the fly. Field blend to be equal to lab weight +/- 0.1 ppg. Fluid Loss: 40 — 80 cc / 30 min Thickening Time: Minimum 6 hours Cement thickening time Activity Time (hours) Cement displacement 4 Cement contamination 1 Safety 1 Minimum required thickening time: 6 TREE 5 X 7 S FMC 120 WELLHEAD = GRAY ACTLIATOR= BAKERC OKB. El -EV = 84' BE ELE-V = --. - . KOP= P800' Max Angie = - -._. 34' @ 6000• ODIUM W - - - . 9641' Datum TVD= 88W SS 13-38" CSG, 720, L-80, D = 12.347 2474' Minimum ID = 3.813" @ 9100' 4-1l2" CAMCO DB -5 NIPPLE 4-10' 0232 opt, D = )p OF 4-112" TE TOP OF TLNH 9116' 9.5/8' CSG, 470. L-BO/SOO95, D= 8.681" 9439' 7 33/8" 3318" 3A/8" 3 118" 31/8" 7 PERFORATION SL#&MRY REP LOG BFKS ON 01/14/82 ANGLEAT TOPIC: 21° @ 9480' Nota Rofof to Production CO for hbtwcal 0erf data 4 9460 - 9480 O 08/03/91 10246' 4 9566-9606 S 12120/85 07/2f 4 9620-9650 0 10/03/92 4 9656-9676 O /003!92 03/10114 E 4 9682-9692 O 10/03/92 05731108 DTMWELL1fAD 4 9711, 9721 C 10/03/92 4 9734-9754 C 70/03/92 4 9768.9778 S 10/16/81 0725 T I. MIL 290, I -80..0371 bpf, D - 0.184" 10239' _ 10 10246' DATE I REVBY COhMEN7S -- -DATE F 012082 ORIGNAL COWPLETION 02MIl h 01103911 SSSLT CONVERTEDTOCANVAS 01/10/12 Tf 01731191 SS -LG REVISION- _ - - 03/10114 E 10/27101.1 FVYW _ CORREC_TIOF& 080_4115 .K 05731108 DTMWELL1fAD COF7ITECTgN 08/73719 M GE 125 ppm 13=19 SAFETY NOTES'I-t2S WHEN ONW WF-LREQUIRESSSASSSVWHEN ONML D = 4.562" 1, - 9039' - J—f8-12" BOY PER ASSYI X aTOD- (y4�lrr c;AMtXi-s NV,D= 9100` 1-1442' DBP PLUG (D8111119) [_µsis� L8 kD rT LOGcm 122o1&s 9898 Nfu1W1 fl 350,100M X PI. UO 4• G IN 0111 2115) 1Y y COMr£NIS - -- - PFIIJDFtOE 6AYt1NfT D%ADDED SSSV SAFETY NOTE WELL. 1319 6U,A-DOEDFQSSAFETYNOTE PEFWN0-'811800 ID+ TREE C70(03M14) . -.— APINo. 50-029-2063000 00;SETHEX PLUG (07112115) _ SEC 14, TIJN, R14E, 2522• F1r1- & 156' FEL AO � SETDBP PLUG (08/11119) BP Exploration (Alaska) TFC= 5X7SFMC 120 9460-9480 WEL`TDR- 08103191 13=19 4 9566 -9606 BAm�C 12/20/85 071 3.318' OKB. ELF\( = 84' O 10)03792 BF. ELR/ 3-378" 4 9656-9676 O 10/03792 f(OP= 4 9682-9692 O 10/03/92 Mex A 4 9711 9721 C 10103192 Datum 4 9734 - 9754 C 10/03/92 Datum TVD = BB(X7 S5 9768 9778 S 10/16/87 Off. ,v 13-3/8' CSG.72x1 _M ! = i2`347 2474'_- uo.Ld HM 1 1 5 in^ TBG -PC. 17x. 1.80. 0232 boL. D - 4.892' 1 TOP pF 7' LNR 9116' 14-1/2' TBC NPC. 12 6x. N80. 0152 bnl. n. 3 95a' 1 981578' CSG. 470. L.80/S00-95. U= 8.681^ 9439'! PEWORATPN S~ RY REF LOG BEKS ON01114182 ANGLE AT TOP PERF: 21° @ 9480' Note Refer to Roducttort OLT for hstor cal oerf data 3-378' 4 9460-9480 O 08103191 7 4 9566 -9606 S 12/20/85 071 3.318' 4 9620-9650 O 10)03792 3-378" 4 9656-9676 O 10/03792 3,118' 4 9682-9692 O 10/03/92 3-1/8' 4 9711 9721 C 10103192 3 178' 4 9734 - 9754 C 10/03/92 ? 4 9768 9778 S 10/16/87 Off. r r - C184-1 r457re011l ►,4�44441�4� _ __.._ t _.- 10/27/01 RWmV cofnECTrm sp4/15 JCM'JAUISETIEX OSr314 OTM MLIWADCORRECTpN 08123779*MlIHW vUSETDBP SAFETY 140;,2 RFADNG8AVERAGE 125 ppm WHEN ON ML WELL REQUIRES A SSSV WHEN QN M L 5.12^ CAM RAI. -O SSSV NP. D - 4 562' 9039' j--i5_72-B0TPBRASSYj I 9069' t-15-112' X 4-112' XO 91OW i-14 12' DBP PLUG (08111119) 9131' -_ 1^4 12 BOT BULLNOSE SHEAROUT SUB { 9132' 4tn^WT.EG 9131' ELWD TT LOGGLD 1228785 rNLITiWELL 350-700 MA PLUG. 4- G FN t07112115) PRLIOHOE BAY L"T WELL, 13-19 PEFbWr4o "811800 ._ APIW, 50-029-20690-00 SEC 14, 7)3N. RI4E, 2527 FW & 15F FEL. RP Expbratlon "skx) 13-19 340 13-318' CSG. 726, L-80. 0 = 12.347' 2474' Minimum ID = 3.813"@91005 4-1/2" CAMCO DB -5 NIPPLE 176, TOPOF T LNN 9115' • 3858' 9318' CSG. 476. L-801$00.95, 0 - 8.081• H 9439' - PERFORATION SM"RY REF LOG: BHCS ON 01714/82 ANGLE AT TOP PERP: 216 Q 9400' Note: Refer to Rodwfion OB for historical peri data SIZE SPF INTERVAL OpnlSgx SHOT SOZ 3-318' 4 9460-9480 p 0803191 11/19) _ 7 4 9566-9606 S 122085 07/25191 3.38` 4 9620.9650 O 10/03182 3-38` 4 9656-9676 O 10103182 3.18` 4 9862.9692 O 10/03/92 3.18` 4 9711-9721 C 1010382 3118` 4 9734-9754 C 70103192 7 4 9768-9778 S 10116/87 07125191 7• LNR. 296.1 80. 0371 opt. D.6.11w' 10238' L_J 10248' 54SLT 'CONVERTED TO CANVAS SIS -LG IREVISON _ SAFELY NOTES' H2S READINGS AVERAGE 125 ppm NMEN ON Alt WELL REQUIRES A SSSV WHEN ON ML ASSY] X0 DOP PLUG (0811 U19) SHEAROUT SUB 2 PRUDHOE HAYUNT :TY NOTE WELL: 1319 YNOTE PERMrTNo.'811800 1 APIN0: 50029-2069D00 12115) SEC 14. TION, R14E. 2522' FN, d 158' FEL 11/19) _ BP Exploratlon(Alaaka) 2 Cj'7)NG I TUBING I LINER DETA'L DE 5l.c �32_C$ ARCO Alaska, Inc. DATE .,� pa .i•i4Wr at AMMkMMf "Wo pwi Pape of peg" . d Remarks r�►i __+Awar1 n COMPLETEDtSCRUMON OF • it Ii i -ram r � w t / .♦ i , OEM PIM Remarks r�►i __+Awar1 n bp 0 IA Cement Squeeze Integrity Engineer Raymundo Lopez (907) 564-5265 Production Engineer Don Brown (907) 564-4675 Expected Start date: December 5, 2019 History Well: 13-19 O� 4 C/ Lk0 r� Well 13-19 is a WAG injector that was completed in 1982. The last time it was on MI was March of 1997. A caliper from 2015 shows that the tubing has wall penetration values ranging from 55-61 % between 1,188'- 8,971' MD. An AOGCC compliant MIT -IA was inconclusive on 4/11/19, resulting in 13-19 becoming Not Operable. Another MIT -IA failed with a LLR of 13.7 GPM at 1,250 psi (4/14/19). An MIT -OA was soon conducted to 1,145 psi and passed (4/18/19). The well head's annuli voids passed a PPPOT-IC (4/19/19). A DBP plug was set in the DB -5 nipple at 9,100' MD (8/11/19), and an MIT -T passed, showing the integrity of the plug. An LDL was run with E -line showing a temperature anomaly at 7,880' MD (8/19/19). The results show a PC leak at 7,865' MD while pumping at a rate of 0.45 bpm and maintaining 1,500 psi on the IA. The purpose of this program is to return 13-19 to "operable" status by remediating the PC leak. Current Status The well is classified as "Not Operable." Objective Repair the production casing leak at 7,865' MD with an IA cement job. Cement the IA to cover the PC leak at 7,865' MD by meeting the regulatory criteria (Conservation Order 736). Cement will be circulated down the tubing and up the IA through the tubing punch at 8,992' MD. This proposed TOC in the IA is 4,078' MD which is 1,500' TVD deeper than the surface casing shoe and 492' MD shallower than the estimated top of UG4. Post job Evaluation MIT -T and MIT -IA SCMT to confirm the Top of Cement (TOC) Long -Term Integrity Monitoring o Biennial MIT -T's and MIT-IAsfor injectors o Record WHPs and Injection rate daily o AOGCC Required Waterflow Logs Procedure: Slickline 1. Pull 4-1/2" DBP Plug from 9,100' MD. 2. Drift 5-1/2" tubing for CBP/CMT Retainer. 3. Drift & Tag with sample bailer to HEX -Plug @ 9,696' MD; confirm plug. E -Line & Fullbore 1. Set 5-1/2" CBP at 9,012' MD in the middle of the first full joint of tubing above the packer (Packer depth from tubing tally attached used as reference). a. Fullbore: Perform MIT -T to 2000 psi to verify CBP set. 2. Punch 5' of tubing in the middle of the first collar above the CBP @ —8,992' MD. 3. Set 5-1/2" Fasdrill SVB cement retainer at in the middle of the second full joint of tubing above the packer. a. Fullbore: Perform MIT -T to 2000 psi to verify cement retainer set. Coiled Tubina 1. Sting into CMT RET. 2. Pressure up CTxTubing annulus to —500 psi & maintain through job to reduce collapse risk. Pumping down coil, establish returns up the IA and pump the following schedule: a. 10 bbl surfactant wash b. 2 bbl FW spacer c. 219 bbl Class G cement v y 3 d. 5 bbl FW spacer z ��r z[o7 Y= `( Y 7 z A e. CT volume of displacement 3. With 1 bbl of cement remaining in coil, unsting from retainer and lay the last 1 bbl of cement on the retainer. 4. Wait for cement to gain 500 psi of compressive strength and RIH with milling BHA. a. Mill the retainer, cement, and CBP from the 5-1/2" tubing. Slickline & Fullbore 1. Set DBP plug in the CAM DB -5 NIP at 9,100' MD. 2. Log Memory SCMT from just above the plug at 9,100' MD to surface to identify TOC. 3. Conduct AOGCC witnessed MIT -T and MIT -IA. Ensure 24-hour notice provided for AOGCC to witness. Proposed Cement Blend Parameters Cement Type/Weight: Unislurry Class G 15.8 ppg mixed on the fly. Field blend to be equal to lab weight +/- 0.1 ppg. Fluid Loss: 40 — 80 cc / 30 min Thickening Time: Minimum 6 hours Cement thickening time Activity Time (hours) Cement displacement 4 Cement contamination 1 Safety 1 Minimum required thickening time: 6 TREE 5X7SFMC 120 C"TDR= BA C 13-19 OKB. ELEV = 84' BF. ELEV = .. 4 9460-9480 0 08103/91 KOP__' -- -- ----. 2-8W __- = 2800' 4 9566 9606 Mbx Angle =.. _ 34' Q 6000' 1220/85 3-318` Datum Mp.-_. _ .9641 9620-9650 O Datum TVD= 8800'SS� 3.318" 4 I 3-31W CSG. 72#. L-80, ID = 12.347• 2474' O 10/03/92 Minimum ID = 3813"@91001 4 9682-9692 4-1/2" CAMCO DB -5 NIPPLE 10/03192 3 118" 15 12' TRC PC, 17#, 1 80, 0232 hpf, ID = 4.892' TOP OF 4- In- TBG-NRc T(W OF 7' LNR9115' 4-12" TBG NPC, 12.6#, N,80, .0152 bpf, 0 = 3 956" 9131' 9-518" CSG, 47#, L 80/S0(195, 0= 8.687" 9439' PERFORAT10N Si MIMRY REF LOG BHCS ON OII14/82 ANGLE AT TOP PE RF. 21° 0 9460' Noto Rafer to RoduCt" OB for hetalcal Dart data 3.318" 4 9460-9480 0 08103/91 7 4 9566 9606 S 1220/85 3-318` 4 9620-9650 O 10/03192 3.318" 4 9656-9676 O 10/03/92 3-118" 4 9682-9692 0 10/03192 3 118" 4 9711.9721 c 10/03/92 31/8" 4 9734 9754 c 10103792 7 4 9768 9718 S 10/16187 7-1. NR. 29#,1 80, 0371 bPf. 0=0184" _1023Y_- ll 10246' - SAFETY NOTES: FQS READINGS AVERAGE 125 ppm WHEN ON M WELL REQUIRES A SSSV WHEN ON Ml. ZU03 rl S-1rd CAM HAI -0 SSSV NP, 0=4.562" " 9039'_. _�-�S 7R"6OTPBRASSYj X 4- ( 8l W- t -y4 -1l1' CAM [li-5 NP, U = 3.813' { 9100' I;4. Irr DBP PLUG(08111/19)1 9131' j_:4-10SOTSULLNOSE SHAROUT SUB L 9131'��Mi1 TT LOGGLI) 7220!85 _ DATE I REV BY _-.COMMENTS.'_, . I -DATE REV BY-,.-C26faENTS__.. 01owi ORIGINAL COMPL.ETpN 02r%ll M .*M ADDED SSSV SAFETY NOTE 01103,011 SIS�SLT CONVERTED TO CANVAS 01/16112 TMI*JMD�ADDEDFf2SSAFETYNOTE 01130N1 SIS -LG REVISION- 03!70174 DUJMDtTREECIO(03 l4) - 1awjolU6 R!WTP CORRECTIONS 08"04!15 JCWJM'SETFEX PLUS(07/12115) -0,/3,Ji OTM VkdWADCORRECTON 08113/19,MIWJMD,SET0f3P PLl1G (0&11119) NfIRWt4t 350700 H1X RUG. 4'C IN(0/!11/1 5) PRUDHOE BAY UNIT IAE.LL. 1319 PEFT,n No.'811800 APINo, 50V2 2069000 SEC 14, TION, R14E, 2522' FN- 8156 FEL BP Exploration (Alaska) TREE 5 X 7 SFNC 120 VVELLFEA0 GRAY M034 ACTUATOR= Ev C 9566-96% OKB. ELEV = 84' 3.318" BF. ELEV 9620.9650 O IUatum TVD= 8800'SSI i 13-318• CSG_72x. L eo., U127• _ 2474'__ . i 4-1l2" Fill) DB -5 NIPPLE 0232 bpf, U • 4.892• 1POF 4-1/7 TBG -NR; T(DP OF rI.NR 9116' 9.518• CSG. 470, L-80/SOO-95.It) =8.681• 9439'— PERFORATION 439' PERFORATION SLAVMRY REF LOG: SHCS ON 01/14/82 ANGLEAT TOPPEFF: 21° @ 9460' Note Refer to Production DB for hstoncal oerf data 3-318" 4 9460 - 9480 O M034 ? 4 9566-96% S 12120/8 3.318" 4 9620.9650 O 10103/9, 3.3/8" 4 9656-9676 O 1010319: 3.118" 4 9882-9692 O 1010319, 3 118" 4 9711 9721 C 10)034. 3118" 4 9734 9751 C 101034; ? 4 9768 9778 S 10/16/8 7.1. NR 290, 1 80. 0371 bpl. D - 8 164' 10239' lD 10248' \TE - . REV BY _ _ _. _CCW ENTS - ........_ DATE F ?0782 ORIGINAL COMPLETgN 0209!11 h )=I SLS-SLT CCNVEFREDTOCANVAS 01116;12 _T1 Xk01 : S51VLS G RECN 03110/14- C MOI j RNITP CORRECTIONS 0804715 x II/W ; D- M MLLFEAD CORREdTgN 08713719 M GE 125 ppm 13 19 SAFETY NOTES FQS VJFiEN ON K WELL REQUIRESA SSSVWHEN ONNI. U = 4.562" 9039'. I -{stn" BOT PBRASSYI 9058' 9-5/8' % 5-vr BOT 3 X 4-1/7 9109' j—,$Lrr UBP PLUG (08171119) BOT BULLNOSE SFEAROLR SUB 9132' _ b�i/2"m.rc 9i3V - (IN) TT LUGGED 12/20/85 IM! LL 390-700 )tE% fLtKa, 4' G FN (07/19115) -- _COM�75 N.. .. 1 PRUDHOE BAY LMT )IADDEDSSSVSAFETYNOTE ) NELL. 13-19 D ADDED FRS SAFETY NOTE PEtWN0..'811800 ITREE GO(03!03/14) API W: 50-029.2069600 D SETFEX PLUG 07/12/75 SEC tb, TON. RUE. 25Y1' Ftp 8 S56' FEL _ D: SETDBP PLUG(08111/19) BP Euplorb6on (Alaska) TREE _ S(?X WH -L NVERVAL ACTUA SHOT OKB. 3-31W BF EL 9460- 9180 O 08703!91 Max Angle = 34° Q 60( Datum WD= 9& (ktum TVD = 8800'; 13.318' CSG. 729, L-80. D = 12.347' 2474• Minimum ID = 3.813" @ 9100' 4-1/2" CAMCO DB -5 NIPPLE 'fOPOF 7- LNR 9116' 0152 9-518' CSG, 479, L-80/SOO-95, D - 8.881' 9439' PERFORATION SL14V1ARY FIEF LOG: BNCS ON 01/14/82 ANGLEATTOPFEW: 21° @9460' NOW Refer to Production OB for hslonal Pert data S(?X SPF NVERVAL OwVSgz SHOT SO2 3-31W 4 9460- 9180 O 08703!91 7 4 9566 - 9606 S 12/20/85 07/25/91 3-318' 4 9620.9650 O 10103192 3-316' 4 9656-9676 O 10103182 3-18' 4 9682-9692 O 10/03192 3-1B" 4 9711-9721 C 10/03/82 3-18" 4 9734.9754 C 108382 ? 4 9768-9778 S 1011687 07125191 GE 125 ppm 13 19 I WHEN ON MIT WELL REOUtSAFETY NOES: H2S RESA SSSSSV WHEN ON UL 7' 1 NR, 299, l .80. 0371 SPF, D 8.184' 10239' —A 10 10246' — IS -1! CAM BAI:O SSSV NP, D r 4.$82' I 91w I--(412'CAM OB -S tW,U=3.813' 9100'. I--+4 12' UBP PLl1G (08111119) I 9131' J-4.12" 80T OIkLNOSE 3HF.AROU7 5lla 0.131• ano TT LOGG[D 122085 —_— PRIIONOE BAY(NlT WELL13-19 PERA97No' '811800 APINo. 50-029-2069000 SEC 14, TION, RUE. 2527 FW & 158' FEL BP Explora8on (Aiaaka) 0 Ct'JNG I TUBING I LINER DETA'L DRIB, SI, c_ _Ls� ARCO Alaska, Inc. DATE '� `'� SUW. , W a.rws*w,e..ic-om" h. Page . of pea" ROIaAs COMPLETEOISCRIPTION OF r ®� .1. r t v �� 'r t J • J r � t' ROIaAs THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Raymundo Lopez GWO Engineering Challenger BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 13-19 Permit to Drill Number: 181-180 Sundry Number: 319-426 Dear Mr. Lopez: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 411PZ5�-� Daniel T. Seamount, Jr. Commissioner S� pri—�Df7� r DATED this � day of Septamber, 2019. RBDMSJZ OCT 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 s Operations shutdown ❑ (/j 2 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other IA Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 181-180 3, Address: P.O. Box 196612 Anchorage, AK r 99518-6812 Streligrephic ❑ Service 0 6. qpl Number: 50-029-20690-00-00 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 13-19 s 9. Property Designation (Lease Number): 10. Field/Pools: 1 r ADL 028315 8 028311 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (6): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi). Plugs (MD). Junk (MD). 10246 9448 9100 8378 9100.9696 None Casing Length Size MD TVD Burst Collapse Structural Conductor 60 20" 38-118 38-118 1490 470 Surface 2434 13-3/8" 38-2472 38-2472 5380 2670 Intermediate 9403 9-5/8" 36-9439 36-8695 6870-8150 4760/5080 Production Liner 1124 7" 9116-10239 8392-9442 1 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9460- 9754 8715 - 8990 5-1/2" 17# x 4-1/2" 12.6# L-80 / N-80 34-9131 Packets and SSSV Type: 5-1/2" BOT 3-H Packer Packers and SSSV MD (ft) and TVD (ft): 9058, 8338 No SSSV installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: October 18, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Lopez, Raymuntlo be deviated from without prior written approval. Contact Email: Raymuntlo. LopezCbp.com Authorized Name: Lopez, Raymuntlo Contact Phone: +1 9075645265 Authorized Title: GWO Engineering Challenger Authorized Signature: Date. l 9 1q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I ot ' Li ?,U i/ Location Clearance ❑ Plug Integrity ❑ Test ❑ Integrity Test eeBOP �+ QdrJ�TMechanical C•rG/r%E�i ZdG F7 -/W/74,6—cC- Other/� .` pAgr(i 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ &6.7 e, Flwa Spacing Exception Required? Yes ElNo 3r/ Subsequent Form Required: 16 APPROVED BYTHE i Approved by: COMMISSIONER COMMISSION Date: ORIGINAL RBDMSj � ocr o 12o19 _� l' 10(I"I Submit Form and Forth 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate rI G,2 — ;YT)—f.B 91240119 13-19 Tubing Leak Cement Job Sundry API No: 50-029-20690-00 Integrity Engineer Raymundo Lopez (907) 564-5265 Production Engineer Don Brown (907) 564-4675 Expected Start date: October 18, 2019 Well: 13-19 History Well 13-19 is a WAG injector that was completed in 1982. A caliper from 2015 shows that the tubing had wall penetration values ranging from 55-61% between 1,188'-8,971' MD. An AOGCC compliant MIT -IA was inconclusive on 4/11/14, resulting in 13-19 being marked as Not Operable. Another MIT -IA failed with a LLR of 13.7 GPM at 1,250 psi (4/14/19). An MIT -OA was soon conducted to 1,145 psi and passed (4/18/19). The well head's annuli voids passed a PPPOT-IC (4/19/19). A DBP plug was set on 8/11/19 in the DB -5 nipple at 9,100' MD, and an MIT -T passed, showing the integrity of the plug. An LDL was run with E -line on 8/19/19 showing a temperature anomaly at 7,880' MD. The results show a production casing leak at 7,865' MD while pumping at a rate of 0.45 bpm and maintaining 1,500 psi on the IA. The purpose of this program is to return 13-19 to "operable' status by remediating the PC leak. Current Status The well is classified as "Not Operable." Objective Repair the production casing leak at 7,685' MD with an IA cement job. Cement the IA to cover the PC leak at 7,865' MD by meeting the regulatory criteria (Conservation Order 736). Cement will be circulated down the tubing and up the IA through the tubing punch at -8,992' MD. This proposed TOC in the IA is -7,380' MD which is 4,348' TVD below the surface casing shoe and about 2,810' MD deeper than the estimated top of UG4. Post -job Evaluation o MIT -T o CMIT-TAA Long -Term Integrity Monitoring o AOGCC compliant pressure tests for injectors Procedure: Slickline 1. Pull 4-1/2" DBP Plug from 9,100' MD. 2. Run drift for CBP and cement retainer. a. At WSL discretion – the plug pulled from step #1 could be considered the drift E -Line & Fullbore 1. Set 5-1/2" CBP at 9,012' MD in the middle of the first full joint of tubing above the packer (Packer depth from tubing tally attached used as reference). a. Fullbore: Perform MIT -T to 2000 psi to verify CBP set. 2. Punch tubing in the middle of the first collar above the CBP. a. Fullbore: Pump down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel: pump 400 bbls of diesel. 3. Set 5-1/2" Fasdrill SVB cement retainer at in the middle of the second full joint of tubing above the packer. a. Fullbore: Perform MIT -T to 2000 psi (repeat of MIT#1 on pumping sheet) to verify cement retainer set. Coiled Tubing 1. Sting into Fasdrill SVB cement retainer. Ensure 500 psi in the tubing while pumping down coil to reduce risk of collapse from the de -rated tubing. Establish returns up the IA and pump the following (target TOC in the IA is 7,380' MD): a. 10 bbl surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 b. 2 bbl FW spacer c. 75 bbl Class G cement d. 5 bbl FW spacer e. CT volume of displacement 2. With 1 bbl of cement remaining in coil, unsting from retainer and lay the last 1 bbl of cement on the retainer. Note pressures after un -stinging from retainer—do not bleed any pressure. Ensure that retainer is holding pressure, and if so, circulate or reverse the cement off the retainer and POOH. 3. Wait for cement to gain 500 psi of compressive strength and RIH with milling BHA and 3.80" mill. Mill the retainer, cement, and CBP from the 5-1/2" tubing. Mill/push the remainder of the CBP until it is past the open perforations. Slickline & Fullbore 1. Set PX plug in the CAM DB -5 NIP at 9,100' MD. 2. Log SCMT from just above the plug at 9,100' MD to surface to identify TOC.'ZoC, 40£Sv1-r 7Z) 6d GC - 3. Conduct AOGCC witnessed MIT -T and CMIT-TxIA to max applied pressures of 2,000 psi. Ensure 24- hour notice provided for AOGCC to witness. Proposed Cement Blend Parameters Cement Type /Weight: Unislurry Class G 15.8 ppg mixed on the fly. Field blend to be equal to lab weight +/- 0.1 ppg. Slurry Temperature: between 80 and 110 IF Fluid Loss: 40 — 80 cc Thickening Time: Minimum 7 hours Cement thickening time Activity Time (hours) Cement displacement 4 Cement contamination 1 Safety 1 Minimum required thickening time: 6 TREE= 5XT YALLKAD SIZE aCR14TOR--- 7T _. BAI®2C C4<B: ECP/ BF a 3.38' ly3 5 CSG. 720. L-80. ID - 12.34r 2474' Minimum ID = 3.813" @ 9100' 4-1/2" CAMCO DB -5 NPPLE 5-12' TSC M 170. L-80..0232 opt, 0.4.892'_ 9089• TDP OF 4.1/2- TSC -NPC 9089' fOPOf r LNR 8115' 9.&W CSG. 470, L-80/SO0,95. D-8.881' 9439' 13 19 SAFETY NOTES: MS READNGS AVERAGE 125 ppm N*4N ON ML WELL REQUIRES A SSSV WHEN ON UL FEFWORATION SUA"FTY REF LOG: OHM ON 01114W ANGLE AT TOP FEF F: 210 Q 94W Note: RdOr to Roduction OB for hslo "Wf dMIS SIZE SPF I INTERVAL OpNSpx SHOT SOZ 3.38' 4 9480.9180 0 09103181 ww CORECTONS 7 4 9558-9808 S 122085 072581 3-38' 4 9820.9850 0 1010382 3-38' 4 9858 - 9878 O 10103-'92 3-18• 4 9582. 95W O t0/03A2 3.118- 4 9711 - 9721 C 1010392 3-18" 4 9734-9754 C 1010392 7 4 9755 - 9775 S 10115/87 0725194 r LNR. 290. L-80-0371 eW, o - 5.184• _ 10239' in 102A8' 8038' 15-12' CAM BAL -0 SSSS NP. o - 4.562- CAM -913j'- �4-12' BOT BULLNOSE SFENWW SUB F 9131' H.MD TT LOGO 122085 DATE 1 REV BY —_ - _COMMENTS DATE " REV BY I CCU ENT5 0720821 OFJGlN L_ COMPLETIONt QZ09711 I MBLM IADDED SSSV.SAFETYNJTE 01A3gt 56SLT COFNERTEDTOCANVAS I 01M8112 TA4W.M10 AOQEDH2SSAFETVNOTE 01730101 SIS -LG REVVXN 03!10%4 IX1t60 TR M 14) 1077101 ww CORECTONS I ORWS jXWJMDjSVWX PLUG 11215 L06/d1A8 I D1M V1EL1lEAD CCTSTECTIDN I 05113119 MMJMDSETDBPPLUG 11719 _I P PRUDFK)E BAYL"T HELL. 13-19 PEPMTW, 811800 PPI No 504292089000 SEC 14. TION. RUE, 2527 FNL d 15U FEL SP EapWvtlon (AbMa) TFff= 5X7S R= SAKE 113/8' CSG. 72lt, L-80. O = 12.347' 2474' Minimum 11) = 3.813" @ 9100' 4-1/2" CAMCO DB -5 NPPLE Simi TBG -NFC TOP oP r LHat 9116' 9 -SW CSG. 471, L-80500-95, O - 8.081" 943W 13-19 PERFORATDN SLA"RY REF LOC: BRCS ON 01!14/82 ANGLEAT TOP PERF: 21- ® 9480' NDW FWw to Roduclgn 06 fw historical pwf data SIZE SPF INTERVAL OONSg2 SNOT SOZ 3-3+8• a 9460 - 9480 O 0&03/91 1027101- 7 4 9566. 9606 S 122095 0725191 3.318" 4 9620 - 9650 O 1010392 1318' 4 9858 - 9676 O 1010.792 1118' 4 9682.9892 O 1010382 3-11W 4 9711-9721 C 1010392 3-18• 4 9734 - 9754 C 1010392 7 4 9768-9718 S 101181077 072591 r Lmt 21W. L-80-03711 ppf, O- SAW19239' - TD 10246' - SAFETY NOTES: H2S REAONGS AVERAGE 125 ppm MEN ON H.4 WELL REQWRES A SSSV WHEN ON M L x 5 - x 9100' i-{4-12' GM OB -5 fA'. D • 3.813' 9100' _-.1-j.-�2'.DeP PLt1G I00/11ns1.i 9131' aL0 TT LOGGED I=M DATE REV BY COMMENTS DATE REY BY COMMB4I5 01207!2 lawwLcq4PLE710N Q1ABI11 M1/JM® ADDEDSSSVSAFETYNOTE 01=01 S6 SL.T CCWERTED TOCANVAS 01118112 1 TMYJMD ADDED HQS $APEIYNOTE 0113001 SEiLO REV610N__ 03MOM41 DLPJMO TREECAD 4 1027101- RWTP CCRRECTICh6 060415 J WAU I SET HEX PLUG 112115 0531105 DTM IY1CiLFEAD OORRECTCN 0613!19 MTWJMD SETDBPPLtJG 1119) = 4.562' PRUDHOE SAYLMr WELL: 13.19 PERMR No: '811800 APINo: 504M2069000 SEC 14, TICK RUE. 2522 FNL. 5 15V FEL SP Exploration (Amw) Wo 13 19 Fw= PA WELLOTES REQUMES A SSSV E ON F1 WELL REQU/RESA SSSVWNEN ONYI. •"- 2083' 5-Irr CAMBAL-O SSSVNP.D=4.582' 3 13-38' CSG, 720. L-80. D • 12.14' 2x74' Minimum = 3.813" @ 9100' 4-112" CAMCO DB -5 NIPPLE St? MGGPC 1711 L-80..0232 bpi. D • L.397 -J-1 S%W I TOPOF4-1/YT8G-MC 9059 TOPOF r lNR 9115' 4-1/r TBG -NPC 12.602 N 80..0152 bpf. D - 3.959' 9131' 9.518' CSG. 478. L-801$00.95. D • 8.881• 9439' PE WORATON S~RY Rff LOG: SICS ON Oi/14182 ANGLE AT TOP Mfi 21•Q9480' Now Refer to Produ08on OB for br6or" perf dW SIZE I P Nf&' AL OPMS02 SNDT SO2 3-3/W 4 9480.9480 O 08413191 f16(d1A6 I 7 4 9566-9606 S 122085 0712591 3-318' 4 9820 - 9850 O 10/03182 3-310 4 9856 - 9676 O 1003192 3-118' 4 9662-9692 O 10cm 3-118' 4 9711-9721 O 10/03/92 3.116' 4 9734.9754 C 1003192 7 4 9768-9778 S 1018187 07125N r LM 290, L-80..0371 bW. D • 8.184• 10239' rD 10216' 9131' –'4-1R' BOT BLUMSE SHEAROW SU0_- B1j2' 9131'.. EI.YD TT LOGO®1212 M DATE REV BY COWAF ITS DATE._. -REV BY COMMENTS 01/2092 019301 __ ORGN^L COhPLETION _ Si;aT ORNERIED M,;Mt AS 02MIl '.NBIJND �ADOE0 SSSV 9AFETYNOIE 01//8112 } WJKV ADDED WS SAFETYNOTE 0li3W SBLO fEV61LY4 03'1014 0-2'TRfECJO O�OAI_,/11 10Q/A11 R41P (X7R�CTCf6 0604/15 JCAY.9.0 SETFEX PLUG !12015 f16(d1A6 I DIM IWELLIVAD CUR 9E710N 0&13'19 MiW.AtD SETOSPIPLUGIOWIM91 PRUDHOE BAYWT HELL 13-19 PEFW ND: '811800 APINo: 50020.2019904)0 SEC 14. TON, R14E. 2522' FPL 6158' FEL SP Explomdw Pk*W I 181160 31142 CASED HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Leak PointTM Survey 2) Signed Print Name: BP Exploration (Alaska), Inc. SIM Data Manager Attn: Marion Kendall MB 7-5 900 Benson Blvd. Anchorage, AK 99508 GANCPDC(a),USAANC bou.xwh.BP.COm and READ Cased Hole, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Diane.williams@readeasedhole.com 19 -Aug -19 13- CD RecEejv D AUG 2 9 2019 AOOOc 50-029-20690-00 A-�a-- Date: d PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: READ-ANCHORAGEr(DREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM haps:.,eadcasedhole-my,sharepoint.compersonalldiane williams readcasedhole_,oMD mens DesktopMP T=smcdocx Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Monday, April 29, 2019 2:35 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS3 DS Ops Lead; Ak, OPS FS3 Facility PTL; Ak, OPS FS3 Field PTL; AK, OPS FS3 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Brown, Don L.; De la Cruz, Paulina; G GPB FS3 Drillsites; Vandergon, Mark A; Vohra, Prachi Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; 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 1; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 13-19 (PTD #1811800) will lapse on AOGCC witnessed MIT -IA All, Injector 13-19 (PTD #1811800) is currently Under Evaluation for failing a pre state witnessed MIT -IA on 04/14/19. The well is due for a state witnessed MIT -IA by the end of April. It was shut in on 04/22/19 and engineering is currently working a plan to set a plug and perform a LDL. This work will not be completed before it lapses on the required AOGCC witnessed MIT -IA. The well is now classified as NOT OPERABLE. The diagnostic work will continue as previously outlined. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, April 22, 2019 9:48 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead@bp.com>; Ak, OPS FS3 Facility PTL <AKOPSFS3FacilityPTL@bp.com>; Ak, OPS FS3 Field PTL <AKOPSFS3FieldPTL@bp.com>; AK, OPS FS3 OSM <AKOPSFS30SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Brown, Don L. <browd2@BP.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Meixueiro, Paulina <paulina.meixueiro@bp.com>; Vandergon, Mark A <Mark.Vandergon@bp.com>; Vohra, Prachi <Prachi.Vohra@bp.com> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Sunday, April 14, 2019 12:12 PM To: AK, OPS EOC Specialists; AK, OPS FS3 DS Ops Lead; Ak, OPS FS3 Facility PTL; Ak, OPS FS3 Field PTL; AK, OPS FS3 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Brown, Don L.; G GPB FS3 Drillsites; Meixueiro, Paulina; Vandergon, Mark A, Vohra, Prachi; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; 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; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector 13-19 (PTD #1811800) Suspected production casing leak after failed M IT -IA Attachments: 13-19.pdf All, Injector 13-19 (PTD #1811800) failed a pre state witnessed MIT -IA on 4/14/2019 indicating a loss of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead—PPPOT-IC 2. Production Engineer— Evaluate for leak detection log Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMIE 1 REPORT OF SUNDRY WELL OPERATIONS 1e Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ / Plug for Rednll 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: J//(xp/✓ f 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-f880 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 12f 6. API Number: 50-029-20690-00-00 7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number: PBU 13-19 9 Logs(List logs and submit electronic and printed data per 20AAC25.071)• 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL y, 11.Present Well Condition Summary: rs`�' E r �L ;i'i ��w,D Total Depth: measured 10246 feet Plugs measured 9696 feet true vertical 9448 feet Junk measured None feet Effective Depth: measured 9696 feet Packer measured 9073 feet e t +-r�'a true vertical 8936 feet Packer true vertical 8353 feet i n .p(,3 t„./C Casing: Length: Size' MD: TVD: Burst: Collapse: Structural Conductor 82 20"91.5#H-40 40-122 40-122 1490 470 Surface 2439 13-3/8"72#L-80 40-2479 40-2478 4930 2670 Intermediate 8113 9-5/8"47#L-80 36-8149 36-7503 6870 4760 Intermediate 1211 9-5/8"47#S00-95 8149-9360 7503-8621 8150 5080 Intermediate 85 9-5/8"47#L-80 9360-9446 8621 -8701 6870 4760 Perforation Depth: Measured depth: 9460-9480 feet 9566-9606 feet 9620-9650 feet 9656-9676 feet 9682-9692 feet 9711-9721 9734-9754 feet 9768-9778 feet True vertical depth: 8715-8733 feet 8814-8852 feet 8865-8893 feet 8898-8917 feet 8923-8932 feet 8950-8959 8971-8990 feet 9003-9012 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"3H Perm Packer 9073 8353 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15 Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development ❑ Service ® Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ IZI WAG 0 GINJ 0 SUSP ❑ SPLUG ❑ 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: 315-410 Contact Summerhays,Nita r IPRO Technolog s) Email Nita.Summerhays@bp corn Printed Name ummerha • it./ (WIPRO Techn••gies) Title Petrotechnical Data Manager Signatu - A� ��f Phone +1 907-564-4035 Date 08/05/2015 Form 10-404 Revised 5/2015 r TL -1 w// bmit Onginal Only 0 fid c RBDMS AUri 1 4 2015 _ 0 co / U_ ƒ O/ / VI < a_ LL < < F- ' / .... a R 5 cc a R z ° k co Luc') $ U) per? p4 / U < A3 ƒ 2 £ U) UD_ D 0 03 -J q \ a)o & 2w / q � o2 , Q c Le L < -J o o o t. -J � � m a_ Da Q ® co < ^ LE\ E m L u. m m R n q = cm C 2 �DWI o / % k $ / -1 © 0 2H SCwo D kLL e / Uo� _j � / 2 a) 75 ^0Q a_D o _ 5 2 % -J ›- ,• D f IF 4 _ o m c0 2 o � -J : We Z w > t w 01 0 : < E o ' W W H o 2 , 2 A -2 u_ E> -) = w 2 R 2 © * � � / b 0w S � \ kA Lu 2 2 $ x - a- H < o g x < e m b oTomo - / 5D � LLN- ‹ < 0 � 0iow0az * ¥ U � 22 ƒ \ ao W _J / EEA2 0Z W0) / - I- Zb2o � w / 900Uw° E % 01_ 2 -J % H CD0W /_j / % / / / / / � 0 & \ R 0 a 0-00 w w < k k o o -- / ° L f O / : ƒ ƒ b i 5 I I a S z L 5 / / : E ! ! 2 cccct : � c7 Fc i= E a : 5 '— I I u < in r n d dcogq 5 e f .- 0:1R N- ® / 1 / • ca QoQ00000 O ti O N- N IU C N lf) CO I. 0 L00) MO- SP q2 m N- Nr (O O (0 I,- 00 N00 M e-- 1- M N Trto CO I- M Tt N N- O000O00 lllll M M 0 0 CO 0 N LC) C0 M C) 4.0 O O O O M (0 N N (0 t N- M N � N 00 0) 0) O) O) I .o o) Q MO M 0000 ,T (O 'VN- imM M M O) M O 3 CO I— a. 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KOP= 2800' Max Anpk= 34'0 6000 - I 2083' H 5-12'CAM BAL-O SSSV NP,D=4.562' Datum MD= — 9641' • Datum TVD= 8800 SS 13-3/8'CSG,726,L-80,D=12.347' H 2474' , Minimum ID = 3.813" (4 9100' 4-1/2" CAMCO DB-5 NPPLE l J 90.31, 1—L6-12"BOT RIR ASSY $ 2K\ { 9068' —I9-5/8'X 5-1/2 BOT 3-H PERM FKR 5-12'TBG-PC,17a,L-80,.0232 bpf,D=4.892' H 9069 \ / 90611C X 4-12'XO TOP OF 4-12'TBG-NPC H 9089' ' I I I 9100' H4-1/r CAM DB-5 NP,D=3.813" TOP OF 7"LNR H 9116' 9131' H4-12'BOT BULLNOSE SHEAROUT SUB I 4-1/2 TBG-NPC,12.68,N-80..0152 bpf,D=3.958' H 9131' 7 9132' 4-1/2'MEG 9131' --I ELMO TT LOGGED 1220/85 9-5/8'CSG,47a,L-80/S00-95,D=8.681' H 9439' ' PERFORATION SUIRIN►RY I REF LOG(BRCS ON 01/14/82 ANGLE AT TOP FE RR=:21'®9460' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ I 3.3/8' 1 4 9460-9480 0 08103/91 ? 4 9566-9606 S 1220185 07/25/91 3-3/8' 4 9620-9650 0 10103192 33/8" 4 9656-9676 0 10103/92 3-1/8' 4 9682-9692 0 10103/92 9696' —I I4TB x1350-700 FEC RUG.4'G R4(07/12/15) 3.1/8" 4 9711-9721 C 10103/92 3-1/8" 4 9734-9754 C 10103/92 ? 4 9768-9778 S 10/16/87 07/25191 I 7'UR 29d,L-80,.0371 bpf,Dr1�eeovirei1r 6.184" —{ 10239' •••••••• 1111111111111111 ID 10248' DATE REV BY COM ENTS 7 DATE REV BY COMMENTS PRU CFIOE BAY UNIT T 01/20/82 ORIGINAL COM'LETTON 02/09/11 MAO ADD®SSSV SAFETY NOTE 1/1.13_L 13-19 01/03/01 Sly-SLT CONVERTED TO CANVAS 01/16/12 TM+YJMD ADDED MS SAFETY NOTE PERNIT No: '811800 01/30/01 SIS-LG REVISION 03/10/14 DUIJMD TREE C/O(03103/14) AR No: 50-029-20690-00 10/27/01 RNITP CORRECTIONS 08/04/15 JCMMJMD SET FE(PLUG(07/12/15) SW 14,TION.R14E 2522 FNL&156'FEL 05/31/06 DTMI 1NBIFEAD CORRECTION BP Exploration(Alaska) • rF T�� I�7�,s� THE STATE Alaska Oil and Gas �� of LAsKA Conservation Commission -t#=_=_�y 333 West Seventh Avenue AV GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "•'' Main: 907.279 1433 OF ALAS11"1' Fax: 907 276.7542 www.aogcc.alaska.gov Irwin Chou Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-19 Sundry Number: 315-410 Dear Mr. Chou: SCANNED JUL 1 3 2015 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this iD day of July, 2015 Encl. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COM, )N JUL 0 7 2015! APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 0T S �T 1. Type of Request: Abandon 0 Plug Perforations m. Fracture Stimulate 0 Pull Tubing 0 AOGCC shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other SC f"//CX/J 1fy 2. Operator Name: BP Exploration(Alaska),Inc 4 Current Well Class: 5. Permit to Drill Number 181-180 • 3. Address: P O Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service VI. 6 API Number: 50-029-20690-00-00 - 7. If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? -- Will planned perforations require a spacing exception? Yes 0 No I 1 PBU 13-19 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028311 • PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 10246 • 9448 • 10197 9402 Casing Length Size MD ND Burst collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment _ Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft). See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. 5-1/2"3H Perm Packer Packers and SSSV MD(ft)and TVD(ft): 9073, 8353 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 13• 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4//I b'olc-- Oil 0 Gas 0 WDSPL❑ Suspended 0 16 Verbal Approval. Date. WINJ 121- GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chou,Irwin Email Irwin.Chou@bp.com Printed Name Chou,Irwin Title Production Engineer Signature —47• , Phone +1 907 564 5538 Date 1t(t 6 COMMISSION USE ONLY Conditions of approval.Notify Commission so that a representative may witness Sundry Number 315 -1—E ° Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No V Subsequent Form Required: f 0 — 404- , , , APPROVED 04- APPROVED BYTHE Approved by. f -7 COMMISSIONER COMMISSION Date: /-/o ./ s---- If 7-1- ----v--/-1- /8/'15 ORIGINAL A -, O.s /1-A-7.751//1- Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attach nts in Duplicate RBDMS. 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CL M M M M M M CO• ¢ m m 0 - a a a Q • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: 13-19 Well Type: WAG Injection Well API Number: 50-029-20690-00 Well Activity Conventional 4 Classification: Activity Description: Set HEX Plug Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Required? No — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Irwin Chou Contact numbers: (907) 564-5538 (907) 632-399 Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 1907) 301-124 Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907) 360-748 Date Created: June 11, 2015 Revisions(date,who,what changed): 6/30/2015,Irwin Chou,Added a step to perform a caliper log during D&T. Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) (psi) Cut (%) (Mscf/Day) • 6/10/2015 13,631 0 1,281 Current Status: Operable • Flowing • Inclination>70°at Depth(ft) N/A Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 34° 6,000' MD — Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 5° 2,700' MD Reservoir pressure(date, 7/15/1996 3,484 psi Minimum ID and Depth 3.813"Q 9100' MD psig) Reservoir Temp, F 170° F Shut-in Wellhead Pressure 900 psi Known mech. integrity None problems(specifics) Last downhole operation (date, 3/9/2014 Pull P.Prong&DBP Plug Body from 9100' MD operation) • Most recent TD tag (date,depth, 10/21/2008 9745' ELMD 2.50"CENT, TEL, S-BAILER toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, 13-19 is a PWI that is twinned with 13-21A on the surface. Based on an extensive IPROF history, it is background information, suspected that there is a likely channel from the bottom set of perfs to Z3 and that most of the injection etc: water is going into Z3 instead of Z4. If this is the case, we will not have swept oil from the upper zones. This well also has a history of several mud acid jobs, which have been evident to eat away at cement and . formation and connect wells to Z3. The purpose of this job is to set a Interwell HEX Plug to isolate the lowest set of perfs (42P) in attempt to • force injection into the upper zones. Well Intervention Details Suspected Well Problem: Channel to Z3 through bottom set of perfs. Specific Intervention or Well Objectives: 1 Set Hex Plug to isolate the lowest set of perfs(42P). 2 3 Key risks,critical issues: Mitigation plan: 1 19'of standoff between perfs Ensure proper tie-in and set sealing element between perfs. 2 Possible channel behind pipe Will perform cement squeeze if job unsuccessful. 3 Debris or dirty pipe at setting depth Perform caliper log to ensure pipe is clean Summary Service Line Activity Step# 1 S Drift&Tag to TD. Perform caliper log. 2 EL Set Hex Plug. 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Drift&Tag to TD with interwell HEX dummy plug. Perform caliper log from TD to surface. Ensure to log r, .iqh plug setting depth. 2 EL Set Interwell Hex Plug(Model 363-700)at 9702' MD. 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Turn over to ops to POI. Target rate -15,000 bwpd. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= '. 5X7SFT 0120 AVERAGE 125 ppm , !ELL EAD= Y 13-19 OMIWEL REQUIRESASSSV WHEN ONMI. ACTUATOR= BAKER C OKB.a.EV= 84' BF.BEV= ? KOP= 2800 MMx Angle= 34'@ 6000' 2083' H 5-112"CAM BA L-O SSSV NP,ID=4.562" Datum MD= 9641' C) Datum TVD= 8800'SS 13-3/8'CSG,72#,L-80,ID=12.347" -1 2474' }----A Mirimum ID = 3.813" @ 9100' 4-1/2" CAMCO DB-5 NIPPLE L J 9039' H5-1/2"BOT FSRASSY Z 9058' H 9-518-X 5-1/2"BOT 3-H PERM FKR 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" H 9069' / 9069' H5-1/2"X 4-1/2"X0 TOP OF 4-1/2"TBG-NPC — 9069' ' ' 9100' H4-1/2"CAM DB--5 NP,D=3.813" TOP OF 7"LNR — 9115' 9131' —I 4-1/2"BOT BLtLNOSE St-EA ROUT SUB 4-1/2'TBG-NPC, 12.6#,N-80,.0152 bpf,D=3.958' —1 9131' i 9132' —is-tn•vwEG 9131' HELM) 9-5/8"CSG,47#,L-80/S00-95,D=8.681' —1 9439' hi , PEFFORATION SUMMARY I REF LOG:BI-CS ON 01/14/82 ANGLE AT TOP FEW:21°@ 9460' Note:Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 9460-9480 0 08/03/91 ? 4 9566-9606 S 12/20/85 07/25/91 3-3/8" 4 9620-9650 0 10/03/92 3-3/8' 4 9656-9676 0 10/03/92 3-1/8" 4 9682-9692 0 10/03/92 3-1/8' 4 9711-9721 0 10/03/92 I 3-1/8' 4 9734-9754 0 10/03/92 ? 4 9768-9778 S 10/16/87 07/25/91 I 7'LNR 29#,L-80,.0371 bpf,D=6.184" H 10239' irm e.4�e11i.e4 . TD H 10246' DATE REV BY C'OMvENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/20/82 ORIGINAL COMPLETION 02/09/11 M3/,1M3 ADDED SSSV SAI-LI Y NOTE WALL 13-19 01/03/01 SS-SLT CONVERTED TO CANVAS 01/16/12 TMtVJMD ADD®I-QS SAFETY NOTE FERMI No: '811800 01/30/01 SIS-LG REVISION 03/10/14 DLIUM3 TREE C/O(03/03/14) API No: 50-029-20690-00 10/27/01 FZTYTP CORRECTIONS SEC 14,TION,R14E,2522 ANL&156'FEL 05/31/06 DTM 11VELLI-EAD CORRECTION BP Exploration(Alaska) F -c13- ii P )511sop Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 02, 2015 10:27 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator (� C\ 6�4�tS Subject: April 2015 AOGCC MIT Forms Attachments: April 2015 MIT Forms.zip Please find the attached MIT forms for April 2015: �uN a 8 2.05 ' CMANE Well PTD Comments 24( 13-19 1811800 AOGCC Form A-08 1740040 AOGCC Form A-27 1982350 AOGCC Form L-105 2020580 AOGCC Form NGI-03 1750610 AOGCC Form P2-28 1950440 AOGCC Form P2-46 1931320 AOGCC Form PWDW3-1 1780390 AOGCC Form S-09A 2140970 Post RWO S-11B 1990530 AOGCC Form V-217 2061620 AOGCC Form Kevin Parks (Alternate: Whitney Pettus) BP Alaska -Well Integrity Coordinator Clo ifells I., rganI7 . , ; 'i, Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(atalaska.00v AOGCC.Inspectors(rtalaska.gov- phoebe.brooksaalaska.gov chris.wallaceaalaska.gov OPERATOR: BP Exploration(Alaska),Inc. kIt< FIELD/UNIT/PAD: Prudhoe Bay/GPB/13 11 DATE: 04/17/15 OPERATOR REP: Whitney Pettus AOGCC REP: Waived witness by Chuck Scheve-voicemail Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-19 ' Type Inj. W - TVD 8,338'- Tubing "1,247 '1,247, 1,247 '1,247 Interval 4 P.T.D. 1811800 ' Type test P Test psi 2084.5 Casing '246 '2,501 ' 2,465 2,451 P/F P Notes: 4 yr MIT-IA OA 13 19 ' 20 ' 20 .- 156 F temp Pumped 2.5 bbl ambient diesel TIME 4:28pm 4:56pm 05:11 pm 05:26pm Well Type In). TVD TubingInterval P.T.D. Type test Test psi Casing P/F Notes: OA Well, Type Inj. TVD TubingInterval P.T.D. Type test Test psi Casing, P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing. . P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test I G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU 13-19 04-17-15.xls • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re ` / DATE: Monday, May 09, 2011 P.I. Supervisor � 1 /l rt SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13 -19 FROM: Lou Grimaldi PRUDHOE BAY UNIT 13 -19 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry (2i' NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 13 -19 API Well Number: 50- 029 - 20690 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110504182714 Permit Number: 181 -180 -0 Inspection Date: 5/4/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tI 13 -19 ( Type Inj. 1 W TVD 8338 - IA I 540 r 2200 7 2150 2140 ' P.T.D1 1811800' 1 TypeTest SPT [ Test psi 2084 QA 90 170 I 165 165 Interval 4YRTST P/F P Tubing 1340 1340 t 1340 1340 1� Notes: Good test, 3.9 Bbls neat Meoh pumped -3.2 bled back. Av 1 2 701', Monday, May 09, 2011 Page 1 of 1 t 1 /04/08 ~~ii~~m~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh it N0.4952 ,~.., ~ ~, ~, x Company: State of Alaska t{ ,~i~,Sn a' > ~ ~ i,= rt (1d'i ,,,~ ~'a~ r 1 ~ ,~ :- ~, ±_ ~? ~tlt~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 1 nn rlne nN.... n..•.. D-29 12103692 USIT J 10/19/08 -- _ 1-. 1 13-16 12103694 INJECTION PROFILE (REVISED) / 10/20/08 1 1 13-19 12103695 INJECTION PROFILE ~I 10/21/08 1 1 03-04 12031526 INJECTION PROFILE 10/22/08 1 1 J-08A 12031514 CBL O- 'a I 09/20/08 1 1 06-17 11970850 PRODUCTION LOG ~ / (p~ 10/30/08 1 1 01-33 11999052 RST - 10/10/08 1 1 1-45/0-26 12096920 LDL ~-. ~ 10/10/08 1 1 3-05/0-29 12083416 MEM LDL ~ 10/24/08 1 1 L-116 11999055 USIT O _ ( 41. / . d 10/31/08 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: , ,~ ~ 'j ~i ~'; ~. i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99 03-283 ATTN: Beth Received by: ---~ • • . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 1? I P.I. Supervisor K..efr 7 11(0 7 DATE: Tuesday, July 03,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-19 PRUDHOE BAY UNIT 13·19 Src: Inspector \ _ \C60 \<b Reviewed By: P.I. Suprv 'JR£.. Comm FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-19 API Well Number: 50-029-20690-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG0705291430 15 Permit Number: 181-180-0 Inspection Date: 5/29/2007 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. / i 13-'I9JType Inj. j w i TVD ¡ /, IA I Well 8338 I I 290 2180 2130 i 2120 I - I I' -~~ I I I P.T.Di 1811800 ¡TypeTest I SPT ¡ Test psi ! 2084.5 OA ! 100 160 160 160 I -- . ---¡---:- --T--~--+-----------~_.- Interval 4YRTST PIF P Tubing' 1500 1350 1220 j 1220 i ,____~.L...- Notes: 6 bbl's pumped all fluid bled back. Good test .// 5CANNED JUL 2 0 2007 Tuesday, July 03, 2007 Page I of I . . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudoe Bay I PBU I OS 13 OS/29/07 Anna Dube Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Weill 13-19 I Type Inj. I W TVD 8,338" Tubing 1500 1350 1220 1220 Interval! 4 P.T.D.11811800 I Typetest I P Test psi 2085 Casing 290 2180 2130 2120 P/FI P Notes: AOGCC Witnessed MlT -IA for regulatory compliance. OA 100 160 160 160 Weill I Type Inj. I TVD Tubing Interval! P.T.D.I I Type test I I Test psi I Casing P/FI Notes: I OA Weill I Type Inj.1 TVD Tubing Interval! P.T.D.I I Type testl Test psi Casing I P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OAI Weill I Type Inj. I TVD I Tubing I I Interval I p.T.O.1 I Type test I Test psil Casing P/FI Notes: OAt TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Slandard Pressure Test R = Internal RadioactNe Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL COdes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) SCANNED JUN 1 22007 MITPBU 13-19 05-29-07.xls \CbÙ \~\' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS-13 06/12/03 Joe Anders John Crisp- Declined to witness We11113-19 ' P.T.D.I1811800 Notes: P.T.D.I Notes: P.T.D. Notes: Type Inj. Type Inj. Type Inj. Type Inj. Type Inj. Packer Depths (ft.) Pretest Initial 15Min. 30 Min. Notes: WellI P.T.D.I Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 SCANNED SEP 0 8 2_003 2003-0612_MIT_PBU_13-19.xls ~FYI: MITIA Forms Subject: Date: From: To: CC: FYI: MITIA Forms Thu, 12 Jun 2003 22:19:39 -0500 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein@admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us> "Rossberg, R Steven" <RossbeRS~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com> Hello all. Attached are several MIT reports for recent 4-year MIT's conducted on injectors. All passed except 09-20, currently under evaluation. Note we've had email problems recently, some of these may have already been sent. Let me know if you have any questions. <<MIT PBU 01-11 06-12-03.xls>> <<MIT PBU 13-19 06-12-03.xls>> 14-27 06-12-03.xls>> <<MIT PBU 09-08,10,20 06-06-03.xls>> Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com (Alaska) Inc. <<MIT PBU Name: MIT PBU 01-11 06-12-03.xls "1 [-~MIT PBU 01-11 06-12-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel)i1 En, c,0ding: .b..a.s,e~,4 i ~_)MIT PBU 13,19 06-12-03 ,xls tMIT PBU 14-27 06-12-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) [ Name: MIT PBU 14-27 06-12-03.xls Type:. Microsoft Excel Worksheet (application/vnd.ms-excel) I ,E, ns. od, in.,,,gLb~.e~.4. [-~MIT PBU 09-08,10,20 06-06-03.xls Name: MIT PBU 09-08,10,20 06-06-03.xls Type: Microsoft Excel Worksheet ( app li cati on/md.ms-ex cel) Encoding: base64 1 of I 6/25/2003 3:10 P STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ FILL CLEANOUT Pu, tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _ Exploratory_ Stratigraphic_ Service_X 4. Location of well at surface 2522' FNL, 155' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 4793' FNL, 5021' FEL, Sec. 12, T10N, R14E, UM At effective depth 4730' FNL, 4998' FEL, Sec. 12, T10N, R14E, UM At total depth 4558' FNL, 4937' FEL, Sec. 12, T10N, R14E, UM (asp's 687040, 593282~ (asp's 687378, 5935839) (asp's 687399, 5935902) (asp's 687455, 5936076) 12. Present well condition summary Total depth: measured true vertical 10246 feet Plugs (measured) 9448 feet Perforate _ Other_X FILL CLEANOUT 6. Datum elevation (DF or KB feet) RKB 84 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-19 9. Permit number / approval number J 181-180 10. APl number 50-029-20690-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Tagged TD @ 9745' CTMD (02/26/2003). Effective depth: measured true vertical Casing Length Conductor 110' Surface 3949' Intermediate 9361' Liner 1053' 9745 feet Junk (measured) 8982 feet Size Cemented Measured Depth True Vertical Depth 20" 2892 # Poleset 142' 142' 13-3/8" 3200 sx CS III, 600 sx 3981' 3555' Class 'G' 9-5/8" 875 sx Class 'G' 9393' 9164' 5-1/2" 475 sx Class 'G' 9087' - 10140' 8366' - 9349' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 9458'-9478', 9618'-9648', 9654'-9674', 9680'-9690', 9709'-9719', 9732'-9752'. Sqzd Perfs 9564'-9610', 9616'-9618', 9648'-9654', 9674'-9680', 9690'-9696', 9706'-9709', Sqzd Perfs (continued) 9719'-9721', 9730'-9732', 9752'-9759', 9764'-9778'. Open Perfs 8713'-8732', 8863'-8891', 8897'-8915', 8921 '-8930', 8948'-8957', 8969'-8988'. Sqzd Perfs 8812'-8855', 8861'-8863', 8891 '-8897', 8915'-8921 ', 8930'-8936', 8945'-8948', Sqzd Perfs (continued) 8957'-8959', 8968'-8969', 8988'-8995', 8999'-9012'. 5-1/2", 17#, L-80 TBG-PC @ 9069' MD; 5-1/2" x 4-1/2" XO @ 9069'; · 4-1/2", 12.6#, N-80 TBG-NPC @ 9131' 9-5/8" x 5-1/2" BeT 3-H Perm Packer @ 9058'. Il %,~..~...~.~...~U 5-1/2" Camco BAL-O SSSV Nipple @ 2083' MD. 13. Stimulation or cement squeeze summary MAR Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Al~0{I &C~G~.(~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/20/2003 1253 1172 Subsequent to operation 02/26/2003 4607 1344 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil ~ Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~)~t~e.~ ,~J~.~,~ Title: Technical Assistant DeWar/ne R. Schno Date February 27, 2003 Prepared b~/DeWar/ne R. $chnorr 564.5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 13-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/25/2003 F:[LL CLEAN OUT: LOAD WELL TO SECURE/ SSSV C/O OR STROKE 02/26/2003 FILL CLEAN OUT: FILL CLEAN OUT 02/26/2003 F:[LL CLEAN OUT: SSSV C/O OR STROKE 02/26/2003 TESTEVENT--- TN3ECT];ON PRESSURE, PS:I: 1,344 TYPE: PW VOLUME: 4607 BWPD. EVENT SUMMARY 02/25/03 SLICK-LINE ASSIST, F.P. WELLBORE W/60/40 MEOH. RUN 4.7" GAUGE RING TO 2056' SLM. PULL 5 1/2" A-1 INJ VALVE @ 2056' SLM. (SER #HLS-913). FLAPPER BAD(BROKEN SPRINGS/PIN ALMOST SHEARED). BEGIN RIG DOWN. JOB CONTINUED ON NEXT DAY. 02/2~03 MIRU UNIT #8. RIH WITH 3" JSN. JET TUBING WITH 1% KCL ON WAY IN HOLE. RECIPROCATED PIPE IN LINER WHILE JETTING WITH 120 BBLS 90/10 DIESEL/XYLENE, TAGGED AT 9745' CTMD. POOH. FREEZE PROTECT COIL WITH 60/40 METHANOL. NOTIFIED DSO. PUT WELL BACK ON INJECTION. <<< JOB COMPLETED >>> 02/26/03 <<< PUT WELL BACK ON INJECTION WITH ISSSV OOH >>> O2/26/03 TESTEVENT--- IN]ECTION PRESSURE, PSI: 1,344 TYPE: PW VOLUME: 4607 BWPD. Fluids Pumped BBLS 1 PRESSURE TEST LUBRICATOR TO 3000 PSI W/1 BBL OF DIESEL. , 127 60/40 METHANOL WATER 290 1% SLICK WATER 120 90%/10% DIESEL XYLENE 538 TOTAL Page I Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2785 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/15/03 Color Well Job # Log Description Date Blueline Prints CD D.S. 1-19A c"~ '~ LDL 05/11/03 1 :D.S. 13-19 _~ - \ ~'~ INJECTION PROFILE 05/07/03 1 O.~. 7-13B ~- \'~ I~c 23057 MCNL 01/15/03 1 I ) ._~/~ '~' ,,, , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date Delivered: *v 3 0 Gas Cons. ~ch~e Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill ~, v~ DATE: December 7, 2002 Commissioner ~[g~ S U BJECT: Mechanical Integ rity Tests THRU: Tom Maunder BPX P.I. Supervisor ~,3-'~,~O'~~ MPI 5-02/SD 10 FROM: John Crisp Endicott Petroleum Inspector Duck Island Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Not~: Notes: - We"l~-'e2/SD-~01mypelnj.I S I T.V.D.I N/^ I Tub~,gl 0 I 0 I 0 '1 0 I lntervall VI >.~.D.I ~s~sol~yp,~l U I~"s~p~l N/A I CasingI 0I 0I 0I 0 IP/F} I Notes: Tested. Safety'System'installed on IA. 500 PSI Alarm, 1000 PSI will shut down injection. ' I Well l' I Type Inj. II T.V.D.I ITubingI I I I.I lntervall I P.T.D.I ITypetestl ITestpsil . I'Casingl I I I I. P/"l I Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER I'NJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test' Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during W0rkover ' O= Other (describe in notes) Test's Details I travelled to BP's Endicott MPI to wi'mess annulus safety shut down system test on well 05-02/SD 10 injection well. This well has variance to continue water injection w/no casing integrity. Tubing integrity was verified w/'E line waterflow ~log,tools. BP Rep. Mark Souve assured me that E line logs Were interpreted by AOGCC staff'in Anchorage to verify this wells tubing & packer integrity. Sundry approval # 302-342. M.I.T.'s performed: 1, Attachments: Number of Failures:.. _.0 Total Time during tests: 4 hrs. cc:. MIT report form 5/12/00 L.G. MIT BPX DIU 05-02 12-06-02'JCxls.xls 12/11/2002 ALASKA OIL AND GAS CONSERVATION COMMISSION p mtina u d w _ Re-enter suspended T~me e~ension 1. Type of request: Abandon_X Suspend_ Alter casing _ Repair well _ Change approved program _ Plugging _X Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface v ,/' 2519' FNL, 155' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 487' FSL, 259' FWL, SEC. 12, T10N, R14E, UM At effective depth At total depth 4557' FNL, 4936' FEL, Sec. 12, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2390' Production 9355' Liner 1124' 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service __X 6. Datum elevation (DF or KB feet) RKB 84 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-19i 9. Permit number / approval number 81-180 V~ 10. APl number 50.029.20690v/' 11. Field / Pool Prudhoe Bay Oil Pool 10246 feet 'x/Plugs (measured) PBTD tagged @ 9714' MD (12/28/1997) 9448 feet 9714 feet Junk (measured) 8953 feet Size Cemented Measured Depth True vertical Depth 20" 250 sx Permafrost II 110' 110' 13-3/8" 250o sx Fondu & 400 Sx PFC 2474' 2474' 9-5/8" 5OO Sx C~ass G 9439' 8695' 7" 390 Sx C~ass G 10239' 9442' Perforation depth: measured 9460' - 9480'; 9620' - 9650'; 9656' - 9676'; 9682' - 9692'; 9711' - 9721'; 9734' - 9754'. true vertical 8715' - 8733'; 8864' - 8892'; 8898' - 8917'; 8923' - 8932'; 8950' - 8959'; 8972' - 8991'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 PCT @ 9069' MD; 4-1/2", 12.6#, N-80 NPCT @ 9132' MD. 9-5/8" X 5-1/2" BOT 3-H PERMANENT PACKER @ 9059' MD. 5-1/2" CAMCO BAL-O SSSV @ 2084' MD. ORIGINAL 13. Attachments Description summary of proposal ~ Detailed operations program__ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation January 25, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Service Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "'. ~ Tubing Drilling Supervisor FOR COMMISSION USE ONLY Questions? Call Stephen Ward @ 265-1305. Prepared b~/ Paul Rauf 263-4,g90 -- ConditioDi~,e{el;Iproval: Notify Commission so representative may witness ~,O,~eQ ~'-~"' r' . ~ ~e~ Plug Integ,~ BOP Te~ ~ L~at~n cle~ __ e~~ ~, ~_~ ~ec~ic~ ~.t~ Te~t__ Sub,~ue.t ~o~ ~uir~ ~ ~ ~ ORIGINAL SIGNED. BY Approved by order of ~e Commission R~ N_ ~hd~t~n~nq Commissioner { Approval no.~._ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE hJLte~lued PocA Procedure .,Objective: P&A existing interval in preparation for CT sidetracking operations. Intended Procedure RU slickline unit, tag bottom and mn a Kinley caliper log in the 7" casing. RU e-line unit, mn and set top of whipstock in 7" casing at - 9565'. RU CT. Pump 40 bbls Class 'G', 17 ppg cement. Clean cement top to -9575' md (KOP for CTU drilling at 9570') ,,.~xx~, Xo~'Xc~lr~-~,, '2: ~Rt~ WOC, Tag top of whipstock. ~~tLr~ RECEIVED November 4, 1999 6 COILED TUBING UNIT BOP £OU I PIq£NT 1. 5000 PSI 7" WELLHEAD CONNECTOR IrLAI~iOE 2. ~)000 PSI 4 1/16" PIPE RAMS :3. ~)000 PSI 4 1/6" HYDRAULIC SLIPS 4. ~X)O PSI 4 t/6" SHEAR RAMS 5. ~)000 PSI 4 1/6-BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX .HIREL]NE BOP EO.U, IPMENT ! 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE : 2. 5000 PSi WIRELIN[ RAJAS (VARIABLE SIZE) 3. ~)OO0 PSI 4 1/6" LUBRICATOR 4. ~)O00 PSI 4 1/6" FLOW TUBE PACK-Orr WSSSV Tubing-PC Casing Casing PBR PKR XO Tubing-NPC NIP SOSUB Liner T'fL Perf Pen< Pen< Perf pen< 13-19 APl: 50029206g000 Well Type: INJ KOP: 0.00 ftKB ~ SSSVType: Or~lCompltn: 1/~0/82 PBTD: 10239.00ffKB Reference Log: BHCS Ref Log Date: 1114/82 TD: 10239~ 1 AnnutarFluid: Diesel/9,6NaCI LastW/O: 1/19/82 Max Hole Angle: 34deg.6500 LastTag: 9714 ! LastTaf:!Dat~: 12/28/97 ~4D CONVERSION iLast Update:14116/98 [*""~"~" ~ TS: 20_~ ~"~m! 2~ 0ea~ !02~6 mm 84ft Oft Oft Oft 84ff 4-1/2" Camco DB-5 Nipple 4-112" BOT Bulinose Sheamut Sub 91 O0 Min ID = 3.813" I Daterun: 1982-01~20 Interval Date Type I Comment g566 - 9778 7125/9t SOZ 13-19A Proposed CT Sidetrack Horizontal 5-1/2"Tubin( 5-1/2" Camco BaI-O Nipple@ 2083' Packer @ 9058' 4-1/2" DB-5 Nipple @ 9100' Cement top in 7 @ 92OO' Top of 3-3/16" Liner in TT 7" Liner Top 9115' 9-5/8" Casing shoe @ 9439' Initial Perfs -M Window cut in 7" at -9570' - 9575' 41/8" Open hole 3-3/16" liner 'D @ ~ 11340' Current perforations cement squeezed 7"Casing Shoe @ 10239' RECEIVED NOV 05 1999 AlaslaOil & Gas Co~. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS q l - l z l[5.345.34 RECEIVED BY Have A Nice Day! Production Profile Rim 1, Static Temperature Run 1, Prod Profile Run 1, InJ' profile Run 1, Prod Profile l~m 1, Prod Prof/Jewehy ~ 1, Prod Profile Run 1, Prod Profile Run 1, InJ profile mm 1, InJ profile mm 1, InJ profile mm 1, InJ profile mm 1, InJ Profile Run 1, Prod Profile Run 1, CS. DlCO Camco Camco C~mco Camco Camco Camco Camco Camco Camco Camco Camco Camco and return the attached copy as receipt of data. . .. . .- -. Sonya Wallace ATO- 1529 RECEIVED . ~,/,,APR~,K 0 1 1992. ~Oil & Gas Cons. COmmission APPR OVED__-~ ~'. Anchorage Trans# 92052 ~ # CENTRAL FILES # CHEVRON D&M - # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL ' * The Run Date on this log is 1-23-92. #PHILLIPS PB WEI~ FH, F~ R&D # BPI[ # STATE OF ALAS~ TEXACO ARCO ALASKA, INC. F'~O~ BOX iO~60 ANCHORAGE, ALASKA ,4· DATE' 8-i6-9i REFERENCE' ARCO CASED HOLE FINALS F'ROD F'ROF RUN i , 5' PROD I:'ROF RUN t , 5' VERTILOG RUN i, 5' VERTILOG F,'UN t, 5' GR-COLLAR RUN i, 5' GR-CCL RUN i, 5' CBT F,'UN i , 5" CET RUN i, 5' COLLAR-PERF RUN i, 5" INJ PROFILE/PITS RUN t, 5' COLLAR-PERF RUN i, 5" COLLAR-PERF RUN i, 5' PLEASE SIGN AND RETURN THE ATTACHED RECEIVED BY __ HAVE A NICE DAY! SONYA WALLACE ATO-i 529 COF'Y AS RECEIF'T OF' DATA AF'F:'ROVED ~ 'f'RANS¢. 9 ~. CAMCO CAMCO ATLAZ CAMCO CAMCO SCH ' S C !.-t CAMCO Al'LAS ATLAS DISTRIBUTION ~ CENTRAL FILES .~. ,,-'"' C Fi F V R 0 N D & M · ..-'" FXTENSION EXFLgRATION' ' r ', '- EXXON HARATHON ~ MOBIL F'I"t ILL ! F'S F'B WELL FILES R & D B F' X STATE OF ALASKA ]' E X A [: 0 STATE Of ALASKA ALASKA'~'. AND GAS CONSERVATION CC"~IISSION REPORT uF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging ~ Perforate X Pull tubing ~ Alter casing ~ Repair well ~ Other X 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development ..... ~. 84 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Straligraphic 7. Unit or Property P.O. BOX 100360, Anchorage, AK 99510-0360 Service ~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2758' FSL & 156' FEL, Sec. 14, T10N, R14E, UM 13-19 At top of productive interval 9. Permit number/approval number 487' FSL & 259' FWL, Sec. 12, T10N, R14E, UM 81-180/none At effective depth 10. APl number 50 - 029-20690 At total depth 11. Field/Pool 720' FSL, 342' FWL, Sec. 12, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10246 feet Plugs(measured) true vertical 9448 feet Effective depth: measured 10197 feet true vertical 9402 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 250 sx PF II 110' 110' Surface 2390' 13-3/8" 2500 sx Fondu & 400 sx PFC 2474' 2474' Production 9355' 9-5/8" 500 sx CIG 9439' 8695' Liner 1124' 7" 390 sx CIG 10239' 9442' Perforation depth: measured 9460-9480'; 9620-9650'; 9656-9676'; 9682-9692'; 9711-9721'; 9734-9754' true vertical 8715-8733'; 8864-8892'; 8898-8917'; 8923-8932'; 8950-8959'; 8972-8991' Tubing (size, grade, and measured depth) 5-1/2", L-80, 17#, PCT @ 9069' MD; 4-1/2", 12.6#, N-80, NPCT tail @ 9132' MD Packers and SSSV (type and measured depth) BT perm packer @ 9058' MD; Camco Bal-0 SSSV @ 2083' MD 13. Stimulation or cement squeeze summary I~ [~ I~, I- I V I.. Intervalstreated(measured) See attached AU(~ 2 6 199~ Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons. Corn 14. Reoresentative Daily Avera(3e Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 16636 -- 1330 Subsequent to operation .... 8700 -- 1336 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations w Oil~ Gas ~ Suspended ~ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 744MJF c: SW, JWP SUBMIT IN DUPLICATE~. DS 13-19i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE : INJECTION PROFILE MODIFICATION 7/1 8/91: MIRU Stimulation Equipment & PT to 4500 psi. RIH w/CT & performed a tubing wash/fill cleanout from 0' - 10100' MD using gelled biozan, then acid washed perforations at: 9566 - 9606' MD (Z4) 9620 - 9650' MD (Z4) 9656 - 9676' MD (Z4) 9682 - 9692' MD (Z4) 9711 - 9721' MD (Z4) 9734 - 9754' MD (Z4) 9768 - 9778' MD (Z4) Ref. Log: BHCS 1/14/82. Pumped 95 bbls of 15% HCl w/10% Emulsified Xylene, followed by 200 bbls SW Flush. Spotted 12 bbls of 16.3 ppg mud from 9800' - 10100' MD. POOH. Rigged down. 7/25/91: A CTU Cement Squeeze for Injection Profile Modification was performed as follows: MIRU CTU & PT equipment to 4500 psi. RIH w/CT & fluid packed the wellbore w/seawater, then pumped 5 bbls of neat acid resistive cement, followed by 60 bbls of acid resistive cement w/aggregate, squeezing the perforations (listed above). Squeeze pressure broke back at 2500 psi. Bled well to 500 psi & then pumped an additional 35 bbls of acid resistive cement w/aggregate. A total of 45 bbls of cement was placed behind pipe at 2500 psi maximum squeeze pressure held for 1 hour. Contaminated cement w/contaminant & jetted cement from wellbore. POOH. RD. 8/2/91: RIH & performed a wellbore fill cleanout from 9732' - 9770' MD. Performed an Injectivity test indicating the squeeze was holding. Rigged down. 8/4/9 1: Added perforations: 9460 - 9480' MD (Sag) Reperforated: 9620 - 9650' MD (Z4) 9656 - 9676' MD (Z4) 9682 - 9692' MD (Z4) 9711 9721' MD (Z4) 9734 - 9754' MD (Z4) Ref. Log: BHCS Ref. Log: BHCS 1/14/82. 1/14/82. RECEIVED AUG 2 6 1991 .0il & 6as Cons. commission Nich0rage Returned well to produced water injection & obtained a valid injection test. Data suggests that the channel to the thief zone has been successfully squeezed. DATE ' 4-4-~ F;.~E"F'Ei:'(ENCE: ARCO CASED I"IOLE F:INAI..j/ "~'-- t ? ':;'" t t - ~? t F:'R 0 D U C T I 0 N t" I", U F' .!. L.. E R U N i , '::'" ~.. ,~'-' i 6- ~:' t L E A K D E I E L. [ I 0 N R U N .......'~: .... ':~ t ..... i 8-. ~ t ,S' F:' I N N E R / ...... ! t:.~;~IF"' RUN ' I , 5" ~ "- q S - t 7 - '7 t I N J E C T I 0 N R U N S .... t~:, S-.t7--.~t INJECTION RUN i, 5" 4-2~ t .... '.5-7t F'IT;g' RUN t , 5" '~ S"" ' .... F:' ~S .... ,.. t 6 9 t I T 5' R I..I N ~:~ ':::" ? .... t6 ;3'-'t4-~;'t F'I'T;g' RUN t, 5" ?' --. ~ 4 ,.."~; ..... I 5 '-" c;,, tI N J E C T I O N / 1" E H P R l.J N t , ..,~'" it .... 9 'i .... '7-"-~7t F';CTS RUN I, '.5" -~ c' 2-'-':~ ':~'" tt .... ~'.d i .... i t F'RODUCTION I::'ROFIL. E RUN t ~ ~ ,./' t3;--20 S .... i'7-..~t INdECTION RUN t; 5" t ~..-'~3A ~-1 6--~7t INJEL, TION RUN t, .., t...':~ .-- t '[ ,:'~ -.. t ~ -, t F' E R F' B R E ~ K -.. D 0 W N R U N t ':::" I 6-..9 ~'~-'~,,'z-~, t ,S' I:' ~ NNER/I N JEE C T Z ON RUN i8 .... it g-"8-~t F'ITS' RUN t, 5" I::'I_E..'r-.SZgE: :.";'IGN AND RETURN THE A'/'/ACHED COPY A,~ RF'CEIF'T OF DAI'A. HAVE' A NICE DAY I T'HE 1"1 I-',., CAMCO I..I i:~ C A H C 0 C A i',1C 0 i-.i F;,' l' r'. ,,."~ r'I ,',.: ,.s C A H C 0 C: r:.'t H C 0 H F;.: C A H C 0 C: A H C'. 0 C:AMCO I..i i;;,' l--t F;,' I.t I';,'..S' ~NL;HUk~I."t:..... AI_A,.¥K A ¥'¥ .')~ (':) DATE: RFFEF;.'FNCF' AR'CO ~A,~'.F..D HOI...E FINAl... . · ,: F'WI)W2-~ t ~-6-R7 CFII...I..,AR/PFR'FORATTF1N RIIN · 4-29 '1 "~ "~ . · ,; -,..O-R7 ~1 [. AF,'/PER'FFIRATTrlN RIIN 5-'10 't -6-88 CI, II..I..AR'/PERF'.ORAT.'[ON RIIN c?-'2 't ~-R-R7 9-5 'i 't -t 3-87 COI...I.,AR' RUN 'i q_.c;. '1 'l -R-R7 CI't[. I. AR' RI. IN 'l 9-t 5' 9-2. R-87 COl..EAR R'I.IN 'i 'i 0-'16-R7 CO[. [. AR/F'ERFFIR'AT.TDN RI.IN 'i I 3-2.8 'i -~-88 COI...I...AR./PERFOR. AT .T FJN RUN '~ 4-26 'i -7-R8 cEi. RI.. [..AR/PERF'ORAT.T['IN R'IIN 't 'i 4-:55 'i t -..5-87 COI...LAR RI.iN t 'l ~-'t f ~.0-2,4-R7 C[II...I.AR RI. IN '17-~ 1 -2-88 COI...LAR/F, ERFOF.~AT.T ON F.'I..IN '18-~ 'i C).-24-87 COl.. I...AR RIIN 't ,RECEIVED BY ./ HAVE A N.TCE. DAY' ': F'EGG'Y ~ENi~ETT ATO-t 529 ,laska Oil & Gas ~ ~ CENTRAl... F .'[ I...E,.~ ~ PH .TI...L IP,.-9 · ,,."" CHEVRON F'R WELl.. .F'TL.F,~ D & M F;.'. & D ~' EXTEN,~ION F. XF'I... ORAT I ON ~ '"' EXXON ":~ ':'",~'T-ATE.- £1F '~'¢~i.}A,S'K A ~ . ..... MARATHON ~ ~ TEXACO .,,- MOBIl... Ammummum~,we, Alaska 9961U-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 10, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-19 Approval No. 7-509 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company J. Gruber, ATO-1478 PI(DS 13-19)W1-3 RECEIVED Oil & 6as Cons. Commis~i:2~ An~hcra§e WELLS / 32 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate - Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2758' FSL & 156' FEL, Sec. 14, T10N, R14E, UM At tQp of productive interval 487' FSt.& 259' FW'L, Sec. 12, T10N, R14E, UM At effective depth At total depth 720' FSL, 342' FWL, Sec. 12, T10N, R14E, UM 5. Datum elevation (DF or KB) 84' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 13-19 8. Approval number 7-509 9. APl number 50-- 029-20690 10. Pool _ Prudhoe Bay 0il ;Pool 11. Present well condition summary Total depth: measured true vertical 10246 feet 9448 feet Effective depth: measured 10197 feet true vertical 9402 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 250 Sx Surface 2474' 13-3/8" 2500 & 400 Sx 110' 110' 2474' 2474' Production 9439' 9-5/8" 500 Sx Liner 1124' 7" 390 Sx Perforation. depth: measured 9566-9606'; 9620-9650'; 9656-9676'; 9682-9692'; 9711-9721' true vertical 9439' 8695' 9115-10239' 8392-9442' ; 9734-9754'; 9768-9778' 8814-8851'; 8864-8892'; 8898-8917'; 8923-8932'; 8950-8959' Tubing (size, grade and measured depth) 5~"~ , L-80, 17#, 9132' MD Packers and SSSV (type and measured depth) BOT Perm Packer @ 9058' MD; Camco Bal-O SSSV @ 2083' 12, Stimulation or cement squeeze summary ; 8972-8991' ; 9003-9012' REC iVEI) Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Wate>Bbl Casing Pressure .... 14000 -- .... 14000 -- ~bing Pressure 1100 1300 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed/~) '/')~.~~ ,4~~~--'-", Title Operations Engineering Manager Form 10-404Rev, 12-1-85WELLS/32 T. A. Billingsley, ATP-1506, 265-6821 Date Submit in Duplicate DS 13-19i COILED TUBING UNIT CEMENT SQUEEZE PROFILE MODIFICATION - LOWER CHANNEL SHUTOFF 9/18/87 Performed State annulus pressure test. Pressured 9-5/8" annulus to 1975 psi. Held at 1975 for 30 minutes. Pumped pre-squeeze acid wash through coiled tubing with following volumes plus additives: 47 bbls xylene 47 bbls 15% HC1 47 bbls 6% HCl/1.5% HF 47 bbls 15% HC1 Pumped 50 bbls cement plus additives through coiled tubing. Obtained squeeze pressure of 1000 psi for 85 minutes. Contaminated cement in wellbore. Shut in well overnight. 9/19/87 Jetted out contaminated cement. Shut in well. 10/16/87 Reperforated: Ref. BHCS 1/14/82 9711-9721' 6 spf 9734-9754' 6 spf 9768-9778' 6 spf Shut in well. 10/19/87 Reperforated: Ref. BHCS 1/14/82 9566-9606' 6 spf 9620-9650' 6 spf 9656-9676' 6 spf 9682-9692' 6 spf Placed well on injection. WELLS/32 DATE' ~-27-~ REFERENCE' ARCO CA.~E.1}. I--Ir!!..E PRR. ]DIJr, T T [IN P .1:;.'1] F' T ! .. F'-./.? P 1' N / T FHP PI. IMP-TN TFHF'FR'ATItRP'/GR Pl._EASE S RECEIVED HAVE A N I';'l.!kt RI. IN P T T?.,/TF'.HF' RI!N F'K'F10!i.C. TTi.'INI Pg:RF'rl. I--/I-tPF'M/RK' !;:!tki PF:£]D! t(~T T F1N PR'riD T I..E.'/liENS', T TY/TFHP RI!N PK'Rf~IIFi'TTf]N PF,,'RF'[i. I:/t.-IPFH/TFNP F:!!N T FJ.JF(~T T FIN P I:.;,' fl F 1T 1 .. !:'/,.¢, P T N N !::' K' 17lIN PK'.RO11F:T T RN Pt:;:f]F T. i E/NPFH-lJI-ti IT RI lkl PRE!D! JrIT T Flt'.J P K'[IF T i .I...- / S'P '[ hINES: F;:lli'-J t . F'R[1T')Ii.r..TTQkl PF,.'RF'T!. F/..".:.'F'TNNF'K' K'tlN [;AMHA I;'AY/'f'TF'-..'ri'.I I. Of'; K'IJN F,,AMMA R'AY/'TTF-TN [.f'l~ !-~lll'..J F'E&GY BENNIE"rT A'TO- i 52.9 TRAN.? AF'PR[.1VL--..I) ~ '[ ,~'r F.,: 'r T-Il. IT T Fi i'.J F: A N r,'. F} C. AMFi.~] l-i P, M I'ilq F:AMC..rl · "' r' t:' N T r-;., A i, ...... !-': :I. I... I::.,:, -'J: F'H '[ t... I.. T. t::' .?... ~ !31.-tEVROJ"-J pR WFI.. I. F'f! I) ,*. M R' ,'~..0 · ~ F'KTFN.',.,"Tr~N FXP!.. f]RATTF~N :'.'. .~APf': M ¢~ R A 'T !.4 I1 t,J :~ 'T F. 'K ~'4 P. Ft ~, i'4f3 R T I,.. ARCO ALASKA, INC. ,"~..~ P.O~ BOX t0G36~ -- ANCHORAGE, ALASKA 995~G DATE: t-?-88 REFERENCE: ARCO PRESSURE DATA t2-2~/24 t2-23-87 t2-t3-87 BHP REPORT BHP REPORT BHP REPORT BHP REPORT PLEASE SIGN AND RETURN THE ATTACHED COPY AZ RECEIPT OF DATA, CAMCO CAMCn CAMCO CAMCO RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT AT0-t529 TRAN£ ~88Gt4 APPROVED DISTRIBUTION CENTRAl.. FIL. EE CHEVRON EXTENSION EXF'I...ORATION EXXON MARATHON MOBIL PHIl_LIPS PB WELL FT.L.E,~ TEXACO Alaska Oil & A~o~aO~eS' Gommi~iorl 99,:~' ~ .! D A T E ' '1,3- 2 6 -8 '7 R ti!; F:' Fi; F;..' E i"J. C E ' A R (il 0 C,.':~ .'..:; e d I.'! o I. e F:' i 'n,.'-~ I ReceiYed By ............................................................................ t'-tA V E' A N .'t~ C I:!i D A Y ! ' · ,,' ~.~., 7 5 '71 A p p r o v e c! ......................................................................... Anchorage A,,,~rtorage, Alaska t~9610-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 11, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001'Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-19 Permit No. 81-180 Dear Mr; Chatterton: Attached is the "Intention" Sundry Notice detailing work planned on the above-referenced well. Very truly yours, D. F. Scheve DFS/TA~/jp Attachment cc: Standard Alaska Production Company P1 (DS 13-19)W1-3 WELLS / 32 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED Alaska Oil & Gas Cons. Commission Anchorage AR3B--6132-C APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 84' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 2758' ?SL & 156' FEL, Sec. 4~t top. of productive interval 7' FSL & 259' FWL, Sec. At effective depth At total depth 720' FSL, 342' FWL, Sec. 14, TION, R14E, UM 12, T10N, R'14E, UM 12, T10N, R14E, UM 7. Well number DS 13-19 , ,, 8. Permit number 81-180 9. APl nUmber 50-- 029-20690 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10246 feet Plugs (measured) 9448 feet Effective depth: measured 10197 feet Junk (measured) true vertical 9402 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 250 Sx 110' 110' Surface 2474' 13-3/8" 2500 & 400 Sx 2474' 2474' Production 9439 ' 9-5/8" 500 Sx 9439 ' 8695 ' Liner 1124 ' 7" 390 Sx 9115-10239 ' 8392-9442 ' Perforation depth: measured 9566-9606'; 9620-9650'; 9656-9676'; 9682-9692'; 9711-9721'; 9734-9754'; 9768-9778' true vertical 8814-8851'; 8864-8892'; 8898-8917'; 8923-8932'; 8950-8959'; 8972-8991'; 9003-9012' Tubing (size, grade and measured depth) R E 6 E IV E D 5½", L-80, 17f~, 9132' MD Packers and SSSV (type and measured depth) BOT Perm Packer @ 9058' MD; Camco Bal-0 SSSV @ 2083' 12.Attachments Description summary of proposal ~ Detailed ope. r, atjon~.prpg.[ram [] BOP sketch AlaSKa Ul/& 13. Estimated date for commencing operation 9/15/87 14. If proposal was verbally approved Name of approver Date approved 15. I herebyqcertify tl'j~t the foregoing is true and correct to the best of my knowledge // Signed ~r¢~C/'~~~~ Title Operations Engineering Manager _ ~ Commission Use Only Date Conditions of approval Notify commission so representative may witness Approval No. [] Plug integrity [] BOP Test I-i Location clearance ~.-- ,~'"O ~' ~ i ' byorderof Approved by ~" Commissioner the commission Date ..... SuDmit in trip}icato~ Form 10-403 Rev 12-1-85 WELLS/32 T. A. Billingsley, ATO-1506, 265-6821 · · · DS 13-19 Ensure well is on'water i~jection, not gas injecfion. Pull SSSV. ~Tag pBTD. 'Last PBTD was 10161 on 12/18/86· RU coiled tubing unit· Clean out biomass, if necessary, to 10161'. '4. Perform xylene-acid wash. Note any injectivity change. jecting water overnight. 5. .RIH with CT. Pump.44 bbls cement down CT. Continue in- 6. Pressure up on squeeze to 5200 psi BHP and hold for 1 hour. · GIH contaminating cement to PBTD. Slowly bleed pressure while contamin- ating to leave a minimum of 200 psi differential into the formation. 8.. Jet out contaminated'cement to PBTD. POH and freeze protect. 9. Wait at least two weeks before reperforating. 10. Determine if any perforations are still open. Run spinner if necessary. 11. Nitrogen lift top 2000' of fluid for drawdown during perforating. 12. Reperforate original intervals: (Ref. BHCS 1/14/82) 9566-9606' '4 SPF Zone 4 9620-9650' " " 9656-9676' " " 9682-9692' " " 9711-9721' " " 9734-9754' " " 9768-9778' " " 140' total 13. Return well to inJectio_~n. 14. Run spinner/temperature log. RECEIVED ~Aiaska Oil & Gas Cons~ Commissio~ AFE3/334 6 5 4 3 2 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 4 1/16" PIPE EAM$ 5. 5000 PS1 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX CO I LED TUB ] NO UN I T BOP EQU I PMENT :3 · ii ii ! , 2 ~1 , ij ! I! 1. 5000 PSI 7" WELLHEAD OONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) ~. 5,000 PSI 4 1/6" LUBRICATOR 4. .5000 PSI 4 1/6" FLOW TUBE PACK-OFF I, IIRELINE BOP EQUIPMEN'I' ~h.:l.....'U 'A ta~ka, inc. P..O., Bo;.< t Anchorage: Alaska DATE' August ii, p p F-I:' I:;, ~' i,.! r-E · ;.'_-, r, r- r', i 986 Cas'ed N,'", ! p F ina !. "" -" .... F'rof i I ,=, Run 3-i ,5 7-....,I -°6 Injec: :,...,:: ....... : _. 6-i i 1-23-c_,..--"-"'=' CE'/ loc pr,=,----:.q.,'.leeze Ru~] i '~" 2-3 1 2-I 2-":':',..,_. F'er fora *,. ;' i]g P. ¢,,.- o r d_ _ :-::"" un ~. ":._:. ' i 2- I,.'~_ i2-t''-'-°:'~ ,_,_.--Per fo.r.a '"', i 'rig Record Run i2-i7 i2-i"' o:- .-. _.' "",= ..... R. un I -'-,'-,...,-:- L. Of,~ip [~" ,"f; Ol] ,,'.._uul d _:. i, .'?,-oi,_ .,_ i ":'--'~ '4-:75~ , . _ Comp [e't ~ on, R~rord_ _ R.'..tr,.. ~., _. --., o~T.. -- 0-~T ' ..,- ..'-,_.:- Perfora't:i;",g Record F<un 2 ~-':" t..,.- .. _..- i ,7,- ~ ',-'.' I . ~ ~-... ,...,.., F'er f .. and REPer f .,. F.:un I 5" A ~ i i _--,.::-._o= , , i~-, .._.. ,...,_., CET ~.o,:,.. Ce,,¥,,en'f Eva[ ~.og Run I ...,='" C a :.'.,..' c h S:rh :-','ch $ch ".:c h £ch :?ch :2-. Ceni'ra ,'..Fi ..'-- ,.-. i i E'." ¥ i- ~ i-i '"- F'×i'm~]..~io'.,q F'xm [o'.,-al' int., Ex xofi Ha'fa 'thon ~ Mob i [ ARCO ALmskm, Inc p.O. 'Box ~00360 Anchorege, Alaska DATE' March REFERENCE' 27, i 986 ARCO Cased Hole Final_ DS 6-5 -~-~-~-86 DS 6-5 ~-t2-85 DS 6-5 J -9-85 DS 6-5 t-~-85 DS 6-i i - 2-7-85 DS 6-t t 2-7-85 DS 7-8 t2-28-85 Caliper Inspection CCL/Perf. Record CET Cement Eval CET CCL/F'erf. Record CET F'LS DS 9-i 2-i5-86 6mmmm Rmy DS 9-3 3-~-86 Gaml,',a Ray DS 9-i6 2-i-86 Inj· Spinner DS 1 2-! ~ t i-30-84 TDT DS t~ i6 2-t7-86 ~' ' ~-- ~.-Y Caliper Log Run i 5' Run t 5 ' Run t 5' Run 2 5' Rut, 2 Ru~ 2 5' F'lea~e sigr, and return The Rut, t 5 ' Run i 5" Rut, t 5' Run Rl. tll J :' ' Rut, 3 5 ' Rur, i 5 ' Sp inner Run i 5 Sp inner Ru'n i_.q" Sp inner Run aT¢ached copy as receipt of da¢a. Sch Sch Sch Sch $ch DA C 8 hi C 0 Ca ~c 0 Go ~0 ~.h Ca ~r~,._- o ~o Go Camco Received By HAVE A NICE DAY! Irma Carlin ATO-i429F TRANS ~862i 4 DISTRIBUTION ~ ~ Phi llips .- Central Fi les .,- . Chew-or, F'B WeLL Fi Les D & M R & D ~ ExTension ExploraTion ~ Sohio · ~ Ex xo~l . STa~e of A Mmra'thon ~- Texmco Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 20, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-21 DS 13-19 Permit No. 82-53 Permit No. 81-180 Enclosed are the "Subsequent" Sundry Notices detailing work completed the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosure cc: SOHIO Alaska Petroleum Co. File Pi(DS 13-21)W1-3 File Pl (DS 13-19)Wl-3 RECEIVED 2 1986 Alaska Oil & bas Culls. UommJssioD Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA £ _ AND GAS CONSERVATION ,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERV~][:E [] Wag Injection 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-180 3. Address , 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20690 4. Location of well at surface 9. Unit or Lease Name 2758' FSL & 156' FEL, Sec. ih, T10N, Ri~E~ UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number ~87' FSL & 259' FWL, Sec. 12, TiON~ Ri~E~ UM DS 13-19 At Total Depth 11. Field and Pool 720' FSL & 3~2' FWL, Sec. 12, TiON, Ri~E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 84' RKBI ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/18/81 1/lh/82 1/20/82I N/A feet MSLI 1 17. TotaIDepth{MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 102~6'MD,9~8'TVD ' lO197'MD~9~02'TVD YES [~Z NO [] 2083 feet MD 1750' (approx.) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, LonK Space Sonic/GR, GR/CBL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED S00-95 7" 29.0# L-80 911~' 10239' 8k" ~qfl .~ C1~9~ licit 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9566-9606'MD ~" 9130' 9057' 9620- 9650'tE) 9711-9721'MD hspf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 973z+-975MMD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9768-9778'MD 881h- 9012 ' TVD Ref; BHCS 1 27. PRODUCTION TEST Date 'First Production Method of Operation {Flowing, gas lift, etc.) WaS Injector N/A Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO N/A TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE =F 28. CORE DATA Alaska Oil & Gas. Cons. Go[~rnJssioti Anchorago Form 10-407 CONTINUED ON REVERSE SIDE Submit in duplicate .............. · NAME .. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. __ Top Sadlerochit 9561' 8809' N/A O/W Contact 9866' 9094' Base SaQlerochit 10169' 9376' ! 31. LIST OF ATTACHMENTS None .................. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam iniection, air injection, salt water disposal, water Supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate produc,tion from more than one interval (multiple completion)., so state in item 16, and in item 24 show the producing intervals for only the interval reported' in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COi~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~:X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3, Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 2758' FSL & 156' FEL, Sec. 14, T10N, R14E, UM At Top Producing Interval: 487' FSL & 259' FWL, Sec. 12, T10N, R14E, UM At Total Depth: 720' FSL, 342' FWL, Sec. 12, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB I 6. Lease Designation and Serial No. ADL 28311 7, Permit No. 81-180 8. APl Number ., ~"~. 50- 029-20690 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (Submit in Duplicate) []X Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 12-20-85. RU perforating unit and pressure tested equipment. RIH w/gun ~IA and gun 9lB and gun 91C, shot interval 9768-9778' MD (4 spf), and shot interval 9645-9650' MD (4 spf), and shot interval 9640-9645' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired on guns 9lA and 9lB. Gun 91C didn't fire. RIH with gun 92, shot interval 9625-9645' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun 93A and gun 93B shot interval 9620-9625' MD (4 spf) and shot interval 9586-9606' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH with gun #4, shot interval 9566-9586' MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSSV, Secured well, all shots fired. RD. Ref: BHCS 1-14-82 JAF 2 1986 AJaska Oil & b~s (;uns. t;u~l~nJSSJOI1 Anchorage 14. I hereb~,~certify that the foregoing is true and correct to the best of my knowledge. ~~~ Operations Engineering Mgr. Signed ~x- ~3,,~ Title The space below for Commission use Date Conditions of APproval, if any: Approved by COMMISSIONER Form 10-403 Rev. 7-1-80 By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Al.a~;'ka, Inc:, F',.O, Box i00360 Anc:l'~c)rage, A La~;'l,,a 995t 0 DATE: I) ecember 3 t, t986 RE. FE.F~E.NC['::' ARCO Ca~'e(:t Hole Final 1 -" Iii t 2 -' t 2'-' 86 I n .j e c: t i o n F' r o f i I. e R u n t, 5" 3-t7 t2-~0-86 In.jec:tion F'rofJ Le Run S. 1:; ]2-]S-86 Injec'[ion F:'rofi I.e Run 4-2~ t~,.-.4--86 F'Lope'trol. F'rod. Logging Run ~, 5 9-4 ~2--~....86 Temp/~'pinner(L. eak De~ec~ion) Run 9-..~& ~2-..~.-.68 Injec1'ion F'rofiLe Run t, 5" tS-..t9 t2-.~9-.86 F:'LopeSroL F'rod. Logging Run ~6-..2 t2-..~4-86 l'emp/~2pinner'(Leak De'tec$ion) Run C8 ~liCO C a m c o Camco F Lopetro L C~mco F' Lopetro L C a m c o DISTRIBUTION ~' Cent'ral Fi le~ '~: F'hi llip.~ ~. Chevron F:'B Wel L F'i Le:s D & M R & D ~: Extension Exp [ora~ ion $ ~'oh i o · '" State of Ala.~ka ~. El x × o n '.- May'ail'ion · ,,. Texaco ~: Mob i I ARCO Alaska, Inc. ,~ Post Office B~,...~,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 Permit No. 82-157 13-19 81-180 13-20 82-09 13-21 82-53 13-23A 82-23 13-24 82-65 13-25 82-91 13-32 82-123 Attached are the "Intention" Sundry on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)Wl-3 Pi(DS 13-19)Wl-3 Pi(DS 13-20) W1-3 PI(DS 13-21)Wl-3 Pi(DS 13-23A)Wl-3 P1 (DS 13-24) Wl-3 PI(DS 13-25)Wl-3 P1 (DS 13-32)Wl-3 Notices detailing work proposed ARCO Alaska, Inc. is a Subsidiary of AllanllcRichfleldCompany -~'h) STATE OF ALASKA .... ) ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P,O. Box 100360, Anchorage, Alaska 99510 50- 029-20690 4. Location of Well 2758' FSL, 156' FEL, Sec.14, T10N, R14E, OM (surf) 487' FSL, 259' FWL, Sec.12, T10N, R14E, UM (Top Prod) 720' FSL, 342' FWL, Sec.12, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 84 ' RKB 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate ~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate well 13-19 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9566-9606'MD 9620-9650'MD (reperf) 9768-9778'MD (reperf) Ref: BHCS 1-14-82 RECEIVED NOV 0 7 1985 .... · ~,, ~ u~$ Cons. Commission Anchorage 14'1 hereb~/~ertifyth~~~rrect tO the best Of my kn°Wledge'Title ~ ~~ .. Operations Engineering Mgr. Signed The space below for Commission use Date Conditions of APproval, if any: ORIGINAL $161(EB BY LONNIE C. SMITE By Order of Approved by COMMISSIONER the Commission Approved Copy Eeturr~d Date _ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office--~;~x 100360 Anchorag~ ,laska 99510 Telephone 907 276 1215 Date: February 4, 1985 Reference: ARCO CH Finals 11-15 CBL Run 1 5" 13-19 CFS Run 1 5" 17-10 Diff. Temp run 1 5" 17-13 CBL Run li5" GO 1-6-85 GO 12-30-84 GO 12-29-84 DA 1-11-85 ease sign and return the attached copy as receipt of data Received by Pam'Lambert ATo 1429C Trans 021 Chevron D & M Exploration Services Extension Exploration Texaco Marathon Mobil~ Mmbil,~ E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanllcRichfieldCompany ARCO Alaska, Inc. Post Offic~,-~ox 360 Anchorag ~laska 99510 Telephone 907 277 5637 April 2, 1984 Reference: ARCO Cased Hole Finals D.S. 3-25~'~ 12-2-83 ACBL/VDL/Signature/GR D.S. 3-26"' 11-10-83 ACBL/VDL/Signature/GR D.S. 13-19 /'12-28-83 EPL D.S. 13-21'~ 1-2-84 EPL ,D.S. 13-98'~ 3-7-84 CPL/GST Run 3 D.S. !4-7~' 3-3-84 Temperature D.S. 14-36-z 1-5-84 CBL/VD Run 1 5" DA Run 1 5" DA Run 2 5" Sch Run 2 5" Sch 5" Sch Run 1 5" Otis Run 1 5" Sch and return the attached copy as receipt of data. HAVE A HAPPY EASTER! Kelly McFarland ATO-1429F Trans. # 124 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon ARCO Alaska, Inc Prudhoe Ba~Zngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 ~DS i3'I9 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit prOducing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 ARCO Alasks, In(;. Is a Subsidiary of At ant cR chfleldCompan" STATE OF ALASKA ALASK, '~IL AND GAS CONSERVATION f ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APINumber P.O. Box 360, Anchorage, Alaska 99510 50- 029-20690' 4. Location of Well 2758' FSL, 156' FEL, Sec. 14, T10N, R14E, UM (surf) 487' FSL, 259' FWL, Sec. 12, T10N, R14E, UM (top producing interval) 720' FSL, 342' FWL, Sec. 12, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 84' RKB I ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-19 12. 11. Field and Pool Prudhoe Bay Field Prudhoe .Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~X Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinen.t dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 13-19 to a Water-Alternating-Gas Injection well. Th date of first injection was 12/30/82. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~~~ ~~ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by_ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~x 360 Anchorag~ ,~aska 99510 Telephone 907 277 5637 February 24, 1984 Reference: Arco Pressure Data D.S. 11-2 --'-~1-18-84 'D.S. 13-.19 ~'-12-28-83 D.S. 13-21-'~i-2-84 D.S. 14-14 ---~-12-84 D.S. 18-1 ~'~ 2-4-84 2-4-84 PBU Data Sheet PBU Horner Plots w/Listing HOrner Plots w/Listing Horner Plots w/Listing PBU PBU Data Sheet DA Sch Sch Sch Camco . se sign and return the attached copy as receipt of data. HAVE A NICE DAY! Kelly McFarland ATO-1429F Trans. # 069 they=on D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc, '-" ~ Prudhoe BaoI, gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone.907 263 4248 Donald F. Scheve Regional Operations Engineer June 29, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 13-21 DS 13-24 Permit No. 81-121 Permit No. 81-180 Permit No. 82-53 Permit No. 82-65 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lw 'Attachments cc' Sohio Petroleum RECEIVED J U L - 1 i983 Alaska 0il & Gas Cons, C0mmis$i0r~ Anchorage ARCO Alaaka, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL WAG Injection OTHER 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 360, Anchoraqe, Alaska 99510 4. Location of Well 2758' FSL, ]56' 487' FSL, 259' FEL, Sec. 14, TION, R1 FWL, Sec. 12, TION, R1 4E, UM (Surf) 4E, UM (Top Prod) 720' FSL, 342' FWL, Sec. 12: TION;. R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. __84' RKB ] Ar~l 2R311 12. Check Appropriate Box To 7. Permit No. 81-180 8. APl Number 5o-029-20690 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) IX] Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for .Abandonment see 20 AAC 25.105-170). Began perforating operation 5/4/83. RU perforating unit, pressure tested surface equipment. RIH with gun #1., shot 9730-9750' MD 4 spf (20' ref: CNL 1/25/82). POH- all shots fired. RIH with gun #2, shot select-fire 9764-9774' MD and 9707-9717' MD 4 spf (20' ref: CNL 1/25/82). POH - all shots fired. RD. Ran SSSV. Secured well 5/6/83. JUL -- 1 i983 0ii & Gas Cons, Commjssiol~ .Anchorage . 14. I hereby,~'~lrtify that the foregoing is true and correct to the best of my knowledge. Signed ......... _ _ Title Regional The space below for Commission use Engineer Date Conditions of Approval, if any: Approved by. COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplic~i~te and "Subsequent Reports" in Duplicate ' ~ STATE OF ALASKA ~ ALASKA L AND GAS CONSERVATION "}MISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG/ 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ WAG. Injector ~/~. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P. 0._Box 100360, Anchorage, AK 99510 50029-20690 4. Location of well at surface ~ 9. Unit or Lease Name 2758' FSL, 156' FEL, Sec. 14, T10N, R14E, UM . ..'p.rudhoe.B.ay Unit At Top Producing Interval 10. Well Number 487' FSL, 259' FWL, Sec. 12, TION, R14E, UM D.S. 13-19 · At Total Depth 1 1. Field and P°ol 720'_FSL, 342' .FWL, Sec. 12, TION, R14E, UM .Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool RKB 84' , 'ADL 28311 12. Date Spudded12/18/8l 13. Date T.D. Reached 1/14/82 14' Date C°mp" Susp' °r Aband' 115' Water' Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 1 /20/82 feet MSL 1 17. Total Depth (MD+TVD) 18. Plu~ BacJ< Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 2~1. Thickness of Permafrost 10246'MD 9448'TVD 10197'MD,9 ..02. T.V[ YES[~ NO[] 2083 feetMa 1750' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/ONL/GR/Cal' Long Space Sonic/GR, GR/CBL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 110'" 30" . 250 sx P F. II cement · 13-3/8" 72# L-80 , Surf 2474' 17'1/2" 2500 sx Fondu & 400sx P.F. "C" cmt. "9-5/8" 47#.. L-80/ Surf 9439' 12-1./4" 500 sx Class "G" cement ,., S00-95 7" 29# L-80 9115' '10239" 8,1/2" 390 sx Class "G" ce,~ent · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD -interval, size and number)~ SIZE DEPTH SET (MD) PACKER SET (MD) 9711-9721 ' MD 5-1/2" 91.qn' 9057' 9734-9754' MD 9768-9778' MD ' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8950-9012' TVD . DEPTH INTERVAL (MD) AMouNT & KIND OF MATERIAL 0SED Ref' BHCS 1/14/82 , , ., 27. PRoDucTION TEST I ' Date First .Production Method of" Operation (Flowing, gas lift, etc.) WAG Iniector N/A .... Date of Test Hours Tested PRODUCTION FOR Gl L-EEL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO N/A TEST PERIOD.I~ Flow Tubing Casing Pressure CALCULAT. ED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. ' CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ECEtVED JUL ./. ,- AlasJ~ Oil & Gas Cons Cornmj$~;i~r~ Anchorage. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9561' 8809' 0i 1/Wate r' Conta :t 9866' 9094' Base Sadlerochil 10169' 9376' , , 31. LIST OF ATTACHMENTS 32. i hereby certify that the foregoing is true and correct to the best of my kn(~wledge Signed Title mnc~i neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple com'Pletion), so state in item 16, and in item 24 show the produCing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation- Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. '%, Post Office B,,)~60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 29, 1983 Reference: Arco Cased Hole Finals D. S. 13~19 D.S. 13-26 D. S, 13-98 3-] 8-83 EPL 3-7-83 TDT 3-3-83 3-3-83 3-5-83 Run 1 5" Sch Run 1 5" Sch GST Inelastic'& Stations Run 1 5" Sch GST Capture & Activation Run 1 5" Sch CNL Run 2 5" Sch ease sign and return the attached copy as receipt of data. Kelly McFa~iand AFA-403 Trans. # 306 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION ARCO Alaska, Inc. is a Sub$1'3iarv of EXXON MOBIL GETTY D&M DALLAS CAROLINE SM!TH Naska 0ii & Gas Cons, Commissi, Anchorage ARCO Alaska, Inc. '~,~ Prudhoe Bay £~eering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 10, 1982 C. V. "Chat" Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re' D.S. 13-19 D.S. 13-22 D.S. 13-25 D.S. 13-32 Permit No. 81-180 Permit No. 82-77 Permit No. 82-91 ,Permit No. 82-123 Attached are Subsequent Sundry Notices and Completion Reports for the subject wells. Due to conversion of the surface piping on these wells for injection, i.e. choke and check valve reversed from the producing configuration, the usual well tests were not obtained following perforation. These wells were unloaded briefly to tanks, during perforating and were subsequently shut-in to await injection startup. Very truly yours, D. F. Scheve DFS/lmi Attachments cc' Sohio Petroleum RECEIVED DEC2 1 t982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ' Classification of Service Welt OIL [~]X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Nameo~Op. erator 7. Permit Number ARCO Alaska, Inc. 81-180 .... 3. Address- 8. APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20690 ..... 4. Lo a ion ~)f well surface 9. Unit or Lease Name ,6~58 FSLat156'FEL,, Sec. 14, T10N, R14E, UN Prudhoe Bay Unit At Top P~roducing Interval 10. Well Number 487 FSL, 259'FWL, Sec. 12, T10N, R14E, UM 13-19 At~ Dep_th 11. Field and Pool 'FSL, 342'FWL, .Sec. 12, T10N, R14E, UM Prudhoe Bay Field , , 5. E,evationi, feet lindicateKB, DF, etc. IRKB 84'I L281 I 6. ke~)Design~io:~andSeria, No. Prudhoe 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/18/81 1/14/82 1/20/82 I , - ..... feetMSL. I 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey i 20. Depth where SSSV set I 21. Thickness of Permafrost 10246 ' MD , 9448 ' TV[ 10197'HD,9402'TIDEs~(X NO[] I 2083. feetMD I 1750' (approx) , 22. Type Electric or Other Logs RUn DIL/SP/BHCS/GR, FDC/CNL/GR/Cal Long Space Sonic/GR, GR/CBL/CCL 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:~ 94# H-4u Surf-. 110' 30" 250 sx P.F ' I I cE~m'ent 13-3/E" 72# L-80 Surf. 2474' 17½" 2500 sx Fondu & 4(10 sx P.F. "C" cmt 9-5/8" 47# L-80/ Surf. .9439' 12¼" 500 sx Class "G" cement S00-9.~ , I 1 II 7" 29# L-80 9115 10239" 8~ 390 sx Class "G" ceme'nt · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ~ .: ' SIZE DEPTH SET (MD) PACKER SET (MD) Ref' BHCS 1/14/8'2'' ~ 5½" 9130' " 9057' , 9620-9650' MD , 9656-9676' MD 8781' TVD - 8906'TVD 25. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9682-9692' MD. . ' DEPTH INTERVAL !MD) AMOUNT & KIND oF MATERIAL US~:D 9711-9721' MD . ..... 9734-9754' MD ,,. , 27. PRODUCTION TEST Date First Production Method of Operation {Flowin§, gas lift~ etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BIlL CHOKE SIZE IGAS-OILRATIO : TEST PERIOD I Press:FI°w Tubing Casing Pressure 24-HouRCALCULATED'RATE I~__r. OI L-BBL GAS-MCF WATER-BBL OIL GR A~'CI~ ~V~-- -----,. , 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. DEC2 See Dri 11 ing Hi story Alaska 0ii & Gas Cons. Commission.· Anchorage , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 'GEOLOGIC MARKERs FOt:~M,~,TtON i'ES'i~¥ I~AME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 'op Sadlerochit 9561! 8809' )i 1/l~ater Contact 9866' 9094' lase Sadlerochit 10169" 9376' , , 31. LIST OF ATTACHMENTS ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more. than one interval (multiple completion), so state in item 16, and in item...,24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ elephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-6 D.S. 13-9 D.S. 13-15 D.S. 13-16 D.S. 13-19 D.S. 13,21 D.'S. 13-22 Permit No. 81-121 Permit No. 81-158 Permit No. 82-157 Permit No. 82-148 Permit No. 81-180 Permit No. 82-53 Permit No. '82-77 D.S. 13-23A Permit No. 82-23 D.S. 13-24 Permit No. 82-65 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No. 82-123 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cC. Sohio Petroleum DEC 0 8 i§82 Alaska OiJ & Gas Co,~s~ Ocmmiss~o~ Anchorage ARCO Alalka, Inc. la a Subsidiary of AtlantlcRIchfleldCompany O STATE OF ALASKA ALASKA AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL ~( OTHER [] ~00 p,~rf ~o~ 7. Permit No. 2. Na ka, Inc. 81-180 3. Ad~)res~ BOX 360, Anchorage, Alaska 99510 8, API Number .... 5o- 029-20690 4'k°c~°'~WF~L, 156' FEL, Sec, 14, TION, R14E, UM (surf) 487' FSL, 259' FWL, Sec. 12, TION, R14E, UM (top producing interval) 720' FSL, 342' FWL, Sec. 12, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il P001 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other I-)(]X Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, inclu~ling estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert this well to Water-Alternating-Gas Injection .service. Injection will be into the Sadlerochit; surface piping and instrumentation have been installed as necessary for injection. A downhole safety valve will remain in service in this well following the initiation of injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ......... j Title Regional The space below for Commission use Engineer Date Conditions of Approval, if any: Approved by. ORIG!~A[ SIGHED BY H^~R¥ W. KUGI. ER Approved :Zopy Returned /02 _ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ;~ox 360 Anchorag~ ]~aska 99510 Telephone 907 277 5637 October 22, 1982 Reference: ARCO Cased Hole Finals D.S. 7-6. 9-17-82 D.S. 12-4A 9-6-82 D.S. 13-17 8-3-82 D.S. 13-19 10-2-82 D.S. 13-20 9-26-82 D.S. 1 3-23A 9-30-82 Completion Record Collar and Perf. Log Collar and Perf. Log Completion Record Spinner Completion Record 11 5" 5" 5" 5" 5" Run 1 Run 1 Run 1 Run 2 Run 1 Run 1 SCH Gearha Gearhal SCH Gearhai SCH s.e sign and return the attached copy as receipt of data. Becky-Bendict AFA - 4Q3 Trans. #573 DISTRIBUTION NORTH GEOLOGY R&D -DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY o sr, A Alaska Oil & Gas Cons. October 22, 1982 Reference: ARCO Pressure Data D,S. 17-5 10-14-82 D.S.' 13-19 10-8-82 D.S. 16-3 10-26-81 D.S. 14-18 9-16-82 D.S. 18-2 9-26-82 Pressure Build-up Survey Pressure Build-up Survey Pressure Build-up Survey Static Survey Static Survey ~Piease sign and return the attached copy as receiPt of data. OTIS Gearhart OTI, S D/A CAMCO Becky Benedict AFA - 403 Trans. #576 R&D MOBIL DRILLING GETTY SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON DALLAS bonservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-5 D.S. 13-19 D.S. 13-23A - Permit - Permit - Permit Attached are "Subsequent" the above-mentioned wells. Very truly yours, D.~'Fg~. ' Sc~e~ Regional Engineer DFS:TKKW:skh Attachments cc: Sohio Petroleum Co. No. 81-103 No. 81-180 No. 82-23 Sundry Notices detailing work done on RECEIVED OCT 2 ~ 1982 Alaska Oil & Gas Cons~ Commissiom Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ~ ALASKA uiL AND GAS CONSERVATION CUMMISSION. SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50-029-20690 4. Location of Well 2758' FSL, 156' FEL, Sec 14, TION, R14E, UM (surf) 487' FSL, 259' FWL, Sec 12, TION, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-19 (top producing interval ) 11. Field and Pool 720' FSL, 342' FWL, Sec 12, TION, R!4E, UM (TD) Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. _ RKB 84' [ APL 2831t Prudhoe Oil 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Field Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations J~[] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 10/2/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, no shots fired. POH. RIH with gun #lA, shot ,9730-9750' MD 4 spf (20' ref. CNL 1/25/82), flowed to tank for cleanup, monitored rate, took shakeouts. POH - al! shots fired. RIH with gun #2, shot 9677-9687' MD 4 spf (10' ref. CNL 1/25/82] flowed well. POH - all shots fired. R[H with gun #3, no shots fired. POH. RIH with gun #4, no shots fired. POH. RIH with gun #5, shot 9706-9716' MD and 9636-964~' MD 4 spf (20' ref. CNL 1/25/82), flowed well. POH - all shots fired. RIH with g~h'#6, shot 9652-9672' MD 4 spf (20' ref. CNL 1/25/82), flowed well. POH - all shots fired. RIH with gun #7, shot 9616-9636' MD 4 spf (20' ref. CNL 1/25/82), flowed well. POH - all shots fired. RD. Ran SSSV. Secured well 10/4/82. 14. I hereby/d~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,~~.,,,'~'~ ~ The space below for Commission use Title Regional Operations Engineer Date 10/18/82 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Submit "Intentions" in Triplicate · Rev. 7-1-80 and "Subsequent Reports" in Duplicate August 13, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Re: ~. 13-191, Permit No. 81-180 Permit No. 82-23 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS :TKKW :ml c Enclosures Distribution' Sohio Petroleum Company AUG I ? 1,982 0il & Gas Cons. ~chora~ Cornrn~,s~ion ARCO Alaska, ~rc. is a s~*i~shiiary of A!lanticRichfi~..! ~Comp,'.ny SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20690 4. Location of Well 2758'FSL, 156'FEL, Sec 14, T10N, 487'FSL, 259'FWL, Sec 12, T10N, (top producing interval) 720'FSL, 342'FWL, Sec 12, 5. Elevation in feet (indicate KB, DF, etc.) RKB 84' R14E, UM (surf) R14E, UM 12. T10N, R14~., UM (TD) I 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe proposed Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additiOnal drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. &P'~'/~~/'~ Title Reg, The space below for Commission use Opts. Engineer Date Conditions of Approval, if any: : Approved by ORIGINAL SIGNED BY LOH]ilE C. SI tlTIt Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Aiaska, Inc. Post Office Box 360 Anchorage, Al~a 99510. Telephone 90,]7 5637 August 9, Reference: 1982 ... D.S. :12-Y D.S. 12-7" D S 12- 7A~/~ D.S. 12-7A / D.S. 12-7A.-~ D.S. 12-7A--~ D.S. 12'7A~'~ D.S. 12-7A~-- D. S. D.S. 13-19 D.S. 13-19 D.S. 13-19- D.S. 13-19 D.S. 17-10~? D.S. 17-10~- D.S. 17-10 D.S. 17-10-' D.S. 17-10 ...... Arco Open Hole Finals Listing of Productivity/DaY Volan listing (Recomputed) 10707,62710 10707,62710 CPL/Producibility 12/81 (5-1-82) IPRLOG 10706,62417 Listing of Productivity/Day 10706,62417 Listing of Productivity/Day 10707,62711 Liquid,Water,Oil,Gas Flow Rate charts 5-1-82 Volan listing (Recompu.ted) 10707,62711 CPL/Producibility 1-14-82 (4-1-82) IPRLOG 10707,62533 Listing of Productivity/Day 10707,62533 Liquid,Water,Oil,Gas Flow Rate Charts 4-2-82 Volan listing (Recomputed) 10707,62533 CPL/Producibility 8-8-81 (4-1-82) IPRLOG 10707,62532 Listing of Productivity/Day 10707,62707 Liquid,Water,Oil,Gas Flow Rate Charts 4-1-82 Volan listing (Recomputed) 10707,62707 ~ease sign and return the attached copy Kelly McFariand Trans. ~ 357 as receipt of data. DISTRIBUTION NORTH-GEOLOGY R&D~ · ' DRi'LT.~G P~ILT. J2 $~ $O]LT.O?- ~~0~ CHEVRON ~~ns. ~o.. ....... on D~ G[0 0gy STA~ OF ~S~ ARCO Alasi(a, Inc. is a subsidiary of AtlantlcRichfleldCompat~y ARCO Alaska, Inc. Post Office Box Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA Alaska Oil & Gas Conservation Comm. 3001. Porcupine Drive Anch.,Ak. 99S0~ Attn: William VanAlen OPERATOR: ARCO SAMPLE TYPE: Core chip samples SAMPLES SENT: 9S00 - 9SS8 .a{ 1' intervals 9S60 - 9919~ at 1' intervals DATE: Jun~ 5,1982 NAME' D.S. 13-19 NUMBER OF BOXES: 15 SHIPPED BY: .... ~. . Teresa Gorup/Paleo lab supervisor UPON RECEIPT OF THESE SAMPLES, .PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN: R. L. BROOKS DATE' Oil & Gas Cons. Commission /~=chorag= ARCO Alaska, Inc. is a subsidiary of AtlanticRichfleldCompany ..... . .,, . t~ ' ' ' ,u , ~ .... _ . . . ~.~' .'~ '' . . · . .. ~.. ~ " ~.~, ~,~' ._ . . ..- "~'~'~,~ 0 '~- ~'~" I HEREBY CERTI~ THAT I AM PROPERLY REGISTERED AND ~T~T~ ~_ ;+ LICENSED TO PRACTICE LAND , t~ ~ ~ ~ ~ ~,~uA~SKA AND THAT THIS PLAT REPRESENTS AN ~S-.BUILT SuRvEY ""~r0~ MADE BY ME, AND TH~.T .~zas~a 3982DIMENSIONS AND OTHER DETAILS . Oil&GaSConS. Co~ ARE CORRECT, AS OF: AnC.~orago '//~issio~ I I I I I II I II I II ill I oil" '"C'-o ........ " ' ' ARCO and Gas pany ~ DATE ~ DRAWING No.= m ' NORTH ALASKA DISTRICT. PRUDHOE BAY I~[~t~i ~1~ - I II I J III I I I ii ~ ., ' ' BI ' [ I I ARCO Alaska, Inc , North Slo~ )istrict Post Office 5~,oz 360 Anchorage. AI;:sk~] 9951(~ Telephone 907 277 563'7 Jerry A. Rochon District OperatiOns Eh§]neet March 16, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Subject. D.S. 4-11 Permit No. 78-6 D.S. 13-5 Permit No. 81-103 D.S. 4-14 Permit No. 78-36 D.S. 13-7 Permit No. 81-129 D.S. 11-1 Permit No. 81-123 D.S. 13-8 Permit No. 81-148 D.S. 11-2 Permit No. 81-128 D.S. 13-9 Permit No. 81-158 D.S. 11-3 Permit No. 81-147 D.S. 13-10 Permit No. 81-165 D.S. 11-5 Permit No. 81-155 D.S. 13-12 Permit No. 81-142 D.S. 11-6 Permit No. 81-161 ~'~_ ~Permit No. 81-180 D.S. 12-4A Permit No. 81-187 D.S. 14-12 Permit No. 81-109 D.S. 12-7A Permit No. 81-175 D.S. 14-13 Permit No. 81-101 D.S. 12-8B Permit No. 81-167 D.S. 14-26 Permit No. 81-110 D.S. 12-13 Permit No. 81-87 D.S. 12-14 Permit No. 81-138 Enclosed are our Sundry Notices ,detailing the work to be done on the above mentioned well. Ve/~]truly yours, _ ,]. Ao Rochon JAR.TKKW.mlc Enclosure Amska 0it & 0~s Cons. Anch0~-age ARCO Alaska, Inc. is a subsidiary of AllanticRich¢ieldCompany STATE OF ALASKA ALASKA-~I L AND GAS CONSERVATION C~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] -2, Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50-029-20690 4. Location of Well 2758'~SL,156'FEL,Sec 14,T10N,R14E,UM 487'FSL,259'FWL,Sec 12,T10N,R14E,UM 720'FSL,342'FWL,SEc 12,T10N,R14E,UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 84' (surface) (top- interval ) (TD) I 6. Lease Designation and Serial No. ADL 28311 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-19 .Fie~and Pon ruonoe ~ay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report; or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. 14. I hereby certify__[hat the foregoing i~ue and correct to the best of my knowledge. Signed Title Dist. Oprs. The space bel~/w~or Commission use Conditions o{~Approval, if any: Date ~//~/~ ~ Approved by_ COMMISSIONER ApprOved ~Op¥ Returned By Order of the Commission Date Form 10'~,'03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Be[ ,~0 Anchorage, Alaska 99510 Telephone 907 277 5637 March lC, 1982 Mr. C. V. Chatterton State of Alaska Oil & Gas Conservation Commission 300 Porcupine Drive Anchorage, Alaska 99501 RE- Core Summary - ARCO Drill Site 13-19 Dear Mr. Chatterton: Enclosed please find the Core Summary for ARCO Drill Site 13-19, submitted as Item #36 on Form P-7 for the above mentioned wel 1. Please sign and return one copy of the enclosed transmittal. Very truly yours, A. J. ~B¢~oks Geol ogi cal Manager ARCO Alaska, Inc. AJB/JBM:dvh Enclosures cc: File: GO 12a ARCO Alaske,, Ir~c. is m sub,*;idi~'y oi Allanl!icRichfie]dCe~r,p~qnl? RECEIVED MAR 1 2 ]982 Alaska 0ii & Gas Cons. CommJss~o~ Anchorage ARCO Drillsite 13-19 API #50-029-20671 Core Depth 9500 -9560 9560 -9620 9620 -9680 9680 -9740 9740 -9800 9800 -9860 9860 -9920 CORE SUMMARY Cut/Recovery, 60.0'/59.0' 60.0'/60.0' 60.0'/60.0' 60.0/60.0' 60.O'/58.O' 60.0'/58.0' 60.0'/60.0' % 98.3% 100% 100% 100% 100% 96.6% 100% Lithology Limestone-Shale/Limestone Fine-grained Sandstone Fine-Grained Sandstone Fine-Grained Sandstone Pebbly Sandstone Conglomerate Conglomerate-Pebbly Sandstone Atlantic Richfield Company NORTH SLOPE' DISTRICT TP~3: S,.'-I !ITAL o . :ansmittad hera.with are the fOllowing:. receipt to. Atlanti'c Richfield Company ' Date: ltorth .Slope DistrSct Attn: District Geologist- P.O. Box 360 ;unchorage, Alaska 99510 RECEIYEI) MAR 1 2 1982- Al~sYa 0ii & Gas O°ns.~mi~$io'" Anchorag~ Processed by:_ ,N ~,~.~d,~;~.._ , ARCO Alaska, Inc. ~. Post Office ~( 360 Anchorage, ~aska 99510 Telephone 907 277 5637 March 8, 1982 Reference: ARCO OPEN HOLE FINALS D.S.13-19 D.S.13-19 D.S.13-19 D.S.13-19' D.S.13-19 D.S.13-19 D.S.13-19 1/14/82 1/14/82 1/14/82 FDC Run 2 5" FDC/CNL Run 2 5" BHCS Run 2 2" & 5" Run 1 & 2 2" & 5" Cyberlook Run 2 5" 4 Arm Hi Res Dipmeter Run 2 5" Long Spacing Sonic Run 2 5" 1/6/82 & 1/14/82 DIL/SFL 1/14/82 ~/~4/82 1/14/82 ~e s~gn and return the attached copy as receipt of data. Mary ~. Kellis North Engineering TransmiTtal # 10 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON S~TE~OF~,.A'~LASKA CHEVRON Alask~ 0il & Gas COns. Commission Anchorage ARCO Alaska, Inc. Post Office-9ox 360 Anchorag ')aska 99510 Telephone ~07 277 5637 March 2, 1982- Reference: ARCO MAGNETIC TAPES & LISTS D.S.11-6 1/22/82 Tape #62522 Tape #62501 (UPDATED)' NOTE: The enclosed tape for D.S.13-19 is an updated copy that contains additional data. The tape previously sent to you shoul, d be destroyed. The date on both tapes is the same. ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmitatl # 2 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO' GEOLOGY MARATHON STATE OF ALASKA CHEVRON 4 1982 0il & Gas Cons. ARCO Alaska, Inc. '~ Post Office B,...,,'360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' State Reports Dear Sir' Enclosed please find Well Completion Reports for the following drill sites' 11-6, 12-4A,~~~14-9A, 14-26, 15-15, lA-12, lA-13, and B-11GI. Also included are Monthly Reports for January on drill sites- 13-20, 13-23, 14-30, 15-1, and lA-14. Sincere ly, P. A. VanDusen District Drilling Engineer Enclosures PAV/GLA: sins ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA 0 I:116 IN A L WELL COMPLETION OR'RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well · : OIL:I~ GAS [] SUSPENDED [] .ABANDONED [] SERVICE [] : , 2. Name of (~perator '" 7. Permit Number ARCO Alaska, Inc. 81-180 , 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20690 4. Location of well at surface 9. Unit or Lease Name 2758' FSL, 156' FF, L, Sec. 14, T10N, R14F., UM Prudhoe Bay Unit At Top Producing Interval LOCAT;©N$.110. Well Number 487 FSL, 259 FWL, Sec. 12, T10N, R14E, t~! VERtF]ED 13-19 · At Total Depth Surf._ .~- 11. Field and Pool 720 FSL, 342 FWL, Sec. 12 T10N, Rt4F,, t~.H..~, Prudhoe Bay Field .5 Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. : ?rude_De 0il 2ool RKB 84'] ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/18/81 01/14/82 01/20/82 feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+rVD) 19. Directional Survey 20. Depth where SSSV set ] 21. Thickness of Permafro~t - 10246'MD,9448'TVI) 10197'MD,9402'TVD YES~: NO [] 2083feetMDI 1750' (approx 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal Long Space Sonic/GR, GR/CBL/CCL 23. CASING, LINER AND CEMENTING RECORD ': SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20,, 94# H'40 Surf. '110' 30" ' 250 sx P.F. IT c. mt "~ 13-3/8" 72# L-80 Surf. 2474' 173" 2500 .~× Fond]] and ~!~0 _~ 9-5/8" 47# L-80/ Surf. .9.439': '12~,, . ..500 sx Class ,.,G,, d~t. -- S00-95 7" 29# L-80 9115' 10239' 8!'' 2 390 sx Class "G" ~nt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) . S!ZE .' DEPTH SET (MD) PACKER SET (MD) 53" 9130' 90_57' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,.. DEpyH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED r ' '' '' ':'; '""" :'''' .... ' N/A ' · . . ~. , pRoDuc~oN~'YES~ Date First production .... I Method of O@erati0n (EIo.w ng, gas ift, etc.) ~N/AI , . · .r ~.,..~ · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 'WATER-BBL CHOKE SIZE IGAS-OILRATIO .. . TEST PERIOD l]~ . : Flow Tub ng Casi!!g Pressure cALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '-~ 28. CORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · See Drilling History ~i~ .,, ~' t~. L.~' . 7', ;' ..... ~... lC! V: Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARK~ERS FORMATION TESI"S ... NAME . ' ., Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. Top Sadlerochi - 9561' 8809' N/A Oil/l~ater 9866 ' 9094 ' Base Sadleroch±' 10169' 9376' 31. LIST OF ATTACHMENTS ,,, , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Drilling EngineerDate ., INSTRUCTIONS General· This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for inositu combustion. · Item 5: Indicate which elevation is used as reference (where nOt otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is c9mpleted for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well shoUld show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, SUbmersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 13 - 19 Drilling History NU 20" Diverter. Spudded well @ 1200 hrs, 12/18/81. Drld 17~" hole to 2490'. Ran 61 jts 13-3/8" 72#/ft L-80 BTC casing w/shoe @ 2474'. Cmtd 13-3/8" csg w/2500 sx Fondu and 400 sx Permafrost "C" cmt. No cement returns to surface. Ran 1" top job to 224' RKB in 13-3/8"x 20" annulus - pumped total 520 sx Permafrost "C". ND 20" Diverter. Instld 13,,3/8"packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW.- ok. Drld 122" hole to 6572'. Fisher,hacked off drill pipe. Drilled to 6792' Fish twisted off drill pipe. Continued drilling 122" hole to 9459'. Ran 229 its 9-5/8" 47#/ft S00-95/L-80 casing w/shoe @ 9439' Cmtd 9-5/8" csg w/500 sx Class "G" cmt. Instld 9-5/8" packoff & tstd to 50~0~psi - ok. Tstd csg to 3000 psi - ok, Drld FC & cmt.~ Tstd csg to 3000 psi - Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FSi& 10' new form. Tstd fom to 12 5 ppg EMW ok Drld TM . - 8~' hole to 9500'. RIH and core the following intervals 9500-9560', 9560' -9620', 9620' - 9680', 9680' - 9740', 9740' - 9800', 9800' - 9860', and 9860' - 9820' Cont, d drilling 8~" hole to 10246'. Ran DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, Dipmetes and Long Space Sonic/GR. Arctic packed 9-5/8"x 13-3/8" annulus w/300 bbl H20 300 sx Permafrost "C" and 125 bbl Arctic Pack. Ran 27 jts 7" 29#/ft L-80 TBC liner fr/10239 to 9115'. Cmtd 7" liner w/390 sx Class "G" cement. Drld cmt to 10197'.~LiTStd lnr lap to 3000 psi - ok. Ran GR/CBL/CCL. Displaced well to NaC1/NaBr. Ran 5~" completion assy w/tail @ 9130' &pkr @ 9057'. Tstd tbg hanger & pa~k~ff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Tstd tbg to 3000 psi & ann to 200 psi - ok. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1200 hrs, 01/20/82. RECEIVED F E B 2 1982 ~aska Oil & Gas Cons. Commission Anchorage ~I:;,'CO At~ASKA ~ ..... ~T.t";.:.='~ ....................................... ].S 13 ~ W E L.I...: N 0 ,* '19 I)'~S "RUDHOE BAY, NORTH c: A 12 81 D 0 :l, 4 7 'IL.E i',IUMt ER I 2:.~4 · 0 I.,57-I 2-2 · -'. 2 -- JAN- 8 2 A PE'TI~O[ ANE (.)¢)Mt~ANY F,'CO AL. ASK'A, INC. · "1'3 ~,-'t,! E b [F.-"~N O't ...... ~'9'" X)~.~ f~ 'RUDHOE BAY, NORTH SI. OPE, AI..A~KA C. OI"iF:'UTA T.T ON PAGE: i'!O, '.L J O'B-l'fO,'f---Cd:~~.i'. 4'7 ...... F I-fl E ' ' .... E~-'i' E ......... .............. CODE .............. HEASUREI) VF!:R'TICAL. HD-.-TVD VERTICAl. R E C l' A N G U I.. A R C L 0 S t.I F: E VI:RI'iCAL ............ I " ' ' ', ' . '" '.~0:~ NA~E ............ ='" [EF'TI.'I DE. F1H D;rFF DEPTH C 0 0 R D Z N A T 5 S DZS'f'ANCE DZRECTZO~'( THZCNNE,..,. F-EF~-~ .......F:.BE-T ..... ~;.E-[~:!: ......F~:f~'~: FEET FEE'F ,D -N SAG RIVER -T.~ R-4~A.[~ HOT ZONE O/W COHTACT -.BASE S 9462.00 8728 34 7.7,3 7 '..'.','. ,~,! . "~ 302 09 40 · · .:,,-'.,t-,. ~42986 o,; N 455.06 E 1. N S E 9809.00 ~05m.41 ..... -"' '7,.,6,68968.4I ,s"' :t O3 . 00 N 49.7,99 E 3142.71 N '~' 7 E 98~"~. O0 ~11'5.67 761,~ 903~ .67 '~126 +~:' . ~ ~3 " ......... ,1 N 5o6,25 E 67,.. N ;, 12 E A PE'TROLANE'COMPANY [~S 1~, W'EI.I.. '~l(:); 17 ~.;SS .,. JOB NO: A1281D0147 PRUDHOE BAY, NORTH SI..OF'E, .ALASKA. "'COREX, '~504-~720 MD', ,SURVE'YOR': ~.J MILLER, ENDING DATE 13--JAN--8':2 RIG; ROWAN ~ ....... [;E G~-~ N A T-I,~ N4-~ O--i-/2--D E;.G.-~--E AG-l: , , · ' , ..................... RI;i:.C,.OR,E~.-OF;:-.-.SU.R.VE~ RADILIS OF:' cURVATURE HEI'HOD COHPUI'A T,I' ON I" ' ly7 dO'B--NEFtW'nl~20.-t-BO'J?~ 7 --- ...... :Pt'HI'i: ;I 0 ,* ,~ 3: 16 '~ '*~- " .. c. ,*,, PAGE NO. I ,.,LIB"'IF:Ac, I'VD F"F:E'T 2933;. 13 45 N '18 0 E 93. 2928,46 1, o.,,...6.1. ~-:.o44 46 ~:'" 3119.~ 0 N 4 0 E 92, 3105.0,1 120.1,1 3021. .04 115.,.,°5 N 47.70. 57.8¢ ' -o181. 24'45 N 3 0 E 62. 3161.9.4 14,1.s'-',,:, 3077.94 140.40 N ,~9":' .37 ~ .~.'-, -- ,..~ ....... ., ~' 60. '--~-~, .... 2~- 0 --N .... 2 0-~' · ~s~4~- ~ ~.~ ~ ~ ~-~ ~o _ ~ z z g"~ ~' · , =' 'z ~ '~ r ..... '* ,'.14:,,E'~O:.N..:.r,,.;¥.:::.~o,~,,O./"') ', z .... . , N ,...° 2 · .... ' 4 ~45 25 1=; N 4 0 E ~ . ..~..¥..c. ......... .,,,~.. .... ~ ....... ~ , ....~.. - ._. E.~,~.1:1 N u ~o E 0.08 · ~ ~ ~ ~'5 4 5 N ~ :,','~',,~ ~ , -. t .~, ' , ..~ " '~" "' ' .... N ,,=' ~"" 1 .. ., A Pf~"IROLANE C(mF~NY 5 511,,.31 0 ' N 7 0 E: 4 3 J., 5 24 8,03 118 0 .0 8 ,.~; :!. 64 , t~.. 3. .1. J. ""z ,;, 36 ''~ "' N 1,13 , --61 o 4., ........... ~ .......... 0 ---N ...... 8 ............ 0.-E ............ 6-t 3--, ............ 57.67.,-8-~]~ .............. J.-504.~-4 8 ............. ~::.6 8 :3-.. ,-. 8 73 .......... ~ .4 9.4--,-4 O- "'::' ~:' " 67.51. 32 30 N 10 0 E 4JO. 5~°] 67 18'17. ')'''' ':" '" ..... " ...,... ';,~ 6207.67 ~<::'3a,,.,6 N 240.34 E J8':50.,:,t N 7 o8 E r " ',~.~ ~' '~ ~'" ' 'u'~'~ ~:: -~.l_~'= 49 ~' 2oo 7638. 28 0 N 7 0 E 2.84. 7055.52 22?7.32 697.1.52 2279.95;' N 307.24 E 2300.60 N 7 40 E 0.72 - ~9, 1~ ....2-5-.45--N 7--.-O---E;--- ~7-2, 7-2~-8,~~2~-Q--~t--6 - 7;%i-.¢~;~ ....,:~,0~: ~ ~2&%~~- ~-, ~~-,~---.~-.-~...,-- E ...... 0,83-- 8273, 24 0 N 8 0 E 363, 7627, ~'I ~,s?':, 6":' '~'~":' " ~'~ .... ~ 7543,44 ~..~3.40 N .~42,16 E 2576.o'~ 5 8902, 21 45 N 15 0 E 629. 8206,94 2815,23 8122,94 2792,83 N 390,87 E 2820.05 N 7 58 E 504 HD IS 15T COREX "SURVEY" STATION 9504. 20 45 N 23 0 E 160. 8'767, .5"',.. ,.7.0.o?.., .o6, 8683;.,.,~:":'",., ,..=000.62 N 460.58 E :3035.76 N 8 44 E 0.74 ~' 8819 83 3047 .°1 8'"'='. ~ '~ 9560~ 21 15 N 19 0 E ~6.. .,.. 7,3,, 83 3019.35 N 467.77 E 3055.37 N 8 4b E ,~.71 ?&80. 20 45 N 20 0 E &O. ~932.05 ,.,=088.25 8~48.05 ~059.37 N 482.13 E 3077.13 N 8 ,,='7 E 0.42 ALASKA 'ff~ASUR~F; [RIFT I:d.,. ~ FT COURSE DF:.PTH ANGLE.: DIRECTION LENG'f'H PAGE NO. 2 · l'Aq ir" VERTICAl. VER'T'.T[;AI. StJP, SE:A R E C l' A N G U L A R C L. 0 S tJR E. DOGLE~ DEPTH SECTION 'fyi). c 0 0 R D I N A T E S DISTANCE DIREC.TION SEVERIi F4Z~;-T- F E E T F: E E T D M · D G / ! ~; 9740+ 21 0 N 20 0 E 60, 8988~'1..1 3108,86 8904+1.1 3079.46 N 489..45 E 3118,11 N 9 2 E 0.42 ---98~,,---2~--~4',,-N-..-2..0 -0- E ~.'),, ~..,~.'~.+ O~ 3129-,8~.' -_8~.6L,-~ -~':~~~ N - 496 ~ 88 E .... 3:[~9_~ 4-~N~~; 98&0 21 ~0 N 19 0 E &O 9099 8& ~15i+08 9015 8& ~1° ' - .. . . ,. ~0.o2 N 504.-~ E 3:(61.09 N 9920+ 21 ~0 N 19 0 E 60 o~55 - (> ,68 ,~:172 ~8 9071,68 3:!41 41 N 511,38 E ~182 76 N 9 ,o920 MD IS LAST "COREX" SURVEY STATION ,~ D I STANCE ,* A PETROLANE COMt~NY ARCO ALA,.KA' INC DS 1~, WELl.. NO.~ 1~,; DSS JOB NO~ A1281D0.147 'ONVERSATIONAI. SURVEY PROGRAH ,. · V02oll A PE"TFIOLANE' COMPANY SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage, Alaska 99502 · 907~ 349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED February 8, 1982 Job #5287 North Slope Drilling- Enclosed please find our Gyro along with our Horizontal and Film, and Field paperwork. Survey on DS 13-19 Vertical View maps, If any other information is needed please ca!l. 349-3541. Thank you for using Scientific Drilling and please call again. International Sincerely Manager COMPLET ION ~"~PoRT ARCO ALASKA INC. 6YROSCOP!C SURVEY RADIUS OF CURVATURE METMOD OF COMPUTATION COMPUTED FOR SDC BY FM L INDSEY 6. AS$OC WELL DS 13-19 KB ELEV 84 FT JOB NO 528~7 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SE.A DIREC DEG, TOTAL COORDINATES 0 0 0 0,00 100 0 0 100,00 200 0 0 200,00 300 0 0 300,00 400 0 O' 400.00 50O 0 0 500.0O 600 0 0 600,00 700 0 0 700.00 800 0 0 800.00 900 0 0 900.00 1000 0 0 1000.00 -84.00 N O,OOE 16.00 N O,OOE 116.00 N O.OOE 216.00 N O.OOE 316.00 N O,OOE 416.00 N O.OOE 516,00 N O,OOE 616.00 N O.OOE 716.00 N O,OOE 816,00 N O,OOE 916,00 N O.OOE 1100 0 0 1100.00 1016.00 N O. OOE 0.00 'S 0.00 W' 0.00 S 0.00 W 0.00 S 0.00 W 0,00 S 0,00 W 0.00 S 0,00 W O,O0~S~ :~'..~-0-00 W_ O.O0~.S ~.~;-~0,00 W o.oo w, O..O0--S ~h~O,oo-w 0.00 S 0.00 W 0.00 S 0.00 W 0.00 S 0.00 W 1200 0 0 1200.00 1116,00 S O.OOE -, 0.00 S 1300 1 0 1299,99 1215,99 S21,23E 1400 0 30 1399,98 1315,98 S32.25E 1500 0 30 1499,98 1415,98 S46,26E 1600 1 0 1599,97 1515,97 S41,26E 1700 1 0 1699,95 1615,95 S42,28E 1800 0 45 1799.94 1715.94 S34,28E 1900 1 0 1899.93 1815,93 S35.30E 2000 0 30 1999,92 . 1915,92 S42,36E' 2100 1 0 2099,91 2015,91 S13,38E 2200 1 0 2199.90 2115,90 Sll,38E 2300 0 0 2299,89 2215.89 S O.OOE 2400 0 0 2399,89 2315~89 S O.OOE 0,85 S 2.01S 2,69 S 3,63 S 4,94 S 6.13 S 7.39 S 8,41 S 9.55 S 11.26 S 12,12 S 12.12 S 0.00 W 0.15 E 0.74 E 1.29 E 2.20 E 3.36 E 4.31 E 5.18 E 6.00 E 6.60 E 6,98 E 7,06 E 7.06 E CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 0.00 5 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0o00 $ 0 .0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.86 S 10 36 59 E 2,15 S 20 19 5 E 2,99 S 25 44 20 E 4.25 S 31 12 /+ E 5.97 S 34 16 18 E 7.5O S 35 5 13 E 9,02 S 35 2 13 E 10,33 S 35 31 2 E 11,61 S 34 40 5 E 13.25 S 31 /+8 18 E 14,03'5 30 14 23 E 14,03 S 30 14. 23 E 0,000 0,000 0,000 0.000 0,000 0,000 0o000 0.000 0.000 0.000 0.000 0.000 0,000 1.000 0,500 0.122 0,500 0.018 0.250 0.250 0-500 0,500 0.035 1,000 0,000 ~-.....~ SECTION DISTANCE 0.00 0o00 0.00 0.00 0.00 0.00 0.00 0-00 0.00 0.00 0,00 O. -0,81 -1.88 --2.46 -3,26 -4.37 -5.41 -6.51 -7.40 -8,44 -10,06 -10,91 -10,91 ARCO DS GYROSCOPIC SURVEY ~_..DB NO 5287 4 FEB, 82 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 2500 1 0 2499,89 2415.89 S22,415 2600 1 15 2599.87 2515,87 $88,435 2700 6 0 2699.64 2615,64 NSO.40E 2800 11 15 2798,47 2714,47 N29,115 2900 12 0 2896,42 2812,42 N18,215 3000 17 0 2993.21 2909,2t N 9.265 3100 21 45 3087.51 3003,51 N 3.515 3200 24 0 3179,64 3095.64 N 1,685 3300 25 . 0 3270,64 3186,64 N 2,585 3400 25 0 3361,27 3277,27 N 3,4BE 3500 25 30 3451.72 3367.72 N 3.435 3600 25 15 3542,07 3458,07 N 4,315 3700 26 0 3632,23 3548,23 N 5.205 3800 25 30 3722,30 3638.30 N 5,205 3900 25 0 3812,75 3728,75 N 5,205 4000 25 30 3903.19 3819,19 N 4.285 4100 25 0 3993.64 3909,64 N 5.185 4200 25 15 4084.17 4000,17 N 5,165 4300 25 15 4174,62 4090,62 N 6,965 4400 25 0 4265,16 4181,16 N 5,155 4500 25 0 4355.79 4271.79 N 6.955 4600 25 45 4446.14 4362,14 N 8,715 4700 25 45 4536,21 4452.21 N 7,815 4800 26 0 4626.19 4542,19 N 7,805 4900 27 0 4715,68 4631,68 N 7.705 5000 28 0 4804.38 4720,38 N 7,655 5100 28 0 4892,67 4808,67 N 7.635 5200 28 30 4980.76 4896.76 N 8.485 5300 29 0 5068.43 4984,43 N 8,455 1025.34 N 12,97 S 7,23 E 14.03 S 8,76 E 12,01 S 14,61 E 0,55..S 24,14 E 17,87 N 32.22 E 42.15 N 38.16 E' 75.10 N 41,85 E 11~,93 N 43.61E 155.37 N 45.16 E 197,57 N 47.37 E 240,15~N~ '!:i~49.93 ~:E:: 282.91~iN~~ i: ~ilii52,82 E 326,00~.N..: 56,41"E 369,27~N ~ 60.,35::E· 411,75 N 64,22 E 454,26 N 67.74 E 496.77 N 71,26 E 539,06 N 75,09 E 581,47 N 79.60 E 623,70' N 84.08 E 665,72 N 88,53 E 708.17 N 94,38 E 751,17 N 100,62 E 794.40 N ~06.55 E 838.61 N 112,57 E 884.37 N 118,7'3 E 930,90 N 124,98 5 977.77. N 131,61 E 138,69 E CLOSURE5 DISTANCE .ANGLE D M 5 DOG LEG SEVERITY DEG/IOOFT 14,86 5 29 8 58 E 16.54 S 31 59 48 E 18.92 $ 50 34 25 E 24,15 $ 88 40 37 E . 36,84 N ~0 59 20 'E 56,86 N 42 9 9 E 85,97 N 29 7 48 E 121,99 N 20 56 55 E 161,80 N 16 12 26 E 203,17 N 13 29 6 E 245.29 N 11 44 44 E 287.80 N 10 34 38 E 330,85 N 9 49 5 E 374,17 N 9 16 56 E 416.73 N 8 51 ~3 E 459.29 N 8. 28 56 E 501,86 N 8 9 49 E 544.26 N 7 55 50 E 586.90 N 7 47 43 E 629.34 N 7 40 41E 671,58 N 7 34 32 E 714.43 N 7 35 28 E 757,88 N 7 37 47 E 1,000 0.252 4,771 5.312 0,886 5,058 4,815 2,270 0.359 0,500 0,297 0,769 0,500 0,500 0.528 0,525 0,250 0,708 0,410 0,761 0.821 0,391 801,52 N 7 38 22 E ' ' 0,250 846.13 N 7 38 43 E 1,000 892,31 N 7 38 49 E 1,000 939,26 N 7 38 48 E 0*008 986.59 N 7 39 59 E 0,536 1034,68 N 7 42 13 E 0.500 SECTION DISTANCE -11,. ~; -12.~ -9.65 3.12 22.56 47'.47' 80.59 119,24 160'~3 202,48 244.95 287.65 330.79 374.15 416,73 459,28 i, 586,82 629,23 671.44 714.29 757,73 801.37 845,98 892.15 939,08 986,41 1034,51 ARCO DS ~.,,~.19 GYROSCOPIC SURVEY · .~..~OB NO 5287 4 FEB, 82 'RECORD OF SURVEY MEA$, DRIFT DEPTH ANGLE D M 54O.O 30 0 5500 31 0 5600 32 0 5?00 32 30 5800 33 0 5900 33 0 6000 34 0 6100 33 30 6200 34 0 6300 34 '0 6400 34 0 6500 34 0 6600 33 0 6700 33 45 6800 32 30 6900 33 0 7000 32 0 7100 32 0 7200 31 0 7300 30 45 7400 30 0 75O0 3O 0 7600 28 0 77OO 27 45 7800 27 30 7900 27 0 8000 27 0 8100 25 0 8200 24 45 TRUE VERTICAL DEPTH 5155,47 5241,63 5326,89 5411.47 5495.57 5579.44 5662.82 5745.97 5829.12 5912,02 5994.92 6077.83 6161.22 6244.72 · 6328.47 6412.57 6496,91 6581.72 6666.98 6752.81 6839.08 6925.68 7013.14 7101.54 7190.14 7279.04 7368,14 7458,02 7548.74 SUB SEA 5071,47 5157.63 5242,89 5327,47 5411,57 5495,44 5578,82 5661,97 5745.12 5828.02 5910.92 5993.83 6077,22 6160.72 6244'.47 6328.57 6412.91 6497.72 6582.98 6668.81 6755.08 6841,68 6929.14 7017,54 7106,14 7195.04 7284.14 7374,02 7464.74 DRIFT DIREC DEG, N 8.385 N 9.185 N 9.115 N 9.065 N 8.185 N 9,015 N 8,105 N 8.115 N 8,915 N 8,085 N 5,515 N 3.015 N 3.855 N 4,655 N 7.205 N 8,015 N 8.065 N 5.505 N 5.515 N 2,935 N 2,9IE N 2,915 N 3,785 N 1.11E N 2,835 N 3.715 N 5,005 N 5,035 N 5,535 TOTAL COORDINATES 1074.05 N 145.90 E 1124,21 N 153,65 E 1175,80 N 161,96 E 1228.49 N 170,39 E I281.97 N 178.50 E 1335.82 N 186,65 'E 1390.40 N 194.86 E 1445,40-N 202.70 E 1500.35 N 210.93 E 1555.65 N 219,19 E 1611 ' 17 :-'.'~N:' ~>2-25 ,.'8 1 ~i: g 1666,93-:N:' i:i ~'~22-9,97" E '1722'02111N'' :~ ~23~';'2'8. E 1776.88 N :237'35-E 1831.23 N 242.99 E 1884.85 N 250.16 E 1938,06 N 257.67 E 1990,67 N 263,93 E 2042,68 N 268.95 E 2093,85 N 272,73 E 2144.35 N 275.31E 2194,29 N 277.85 E 2242.68 N 280.68 E 2289,39 N 282.68 E 2335.73 N 284,28 E 2381.44 N 286,90 E 2426.71N 290.35 E 2470.37 N 294.18 E 2512.26 N 298.05 E CLOSU DISTANCE RES ANGLE O M $ 1083,92 N 7 44 9 E 1134.66 N 7 46 58 E 1186.90 N 7 50 35 E 1240.25 N 7 53 48.E. 1294.34 N 7 55 37 E 1348.80 N 7 57 15 E 1403,99 N 7 58 41 E 1459-55 N 7 58 59 E 1515.10 N 8 0 9 E 1571.02 N 8 1 13 E 1626.92 N 7 58 42 E 1682.72 N 7 51 18 E 1737,75 N 7 42 53 E 1792.67 N 7 36 30 E 1847,29 N 7 33 31 E 1901.38 N 7 33 36 E 1955.11 N' 7 34 24 E 2008.09 N 7 33 9 E 2060,31 N 7 30 2 E 2111.54 N 7 25 16 E 2161.95 N 7 18 58 E 2211.81 N 7 13 0 E 2260.18 N 7 8 2 E 2;306.78 N 7 2 20 E 2352,97 N 6 56 21 E 2398,66 N 6 52 10 E 2444.02 N 6 49 22 E 2487,83 N 6 47 27 E 2529.88 N 6 45 57 E DOG LEG SEVERITY DEG/iOOFT 1.000 1.022 1.000 0.500 0.564 0.454 1,040 0,500 0,559 0,466 1,435 1,398 1.030 0.790 1,451 0.556 1.000 1,360 1.000 0,720 0.750 0,000 2,009 0.630 0,443 0.532 0,583 2,000 0,265 SECTION DISTANCE 1083~ 1134,50 1186.75 1240.11 1294.21 1348,67 1403,86 1459.42 1514.97 1570,89 1626.77 1682m52 1737.47 1792.31 1846,89 1900,98 195.. jO 2059.82 2110,98 2161,28 2211.02 2259.28 2305.75 2351,80 2397.37 2442,64 2486,38 2528.37 ARCO DS l S...~9 GYROSCOPIC SURVEY ~._,JB NO 5287 4 FEB, 82 ~ . RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 8300 25 0 7639,46 7555,46 N 6,93E 2554,07 N 8400 24 0 7730.46 7646,46 N 7,48E 2595,21 N 8500 23 15 7822,07 7738.07 N 8,93E 2634,88 N 8600 24 0 7913,69 7829,69 NiO.31E 2674,39 N 8700 22 45 8005,48 7921,48 Nll,80E 2713,32 N 8800 22 30 8097,79 8013,79 N13,25E 2750.88 N 8900 21 30 8190.50 8106,50 N14-75E 2787.22 N 9000 20 30 8283,86 8199,86 N16.86E 282i.70 N 9100 20 0 8377.68 8293.68 N17.40E 2854.78 N 9200 21 0 8471,35 8387,3'5 N16,46E 2888,28 N 302,62 E 307,82 E 313,55 E 320.25 E 327,85 E 336,20 E 345,26 E 355,02 E 365.22 E 375,42 E 9300 20 45 8564.78 8480,78 N16.53E 2922,44'~"N:~ 385,54' E 9400 20 30 8658,37 8574,37 N19,06E 2955,98-'N! ~396,31 E 9500 20 30 8752,04 8668,04 N20,81E 2988':',90:iN 408'25 E 9600 20 0 8845,86 8761,86 N20,70E 3021.27~N 9700 21 0 8939,52 8855,52 N19,56E 3054.15 N 9800 21 30 9032,73 8948,73 N19,41E 3088.31 N 9900 22 0 9125,61 9041,61 N21,11E 31'23,07 N 10000 21 30 9218.49 9134.49 N20,O8E 3157.76 N 10100 21 0 9311,69 9227,69 N17,28E 3192,09. N 10200 21 0 9405,04 9321,04 N17,95E 3226,24'N 420,52 E 432,57 E 444,66 E 457,50 E 470,54 E 482,15 E 492,99 E THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 10246 21 0 9447,99 9363,99 Nt7,95E 3241,93 N 498,07 E C L O S U R E 5 DISTANCE .ANGLE D M 5 2571,94 N 6 /+5 26 E 2613,41 N 6 45 52 E 2653,47 N 6 47 10 E 2693.49 N 6 49 42 E 2733.06 N 6 53 23 'E 2771.35 N 6 58 4 E 2808.53 N 7 3 41 E 2843,95 N 7 10 16 E 2878.05 N 7 17 25 E 2912,58 N 7 24 21 E 2947.77 N 7 30 55 E 2982,43 N 7 38 10 E 3016.65 N 7 46 40 E 3050.39 N 7 55 26 E 3084.63 N 8 3 41 E 3120,16 N 8 ll 36 E 3156,40 N ' 8 20 2 E 3192,62 N 8 28 31 E 3228,30 N 8 35 21 E 3263,69 N 8 41 16 E 3279,96 N 8 44 3 E DOG LEG SEVERITY DEG/IOOFT 0,354 1,004 0,783 0e784 1.270 0.328 1,020 1,033 0,504 1,007 0.250 0,399 0,613 0,500 1.011 0,500 0,554 0,519 0,616 .0,239 0,000 SECTION DISTANCE 2570.8--4-~' 2611. 2651,92 2691.99 2731.63 2770;01' 2807,3'1 2842,88 2877,12 2911,78 2947,09 2981,87 3016,22 3050,08 3084,41 3120.01 3156 3228,28 32b3,69 3279.96 BOTTOM HOLE CLOSURE 3279,96 FEET AT N 8 44 3 E ARCO DS 1~9 z+ FEB. 82 CODE NAME GYROSCOPIC SURVEY .~.~)B NO 5287 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE - MEASURED VERTICAL TOTAL COORDINATES ~ C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D N $ SUB SEA TOP SAD 9561 8809.23 3008,83 N 415.50 E OIL/WATER 9866 9094.06 3111,26 N 452.86 E BASE SAD 10169 9376.10 3215.73 N 489.38 E PBTD. 10197 9402.24 3225.33 N 492.31 E TD 10246 9447.99 3241.93 N 498.07 E 3037.39 N 7.51 45 E 8725.23 3144.04 N 8 16 53 E 9010.06 3252.76 N 8 39 10 E 9292.10 3262.69 N 8 40 43 E 9318.24 3279,96 N 8 44 3 E 9363.99 ARCO DS I3,..~9 GYROSCOPIC SURVEY ~..,~B NO 528? 4 FEB. 82 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFEREN¢£ CORRECTION TOTAL DEPTH. COORDINATES '184 184 284 284. 384 384. 484 484. 584 584. 684 684, 784 784. 884 884. 984 984. 1084 1084. 1184 1184, 1284 1284, 1384 1384, 1484 1484. 1584 1584, 1684 1684, 1784 1784. 1884 1884, 1984 1984, 2084 2084. 2184 2184. 2284 2284. 2384 2384. 2484 2484, 2584 2584. 2684 2684. 2785 2784, 2887 2884, 2990 2984, 3096 3084~ 3205 3184. 3315 3284. 3425 3384. 3536 3484. 3646 3584, . 100 200 300 400 500 60O 700 800 90O 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 3 6 12 2O 31 41 52 62 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 3 6 8 11 10 11 10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.60 1.89 2,59 3.44 4.73 5.96 7.17 8.30 9.30 10.98 12.10 12.12 12.73 13.98 12.76 2.86 15.34 39,36 73.66 115.87 161.59 208,15 255.49 302.60 5 5 5 S 5 $ $ S S 5 5 S 5 S 5 S 5 $ S 5 5 S S S $ N N /'4 N N N N N 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0,00 W 0,00 W 0.09 E 0,66 E 1.19 E 2.02 E 3.17 E 4,18 E 5.02 E 5.89 E 6,51 g 6.91 E 7.07 E 7.06 E 7.16 E 8.42 E 13,28 E 22,57 E 31.29 E 37.55 E 41.53 E 43,65 E 45,38 E 47.93 E 50.78 E 54.28 E ARCO DS 1 ~ 9 MEASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY ~,~B NO 5287 FOR EVERY EVEN 100 FEET OF SUB SEA MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL DEPTH. COORDINATES FEB. 82 3757 3868 3979 4089 4200 4310 4421 4531 4642 4753 4864 4977 5090. 5204 5318 5433 5549 5667 5786 5905 6025 6146 6266 6387 5o7 6627 6747 6866 6985 7103 7220 7336 7452 7567 7680 3684. 3600 73 3784, 3700 84 3884, 3800 94 3984, 3900 105 4084. 4000 115 4184, 4100 126 4284, 4200 137 4384, 4300 147 4484, 4400 158 4584. 4500 169 4684. 4600 180 4784, 4700 192 4884e 4800 206 4984. 4900 219 · 5084. 5000 233 5184, 5100 248 5284, 5200 265 5384, 5300 283 5484, 5400 302 5584, 5500 321 5684, 5600 341 5784, 5700 361 5884, 5800 382 5984, 5900 403 6084. 6000 423 6184, 6100 443 6284, 6200 463 6384, 6300 481 64840 6400 501 6584, 6500 519 6684. 6600 536 6784, 6700 552 6884. 6800 568 6984. 6900 583 7084. 7.000 596 11 11 10 11 10 11 1'1 10 11 ll 11 12 14 13 14 15 17 18 19 19 20 20 21 21 2O 20 2O 18 2O 18 17 16 16 15 13 350.77 N 398,25 N 445.17 N 492.15 N 538.99 N 585,72 N 632.44 N 678,80 N 726,25 N 774,07 N 822.57 N 873.77 N 926.31 N 979,51 N 1033.92 N .1090,47 N 1149.32 N 1211,03 N 1274,45 N 1338,51 N 1404,22 N 1470,43 N 1536,89 N 1603.86 N 1670,84 N 1736.75 N 1802,74 N 1866,56 N 1930.04 N 1992.09 N 2052.86 N 2112.17 N 2170.27 N 2227,02 N 2280.09 N '58.58 62.89 66,91 70,69 74,96 80,04 84,86 89.98 96,85 103043 llO,Ol E 116,88 E 123,88 E 131,86 E 139.90 E 148.26 E 157.63 E 167,54 E 177.32 E 187.07 E 196,80 E 206.22 E 216.06 E 224.85 E 230.18 E 234,08 E 239.48 E 247.54 E 256,51 E 264,06 E 269.78 E 273,37 E 276.21 E 279,19 E 282,12 E E E E E E E E ! E E E ARCO DS 1~9 MEASURED DEPTH AND GYROSCOPIC SURVEY OTHER DATA FOR EVERY EVEN 100 MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE ,,....,cB NO 5287 FEET OF SUB ,SEA VERTICAL CORRECTION TOTAL DEPTH, COORDINATES 4 FEB, 82 7.793 7906 8018 8129 8239 8349 8458 8567 8677 8785 8893 9000 9107 9214 9321 9427 9534 9641 9748 9855 9963 0070 0177 7184. 7100 609 7284, 7200 622 7384, 7300 634 7484, 7400 645 7584, 7500 654 7684, 7600 665 7784. 7700 674 7884, 7800 683 7984, 7900 693 8084. 8000 701 8184, 8100 709 8284. 8200 716 8384. 8300 722 8484, 8400 730 8584, 8500 737 8684, 8600 743 8784, 8700 750 8884' m8800 756 8984, 8900 763 9084, 9000 771 9184, 9100 779 9284. 9200 786 9384, 9300 793 13 13 12 11 9 11 9 9 10 8 8 7 6 - ~ 8 ' ,:.: -~:'i-.i:=~ ~: - 6 , 6 7 8 8 7 7 2332,51 N 2383,96 N 24 34,69 N 2482,42 N 2528,48 N 2574,49 N 2618,41 N 2661,29 N · 2704,48 IN 2745.35 N 2784,81 N 2821,70 N 2856,98 N 2892,94 N 2929,42 N 2964.91 N 3000,05 N 3034,47 N 3070 · 39 N 3107.42 N ~144e97 N 3181.83 N 3218,48 N 283,79 E 287,03 E 291,05 E 295,23 E 299.53 E 304,85 E 310,79 E 317.58 E 325,76 E 334,58 E 344,32 E 355,02 E 365,89 E 376,76 E 387,58 E 399,41 E 412,31 E 4'25,27 E 438,16 E 451,45 E 465.77 E 478,80 E 490,21 E ARCO DS 1 INTERPOLATED VALUES T MEASURED VERT DEPTH DE 1000 2000 1 3000 2 4000 3 5000 4 6000 5 7000 6 8000 7 9000 8 lO000 9 GYROSCOPIC SURVEY -,,,_,,~B NO FOR EVEN 1000 FEET OF MEASURED DEPTH. RUE ICAL SUB PTH SEA TOTAL COORDINATES 000. 916, 0.00 S 0.00 W 999. 1915. 8.41S 5.99 E 993, 2909. 42,18 N 38,06 E 903. 3819. 454.28 N 67,56 E 804, 4720, 884.44 N 118.19 E 662. 5578, 1390.41 N 194.81 E 496, 6412, 1938.06 N 257,63 E 368, 7284, 2426.73 N 290.06 E 283, 8199, 2821o84 N 354.53 E 218, 9134, 3157,78 N 470,48 E 5287 FEB. 82 , HORIZONTAL.. VIEW 'ARCO ALASKA INC ......... RADIUS OF CURVATURE GYROSCOPIC .............. FEBRUARY .... - '---ot..,ieu~ ............................................................. ""'i ........................................................... 9~00 ...... ': ................. ~- ' ............. : ................ : ........ ' ...... '"-":' ~ ........ :"-: ............. ::-i .............................. :,._:_:..: .................... :..: ........ : ......:_ _..: ' - ................................... ~ ............. ? ............. ........................................................... , ........... I~" ''~ '~' ...... : ! '-"" - ' · ~. ..... ~" ......... '7' .... :' ................ ; .................... ; ............. ~ .................................................. i ................... 6000 ;~ .................................... -~ ..............................: ............................... '~-"'" .......................................... ' .......... ,, ...... 7: .......... ~ ........................ .: ................. .................... ~ ........... :'-T''-- ~-- ......: ...............~- ........... ': .............. "; ..................................... 5600 ~ ................................ ; ......... : ................... ~ ' : ........... i ............................. _ ._..--: ...... : .............. : .......... 40 ........................ : .......... ~ .... ! ..... : ................. : ....... : ..... :"'~ ................. -T ....... ~ ....... ":' ,soo..: ............. , .......................... ~ ..... ~ ..... i ....................' · $~oo-. ...................................................................... "' ........................... ............... -:- . , ................................... :_ ,.- ........... ; ............................ ............. i ...... -" .......... ALL 'D EP3'H$_S HOWN::..: .... . : . i ....... ARE VD ._~ - ...... ~ .................. .......... : .............................. ~...-- .................. : ................................ ~ . ~ .......... : .......... ..... . :~ ~. ... ....... :.: ................... , · ....... ~ ....... _ . . . i . : .... '. ............................. : ....... ....... ...................................................... 14' -1:5 ............ T ION ~ Ri4E~ U.M. ,-~ SURFACE LOCATION IS '\ 2758' NSL ~ 156' WEL SEC. 14 ~ ¥ION ~ RI4E ~U.M, - 400 VERTICAL SECTION --8oo _ .. ARCO ALASKA INC.- . , - ................................... . ................... ............................................................................................................. WELL.... DS ~.... !.$..~.! 9 " RADIUS OF CURVATURE --~2oo .; . ' 'i ..... ~ .... GYROSCOPIC SURVEY · , ................................ 2000 ' : . ~ ...... ; -; ..... :~ -2400 ........ ~ .................... ~800 , - ..... ~600 ~ ...... - ~ - _ ~ ........................... . · ~ - ~. ......... : ......... ~ ........... :-- ~-'-T ''~ ..... ~ ........................ .......... . . .... 4400 ~*- - -' ALL. DEPTHS SHOWN .... 7- ..................... -. , _ ~ ...... . ...... ARE TVD ..... 4800 .... ............... ~ 5ZOO 5600 ' : ~ -' - .[64oo _ 800 ~ 7200 7600 - . : . --8000 ................................................ -: ............................ . 8400 8800 9200 TVD ~= 9448' TMD = 10~246' Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Name 'and Number Reports and Materials to be received by: Date Required Date Received Remarks o Completion Report Yes · Well: History'~ - ' Yes. .' ' Core ~scription ' ~ ~ " I Inclination Su~ey , Dire~ional su~eY ~e3 - Drill St~ Test Re~s ~ff~ ~ . Pr~u~ion T~t Re~rts /~~ ~ _ - , ~ .~ ...... ~S R~ ~:-' ....... ' L% Yes STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDIX ARCO Alaska, Inc. Post Office ~%~360 Anchorage,, lka 99510 Telephone 907 277 5637 -) February 11, 1982 Reference: ARCO CASED HOLE FINALS -' ~):s. 1-1o 8/18/80 Epi.log/DDNLL/Five Pass. & Sigma Average 5" Collar Log For Gyro Correaltion 2"/5" 1/25/82 CNL/GR Run 1 2"/5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #958 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ... .. .:.,.: ..... . ~... ~,. .... , ~ ,. . c' .."'~'~" ~-.RCO Alaska. INC.. IS. a s,~b,~d,ar¥ OI Atla-!lc~cht:,:idCompany ARCO Alaska, Inc. Post O/rice Anchorage. ~ka 99510 Telephone 907 277 5637 February 10, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.14-12 2/4/82 Gyroscopic Job No. 5268 2/4/82 Gyroscopic Job' No. 5287 D.S.15-15 2/4/82 Gyroscopic Job No. 5286 ,D.S.12-4A 1/25/82 Gyroscopic Job No. AO182G0240 D.So14-26 2/4/82 Gyroscopic Job No. 4757 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal#955 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY SOHIO GEOLOGY ~THON STATE OF CHEVRON ARCO Alasaa. InC. is a suo~,dJa~y o! All,3nl,c~ltchlle~dCo~i~pany ARCO'Alaska, Inc. Post Office Anchorage, ka 99510 Telephone 907 277 5637 February 4, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA 1/13/82 Single-Shot Directional Survey Job No. A1281DO147 D.S.12-8B 12/19/81 Gyroscopic Job No. Boss-16945 Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering TransmittAl # 940 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO~ GEOLOGY MARATHON STATE OF ALASKA CHEVRON Alaska 0il & Ga~ Cons. Commissiom ARCO Alaska, inc. is a sui~3,d~ry ot AtlanilcRichfie!dCompany ARCO Alaska, Inc. .... Post Office ~ 360 Anchorage. Alaska 99510 Telephone 907 277 5637 February 2, 1982 Reference: ARCO OPEN HOLE FINALS D.S.15-14 12/17/81 FDC D.S.15-14 12/17/81 FDC/CNL D.S.15-14 12/17/81 BHCS D.S.15-14 12/17/81 DIL/SFL D.S.15-14 12/17/81 Cyberlook Run 1 5" Run 1 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 5" 1/14/82 HDT(Arrow Plot From Cluster Listing) With Listing Run 2 2"/5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal f~ 927 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. Inc. is a suC, s~d~ary of Allant~cRichfie!dCo At,3s~ 0it & Gas Cons. C0mmissi0n ~chorago ARCO Alaska, inc. Post Office 9oz760 Anchorage. ~ ~a 99510 Telephone ~0'~ 277 5637 February 1, 1982 Reference: ARCO CASED HOLE FINALS D. S. 14-26 12/31/81 CNL Run 1 ~ D.S.14-12~'~ 12/5/'81 CNL Run 1 2"/5" 2"/5" D.S.13-3 J 1/2/82 Gamma Ray Run 1 5" moSo 15-10 o,,--' 1.2/3/8i 14_26~,.f"',['1/4/82 Collar Log Run 1 5" ACBL/VDL/GR Run 1 5" D. S. 14-14 u'z 10/29/81 CNL/GR Run 2 2"/5" ACBL/VDL/GR Run 1 5" -- D.S.14-13,~ 11/23/'81 CNL Run 1 2" D.S. 14 11/23/81_ CNL Run 1 5" ~-----D~Sol3-10 12/5/81 Temp Log Run i 2"/5" / DoSo14-13v/ 11/23/81 CCL With Gyro Run 1 2"/5" D.S.14-12~ 12/7/81 CBL/VD Run 1 5" D.S.15-13~/11/28/81 CBL/VD Ru~ 1'/ ~5" *NOTE::D.S.14-13 2" CNL is dated incorrectly and the date should be 11/23/81 instead of 11/2/81. /~ sign and. return the attached copy as receipt of data. Mary Fo Kellis North Engineering Transmittal # 924 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS. SOHIO~ EXXON MOBIL GETTY D&M GEOLOGY MARATHON STATE OF ALASKA CHEVRON FEB 0 5 198,: ARCO Ala$1~a. inc. is a ~ubs,,J,ar.y o! All3nt~CR~chf,etdCompany A~sk~, 0ii & Ga~ Cons. C0mmissio.~ An. chorz§~ ARCO Alaska, Inc. Post Office ~o.~. 360 Anchorage. / Xa 99.510 Telephone 907 277 563'7 January 28, 1982 Reference: ,:ARCO MAGNETIC TAPES & LISTINGS D.S. 13-10 12/20/81 Tape #62406 Tape #62501 sign and return the attached copy as receipt of data° Mary F. Kellis North Engineering Transmittal # 916 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO' MARATHON CHEVRON ARCO Alaska. lnG. Is a Sug:,~d~ary o! A;tanllc~lichfie~dCompany EXXON MOBIL GETTY D&M GEOLOGY .STATE OF ALASKA CE! AJaska Oil & r~s Cot)s. C°mmis$ioa ARCO Alaska', Inc. Post Office B )60 Anchorage, Alaska 99510 Telephone 907 277 5637 January. 25, 1982 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Dear. Sir: DS 11-5 DS 14-12 DS 11-6 DS 14-26 DS 12-7A DS 15-14 DS 12-8B DS 15-15 DS 13-10 DS lA-12 DS 13-19 DS B-11GI DS B-8 Enclosed please find the Well Completion Reports for the following drill sites: 11-5, 12-7A, 12-8B, 13-10, 14-12, 15-14, as well as an up-dated Completion Report for DS B-8. Also included are the Monthly Drilling Reports for drill sites- 11-6, 13-19, 14-26, 15-15, lA-12 and B-11GI. Sincerely, P. A. VanDusen District Drilling Engineer ~rlclosuTes PAV/GA: ss ARCO Alaska, Inc. is a Subsidiary of Atlant cR chfie dCompany - STATE OF ALASKA ALASKA C )AND GAS CONSERVATION COi~, ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-180 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20690 4. Location of Well at surface 2758 ' FSL 156' FEL Sec 14, T10N, R14F., UM 5. Elevation in feet (indicate KB, DF, etc.) REB $4' 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 13-19 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool For the Month of D~celilber ,19 '81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1200 hrs, 12/18/81 12~" hole to 7749. Ran, cemented and tested 13-3/8" csg. Drilled See Attached Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 20", 914# H-40 Conductor to 80'. Cmtd w/400sx ?erma£rost II 13-3/8" 72# L-80 casing to 2474'. Cmtd w/2500sx Fondu and 400sx Permafrost "C". 14. Coring resume and brief description N/A 15. Logs run and depth where run None To Date. 1 6. DST data, perforating data, shows of H2S, miscellaneous data m/^ S,SNED ~~'/ T,TLE Senior Drilling EngineerDaTE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 DS 13-19 Drilling History NU 20" diverter. Spudded well @ 1700 hrs, 12/18/81. Drld 17-1/2" hole to 2490'. Ran 61 jts 13-3/8" 72#/ft L-80 BTC csg w/shoe @ 2474'. Cmtd 13-3/8" csg w/2500sx Fondu and 400sx Permafrost "C". No cement returns to surface. Ran 1" top job to 224' RKB in 13-3/8"x20" annulus - Pumped total of 520sx Permafrost "C". ND 20" diverter. Instld 13-3/8" packoff and tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 Drld FS & 10' new form. Tstd'to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 6572'. Fished backed off drill pipe. Drilled to 6792'. Fished twisted off drill pipe. Drld to 7749, as of 12/13/81. o . .o BLOWOUT PREVE. N-f'b_I( 1 k_b I . RES ENG T~$T' ii il ,i i I i I ii I i i ii iii L I I . I I ,, ....... ,1 1, I i i i I I i ill i · iiiii i i ii _ ii i i i i iiii i i · ii i i i1 i ii i i i i . _ i ii · Al,~.~l(a gii & Gas Cons. Commission " Andn6raoO ...... i "17FtFIV'Fn ' i i i i ii i ~ iii i · i,,, ii] i i ii iiii i! i i I i i I I~PCo _,, ]qa] , ,. i i iiiI i ii ....... i ii i i I December 9, 1981 ~ir. C. E, Ross Senior D~i I I lng Engineer ARC~O Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 13-19 ARCO Alaska, Inc. Permit No. 81-180 Sur. Loc.: 2758'FSL. 156'FEL, Sec 14, T10N, RliE, Bottormhole Loc.: 675'FSL, 100'F~, Sec 12, TION, R14E, Dear ~r. Ross: Enclosed is the approved application for permit to drill the above referenced ~el l. ]Yell samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25,050(b)(5), If available, a tape containing the digitized log information shall be submitted on ali logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~lany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~nmencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to ~. C. B. Ross ?rudhoe Bay Unit DS I~-19 -2- December 9, 1981 e~neing operations you may be contacted by a ~epresentative of the Department of l~nvtro~ntal C~nse~vation. To aid us in scheduling field work, we would appreciate your notifying this office within ~45 hours after the well is spudded. ~e would al so like to be notified so that a repre- sentative of the Conanis.sion may be present to wetness test int~ of blowout preventer equipment before surface easing shoe. is dri I led. In the event of suspension or-abandonment, please give this office adequate advance notification so that we may have a witness present. Very t rul y your s, ltoy II. Hamilton ~ai r~an of ,~Y "~"~:~ Alaska Oil · Gas ~nse~ation ~ission ~nclosure ecs Department of Fish & Game, Habitat Section w/o oriel. Department of Bnvironmental Conservation w/o/enol. HHH:be ARCO Alaska, Inc. Post Office L 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 4, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3.001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 13-19 Permit to Drill Dear Sir: Enclosed please find our application for Permit to Drill DS 13-19 and the required $100 filing'fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedUre, including anticipated pressures. Due to a recent change in our drilling schedule, we anticipate spudding this well on or around December 15, 1981. Your prompt review of this application would be greatly appreciated. Very truly yours, C. E. Ross Sr. Dril 1 ing Engineer CER:JBK:ltc Enclosures RECEIVEi) DEC~. 7 1~,~, Alaska 0tl & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] S~:RVICE~]F r~I~I~(I~APHIC []' REDRILL [] DEVELOPMENT OIL ~] SINGLEZOI~E'&J'" .... ' . DEEPEN [] DEVELOPMENT GAS [] MULT,PLE ZONE [] 2. Name of operator DEC 0 ARCO Alaska, Inc. 3. Address A~$k~ 0ii & Gad C0ii$. Commission · P.O. Box 360, Anchorage, AK 99510 Anchorage ___ 4. Location of well at surface 9. ·Unit or lease name . 2758'FSL, 156'FEL, Sec 14,....T10N, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 400'FSL, 80'FWL, Sec 12, TION, R14E, UM DS 13-19 At total depth 11. Field and pool 675'FSL, 100'FWL, Sec 12, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe 0i 1 Pool 84' KBI ADL 28311 12. Bond information (see ~0 AAC 25.025) TypeStatewide Suretyand/°rnumberFed Ins Co.. #8080-26-27 Amount $'500~000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance ~o neare%t,,d~;illi.ng or~c,.omEl~te~ 1½ NW of Deadhorse, AK miles South Line ADL 28311 400feet wbe~r~ace-~' 1~o k}~ J~=f~et - TD-I~ f.n DS 6-9 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10,185'MD 9432' TVD feet 2560 12/15/81 s, 19. If deviated (see 20 AAC 25.050) J20. Anticipated pressures 3945 P 'g Surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 28°J (see 20 AAC 25.035 (c) (2) 4603 psig@_9_4.32_ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30 20 94 H-40 PEB R-3 0 I 0 110 ! 110 2505x PFII to surf. 2500 17½ 13-3/8 72 L-80 Butt R-3 0 ~ 0 2500~1 23005x Fondu + '400Pr I 12~ 9-5/8 47 L-80& Butt R-3 0 ,~ 0 937018706 500sx G - 1st sta.qe 9-5/8 47 S00-95 Butt R-3 ~ i 300sx PF "C" 2nd sta9, 8½ 7 29 L-80 Butt R-3 9070 ~, 8440 10,185~ 9432 750sx Class "G" Cmt 22. Describe proposed program: ARCO Alaska, Inc. proposes to dire~:tionally drill this well to 10,185'MD (9432'TVD) to pro. duce the Sadlerochit zone. Logs will be' run across selected intervals. A 13-5/8" 5000 ps RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be press ure tested each week thereafter. A string of 5½" 17# L-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be.left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. The downhole safety valve will be tested and installed upon conClusion of jo NOTE' Permafrost base at DS 13 is 1850'TVD. · Bottom hole pressure based on virgin reservoir pressure. Surface pressure calculated wit unexpanded gas bubble at surface including temperature effects. · · 23. I hereby certify that the foregoing is true and correct to the best of my knowledges.. The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number []YES J~-NO []YES J~O [~YES I-lNg 50- Permit number Approval date S'/-/~° 12/09/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY. ,COMMISSIONER DATE Deeenbe]~ 9, 1981 . ..... by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 SURFACE HOLE DTVERTER SYSTEM ARCO ALASKA INC'. SCHEMATIC IO" HYD. (>PR. BALL VALVE WELL BORE (SEE DETAIL) J ~"...~--- IO" HYD. OPR. BALL VAL,V,E //',," I ALL 90° TURNS ARE "TEE ,- I~LL (~BORE I I I RESERVE PIT AREA FLOWL INE F DR ILL ING RISER 20" 2000 PSI WP ANNULAR PREVENTOR ,/ ! I J ~10" HYDRAULIC ~~ ~ OPERATED BALL VALVES D IVERTER L 20" CONDUCTOR PIPE "DETAIL" 2026O10203 q~3- RNNULAR PREVENTER BLIND"RRMS PIPE RRHS SPOOL PIPE RRMS Maximum Anticipated Bottom Hole Pressure, psi. - Maximum Pressure to which BOP's could be subjected. Calculated by allowing a gas bubble at reservoir pressure to rise w/o expanding but cooling to 80VF, psi. . 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and t200 psi remaining, pressure.) 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non- freezing liquid. 2. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. 3. Close annular preventer and chokes and ~ypass valves on manifold. 4. In_each of the following tests, first hold a · 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 5. Increase pressure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe "rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 7. ClOse valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. 19. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe ramq. ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of De Gasser. 16. Record test information on Blowout preventer test form. Sign and send to Drilling Super. 17. Perform complete BOPE test once a week and functional operate BOPE daily. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (~ thru 8) (3) Admin 9~ ( th~ 1 (4) Cas~~'~ /~-~ / ~12 thru 20) (5) BOPE ~ /~f-f ! ~21 thru 24) YES NO I th p it f h d 6z!~ s e e rm eM attac e ...... ....................... ..... ....... / 2. Is well to be located in a defined pool ............... 3. Is well located proper distance from property i~n;' i i1.!· 4. Is well located proper distance from other wells .... 5. Is sufficient undedicated acreage available in this o . 6. Is well to be deviated and is well bore plat included ........ 7. Is operator the only affected party .......................... 8. Can permit be approved before ten-day wait ................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Does operator have a bond in force ........................... Is a conservation order needed ............................... Is administrative approval needed ............................ Is conductor string provided ...................................... Is enough cement used to circulate on conductOr and surface .''''.. Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .................. Will surface casing protect fresh.water zones ................ ' Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation proposed .......................... · e e e · · · · . __ Is a diverter system required ....................................... ~ ~.,~- Are necessary diagrams of diverter and BOP equipment attached ...... ~ Does BOPE have sufficient pressure rating - Test to ~aP~P psig .~ Does the choke manifold comply w/API RP-53- (Feb. 78) .................. REMARKS (6) Add~ /~?~2~ / 25. Additional requirements ............................................. __~ Additional Remarks: Geology: Engin~j~ring: HWK ~ L'CS f~ BEW ~-- WV~, JKT ~/RAD rev: 03/10/81 INITIAL t GEO. UNIT 'ON/OFF POOL , CLASS STATUSt AREA NO. SHORE · · Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well. Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of thiS nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. .o i~I~[~.~G OF PROD[JCTiV'iTY /.DAY FIELD ARCO Q.S, 13-19 P~ODH~E BAY 10707,A62533 RECEIVEO AUG 1 1 1982 Rlaska Oil & Gas Cons. Commission Anchorage PAGE T~~,,[~ C~..,. PER DAY * : i .O000OO · . ~. ~.% ~ . · 97~0.00 - 9710.0 PAGE FACE DO ~ ~ SOL FREE PRES PRE;S O~ ~ CAS ~ATER OIL ~AS GAS 3W15. O 10,0 '197 '144 -77 2 ~'OTAL '144 '76 3825.0 I00.0 ~uS. 0 Zu. u 72 -53 28 3 ~O~AL -53 -25 3~95,0 30.0 52 38 20 5 ~OTA5 3~ 25 3SSS.0 ~O.O 176 ~29 69 7 ~OTA5 ~29 76 3~75.~ 50.0 300 i 219 11~ TOTA~ 219 126 3~65.0 60'0 i2¢ I ]09 i65 I0 ~u~5 ~09 ~76 3'''''~' ~ 70 .~5~.0 .0 5~'7 1 39~ 214 -~,~'~n 399 ~ .... 22b 3~45.0 SO.O 679 I t89 263 13 ~JO~Ab 489 275 3~3).0 90.0 7~3 1 579 311 15 9]5 1 668 359 WATER BB/D GAS WATER ' OIL ~F3D ~B/O BB/D ,S fJ R KF3D A C E FREE GAS WATER KF3D ~B/D TOTAL 66~ 375 31ZO.0 2U~,,. 0 2124 2 1551 832 32 TOT~L I551 854 Jo25.0 ~o0.~ 3300 3 2~ 1295 47 ~OTAL 2413 1343 3525.0 400.0 4459 4 3255 1747 62 TOTAL 3255 1809 3,~25.0 5~0.0 558~ 5 4076 2188 77 'OZAh 4076 2265 3J25.o 600, {.~ 6682 '6 4:877 261~ TOTgL 4'877 2709 '~225.0 700.0 7751 7 5658 3037 i04 'i~OT~~ 5u58 3142 TOTg L 6q I ~ ~925.O lOO0.O ~0792 I lO 7877 q229 'xO?i ~,~ 7:877 3563 130 3973 143 4372 10 10 PAGE FAC£ !925ou DRA~ PRFS 20UO.O SOL 0,[~ GAS WATER (')IL .'SAS B£~/O KF3D ~BID B~/D- ~{F3D [91] t i 21 13949 74~9 ~3949 A C E FREE GAS WATER KF3D BBtD 925.o 3000.0 24534 ! 3'1 17981 9653 TOTAL 17981 0 3925.0 27254 I ~0 . 19893 10680 TOTAL 1989~ 244 7733 303 9956 321 11001 20 2O 30 30 39 39 RUN NO, TWO dOS NO. CLU~T~ NE~UbT~ O~bY 4155 FT. X2 SEARCIi ANGLE FT. ~:~P ,© * D~P~H * DiP DIP * D~Vo D~V, DIA~ DIAN ** 9472.0 7.b 34,9 0.7 21.~ 2?4 21.3 35 21,2 I19 21.0 9480,0 94 4.0 .*.: 9490'0 * 9496.0 $.~ 270 * 9 .0 * 9508,0 24 8,0 8 8.2 9,5 O * 7 8,1 9,6 9 8.5 10,1 2~0 20.9 20.9 20.8 20.~ 8 8 8,4 9.7 C ~0 11 8.4 9,7 E 11 8.4 9,7 E * 95 ,.0. 2.7 .0 5,2 , 9520,0 i5.3 *'.'952i~:*0 · 9524.0 261 20. 10 :20,17.: i.: .,!.o 20.7 10 290 28i : 952.6' 0 · <:: ::~: :., :: * 952B.0 8.3 2.39 b.8 242 * 95~6°0 12.9 20{ * 9538'0 I0,7 227 , 9540.0 10.1 168 * 954{,0 * 9544,0 * 9546,0 4.9 199 * 9548,0 6,~ 180 , 9550,0 5.4 208 20.7 12 20.b 12 20,b 13 20.5 20,5 13 20*5 20,5 12 20,5 12 20,5 20,5 12 20,5 11 20,4 11 B,-3 9,4 B.3 9.4 B.3 9,3 8',3 9.3 8,3 9.2 O.3 9"1 B,.4 9.1 8.4 8.3 9 8,4 9-i B.4 9.0 B,4 9,0 B,4 9.0 B.4 9.0 8.4 9.0 8,4 B.9 * DEP?H * D I P O I P :* D E: V, D F~ V, D ! A ~ 9572,0 9576,0 * ,0 8,0 2 t 5 20,4 I 8,2 8 · 4 B 951B,O' 4,7 26b 20,4 12 8,2 B,4 A * 150 20.4 0.5 2,94 20,4 12 20,'4 13 · :~0:.'4: 8-:,3 * 9620,0 9,5 248 20,5 12 , 2, t o.5 * 9624,0 5,b 137 20.5 * 9626,0 6.7 2ii 20,5 * 9628,0 li,O IBb 20,5 * 9630,0 20'5 ******************************************* e"] : _ C 8,3 ~,4 C B.2 8.4 A , 8,2 8.4 C * 8,2 a-4 * PAG~ 9644 9 9 ,0 9688.0 9696,o 96.98,0 9700.0 ~702,0 ¢704,0 9706.0 9708.0 9710.0 5,1 20.8 10 8,3 iO 145 20,'8 10 B.3 20,9 ~I,0 324 ~1,0 2:~:6 2:1.0 2i9 21.0 205 21.1 202 2t.1 206 2i.1 257 21.1 245 21,1 236 21,-1 5.3 12,8 11.4 7,8 7,5 10 8.2 10 8.3 11 ii 8*4 11 12 11 10 8,4 * 9 .0 6.9 2~8 21.1 ~:.~::. 9~:i4,0: :3.::*:.~ ~: 2.20:: ~ : * 9720,0 9,5 2~7 21.i * 9728,0 2,0 201 ,':':: * r * . 10 8.3 8.4 D * 2 8.3 8.4 * 8,~ 8.3 D * 8.3 8.4 B 10 8.3 a,4 C * .7 197 21,3 5,0 4.1 21.3 I1 8.3 8'3 * 213 21.4 11 8.3 8,4 A * 173 21,4 1! 8.3 8,4 C , 174 2i.4 10 2 10 21.4 7-4 272 2i,4 7,0 125 21,4 10 2,9 2~9 2i,5 3.0 246 21,4 1.7 266 21,4 ii · 9772.0 , · 978¢~0 · 9786.0 · 9788.0 , 0 0 * FORMATION · BOR~HOb~ · OUA~, * 9796.0 ~.0 I~3 21.5 10 8.3 * 9820,0 * .0 * 9852,0 · , * 9860,0 , 9862-0 * 9864.0 , 9'868.o , e,.7 21t5 21 21.6 10 21,b 9 8.2 8,4 * ~.4 187 21.b 10 8.1 214 21,7 10 8'7 97 21,8 9 8.2 6.4 C * o.v ~o9. ~.2 178 ~1.8 lo a.~ e.s ~ , ~..3 8J 21,8 10 8,2 a-5 A , {, 2 160 21 2.8 28b 21.9 9 8.2 6.{ B * 9.8 355 21,9 9 ....... ~ , ~ORMATi'oN . 21.9 * 6°0 21.9 8 8,3 8.3 * 0.0 1.0 153 22.0 6 8.2 8,3 , 9e 4.0 8.9 357 22.0 ~! 8..! 8..~ 8.2 8,3 D 22.t 1,3 8 D * .0 22.-! 13 ~.2 8,3 * * 9896.0 7.9 }0.0 * 9908.0 7.9 * 9' .t.16 22.1 13 8.2 ~.3 B * 22..1 4 8,,~ 8.3 8.2 8,3 :::.::::. :::: :.:..t:~:: ::: .:,~.;ii~: '::'. 237 22,2 15 8.~ 8.3 O 5.5 1~4 22,2 16 8,2 8.3 ~ * . .0 ..b 173 22.2 15 8.2 8.~ 242~ 323 335 292 274 139 180 4.3 16.0 · 99~2. o 7.~ · 9944.0 · 9946,0 3.9 , 9048.0 · 9950'0 3.5 289 22.1 ~3 8.t 8.~ g * _ 22.0 13 8.4 8.5 h 22,:0 15 8.6 ~.e A 22.0 15 8.3 8.3 tS ,-3 22.0 16 8.3 8.3 22.0 18 8.4 8'3 22.0 2t 8.4 8.3 a · 22.0 23 8.4 8*4 ~ * 22.0 23 8.5 8.4 21.9 23 8.6 8,6 E * © '------------------,----------------------------------, INDEX * DEPTH * DiP DIP * O~V. DEV. UlA~ D~A~ * B~ST * , 9952.0 3.0 308 21.9 21 ~.7 , 9954.0 6.3 51 21.9 20 8.6 * 9956,0 7,9 1~8 21.9 19 8°6 * 995~.0 2.8 55 , 9v~2-o ~.o 205 ~t,~ 20 ~.:? * 9964.0 2.9 279 2~.7 19 8,7 ~:,,¥:..996,6.0 7.4 * 9968.0 ~.3 272 21.7 9972.0 3.9 246 21.7 18 8°5 8,6 C 18 8.4 ~,b A 9.4 .8 83 21,b 6 ~,4 B.2 ~ .0 .0 4,~ 6,,9 15~ 21.5 AT,AN?lC RZ~HFZEbD CO.- Dg~~£ 13-19 PAG~ ~-FI~B ,----------------'--,----------------------------------, · t0032o0 9,,0 195 21.5 14 277 ~1.5 ~8 162 20 2~ 21.5 23 27~ 2~,.4 25 8.7: 8*7 D 8,7 7 '5 8,2 C * ;¸2 8,2 A 6,2 A * 9'7 i 9 !.1 F * A?bANTIC RICftFI£bD CO, D~IbI.,$IZ~ 13-19 PAG~ 1-FIL~; I * * FORMATION * IBURi~H'OI.,E · OUAb, m , ,-------------.-.---,--------------------.--------------, x i:v X , DF.V° DIA~4 DIAH AZZ, 1-3 2-4 9474.0 21.4 25 8.! 9.4 9476,0 0.5 309 21-3 25 O,O 9-4 9478.0 3.3 314 21.3 24 8.0 94{.0.0 6-6 ~22 2i,2 24 8.! 9-6 9482.0 2.-4 40 21.1 25 8,4 9,9 4{ · 21,1 25 g486,0 2,1 360 21,0 25 8,4 10,! 9494 * 9 o0 A · ¢ 2 260 340 20,8 9¸: 20.,6 ; g,2 g,2 A * 0,5 2! ~'3 9,t E * 9,1 2i ~ 20,5 25 8,3 9,0 E * * , 95i 2,,0 7~ 223 2:0,6 25 8,4 9,0 ~ * 180 20,5 25 8,4 9,0 ~ * 210 20,.4 26 8,4 8,9 ¢ 126 20,,~ 25 8,4. 8,9 A * DEPTH * 9554.0 ~.3 251 ~0.3 25 ~.4 ~.~ . * 9558.0 1.7 180 20.3 26 8.4 ~.~ * 956'0.0 3.2 146 20,4. * 9562.0 3.7 i60 20.~ 27 8.2 ~.5 ~ 9564'0 203, 20,5 27 * 9566.0 b,2 227 20,5 27 8, 6.3 20.5 27 8.~ 8.3 * 20,5 25 325 20.5 25 9582.0 9590.0 2,~ 265 20.5 26 .5 49 ~0.5 26 8,2 ~.'4 D , .0 5.6 201 * 9602..0 20.5 25 , 9606.0 10.9 306 20.a 25 * 9'610.0 5.9 14~1 20.$ 25 8.4 ~ ~.2 ~.~ 8.2 8.4 ~ 96.30.0 20.5 25 8.2 D · 9634.0 33.2 322 20.6 24 · 9636,0 20,b 24 ~.2 · 96~8,0 20,b 25 ~,~ · 95~0.0 20.8 223 20.6 25 8,2 · 9642.0 19,b 222 20.6 24 19'0 223 20.7 24 8,2 17,0 218 20.7 24 96,~8,,0 ~:.~ 2~ 20,,7 25 8,4 t5':7 24 · ~e~4;o ~,~ ~ ~0"? ~ ~.~ ~.4 ~ * 24!9 * 9 . ,6 4,4 , 91 4,1 i0,2 24 ~,2 :25 B,2 8.4 220 2 2.15 2~0 AT~A~TZC RICHFIEhD CO, D~I~[~I~ 13-i9 PAG~ 4-FI~ ! * ~ FO~ATION · BU~EHO~ · OUAbo * e '----------'-------',---------------------------'------'-" ~NDEX · ~ D~P H * D1P DIP ~ DEV ~EV, DIA~ DIA~ * ~8~ · * 9714.0 3.7 229 21.1 23 ~o3 ~.3 F * * 97i8,0 21.2 22 ~.2 U.3 * -* 9:720:.0 21.2 22 , 9722.0 5oa 239 21.2 23 ~.2 ~.3 ~ * , ~726.o ~.~ 2~o ~.~ 2~ ~.~ ~.~ r · :" ": 9:'/28.0 ~6.~ 234 * 97~0.0 6.t 22'9 * 9 * 9 5.7 1,5 2~9 21.2 22 8,~ 8,~t D .2 20 ~ 99 2,9 6,0 0 ATbANTIC RICHFIEbD CO, D~IbLBI~E 13-19 PAGE 5-FILE I 9794.0 9796,0 ~.3 2i.¢ 23 9798,0 6,3 21o6 24 980.0.0 9.7 21,4 24 9802°0 7.7 21.4 25 9804,0 7,i 21.4 24 9806,0 3.0 21.4 23 9'808.0 4.2 21-& 22 9810.0 5.7 ~1.5 22 9814.o 11.7 21.5 23 * 8,0 · 98 .,0 .0 .0 13.5 249 227 8.2 8,2 220 8.~ ".2 231 8.2 8.2 222 213 8.~ 8,2 178 8.2 '~.2 229 i28 8.2 8,2 231 21,5 22 .... 21,5 21 21.5 22 4,1 305 21.5 2~ 21,6 2.4 51 * 9862,0 1.2 236 , 9866,0 2.3 34 * 9870,0 8.2 * * FORHA?ZON , ROREHULE * '-------------.---.--,----------------------'--------"--, * DEPTH * DiP DiP * DRV. bEV. DIAH DLAM * * AZZ.. · AZI, I-3 2'4 * 9874.0 18.2 104 21o8 20 8.2 8.2 F 9976,0 2t,9 18 8~2 8,2 987~.0 21.9 15 8o~ 8.2 98~6o0 I~.8 ~92 8.2 ~,2 'i:79 22,9 16 21,9 21,9 15 · 9898.0 2i.9 15 9902,0 .0 9 0,0 22.0 15 9.4 323 22,0 13 6,6 15 22.0 0,8 200 22.0 - 8,2 ,0 9,2 12g 2~,9 359 8.4 249 21.9 9 i6,,0 ~0 ,, 0 3.0 199 2It.9 21.9 2i.8 ... 10 8,2 13 8.3 © 0 ~ * FOE~A?ION * BUREHUbE · OUA~. ~ · '-'-'-------'-'-'-''---'--------------------'-------'-' ZNDEX * · DBP?~ * OZP DZP * DgV. DEV, D~AM DIAM * B~$~ * , 99~8.0 2.2 336 ~.7 ~.~ * 9960.0 2$,7 * 9962,0 2.3 246 21.7 , 9966.0 ~1-9 272 7.0 275 21,7 0,0 9,7 $o0 1,7 30 21.6 15 16 20 22 21 8,8 22 8.6 22 8.5 : C.~ 22 8.4 22 8.4 9982,,0 5.1 .0 7.4 180 252 21.6 * :0.0 224 * i0022.0 9.2 2!1 * I O: 6, '7 126 ,0 ,:8 I I # DEPTH * D! · 10034.0 4,6 · 10036.0 3.2 · 10038.0 b,6 · i0040,0 2.2 · 10042,0 * I0046,0 3,2 191 21.5 316 21,5 277 21,5 227 21,4 270 21'4 2$& *:100.48:,0 4,.b 26~ 21,3 11 8,5 !8,6 A * 10050.0 5.5 242 21,3 13 8,5 e:~S :~. 10054.0 2,2 180 21.2 13 B.4 , 94?2,0 33,4 150o 21.4 24,, , * BOTTO~i * ~ ' 8 ' 2 ! 2, , * 9474,0 17.7 152. 21.4 25. * BOTTOH IRPERF= ,12500 IN2 ORVS]Z~ L~O.O00 PORIND= ~' ° "· · · · · · o · · - · - * · o · o o o o * - . · ,,. · · · o · . · · . o · · . o o . . . o . . · · o · · o . · .~ · o . · . · ,~ · o . · o · o o · .L' o . · . 0 ~ P£RF DEN$~ 2 FT-! · PERF DENS= ~ FT-I X PERF DENS= 8 FT-! ~ PERF DENS= 12 FT-! ~ PERF DENS= 16 FT-! 0 PERF DENS= 2~ FT-! ............................... ~ PERF DENS= PER IPR 600.00 $ TI PWH= 700.00 · DP PNH= 700.00 ' · TI PNH= 800.00 [] DP PWH= 800.00 [] TI PWH= 900.00 .............. ~ DP PWH= 900.00 ' '[] TI PWH= 1000.0 · ,~ DP PNH= lO00.O PSI PSI PSI PSI PSI PSI PSI PSI PSI PSI · ~ ')~'~ I ' I · O0 20. O0 ~0. O0 80. O0 80. O0 100. O0 120. O0 LIQUID FL ON BRTE -xlO 1~10. O0 180.00 BB/D 2-APB-82 07:05:38 RTLRNTIC RICHFIELO C PRUDHOE BR¥ lOI: ~.9500 IN CDI= 6.1000 tN o RPEBF= .12500 IN2 GRVSIZ= ttO.O00 · ,. · 13-19 SCROE-999.25 IN PGRIND= 7 CiD ~D CD .00 5.00 10.00 15.00 20.00 25.00 I^IIQT~R ~-I PII^I RI21T~ ~0.00 35.00 ~ PERF 'DENS- 2 FT-1 ~ PERF DENS: q FT-1 X PERF DENS: 8 FT-1 ~ PERF DENS= 12 FT-1 X PEBF DENS= 1G FT-1 O PERF DENS= 2~ FT-1 ~ PERF DENS= 32 FT-1 ~ PERF DENS= S8 FT-I X PERF DENS= ~0 FT-I + PERF DENS: ~8 FT-! · IPR CURVE ~0.00 RTLRNTI'C RICHFIELD C RRUOHOE BRY 13-19 TI)I= Lt.9500 IN COl= 6.1000 IN SCRDE-999.25 o RPERF= .12500 IN2 GRVSIZ= L~O.O00 PGRIND= ~'~J-,~ o · o o o · · , o · · · # · · · · o o . o o o o o . , o . · . . . o o · . . · o rT-c~ COo LLJO rT- ' [] PERF DENS- 2 FT-1 · PERF DENS= ~ FT-! X PERF DENS: 8 FT-I ~ PERF DENS= 12 FT-I ~ PEBF DENS: 16 FT-I O PERF DENS= 2N FT-1 .......... ~ PERF DENS= 32 FT-! ~ PERF DENS= 36 FT-I X PERF DENS: ~0 FT-! · PERF DENS= ~8 FT-! · ~PR CURVE 0 oo I 5. O0 10. O0 15. O0 20. O0 25. O0 30. O0 NF:tTFR FI FIN RIq'FF I 35.00 I L~O. O0 RTLRNTIE RICHFIELO C PRUDHOE DRY 13-19 TUI= Ll.~500 JN COI= 6.1000 IN ~CBOE-999.25 IN 0 RPERF= .12500 IN2 GRVSIZ: L~O.O00 PGRINO: 7 CD cD c~. O0 2 0.00 30.00 60.00 90.00 120.00 150.00 180.00 OIL FLOW BATE2 ~-HMM-Ud U/:Ub:d8 ~ PERF DENS= 2 FT-1 ~ PERF DENS= 4 FT-1 X PERF DENS= 8 FT-1 ~ PERF DENS= 12 FT-1 ~ PERF DENS= 16 FT-1 ~ PERF DENS: 24 FT-1 ~ PERF DENS: 22 FT-! ~ PERF DENS: 36 FT-I ~ PERF DENS: ~10 FT-1 + PERF DENS= 48 FT-I · IPR CURVE 2u, o.o0 BB/O c'~ cz) i RTLRNTIC RICHFIELD C PRUDHOE RRY 13-19 ']UJ= L~.BSUO JN CIJI= G.1OO0 IN SCBDE-999.25 IN 0 RPERF= .12500 IN2 GRVSIZ= gO.O00 PGRIND= 7 , , ~ . .................. i .......................................................... , ~ ....... ~ . .................................. X ................. x ............................ · 00 ~0.00 80.00 gO.O0 ~20.00 ~50.00 ~80.00 2 0.00 2~0.00 ~ PERF DENS= 2 FT-1 ~ PERF DENS= g FT-1 × PERF DENS= 8 FT-! ~ PERF DENS= 12 FT-1 ~'PERF DENS= !6 FT-I 0 PERF DENS= 2g FT-1 ~ PERF DENS= 32 FT-1 ~ PERF DENS= 36 FT-1 ~ PERF DENS= IlO FT-I + PERF DENS= ~8 FT-I · IPR CURVE OIL FLON BBT-F ~02 r'-HMh-U~' U /: Ub: 06 BB/O [1TLF1NT]C FI'I£HF]ELD C PRUDHDE BnY 13-.~q I'UI=: q,USUU IN CI31= 6.1UOU IN 5L:FIUE-999.25 IN c:) RPERF= .12500 ~N2 GRVSIZ= LiO.O00 PGRINO= -/ ~ PERF DENS= 2 FT-! ~ PERF DENS= q FT-I X PERF DENS= O FT-1 ~ PEBF BENS= 12 FT-1 X PERF DENS= 16 FT-! ~ PERF DENS= 24 FT-! ...................................................................... ~ PERF DENS= 32 FT-1 ~ PERF DENS= 9G FT-1 ~ PEBF DENS= L!O FT-! 4- PERF DENS= ~0 · IPR CURVE · GRS FLON BriTE MF30 m-RPB-82 07;05;38 NTI_NNTIC RICHFIELD C PI:3UOHOE 13N¥ .1.3-19 IUI : ~t.9SUU ,IN CD].= 6.1UO0 IN 5CBUE-999.25 IN 0 APERF= .12500 IN2 GRVSIZ= LiO.O00 PGRIND= 7 . · ~ PERF DENS= 2 FT-I · PERF DENS= q FT-I X PERF DENS= O FT-1 ~ PERF DENS= 1~ FT-! ~ PERF DENS= 16 FT-! ~ PERF DENS= 2~ FT-! ...................................................................... A PERF DENS: 32 FT-1 ~ PERF DENS= 3G FT-I ~ PERF DENS= ~0 FT-1 q- HE~F DEI~S= ttO FT-i · IPR CURVE 6 O0 8 O0 GF1S FLOW RFITE C-) ....................... I'" ~0 O0 2 O0 u, O0 i 10.00 12.00 111.00 18.00 MF3O 2-FIPB-82 07:05:38 · "'... :' . .',: .' . ' : ,. '... ::L: .J j.i ::=::::~:: :.:jJ,~:J::::::J:.=~:".~=j::'::: ::~?::J<":::]~::::::::::::::::::::::::::::: (GLO~AI, PA~A~4tiT~Rb ) (VALUE) JOB START D~PTH JSTAPT I 9800,00 FT 3~RFAC~ T~;NPERATU~M ST ~ 155,000 D~GF ~I CURV~ FLAG TitL~ { I 0000o PERF DEN. CURVE FDAG P~RFi, G ~ ~I 1~00000 PVT INT~ICATOR P~TIND : ~,O~O00 ~PEC, ~AVI YY p PROD,(.;A~ SGPG ~ ,733000 .~ ................ :....,; .:,: ............ ., ;~ ................................... :>.:::........L......: ~L~,~....~ ............ ?!~:~: ............ ~ .......... ~'DLATILB OXG ~PT vOLOID l [~ORgIIGLE DIAMETER BDI:A~ ~ 8.5~000 bS;NGTH OF PER~'f]RATION [.,PERF' ~ ,.I04000 ~?T ~ (MATRZX PArAMeTERS) ~...:~. ~ ~;~:?~.~Z~<~ j~.~;~i~i~; ~.~.~ j ?: ~:.~ ~'~ :.. ~ ::::, :~::. ~:; :~::~:~:~:: :: .:.::::- :,.'.: ~.~:::~:.,'~::~,..?;,:-. ;.: ::~ :. :. ~..~. ~.%:.....: ::... ~:~:;{{~;~:~;~...%:<< .,~ :~v .~: :.:~. su' ':.~ :' ::. :~ :~: :~:: ~:. ~ :::~e. :~,~:~. ~$~¥' ~:~:.: ,:~:~. j.~:~% ~:.~,?~:~:~:, %~ ~ ~{ :~ ~:~::~ ~ .~;~:~,::~ :~:~::v~, ~:~,b:,~:: :~,:: ~ ::~~~?~~~?`~:~`~?~:~jj~?~:~.~:~:~.~..~~:.~ :~.~ :[ <~[]~[~~k?.~:`~].:]~:~.]:[~:]j5.~q~]~]d{`~[~~-~ . ;~ ..-..:..:.. .... . ..,~::.... .:~¢?~.:..<~.:.::~.:.:. :. ,:..,.::.:.::..:-:.:.::.~]~ ~ .............. ~ ............... ~.,P ........... ~9 ~.,P...!2~P !6.,.9 24,~ ~a,~ 36,0 , . 5 ~,0 ~,n 8,0 12,O 16,0 24,0 32,0 36.0 , · ;-'.:..~.'.. :. · :.',.'.'-.: ..' 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DEPT SP GR N C ~"~ b DTL I02bq,500 SFLU -999.250 GR 39.406 CALi 1002.500 FCNL -999.250 GR 10200,000 SFLU -31.766 G~ 122.68~ CALl 258~.000 FCNL 77,875 GR 10100.000 SFLU -92.563 GR 27.203 CA51 3938.000 FCN5 76.125 GR 10000.000 SFbO -119.813 GR 21.053 CALl 3654.000 FCNL 85.250 GR 9900.000 SFLU -115.000 G~ 2i.391 CALI 3~68.000 FCNL 85.750 G~ 9~00,000 SFLU -97,000 GR 22.109 CALI 4b16.000 FCN5 75.250 GR 9700.000 SFLU -59.750 G~ 61.531 CALI 2988.000 FCN5 84,625 G~ 9~00.000 SFLU -101,]12 GR 27.734 CALl 3568.000 FCNL 98.750 GR 9500.000 SFLb -32.844 GR 99.312 CALI 3466.000 FCN5 80.000 GE -999. -999. 5. 32B. -999. . 97. 8. 1034. 89, 59. 8. 1654, 33. m 20. 8. 1386, 17. i8. 1294. 19. 67i. 17. 261~. 53. 28. 1295. 4i, 39, 30. 8. 1455. 2i. 22. 85. 9. 17t8. 86. 250 250 539 250 250 82O 125 789 000 563 430 406 367 000 750 605 984 461 000 5!6 688 453 477 ~44 000 703 531 000 406 594 703 8i3 000 250 625 578 656 000 953 56.3 750 484 0 O0 250 NPHi DRHO DT DT NPHI DRHO DT DT NPHI DRHO DT DT NPHI DRHO DT DT NPHI DRHO DT DT IbM DRHO OT DT NPHi DRHO DT DT NPHI DRHO DT DT NPHI DRHO DY -999 34 0 -999 -999 5 25 0 76 77 4 78 7~ 2 26 0 86 88 2 25 -0 88 85 ! i3 -0 72 76 19 21 0 82 83 24 22 0 85 12 0 77 78 ,250 ,570 .276 ,250 .25O .375 .293 .O45 .375 .500 .625 ,875 ,010 .563 ,125 .20i .22i .002 ,563 .000 .299 .537 .005 .750 ,250 .287 .672 .010 .750 .250 .656 .436 ,07~- .375 .250 .297 .949 ~008 375 ,875 .328 .262 .001 .000 .750 RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR I DD RHOB NRAT GR I~D RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR -999,250 2.299 2.811 -999.250 5.563 2.641 2,447 97.125 3.873 2.342 2 188 2.135 2.340 2.486 20.984 2.076 2,256 2,439 18.453 0.BO0 2.604 i.655 17.703 23.000 2,539 2 193 28.922 2.344 2,285 30,578 ii.969 2.646 2,037 85.750 LYe 00~'~.i"]05 VERIF][CATiOi'~ blSTi~G DEPT GR NC~'L DTL 9400.000 Sf'LU -34,969 GR 54.531 CALl 1302.000 FCNL -999.250 GR 2000,000 48.031 NPHI 6.766 DRHO 272.750 DT -999'250 DT DEPT SP GR NCNL DTL 9393,000 SFL$ -999.250 GR 55.312 CALl i355.000 FCNL -999.250 GR -999,250 -999.250 6.758 DRHO 334,750 -999,250 DT ** FIbS TRAILER FIbK ~aME :SERVIC.O0! SERVICE NAME VERSiO~ #' DAT~ ~ MAXi~O~ LkNGTH : ~024 FiLE ~YPE NEXT FILE NA~E 2000.000 ILl) 58.252 RHOB -0,699 NRAT 62.375 GR -999,250 -999,250 49,902 RHOB -0.584 NRAT -999.250 GR -999.250 6,863 1.926 4,340 48,031 -999,250 2,021 3,877 -999,250 ** TAPE TRAILER ** SERVICE NAM~ :$ERVIC DATE :~2/02/19 ORiGI~t :1070 TAPE ~AME :6250! COSTI~UATiOM ~ :01 NEXT TAPE NA~IE : COMmEnTS :TAPE COMMENTS ** R~Eb TRAILER ** SERViCP: NAME :8ERVIC DATE :~2t02/t9 ORIGt~ : REEL ~a~E :REEL ID CONTi~i!ATIOb # :0~ NEXT REEL NAME : CO~!~E~'fS :REEL COMMENTS ~mmmmmmmmmmmmmmmmmmmm~ *----$CHbU~BERGER----~ ~mmmmmmmmmmmmemmmm~me~ LIS TAPE VERIFICATION bISTING ~VP 009,H05 VERIFICATION LISTING PAGE ** REEL HEADER SERVICE NAME ISERVIC DATE :82/01/21 ORIGIN : REEL NAME :REEL ID CONTINUATION # PREVIOUS REEL COMMENTS ~REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :82/01/21 ORIGIN :1070 TAPE NAME 162501 CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS **********'EOF ** FILE HEADER ** FILE NAME ISERVIC.O01 SERVICE NAME : VERSION # : DATE I MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS ** MNEM CONTENTS CN : ARCO ALASKA INC, WN : D,S, 13' FN : PRUDHOE BAY RANG: TOWNI iON SECT: 14 COUN: NORTH SLOPE STATI ALASKA CTRY: USA MNEM CONTENTS PRESl DIbOO1F RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 0t6 065 000 000 010 065 000 000 012 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE, CODE 000 000 007 O65 bVP 009,H05 VERIFICATION LISTING RECORD TYPE 047 ** RECORD TYPE 047 ** COMMENTS ~* SCHLUMBERGER PACIFIC COAST'COMPUTING CENTER COMPANY = ARCO WEbb = D.S, 13-19 FIELD = PRUDHOE BAY COUNTY = NORTH STATE = ALASKA JOB # 10707,62501 RUN #2, LOGGED 14-DEC-81 BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY 10490 FT, 9 62 . ~ 9444 FT, 8:5 IN. BLAND 10 42 PAGE LVP 009,H05 VERIFICATION LISTING PAGE 3 PH = 9.0 FLUID LOSS = 5.8 C3 RM g MEAS TEMP. = 5.49 9 70 F RMF 9 MEAS:; TEMP. : 4.32 ~ 70 F RMC ~ MEAS' TEMP. 3.87 , 186 r RM ~ BHT a 2,190 ~ 186 F MATRIX SANDSTONE ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 60 9 4 65 0 I 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API APl API AP1 FILE SIZE PROCES& SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. bEVEL CODE 0 0 4 0 , 68 DEPT FT 0 0 0 SFLU DIL OHMM 7 0 0 0 0 IbM OIL OHMM 7 0 0 0 0 IBD DIL OHMM 7 12 46 0 0 SP OIL MV 7 I 0 0 0 GR OIL GAPI 7 31 32 0 0 NPHI FDN PU 4268 20 0 RHOB FDN G/C3 42 35 1 0 0 GR FDN GAP! ~ 3,320 0 o o 4 0 ! 68 4 0 I 68 4 0 6 4 0 I 68 4 0 , 68 4 0 ! 68 4 0 I 68 4 0 I 68 4 0 I 68 4 0 , 68 4 0 I 6 8 4 0 1 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 I 68 DATA LVP SP GR NCNb DTL DEPT SP GR NCNL DTb DEPT SP GR NCNb DTb DEPT SP GR NCNb DTL DEPT GR NCNL DTL DEPT GR NCNb DTL DEPT 8P GR NCNb DTb DEPT SP GR NCNb DTb DEPT SP GR NCNb DTL 009,H05 VERIFICATION 10264.500 SFbU '=999.250 GR '39.406 CALf 1002'500 FCNL '999,250 GR 10200 000 -31 766 122 688 2584 000 '77 875 SFLU GR CALf FCNb GR 00,000 SirbU 10~92,563 GR 287.203 CALf 125 GR 10000,000 SFbU -119'813 GR ' 1,063 CALf 3654,000 FCNL 85,250 GR 9900,000 SFLU =I15.000 OR '21,391 CALl 3468.000 FCNb -85,750 OR 9~900.000 $fbU 7'000 GR 22,109 CALf 4516'000 rCNb 75,250 GR 9700,000 SFLU "69,750 GR 61 '531 CAb]: 2988!000 FCNL '84 625 GR 9bO0 000 -I01 312 -27 734 3568 000 '98 750 9500.000 ,312 3466.000 -80.000 SFLU GR CALl FCNb GR $FLU OR CAb]: FCNb GR LISTING -999 -999 5 328 -999 5 97 8 1034 89 9 59 16548 33 7 20 8 1386 17 9 18 61½ 8 2614 15 53 28 8 1295 41 3 1455 24 22 85 17189 86 ,250 .250 .539 .250 ,250 ,820 I25 '78g '000 ,563 .430 .406 !oo 75O 605 984 461 000 5!6 .688 .453 477 000 844 .000 .703 '531 :ooo ,406 ,594 .703 ,813 .000 ,250 656 000 953 .563 '750 .484 .000 .250 IbM NPHZ DRHO DT DRHO DT NPHI RHO T IbM NPHI DRHO DT IbM NPHI DRHO DT NPH! DRHO DT DRHO DT ibm DRHO IbM NPHI DRHO '999,250 ILD 34,570 RHOB 0,276 NRAT "999.250 GR 2~,375 XED .293 RHOB 0,045 NRAT 77,500 GR 4,625 XLD 2t,875 RHOB 0,010 NRAT 76'125 GR 2,201 XbD 26,221 RHOB 0'00 NRA~ 88.000 GR 2,299 ILD 25,537 RHOB ,005 NRA2' 1,28 XLD 13,671 RHOB ~0,010 NRAT 6.250 GR 19,65 IGD 21'4366 B RHO 0,07 NRAT 83.2505 OR 24.29 22,.94~ RHOB 0,008 NRA~ 84.875 GR 12.328 18,262 RHOB 0,001 NRAT 78,750 GR PAGE '299 2,81I -99 . 250 5,563 2,64I 2,447 97,125 :~.873 '342 8 :Z35 2 48 256 453 8OO 703 23,000 2,539 2~'193 .703 '285 11.969 2.646 2.037 85.750 LVP 009,H05 VERIFICATION LISTING PAGE 5 DEPT 9600 000 SFGU SP -34~969 GR GR 54.531 CAb! NCNb 1302,000 FCNb DTL '999°250 GR · DEPT 9393,000 SFbU SP '999.250 GR GR 55,312 CAb! NCNb 1355,000 FCNL DTL '999,250 GR 2000,000 IbM 48,03! NPHI 8,766 DRHO 272,750 DT -999,250 -999,250 ILM -999.250 NPH! 8 ~58 DRHO 334! 50 DT -999 250 ** FILE TRAILER *~ FILE NAME ISER¥IC,O01 SERVICE NAME I VERSION # I DATE I MAXIMUM LENGTH I 1024 FILE TYPE I NEXT FILE NAME I ** TAPE TRAILER ** SERVICE NAME ISERVIC DATE 182/01/21 ORIGIN {1070 TAPE NAME i62501 CONTINUATION # 101 NEXT TAPE NAME I COMMENTS ITAPE COMMENTS ** REEL TRAILER SERVICE NAME ISERVIC DATE 182/01/21 ORIGIN ~ REEL NAME IREEb ID CONT~NUATZON # NEXT REEL NAME COMMENTS :REEL COMMENTS 2000,00 58'25~ RHOB .9~0.699 NRAT 9,250 OR '999,250 -49~902 RHOB . '0,584 NRA/' 999,250 GR 6 863 1:926 4,340 48,031 3,877 -999,250