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Home My WebLink About183-172CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2F-15 (PTD 183-172) Update Date:Wednesday, April 23, 2025 8:21:46 AM From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Wednesday, April 23, 2025 8:11 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2F-15 (PTD 183-172) Update Well Name: 2F-15 Facility: CPF2 PTD: 183-172 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Plan Forward Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): N/A Hi Chris, KRU 2F-15 (PTD 183-172) is an injection well currently shut in due to tubing x IA communication. A permanent patch was set and did not provide integrity and the millable tubing tail plug is leaking. The well was circulated out to 13 ppg brine with a diesel freeze protect to manage the IA and tubing pressures below the OPL and CPAI is evaluating the options to complete a RWO. To evaluate the RWO an MIT-OA was conducted and failed. CPAI conducted a SCLD which passed indicating the leak is only active at pressures exceeding 1200 psi and is likely at the shoe. The well will continue to remain shut in in evaluation of the RWO. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from jaime.bronga@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2F-15 (PTD 183-172) Date:Wednesday, April 16, 2025 4:22:05 PM Attachments:AnnComm Surveillance TIO for 2F-15.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Wednesday, April 16, 2025 4:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2F-15 (PTD 183-172) Well Name: 2F-15 Facility: CPF2 PTD: 183-172 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Failed MITOA Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): N/A Hi Chris, KRU 2F-15 (PTD 183-172) is an injection well currently shut in due to tubing x IA communication. A permanent patch was set and did not provide integrity and the millable tubing tail plug is leaking. The well was circulated out to 13 ppg brine with a diesel freeze protect to manage the IA and tubing pressures below the OPL and CPAI is evaluating the options to complete a RWO. To evaluate the RWO an MIT-OA was conducted and failed. CPAI intends to conduct a SCLD to confirm the depth of the OA leak and continue to investigate options to repair the integrity of the well with a RWO. The well will continue to remain shut in. Please let me know if you have any questions or disagree with the plan. The TIO plot, schematic, and bleed log are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2F-15 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 57' of Fill) 7,012.0 2F-15 12/13/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled 1.5" DV 2F-15 9/19/2024 jhanse11 Notes: General & Safety Annotation End Date Last Mod By NOTE: Frac Sleeve for work below SSSV 4/3/2000 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.9 2,896.2 2,741.8 36.00 J-55 BTC PRODUCTION 7 6.28 29.5 7,526.3 6,500.1 26.00 J-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.6 Set Depth … 6,874.3 Set Depth … 5,899.3 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.6 23.6 0.09 HANGER 8.000 FMC TUBING HANGER 3.500 1,806.7 1,804.4 11.89 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT 1/29/04) CAMCO TRDP- 1A 2.812 6,776.5 5,811.0 26.08 GAS LIFT 5.940 OTIS LBX OTIS LBX 2.907 6,819.6 5,849.8 25.52 PBR 5.625 CAMCO OEJ PBR CAMCO OEJ 2.813 6,842.2 5,870.2 25.29 PACKER 5.937 CAMCO HRP-1SP HYD SET PACKER CAMCO HRP- 1SP 2.867 6,862.8 5,888.9 25.07 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,814.7 1,812.2 12.20 SPACER PIPE ISEALATE PATCH OAL 3.3', MIN ID 2.70" ISEALAT E N/A N/A 2/13/2024 2.700 6,761.0 5,797.1 26.32 SPACER PIPE ISEALATE PATCH OAL 9.8', MIN ID 2.49" ISEALAT E N/A N/A 2/13/2024 2.490 6,766.0 5,801.6 26.24 LEAK - TUBING LEAK POINT IDENTIFIED IN TUBING ON LDL PERFORMED 1/17/23, RECONFIRMED WITH ACOUSTIC LDL ON 4/5/24 (ISEALATE PATCH LEAKING) 1/17/2023 2.992 6,857.9 5,884.4 25.12 PLUG MAGNA-RANGE PLUG SET @ 6859.0' MID-ELEMENT - NON-RETRIEVABLE QUADC O 4200- 219- AC- 001 12/20/2022 0.000 7,234.0 6,229.3 22.31 FISH FISH 5" Vann Gun, 208.16' long 3/19/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,776.5 5,811.0 26.08 1 GAS LIFT Open Pocket Open 9/19/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,007.0 7,018.0 6,020.2 6,030.3 A-5, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 7,035.0 7,069.0 6,045.9 6,077.1 A-4, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 2F-15, 9/20/2024 8:03:42 AM Vertical schematic (actual) PRODUCTION; 29.5-7,526.3 FISH; 7,234.0 IPERF; 7,035.0-7,069.0 IPERF; 7,007.0-7,018.0 PLUG; 6,857.8 PACKER; 6,842.2 GAS LIFT; 6,776.5 LEAK - TUBING; 6,766.0 SPACER PIPE; 6,761.0 SURFACE; 30.9-2,896.2 SPACER PIPE; 1,814.7 SAFETY VLV; 1,806.7 CONDUCTOR; 31.0-108.0 KUP INJ KB-Grd (ft) 33.99 RR Date 12/18/198 3 Other Elev… 2F-15 ... TD Act Btm (ftKB) 7,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292104800 Wellbore Status INJ Max Angle & MD Incl (°) 46.95 MD (ftKB) 3,100.00 WELLNAME WELLBORE2F-15 Annotation Last WO: End Date 1/26/1987 H2S (ppm) DateComment SSSV: LOCKED OUT CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 2F-15 (PTD #183-172) Date:Tuesday, July 9, 2024 2:35:21 PM Attachments:AnnComm Surveillance TIO for 2F-15.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, July 9, 2024 11:15 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: 2F-15 (PTD #183-172) Hi Chris, 2F-15 (PTD #183-172) is a produced water injection well that is shut in due to Tubing by IA communication. A plug was set in the tail pipe in 2022 and a patch repair was attempted in 2024. Following the lower patch setting, a draw down test confirmed the tail pipe plug failed and the patch setting was unsuccessful. The well still has TxIA and the plug is allowing pressure build up. The IA has stabilized at 2160 psi. The well is equipped with 7” 26lb J-55 production casing which has a burst rating of 4980 psi. CPAI intends to attempt to fish the failed patch and mill out the failed tail pipe plug. Following these steps, CPAI intends to reset the plug to secure the well and attempt to repair the TxIA. Due to the current state of the well, CPAI intends to allow the IA pressure to remain above 2000 psi but below 2300 psi to prevent bleeding off the freeze protect fluid in the IA while conducting remediation. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2F-15 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2F-15 2024-04-10 2050 1650 -400 IA 2F-15 2024-04-12 2150 1600 -550 IA 2F-15 2024-07-08 2150 1450 -700 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 57' of Fill) 7,012.0 2F-15 12/13/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added two Isealate patches 2F-15 2/13/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Frac Sleeve for work below SSSV 4/3/2000 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.9 2,896.2 2,741.8 36.00 J-55 BTC PRODUCTION 7 6.28 29.5 7,526.3 6,500.1 26.00 J-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.6 Set Depth … 6,874.3 Set Depth … 5,899.3 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.6 23.6 0.09 HANGER 8.000 FMC TUBING HANGER 3.500 1,806.7 1,804.4 11.89 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT 1/29/04) CAMCO TRDP- 1A 2.812 6,776.5 5,811.0 26.08 GAS LIFT 5.940 OTIS LBX OTIS LBX 2.907 6,819.6 5,849.8 25.52 PBR 5.625 CAMCO OEJ PBR CAMCO OEJ 2.813 6,842.2 5,870.2 25.29 PACKER 5.937 CAMCO HRP-1SP HYD SET PACKER CAMCO HRP- 1SP 2.867 6,862.8 5,888.9 25.07 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,814.7 1,812.2 12.20 SPACER PIPE ISEALATE PATCH OAL 3.3', THEORETICAL MIN ID 2.71" (WILL BE CONFIRMED WITH CALIPER LOG) ISEALAT E N/A N/A 2/13/2024 2.710 6,761.0 5,797.1 26.32 SPACER PIPE ISEALATE PATCH OAL 9.8', THEORETICAL MIN ID 2.71" (WILL BE CONFIRMED WITH CALIPER LOG) ISEALAT E N/A N/A 2/13/2024 2.710 6,766.0 5,801.6 26.24 LEAK - TUBING LEAK POINT IDENTIFIED IN TUBING ON LDL PERFORMED 1/17/23 1/17/2023 2.992 6,857.9 5,884.4 25.12 PLUG MAGNA-RANGE PLUG SET @ 6859.0' MID-ELEMENT - NON-RETRIEVABLE QUADC O 4200- 219- AC- 001 12/20/2022 0.000 7,234.0 6,229.3 22.31 FISH FISH 5" Vann Gun, 208.16' long 3/19/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,776.5 5,811.0 26.08 1 GAS LIFT DMY RO5 1 1/2 0.0 12/23/1987 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,007.0 7,018.0 6,020.2 6,030.3 A-5, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 7,035.0 7,069.0 6,045.9 6,077.1 A-4, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 2F-15, 2/14/2024 4:37:37 AM Vertical schematic (actual) PRODUCTION; 29.5-7,526.3 FLOAT SHOE; 7,524.6-7,526.3 FLOAT COLLAR; 7,442.5- 7,444.1 FISH; 7,234.0 IPERF; 7,035.0-7,069.0 IPERF; 7,007.0-7,018.0 NIPPLE; 6,862.8 PLUG; 6,857.8 PACKER; 6,842.2 PBR; 6,819.6 GAS LIFT; 6,776.5 LEAK - TUBING; 6,766.0 SPACER PIPE; 6,761.0 SURFACE; 30.9-2,896.2 FLOAT SHOE; 2,894.4-2,896.2 FLOAT COLLAR; 2,813.9- 2,815.5 SPACER PIPE; 1,814.7 SAFETY VLV; 1,806.7 CONDUCTOR; 31.0-108.0 HANGER; 30.9-35.1 HANGER; 29.5-34.5 HANGER; 23.6 KUP INJ KB-Grd (ft) 33.99 RR Date 12/18/198 3 Other Elev… 2F-15 ... TD Act Btm (ftKB) 7,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292104800 Wellbore Status INJ Max Angle & MD Incl (°) 46.95 MD (ftKB) 3,100.00 WELLNAME WELLBORE2F-15 Annotation Last WO: End Date 1/26/1987 H2S (ppm) DateComment SSSV: LOCKED OUT Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7550'feet 6858'feet true vertical 6522' feet 7234' feet Effective Depth measured 6858'feet 6842'feet true vertical 5884' feet 5870' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 6874' MD 5899' TVD Packers and SSSV (type, measured and true vertical depth)6842' MD 1807' MD 5870' TVD 1804' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 2896' 2742' Burst Collapse Production Liner 7497' Casing 6500'7526' 2865' 108'Conductor Surface Intermediate 16" 9-5/8" 77' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-172 50-02921048-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025657 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2F-15 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~~~ INJECTOR ~~ ~ 324-022 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Camco HRP-1SP HYD SET Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv Dusty Freeborn dusty.freeborn@conocophillips.com (907) 265-6218Senior Well Integrity Specialist 7007-7018', 7035-7069' 6020-6030', 6046-6077' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:12 pm, Apr 29, 2024 Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E= dusty.freeborn@conocophillips.com Reason: I am the author of this documentLocation: Anchorage, Alaska Date: 2024.04.29 12:38:05-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn RBDMS JSB 043024 DSR-4/29/24 DTTMSTART JOBTYP SUMMARYOPS 1/29/2024 ACQUIRE DATA PULLED 2.84'' ISOLATION SLEEVE 1807' RKB. BRUSHED DOWN TO SSSV. DRIFTED W/ 2.70 x 27.5' TO 4' INTO SAFETY VLV 1811' RKB, (SLIGHT OVER PULL 1004' RKB. READY FOR PATCH. 2/12/2024 ACQUIRE DATA SET ISEALATE PATCH OVER SSSV, PATCH DEPTH 1814.7' - 1818' RIH WITH 2.70" DRIFT WITH PRESS/TEMP/CCL, DRIFT THRU PATCH, LOG TEMP AND PRESS OVER LEAK POINT JOB CONTINUED NEXT DAY 2/13/2024 ACQUIRE DATA JOB CONTINUED, BRUSH PIPE AROUND CASING LEAK, 6753'-6776' RIH WITH ISEALATE PATCH WITH WELLTEC SETTING TOOL AND STANDBY 10 HRS FOR RESIN TO CURE T/I/O PRIOR TO SETTTING = 1400/1360/0 T/I/O AFTER 10HR CURE TIME = 2145/1950/0 CENTER OF PATCH = 6766', CCL TO CENTER OF PATCH = 40', CCL STOP DEPTH = 6766' CCL TO TOP OF PATCH = 35', CCL TO BTM OF PATCH = 44.8' PATCH INTERVAL = 6761' - 6770.8' 2/14/2024 ACQUIRE DATA INSTALLED ISEALATE PATCH WITH WELLTEC SETTING TOOL AND POOH T/I/O PRIOR TO SETTTING = 1400/1360/0 CENTER OF PATCH = 6766' CCL TO CENTER OF PATCH = 40' CCL STOP DEPTH = 6766' CCL TO TOP OF PATCH = 35' CCL TO BTM OF PATCH = 44.8' PATCH INTERVAL = 6761' - 6770.8' JOB COMPLETED, POOH, RDMO 2/16/2024 ACQUIRE DATA (AC EVAL) T DDT (FAIL) & IA DDT (FAIL) 2/25/2024 ACQUIRE DATA DRIFT TBG & TAG OBSTRUCTION @ 6820' RKB (OEJ PBR) TAGGED INSIDE LOWER PATCH @ 6761' RKB W/ 2.62" LIB. TAGGED OBSTRUCTION @ 6820' RKB W/ 2.49" LIB. TAGGED @ 6852' RKB W/ 2.24 LIB (FACE OF LIB DIDN'T HAVE AN IMPRESSION). MITT TO 2500 PSI (FAIL) RAN 24-ARM CALIPER FROM 6845' RKB TO SURFACE. JOB COMPLETE & READY FOR A PLAN FORWARD. 3/17/2024 ACQUIRE DATA (AC EVAL) IA X T X FORMATION LLR TO 3000 PSI - ESTABLISHED LLR OF 0.2 GPM (COMPLETE) 4/5/2024 ACQUIRE DATA PERFORM LEAK DETECTION LOG W/ READ ACOUSTIC TOOL. LOG BASELINE TEMPERATURE PASS FROM SURFACE TO 6842' UNABLE TO GET ANY DEEPER (HARD TAG, PREVIOUS INTERVENTION WORK SUSPECTS MAGNA RANGE PLUG HAS MOVED UPHOLE). ATTEMPT TO PUMP DOWN IA TO FORMATION AT 3000 PSI. TBG PRESSURE TRACKING WITH IA. ATTEMPT 3000 PSI CMIT TxIA AND CMIT NEARLY PASSES. CALL FOR JUMPER EQUIPMENT AND PRESSURE UP TUBING TO 2800 PSI AND OPEN IA TO FLOWLINE PRESSURE (200 PSI). LOG UP, LEAK FOUND KNOWN TBG LEAK DEPTH OF 6766' (IN ISEALATE PATCH). NO OTHER LEAKS FOUND. LRS PERFORM PASSING 3000 PSI CMIT TxIA AFTER LDL. JOB COMPLETE, READY FOR PLAN FORWARD 2F-15 Patch Summary of Operations Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added two Isealate patches 2F-15 2/13/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Frac Sleeve for work below SSSV 4/3/2000 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.9 2,896.2 2,741.8 36.00 J-55 BTC PRODUCTION 7 6.28 29.5 7,526.3 6,500.1 26.00 J-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.6 Set Depth … 6,874.3 Set Depth … 5,899.3 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.6 23.6 0.09 HANGER 8.000 FMC TUBING HANGER 3.500 1,806.7 1,804.4 11.89 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT 1/29/04) CAMCO TRDP- 1A 2.812 6,776.5 5,811.0 26.08 GAS LIFT 5.940 OTIS LBX OTIS LBX 2.907 6,819.6 5,849.8 25.52 PBR 5.625 CAMCO OEJ PBR CAMCO OEJ 2.813 6,842.2 5,870.2 25.29 PACKER 5.937 CAMCO HRP-1SP HYD SET PACKER CAMCO HRP- 1SP 2.867 6,862.8 5,888.9 25.07 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,814.7 1,812.2 12.20 SPACER PIPE ISEALATE PATCH OAL 3.3', MIN ID 2.70" ISEALAT E N/A N/A 2/13/2024 2.700 6,761.0 5,797.1 26.32 SPACER PIPE ISEALATE PATCH OAL 9.8', MIN ID 2.49" ISEALAT E N/A N/A 2/13/2024 2.490 6,766.0 5,801.6 26.24 LEAK - TUBING LEAK POINT IDENTIFIED IN TUBING ON LDL PERFORMED 1/17/23, RECONFIRMED WITH ACOUSTIC LDL ON 4/5/24 (ISEALATE PATCH LEAKING) 1/17/2023 2.992 6,857.9 5,884.4 25.12 PLUG MAGNA-RANGE PLUG SET @ 6859.0' MID-ELEMENT - NON-RETRIEVABLE QUADC O 4200- 219- AC- 001 12/20/2022 0.000 7,234.0 6,229.3 22.31 FISH FISH 5" Vann Gun, 208.16' long 3/19/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,776.5 5,811.0 26.08 1 GAS LIFT DMY RO5 1 1/2 0.0 12/23/1987 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,007.0 7,018.0 6,020.2 6,030.3 A-5, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 7,035.0 7,069.0 6,045.9 6,077.1 A-4, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun IPERF; 7,035.0-7,069.0 IPERF; 7,007.0-7,018.0 PLUG; 6,857.8 PACKER; 6,842.2 GAS LIFT; 6,776.5 LEAK - TUBING; 6,766.0 SPACER PIPE; 6,761.0 SURFACE; 30.9-2,896.2 SPACER PIPE; 1,814.7 SAFETY VLV; 1,806.7 CONDUCTOR; 31.0-108.0 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2024-04-05_15978_KRU_2F-15_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15978 KRU 2F-15 50-029-21048-00 LeakPoint Survey 05-Apr-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 183-172 T38700 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.11 09:49:32 -08'00' Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 183 -1 7 2 2F Ͳ15 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7550'7234' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 1/26/2024 3-1/2" Packer: Camco HRP-1SP HYD SET Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv Perforation Depth MD (ft): J-55 2865' 7007-7018', 7035-7069' 7497' 6020-6030', 6046-6077' 7" Perforation Depth TVD (ft): 108' 2896' 6500'7526' 16" 9-5/8" 77' 6874' MD 108' 2742' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025657 183-172 P.O. Box 100360, Anchorage, AK 99510 50-029-21048-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6842' MD and 5870' TVD 1807' MD and 1804' TVD Dusty Freeborn Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: dusty.freeborn@conocophillips.com (907) 265-6218 Senior Well Integrity Specialist KRU 2F-15 6522' 6858' 5884' 6858' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2024.01.19 12:33:37-09'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn 324-022 By Grace Christianson at 11:20 am, Jan 22, 2024 x 10-404 VTL 01/24/2024 DSR-1/26/24 SFD SFD 1/26/2024 x *&:JLC 1/29/2024 1/29/24 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.29 15:05:00 -09'00' RBDMS JSB 013024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 19 January 2024 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2F-15 (PTD 183-172) to set an Isealate isolation sleeve across the SSSV to hold the damaged flapper open permanently and set an Isealate tubing patch across the known tubing leak at 6766’ to regain tubing by inner annulus integrity. Please contact me at 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O= ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2024.01.19 12:31:54-09'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn 1. RIH w/ the Welltec Wish Bone Honer / brush to the designated set depth of the patch. 2. 50 fpm is the maximum speed through all jewelry and restrictions running in the hole and pulling out of the hole. 3. Stop for pickup weights every 2000ft during RIH. 4. Verify measured PUW values match the simulation modeling of the job. 5. At no point should “Max Safe Pull” of the wireline weak point be exceeded during the hoisting of tools. 6. Brush 10‘ of the TBG above and below at the known leak site. This will enable us to have clean pipe at the setting depth of the patch no matter the identified spanning of the patch. 7. Once the zone of interest is brushed a total of 3 passes, POOH 8. Once on surface, inspect tools, and prep the next BHA. 9.Rig up according to procedure and RIH (max. RIH speed is 30ft/min). a.Note that the patch is run sleeveless (Epoxy exposed), RIH speed should reflect this 10.RIH with CCL analog signal monitored. 11.Run carefully through the previously set Isolation sleeve set in TRSV. 12.RIH below target depth, perform CCL correlation and make sure that on-depth. 13.Pull up and locate the patch such that the 3-meter patch will cover the identified leak point at 6766'. Place the Isealate patch center at the identified tubing leak. Target set depth of top of patch ~6761 and bottom of patch at ~6770’. 14.Monitor well temperature. 2F-15 Isealate Isolation sleeve and tubing patch Running procedure. 1.Rig up according to procedure and RIH (max. RIH speed is 3,0ft/min). 1.Note that the patch is run sleeveless, run carefully through wellhead ++ 2.RIH with CCL analog signal monitored. 1.Do not attempt to pass the TRSV (1806 ft) 3.RIH 30 ft above target depth, perform CCL correlation and make sure that on-depth. 4.RIH carefully and land setting section on top of the TOP NOGO 5.Start hydraulic fluid pump and activate IPI Packer to release patch 6.Pump until pressure reach approx. 10-11 bar, shear steel straps/bands (+/-10min). 1.Hydraulic packer pressure will decrease when patch band breaks. 7.Bleed pressure to 0 / deflate packer 8.Keep hydraulic back pressure for 15 minutes. 9.DO NOT set pressure on the packer after the patch has been released. 10.POH 11.RUN a drift of 2.75” through the TRSV to make sure the patch is set correctly. General Isealate running procedure (sealing of connection leak) 15.Start hydraulic fluid pump and activate IPI Packer to release patch. 16.Pump up hydraulic packer until pressure reach approx. 10-11 bar, shear steel straps/bands (approx. 10 minutes) a.Hydraulic packer pressure will decrease when patch band breaks. 17.Continue to pressure packer up in steps 3-6-9-11 Bars and finally 20 Bar (approx. 15 minutes) reason for this is to give epoxy time to distribute)) 18.Bleed pressure to 0 bar, retract the packer by switching solenoid and activate pump. a.Keep hydraulic back pressure for 30 minutes. 19.Let Epoxy on patch solidify for time determined based on current wellbore temperature. a.Will depend on heating element efficiency 20.POH 21. Perform MIT-T to 2000 psi. Record initial, 15 and 30 min TIO pressures. 22. Perform SW MIT-IA once well is online and stabilized. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 57' of Fill) 7,012.0 2F-15 12/13/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Leak point identified in tubing @ 6766' RKB 2F-15 1/17/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/13/2010 ninam NOTE: Frac Sleeve for work below SSSV 4/3/2000 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By STILL NEED TO USE CAUTION WHEN DOING WELLWORK BELOW FLAPPER. SEE WSR FOR 1/29/2004 1/29/2004 Admin Frac Sleeve for work below SSSV. See WSR 2/7/00. 4/3/2000 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.9 2,896.2 2,741.8 36.00 J-55 BTC PRODUCTION 7 6.28 29.5 7,526.3 6,500.1 26.00 J-55 BUTT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.6 Set Depth … 6,874.3 Set Depth … 5,899.3 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.6 23.6 0.09 HANGER 8.000 FMC TUBING HANGER 3.500 1,806.7 1,804.4 11.89 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT 1/29/04) CAMCO TRDP- 1A 2.812 6,776.5 5,811.0 26.08 GAS LIFT 5.940 OTIS LBX OTIS LBX 2.907 6,819.6 5,849.8 25.52 PBR 5.625 CAMCO OEJ PBR CAMCO OEJ 2.813 6,842.2 5,870.2 25.29 PACKER 5.937 CAMCO HRP-1SP HYD SET PACKER CAMCO HRP- 1SP 2.867 6,862.8 5,888.9 25.07 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,806.7 1,804.4 11.89 ISO-SLEEVE 2.84" No-Go HOLD OPEN SLEEVE (117" OAL / 2.31" ID) 5/5/2022 2.310 6,766.0 5,801.6 26.24 LEAK - TUBING LEAK POINT IDENTIFIED IN TUBING ON LDL PERFORMED 1/17/23 1/17/2023 2.992 6,857.9 5,884.4 25.12 PLUG MAGNA-RANGE PLUG SET @ 6859.0' MID-ELEMENT - NON-RETRIEVABLE QUADC O 4200- 219- AC- 001 12/20/2022 0.000 7,234.0 6,229.3 22.31 FISH FISH 5" Vann Gun, 208.16' long 3/19/1984 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,776.5 5,811.0 26.08 1 GAS LIFT DMY RO5 1 1/2 0.0 12/23/1987 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,007.0 7,018.0 6,020.2 6,030.3 A-5, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 7,035.0 7,069.0 6,045.9 6,077.1 A-4, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 2F-15, 1/18/2023 4:33:51 AM Vertical schematic (actual) PRODUCTION; 29.5-7,526.3 FLOAT SHOE; 7,524.6-7,526.3 FLOAT COLLAR; 7,442.5- 7,444.1 FISH; 7,234.0 IPERF; 7,035.0-7,069.0 IPERF; 7,007.0-7,018.0 NIPPLE; 6,862.8 PLUG; 6,857.8 PACKER; 6,842.2 PBR; 6,819.6 GAS LIFT; 6,776.5 LEAK - TUBING; 6,766.0 SURFACE; 30.9-2,896.2 FLOAT SHOE; 2,894.4-2,896.2 FLOAT COLLAR; 2,813.9- 2,815.5 SAFETY VLV; 1,806.7 ISO-SLEEVE; 1,806.7 CONDUCTOR; 31.0-108.0 HANGER; 30.9-35.1 HANGER; 29.5-34.5 HANGER; 23.6 KUP INJ KB-Grd (ft) 33.99 RR Date 12/18/198 3 Other Elev… 2F-15 ... TD Act Btm (ftKB) 7,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292104800 Wellbore Status INJ Max Angle & MD Incl (°) 46.95 MD (ftKB) 3,100.00 WELLNAME WELLBORE2F-15 Annotation Last WO: End Date 1/26/1987 H2S (ppm) DateComment SSSV: LOCKED OUT CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU injector 2F-15 (PTD #183-172) report of recharging IA pressure. Date:Tuesday, December 20, 2022 9:35:29 AM Attachments:image001.png AnnComm Surveillance TIO for 2F-15.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, December 12, 2022 4:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: KRU injector 2F-15 (PTD #183-172) report of recharging IA pressure. Chris- KRU injector 2F-15 (PTD #183-172) was reported by operations to have a recharging IA pressure. An IA bleed attempt was conducted and the IA began building pressure immediately after and has now stabilized at 2015 psi. The well is equipped with 7” 26lb J-55 production casing which has a burst rating of 4980 psi. The well has been shut in for reservoir management purposes since May of 2017. CPAI intends to secure the well and conduct diagnostics to identify the failure mechanism. Depending on the results of the diagnostics the proper paperwork for returning to injection status or repair will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,023.0 5/5/2022 2F-15 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Iso Sleeve & Updated Tag Depth 5/5/2022 2F-15 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (lb… 62.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 30.9 Set Depth (ftKB) 2,896.2 Set Depth (TVD) … 2,741.8 Wt/Len (lb… 36.00 Grade J-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 29.5 Set Depth (ftKB) 7,526.3 Set Depth (TVD) … 6,500.1 Wt/Len (lb… 26.00 Grade J-55 Top Connection BUTT Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING WO String … 3 1/2 ID (in) 2.99 Top (ftKB) 23.6 Set Depth (ft… 6,874.3 Set Depth (TVD… 5,899.3 Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMO D Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 23.6 23.6 0.09 HANGER 3.500 8.000 1,806.7 1,804.4 11.89 SAFETY VLV 2.812 5.937 CAMCO TRDP-1A 6,776.5 5,811.0 26.08 GAS LIFT 2.907 5.940 OTIS LBX 6,819.6 5,849.8 25.52 PBR 2.813 5.625 CAMCO OEJ 6,842.2 5,870.2 25.29 PACKER 2.867 5.937 CAMCO HRP-1SP 6,862.8 5,888.9 25.07 NIPPLE 2.750 4.540 CAMCO D Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 1,806.7 1,804.4 11.89 ISO-SLEEVE 2.84" No-Go HOLD OPEN SLEEVE (117" OAL / 2.31" ID) 5/5/2022 2.310 7,234.0 6,229.3 22.31 FISH FISH 5" Vann Gun, 208.16' long 3/19/1984 0.000 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,776.5 5,811.0 26.08 1 1/2 GAS LIFT DMY RO5 0.000 0.0 12/23/1987 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,007.0 7,018.0 6,020.2 6,030.3 A-5, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun 7,035.0 7,069.0 6,045.9 6,077.1 A-4, 2F-15 3/19/1984 12.0 IPERF 5" Vann Gun Notes: General & Safety End Date Annotation 10/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/3/2000 NOTE: Frac Sleeve for work below SSSV 2F-15, 5/6/2022 8:50:00 AM Vertical schematic (actual) PRODUCTION; 29.5-7,526.3 FISH; 7,234.0 IPERF; 7,035.0-7,069.0 IPERF; 7,007.0-7,018.0 NIPPLE; 6,862.8 PACKER; 6,842.2 PBR; 6,819.6 GAS LIFT; 6,776.5 SURFACE; 30.9-2,896.2 SAFETY VLV; 1,806.7 ISO-SLEEVE; 1,806.7 CONDUCTOR; 31.0-108.0 HANGER; 23.6 KUP INJ KB-Grd (ft) 33.99 RR Date 12/18/198 3 Other Elev… 2F-15 ... TD Act Btm (ftKB) 7,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292104800 Wellbore Status INJ Max Angle & MD Incl (°) 46.95 MD (ftKB) 3,100.00 WELLNAME WELLBORE2F-15 Annotation Last WO: End Date 1/26/1987 H2S (ppm) DateComment SSSV: LOCKED OUT t�Z-C( 7-F- 1� I6317Z6 Regg, James B (CED) From: Well Integrity Compliance Specialist CPH & 2 <n1617@conocophiIIips.com> Sent: Wednesday, July 15, 2020 8:39 AM To: Regg, James B (CED); Wallace, Chris D (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: KRU Non Witnessed MITIAs 7/13/20 Attachments: MIT KRU 2F PAD SI TESTS 07-13-20.xlsx; MIT KRU 1 D-38 SI TEST�07-13-20-.xlsx y""'AI I, Attached are Non Witnessed MITIA's performed in Kuparuk 7/13/20. Please let me know if you have any questions. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iintregn0alaska.gov: AOGCC.Inspectorsfalalaska.gov; phoebe.brooksealaska.cov OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT / PAD: Kuparuk / KRU / 2F Pad DATE: 07/13/20 OPERATOR REP: VanCamp / Weimer AO= REP: 60 Min. ch rismallace(ctalaska gov l 17117'1-;ro Well 2F-04 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fail PTD 1831900 Type Inj N Tubing 2120 2125 2125 2125 N = Not Injecting Type Test P Packer TVD 5765 BBL Pump 2.5 IA 225 3300 3225 3200 Interval V Test psi 3000 BBL Return 2.2 OA 90 90 90 90 Result P Notes: MITIA to maximum anticipated injection pressure per AIO 2B.074 Well 2F-14 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831590 Type Inj N Tubing 1500 1550 1550 1550 Type Test P Packer TVD 5857 BBL Pump 2.0. IA 225 3325 3260 3250 Interval V Test psi 3000 BBL Return 2.0 OA 60 60 60 60 Result P Notes: MITIA to maximum anticipated injection pressure per AI0 2CC64 Well 2F-16 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, PTD 1831720. Type Inj I N Tubing 1975 2025 • 2000 2000 Type Test P Packer TVD 5870 BBL Pump 3.0 IA 200 2760- 2675- 2650' Interval 4 Test psi 1500 BBL Return 2.8 OA 20' - 20 - 20 20, Result P Notes: Well 2F-16 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1831770 Type Inj N Tubing 2075 2075 2075 2075 Type Test P Packer TVD 5834 BBL Pump 3.0 IA 225 2860 2775 2750 Interval 4 Test psi 1500 BBL Return 2.8 OA 80 80 80 80 Result P Notes: Well 2F-21 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2141360 Type Inj N Tubing 2300 2300 2300 2300 Type Test P Packer TVD 6110 BBL Pump 2.4 IA 275 1800 1750 1725 Interval 4 Test psi 1528 BBL Return 2.4 CA 140 255 270 270 Result P Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Cotles W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas O= Other(desaibe in Notes) 4=Four Year Cycle F=Fail S=Slurry V= Required by Variance 1=Inconclusive I = Industrial Wastewater O = Other (descnbe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 2F PAD SI TESTS 07-13-20 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r DATE: Monday,August 29,2016 P.I.Supervisor ! e-11 n �(�f l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-15 FROM: Johnnie Hill KUPARUK RIV UNIT 2F-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jet-- NON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-15 API Well Number 50-029-21048-00-00 Inspector Name: Johnnie Hill Permit Number: 183-172-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826173550 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 2F-15 Type Inj W"TVD 5872 - Tubing 2610 2600 ' 2550 - 2575 - PTD 1831720 • Type Test[SPT(Test psi 1500_ IA 440 1960 . 1875 - 1840 Interval ;4YRTST P/F P ✓ OA 580 • 580 - 580 580 - Notes: �Ep , U 2 3201 SCAMonday,August 29,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, December 28, 2015 10:18 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly KRU injector 2F-15 (PTD 183-172) 11-28-15 update 12-28-15 Attachments: MIT KRU 2F-15 diagnostic MITIA 11-29-15.xls Chris, The MITIA to 3150psi and T&IC POTs on 2F-15 were performed on 11/29/15 and all passed. The well is nearing the end of its 30 day monitor period. With the exception of thermal fluctuations,the IA is no longer demonstrating the pressure fall-off as previously reported last month. Therefore the well is being returned to 'normal' classification. Please let me know if you disagree. Attached are the MIT file and most recent 90 day TIO file. %AWED SEP 1 92016 Well Name 2F-15 Notes: Start Date 9/29/2015 Days 90 End Date 12/28/2015 Annular Communication Surveillance 4000 - 69 _WHP IAP 3500 _OAP 68 WMT 3000 67 I 250066 as 2000 65 \A\ltivw G. A 1.\\ 1500 64 1000 63 JEJ 500 62 0 61 Sep-15 Oct-15 Oct-15 Oct-15 Nov-15 Nov-15 Nov-15 Dec-15 Dec-15 Dec-15 Jan-16 ssaa- O ® 5031 PYO d 31000- GtP6 SOC 0 Sep-15 Oct-15 Oct-15 Oct-15 Nov-15 Nov-15 Nov-15 Dec-15 Deo-15 Deo-15 Jan-16 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 2 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, November 28, 2015 10:21 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly KRU injector 2F-15 (PTD 183-172) 11-28-15 Attachments: 2F-15 schematic.pdf Chris, KRU WAG injector 2F-15 (PTD 183-172) is experiencing a drop off in IA pressure. The operator recently charged the IA and OA to establish a better dP across the two at a higher pressure on November 16, 2015. While the OA has maintained its pressure, over several days the IA pressure slowly dropped back to where it had been prior to the charge (down to 100psi). ConocoPhillips intends to perform initial DHD diagnostics to include an MITIA and packoff testing. If the MITIA passes, elevated pressure will be left on the IA and monitored for 30 days to ensure the pressure does not drop off again. If the MIT fails,the well will be shut in and freeze protected as soon as possible, with followup well intervention work with Slickline/Eline as appropriate.A followup email will be provided at the conclusion of the monitor period (or sooner if need be). Please let me know if you disagree with the plan. Attached is the schematic and 90 day TIO plot. SCANNED AUG 1 8 2016 1 • 4111 Well Name 2F-15 Notes: Start Date 8/30/2015 Days 90 End Date 11/28/2015 Annular Communication Surveillance .ccc - — 1z0 WHP 3500 OAP WHT — 120 _'CCC — 100 2SCC — 80 .;)" 2000 • — 60 1500 — 40 1000 500 — 20 v—. 0 0 Aug-15 Sep-15 Sep-15 Sep-15 Oct-15 Oct-15 Oct-15 Nov-15 Nov 15 Nov-15 Dec-15 Deo-15 2000 -earaNsi, OIri."145.1"M°..11.4%.0""" Ndlre"1".." . PYA d .wt CtDC Aug-15 Sep-15 Sep-15 Sep-15 Oct-15 Oct-15 Oct-15 Novi-15 Novi-15 Nov-15 Dec-15 Date Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907)659-7000 pgr 909 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg [� / DATE: Monday, June 18, 2012 P.I. Supervisor l f Z (i v SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F -15 FROM: Lou Grimaldi KUPARUK RIV UNIT 2F -15 Petroleum Inspector Src: Inspector Reviewed By: P.1. Supry NON - CONFIDENTIAL Comm Well Name KUPARUK RN UNIT 2F - 15 API Well Number 50 029 - 21048 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 183 - 172 - Inspection Date: 6/7/2012 Insp Num: mitLG120607105032 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F -15 • Type Inj W 'TVD 5872 IA 500 2000 - 1900 1875 - PTD 1831720 Type Test SPT Test psi 1500 - OA 340 . 460 480 480 - Interval 4YRTST P/F P - Tubing 2650 . 2675 2625 2625 Notes: 1.6 bbl's up, 1.6 down. Good stable test. - &AI MED JUL 2 5 2012 Monday, June 18, 2012 Page 1 of 1 • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 t ~ ~' ~~~ `~ ~' .', ~^{' .. _, Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 27 and October 30, 2008. The corrosion inhibitor/sealant was pumped November 2, 2008. The attached spreadsheet. p~esent.~.the.~vell xiame, .top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~ ~~~~~~ ~`' ~ i ~ ",` ~Du Perry ul ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field r1a+w 11 /3/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor. Corrosion inhibitor/ sealant date ft bbls ft al 2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008 2F-04 183-190 48" NA 48" NA 25.5 11/2/2008 2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008 2F-08 184-021 SF NA 20" NA 2.55 11/2/2008 2F-09 184-036 18" NA 18" NA 1.7 11/2/2008 2F-10 184-040 22" NA 22" NA 1.28 11/2/2008 2F-12 184-043 20" NA 20" NA 2.12 11/2/2008 2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008 2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008 To: Jim Regg ~~~ ~~ ~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-]5 KUPARUK RIV UNIT 2F-IS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~~~ Comm Well Name: KUPARUK RN UNIT 2F-15 Insp Num: mitRCN0 80707 1 42244 Rel Insp Num: API Well Number: 50-029-2 t o48-00-0o Permit Number: Is3-t72-o Inspector Name: Bob Noble Inspection Date: x/5/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ zF-1s (Type Inj. ~ ~ ~ TVD i ss72 i IA i azs z37o u9o j z19o ~ i P.T. ~ 1831720 ~TypeTest SPT Test pSl ~ 2370 +'~ QA I 110 100 ~ 100 100 ~ ~ Interval 4YRTST p~ P / Tllbing ~ 3800 i 3800 III 3800 i 3800 ~I Notes: ~~~N~~ AUG ~ ~ 20x8 Tuesday, July 08, 2008 Page 1 of l MEMORANDUM TO: ~k" . 7/ /? ,') 11"14- t'1 (l [,' f'- Jim Regg P.I. Supen'isor FROM: Lou Grimaldi Petroleum Inspector Well Name: KUPARUK Rl\' UNIT 2F-15 Insp Num: mitLGO-t07130955-t-t Rei Insp Num: State of Alaska Ala!\ka Oil and Gas Conservation Commission DATE: Wednesda~'. Jul) l-t. 2(10-t SlIBJECT: t\lechamcallmegrH) Tem CONOCOPHILlIPS .o\LASK..o\ INC 2F-15 KUPARL!1: RIV UNIT 2F-15 Src: Inspector NON-CONFIDENTIAL API \\'ell Number: 50-029-210-t8-(1)-OCt Permit Number: 18J-17::!-O Reviewed B,': -"""T""..~ P.I. Suprv J~ Comm Inspector Name: Lou Grimaldi I nspection Date: 7/ (J/20û-t Well 2F-I.5 IType Inj. P P.T. I 1831720 TypeTest SPT Interval .tYRTST P/F Notes: Good test. no problems, Packer Depth Pretest Initial 151\1in. 30 Min. 45 Min. 60 1\1 in. TVD I 6522 ! IA 1600 1880 18iO 1865 1_-= Test psi I 1.t68 lOA 160 160 160 160 I P Tubing 2-100 2.tÜÜ 2.10Ü 2.tOO I Wednesday. July 14.2004 Page I of I MEMORANDUM TO: Dan Seamount CommiSsioner THRU: Blair W°ndzell P.I. Supervisor FROM: John Cri~p Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: SePtember 28, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2F Pad 15,16,17 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL ~ ' Pa(~l~er Depth Pretest Initial 15 Min. 30 Min. I WellI '2F-15 [Typelnj.I G I T.V.D. i 5872 I Tubing[ 3850 I '3800 I 3800 [ 3800 [IntervalJ ~t / P.T.D.I 18§1720 ITypeteStl P I Testpsil 1468 ICasingI 1000 I' 1650l 1640 I' 16301 P/F I P'I' Notes: - I We"l ~-~ I'~.~e'~'l ~ I~-'v'o"l ~ I~u~''~ I~°° I~°° I ~oo I~0o I,n~e~.,l' ~' P.T.D.I 1831770 ITypetestl P ]TestPsiI ~459 I Casingl 1025 I 1740 I 1720 I 1720I P/F i E'~ Notes: -IType,nj.I N I T.V.D. I 57~7'~TubingI 1840 11860 11850 J 1825 [Inte~alI 4 / we~I 2F-16 [~ypetestl P I Test~sil 1~29 ICasingI ~775I 2500I 5200I 2490 J ~F'I P ~ P.T.D.I 1962040 Notes: · WellJ J Type ,nj.I ! ~.v.o. 1' ' ITubingI I I I J lntewalJ P.T.D.J JTypetestJ ' J Test psiJ I casing J J I I I P/F I Notes: ' WellJ P.T.D.J N~: Type INJ.' Fluid Codes F = FRESH WATER INJ. 'G=GASINJ. : S = SALT WATER INJ. 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 dudng Workover O= Other (describe in notes) Test's Details I traveled to Phillips KRU to witneSs 4 year MIT's on 2F Pad. All teSts successful, no problems. .I.T/s performed: 3 Attachments: none Number of Failures: 0 Total Time during tests: 1.5 hrs. ,cc: MIT report form 5/12/00 L.G. MIT KRU'2Fb 9-28-00jC.xls 10/3/00 ADDENDUM WELL: 2F-15 12/19/83 1/9/84 9/10/84 9/18/84 9/22/84 9~24~84 Arctic Pak w/~ sx AS I, followed by 53 bbls Arctic Pak. Rn GR/CBL/CCL f/7442'-3000'. Rn gyro f/surf-7742'. 7442' PBTD Rn CCL/temp pre-frac logs f/7200'-6720'. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1411 hrs, 9/18/84. B. J. Hughes frac'd 2F-15 "A" sand perforations by pmp'g 40 bbls hot diesel w/5% J-40 @ 17 BPM w/4840 psi. Pmp 20 bbls HoO/gel @ 17 BPM w/4450 psi; 25 bbls of 1 ppg 100 mesh (%000#) @ 17 BPM w/4000 psi; 50 bbls of H~O/gel @ 18 BPM w/3180 psi; 25 bbls of 2# 12-20 sand (2000~) @ 12 BPM w/2600 psi; 46 bbls H?O/gel of 8 ppg 12-20 sand @ 12 BPM w/2500 psi (total sand = 11,400#). Flush w/gel diesel. (Note: Bbl counter & rate/min failed @ start of flush. Pmp flush by calculating time. Found vlv open on ribbon blender to be cause of counter failure during flush. Lost 11 bbls to blender.) Est flush = 50 - 55 bbls. Pmp est 65-70 bbls diesel/gel & SI w/ISIP = 2000 psi. 15 min SI = 1670 psi. Rn Temp/CCL, tag H?0 @ 3400'. Cont in hole, stack out @ 6900'. Indicates 31 bbl displacement. Ck sand fill inside tbg "A" sand perf's: 7007'-7018' and 7035'-7069' RU S/L, tst BOP & lub to 2500 psi. RIH w/sinker bars, tag fill @ 6490', POOH, RD. 7234' PBTD Ck sand fill inside tbg "A" sand perfs: 7007'-7018' and 7035'-7069' RIH w/CTU, circ w/40# gelled diesel @ 6400' @ 1-1/4 BPM, 4000 psi; tag fill @ 6491', circ dn to 7207'. Circ dn 10 bbl pill gelled wtr, 20 bbl gelled diesel spacer, 10 bbl gelled wtr pill. Displ pills out of hole while pulling up into tbg. Stop circ @ 150', rec'd heavy sand. RD CTU, SI well. (cont'd.) ADDENDUM WELL: 2F-15 9/26/84 7234' PBTD AFE 404161 RU S/L, tst lub & BOPE to 2500 psi. RIH w/WL, tag bridge in tbg @ 6784' (tbg tailpipe @ 6854~'), POOH. Flow well to tst tank to remove obstruction in tbg. Produced 25.5 bbls. SI well. RIH w/S/L tls, tag fill @ 7097' (btm perf's @ 7069'). SI well, ready f/production. Drmllmng Supermntendent ' Dante ~ ADDENDUM WELL: 2F-15 12/19/83 1/9/84 9/10/84 9/18/84 9/22/84 9/24/84 Arctic Pak w/~ sx AS I, followed by 53 bbls Arctic Pak. Rn GR/CBL/CCL f/7442'-3000'. Rn gyro f/surf-7742'. 7442' PBTD Rn CCL/temp pre-frac logs f/7200'-6720'. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1411 hrs, 9/18/84. B. J. Hughes frac'd 2F-15 "A" sand perforations by pmp'g 40 bbls hot diesel w/5% J-40 @ 17 BPM w/4840 psi. Pmp 20 bbls HoO/gel @ 17 BPM w/4450 psi; 25 bbls of 1 ppg 100 mesh (%000#) @ 17 BPM w/4000 psi; 50 bbls of H~O/gel @ 18 BPM w/3180 psi; 25 bbls of 2# 12-20 sand (2000~) @ 12 BPM w/2600 psi; 46 bbls H?O/gel of 8 ppg 12-20 sand @ 12 BPM w/2500 psi (total sand = 11,400#). Flush w/gel diesel. (Note: Bbl counter & rate/min failed @ start of flush. Pmp flush by calculating time. Found vlv open on ribbon blender to be cause of counter failure during flush. Lost 11 bbls to blender.) Est flush = 50 - 55 bbls. Pmp est 65-70 bbls diesel/gel & SI w/ISIP = 2000 psi. 15 min SI = t670 psi. Rn Temp/CCL, tag H 0 @ 3400'. Cont in hole, stack out @ 6900'. Indicates ~1 bbl displacement. Ck sand fill inside tbg "A" sand perf's: 7007'-7018' and 7035'-7069' RU S/L, tst BOP & lub to 2500 psi. RIH w/sinker bars, tag fill @ 6490', POOH, RD. 7234' PBTD Ck sand fill inside tbg "A" sand perfs: 7007'-7018' and 7035'-7069' RIH w/CTU, circ w/40# gelled diesel @ 6400' @ 1-1/4 BPM, 4000 psi; tag fill @ 6491', circ dn to 7207'. Circ dn 10 bbl pill gelled wtr, 20 bbl gelled diesel spacer, 10 bbl gelled wtr pill. Displ pills out of hole while pulling up into tbg. Stop circ @ 150', rec'd heavy sand. RD CTU, SI well. (conc'd.) ADDENDUM WELL: 2F-15 9/26/84 7234' PBTD AFE 404161 RU S/L, tst lub & BOPE to 2500 psi. RIH w/WL, tag bridge in tbg @ 6784' (tbg taiipipe @ 6854'), POOH. Flow well to tst tank to remove obstruction in tbg. Produced 25.5 bbls. SI well. RIH w/S/L tls, tag fill @ 7097' (btm perf's @ 7069'). SI well, ready f/production. Drillfn8 Superintendent ' Da're STATE OF ALASKA .... . ALAL....~, OIL AND GAS CONSERVATION CON,. $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate © Plugging ~ Perforate [] Pull tubing Alter Casing ~ Other ,~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 127' 3. Address 6. Unit or Property name P.0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 7. _l nu ber 4. Location of well at surface 143' FNL, 1736' FEL, Sec.33, T11N, RgE, UH At top of productive interval 1311' FNL, 1001' FWL, Sec. 34, T11N, RgE, UM At effective depth 1425' FNL, 1156' FWL, Sec.34, T11N, R9E, UM t total depth A1450' FNL, 1189' FWL, Sec.34, T11N, R9E, UM 8. Approval number 7-28 9. APl number 50w 029-21048 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7550 ' MD 6522 ' TVD 7442 'MD 6422 'TVD feet feet feet feet Plugs (measured) None Junk (measured) 208' Vann Gun Fish ~ PBTD Casing Length Size Conductor 109' 16" Cemented 150 sx CS I I Measured depth 109 ' MD True Vertical depth 109 ' TVD Surface 2896' 9-5/8" Production 7526' 7" 850 sx AS III & 650 sx Class G 250 sx AS I & 260 sx Class G 2896'MD 7526'MD 2741 ' TVD 6500 ' TVD Perforation depth: measured 7007'-7018' 7035'-7069' true vertical 6019 ' -6030 ', 6045 ' -6076' depth) uio_q,(size.~rade and measured -l/D, J-5~, tbg w/tail ~ 6876' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 6844' & TRDP-1A-SSA SSSV ~ 1809' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associate Engineer (DANI) SW02/008 Date Form 10-404 Rev. 12-1-85 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "FIl~al~Rel~3rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also whsrl ol3eratione are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completioI! and represelltative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ~County or Parish State Alaska I; North Slope Borough Alaska Kuparuk River ADL 25657 Auth. or W,O. no. ITitle AFE AK1959 I Completion Nordic 1 API 50-029-21048 Operator I A.R.Co. W,I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Complete J 1/24/87 Date and depth as of 8:00 a.m. 1/26/87 ,Complete record for each day reported rrotal number of wells (active or inactive) on this ~cost center prior to plugging and ~ Jabandonrnent of this well ~Hour I Prior status if a W,O. 7" @ 7526' 7442' PBTD, RR 6.8 ppg diesel Accept ri~ @ 1815 hfs, 1/24/87. Displ well w/brine, ND tree, bTU & tst BOPE. RIH w/RTTS, set pkr & sting out. ND BOPE, chg_ tree to 5000 psi. NU & tst BOPE. Pull RTTS. POOH w/3½" tbg chg out couplings. RIH w/214 its, 3½", 9.2#, J-55 EUE 8RD AB-Mod tbg & lnd w/SSSV @ 1809', HRP-1-SP pkr @ 6844', & TT @ 6876~ Press tst tbg/ann to 2500 psi. Tst SSSV. ND BOPE, NU tst tree to 5000 psi. Displ well w/diesel. RR @ 0600 hrs, 1/26/87. Old TD Released rig 0600 hrs. Classifications (oil, gas, etc.) Oil TD INew IPB Depth 7442' PBTD IDate IKind of rig 1/26/87 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas ITest time Production Oil on test Gas per day Pump size, SPM X lenglh Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Theab~e~i t ....... IDate ITM Sign ure ' --' sF~; f~rro~2~epa~d .... '-~a:u:,n.%dei¢st'r~b~'lO~.n' ~/"/ o'~/~ ~ Drilling $.petwisor DrilHng, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively Page no. I as they are prepared for each well. I 1 DIvlIJo~ of AllantlcRIchfleldCompa~ ' " STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM. 51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon rq Suspend ...-3 Operation Shutdown ,~ Re-enter suspended well F~ Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate ~, Pull tubing, '~. Amend order ,_-. Perforate- Other 2. Nal;g.e...of~ .Operator ~K~.u ~lasKa, /nc. 3. Address, ~-.u. ~ox 100360 Anchorage, AK 99510-0360 4. Location of well at surface 143' FNL, 1736' FEL, Sec.33, T11N, R9E, UM At top of productive interval 1311' FNL, 1001' FWL, Sec.34, T11N, R9E, UM At effective depth 1425' FNL, 1156' FWL, Sec.34, TllN, R9E, UM At total depth 1450' FNL, 1189' FWL, Sec.34, T11N, R9E, UM 5. Datum elevation (DF or KB) RKB 127' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Permit number 83-172 9'. APl number 50-- 029-21048 10. Pool 3(uparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 7550 ' MD 6522 'TVD Casing Conductor Surface measured 7442 'MD true vertical 6422 'TVD Length Size 109' 16" 2896 ' 9-5/8" Production 7526' 7" feet feet feet feet Plugs (measured) None Junk(measured) Cemented 150 sx CS II 850 sx AS III & 650 sx CI'G' 250 sx AS I & 260 sx CI'G' Perforation depth: measured 7007'-7018', 7035'-7069' true vertical 6019'-6030', 6045'-6076' Tubing (size, grade and measured depth) 3-1/2", J-55, ~ 6878' Packers and SSSV (type and measured depth) HRP @ 6844' & TRDP-1A ~ 1807' 208' Vann Gun Fish ~ PBD Measured depth 109'MD 2896'MD 7526'MD True Vertical depth 109 ' TVD 2741 'TVD 6500'TVD 12.Attachments Description summary of proposal,~ Detailed operations program -- BOP sketch/~ 13. Estimated date for commencing operation February 5~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Commission Use Only (JLQ)$A/205 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI , ,, Approved by Date feet /~'~ by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Workovers Coupling & Wellhead Changeout Without Pulling Packer Preliminary Procedure and Cost Breakdown Pre-Rig Arrival Operations 1. Set positive plug in 'D' nipple & test same. Bleed pressure off tubing and annulus. 2. Pull gas lift valve from 1st mandrel above retrievable packer. 3. Circulate kill weight fluid. Test wellbore to 1000 psi. Rig Operations 1. Move in, rig up workover rig. 2. ND tree. NU BOPS & test same. 3. Pull tubing free from packer. POH 2 stands. 4. PU storm packer &MU same into tbg string. 5. GIH 1 stand. Set storm packer. Rel f/same & test to 500 psi. POH. 6. ND BOPS.Changeout wellhead to 5000 psi equipment. NU BOPS. 7. GIH & latch storm packer. POH with same. 8. Fin POH with tubing. LD GLMs & changeout couplings to AB MOD while POH. 9. Re-run completion assembly with reconditioned AB MOD GLMs. 10. ND BOPS. NU tree. 11. Displace well to diesel. 12. Release rig. 13. Move in, rig up slick line unit. ~- . 14. Pull plug from 'D' nipple. TOTP~. Anticipated Bottom Hole Pressure: 3100 psi Completion Fluid: 10.2 ppg NaC1/NaBr Brine ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAMS TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO $000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, ! 3. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY ii.;~ '~ ': · dO dULY 28, 1986 (NORDIC RIO 9-5/8") ARCO Alaska, Inc..~.~-'-~. Post Office _ ,100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed on the 1F-4 1F-5 1F-8 1G-3 1G-4 1L-3 1L-5 1Q-8 1Q-12 1Q-14 1R-3 1R-10 1Y-? 1Y-10 1Y-15 1Y-13 2B-6 2B-8 2B-11 2B-12 2C-2 2C-4 2C-5 2C-7 2D-4 2D-5 2F-3 2F-4 2F-15 2F-16 2D-10 2D-16 Conversion 10/24/85 Conversion 10/24/85 Conversion 10/24/85 Conversion 10/25/85 Conversion 10/25/85 Conversion 10/24/85 Conversion 10/24/85 Conversion 10/25/85 Conversion 10/25/85 Conversion 10/25/85 Conversion 10/26/85 Conversion 10/26/85 Conversion 10/26/85 Conversion 10/26/85 Conversion 10/26/85 Conversion 10/26/85 Conversion 11/5/85 Conversion 11/5/85 Conversion 11/5/85 Conversion 11/5/85 Conversion 11/6/85 Conversion 11/6/85 Conversion 11/6/85 Conversion 11/6/85 C'onversion 11/6/85 Conversion 11/6/85 Conversion 11/2/85 Conversion 11/2/85 Conversion 11/2/85 Conversion 11/2/85 Conversion 11/6/85 Conversion 11/6/85 -~-i_ ARco Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E3X OTHER [] 3. Address O. BOZ 10 0 3 6 0, ANCHORAGE, ALASKA 99510 TI iN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. 7. Permit No. 83-172 8. APl Number 50- 029-21048 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2F-15 11. Field and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RIVER OIL ADL 25657 ALK 2583 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). On November 2, 1985 Kuparuk well 2F-15 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED 0Ii & 6as C0rls. Com~issior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/,~ ~/c4,~ Title KUPARUK OPERA'?TONS The space below for Commission use Conditions of Approval, if any: Date COObLU YNA'I'OR 12/04/85 Approved by 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 L-_.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to.be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the CommissiOn in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: . J. F. Beall TMD:ps:013 RECEIVED 0~ & G~s Co~s. Commission AnChorage ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichlieldCompany STATE OF ALASKA ALASK,~'L AND GAS CONSERVATION C'~-'!MISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, :[nc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well · N/A COMPLETED WELL OTHER [] 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool N/A I see attached 12. 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). Pursuant to form 10-403, it is proposed that the attached list of~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will 'be into the A and C sands. sEP 2 o 19 5 AlaSKa Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~ ~~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 ~kpprove~l Copy ,Returne~ / By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 " 2580 12/15/85 20970 " " 10/15/85 20974 " " 12/15/85 029-21177 25653 2579 12/15/85 21176 " " 10/15/85 21157 " " 10/15/85 21169 " " 12/15/85 21135 25658 2584 10/15/85 21134 " " 12/15/85 21183 " " 12/15/85 21185 " " 10/15/85 029-21246 25658 2584 12/15/85 21227 " " 12/15/85 21213 " " 12/15/85 21214 " " 12/15/85 029-21058 25657 2583 12/15/85 21063 " " 12/15/85 21062 " " 10/15/85 21065 " " 10/15/85 21032 " " 12/15/85 21035 " " 12/15/85 21048 " " 10/15/85 21052 " " 10/15/85 029-21150 25656 2582 12/15/85 21165 " " 10/15/85 21119 " " 10/15/85 21124 " " 12/15/85 21140 " " 10/15/85 21159 " " 12/15/85 21163 " " 10/15/85 029-21269 25644 2575 10/15/85 21270 " " 12/15/85 21283 " " 10/15/85 21303 25643 2574 10/15/85 21262 " " 10/15/85 21264 " " 12/15/85 029-21037 25655 2581 10/15/85 21041 25644 2575 10/15/85 21051 " " 10/15/85 21054 " " 12/15/85 21055 25655 2581 10/15/85 21061 " " 12/15/85 029-21279 21275 21208 21228 21235 25642 2573 10/15/85 " " 12/15/85 " " 12/15/85 ,, ,, ~ ,~k2/15/85 !1 ~1 ECEIV ARCO. Alaska, Inc: Post Office B 100360 Anch. orage, Alaska 99510-0360 Telephone-907 276 1215 --',1'"~.~ 4 ./... .... '.... ~ -""~ I'"~ .,,[ .'.:~: C-'- i · 2 ('2 .... ~ .% ?'-'-.-i ,5 ~' :.~% · ~.~ tT ..~ 4 ~._ ~..;; ' ' -i ...> :':r-- i T..' ..; t3' "- ..3 ~.~. .... "7-~ ~'_ %"¢ I z. .... :.. 2U'- ! 6-,' -' C: :7. V .,-~': t-~ ~ 2:::'--~ r.~-'~ .~' · .-z.. ,-" i x' · .'...-'~." '~ 3 ~ :"~ '-...' ~ ..... ~-. '" i · . .'.':.:iT' 0 "f' :!: ,% ¢"~ ":" T -" ' :2 "f' ]: ,?. rj 'f' :[: S' ,... "" "-' ~ ' "HB/R ~1,.. ...... _. -!. ~.. ¢; ,... -~'T.T .? El. TI ~ 0 T ]: ,:-?. ~.jTT '--.'7 ,-i "r 'T ~ (:)'T'I %./ : .;. ,.:- .,. i.: C,T '-::~ T :~..7 F' .r:: U F'DU E,'. H F' DI-'I .:?-f'AT ]: C t-, ,-, -. , I'" -" '~ ,_I f"l ?, , ~-',l:- F r.: 0 R F , ,'~. I't :_- .... F' .,'T 'T'~ IT::-'ri-/.G F"-;'"' ...... ,_.,, FI:;,' A C E:H ,"r- 'FAT I C 30UI;,'CE W,'-'-'iTER W¢'..:TH RUN 6LV ' ,7 F.'. U N r.: I-. V' Y F'U'l.... Ir-:, F B H F' F _,:,U OPEN ' C' YANi:,,/YT¢-,T:[C F', T, '~ U]:,' I i'-!G/F'RE--FF,'AC PREP. FOR 'C.., ' "'Ai',~D/,gl'AT.T..C :--'. ! · "'T:-"TC T'~I..IF'.,/'._..'i:At;!!) ONLY ~- ,-I'*1 I .. F'F:EF' ~..'nF: F.'RA~' F'L!I_L. D"/' ,~?RU.N :.., '-... B H F' ( I N :1: T :[ A I_ '~ F-,' I:-I F.:' ARCO Alaska, _Inc..is a Subsidiary of AtlanlicRichlieldCompany /- ARCO Alaska, Ine--~ Post Offic6 ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 f' Tr.~wnsmitted herewith are the following items. Please acknowledge receipt /,~nd return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-lw~' 10/16/84' '"Static" SBHP 2B-i~ .... 10/17/84 " " 2B-2~~'~' 10/17/84 " " 2B-6M-~- - 6/02/84 " 2B-10~-~ 6/02/84 " 2~-11~:~ 6/o3/84 " 2B-12~- 6/02/84 " 2B-14~-~ 10/28/84 " " 2B-13y~ 10/28/84 " " 2D_5_A ~ 10/05/84v ,, ,,. 2G-l~ ~ 9/21/84 "Static/G. Ring" 2G-2 ~ ~ 9/22/84 " " 2G-3-~ 9/23/84 " " 2G-4 ~ 9/23/84~ " " 2G-8 ~-- 9/30/84 2F-15~- 4/13/84 2X-13~ -12/18/84 2X-14~' 12/21/84 2X-15~ .... 12/23/84 2X-16~-'12/21/84 "St&tic/G. Ring/Tag;' SBHP Receipt Acknowledged: 1B-3~-~' ¢/26/84 lB-4 ~-"~..,6/26/84 lB-6 ~; '..7/0~/84 1E-2 w"¢ 6/22/84 1E-7 ~ ~'~/14/84 1E-4 ~-- 10/15/84 1E-12~ 6/24/84 1E-20X-- 6/23,22/84 1E-22~--4/23/84 1E-25~-~ 6/23/84 1E-25~ 11/09/84 1E-29~ 6/23/84 1E-29} 10/14/84 1F-4 ~-- 9/14/84 1~-4 ~ ..... 9/14/84 1F-7-x '" 7/05/84 1F-11~"' 4/.25/84 1F-14x ...... 2/07/84 1F-15~ 2/14/84 1G-l, ..... 6/29/84 ¢iG-i~-- 9/13/84 /1G-3'.~~'' 5/16/84 . ¢1G-5," 6/29/84 1H-4~-' 6/24/84 1Y-3't-- 1/21/84 1Y-5~"'" 5/06/84 1Y-9!¢''- 5/06/84 .1G-14.--" 1/12/84 1L-2~'-- 10/21/84 tL-3-~~ Date: DISTRIBUTION B. Currier Drilling W, Pasher BPAE Geology G. Phillips Chevron Mobil Phillips Oil D&M NSK Ops. J. Rathmell SBHP " "Static" " "Static" ,I " I1 II ,1 ,I II I, II " "Static" ,1 ,, II fl '' ,, !1 Il I1 11 !I I1 Il Il State Union Well Files ARCO Alaska, In~-- Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P. O. ~x/ 100360 y orage, AK 99510 ' . ~ /T/~nsmitted herewith are the following items. Please acknowledge receipt rand return one signed copy of this transmittal. OTIS PBU SURVEYS 2W-8/ 1/08/85 lB-7 '-- 12/14/84 2F-12 1/06/85 2F-5 ~ 1/02/85 2W-5 -" 1/07/85 ~2W-6 -' 1 / 07 / 8 5 12W-7 -" 1/07/85 i lA-1" 12/31/84 lA-1 12/15/84 /lA-1 12/23/84 ~iG-5.-- 12/25/84 2F-3~ '12/31/84 2V-8A ~ 12/16/84 2B-10' 12/17/84 1Y-9~' 12/20/84 -~1 C-.r~ 12/10/84 2F-2 ~' 12/29./84 2F-15 ..... 1/05/85 2F-14-- 1/04/85 2F-9 _i 1/02/85 2F-8 -~ 1/01/85 API 029-21228 '029-2D616 02 9-21097 029-21073 -- 029-21220' -- 02 9-05900 -- : 029-20908 0~9-21178- 029-21084 029-20935 f.. '~ 029-20564"-/6- ,2~~,~_:.~Z-~_. Z-~'~-~~-~ 029-21 063 02 9-21048 029-2~.090 029-21077 CAMCO PBU SURVEYS 1E-12 ~ 12/14, 16/84 /cat Receipt Acknowledged: ;,nchoraco DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Ratkmell Well Files ARCO Alaska. Inc. is a subsidiary ol AtlanllcRichfieldComnanv ARCO Alaska. Inc. ,-- '.:'~- ~:-L:: -:. -; ;;c:,~. S'::- 277 5937 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 1C-5 " " 1C-6 Gas Disp. 1C-7 PBU 1C-9~Falloff Test 1C-10~ " " 1D-1 Static BHP 1D-5 Falloff Test 1E-12 Flow BHP/GLV 1E-17 Static BHP 1E-18 " " 1E-24 Injectivity 4/12/84 Camco 4/13/84 " 5/16/84 Otis 4/20~21 Camco 4/29/84 " 5/06/84 " 4/19/84 " 4/29/84 Otis 7/01/8484 Camco 1/8-11/84 Otis 1/03/84 " 6/21-22/84" 2F-8 T Log PBU 2F-11 Initial PBU 2F-12 Initial Well 2F-13 " " 2F-14 PBU 2F-15 PBU State /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron 5/06/84 Otis 5/22/84 Camco 5/15/84 " 5/14/84 Ot±s 5/03/84 " 4/26/84 Camco D&M DISTRIBUTION W.V. Pasher Dzilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union NSK Operations R&D Well Yiles KUPARUK ENGINEERING Date: ~0~ We Z Transmittal Log DISTRIBUTION NSK Operations Dr il 1 ing Geolbgy /Ken Blueline Bluel ine Film Blueline & Sepia Date Run ~L Sign & return the attache ce',~'/'~ o:1: dat,,a. ,, ..-~ . -., ,,~, ,, of copy as re-P/ /~'~'-~~ rn to: ARCO A~S~, lng. ATO-lllSB P.0. Box ~00360 Anchorage, AK 995~0 ARCO Alaska, Inr~-'~ Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 4, !984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2F-15 Dear Mr. Chatterton- Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Associate Engineer JG' tw GRU6/L83 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK. jIL AND GAS CONSERVATION (.-_.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL Yl~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8:5-172 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21048 4. Location of well at surface~=--~-_~ ~ 9. Unit or Lease Name 143' FNL, 1736' FEL, 5ec.33, T11N, R9E, UM ~LOCAT~OIqSi Kuparuk River Unit At Top Producing Interval_ ¢" ~' 10. Well Number 1311' FNL, 1001' FWL, Sec.34, T11N, RgE, UH !Sur.~- ¢-~-~ 2F-15 At Total Depth i5.14. __3¢~! 11. Field and Pool 1450' FNL, 1189' FWL, 5ec.34, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKB ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/08/83 12/18/83 03/19/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ I-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7550'MD,6522'TVD 7442'MD,6422'TVD YES [] NO [] 1807 feet MDI 1400' (approx) 22. Type Etectric or Other Logs Run D IL/SFL/SP/GR, Cal/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 150 sx CS II 9-5/8" 36.0#/47.0# J-55/L-80 Surf 2896' 12-1/4" 850 sx AS Ill & 650 sx Class G 7" 26.0# J-55 Surf 7526' 8-1/2" 260 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7007' - 7018' w/12 spf 3-1/2" 6878' 6844' 7035' - 7069' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of OPeration (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE /~.!::t!,'.~ Od .~% Gas r:~,¢,,..~,.... ComrnJssJort Form 10-407 Submit in duplicate Rev. 7-1-80 GRU6/WC09 CONTINUED ON REVERSE SIDE 29. -' ' : .'-!" GEOLOGic. MA:RKERs ' .'~i_i i'!' ~_; :~ ? ,.... ': " .~' ~-' ~' FOF~MA~i'ON TESTS' . . NAME Include interval tested, pressure data, all fluid~ recovered and gravity, . MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6944' 5962' Base Upper Sand 6951' 5969' N/A Top Lower Sand '6993' 6007, Base Lower Sand 7124' 6127' . . . 31. LIST OF ATTACHMENTS Drilling Histor)'~ Completion Summary, GyroScopic Survey (2 copies) 32. I h~reby certify that the foregoing is true and correct to the best of my knowledge Signed Title Ar~ ~r~ll~n~ ~'n,,- 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,Zvvater supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion)~ so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of OperatiOn. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". 2F-15 DRILLING HISTORY NU 20" Hydril & diverter and tstd same. Spudded well @ 1400 hrs, 12/08/83. Drld 12-1/4" hole to 2938'. Ran 70 jts 9-5/8" 36f~ & 47f~ J-55 & L-80 HFERW BTC csg w/shoe @ 2896. Cmtd 9-5/8" csg w/850 sxs AS III & 650 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND 20"hydril & diverter. Installed 9-5/8" packoff. NU BOPE & tstd to 3000 psi - ok witnessed by Ben LaNorman AOGCC rep. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 11.5 ppg - EMW - ok. Cont drlg 8½" hole to 4209'. Set stringers, performed squeezed using 60 sxs AS I and 100 sx class "G" cmt. Set cmt plugs from 2976 to 2796. Performed from leak off test to · 12.5 ppg EMW. Side tracked old hole @ 2938. Cont drlg 8½" hole to 7400'. Ran ~logs DIL/SFL/SP/GR f/7400' to 2896'. CAL/FCS/CNL f/7400" to 6740. Continue drlg 8½" hole to 7550 TD as of 12/18/83. Ran 172 its 7" 26f~ HFERW BTC csg w/shoe @ 7526. Cmtd 7" csg w/260 sx Lone Star "G". Bumped plug w/3000 psi - floats held - ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. ND BOPE. Instld 7" packoff and tstd to 3000 psi - ok. Leave top of 7" csg void for freeze protection. Secured well and released rig @ 2400 hrs on 12/18/83. HILL/DH71 1/12/84 2F-15 COMPLETION SUMMARY RU GO/Eastman Whipstock. Removed adapter flange & master valve. Ran GR/CBL/CCL f/PBTD - 3000'. Ran Gyro. Installed adapter flange & master valve. RD GO/Eastman Whipstock. Secured well. Accepted rig @ 1100 hrs, 03/17/84. Removed adapter flange. NU BOPE & tstd to 3000 psi - ok. Ran 3-1/2" completion assy w/tail @ 6878', pkr @ 6844' & SSSV @ 1807' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel ~ 244 bbls crude oil. Dropped bar & perforated the following intervals- 7007' - 7018' 7035' - 7069' w/12 spf Flowed well. SI. Dropped ball. Tubing gun release sheared out. Pumped 9 bbls diesel down tubing for freeze protection. Set BPV. Secured well & released rig @ 1200 hrs, 03/19/84. GRU6/CSO5'tw ARCO Alaska, Inc Post Office ~,.~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 2, 1984 Mr. C. V. Chatterton Commi s s i on e r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-15 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, j~. Gruber Associate Engineer GRU6/L72'tw Enclosure If P, EC. EIVED .APR 984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc, 83-172 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21048 4. Location of Well Surface: 142' FNL, 1736' FEL, Sec.33, T11N, R9E, UM 5. Elevationinfeet(indicate KB, DF, etc.) 127' RKB 12. I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-15 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU GO/Eastman Whipstock, Removed adapter flange & master valve, Ran GR/CBL/CCL f/PBTD - 3000', Ran Gyro, Installed adapter flange & master valve, RD GO/Eastman Whipstock, Secured well, Accepted rig ~ 1100 hrs, 03/17/84. Removed adapter flange. NU BOPE & tstd to 3000 psi - ok. Ran 3-1/2" completion assy w/tail @ 6878', pkr @ 6844' & SSSV ~ 1807'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel & 244 bbls crude oil. Dropped bar & perforated the following intervals: 7007' - 7018' 7035' - 7069' w/12 spf Flowed well. SI. Dropped ball. Tubing gun release sheared out. Pumped 9 bbls diesel down tubing for freezel protection. Set BPV. Secured well & released rig @ 1200 hfs, 03/19/84. RECEIVED APR ~-;~ tg~!~ Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby,q,e~fy that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri l 1 ing Engineer The spac~elo~ ~/Y/~Smmission use Cond.t~ns of A p~val, if any: By Order of Approved by. COMMISSIONER the Commission Date .......... Form 10-403 Rev. 7-1-80 GRUG/SN28 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ' ALASKAOIL AND GAS CONSERVATION COMMISSION ./~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Water Injector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-172 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21048 , ,, 4. Location of well at surface 9. Unit or Lease Name 143' FNL, 1736' FEL, Sec.33, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1311' FNL, 1001' FWL, Sec.34, T11N, R9E, UM 2F-15 , At Total Depth 11. Field and Pool 1450' FNL, 1189' FWL, Sec.34, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKB ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 18. No. of Completions 1 2/08/83 1 2/1 8/83 03/19/84* N/A feet MSL 1 17. Total Depth (M D+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7550'MD,6522'TVD 7442'MD,6422'TVD YES [] NO [] 1809 feet MD 1400' (approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR, Cal/FDC/CNL, GR/CBL/CCL, Gyro, CCL/Temperature log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 109' 24" 150 sx CS II 9-5/8" ~56.0#/47.0~ J-55/L-80 Surf 2896' 12-1/4" 850 sx AS Ill & 650 sx (lass G 7" 26.0# J-55 Surf 7526' 8-1/2" 260 sx Class G & 150 sx ~S I. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7007' - 7018'MD w/12 spf 3-1/2" 6876' 6844' 7035' - 7069'MD 6019' -6030 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6045'-6076'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL ~J~;ED See attached Addemum, dated 10/11/84. for Fracture ~at~. ,, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATI~'R-BBL cHOKE SIZE IGAs-OILRATIO I TEST PERIOD I~ Flow Tubing Casing P~essure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (Corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE *Note: Drilled RR 12/18/83. Well n~.rfnrat-~rl ~, ~'..Hinn .... n'~/lq/R~, We]-]- wor]~ect o~ze~c 1/9.6/86. Form 10-407 Rev. 7-1-80 CONTINUED ON Submit in duplicate GEOLOGicMAR~IS ;i~::~',.~'.-.' ~ ! · : 'i'FORMATIONTESTS · ~.,~ ' ~ ~ . ~ . ~ :~ ~ .,%-; ?~ ~ .~.,-,:; .,-.., .,: ~ . . - .. :~ :;. . ;- ...... :..r .~.. ., : ~ '. .... .~ ., ,. -: .~ ~- . - .: . .-~.-. ~ .. :, .~:. . . .-..... - . .... : , · . . . - . ., , '. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , Top Upper Sand .69/+/+" 5962~ N/A , . · Base Upper Sand 6951' 5969~ Top Lower Sand : ~ 6993~ 6007' . Base Lower Sand 712b,~ 6127~ . · . , 31. LIST OF ATTACHMENTS AddendUm, (dated 10/11/8/+), 32. I hereby certify that the foregoifig is true and correct to the best of my knowledge Signed (~ ~/?/'~,/ ~ Title Associate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and-leases in Alaska. Item 1' Classification of ServiCe Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARE 0 AI.._AE.;t::;A., '1; I',.tC, I:":-' A f..) :2. F.., W [.:.; L I... N 0: 1 .':5 '.;.:.; I G M A'.'.. G Y R 0 ,._ 0 B N 0: A 01 :.=.: 4. Z 02 ;.--". 4. I.:::I...II:'¢..~RUI.::: I::IELD, NORTH SLOF'E, ALASI-:::A '..~!;IGMA'.-GYRO,, 0.--740:2.~ MD., SIJRVEYOR: ,_IAHN/CORAM... DATE RLIN: ,O :E: .- ,_I A N - L'-: 4- S I GI"I f& 1 / ._ Nr", /.:,/_':,:2.., F'F~r] BE N 0: 0/:, 4. I::' 0 R E '.-S; :[ G F.I T : '..:..:'? 4 E: E SI..IRVLSY 'T~I':::EN FI::~[IM t,,IELL.[..IE(~}[:I VERT :[ CAL .=,E _. T I IZ~N C:AL~"':I_ILATED I Ixl F'LANE CIF F'RCIPO'.=;AL . r._~IRE:r':TION: ".=_; 68 [IE6. 55 MIN, E RECORD OF '.=;URVEY Rf~Dfi_I'._=: OF r':I_IRVATI_IRE FIETHO£1 A R C Fi A L A'.:;I':: A., I N C. PAD 2F, WELl_ NCI: 15 SIGMA-GYRO KI_IPA RI_IK I:: I E L [I., N 0 RT I--I '.:':;I_OPE., A L A F:;KA ,JOB NO: A01:E:4Z0224 F'AGE NO. TRU.E MEAL--;URED [~F;,:IF'T DRIF:'T COUR'.=_:E VERTICAL. VERTICAL SUBSEA R E C T A N O U L. A R C L 0 S LI R E F,]EL..EjFi: DEF'.TH ANGLE DIF;:IEF:'FION I_ENO'TH DI:-:.PTH a;ECTION TVD C 0 0 R D I Iq A T E.:,':..:' DISTANCE DIRECTION SEVE:RI'I' F:' E: E:' T D M D M F E E T F E E: T F E E T F' E E T F E E T F E E T D M D G / 1 (')c")F:: c). c] 0 (], c) ,0 ,, c"). c} () ("). Oc} - 127. (}c") (} ,, 0(} (],, c")(} 1,0("). (3, 24 Iq /=,() 12 E lC.'.)c"). 1(}0.c')0 ('J,,,22 -27.0c:) (). 1'7 N ('). :2:c], E 200. 0 22 N :3:':: 7 E 1. 00. 2.'()0. AO 0.50 7:3.0(') 0./=, 1 N 0.7'7 E :BO(). 0 1. 8 N /=,f.'"': :B8 E 1()0. :300.0(') 0. ;:::0 172:. 00 0.99 N 1 ,, 24. E 40. o... O_ 5 N 7 A.. ._...'=,":' E 100.. ..":~ ..... 99.9'-?. I .08 272 .9. 9. i . 10 N1 ...... ,, I'-' 5c:)c],. 0 5 N 19 45 E 10, C). 4'.--.,"2,9'.:.:." 1,1.5 :'::72.99 t.'21 N 1,'7(} E C,:~ 1:7 600. C) 9 N ...... , 1. 9 E 1. c:) c]) . ~ .... 99 .9. 'T,,. 1 .21 472 · '9. '-".~. 1 , :B :=: N 1. ,_,'::'..,':' E '7(])() () 20 N P;() "-]'" ..... .':'] '"' . ,, ........ :, E i c}0 699 ':;'9 :t 44 ... 7 .-:. ,, 99 I .,.:,4 N 2. 18 E ::::: ()0 ,, -0 2:3 N ./::, 7 '-."/ E 1 ()0. '799.99 I '=' ''~' / ' '-' ':/'-:'/ ..... ............ :. ::,Tz. ...... 1 9A N :'2 71 F' ,I 900 ................ c") 22 S 77 20 E 1,¢)0 :::9':.~.9'-,-/ "":.. 40 772.':.>"P.. '2.02: N :3 ......... ":'~ E 0.00 0 0 0. '-'=; _ . .: ..... N /-,c7) 12. E c}.9:=: N 5:L :24 E I. 59 N 51 12 E 1.92 N 55 7 E 08 N ::;4 '"-''=; E: 2. :30 N 52 57 E 2.7:B N 52 59 E ':' '="-"-;N 54. /=, E · :,"'. '--/1. N :SF.:: 5/,_ _ E 0.4 () 0. 18 0.2',:]: c"). 2:2 (). 10 0. 17 c). 11. 0.2.:3 100(),, 0 19 S 67 1.:3 E 100. ?99, 99 3,01 .: 872.'.:;'? 1.83 N :3.94 E 11c])('). 0 19 S /=.7 :'::E: E 1.00. 1099.99 3,57 972.99 1./_,2 N 4.45 E 1::::'00. 0 19:2; 54 55 E 100. 11'79.'F/8 4. 12 1072.98 1.:2:5 N 4.94 E ;l:300. 0 20 E; 32 4. E 100. 129'F.~.98 4./=,5 1172.98 0.93 N 5.34 E .1.40c). 0 22 ,.$; 14 12 E 10c). 13'.-.79. 98 5.08 1272.98 0.36 N 5.58 E 4.. 34. N /::,5 2 E 4..74. N 7C) 0 E 5. 12 N 74 4.2 E · 5.42 N :2:0 6 E 5. E,0 N :Fi:6:21 IE 0.08 0.0 _1. 0. (:)7 0. 1:2: 0. 1 ':..": 15C) c"). 0 58 S 59 ,/':, E 1.6c")0. 4 22 S 72 :3 E 1700. '7 47 '..:-]; 71 ';..!:4 E 1. 800. 11 :.3:2: S 69 27 E .1. 9(~('). . .. 1 ':';._ .-....":":' '.E; 74 1:2: E :20o0. 1.,.:.7 1'7 S 7:2:12 E 21oo... ..._,":'":' 16, '.::; 70 :'::R__ E ';:.:::2 C) 0. 27 1 S 72 I E :;;!::300,. :':::'.:.,' 1::: '.:_'; 71 15 E 2400. :.-'::1 :36 S 70:2::2 E 100. 1499.97 1. 00. 1599.85 100. 169'P. 27 1 (:)0. 1797. :2:2 100. 1895.01 100. 1990.4-3 100. 2:'('.)8(::. 56: 100. 2174.09 1 (')0. 2262.24 100. 2:34:3.43 6,, 05 1372.97 10.70 1472. ,'.-]!:5 2.'-: 1.2'7 157 '2.27 :38. 14 167c). 82 /=, 1.55 17/=,,=,. 01 91. :32 1:36:3.4:3 12'7.56, 195/:,, 58 17c). 02 2047.09 217. 17 2135.24 267. :.:.!:4 2221.4:3 0.57 S 6.27 E: 2.49 S 10.50 E 5.80 S 20.56 E 11.45 S :36,.46 E 18.76. '.E; 5:2:. 7:2: E 27. 14 S 87.41 E 38.42 '._:; 121.90 E 52.04 S 162. 16 E /=,6. '.-7/1 S 2c)/=,. 9/_-, E :2:3.4'Fy S 254.86 E /=..30 S 84. 51 E 1A.7'P S 76 41 E 21.3/=, :2; 74. 14 E :38.21 S 72:2:4 E 61./=,/=, S 72 17 E 91.53 S 72 45 E 127. :2:1 c.._, 7'.--'~ :31 E 170.:30 S 72 1:3 E 217.50 '.2; 72 5 E 2/=,:2:.19 S 71 52 E 0 ' =: :'::. 4:3 3.42 :2: ,, 8/=, 4 )) 3.81. 4.10 :3.79 2. :2:2 2. :3:3 2500. :2::':: '29 '.i-:: 69' 54 E: 2600. :.35 12 S 6.9 I8 E :;;:'700, ..:,""'"'.-., 40 c.._, 62', :B1 E '2:2:00. 41 4:3 '.2; 67 4'.-.':' E · '::":.., ,n () 4.4. 4:3 c. 67 ':'.' E 100. 243:2.71 1 (") (') ""'=' .... · .._, 115. :28 100. 25'? 5,20 100. 2671.57 100. 274.4.. 4..'.-;: 321.62 2.'-_-:c)5.71 :--:78.0:2: 2388.28 4 :BS. 1 I 246:E:. 20 5(.'.):2. 64 ]-.':54'4.5'7 571. 1(].) 2617.4:3 101.69 S 305.49 E 121.:2:5 S :35:E:.37 E 142.9'7 '.E; 4.14.. 42 E 166,';:'6 S 474.:34 E 193.17 E; 5:37,6,0 E 321.97 S 71 35 E 37:3.35 S 71 I8 E 4:2:8.:B9 F: 70 58 E 502.:2:6 'S 70:2:7 E 571.25 S 70 14. E 1.90 1.7.5 :2: ._ k) :'::. 0:::: :-4.0:3 PAD 2F., WEL_L Nf'/..: 1 =;._ '::'... I [,MA-'-~~ .:,YRU K IJ F' ~ R I..I K F' I E L 1.:1, I',10 R'I" H S L 0 F:' IF', A L. ~ S K A ,_10 B N 0: A(") 1. 84. Z C) 2:;ii:4 C 0 M I=' I...I T'A'I" I 0 N T I M E D A l' E .l 1.: :'=: 5: 26 '25 -..,,.,I A N -::3.' TRUE ME:A:,:UF(EK~ £~RIF'F DRIFT COURSE VERTICAL.. VFRTICAL F;UBSEA R E C: T A N G I..I L A R C L 0 S U R E DEF'TH ANEiLE DIRECTI ON I_EI',IGTH DEPTH F;ECTION TVD C ID CI R D I N A T E S DI'STANCE [iIRECTION 'SF'VERI"f FEEl" D H D H FEET F'EET FEE"[' FEET FEET FEET D M DG/10(')1::- :3100. 46 57 :=; 66 49 E :"-':20C). 46 7-:'.-.- S 66 47 E :3:--:00. 4.5 48 'S 6E. 49 E :.3400. 4..5 4 ,.'E; 66 ..S...,,:,':" E ::ii:500. 44' ::::2 $ 6'7 .t .7: E :'.:: 6 () () . 44 2 '.,; 67:3 t E :3700. 4.3 3:-'.i: S 67:39 E: 3:::00. 4:3 10 '.S 6'7 52 E · ':::c.~C~('~.. ..... ,, 4=.': :.3:3 ._,c:. 6:=: 0 E 4.000. 4.1 53 S 6 ::4 10 E Zl. 10C~. 41:20 S 68 22 E 4:20(). 40 43 S 6 :'3 1'.-.-~ E 4:::'.0C~. 40 ? '.::; 68 30 E 4, 400. :2:'.'.'-* 4.1 :':; 68 2:2: E 100. 2814.36 100. 2. 8 :E: 2. 88 100. 2'.".~5 l. 4:2 100. 3020. 70 100. 30'P0. :96 642.54 2687.36 715.33 2755.88 7:,::'3. 11 2:,:24.4.2 860. 19 28'F/:'::. '70 '2:31. :-":'.-?2 'F~ 6:3.86 J. 00. :3161.80 10¢) 1 ,, 84 :=:0:34.80 1 ()0. :32:3:3. :37 10'71.65 :S' 106. :37 100. :3:305.4':? 1140. 'F,/1 :2:17 :::. 49 100. 3:378.14 1209.61 3251.14 100.. 3451.44. 1277.6::: 3:_::24.44 221.03 S 603. z[2 E 249.6:2 S 6'70.4.2 E 278.2'~ S '7:37. :3'7 E · -,(' · /, o ,", '-, · :, )6 :,,:, F; .:,0.:,. 67 E 334./=,:3 S 8/_".?:*. 20 E .::ll:,::l.. 8 642,6:.: S 6'P 53 E -7'15 '--' .., ..... . .:::::, c. 6,'.'-.'~ ':'~ E 788 · 1:.-:: S ./::,9 19 E 860. I'P S 6'P 7 E 731.3'.~ S /=,8 57 E :.34. ,, 1 :=: E 1001,84 :-'.; L-,::: 4'? E 'P:.3.60 E 10'71./", .6 S 6 ::: 4:3 E 0.44 O. 4'7 ¢'). 70 0.7:3 0. 0.54 415.3:3 'S 1062.64 E I 140. '.-? 2 S 68 3 .cz E ' 0.4. ::."' 441:3:3 :::; 1126. '-' = . ...' ..., E 1:2('.'~G>. 6:3 '.3 6:E: :2:6 E 0. ~" 466.87 '='.., 11 '"_ '-. · :::_ ¢~. E 1277 .65 S 6 ::=: :2:4 E 0 .62 100. :3525.4"2 1344.82 33'~8.47 4"B 1.94 S 1251.65 E 1344.85 S 68:33 E 100. 3600.25 1411.24 '3473.25 516.5:2: S' 1313.35 E 1411.27 S 68 .7:2 E 100. 3675.68 1476.88 3548.68 540.76 S 1:374. :35 E 1476. '.:.¢ 1 S 68 31 E 100. 3751.7'9 1541.74 3624.79 .564.62 S 1434.67 E 1541.78 S 68 31 E 100. 3828.47 1605. ':.--~2 3701.47 588. I'~ S 14'.-74. :..:.,'7 E 1605. '.-76 S 68:2:1 E 0.66 (") ~,:, 0./;:.2 (), 57 0.4-'7 4.500. 37 7 :E; 6::: 24. E 4/:.,r)() ':":' '::'":' S 6:.3 20 E -- . . m ...' ,-~ .~- ,4-700. :=:: 74- 6 '.:.:; 6::: 22 E 4800. :37 10 S 6:--: 2'7 E 4. 9()0. :36:2:0 '.:; 68 11 E 5000. :..'-::5 52 8 68 16 E 5100. 35 16. :.=; 6::: 11 E 5200. :.:.:4 '.-25 '.3 67 54 E 5:::00. :3:E: 4.1 8 68 1::: E 540(.'). 32:12 S 67 46 E 100. .'::905.74 1669. :::8 3778.74 100. 3'P8:3.72 17:31. ?7 :3856.72 100. 4062.44. 17.c/3.64 3':?:35.44 100. 4141.7'F~ 1854.4:_: 4014.79 100. 4221.82 1914.4:2: 4094. :=:2 100. 4302.53 19'7:3.47 4.175.5:_-: 100. 4383.86 20:_:: 1./=,4 4256.86 100. 4465.7'3 208',.3. 7:3 43:2:8.5):2: 100. 4548.78 2144.77 4421.78 100. 46:2:2.22 21 '?'.T~. 88 4505.22 611.56 '.S '1553.37 E 1669.4.2 F; 68:31 E 634.6:3 S 1611.56 E 17:32.02 S 6::-:.' :30 E '"- / '-' ':'":" E 179:5: /.o o 68 :::0 E /- F,'7 .:: ::: '.=; 1 :, 6,: ................. _m..~ --. · · -- 67':?.76 S 1725.45 E 1854.5:2: '._:; 6:_:: :3C) E 701.~/1 S 1781.18 E 1'.-714. 4'? S 68:5:0 E 72:3.80 S 1836.01 E 1'273.52 S 68 2'2 E 745.37 'S 1890.04 E 2031.70 S 68 29 E 766.73 S 1'P4:3.04 E 2088.84 S 68 2:3 E 787./:.4 8 1'P'.:.¢4.'.--.¢8 E 2144.84 ".'; 6:=: 27 E 808. :30 S 2046.08 E 21'P':?.'P6 S 68 27 E 0.57 O. 74 0.6,1 0.59 (.' 0.64 0.59 O. :.38 0.75 O. 54 5500. 2:2 59 S 6.7 2..'. :3 E 56(-x). :2::;2:2:4 S 67 11 E !:.":;700. 32 40 S 6/=, 2:'8 E 5800. :31 54:3 65 4'P E 5':700. 31 21 S 65 23 E 100. 4716.00 2254.47 45:=:'.-?. 00 100. 4800.07 2:308.59 4673.07 100. 4:'::=:4.30 2:3L-.2.4.7 4.757.30 100. 4':768.82 2415.84 4841.82 100. 5053. '.-76 2468.20 4926. '.:~6 ,..'.~ 12 ~_. 2¢)9/-, ~/:. E .-.-._4 56 S /:.:E: 25 E '-'%(') ~')2:3 '--' 146 51 E 2:=:(')8 /-,9 S /- c, ,: ................... 24 E 871.24 S 21 '.:.~ 6.08 E 2362 · F,._ ,_c: '.:; 6 ::: 2,.'-.' E 892.84 '.3 2244.':74 E 24-15.'~:E: S 6:3 1':? E '.:/14.50 S 2272.71 E 2468.37 8 68 15 E 0. :_::0 0.4:3 0.40 0.85 O. 60 AI::~ C C.I ~1_ A :::;K A., I N C. F::' ~ D 2 I:"- -, W F' L.L.. I',ll:"l: 15 S I E M A--'G V R fi KI..IF::' a R IJ K F I I:.'~: L ]["1 .:. N 0 R TI"'I S L. 0 F" E, A L A SI< A ,..I 0 B N [): A () 184 Z 0:2';-:.' 4 C n M F' U'I"A T I 0 N T I ME DATE .1. 1:._,':'r4._: :..:'/-,_ ._".'.' F,--, ...... lAN.-:::::: TRUE .... '"1 "" '" .. _ EIO G L MEA.::,.JREE~ ['~RIFT DF:~IF'r C:L-II_IRS[.' VERTICAL VERTICAL '.~;UBSEA R E r: T A N G I..I L A R C L 0 ~; I_1 R E DEF'TI-i ANGI_E DIRECTION LENGTH DIEPTH SECTION TVD C 0 0 R D I N A T E .:, DI'.:;TANCE DIREC'rlON .:,EVER FEET D M D M F'EE]" FEET FEET FEE,'T FEET FEET D M BG / 1 OC)F' 6000. 31:34 S 64 42 E: 61 o.. c"). · :B .1..=.i._ 1 '::'._, 64 27-: E ./::,2()0. :-:: 1:::~ 5 S ,63 6 IE .F,:,3C~C~. . :,:: 1:-::7 :.:.'!; 6. 1 "-"=;..,,._ E 64.00. :30 '::'8 S 60 t:-2 E (!:,700. 2. '7 .1. 4. S 56 42 E /.:,8()0. 25 4.4 8 !5!5 54 E ,./::.900. 24 4..1. '.E; 55 12 E 100. 5137.26 25:20.29 5012.2L-, 936.5:.2 S 2340.04 E 2520.49 'S 6:-:'-: 11 E 100. 5224.3:2 2572.71 5097. :32 959.12 S 2:-::87.51 E 2572.96 S 68 7 E 100. 5:30'?. ~':'2 =':'/- ":'~_,~,........':::'~._ 51':'2,_,. .2,2 9::::2 ..... .49 S 2.4:34 .91. E "" ""=. .6._, S 6:B 2 E 100. 5:394.2:B 2677.65 5267.23 1006.92 S 2481.55 E 2678.06 S 67 55 E 10(). 5479.90 2728· '72 5352.90 10:32.00 'S 2526.62 E 2729.25 S 67 47 E 100. Y'l .=; /-, /., . ........ 47 :277:-:'-.:: .06 =; 4 ':: "'--'¢ . 47... ._ .. 1057.6.5 ":'._, 2.'-]/-.9 ...... · 61 E ..°778 .76 -':.'._, 67 ._,':":',,., E 100. 565:-::. 84 2825.80 ..552/_-,. 84. 108:3 · 49 '._=; 2/_-, 10 · 81 E 282/.'., · 71 S 67 2:_:: E "" ':-" 7 ':' ':' 100. 574:2.2.1. 2871 ./-..,...,':' F_,/-, .... 15.... 2_ 1 110:::. _. :=..:/-.. _ ..,'::-.' '7_.'!-,5o. .... .1 .'=;.,.. E.~ .... ... .7,_, '.-:; 6,7 1 :i.'.: E :t (')0. 58:-:: 1.71 2915. 15 5704.71 11 :,:::3.61 S 2687.26 E 2916.57 S /:,7 8 E 100. :5 '.'".¢ 2 ';i'. . 1 '7 2956.61 5795.17 1 .1, .=_;7.71 S 2722.40 E 2958. :-::3 S /:.,6 5:'":: E 0.41 0.3:3 0.68 0. ::::6 1. :34. \ 1..:):5 I · 05 1. Zl.]' 1.5:-:: 7000. '..:::3 47 S 54 35 E '= :':::0E '7100 :2:2: .... ,4 ':' ~":' '720 ('). ....":'.:.':' :,:: 2 'S._ ...,.=[':' 9. F '7:::C~0._. _ 21 ~"]':'.,...., S =;':'._ .-, 1:3 E: '73!50. 22 :E: S 53 15 E 100. 6013. :35 299/:,. 46 5886, 35 1181.32 S 2756. O0 E :2998.51 S 66 48 [.:. 100. 6105.16 3034.77 :5978. 1/_-, 1204.59 $ 2788.09 E 3037.18 '.::; 66 38 E 100. 6197.39 3071.98 6070.39 1227.66 S 2819.07 E 3074.79 S 66 28 E 100. 6289.97 3108.37 61/_-,2.~7 ,1250.31 S 2849.34 E :,::111.60 :-q 66 18 E 5(). 6336.32 :3~26.42 6209.32 1261.53 S 2864. :36 E :3129.86 S 66 14 E 0. '.:.) :F.: 0.9'.:,~ 0. :-::'i;' (-) ,z -':' 0.51 F::'F~O,_.IEC:'rED TO PBTD 7442. .:.'.i:':.'-: 8 S 5:B 15 E 92. 64'7:1.54 3159.81 6294.54 1282.27 ".=; 2892.15 E :,::163.66 S 66 5 E 0.00 F' R 0,_1E C"F E D T 0 T O 10C-.:. 65? 1.5:_:.: 31 '.T~'?. 00 /:.,3'~)4.58 1306.61 S '7..:'.T~24.77 E :_::20:--: · :36 S 65 56 E 0.00 F I I',IAL CI_OSI_IRE - D I RECT I ON: D I STANCE: ".E; /-.=,_,._ DEG::;_ _ ....=,,~.: M INS 40 :E;ECS E :2:20:B. 3/--. FEET ARf':O ~'.II...A/SI<A., I Nf":. F::'AE~ 2F., WEL. L. NO: 15 SIt~iMP~-OYRO ,_lOB N~"/: I<UPARLII< FIELD.., NORTH '.E;LOPE, ..... · ~"' ' - I-" . . ~ -" :":!: I GM~-.c::YRI".I,, 0-740':: MD :.-,I...IRVE:.Y _~R .... IAI..'IN / CORAI"I [~ATE RLIN O:.~:-,_I~N-::::4 :.'4IOMA 1'75 N~"i: .662.: F:'RO[~E NO: 064. FCIF(F"SIC';FIT : '.F.;?.) 4E:E :iE:I..IF~VEY TPd<Ii.:iN FROM WELLHEAD RECORD OF INTERPOLATED SURVEY ARCO ALASKA, INC. PAD 2F, WELL. NO: 15 SI_~MA-bYRU KUPARUK FIELD~ NORTH .':"i:LOPE, ALASKA JOB Nf'~: AO184Z0224 COMF'UTAT I ON T I ME DATE 11 ' ":'/- ' 4c) '-"--'-'"" .......... ,: .... --,...lAN-,:,.:, PAGE NO,; 1.' · MARKER ......... CODE NAME TRUE SUBSE:A MEASLIRED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L. 0 S U R E VERTICAl_ D E P T H i - -" . [EFIH DIFF' D["-P'FI"I C O O R D I N A T E ',S DISTANCE DIRECTION 'T'I']ICKNF_"._:;'.!ii; F'EET FEET FEET FEET FEET F:EET D M 'r o P i_11::, F.' E R S A N.O BASE UF::'F'ER SAND TOF' LOWER SAND BASE LOWFR SAND 6'i:)44.00 5962.29 981.7 5835. ';:"~) 11.6:3. 10 S 2737. 18 E 6'."-:&51.00 5'.:.'~68.67 ?~82.3 5841.67 i 16'....'~. 75 '.E: 273'P. 53 E 69'~:3.00 6006.97 986.0 5879. 'F~7 117'.-.-~. 6'7 S 275:3.65 E '7124.00 6127. :29 996.7 6000.2..:9 1210.1:3 S 2795.52 E 2976.01 S 66 53 E 2978.82 S 66 53 E 2975.'70 S 66 49 E: 3046.21 S 66:2:6 E Suggest~ form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. · ~ 'Operator, W~ 1~ Reports and Materials to be received by: Date Required Date Received Remarks . Ccmp le~on Report Yes -. We11 History Yes ~/~ · .. Samples Mud Log ..Core Chips - ~/0 -~--------- Core Description ..~/~ Registered Survey Plat ~/~,~ /~0~ ~ ~v ~/~ ' / · , , ~ / ~ ~ -~ · Drill St~n Test Reports Prcddcti0n Test Reports · Digitized Data , , ./ KUPARUK ENGINEERING TO: DATE' TRANSMITTAL FROM: WELL NAME' Fay Allison see below Transmitted herewith are the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Descript ion Date , · RECEIPT ACKNOWLEDGED' PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON. - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. '99510 KUPARUK ENGINEERING TRANSMITTAL # : TO: FROM- D. Fay Allison DATE' WELL NAME' Transmitted herewith are the following' see below PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Des~ript ion Date RECEIPT ACKNOWLEDGED' · PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/l115-B ,.... P. O. BOX 100360 ANCHORAGE, AK. '99510 ARCO Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-14 2V-3 WSP #2 ~2F-15 2V-4 WSP #13 2F-16 2V-5 2F-1 2V-6 Thank you. Sincerely, ~ District Dri ing Engineer JBK/SH1: ih ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany KUPARUK ENGINEERING TRANSMITTAL TO' ._~ FROM: D. Fay Allison DATE- /. /-~'. ,~// WELL NAME' see be]_ow Transmitted herewith are the following' PLEASE .NOTE- BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well -DeScription RECEI pT ACKNOWLEDGED' ~/ PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTH: D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION (~~~ ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-172 3. Address ' 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21048 142'FNL, 1736' FEL Sec 33 TllN R9E UM 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 98' 127' RKB , 6. Lease Designation and Serial No. ADL 25651 ALK 469 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2F-15 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of December ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 9--5:/8 Spudded well @ 1400 hrs, 12/08/83. Drld 12-1/4" hole to 2938'. Ran cmtd & tstd " csg. Contd drlg 8½" hole 4209'. Set stringers, performed squeezed. Side track old hole. Cont drlg 8½" hole to 7400'. Ran logs. Cont drlg 8½" hole to 7550TD. Ran, cmt, and tStd 7" csg. Leave top of 7" csg void for freeze protection. Secured well and released rig @ 2400 hrs. on 12/18/83. 13. Casing or liner run and quantities of cement, results of pressur9 tests 9-5/8" 47¢~ & 36~f L-80 & J-55 HFERW BTC csg w/shoe @ 2896'. Cmtd w/850 sxs AS III sxs class "g". 7" 26~/ HFERW BTC csg w/shoe @ 7526, cmtd w/260 sxs class "G'". & 650 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR f/7400' to 2896'. CAL/FDC/CNLL f/7400' to 6740' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~J[,/~l:'~, ~i! ~'l t~,~:; ;.;.;i!S. ~,;Orp ~l~i:ir~ NOTE--Repory~ tJ~s~orm/~ ;equired for each calendar month, regardless of the status of operations, and must be f"~ed i~'~uplic~ate with the Alaska Oi. and O,s~nservatio,~'.~Cmmission by the 15th of the succeeding month, unless otherwise directed. ' Form 10-404 ~ ~TLL/~93 Submit in duplicate 2F-15 DRILLING HISTORY NU 20" Hydril & diverter and tstd same. Spudded well @ 1400 hrs, 12/08/83. Drld 12-1/4" hole to 2938'. Ran 70 jts 9-5/8" 36f~ & 47f~ J-55 & L-80 HFERW BTC csg w/shoe @ 2896. Cmtd 9-5/8" csg w/850 sxs AS III & 650 sxs class "G". Bumped plug w/3000 psi - floats held - ok. ND 20"hydril & diverter. Installed 9-5/8" packoff. NU BOPE & tstd to 3000 psi - ok witnessed by Ben LaNorman AOGCC rep. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 11.5 ppg - EMW - ok. Cont drlg 8½" hole .to 4~2~0?_'_~.~:Set stringers, performed squeezed using 60 sxs AS I and 100 sx class-%\ ,~'G" cst. Set cst plugs from 2976 to 2796. Performed from leak off test to .,.12.5 ppg EMW. Side tracked old h01e @ ~2__9_.3.8.~.' Cont drlg 8½" hole to 7400'. Ran logs DIL/SFL/SP/GR f/7400' to 2896'. CAL/FCS/CNL f/7400' to 6740. Continue drlg 8½" hole to 7550 TD as of 12/18/83. ~Ran 172 its 7" 26f~ HFERW BTC csg w/shoe @ 7526. Cmtd 7" csg w/260 sx Lone Star "G". Bumped plug w/3000 psi - floats held - ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. ND BOPE. Instld 7" packoff and tstd to 3000 psi - ok. Leave top of 7" csg void for freeze protection. Secured well and released rig @ 2400 hrs on 12/18/83. HILL/DH71 1/12/84 ARCO Alaska, Inc.; Post Office bux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 19, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2F-15 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:tw GRU5/L74 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _tLANDGASCONSERVATIONC iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~X COMPLETED WELL [] 2; Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-172 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21048 OTHER [] 4. Location of Well Surface: 142' FNL, 1736' FEL, Sec.33, T11N, RgE, UM 5. Elevation in fe~t (indicate KB, DF, etc.) 127' RKB 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-15 I6. Lease Designation and Serial No. ADL 25657 ALK 2583 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool (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.) (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 Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., has officially changed the well number designation from 2F-7 to 2F-15 as proposed in our Sundry Notice dated 12/08/83. 14. I hereby cer/2~hat the foregoing is true and correct to the best of my knowledge. Signed / /~/'~ ~2.~ Title Area Dri l l lng Engi neer The space,~ow/f,6r~,~ission use Conditio , if any: Date Approved by By Order of COMMISSIONER the Commission Date ' I Form 10-403 Rev. 7-1-80 GRUS/SN40 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate FROM: MEMORAN DU M State of Alaska :~ ~fLASKA OIL AMD GAS CONSERVATION CO~IISSION lO: C. n DA/E: December 19, 1983 Cha~~ k~ THRU: Lonnie C. Smith ~--'~':~[c~ ~,c[ No: 1 I. 5 Co~issioner 4~ELEPHONE NO:. Ben LoNor~n SUBJECT: Witness BOPE Tests on Petrolem Inspector ~CO' s Kupa~k 2F-15, Sec. 33, Tll~,RgE,~{, Kuparuk R~ver :,_Decemb~.r.. 10, 1983: I departed my home at 6:00 am.. for a showup and 7:30 ~ departure via Alaska Airlines, ~lt. #55 for Deadhorse arriving at 9:10 am. Weather: -22°F, fair, light wind. BOPE tests on ARCO's Kuparuk 2F-i5 began at 6:30 pm and were completed at 8:00 pm. BOPE inspection report is attached. _S~unday, December i1, 1983: Standing by on ARCO's 2V-4. ~onday, December 12, 1983: BOPE tests on AP. CO's 2V-4 were completed, ~he Subject of a separate report. Testing of low pilots, SSV's, SSSV's and recording of annulus pressures on 83 Sohio Prudhoe Bay Unit wells began at 1:00 pm... Thurs.d. ay, December 15, 1983:...and was completed at 6:00 pm, the subject of a separate report. Friday, December 16, 1983:. i departed Deadhorse via Alaska Airlines, F'it~'"#6~':at 9::50 am arriving in Anchorage at 11:30 am and at my home at 12:00 noon. In summary, I witnessed successful BOPE tests on ARCO's Kuparuk 2F-15. Attachment 02-00IA(Rev. 10/79) o~ ~4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CCMMJSSION B .O.P.E. Inspection Report Inspector Ope rator. Representative C~ ~';:~ ~ l,,'C:~ ~ Well ~_~_2 ~O~._~ ~.3/~ ~F--/~' __ . Location: Sec Con. actor Pe rmi t # ~-/~ ~'~asing Set @ ~~ .ft. Representative ~~ ~/ _~.~ ~ Location, C~nera] Well Sign_ C~neral Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke L~ne Valves H.C.R. Valve-- Kill Line Valves- Check Valve Test Pressure ACCUMULATOR SYSTEM Ful 1 Charge Pres sure ~ Pressure After Closure Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: psig psig min $/J~ec. ~ rain--sec. ,N2 -~ ~_~ Controls: Master Remote 6~/~ Blinds switch cover Kelly and Floor Safety Valves · Upper Kelly, Lo~er Kelly. Ball Typ~ Ins ide BOP Choke Manifold No. Valves.~_ No. flanges,. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure A~justable Chokes Hydrauically operated choke Test Results: Failures. ~ Test Time' /~ hrs., Repair or Replacement of failed equipment to be made within~ days and Inspector/ccmmission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc, Post 'Office box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 5, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-15 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on January 20, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU5L46' tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA _iL AND GAS CONSERVATION C IMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. ~~3- t76~ 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 142' FSL, 1736' FEL, Se0.33, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 6. Lease Designation and Serial No. ADL 25657 ALK 2583 8. APl Number 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. ((~mit in Triplicate) Perforate Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lation 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 complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: January 20, 1984 Subsequent Work Beported 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for C/~mmissioduse Conditions of Appr~val,/if any: Title Area Drilling Engineer Date Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10403 Rev. 7-1-80 GRU5/SN23 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA iL AND GAS CONSERVATION C -iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-172 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21048 OTHER I~x ~~ 4. Location of Well Surface.. 142~ FNL~ 1736' FEL. $e¢.33. TI'~N~ R9E~ U~ 5. Elevation in feet (indicate KB, DF, etc.) 12~' RKB 6. Lease Desi~ignation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. 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 [] [] Other 'J~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-~07 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 changing the well designation from 2F-7 to 2F-15. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,///~~. ,~¢.~.~4' Title Area Drilling Engineer The space/b~'o~ff~'~//o~/m,ss,on use of Ap~r~al, if any: Conditio/~s Approvedby ~,:'~ L~i'i:," ~: '~": .... COMMISSIONER Approved Copy Returned .. By Order of the Commission Form 10-403 Rev. 7-1-80 GRUS/SN29 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Hovember 29, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-7 Permit Application Dear Mr. Chatterton' The permit application for 2F-7 incorrectly lists the lease designation and serial number for this well as' ADL 25651 ALK 469 The correct lease designation and serial number should be' ADL 25657 ALK 2583 Please make this change to your records and/or files. Sincerely, Gruber Associate Engineer JG5L48' tw cc: K. L. Bonzo, ATO 1492 E. A. Lowen, ATO 1115 D. VanHeukelem, ATO 1020A C. House, ATO 1368 2F-7 Well File ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~ovember 23, 1985 ~r.. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 AnChorage, Alaska 99510 Re: Kuparuk River Unit 2F-7 ARCO Alaska, Inc. Permit No. 83-172 Sur Loc. 142'~ 1736'FEL, Sec 33, TII~], R9E, UM. Btmhole LOc. ll71'FNL, 167!'F~%, Sec. 34, TllN, R9E, Dear ~. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a ~ud log are not required, A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying e~cept experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska-and their drainage systems have been classified as important for the spaWhtng or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Ad~.~inistrative Code). Prior to commencing operations you may be contacted by the }labitat Coordinator's Office, Department of Fish and Pollution of' any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promul}lated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to co~ncing operations you may be contacted by a representative of the Department of Enviror~ental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to c~encing installation of the blowout jeffrey 8. ~' ' uparuk Rivor o.~lt 2~-7 -2- Uovel:~ber 23, lqR3 prevention equioment so that a r~presentative of the Commission ~ay be present to witness te~ting of the equipment before the surface ca~ing shoe is drilled. 14~ere a diverter ~ystem is reauired~ please also notify thi~ office 4 hour~ prior to co~-~mencing equipment installation $o that the Commission witness testing before drilling below the shoe of the conductor pzpe. in t?~e event of suspension or abandonment, please give this office ao~quate advance notification ~o _mat we may have a witness ~ ~ ~ pr~e~. Very truly yours, Chairman of Aia~qka Oil and Gas Conservation Commission be: 6:H/A Enclosure G e ~abita t c~ ~ ~.,ection w/o encl. cc: Der~art~.~nt of Fish & .~ -, Depart~nt of Environmental Conservation w/o encl, ARCO Alaska, Inc. Post Office B~,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 16, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-7 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2F-7, along with a $100 application fee. o Diagrams showing the proposed horizontal and vertical projections of the wellbore. ~ o A proximity plat. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. Since we estimate spudding this well on December 5, 1983, your earliest approval would be appreciated. If you have any questions, pleaSe call me at 263-4970. Sincerely, B. Kewi n Area Drilling Engineer JBK/JG5L39 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (J,- AND GAS CONSERVATION CO,.,,vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE ~( '~,~. 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 '.:~;' : 4. Location of well at surface 142' FNL, 1736~ FEL, Sec.33~ T11N, RgE, UH At top of proposed producing interval 1012~ FNL, 1257' FWL, Sec. 34, T11N, RgE, UN At total depth 1171~ FNL, 1671~ FWL, Sec. 34, T11N~ RgE, UH 9. Unit or lease name Kuparuk River Unit" 10. Well number 2F-7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 127', PAD 98' I ADL'~ ALK~ .~¢~ 12. Bond information (see 20 AAC 25.025) - - 'Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2F-6 well 60' ~- surface feet 16. Proposed depth (MD & TVD) 7804' MD, 6528' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1500 feet. 21 14. Distance to nearest property or lease line miles 3609' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 40.1 o (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 12/05/83 2974 . psig@. 80oF Surface 3338 psig@ R578 ft. TD (TVD) SIZE Hole ! Casing Weight ~24" 16" 65.5# 2-1/4" 9-5/8" 36. O# ! 9-5/8" 47.0# ~-1/2" 17" 26# 22. Describe proposed program: Proposed Casin{ CASING AND LINER Grade I Couplingl Length u-4o | WeldJ 80 I !.TCI J-55 | BTCI 7776' m I Liner and Cementing Program SETTING DEPTH MD TOP TVD 29' I 29' 29' I 29' I 1577' ~1576' I 28' I 28' MD BOTTOM TVD 109'I 109' 1577'11576' 2896'12775' 7804'16528.' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 770 sx AS III & 580 sx'Class G 300 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7804' MD (6528' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 2896' MD(2775' TVD). Administrative approval is needed for this setting depth since the field rules call for a maximum setting depth of 2700' TVD. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2974 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an~gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereb cert,~ that the foregoing is true and correct to the best of my knowledge SIGNED /,~/~,~.f~.~/' TITLE Area Drilling Engineer Thespace~v/f~l~is~on use CONDITIONS OF APPROVAL DATE Samples required []YES ~10 Permit number APPROVED BY Form 10-401 Mud log required []YES E~NO Approval date I I lJ,,2'JTfr~ GRU5/PD11 Directional Survey required [ APl number ~(Y-JE S [--INO [ 50_ O "L- gl' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 23, 1983 by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-7 installed and tested upon completion of the job. 2F-7 will be 60' away from 2F-6 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6616'MD, approximately 500'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. 'NO:";_. F-]:ELD,i NORTH- :-::--:---:----- -: ............. ......... : --- ..................... ..~.~ ~,%U, Ix..~-~M,.~-...:~ - ....................... · .......... - _ I .... __ ; I ROJ.EC: :,I i SC' ~LE .,1' iN~1 i! I~O~ FEinT , : .... :, !, ~ ! ........ ,.I .......... ].DOD',.. ' , ' I ~,,~ ..~,'' '' '~ ' I ..... ' ! · ' " ~ ' i ' t ' ' ' ~- ~"' ' I * i I ' ,' ~ 't ...... 1 ' [ ,. ' Ii . ' ] , ' ' ' I ' ............... ': ..... ' .......... ~ ....... T','"t'''~'''': ......... " 'T' !" ":'"" ' "" i" '. ...... : .... i-' ....... : .... ..... ~,,,~ ] r , , ~,,~ ................. ff-~-..: .... , -~ ........ ~ ..... ;-.+ .... ~-.~.'fl--~--' ....... ,--k;~--~-'-~-'~-~'?-'= 't ...... ~-","-'r ....... : ...... , . ~ ... ~ , : l ~~ ' ) : ~ . , ', : ', ~ . :.,t~i. , ...~, ;~ ~.. ~ .. ~. ~. ~',' ~ i:, :~ . ,'~, ,,~ ~ :,,,,, ,~ : , , ~,,.~: ,,~, , .~ , : .... , ..... ,-t ;.' ~ t~ ..... ; -. .......... . .~ .... .: . , , "-'~ ........ t ..... r"~- ' s ~68 .~7:. . ~ .,..;~,~ . ,. . ; . . . ~ . . . . t · ' ' ' ; :' ~' :: : :' ~ '~UTH' ' ' 1,1~:., :' ~ i ' ~;'',, ' ' ' il ~ :... ,% . ......~ .... i . , --..-: i"~ ......... : ....... ~_~_.,,._~.~ .... F__?_~ ...... ~.. . ' . , ; . ) ' ' ', .... ~ , . ,, . ~' , t ~ I~' " ' ~ ~ ' , . , . ' , . ' i ' ~ , ' ..' '. ~ ' '. i i ~ i ~ ~ ~ I ' ~ i ' i , ~:- '~ ' -t ' ,, '_., ...)9gD .... ~ ..... ~ .......... ~ ........ '---~.--.: ........ (--:'-.i.-;-~.~.-F' .................. ' ' ; ' : ' i '', ~ : ::: ~' (. ' I i~ I ' . · ~ ~ i ' , , ' ' '' , ' ~ : : ~' ~ 1'. ~ '~ ~ : · , ~ . , , ~ , : ~ , , t , ] ~ i~, ~ I ~ ~ I , Surface Oiverter System 2. 3. 4. . . . . 16" - 2000 psi Tankco starting head. Tankco quick connect assy. 16" x 20" 2000 psi double studded adapter. 20" 2000 psi drilling, spool w/10" side outl ets. 10" ball valves, hydraulically actuated, w/lO" lines to rese~/e pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. · Maintenance & Operation Upon initial inslallation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'ever7 12 hours. Close annular preventer in the event.that gas or fluid flow to surface is detected. If necessarT, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor ANNULAR PREVENTER m BLIND RAMS c' 71 ) .L _ PiPE RAMS '~J~ PIPE ARMS ) S CSG HD I, I 16. D :AGRAM .--1 13-5/8" 5000 PSI RSRRA BOP STACK 1o 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' o 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi .drilling spool ~. 13-5/8" o 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - $000 psi blind rams -g. 13-5/8' - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID· 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. ,CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED.. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN NEAO. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. '- 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR I0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR 10 MINUTES. 8. CLOSE VALVES OIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE ANO ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR 10 MINUTES BLEEO TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE DOPE DAILY. ANNULAR PREVENTER · 11 BLIND RAMS'- ) io ~ ~PIPERAMS ) 9 m! ¢ · DRILLING O IAGRN4 #2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16' - 3000 psi tubing head 4. 7-1/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8' - 5000 psi x 13-5/8# - 5000 psi drilling spool - 7. 13-5/8' - 5000 psi pipe rmms 8. 13-$/8' - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8' - 5000 psi pipe rams 10. 13-$/8' - 5000 psi blind ~ ll. 13-5/8' - 5000 psi annular ACCU~LATOR CAPACITY TEST 1. OIECK AND FILL ACCUMULATOR P, ESERVOIR TO PROPER LEVEL WITH ~ORAULIC FLUID. 2. ASSURE THAT ACCUMIJLATOR PRESSURE IS 3000 PSI WITlt 1500 PSI DO~NSTREAH OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD TIlE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUNP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT · IS 45 SECONDS CLOSING TIME AND i200 PSI RF, J~AINING PRESSURf. PIPE RAMS (. TBG HD. 13-5/8' RDP STACK TEST 1. FILL 80P STAC~ AND HANIFOLD WITH ARCTI.C OIESEL. ~,. CHECK THAT' ALL HOLD DOI/N SCREWS ARE FULLY RETRACT- ED. PREDETERHINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT Itl WELLFIEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND_CHOKES AND BYPASS VALVES ON HANIFOLD. 4. TEST ALL COHPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. $. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PlPE RAHS. ?. INCREASE PRESSURE TO 3000 PSI AND HOLD' FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES. BLEED ~TRF.~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAINING UNTESTED HANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAH OF VALVE AND ZERO PSI D(~INSTREAH. BLEED S¥STEN TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAHS ANO CLOSE BOTTOH SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI mD HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTi'Og SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAHS AgO RECOVER TEST PLUG· HAKE SURE Ka, NIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOHEY PUMP. RECORD TEST INFORMATION ON SLOWOUT PREVENTER TEST FOP. H SIGN AND SEND TO ORILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. PHASE I AS BUILT CONOUCTORS I - 8 94.4 ~ 94. 4 09 160 010 150 011 140 28 27 BASIS OF PAD ELEV. IS T.B.M. 83o25-49.' O.G. ELEV.'s INTERPOLATED FROM DWG. SR. 8F- 12- :5030 REV. I RENUMBER ALL WELLS PER NSK ~ ~ DRILLING 12/2/83. (180°ROTATION OF '. NUMBERING) REV. 2 CHANGE ALL ELEVATIONS LOCATED IN PROTRACTED SECTION 28 TOWNSHIP II N.,RANGE 9 E.,UMIAT MER. ,BASIS OF LOCATION I$ MONUMENTS C.R.F.-2 N.E.& 2'C MIDDLE PER LHD ASSOCIATES. WELL I WELL 2 WELL3 WELL 4 WELL 5 WELL 6 WELL 7 WELL 8' SITE: BUILT Y= 5,949,541.8:5 X= 517,:392.55 459' FSL Y= 5,949,403.93 .X. 517,382.34 518' FS L Y~ 5,949,460.06 Xz 517,372.18 577' FS L Y" 5,949,51 9.07 Xz ~17,362.08 6:56 FS L i Y" 5~9~9,566. :39 X" 817,658.11 685' FS L ~t'= ~949, 507. 09 X' 817,648.17 62 4' FS L Y=~949,448.14 5ix5~1FSL7'658 . $ I X · 517,668-33 506' FS L 2. f CONDUCTORS LOCATIONS · Lat. 70° 16'21.9780" Long, 1,49° 51 ' 33.357 1837' FEL Let. 70e 15'22.5595" I.oe~. 149081'33.896'' 1847' FEL Lat. 70° 16~23. 1413" Lon~. !49051)34. 161" 1856' FEL Lat. 70o16'23,7219" · Lon~, 1,49°81'34.451" 1866' FEL.' Lat.70° 16' ~4. 18 I1" LonQ. 1,49081'26. 410" 159.0' FEL' Let. 70° 18'23. 5977" Lo hq. 1,49e51 '26.12 I" 1580' FEL Let. 7~e!~'2~.0176" ~ 1.49°81'25.831'' 1570' FEL' Let.70e 1~'22.438 7? Le~. 149e81' 25.543" 1561' FEL · DAVID FILUCCl 827! 30 31 e 32 THIS 33 SURVEY I HEREBY CERTIFY THAT I AM PROPERLY · REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN ~ STATE OF ALASKA AND ... THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION ANO THAT ALL. DETA/1. S ARE CORRECT AS OF NOV.'5~I983. ARCO Alaska, Inc. Kuperuk Project North Sloee Drtlli~ DRILL SITE 2.F CONDUCTOR AS.BUILT LOCATIONS i~cate' I"= 400~ CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc ~2 thru 8) (~"~r u 11) (4) Casg ~-.~ //-~ '~3 (12 thru 20) (21 thru 24) l® 1 3. 4. 5. 6. 7. 8. 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .......................................... ~,. Is well to be located in a defined pool ............................ Is well located proper distance from property line .................. Is well located proper distance from other wells Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat i::luded . ............. Is operator the only affected party .... , .... ' ,~r,.~ ...... Can permit be approved before ten-day wait ............ ' REMARKS Does operator have a bond in force Is conductor string provided ........................................ ~-~ Is enough cement used to circulate on conductor and surface ..... i}}i. _~'~-~ Will cement tie in surface and intermediate or production strings Will cement cover ail known productive horizons .................. Will surface casing protect fresh water zones ................... Will ail casing give adequate safety in collapse, tension ::~ burst.. ~-~. ~---' Is this well to be kicked off from an existing wellbore ......... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating- Test to ~5> psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o ~-~0 Geology: Engineer ing: WVA ~ J~_~-) HJH ~ rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information, O 0 0 000 000 00 n 0 0 0 ; ¢ .9 '2 ~,,.'1~] i'11 ! l i i i, i;] i[_._ [:.]1 .~ f.,(! 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