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Home My WebLink About188-059MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-10 KUPARUK RIV UNIT 3O-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-10 50-029-21823-00-00 188-059-0 W SPT 6360 1880590 3000 2800 2800 2800 2800 40 220 220 220 REQVAR P Adam Earl 6/24/2025 MIT-IA tested as per AIO 2B.033 to max.ant.inj.psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-10 Inspection Date: Tubing OA Packer Depth 325 3500 3315 3280IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625082724 BBL Pumped:5 BBL Returned:4.7 Tuesday, July 22, 2025 Page 1 of 1             C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\2SR1PWCY\2025-07-01_22227_KRU_3O-10_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22227 KRU 3O-10 50-029-21823-00 Caliper Survey w/ Log Data 01-Jun-25 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 188-059 T40637 7/9/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.09 08:01:28 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3O-10 (PTD 188-059) Report of suspect IA pressure increase Date:Wednesday, June 25, 2025 1:48:35 PM Attachments:MIT KRU 3O PAD 06-24-25.xlsx 3O-10 90 Day TIO Plot & Schematic.pdf From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, June 25, 2025 1:46 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 3O-10 (PTD 188-059) Report of suspect IA pressure increase Well Name: 3O-10 Facility: CPF3 PTD: 188-059 Well Type: Inj AA Number (if applicable): AIO 2B.033 Internal Waiver (Yes/No if applicable): Yes Type of Issue: Suspect Integrity Maximum Pressure (if applicable): 1766 Date of Occurrence (if applicable): 6/24/25 Chris, KRU 3O-10 (PTD 188-059) (AIO 2B.033) passed a State witnessed MITIA yesterday (see attached 10- 426) but is now showing signs of suspect IA pressurization during injection. CPAI intends to shut-in the injector as soon as possible, secure the well with a tubing plug and conduct diagnostics. Any required paperwork for corrective action or continued injection will be submitted upon conclusion of the diagnostics. Attached is a 90 day T/I/O plot and wellbore schematic for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est 27' of Rathole) 8,589.0 3/10/2020 3O-10 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 3/10/2020 3O-10 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 5,005.0 Set Depth (TVD) … 4,017.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,815.9 Set Depth (TVD) … 6,756.4 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 33.0 Set Depth (ft… 8,357.8 Set Depth (TVD) (… 6,414.1 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.0 33.0 0.08 HANGER CIW TUBING HANGER 2.875 1,781.1 1,696.2 36.54 SAFETY VLV BAKER FVLD SAFETY VALVE (Attempted to lock out 4/5&7/95 - Unsuccessful) Tested 6/27/01, confirmed SSSV functions properly. 2.310 8,271.8 6,350.6 42.58 PBR BAKER PBR 2.376 8,285.7 6,360.8 42.50 PACKER BAKER HB PACKER 2.376 8,322.8 6,388.3 42.29 NIPPLE CAMCO D NIPPLE 2.250 8,357.0 6,413.5 42.09 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,611.0 6,603.2 41.62 FISH 1 1/2" DMY Left in Hole 8/4/1989 8/4/1989 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,486.0 8,498.0 6,509.7 6,518.7 A-3, 3O-10 3/27/1989 12.0 IPERF 2 1/8" EnerJet; 60 deg. ph 8,508.0 8,532.0 6,526.2 6,544.1 A-2, 3O-10 3/27/1989 12.0 IPERF 2 1/8" EnerJet; 60 deg. ph 8,542.0 8,562.0 6,551.6 6,566.5 A-1, 3O-10 6/27/1988 8.0 APERF 4 1/2" Ultrapak Csg; 45 deg. ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,953.6 2,564.8 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 8/5/1989 2 5,154.0 4,123.8 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 8/5/1989 3 6,357.4 4,970.3 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 6/27/1988 4 6,910.3 5,362.3 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 8/5/1989 5 7,337.9 5,673.6 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 6/27/1988 6 7,796.1 6,005.1 McMurry FHMO 1 GAS LIFT DMY BK-2 0.000 0.0 8/6/1989 7 8,224.5 6,315.9 MERLA TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 8/5/1989 Notes: General & Safety End Date Annotation 3/25/2012 NOTE: AS PER DESIGN, 2.31" BAKER FVLD FLAPPER CANNOT BE LOCKED OPEN. 3/25/2012 NOTE: ONLY HYDRAULIC SHEAR SLEEVE CAN BE OPENED. 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3O-10, 3/11/2020 5:42:13 AM Vertical schematic (actual) PRODUCTION; 33.0-8,815.9 FISH; 8,611.0 APERF; 8,542.0-8,562.0 IPERF; 8,508.0-8,532.0 IPERF; 8,486.0-8,498.0 SOS; 8,357.0 NIPPLE; 8,322.8 PACKER; 8,285.7 PBR; 8,271.8 GAS LIFT; 8,224.5 GAS LIFT; 7,796.1 GAS LIFT; 7,337.9 GAS LIFT; 6,910.3 GAS LIFT; 6,357.4 GAS LIFT; 5,154.0 SURFACE; 35.0-5,005.0 GAS LIFT; 2,953.6 SAFETY VLV; 1,781.1 CONDUCTOR; 36.0-115.0 HANGER; 33.0 KUP PROD KB-Grd (ft) 34.98 Rig Release Date 6/17/1988 3O-10 ... TD Act Btm (ftKB) 8,830.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182300 Wellbore Status PROD Max Angle & MD Incl (°) 46.30 MD (ftKB) 3,600.00 WELLNAME WELLBORE3O-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880760 Type Inj W Tubing 2800 2800 2800 2800 Type Test P Packer TVD 6514 BBL Pump 3.4 IA 390 3520 3470 3450 Interval V Test psi 3000 BBL Return 3.3 OA 120 140 140 140 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880600 Type Inj W Tubing 2950 2950 2950 2950 Type Test P Packer TVD 6386 BBL Pump 0.9 IA 1180 2030 1985 1985 Interval 4 Test psi 1597 BBL Return 0.8 OA 350 360 360 360 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880770 Type Inj W Tubing 2350 2350 2350 2350 Type Test P Packer TVD 6502 BBL Pump 3.9 IA 320 3325 3125 3100 Interval V Test psi 3000 BBL Return 3.8 OA 60 60 60 60 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880590 Type Inj W Tubing 2800 2800 2800 2800 Type Test P Packer TVD 6361 BBL Pump 5.0 IA 325 3500 3315 3280 Interval V Test psi 3000 BBL Return 4.7 OA 40 220 220 220 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880410 Type Inj W Tubing 2900 2900 2900 2900 Type Test P Packer TVD 6321 BBL Pump 1.3 IA 605 2015 1955 1950 Interval 4 Test psi 1580 BBL Return 1.1 OA 80 80 80 80 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880390 Type Inj W Tubing 2150 2150 2150 2150 Type Test P Packer TVD 6421 BBL Pump 2.2 IA 620 2920 2790 2780 Interval 4 Test psi 1605 BBL Return 2.1 OA 110 110 110 110 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2150570 Type Inj W Tubing 2900 2900 2900 2900 Type Test P Packer TVD 6358 BBL Pump 1.4 IA 270 1825 1740 1730 Interval 4 Test psi 1590 BBL Return 1.4 OA 60 60 60 60 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880290 Type Inj W Tubing 2075 2075 2075 2075 Type Test P Packer TVD 6395 BBL Pump 2.5 IA 300 3325 3250 3250 Interval V Test psi 3000 BBL Return 2.4 OA 700 1100 1100 1100 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1880290 Type Inj W Tubing 2075 2075 2075 2075 Type Test P Packer TVD 6395 BBL Pump 0.5 IA 300 375 375 375 Interval V Test psi 1800 BBL Return 0.4 OA 680 2000 1900 1900 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 3O-17 Notes:MITIA to maximum anticipated injection pressure per AIO 2B.033 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov 3O-05 3O-06 3O-10 3O-12 3O-14 3O-07 MITIA to maximum anticipated injection pressure per AIO 2C.032 Notes:MITIA to maximum anticipated injection pressure per AIO 2C.073 Notes: Notes: Notes: Notes: Notes: 3O-16B ConocoPhillips Alaska Inc, Kuparuk / KRU / 3O Pad Adam Earl Arend / Kirk 06/24/25 3O-17 Notes:MITOA to 1800 psi per AIO 2C.026 Notes:MITIA to maximum anticipated injection pressure per AIO 2C.026 Form 10-426 (Revised 01/2017)MIT KRU 3O PAD 06-24-25 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-10 KUPARUK RIV UNIT 3O-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3O-10 50-029-21823-00-00 188-059-0 W SPT 6360 1880590 3000 2730 2720 2720 2720 60 410 400 400 REQVAR P Austin McLeod 6/16/2023 Two year to MAIP. AIO 2B.033. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-10 Inspection Date: Tubing OA Packer Depth 310 3500 3285 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230617185232 BBL Pumped:4.8 BBL Returned:4.4 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Two year to MAIP. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:22:44 -08'00' 1 Carlisle, Samantha J (CED) From:Wallace, Chris D (CED) Sent:Monday, August 30, 2021 7:03 AM To:AOGCC Records (CED sponsored) Subject:FW: KRU 30-10 (PTD 188-059) Update and monitor conclusion Attachments:3O-10 90 day TIO trend 8.26.21.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, August 26, 2021 8:04 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 30‐10 (PTD 188‐059) Update and monitor conclusion Chris, KRU 3O‐10 (PTD 188‐059) showed no signs of AnnComm during the extended monitor period. The IA pressure stabilized and flat lined. CPAI plans to return the well to ‘Normal’ status at this time. If there are any suspect AnnComm issue in the future they will be reported at that time. A 90 day TIO trend is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, July 27, 2021 11:34 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 30‐10 (PTD 188‐059) Update and monitor extension Chris, KRU 3O‐10 (PTD 188‐059) was brought online on 6/28/21 for its 30 day monitor period and has exhibited some IA pressure increase, but it is inconclusive at this time whether the pressure increase is due to thermal expansion or AnnComm. CPAI plan’s to extend the monitor period an additional 30 days to allow time for the well to stabilize or conclusively demonstrate any AnnComm. A follow up email will be made at the conclusion of the monitor period. A 90 day TIO trend is attached. Please let me know if you disagree or have any questions with this plan. 2 Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, June 28, 2021 1:41 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 30‐10 (PTD 188‐059) Update and plan forward Chris, Subsequent the previous report Slickline set a plug and attempted multiple MITTs which failed minutely, but there was no communication seen to the IA. The plug was the suspect source of MITT failure and was pulled. Due to observing no communication to the IA DHD then returned to well to perform diagnostics, passing an MITIA to 3000 psi and a passing IA‐DDT. When initiating the bleed for the IA‐DDT the IA fluid level was at surface, but during the bleed it was noted that charged fluid and then gas was bled off the IA. It is suspect that there may have been a trapped gas bubble deep in the IA which was disturbed during the original SW MITIA causing the IA pressure anomaly. At this point in time there appears to be no annular communication, as such, CPAI plans to bring the well online for a 30 day monitor period to determine if the well has integrity or if the previous suspect IA pressure increase can be activated by injection. I have attached a 10‐426 of the passing diagnostic MITIA performed on 06/26/21. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Friday, June 04, 2021 8:56 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 30‐10 (PTD 188‐059) Report of suspect IA pressurization Chris, KRU 3O‐10 (PTD 188‐059) (AIO 2B.033) Passed its state witnessed MITIA yesterday. Shortly after the MITIA the IA pressure began increasing. Operations bled the IA pressure down multiple times, but the IA repressurized immediately after each bleed. The well was shut in and freeze protected. CPAI plans to secure the well and begin diagnostics with 3 Slickline and DHD. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Annular Communication Surveillance 28 Well Name:33O-10 Start Date:28-May-2021 26 Days:90 End Date:26-Aug-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 28-May-2131-May-213-Jun-216-Jun-219-Jun-2112-Jun-2115-Jun-2118-Jun-2121-Jun-2124-Jun-2127-Jun-2130-Jun-213-Jul-216-Jul-219-Jul-2112-Jul-2115-Jul-2118-Jul-2121-Jul-2124-Jul-2127-Jul-2130-Jul-212-Aug-215-Aug-218-Aug-2111-Aug-2114-Aug-2117-Aug-2120-Aug-2123-Aug-2126-Aug-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 100 200 300 400 500 600 700 800 900 1000 28-May-2131-May-213-Jun-216-Jun-219-Jun-2112-Jun-2115-Jun-2118-Jun-2121-Jun-2124-Jun-2127-Jun-2130-Jun-213-Jul-216-Jul-219-Jul-2112-Jul-2115-Jul-2118-Jul-2121-Jul-2124-Jul-2127-Jul-2130-Jul-212-Aug-215-Aug-218-Aug-2111-Aug-2114-Aug-2117-Aug-2120-Aug-2123-Aug-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Annular Communication Surveillance Annular Communication Surveillance Annular Communication Surveillance 3O-10 90-Day Bleed History WELL_ID TIME STR-PRES END-PRES DIF-PRES CASING SERVICE 3O-10 7/22/21 400 600 -200 INNER SWI 3O-10 6/27/21 142 80 62 INNER SWI 3O-10 6/26/21 685 148 537 INNER SWI Annular Communication Surveillance 3O-10 11/5/12 121 121 0 INNER PWI 3O-10 10/28/12 20 4 16 OUTER PWI 3O-10 10/28/12 285 285 0 INNER PWI 3O-10 10/12/12 70 80 -10 OUTER PWI 3O-10 10/12/12 540 235 305 INNER PWI 3O-10 7/28/12 660 140 520 OUTER PWI 3O-10 6/17/12 1000 700 300 OUTER PWI 3O-10 1/11/12 960 620 340 OUTER PWI 3O-10 6/2/11 850 400 450 OUTER PWI 3O-10 3/17/11 720 400 320 OUTER PWI 3O-10 11/21/09 740 200 540 OUTER PWI 3O-10 9/7/09 1040 900 140 OUTER PWI 3O-10 6/26/09 800 774 26 INNER PWI 3O-10 6/26/09 320 380 -60 OUTER PWI 3O-10 11/6/08 1000 600 400 OUTER PWI 3O-10 10/23/08 1000 600 400 OUTER PWI 3O-10 10/1/08 1000 700 300 OUTER PWI 3O-10 9/29/08 1400 1000 400 OUTER PWI 3O-10 5/22/08 1950 1000 950 INNER PWI 3O-10 5/22/08 1000 100 900 OUTER PWI 3O-10 5/19/08 1000 400 600 OUTER PWI 3O-10 2/16/08 1100 600 500 OUTER PWI 3O-10 1/30/08 1100 450 650 OUTER PWI 3O-10 1/27/08 1000 400 600 OUTER PWI 3O-10 1/27/08 1100 400 700 OUTER PWI 3O-10 12/27/07 2000 1300 700 INNER PWI 3O-10 12/26/07 1000 400 600 OUTER PWI 3O-10 12/25/07 2700 1500 1200 INNER PWI 3O-10 12/25/07 1100 600 500 OUTER PWI 3O-10 12/25/07 2100 1500 600 INNER PWI 3O-10 12/25/07 2000 1500 500 INNER PWI 3O-10 12/22/07 1100 450 650 OUTER MIS 3O-10 12/22/07 3100 2100 1000 INNER MIS 3O-10 11/13/07 950 300 650 OUTER MIS 3O-10 11/13/07 2900 1900 1000 INNER MIS 3O-10 8/31/07 3000 2250 750 INNER MIS 3O-10 7/15/07 3000 2700 300 INNER MIS 3O-10 7/15/07 2850 2000 850 INNER MIS 3O-10 7/5/07 2700 1700 1000 INNER MIS 3O-10 6/25/06 900 200 700 OUTER PWI 3O-10 5/25/06 1000 500 500 OUTER PWI 3O-10 3/15/06 1050 750 300 OUTER PWI 3O-10 1/15/06 1000 550 450 OUTER PWI 3O-10 11/30/05 1000 750 250 OUTER PWI 3O-10 9/11/05 1010 750 260 OUTER MIS 3O-10 9/7/05 1100 750 350 OUTER MIS 3O-10 8/5/05 1100 575 525 OUTER MIS Annular Communication Surveillance 3O-10 8/4/05 3200 2300 900 INNER MIS 3O-10 8/4/05 1100 750 350 OUTER MIS 3O-10 8/2/05 2000 1500 500 INNER GIN 3O-10 7/27/05 1400 450 950 OUTER GIN 3O-10 7/27/05 3400 2500 900 INNER GIN 3O-10 7/17/05 1000 725 275 OUTER GIN 3O-10 7/17/05 3000 2150 850 INNER GIN 3O-10 6/27/05 1800 500 1300 OUTER GIN 3O-10 6/24/05 3000 2300 700 INNER GIN 3O-10 3/18/05 3100 2250 850 INNER MIS 3O-10 2/25/05 3100 2100 1000 INNER MIS 3O-10 4/5/03 1150 120 1030 OUTER PWI 3O-10 12/8/02 1050 750 300 OUTER PWI 3O-10 9/10/02 2250 1500 750 INNER PWI 3O-10 8/31/02 1930 1000 930 INNER PWI 3O-10 8/28/02 2450 750 1700 INNER PWI Annular Communication Surveillance WELL_ID DATE_TEST ANNULUS_ PRES_INNE R ANNULUS_ PRES_OUT ER ANNULUS_ PRES_OUT ER2 ANNULUS_ PRES_OUT ER3 3O-10 5/28/21 453 60 3O-10 5/29/21 457 60 3O-10 5/30/21 490 60 3O-10 5/31/21 535 60 3O-10 6/1/21 523 60 3O-10 6/2/21 536 60 3O-10 6/3/21 526 200 3O-10 6/4/21 1500 300 3O-10 6/5/21 1500 300 3O-10 6/6/21 600 0 3O-10 6/7/21 600 0 3O-10 6/8/21 572 0 3O-10 6/9/21 588 0 3O-10 6/10/21 600 0 3O-10 6/11/21 610 0 3O-10 6/12/21 619 0 3O-10 6/13/21 627 0 3O-10 6/14/21 634 0 3O-10 6/15/21 640 0 3O-10 6/16/21 645 0 3O-10 6/17/21 651 0 3O-10 6/18/21 656 0 3O-10 6/19/21 660 0 3O-10 6/20/21 665 0 3O-10 6/21/21 669 0 3O-10 6/22/21 672 0 3O-10 6/23/21 676 0 3O-10 6/24/21 679 0 3O-10 6/25/21 683 0 3O-10 6/26/21 685 0 3O-10 6/27/21 494 0 3O-10 6/28/21 82 0 3O-10 6/29/21 82 0 3O-10 6/30/21 300 130 3O-10 7/1/21 300 130 3O-10 7/2/21 278 130 3O-10 7/3/21 256 150 3O-10 7/4/21 238 100 3O-10 7/5/21 310 200 Annular Communication Surveillance 3O-10 7/6/21 350 220 3O-10 7/7/21 350 220 3O-10 7/8/21 318 220 3O-10 7/9/21 350 220 3O-10 7/10/21 350 220 3O-10 7/11/21 374 220 3O-10 7/12/21 378 220 3O-10 7/13/21 384 200 3O-10 7/14/21 391 520 3O-10 7/15/21 389 520 3O-10 7/16/21 394 520 3O-10 7/17/21 378 480 3O-10 7/18/21 363 480 3O-10 7/19/21 346 480 3O-10 7/20/21 403 560 3O-10 7/21/21 384 420 3O-10 7/22/21 467 300 3O-10 7/23/21 575 240 3O-10 7/24/21 575 240 3O-10 7/25/21 499 240 3O-10 7/26/21 497 240 3O-10 7/27/21 496 240 3O-10 7/28/21 496 240 3O-10 7/29/21 507 280 3O-10 7/30/21 533 375 3O-10 7/31/21 542 420 3O-10 8/1/21 561 450 3O-10 8/2/21 564 450 3O-10 8/3/21 577 450 3O-10 8/4/21 573 450 3O-10 8/5/21 562 450 3O-10 8/6/21 531 250 3O-10 8/7/21 517 300 3O-10 8/8/21 517 300 3O-10 8/9/21 508 300 3O-10 8/10/21 507 300 3O-10 8/11/21 515 300 3O-10 8/12/21 514 300 3O-10 8/13/21 505 300 3O-10 8/14/21 509 300 3O-10 8/15/21 510 300 3O-10 8/16/21 513 300 3O-10 8/17/21 506 300 3O-10 8/18/21 504 300 3O-10 8/19/21 489 300 3O-10 8/20/21 480 240 3O-10 8/21/21 479 240 Annular Communication Surveillance 3O-10 8/22/21 480 240 3O-10 8/23/21 480 240 3O-10 8/24/21 479 240 3O-10 8/25/21 472 240 3O-10 8/26/21 462 240 Annular Communication Surveillance WELL_ID DATE_INJ WHIP_AVG WHT GAS_INJ_VO L MGI_VO L PWI_VO L SWI_VO L 3O-10 5/28/21 2656 68 0 0 0 819 3O-10 5/29/21 2650 70 0 0 0 791 3O-10 5/30/21 2688 71 0 0 0 786 3O-10 5/31/21 2701 71 0 0 0 768 3O-10 6/1/21 2702 71 0 0 0 765 3O-10 6/2/21 2702 70 0 0 0 762 3O-10 6/3/21 2701 71 0 0 0 752 3O-10 6/4/21 2789 65 0 0 0 125 3O-10 6/5/21 2875 0 0 0 0 3O-10 6/6/21 2618 0 0 0 0 3O-10 6/7/21 2174 0 0 0 0 3O-10 6/8/21 2567 0 0 0 0 3O-10 6/9/21 2926 0 0 0 0 3O-10 6/10/21 2924 0 0 0 0 3O-10 6/11/21 2912 0 0 0 0 3O-10 6/12/21 2905 0 0 0 0 3O-10 6/13/21 2894 0 0 0 0 3O-10 6/14/21 2919 0 0 0 0 3O-10 6/15/21 2918 0 0 0 0 3O-10 6/16/21 2912 0 0 0 0 3O-10 6/17/21 2882 0 0 0 0 3O-10 6/18/21 2900 0 0 0 0 3O-10 6/19/21 2917 0 0 0 0 3O-10 6/20/21 2886 0 0 0 0 3O-10 6/21/21 2911 0 0 0 0 3O-10 6/22/21 2921 0 0 0 0 3O-10 6/23/21 2903 0 0 0 0 3O-10 6/24/21 2896 0 0 0 0 3O-10 6/25/21 2901 0 0 0 0 3O-10 6/26/21 2920 0 0 0 0 3O-10 6/27/21 2908 0 0 0 0 3O-10 6/28/21 2865 73 0 0 0 49 3O-10 6/29/21 2575 73 0 0 0 890 3O-10 6/30/21 2614 77 0 0 0 866 3O-10 7/1/21 2628 75 0 0 0 842 3O-10 7/2/21 2633 72 0 0 0 826 3O-10 7/3/21 2635 69 0 0 0 809 3O-10 7/4/21 2638 72 0 0 0 812 3O-10 7/5/21 2641 74 0 0 0 819 Annular Communication Surveillance 3O-10 7/6/21 2646 73 0 0 0 813 3O-10 7/7/21 2648 73 0 0 0 809 3O-10 7/8/21 2652 76 0 0 0 801 3O-10 7/9/21 2658 79 0 0 0 792 3O-10 7/10/21 2660 80 0 0 0 779 3O-10 7/11/21 2663 81 0 0 0 779 3O-10 7/12/21 2668 81 0 0 0 767 3O-10 7/13/21 2672 82 0 0 0 763 3O-10 7/14/21 2686 81 0 0 0 803 3O-10 7/15/21 2696 81 0 0 0 820 3O-10 7/16/21 2697 80 0 0 0 813 3O-10 7/17/21 2698 77 0 0 0 844 3O-10 7/18/21 2693 76 0 0 0 862 3O-10 7/19/21 2703 81 0 0 0 837 3O-10 7/20/21 2703 83 0 0 0 827 3O-10 7/21/21 2694 79 0 0 0 861 3O-10 7/22/21 2681 74 0 0 0 847 3O-10 7/23/21 2675 70 0 0 0 845 3O-10 7/24/21 2678 71 0 0 0 841 3O-10 7/25/21 2672 71 0 0 0 835 3O-10 7/26/21 2668 71 0 0 0 845 3O-10 7/27/21 2663 71 0 0 0 830 3O-10 7/28/21 2665 73 0 0 0 825 3O-10 7/29/21 2662 76 0 0 0 808 3O-10 7/30/21 2664 77 0 0 0 795 3O-10 7/31/21 2669 79 0 0 0 783 3O-10 8/1/21 2671 79 0 0 0 808 3O-10 8/2/21 2677 80 0 0 0 812 3O-10 8/3/21 2682 79 0 0 0 825 3O-10 8/4/21 2677 78 0 0 0 817 3O-10 8/5/21 2676 73 0 0 0 824 3O-10 8/6/21 2683 74 0 0 0 830 3O-10 8/7/21 2682 73 0 0 0 824 3O-10 8/8/21 2684 73 0 0 0 824 3O-10 8/9/21 2690 73 0 0 0 819 3O-10 8/10/21 2693 74 0 0 0 815 3O-10 8/11/21 2690 74 0 0 0 804 3O-10 8/12/21 2691 73 0 0 0 802 3O-10 8/13/21 2704 74 0 0 0 792 3O-10 8/14/21 2706 74 0 0 0 770 3O-10 8/15/21 2704 74 0 0 0 769 3O-10 8/16/21 2706 73 0 0 0 768 3O-10 8/17/21 2708 72 0 0 0 766 3O-10 8/18/21 2714 71 0 0 0 771 3O-10 8/19/21 2710 70 0 0 0 773 3O-10 8/20/21 2706 70 0 0 0 772 3O-10 8/21/21 2707 71 0 0 0 777 Annular Communication Surveillance 3O-10 8/22/21 2714 71 0 0 0 796 3O-10 8/23/21 2718 71 0 0 0 799 3O-10 8/24/21 2717 70 0 0 0 793 3O-10 8/25/21 2716 69 0 0 0 790 Annular Communication Surveillance WELL_NAME DATE_PROD FTP_AVG WHT OIL_VOL+W ATER_VOL Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, July 27, 2021 11:34 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: KRU 30-10 (PTD 188-059) Update and monitor extension Attachments: 30-10 90 day TIO trend 7.27.21.pdf Chris, KRU 30-10 (PTD 188-059) was brought online on 6/28/21 for its 30 day monitor period and has exhibited some IA pressure increase, but it is inconclusive at this time whether the pressure increase is due to thermal expansion or AnnComm. CPAI plan's to extend the monitor period an additional 30 days to allow time for the well to stabilize or conclusively demonstrate any AnnComm. A follow up email will be made at the conclusion of the monitor period. A 90 day TIO trend is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well In rity Specialist CPF1 & CPF3 Sent: Monday, Jun 8, 20211:41 PM To: Wallace, Chris D (D <chris.waIlace @alaska.gov> Cc: Earhart, Will C <William. rhart@conocophillips.com> Subject: KRU 30-10 (PTD 188-059 date and plan forward Chris, Subsequent the previous report Slickline set a plug arid -attempted multiple MITTS which failed minutely, but there was no communication seen to the IA. The plug was the suspect source of MITT failure and was pulled. Due to observing no communication to the IA DHD then returned to well to perforrri'diagnostics, passing an MITIA to 3000 psi and a passing IA -DDT. When initiating the bleed for the IA -DDT the IA fluid level was.at surface, but during the bleed it was noted that charged fluid and then gas was bled off the IA. It is suspect that there may have been a trapped gas bubble deep in the IA which was disturbed during the original SW MITIA causing the IA pressure anomaly. At this point in time there appears to be no annular communication, as such, CPAI plans to bring the well onlnejor a 30 day monitor period to determine if the well has integrity or if the previous suspect IA pressure increase can be`activated by injection. I have attached a 10-426 of the passing diagnostic MITIA performed on 06/26/21. Please let me know if you disagree or have any questions with this plan. 1 Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, June 28, 2021 1:41 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 30-10 (PTD 188-059) Update and plan forward Attachments: MIT KRU 30-10 diagnostic MITIA 06-28-21.xlsx Chris, Subsequent the previous report Slickline set a plug and attempted multiple MITTS which failed minutely, but there was no communication seen to the IA. The plug was the suspect source of MITT failure and was pulled. Due to observing no communication to the IA DHD then returned to well to perform diagnostics, passing an MITIA to 3000 psi and a passing IA -DDT. When initiating the bleed for the IA -DDT the IA fluid level was at surface, but during the bleed it was noted that charged fluid and then gas was bled off the IA. It is suspect that there may have been a trapped gas bubble deep in the IA which was disturbed during the original SW MITIA causing the IA pressure anomaly. At this point in time there appears to be no annular communication, as such, CPAI plans to bring the well online for a 30 day monitor period to determine if the well has integrity or if the previous suspect IA pressure increase can be activated by injection. I have attached a 10-426 of the passing diagnostic MITIA performed on 06/26/21. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: �Ve Integrity Specialist CPF1 & CPF3 Sent: Friday,`Jurte 04, 20218:56 AM To: Wallace, Christi (DOA) <chris.waIlace @alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 30-10 (PTD 188-059) Report of suspect IA pressurization Chris, KRU 30-10 (PTD 188-059) (AIO 26.033) Passed its state witnessed MITIA yesterday. Shortly after the MITIA the IA pressure began increasing. Operations bled the IA pressure down multiple times, but the IA repressurized immediately after each bleed. The well was shut in and freeze protected. CPAI plans to secure the well and begin diagnostics with Slickline and DHD. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 TO: Jim Regg P.I. Supervisor 6l)(!/ SUBJECT: Mechanical Integrity Tests 111111 CmocoPhillips Alaska, Inc. 3410 FROM: Adam Earl KUPARUK IUV UNIT 3410 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 30(2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-10 API Well Number 50-029-21823-00-00 Inspector Name: Adam Earl Permit Number: 188-059-0 Inspection Date: 6/32021 . Insp Num: mitACE210607104559 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Salo —]Type Inj w TVD 6360 Tubing 2660 2660 - 2660 - 2660 - PTD 1880590 Type Test SPT Test psi 3000 IA 550 3300. 3150- 3130 - BBL Pumped: 10.4 " BBL Returned: 4.1 OA 220 520 520 - 520. Interval REQVAR P/F P Notes: MIT IA tested as per AIO 26.033 to Max Ant. Inj. Psi- ✓ Tuesday, June 8, 2021 Paec. I of I MEMORANDUM TO: Jim Regg 2 -710110W P.I. Supervisor I FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 29, 2020 SUBJECT: Mechanical Integrity Tests ConocoPLillips Alaska, Juc. 30-10 KUPARUK RN UNIT 30.10 Sre: Inspector Reviewed By: P.I. Supry3p- Comm Well Name KUPARUK RIV UNIT 30.10 API Well Number 50-029-21823-00-00 Inspector Name: Matt Herrera Permit Number: 188-059-0 Inspection Date: 6/22/2020 ✓ IDSA Num: mitMFH2O0623171830 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-10 "I�pe Inj µ TVD 6360 Tubing 1s7s - 87s • 1875. 1875 PTD 1880590 jype legt SPT Test psi 3000 IA 300 3300 3170 3150 BBL Pumped: 4.9 ' BBL Returned: 4.9 OA 20 • 50 50 50 Interval REQVAR P/F P Notes: MITIA to MAIP Per A10 211.033 ✓ Monday, June 29, 2020 Page 1 of 1 K9u W - i© Regg, James B (CED) ft I i0)1305go From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, June 18, 2019 4:15 PM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay, Wallace, Chris D (CED); Brooks, Phoebe L (CED) Subject: KRU 10-426 Forms for 3H & 30 Pad and 30-10 Si Tests Attachments: MIT KRU 3H PAD 06-16-19.xlsx; MIT KRU 30 PAD 06-16-19.xlsx; MIT KRU 30-10 SI Test 06-16-19.xlsx Hi All, Please see the attached 10-426 forms for MIT's performed 6/16/2019 on KRU 3H and 30 pad as well as the 30-10 shut- in test. Please let me know if you have any questions. Sincerely, Scwa,Ca-rU &0("k1A'l)I1Radial(.A.ut7k Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop com Cell: 907-331-7514 1 sara.e carlislePcon com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reaa(Walaska.aov: AOGCC.Inspectors(Qalask�jov Phoebe. brooks0alaska.Gov OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT / PAD: Kuparuk / KRU / 30 Pad DATE: 06/16/19 OPERATOR REP: Beck / Caudle AOGCC REP: _ chris.wallam4alaska.00v Well 30.10 ' INTERVAL Cotler Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I = Initial Test P = Pass PTD 1880590 Type Inj N I Tubing 1725 1725 1725 - 1725 - I = Industrial Wastewater Type Test P Packer TVD 6361 BBL Pump 5.1 IA 250 3300 3150' 3100 - Interval V Test psi 3000 BBL Return 4.8 OA 80 375 - 390_ 390 - Result P✓ Notes: MITIA to maximum anticipated injection pressure per A102B.033 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump A Interval Test psi BBL Return OA Result Notes: INTERVAL Cotler Result Codas TYPE INJ Codes TYPE TEST Cotler W = Water P = Pressure Test I = Initial Test P = Pass G=Gas O= Other(descdbe in Notes) 4=Four Year Cycle F=Fail S=Slung V= Required by Variance 1=Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 30-10 SI Test W-16-19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Ll Fracture Stimulate ❑ Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: temporary flowback > 30 days 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑ 188-059 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21823-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 30-10 ADL 0025513 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,830 feet Plugs measured None feet true vertical 6,767 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 8286 feet true vertical 0 feet true vertical 6361 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 Surface 4,970 12 5,005 Intermediate Production 8,783 7 8,816 Liner Perforation depth Measured depth 0 feet True Vertical depth 0 feet Tubing (size, grade, measured and true vertical depth) 2.875 J-55 8357 6414 Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER SAFETY VLV - PKR MD: 8286' PKR TVD: 6361' HB PACKER BAKER FVLD SSSV MID 1781' SSSV TVD: 1696' SAFETY VALVE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 500 1 Subsequent to operation: 1500 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 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 ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Devin Kozak Authorized Name: Devin Kozak Contact Email: Devin.Kozak@conocophillips.wm Authorized Title: Petro Engineer Contact Phone: (907) 263-4121 Authorized Signature: Date: 3/18/2019 urm w-ruw neviseu vrzoii t/'T'[•. q/311-7AVwh sol L Z mvwfFSWaB�uomn n v5n Id U1 Icy N ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 March 18th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 30-10 from Oil Production to Water Alternating Gas Injection service. 30-10 was operating as LZ an injector and had been injecting until 11/2/2018 when it was shut-in and flow back operations started 11/24/2018 for reservoir pressure management ahead of offset CTD drilling. On 3/14/2019, 30-10 was put back on water injection service. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 30-10 (PTD# 188-059) If you have any questions regarding this matter, please contact me at 907-263-4121 Sincerely, Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Well Schematic • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 15,2017 Jim Regg P.I.Supervisor' `1 7 6147 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-10 FROM: Lou Laubenstein KUPARUK RIV UNIT 30-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry `J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-10 API Well Number 50-029-21823-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-059-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607155521 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-10 - Type Inj W• TVD 6360 + Tubing 2800. 2800 • 2800 • 2800 - PTD 1880590 - Type Test SPT Test psi 3000 , IA 620 3450 • 3330 - 3310 - BBL Pumped: 5.8 ' BBL Returned: 5.7 ' OA 410 670- 660 . 650 Interval REQVAR P/F P ,/ Notes: MITIA per AIO 213.033 to MAIP SCANNED SEP 0 5 201 Thursday,June 15,2017 Page 1 of 1 PT I'etoS Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] �_ Sent: Monday, July 30, 2012 8:38 AM ( 14 8 .71 . 113 0 1( - z-- To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: KRU Monthly injector report for June Jim, Initial DHD Diagnostics on 30 -10 and 30 -12 were completed over the weekend. Passing MITOAs were achieved on both wells. The IC -pack off seals were re- energized and IC -POTs were performed. 30 -12 passed both the negative and positive pressure IC -POTs, while 30 -10 passed the negative and failed the drawdown POT. However, the OA drawdown tests for both wej fa led. The wells were in and freezeprotected yesterday and will remain so pending further diagnostics to include but not limited to MITIAs and repeat OA DDTs with IA pressure having been bled off. The proper paperwork and /or permissions will be asked for prior to bringing the wells back on -line. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc !!��W Desk Phone (907) Pager (907) 659 -7000 659-7224 909 sumo MAY 0 2 2D1 3 From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Thursday, July 19, 2012 10:18 AM To: NSK Problem Well Supv Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: KRU Monthly injector report for June 3F -04 (PTD 1852280): report IA pressure bleed on 6/16/2012 (took 2 days to bleed off IA pressure from 1300 to 800psi ?); what was the cause of pressure increase on 6/20 to 1500 psi followed by decline on 6/24 from 1500 to 800psi, and subsequent repressure of the IA to 1250psi as of 6/30? 0 -10 PTD 188059I;))T10 pressures plot indicates OA pressure is tracking IA pressure; this should be investigated 30-12 (PTD 1880410): same issue as 30 -10 3S -18 (PTD 2022060): Huff & Puff well; please add daily production volume to the tabular data for future submittals; otherwise it is not obvious if well is producing or Si when not injecting Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Sunday, July 08, 2012 9:33 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: KRU Monthly injector report for June 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 22, 2011 TO: Jim Regg P.I. Supervisor 1 1 y ( ' (Z 3/s'l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30 -10 FROM: Lou Grimaldi KUPARUK RIV UNIT 30 -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry •j, NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 30 - 10 API Well Number: 50 029 - 21823 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110620191354 Permit Number: 188 - 059 - Inspection Date: 6/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-10 'Type Inj. 1 W'1 TVD 6360 ' IA 580 622 626 632 P.T.DI 1880590 iTypeTest SPT Test psi 1820 , OA 267 1820 1754 1741 - Interval REQVAR P/F P _ Tubing 2850 L 2850 2850 2850 Notes: MITOA as required by CPAI intemal waivers. OA pressure fell below CPAI required 1800 test pressure. This test is not reported to AOGCC , 0-t.0 ! . : , 'OY C` E ( ' JUN a ' } Wednesday, June 22, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 22, 2011 TO: Jim Regg \t l ( 2 7f / P .I. Supervisor t f SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30 -10 FROM: Lou Grimaldi KUPARUK RIV UNIT 30 -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ., NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 30 - 10 API Well Number: 50 029 - 21823 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110620185521 Permit Number: 188 - 059 - Inspection Date: 6/16/2011 Rd Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3010 ' Type Inj. W •'TVD 6360 IA 790 3105 - 3073 3060. P.T.D 1880590 TypeTest SPT Test psi 3105 • OA 310 580 590 600 Interval REQVAR p/F P - Tubing 2850 2850 2850 2840 Notes: Fluid to surface, 5 Bbl's to pressure up 4.6 Bbl's returned. Stable test. ( - A--T-o x,(33 , , -w K fi 6 (2 e) t ec -47.=� p:'es,,, A: ,x J U' 2 4 201 Wednesday, June 22, 2011 Page 1 of 1 ~J MEMORANDUM To: Jim Regg ~7 P.L SuPervisor I~~~~ ~'~Z~l~ j FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-10 KUPARiJK RN LJNIT 30-10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~' Comm Well Name: KUPARiJK RIV iJNIT 30-10 API Well Number: 50-029-21823-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090626190840 Permit Number: 188-059-0 ~ Inspection Date: 6/26/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-10 Type Inj. W 1'~ 6360 jA 800 3000 ~ 2920 2900 P.T.D lssos9o TypeTest SPT Test psi is9o pA 32o a~o a~o a~o Interval ~Qvnx p~ r '~ Tubing z9so 29so z9so z9so NOtes• ~'ell has known Tubing x IA comunication when on gas injection. ~ ~Z~'~;0~3 r2 ~ ~tn,'~'-Sa- :~'~~u,~',~ t 5 ~~ i ti 1 eC~-ciy~ ~~~Sl~IP~- G. ~'l;'~~c~~~ ~- ~" - ~a S ~ r~~~~u.. C~L>l,t~l hh '~~' «f t~`~ i i l~ F' y fr ~l l,i : y ~rb 1, ~ ~ M Wednesday, July O1, 2009 Page I of 1 ~ . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, July O1, 2009 Jim Regg ~` / f P,I, Supervisor O~~ 71 ~Z/~ j SUBJECT: Mechanical Integriry Tests ~ CONOCOPHILLIPS ALASKA INC 30-10 FROM: Chuck Scheve Ktrr,~ux Fuv urrrr so-io Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RN L1NIT 30-10 Insp Num: mitCS090626192508 Rel Insp Num: API Well Number: 50-029-21823-00-00 Permit Number: 188-059-0 Inspector Name: Chuck Scheve Inspection Date: 6/26/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 30-10 Type Inj. W TVD 6360 ~ IA ~ao soo soo soo P.T.D 1880590 TypeTest SPT Test psi 1590 QA 320 1800 ~ 1740 1740 Interval ~QV~ p~ P Tubing 2950 2950 2950 2950 Notes: MITOA. Well has known Tubing x IA comunication when on gas injection. ~~; Z~: D 3 `3 ~ ~; r ~ -:~, ~~~~, t~t,'. F..~~... a Wednesday, July O1, 2009 Page 1 of 1 • 11 ~~' 1I ~1 S Co ocoPh p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder ~~ AUG ~ ~~ 2QG8 Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: L~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, 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, ~[ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor w ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 7/30/2008 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 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 30-10 (PTD 1880590) Report of~pect TxIA communication Regg, James B (DOA) • Page 1 of 3 From: NSK Well Integrity Proj [N1878@conocophillips.com] ~ ~ I ~~~ ~ ~~ Sent: Thursday, January 24, 2008 12:33 PM ')`~. To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 30-10 (PTD 1880590} Report of suspect TxIA communication Jim, Currently 30-12, 30-10, and 3Q-15 are the only wells in which e are currently planning a shortened MI cycle. "~ 30-12 has the highest chance for success (based on the trend from past cycles}. I have the AA application ready to send for that well, however want to complete the cycle first -which ends mid Feb. You will be receiving that AA application no later than 01 MAR08. The other 2 wells, 30-10 and 3Cl-15, are currently SI and will be brought on injection on the water 1 reenergize stage with this appraval. We will plan to wag them to MI around mid February. I'll send you a TtlfO update after they have been on I for a couple weeks (unless the communication is immediate in whioh case you'll be notified right away}. „/ I agree three is a enough wells to test the shortened MI cycle idea. Ifi it works and the process is manageable for both the Commission and CPAI we might pursue others, however do not currently have any plans to do so. Thank you far working with us on this idea. MJ Loveland Well Integrity Project Supervisor Conoco'hillips Alaska, Ino. Oftice (907} 659-7043 Ceii (967) 943-1687 ~~~~ ~ ~I~ ~ 12008 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, January 24, 2008 11:17 AM To: NSK Problem Well Supv; NSK Well Integrity Proj Cc: Maunder, Thomas E (DOA) Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication CPAI is authorized to inject MI on a shortened cycle once the tubing packoff and seals are reenergized for KRU 30-10, as recently approved for KRU 30-12 and KRU 3Q-15. A request for administrative approval under AIO 2B, Ruie 9 should be provided for continued operation of KRU 30-10 at completion of MI injection cycle (March 2008?). We do not consider this a "normal" well that would be exempt from the AA requirement. Please add KRU 30-10 to the monthly injector well integrity report you submit. This is the third well the Commission has approved. This effort is a good test to see if the shortened MI cycle will mitigate the TxIA communication, and so far, based on limited infio provided, appears to support your beliefs. Unless there are other WAG injectors you are ready to test in this manner now, our intent is to wait far the results of these 3 wells before considering others for the shortened MI cycle. If there are others, please provide ASAP. Jim Regg 1 /24/2008 30-10 (PTD 1880590) Report o~spect TxIA communication • Page 2 of 3 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, January 11, 2008 4:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication Tom /Jim, ~ ~ The initial diagnostics on 30-10 (PTD 1880590) have shown that the IA has integrity. On 118/08, the v~ell passed an MITIA, MITOA, and tubing packoff tests. The results of the tests are in the attached non-witnessed MIT form. The well had been on MI since May 4, 2007 and it is our belief that we can repair the communication souroe by reenergizing the tubing packoffs after the well has been on water far a few days (consistent with 30-12 & 3Q-15). The slow TxIA oommunication is attributed to the well head seals dryingout after the wel! has been on MI service for several weeks. The current T1110 after WAG to water is 22901250150. It is ConocoPhillips intention to gain approval from the Commission to continue MI injection in this well after the seals are reenergized on either a shortened MI cycle andlor a periodic seal reenergize PM cycle. .,-- ConoooPhillips will follow up with an AA request if that is appropriate next step ~ I have also attached is an updated 3 month TIRO plot. ~- Please let me know if this plan is acceptable or if you have any questions. Martin Walters From: NSK Problem Well Supv Sent: Wednesday, December 26, 2007 2:28 PM To: 'Regg, James B (DOA)'; 'tom.maunder@alaska.gov' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication 30-10 was WAG'd to water around 1030 am on 12125107. It will be shut in on 01101108 and will followup with the appropriate paperwork following the diagnostics. Please let me know if you need anything else. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1 /24/2008 30-10 (PTD 1880590) Report of spect TxIA communication • Page 3 of 3 From: Regg, James B (DOA) [mailnn.regg@alaska.gov] Sent: Monday, December 24, 2007 11:23 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication You may continue injecting water in this well as requested. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phase: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, December 24, 2007 8:38 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 30-10 (PTD 1880590) Report of suspect TxIA communication Jim, 30-10 (PTD 1880590) is suspected to have TxIA communication on MI injection. The IA maintains a 700 psi to 900 psi differential from the tubing and operates within ConocoPhillips guidelines, however if bled down the IA appears to repressure in 3 to 4 days. The current T/I/O =3790/2500/250. For safety reasons, ConocoPhillips requests approval to WAG 30-10 to water injection for a minimum of 7 days before being SI for diagnostics. Depending on the outcome of the diagnostics, ConocoPhillips will followup with a 10-403 for repair or an AA request for Water only injection. A 3 month TIO plot and a well schematic are attached. «30-10 schematic.pdf» «30-10 90 day TIO plot.gif» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1 /24/2008 KRU 30-10 PTD 188-059 T/UC7 pint - 3t~-1 ~ X000 ~, 2000 o. 1000 0 01-Nav-07 01-Dec-Ol Date ~~~ 150 ~. 100 0 50 0 01-Jan-08 L c: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. I ~~~ I~`v Kuparuk/ KRU/ 30-10 ~~~ 01 /OS/OS Ives /Bates Packer De Pretest Initial 15 Min. 30 Min. Well 30-10 Type Inj. N TVD ` 6,360' Tubing 2,300 2 0 2,300 2,300 Interval O P.T.D. 1880590 Ty e test P Test psi 1590 Casing 350 ,000 2,925 2,925 P/F P Notes: Non witnessed MITIA pre-AA OA 20 20 20 20 Well 30-10 T pe Inj. N TVD 6,360' Tubing 2,300 2,300 2,300 2,300 Interval O P.T.D. 1880590 T pe test P Test psi 1590 Casing 300 300 300 300 PIF P Notes: Non witnessed MITOA pre-AA OA 20 1800 1760 1750 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas 1=Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 30-10 01-08-08.x1s 30-10 (PTD 1880590) Report of~ect TxIA communication Page 1 of 2 Re James B DOA • 99, ( ) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, December 26, 2007 2:28 PM~ ~~ ~ ~ ~~ ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 30-10 (PTD 1880590} Report of suspect TxIA communication 30-10 was WAG'd to water around 1030 am on 12125/07. It wile be shut in on 01I01108 and will followup with the appropriate paperwork following the diagnostics. Please let me know if you need anything else. Brent Rogers Problem WeIIs Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December 24, 2007 11:23 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication You may continue injecting water in this well as requested. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, December 24, 2007 8:38 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 30-10 (PTD 1880590) Report of suspect TxIA communication Jim, 30-10 (PTD 1880590) is suspected to have TxIA communication on MI injection. The IA maintains a 700 psi to 900 psi differential from the tubing and operates within ConocoPhillips guidelines, however if bled down the VA appears to repressure in 3 to 4 days. The current T/I/O =3790!2500!250. For safety reasons, ConocoPhillips requests approval to WAG 30-10 to water injection for a minimum of 7 days before being SI for diagnostics. Depending on the outcome of the diagnostics, ConocoPhillips will followup with a 10-403 for repair or an AA request for Water only injection. 1 /8/2008 30-10 (PTD 1880590) Report of ect TxIA communication Page 2 of 2 A 3 month TIO plot and a well sche~~are attached. i «30-10 schematic.pdf» «30-10 90 day TIO plot.gif» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1/8/2008 30-10 (PTD 1880590) Report of~ect TxIA communication Page 1 of 1 • Regg, James B (DOA) From: Regg, James B (DOA) _ ~ ~ ` ~Z~Z~ `L Sent: Monday, December 24, 2007 11:23 AM~ ~ ~ To: 'NSK Problem Well Supv'; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 30-10 (PTD 1880590) Report of suspect TxIA communication You may continue injecting water in this well as requested. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~~~~~ ~~~ a ~ 2a~~ From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, December 24, 2007 8:38 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 30-10 (PTD 1880590) Report of suspect TxIA communication Jim, 30-10 (PTD 1880590) is suspected to have TxIA communication on MI injection. The IA maintains a 700 psi to 900 psi differential from the tubing and operates within ConocoPhillips guidelines, however if bled down the IA appears to repressure in 3 to 4 days. The current T/I/O =3790/2500/250, For safety reasons, ConocoPhillips requests approval to WAG 30-10 to water injection for a minimum of 7 days before being SI for diagnostics. Depending on the outcome of the diagnostics, ConocoPhillips will followup with a 10-403 for repair or an AA request for Water only injection. A 3 month TIO plot and a well schematic are attached. «30-10 schematic.pdf» «30-10 90 day TIO plot.gif» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 12/24/2007 nl- O~ hG'~ • ~; Cc~~~coPhll~ps Alaska, 1nc» 30-10..:.:-- - APL 50025 SSSV Type: TRDF sssv (na1-1762, ! Annular Fluid: OD:2.875) ~ i R f L Gas Lift andrel/Dummy Valve 1 (2954-2955, OD:4.750) Gas Lift 3ndrel/Dummy Valve 2 (51545155, OD:4.750) Gas Lift 3ndrel/Dummy Valve 3 (6357-6358, OD:4.750) Gas Lift 3ndrel/Dummy Valve 4 (69105911, OD:4.750) Gas Lift 3ndrel/Dummy Valve 5 (7338-7339, OD:4.750) Gas Lift 3ndrel/Dummy Valve 6 p7ssa797, OD:4.750) Gas Lift andrel/Dummy Valve 7 (8225-8226, OD:5.460) PBR (8272-8273, OD:2.875) PKR (8285-8286, OD:6.151) NIP (8323-8324, OD:2.875) TUBING (0-8358, OD:2.875, ID:2.441) Perf (8486-8498) Perf (8508-8532) Pert (8542-8562) KRU 30-10 - _ ----~ mangle @ TS: ~ 42 deg @8440 Angle @ TD: 42 deg @ 8830 e erence Last Ta : 8581 v a,~. TD: 8830 ftKB tea„ ,. '' Last Tag Date:. 6/3/2006 Max Hole Angle: 46 deg Co) 3600 _Casing String_- AL_L_STRINGS__ __ _ ~ ,~ Descri lion Size To Bottom TVD Wt Grade Thread , SUR. CASING 9.625 0 5005 4018 36.00 J-55 PROD. CASING 7.000 0 8816 6756 26.00 J-55 CONDUCTOR 16.000 0 115 115 62.50 H-40 , Tubing String__TUBING ~ i ~~ Slze I Tom .'S 0 Bottom_ -- 8358 _ __ _ TVD ~ Wt G-l1-l 6.50 I Grader Thread J 5~ CUE 8RD AB M(~D ~ ~ Parf~ratinns Summary __ I ~~ ~ ' I Interval I VD zone Status Ft SPF Dete T e comment 8486 -8498 6510 - 6519 A-3 12 12 3/27/1989 IPERF 2 1/8" EnerJet; 60 de h 8508 - 8532 6526 - 6544 A-2 24 12 3/27/1989 IPERF 2 1/8" EnerJet; 60 de h 8542 - 8562 6552 - 6567 A-1 20 8 6/27/1988 APERF 4 1/2" Ultrapak Csg; 45 deg. h ,Gas Lift Mandrels !Valves _ _ St MD rvD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt ~ ~ ~ 1 2954 2565 MMH FMHO DMY 1.0 BK-2 0.000 0 8!5/1989 2 5154 4124 MMH FMHO DMY 1.0 BK-2 0.000 0 8/5/1989 3 6357 4970 MMH FMHO DMY 1.0 BK-2 0.000 0 6/27/1988 4 6910 5362 MMH FMHO DMY 1.0 BK-2 0.000 0 8/5/1989 5 7338 5674 MMH FMHO DMY 1.0 BK-2 0.000 0 6/27/1988 ~{ 6 7796 6005 MMH FMHO DMY 1.0 BK-2 0.000 0 8/6/1989 I ~ ~ 7 8225 6316 Merla TGPD DMY 1.5 TG 0.000 0 8/5/1989 Qther (plugs~e ui ., etc.} - COMPLETION De th TVD T e Descri lion ID 1781 1696 SSSV Baker'FVLD' (Attempt to Lock Out on 4/{5 &7}/95 -Unsuccessful) 2.310 -, TESTED 6/27/0 1, CONFIRMED SSSV FU NCTION S PROP ERLY. ~ ~ 8272 6351 PBR Baker 2.375 ' Y 8285 6360 PKR Baker'HB' 2.375 I 8323 6388 NIP Camco'D' Ni le NO GO 2.250 ~i 8357 6414 SOS Baker 2.441 8358 6414 TTL 2.441 _ Fish -FISH p ~ De th Descri lion Comment ~ f l 8611 1 1/2" DMY Left in Hole 8/4/1989 ICI e e RECEIVED JUN 2 9 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Operat. ShutdownD 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 59' 8. Property Designation: Kuparuk River Unit ¡Ii> (.. &'>; l'i )1> ,.-z.f. 0(, 11. Present Well Condition Summary: Total Depth measured 8830' 6767' . true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size 115' 4946' 8757' 16" 9-5/8" 7" Perforation depth: Alaska Oil & Gas Cons. Commission Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 o o o Other Time Extension Re-enter Suspended Well Exploratory 0 Service 0 5. Permit to Drill Number: 188-059 1 6. API Number: 50-029-21823-00 9. Well Name and Number: 30-10 . 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool" feet feet feet feet Plugs (measured) Junk (measured) MD Collapse TVD Burst 115' 5005' 8816' Sf' ,~t\h\Jq.·..·.·~.·, 'iO?V", ,,¡¡-,,;;...&.. r. ~JUL, !;] Measured depth: 8486-8498, 8508-8532, 8542-8562 true vertical depth: 6510-6519,6526-6544,6552-6567 Tubing (size, grade, and measured depth) 2-7/8", J-55, 8358' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 8285' sssv= SSSV SSSV= 1781' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A NA NA Subsequent to operation N/A N/A N/A NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Marie McConnell / Perry Klein Printed Name Marie McConnell Signature ~ {/ o Form 10-404 Revised 04/2004 OR1G'~~AI Title Phone Problem Well Supervisor 659-7224 6/24/2006 .4'1> ,. '21(. oÞ SUbmilJf. i~... igin~l,9nly ~ /(Jß6 e 30-10 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 6/3/2006ISET 2.25" CA-2 PLUG @ 8323' RKB 6/22/2006 Weld Bradenhead. T/I/O=vac/O/O. Welded three pass seal weld on bradenhead. Rigged up purge & vent hoses on lA, OA and Conductor. Purged with N2 throughout seal weld. Final T/I/O=vac/O/O. 6/23/2006IMITOA passed (post BH seal weld).' See attached form. 6/24/2006IPulled CA-2 Plug @ 8323' RKB. Well returned to injection · MECHANICAL I-rEGRITY TEST (MIT) FORM e WELL NO.: 130-10 I DATE: 106-23-06 WELL TYPE: IWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA I i.e., Tbg, IA /9-5/8", OA 113-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TVPE(S) USED TO PRESSURE TEST: ¡Diesel R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an unna es. START TIME:11600 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING 0 0 0 0 T IA 0 0 0 0 PASS OA 0 1800 1740 1720 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING T IA OA 2 COMMENTS: START TIME: I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA OA 3 COMMENTS: r'SC COMMENTS, * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! []] -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION []] -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. []] -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. W"t I Rogers/Sauvageau I ness: . cc: PWS 6/3/00 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~'it." (; ( ?L /;f...;. '7 DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHIT.LIPS ALASKA rNC 30-10 KUPARUK RIV UNIT 30-10 Src: Inspector \<:&'0" 0 ~ q FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: ~,. .-; P.I. Suprv .J 5¡¿- Comm Well Name: KUPARUK RIV UNIT 30-10 Insp Num: mitJCr060613132202 Rei Insp Num API Well Number 50-029-21823-00-00 Permit Number: 188-059-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 30-"O-Type Inj. I ~ TVD i-~õ-'I"IAì-" 200 '-'1800 1700 I ï¿9Of"- 1------ P:T. 118iö5:~_21'peTest -1-sP.~1 Test psi! 159O'-! OA i 40 ---+.- I -+-- ¡--I Interval.. 4YR"rS~ PIF__. p __!ubingL~ .~~I·_6~-j--~_L~L_-= Notes 3.3 bbl's pumped for test. Short term shut in for braidenhead weld. SSV & SSSV was pumped open to monitor tubing pressure. Tubing was on vacuum. Tubing tail plug set for wellhead repair. SCANNE,D JUN 2, ? 2006 Wednesday, June 14,2006 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: June 28, 2002 THRU: Tom Maunder /~~/~ P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests PAl 3O multiple KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 30-05 ITypelnj. I G I T.V.D. I 6514 I Tubingl 3750 I 3750 I 3750 I 3750 Ilntervall 4 P.T.D.I 1880760 ITypetestI P ITestpsil 1629 ICasingI 1425 I 2050 I 2040 I 2040 I P/F I --P Notes: WellI 30-06 I Typelnj. I G I T.V.D. I 6415 I Tubing I 3675 I 3675 I 3675 I 3675 I"i'nter~all '4 P.T.D.I 1880600 Type testI P I Testpsil 1604 I Casingl 2600I 3000 I 2980 I 29801 P/F I -P Notes: WellI 30-07 ITypelnj. I S I T.V.D. 'i 6502 I Tubing[ 1500 I 1500 I 1500 I 1500 Ilntervall 4 P.T.D.I 1880770 Type testI P I Testpsil 1626 I CasingI 950 I 2250 I 2240 I 2240 I'" PIE I --P Notes: WellI 30-10 ITypelnj. I G I T.V.D. I 6360 I Tubingl 3600 [ 3600 I 3600 I 3600 Ilntervall 4 P.T.D.I 1880590 Type testI P I Testpsil 1590 I CasingI 2550I 3000 I 29801 29701 P/FI P Notes: we,,I 30-12 IType,nJ.I G I ~.V.~. 16404 I Tubingl 3650 13650 13650 13650 I'nterva, I 4 P.T.D.I 1880410 ITypetestl P I Testpsil 1601 I Casingl 760 I 2050 I 2050 I 2°°°1 P/F, I -P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Page 1 of 2 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 5 Attachments: none Number of Failures: 0 Total Time during tests: 4 hfs cc: none MIT report form 5/12/00 L.G. mit(l) kru 30 6-28-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_X WI to WAG Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 974' FNL, 3291' FEL, Sec. 22, T13N, R9E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic __ Service__X (asp's 525624, 6021844) 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or Property name Kuparuk Unit 8. Well number 30-10 At top of productive interval 1059' FNL, 2264' FWL, Sec. 21, T13N, R9E, UM At effective depth At total depth 1099' FNL, 3270' FEL, Sec. 21, T13N, R9E, UM (asp's 520367, 6021704) 9. Permit number / approval number 188-059 / 10. APl number 50-029-21823 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 15' SUR. CASING 4946' PROD. CASING 8757' Size 16" 9-5/8" 7" 8830 feet 6767 feet Plugs (measured) feet Junk (measured) feet Cemented 175 sx AS I 1750 sxAS III & 325 sx Class G 300 sx Class G Measured Depth 115' 5005' 8816' True vertical Depth 115' 4018' 6756' Perforation depth: measured 8486-8498;8508-8532;8542-8562 true vertical 6510-6519; 6526-6544; 6552-6566 Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 8358' MD. Packers & SSSV (type & measured depth) BAKER 'HB' @ 8285' MD. BAKER 'FVLD' (ATTEMPT TO LOCK OUT ON 4/{5 & 7}/95 - UNSUCCESSFUL) TESTED 6/27/01, CONFIRMED SSSV FUNCTIOI~ 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 1609 1785 Casing Pressure 700 Tubing Pressure 2896 700 4082 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil__ Gas__ Suspended_ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~-'~-"'~' C--~~'~,~y~f~~ Title Production Engineering Supervisor Jeff A. 'Spencer Questions? Call Jeff Spencer 659-7226 Prepared by Robert Christensen 659-7535 RBDMS BF L APR 2 9 2002 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 30-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary MICROFILMED 10/12/00 DO NOT PLACE ANy NE W MA TER/AL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS C, ONSERVATION COMMI,'~ION REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging Perforate ,. Repair well Other 1. Operations Performed: Operation Shutdown Pull tubing ~ Alter casing 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development Exploratory _ RKB 59' Stratigraphic _ 7. Unit or Property name service X Kuparuk River Unit ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 975' FNL, 1896' FWL, SEC.22, T13N, R9E, UM At top of productive interval 1059' FNL, 2264' FWL, SEC.21, T13N, R9E, UM At effective depth 1088' FNL, 2072' FWL, SEC.21, T13N, R9E, UM At total depth 1097' FNL, 2008' FWL, SEC.21, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 8830' feet Plugs (measured) true vertical 6 7 6 6' feet feet 8. Well number 30-10 9. Permit number/approval number 88-59 ! 9-403 10. APl number 50-029-2182300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8733' feet Junk (measured) 6694' feet 13. Casing Length Structural Conductor 80' Surface 4 9 70' Intermediate Production 87 83' Liner Perforation depth: measured 8542'-8562', true vertical 6551 '-6566', Size Cemented I 6" 175 SX AS 1 9-5/8" 1750 SX AS III & 325 SX CLASS G 7" 3OO SX CLASS G 8508'-8532', 6526'-6544', 8486'-8498' 6510'-6519' Measured dep~ True vertical depth 115' 115' 5005' 4018' 8816' 6756' Tubing (size, grade, and measured depth) 2-7/8 J-55 @ 8358' Packers and SSSV (type and measured depth) HB PKR ~ 8286', FVLD SSSV ~ 1781' Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL Intervals treated (measured) RECEIV'ED MAR 0 § Alaska Oil .& Gas 0o~$. Comrnissb~'~ Treatment description including volumes used and final pressure 14. Prior to well operation Subse({uent to operation Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 756 496 0 1168 0 0 3149 Tubing Pressure 142 1485 15. Attachments Copies of Logs and Surveys run DailY Report of Well Operations 16. Status of well classification as: Water Injector _X Oil Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE iml I D: KRU;'C I/NU./'DR ! LL I NB .,~ .? TEL N0:907-265-6218 I . Il I i I II v!cr~lfTY Map ALL WELLS LOCATED IN SEC. 22 T. 13 N., R. 9 E., UMIAT MERIDIAN. NOTES I, AIL COORDINATES ARE A.S.R, ZONE 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE 4. REFER. FIELD 8OOK 5. O.[ ELEVATIONS FROM CED-RIXX-$365,~ 6. HORIZONTAL POSITION BASED ON ~ CONTROL MONUMENTS PI[R L,DUN~$URY & W~ll ¥ ~ $'P$, ~, L~TITUDE .....LO~61TUO[ £~L. E~LEI~. ~ 6,0Z ~,095.27 5~5,478. Z7 ~8' ~?,338" 1490 47'~0.897" ~4' 1~4~' IT. 5' 2 6,022,075. ~ 525,490.94 70e~' 17.128 ",, 149° 41'30.5~" 745' J855'I 3 6,022,052, 13 525~.67 ~' 16.91~ !49047'~0. i~" 76~ 1867' 17.7, I .,,,,,.. ,,, ,.: ,..:11.5 6,0ZZ~8.¢ 525~528.38 7¢Z8' 1~5,, t49°47 29.4~" 81 I, 189~; 18. i 0 ~ I ' ~ 6'021,907, 12 S~S,~.?~ ~8', !~2~, 149 47.~.07 . 8~2, 19~ 18. I, 6,02~ ,gGS.~ 5~5,553.~ ~, l~059 ~4~47'28,G~' OS~ 1917, ~0.2, 149 47.~.~. 876; 19~, 16.3, 23.~ 6~0~1 ~. t2 5~ ~578.~7~ i5.632 149°47 27,974 897 194t 18.4 I0 6~021,84~ 525 ~623.61 ;~28' 14.~3" 149o47'26.6~'' 975' 1966' 18.7' II 6~021,822.~ 525,6~5.71 ~' 14.651" 149e 47'Z6.~5" ~7' 1998' 18.0' 23.5' ~ 6,02[ ,8~.87 525,648.~ 7~28', 14.4~7" 149=47'~.9~'* I0i9' 2011' 18.8' 251~ 13 6,02,779, t6 525 ~661.20 ~o~, 14. ZZ3" 149°47'25.5~" 1041'. 2024' 18.9,' 2~.0, 14 6,0ZI ,~7. ~ 5Z5 ~6~.~ · 149°47 24,8~ 2048, ~9.0, 15 6,02 ,735, 76 5Z5 ~6. iZ 11 6,OZI ,69~ 5Z5,7t0.85 ~' 13.369" 149047 Z4.0~ 112~ 2073' 19.0' 18 6,02 ! ,670.97 525 ,?Z~.~ ~25' t3. i57" 149°47'~3.7~3" 1149' 2~5' 19.0' 23.3' i , ,,, . _* , . ,,i .... - 1 HEREBY CE. RTl lrY THAT I AM Ti¢~: LAND SURVI[YING IN THE STATE oIr At, A~KA ANO THAT THIS PI. AT REPRESENTS, A .lOCATION SURVEY MAD~ BY ME OR UNDER. MY ~UPERVISION, AND THAT AL.I. DIMEN$1ON~ A/fO OTI. IF~ DETAII,~ Af~K CORRECT At 0¢ - - m ii m · i __ Alaska Inc. D.S. 3-0 WELL coNDUCTOR AS:BUILT . - .......m~A~D-~- , LOUNSBURY & sociates STATE OF ALASKA AI_AS~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. lnG, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 975' FNL, 1896' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1059' FNL, 2264' FWL, Sec. 21, T13N, R9E, UM At effective depth 1088' FNL, 2072' FWL, Sec.21, T13N, R9E, UM At total depth 1097' FNL~ 2008' FWL, Sec. 21~ T13N, R9E, UM 12. Present well condition summary Total Depth: measured 883 0' feet true vertical 6766' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-10 9. Permit number 88-59 10. APl number 50-029-21823 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8733' feet Junk (measured) 6 6 9 4' feet None Casing Length Structural Conductor 8 0' Surface 497 0' Intermediate Production 8 7 8 3' Liner Perforation depth: measured 8542'-8562', true vertical 6551 '-6566', Size Cemented 1 6" 175 Sx AS II 9 5/8" 1750 Sx AS III & 325 Sx Class G 7" 300 Sx Class G 8508'-8532', 6526'-6544', 8486'-8498' 6510'-6519' Measured depth True vertical depth 115' 115' 5005' 4018' 8816' 6756' Tubing (size, grade, and measured depth 2 7/8" J-55, 6.5# @ 8358' Packers and SSSV (type and measured depth) HB Packer @ 8286' FLVD SSSV @ 1781' 13. Attachments Description summary of proposal _ Convert well from oil producer to water injector. 14. Estimated-date for commencing operation 06-01 -89 16. If proposal was verbally approved Date approved Name of approver Detailed operation program _ 15. Status of well classification as: Oil :X Gas __ Service .,Water Iniector _ BOP sketch Suspended 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION ELSE ONLY Conditfons of approval: Notify Commission so representative may witness Plug integrity M BOP Test Mechanical Integrity Testx Approved by the order of the Commission Form 10-403 Rev 5/03/89 Location clearance Subsequent form require ~i'¢61NAL SIGNED 10- IApproval No. ~-~pproved Copy Returned Commissioner Date ~ '~/~'' ~ ? SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-5,10,12,17 Conversion to Water Injection Service Wells 30-5,10,12, and 17 are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these four wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. WELL Expected SB HI~. 3 O-5 28.00 psi 30-10 2300 psi 30-12 2450 psi 30-17 2500 psi 4 1. ~000 P.~I ?" W£LLH-~ CONN[CTOR FLANG£ :2. 5000 PSI WIR[LIN[ RAMS (VARIABL[ SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-OFF HIREL INE BOP Eo,u, 1PHENT ARCO Alaska, inc. Date: March 24, 1989 Transmittal #: 7447 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk AT©-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3 O- 16 Kuparuk Well Pressure Report I - 3 - 1 8 9 ---- 3 O- 10 Kuparuk Well Pressure Report 2 - 0 4 - 8 9 --'-' 3 O- 13 Kuparuk Well Pressure Report 2 - 0 8 - 8 9 ..,.,,~30-03 Kuparuk Well Pressure Report 1-09-89 ,.-- 3 O- 15 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 ~ 2 G- 14 Kuparuk Fluid Level Report 3-11-89 ~ 2G-13 Kuparuk Fluid Level Report 3- 1 1- 8 9 · "'~ 2G-09 Kuparuk Fluid Level Report 3 - 1 1 - 8 9 ~ 1 E-03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 ~ 1 E -05 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 3 O- 18 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 ~ 3 H - 1 0 Kuparuk Fluid-Level Report 3 - 0 9 - 8 9 ~ 3 A- 03 Kuparuk Fluid Level Report 3 - 0 9 o 8 9 ~ 3 H- 04 Kuparuk Fluid Level Report 3 - 0 4 - 8 9 ~2 B - 1 4 Kuparuk Fluid Level Report 3 - 1 3 - 8 9 ~ 3 O- 13 Sub-Surface Pressure Survey "2 - 0 8 - 8 9 ~30-10 Sub-Surface Pressure Survey 2 o 0 4 - 8 9 ~ 3 ©- 16 Sub-Surface Pressure Survey I - 31 - 8 9 ~ 1 B- 0 7 Kuparuk Fluid Level Report 3 - 3 1 - 8 8 ""'"'..1 B - 0 3 Kuparuk Fluid Level Report 1 - 2 7 - 8 8 ~ 1 B - 0 5 Kuparuk Fluid Level Report 1 - 2 7 - 8 8 '"'"'~1 B -0 7 Kuparuk Fluid Level Report 4 - 2 7- 8 8 ~ 1 B - 0 7 Kuparuk Fluid Level Report 1 - 2 7 - 8 8 ~ 1 L- 0 8 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 '~,.,,~1 L- 0 4 Kuparuk Fluid Level Report 2 - 1 2 - 8 8 '"~3 H- 1 0 Kuparuk Fluid Level Report 7- 8 9 ~ 3 M- 0 1 Kuparuk Fluid Level Report Sand 'A' Sand 'A° Sand 'A' Sand 'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing Ca.' ~'~ Con:. Commissiorl Anchorage '~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '"'""~3 O- 18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~""'~O-18 Kuparuk Fluid Level Report 3-1 7-89 Casing ~'~::~ BO-09 Kuparuk Fluid Level Report 3-1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 8 9 Casing Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil A~chorage 3H-01 3B-13 1E-29 1C-05 3M-17 2Z-20 30-10 31-12 3H-10 Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report BHP Report 2-15-89 Casing 2-17-89 Casing 2-15-89 Casing 2-18-89 Casing/Tubing 2-16-89 Casing 2-18-89 Tubing 2-16-89 Casing 2-20-89 Tubing 2-13-89 BHP Receipt Acknowledged: ....... Date' DISTRIBUTION' D&M ..__State of Alaska . SAPC 'Unocal .~ Mobil Chevron ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1 E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12 12 12 -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-2O-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-1 9-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing 'Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' Amerada Casing Casing c si.g Casing Tu i.g Tu in Casin~ Casin~ ,.~' - STATE OF ALASKA ([~/ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~. GAS ~] SUSPENDED ~l ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number 88-59 ARCO Alaska. Inc. ' 8. APl Number 3. Address 50- 029-21823 ~4. Lo(~a[i[::)~ o-~-~v'ell' ;t-s-u;f-a~:e .......... =-' ............. 9. Unit or Lease Name Kuparuk River Unit 975' FNL, 1986' FWL, 5ec.22, T13N, RgE, UN At Top Producing Interval 10. Well Number 1059' FNL, 2264' FWL, 5ec.21, T13N, RgE, UM 30-10 At Total Depth 11. Field and Pool 1097' FNL, 2008' FWL, 5ec.21, T13N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59'I ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 06/11/88 06/15/88 08/23/88*I N/A feet MSLI 1 ~17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 8830'MD/6766'TVD 8733'MD/6694'/TVD YES [] NO []I 1781 ' feet MD 1700'(approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, CAL, GR'~ CET, Gyro 23. CASING, LINER AND CEMENTING RECORD ... SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" ~?~r~ H-~D (~,_,r~ 1!5' 2~.'' !75 :x AS q-SIR" ~,I:;.0.~ _I-Cat, &,,r~ 5005' !2-!/4" !750 SX .~.S !l! & 325 *..x C.ess C - _ ....... , .......... ~ ~ ~ ,,~ ~.. ~ , 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) Perforated w/8 spf, 45° Phasing 2-7/8" 8358' 8286~ 8542 ' -8562 'MD/6551 ' -6566 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adder~lum, dated 10/26/88, for Fracture data. 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 IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 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 6/17/88, Perforated well and ran tubing 6/27/88. Fractured wel 1 8/23/88. ' .' ~lch0rage Form 10-407 Submit in duplicate Rev. 7-1-80 WC5/081 CONTINUED ON REVERSE SIDE . . GEOLOGIC MARKERS FORMATION TESTS ,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8441' 6476' N/A Base Kuparuk C 8451' 6483' Top Kuparuk A 8472' 6499' Base Kuparuk. A 8613' 6604' " 31. LIST OF ATTACHMENTS Addendums (dated 10/26/RR & g/l~/gg) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engineeroate ~lt' ~--~/z~ ~ 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 inositu combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 30-10 6/19/88 Rn CET f/8720'-7346'. Rn gyro f/8720' - surf. 8/23/88 Frac Kuparuk A sand perfs 8542'-8562' per procedured dated 8/19/88 as follows: Spot 11 bbls 10% Musol @ 1.5 BPM, 2700 psi day before frac. Pmp 150 bbls gelled diesel pre-pad @ 22 BPM, 7000-5180 psi. Pmp 550 bbls gelled diesel pad @ 20-22 BPM, 5200 avg psi. Stage 1: Pmp 30 bbls gelled diesel, 2 ppg 16/20 @ 22 BPM, 4980 psi Stage 2: Pmp 45 bbls gelled diesel, 4 ppg 16/20 @ 21 BPM, 5150 psi Stage 3: Pmp 60 bbls gelled diesel, 6 ppg 16/20 @ 21.3 BPM, 5400 psi Stage 4: Pmp 60 bbls gelled diesel, 8 ppg 16/20 @ 20.6 BPM, 5650 psi Stage 5: Pmp 36 bbls gelled diesel, 10 ppg 16/20 @ 18-20 BPM, 6320 psi Go to flush, lost all pmps. Attempt to come back on line. Pmp 19 bbls @ 10-15 BPM, 5400 psi; formation screened out. Est'd 10 bbls flush stayed in tbg. Fluid to Recover: 838# Sand in Zone: 33,552# 16/20 Carbolite 9/26/88 MIRU CTU. Tst BOPE to 4000 psi. RIH, wsh'g w/0.5 BPM & 300 scf N./M. Tagged hard sand fill in tbg @ 7500'. Inc'd to ~.0 BPM & 600 scf N?/M, 3800 psi. CBU, ck choke samples. Switch to diesel displacement, POH. RD CTU. Turn well~ over to Production. 9/28/88 High volume hot diesel wash in attempt to open up annulus for high rate injection. Wash did not improve injectivity. Perform a slow rate Arctic Pak on well. · Drilling Supervidor Oil & o.. ' '_~i~;horage ADDENDUM WELL: 7/23/88 30-10 R/U hot oil. Test to 4000 psi. Pump 21 bbls hot diesel (180°F) w/ 5% Musol, 1½ bpm, 2800 psi. Pump 54 bbls hot diesel (180°F), 1½ bpm, 2700 psi. Displace 1 bbl above perfs. Secure well. Drilling Super Oil .& ~ o Anchorage SUB-SURFACE DIRECTIONAL URVEY ~]UIDANCE [~]ONTINUOUS I~OOL. Company ,, Well Name FieldlLocation KUPARUK, NORTH SLOPE, ALASKA · i i II I ARCO ALASKA, INC ~.~,'~:u:._i,~,.i I i I 30-10 (975' FNL, 1986' FWL, SEC 22, T13N, RgE, UM) Jo.b, Fleferen. ce No. 72849 Loaaed 8¥: MCBRIDE Date 19-JUNE-88 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY FOR ARCO ALASKA, INC, ] O-lO KUPARUK NORTH SbOPEtALASKA SURVEY DATE~ 19-JUN-B8 ENGINEERI M, MCBRIDE METHODS OF COMPUTATION TOOL LOCATION) TANGENTIAL- Averaqed deviation and azimuth INTERPOLATXONI LINEAR VERTICAL SECTION~ HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 89 DEG 54 NIN N~T ARCO ALASKA~ INC. 3 0"10 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATEI 13-dUE-88 PAGE I DATE OF SURVEY1 KgbbY BUSHING .ELEVATIONI 59 0.. 0 let ENG/NEBR1 M',: MCBRXDE INTERPOLATED VALUES FOR EVEN I00 FEET OF AEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 100.00 200.00 300, 400.~°0 500 O0 600 O0 7OO O0 600 O0 900 O0 0 O0 lO0 O0 2OO O0 3OO O0 399 99 499 99 599 99 699 90 799 40 898 07 -59 O0 41 O0 141 O0 241 O0 340 99 440 99 540 99 64090 740 40 839 0 0 N 0 0 E 0 15 N 39 37 E 0 21 N 53 16 E 0 2i N 59 45 E 0 19 N 65 23 E 0 9 N 62 13 E 0 18 N 25 13 W 3 57 $ 81 10 W 732 S 83 16 W 07 10 52 $ 88 17 N O0 4O 50 6O 7O 8O 190' O0 O0 1091 O0 1186 O0 1279 O0 1370 O0 1460 O0 1546 O0 1630 0 17 72 1032 44 1127 53 1220 93 1311 15 1401 45 1487 04 157 27 165~ 17 1730 995 61 936 61 14 32 72 17 13 44 20 16 53 22 32 93 25 20 15 28 29 45 32 1 04 34 2~ 27 37 17 40 40 S 89 39 W N 89 43 W N 89 8 W N 87 57 W N 86 10 W N 85 5W N 84 47 W N 84 29 W N 84 22 W N 83 55 W I000 100 O0 O0 260~ 27O O0 1862 98 1803.98 43 46 O0 1934 75 1875.75 44 8 O0 2007 02 1948 02 43 3 O0 2081 oo°° O0 23O4 O0 2378 O0 2452 O0 2525 37 2022 37 40 58 31 2098 31 40 34 05 2173 05 43 2 68 2245 68 43 15 36 2319 36 41 54 35 2393.35 43 3 07 2466.07 43 8 N 85 3 W N 88 1 W N 87 43 W N 86 55 W N 86 34 N N 86 25 W N 86 9 W N 85 27 ~ VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 0,00 o02 -1,95 -1,99 1,52 11,24 27,42 49 37 76 94 I08 96 45 45 185 95 230 93 823 3~ 87 393 91 456 27 523 36 592 88 76 793 72 860 02 928 63 996 06 0 O0 0 41 0 15 0 05 0 O0 0 34 I 68 3 59 4 73 3 28 N 85 50 W 1063 14 N 85 28 w 1131,6o 3 63 2 31 301 2 68 2 45 4 O3 3 39 3 46 0 76 2 53 I 88 0 88 2 73 I 52 1 48 2 O6 I 54 RECTANGULAR COORDINATE& HORZZ NORTH/SOUTH EAST/WEST DISTo I AZIMUTH FEET FEET FEET DEG 0,00 O0 0 0 E °.!i O, ~,25 42 E 0 54 0,49 9 E ,.o t i: 1 14 1,54 92N N. 53 28 E 1,54 1,99 ~,52 Ii! 1,51 0,21S 11,25 25 27,42 w 21 1,26 45 I 5 49,37 49 39 89 45 5 145,45 2O 60 394 38 456,23 457 33.80 523,30 ~ 524,39 86 6 47.00 793.~ ~ 795.03 86 55.46 928,53 930,18 60,42 ~ 96 ~ 995, 997.79 65,59 ~ 1063.03 ~ 1065.05 1131,48 1133.68 70.66 86 M 3000 O0 2598 58 2539,58 42 22 41 2613 4] 42 30 N 84 52 W 1199 16 0 N 84 35 W 1266 32 0 69 0 26 2 10 ,29 34 10 25 0 3100 3200 t300 400 500 6OO 7OO 8O0 3900 O0 2 72 O0 2~46 O0 2819 28 oo oo O0 O0 O0 3241 04 2687' 2760,04 42 37 N 84 28 W 1333 52 ,52 42 54 N 85 39 W 1401 , 89 3 540 4 612 684 89 88 3042. 45 52 3112,52 45 39 N 89 28 W 1756 78 3182.78 45 12 N 88 31 W 1827 25 03 89 15 95 74 98 01 O0 42 ~00 100 .36 ,66 I 61 06 N 1333 14 N 1401 74 469 44 6 2 48 1755 72 ~ 1827 54 W t3 10 W 1404 543 1829 32 N 86 6 W 86 ~ 86 95 ARCO ALASKA, INC. 3'0'20 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATEI 23-00L-88 KELLY 8U~HZNG ~bEVAT~ON! 5V.O0 FT TRUE MEASURED VERTICAL DEPTH DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR~Z,~ DEPAR?URE VERT~CA~ PEV~ATION AZIMUTH SECTION SEVERITY NO~TH/SOUTH EAST/WEST DI~T. AZIMUTH DEPTH DEG MIN DEG ~IN FEET DEG/200 FEET FEET FE 4000 O0 331 253 36 450 4]00 4400 4500 4600 4700 4800 4900 O0 3594 O0 3663 O0 373] O0 3802 O0 3872 O0 3943 604 09 3674 87 374] 98 381] 29 3884 28 46 5 57 46 6 09 45 50 87 45 39 98 45 20 29 45 28 '500 4O 550 $6O 570 .5~0¢ 590~ O0 4013 78 3954 78 44 53 O0 4084 97 4025 97 44 31 O0 4156 O0 4226 O0 4296 O0 4366 O0 4436 O0 4506 O0 4576 O0 4646 06 4097 64 4167 78 4~37 69 4 07 46 4377 02 4447 12 4517 75 4587 06 44 53 64 45 18 69 45 46 45 50 02 45 55 11 45 5 75 45 4 60OO 6~00 6~00 6300 640O 650~ 660 6700 6800 6900 O0 471734 O0 4788 O0 4858 O0 4929 O0 4999 O0 5O7O O0 5140 O0 5210 O0 5281 O0 5354 4658,34 45 2 16 4729,16 44 50 95 4799,95 45 2 48 4870,48 45 15 80 4940.80 45 20 10 5011.10 45 19 42 5081,42 45 18 71 5151,71 45 22 80 522~,80 43 48 35 5295,]5 43 24 7000 O0 542695 5367.95 4326 7100 O0 549972 5440.72 43 8 7~00 O0 5572 43 0 7300 O0 5645 7400 O0 571830 5659.30 5731.69 43 40 7500 ?? oo 7900 O0 5790 O0 5862 O0 5935 O0 6007 O0 6079 80 5513,80 75 5586,75 43 24 4331 69 98 5803.98 43 44 26 5876.26 43 41 45 5948.45 4351 52 6020,52 43 53 N 87 55 W 1898 06 N 87 29 W i968 N 87 6 W 2039 N 88 30 W 2110 $ 89 2 W 218i S 89 30 W 225 3 $ 8954 W 2325 N 8957 W 2397 N 89 31W 2468 N 8856 ~ 2539 67 29 06 61 7! 59 22 53 63 033 025 027 273 052 065 018 034 037 038 10494 Ni968189788 49 1111070977 NN N i6Ii'iW . N 2181 N 8 W 8 N 2325 N 12 9O N 2397 N 13 22 N 24~8 N ~14 27 N 2539 N 1~ 2 9 33 W 247, 93 44 ~ 2542,00 N 88 46 W 2610 55 N 8923 W 2680 76 N 89 26 W 2751 N 89 22 N 282 N 89 18 N 2893 N 89 22 ~ 2964 N 8926 w 3036 $ 89 40'~ 3 108 S 8548 ~ 3179 $ 8528 ~ 3249 10 93 20 35 28 42 98 1,40 0,22 0,42 0,37 0'03 0,20 0,21 2,51 0,69 0,27 115 65 N 2620 116 75 N 26 80 117 118 112 47 N 2750 20 N 2821 02 289 59 303 310 03 N 3179 59 N 3249 35 W 26t2 56 W 265~ 90 ~ 27 73 w 2824 99 ~ 2895 50 2966 14 ~ 3038 N8 01plr 44 33 N 2 S 8512 ~ 3320 57 $ 84 45 W 3390 90 $ 8430 W 3461 S 84 22 W 353! $ 84 16 ~ 3602 S 8413 w 3673 $ 84 5 ~ 3743 $ 8359 w 3814 $ 8355 w 3884 $ 835O W 3953 i9 74 48 23 95 68 6O O1 055 0 0 19 0 O4 0 O4 0 1 96 0 17 ,69 ~ 3390.73 3392 88 87,17 ~ 3531.60 3532,67 88 ,,: : 3673,11 3693 88 7301 65.78 3743.84 3744 , 38~4,58 3815 89 5098 3884.52 ~ 3884,85 $ 83 41 ~ 402137 $ 83 22 W 4089 50 S 84 3 W S 8355 ~ 4293 S 8346 W 4362 $ 8329 W 4430 S 83 7 w 4499 $ 82 51W 4568 $ 8249 W 4636 27 20 65 23 89 5O 17 95 0,25 0,47 0,31 0,60 0,24 0,31 0,24 0,15 0,11 0,31 36,20 N 402~ 28,50 N 408 20,40 N 4157 12,66 N 4225 5,52 N 4293 I 87 S 4362 952 $ 4430 1758 $ 4499 2604 $ 4568 3470 $ 4637 31 M 402147 N 89 ~9 M 46 ~ 4089 56 N 896 W 24 W 4157 ~9 N~; 43 W 19 W 4225 1 N 49 W 65 w 429365 N 89 59 W 24 W 4362 24 $89 58 W 91 w 443O 92 S 89 52 W 5' w 4499 58 S 89 46 W 23 w 4568 30 $ 89 40 W 01 W 4637 24 S89 34 W ARCO AbASKA, INC, 3 0'10 KUPARUK NORTH SbOPE,AbASKA COMPUTATION DATEI 13-dtJb-88 PAGE DATE OF SURYEYI 19-JUN-SE KEEE¥ BUSHING EbEVATZONI 59,00 ENGINEERI M. MCBRIDE INTERPOEATED VAbUE$ FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEA$_U RTICAL VE ICAL DE IATION AZIMUTH DEPRED?H VE RT V DEPTH DEPTH DEG MIN DES VERTICAb D~GbEG RECTANGUbAR COORDINATE& HORZZ,..DEPAR?URE SEC~'ION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 6151 77 6092.77 43 32 O0 6224 , O0 6297 41 6238, .86 42 25 °° 00 8 O0 8400 8500 O0 8800 8830 O0 6370 O0 6445 O0 6519 O0 6594 0 6660 0 6744 00 6766 46 6165 46 43 15 $ 82 16 W 4! 42 58 86 6311 02 6386,02 41 49 72 6460.72 41 36 45 6535.45 41 37 27 6610,27 41 36 04 6685,04 41 36 47 6707,47 41 36 S 82 29 W 4705,50 477~,54 S 82 16 W 484 ,30 S 82 13 W 4908,53 S 82 5 W 4974,98 S 81 36 W 5040.78 S 81 14 W 5106.45 S 8122 W 5721 ,02 $ 81 22 W 5237.65 S 81 22 W 5257,34 0,57 0,05 52 0,27 61 0,85 70 0.95 80 0,20 89 0,00 99 0 O0 0:00 119 0,00 122 43 50 S 4705 58 W 4705 78 $ 89 28 W 64 S 4773 85 S 4841 99 $ 4908 08 $ 4975 54 S 5040 49 S 5106 52 S 5472 47 S 5237 45 $ 5257 64 W 4773 41W 484~ 66 W 490 13 w 4975 95 W 5041' 63 W 5107 22 W 5173 87 W 5239 57 W 5258 93 S 89 22 W 81 S 89 16 W 889 lOW 74 $ 88 58 W 60 $ 88 53 W ) , 8 S 88 47 W 3 S8641W 99 S 88 39, W ARCO AbASKAw INC, 0-10 ~UPARUK NORTH SbOP£wAbASKA COMPUTATION DATEI 13-dUb-BE 'PAGE DATE OF SURVEYI 19,,JUN,,O8 KEbb¥ BUSHING EbEVATIONI 59,00 ENGINEER I N.: MCB.R'IDg INTERPObATED VAbUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAE VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG. MIN DEG 0 O0 000 000 000 4000 50 883O 00 995 00 1862 00 2598 00 3312 00 4013 00 4717 00 5426 O0 6151 O0 6766 0 O0 -59,00 I 936 ~8 1803 58 2539 36 3253 78 3954 34 4658 95 5367 77 6092 47 6707 0 0 61 14 32 98 43 46 58 42 22 36 45 0 78 44 53 34 45 2 95 43 26 77 43 32 47 41 36 VERTICAL DOGbEG RECTANGULAR COORDINATES HORIZ,, SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, FEET PEG/lO0 FEET FEET FEET N 0 0 E 0 O0 $ 89 39 W 49 37 N 85 3 W 523 36 N 84 52 W 1199 16 N 87 55 W 1898 06 N 8R 46 W 2610 55 S 85 12 W 3320 57 S 83 41 W 4021 37 S 82 29 W 4705 50 S 81 22 W 5257 34 DEPARTURE AZIMUTH DEG MZN 0 O0 3 63 3 46 0 43 0 33 I 4O 0 55 0 25 0 57 0,00 0 00 N 1 33 76 104 115 106 36 43 122 52 S 49 80 N 523 39 N 1199 94 N 1897 65 ~ ~10 84 N 20 20 N 402 50 8 470~ 45 8 5257 0 O0 E 37 W 49 30 W 524 03 W 1201 88 W 1900 35 W 26 31W 402~ 58 W 470 57 W 5258 0 00 N 0 0 E 39 S 8814 W 39 g 86 18 W 46 N 86 11 N~88 9 W 47 N89 iiW 78 $ 89 W 99 '$ 88 W ARCO ALAAKAA INC. 0-10 ~UPARUK NORTH SLOPE,ALASKA COMPUTATION DATE~ 13-dUb-88 PAGE DATE :OF SURVEYI 19'jUN'BB KEb~Y BUSHZNG EhEVATIONI 59.00 ENGIN~KR: N,.:~.MCBRIDE INTERPOLATED VALUE& FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAb VERTICAb DEVIATION AZ~HUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 O0 59 O0 59 O0 59 O0 35~ O0 559 659 0 759 3~ 860 29 0 O0 59 O0 15900 259 O0 359 O0 459 O0 559 O0 659 O0 759 O0 859 O0 -59 O, 100 200 300 400 5OO 600 700 800 0 0 0 N 04i E 0 0 7 N I E O0 022 N 47 E O0 0 21 N 59 35 E O0 019 N 6321E O0 0 15 N 67 2 E O0 0 6 N 1034 E O0 2'20 $ 84 55 W 00 557 S 8112 W O0 9 41 $ 8641W 96_2 065 386 86O 094 29 1159 82 1259 85 1359 70 1459 79 1559 28 1659 68 1759 48 1859 959 O0 O0 VERTICAL DOGLEG RECTANGULAR COORDINATE& HORIZ,! DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DISTe' AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG HIN 0 O0 0 O0 *0 -1 33 - '02 -0°6? 6.59 20.32 1900'00060 13 6 S 8938 W 40 ,00 16 28 N 8954 N 67 O0 1100.00 19 21 N 89 19 W 99 O0 1~00~00 22 0 N 8819 W 137 O0 1300.00 2458 N 8624 W ~80 O0 1400.00 2826 N 85 6 N 230 O0 1500.00 3231 N 8440 W 289 O0 1600,00 35 17 N 8425 W 355 O0 1700,00 39 6 N 8422 W 431 O0 1800,00 4341 N 8449 W 519 0 O0 038 00l 0 O0 0 O0 010 033 424 34O 288 0.00 N 0,00 E 0.02 N 0,00 0.38 N 0.29 E 0 0.74 N 0.80 E 1 1.04 N 1,33 E 1 ~.26 N 1.82 E 2 1,42 N 2'02 g 1.54 N 0.67 E 1 97 S 20,32 W 2 0 O0 N 00 E N 44:E 29 # 8 69 21 N 55 14 E 47 N 55 302 68 N 23 60 N 86 15 # 35 S 8716 W 07 08 43 32 04 92 20 56 388 2 17 2 2 8O 3 99 3.50 3.46 . 46 S 40 .56 $ 67 1,35 S 99 0.61 $ 137 140 N 180 526 N 230 1042 N 289 16 85 N 355 24 25 N 431 33 47 N 519 07 W -99 08 W 137 42 W 180 31 W 230 02 W 289 90 W 35~ 16 W 43 50 ~ 520 4036 $ 8755 W 0588839N 08 'S 8913 W 08 $ 89 44 W 43 N 8933 # 37 N 8841N 56W 29 N 84 N 86 58 N 86 18 W 2133 2270 2402 2537 2673 2809 2946 3081 3219 3354 782 3924 4065 4207 4349 4493 4639 4780 72 1959 O0 1900.00 43 55 4133 26 2059 23 2159 06 2259 93 2359 09 2459 32 2559 80 2659 61 2759 06 2859 O0 2000.00 O0 2100.00 40 35 O0 2200.00 43 34 O0 2300.00 42 9 O0 2400,00 43 15 N 88 5 W 616.31 N 87 9 W 709.18 N 8634 w 795.17 N 8623 W 885.41 N 8535 W 978,65 N 85 53 W 1069,32 N 85 8 W 1163.03 N 8437 W 1254.08 N 84 29 W 1345056 N 87 9 W 1438,12 2959 O0 3059 O0 3159 O0 0 72 2 15 096 087 183 183 0 82 030 0 05 189 44 3259 93 3359 29 3459 3O 3559 41 3659 17 3759 10 3859 O0 3200.00 4510 N 8819 W 0000 330340§.00 44 455~~ 873~ ~ 1944 ,O0 87 2044 O0 350~.00 45 4~ ~ 89 51 ~ 2145 O0 360~.00 46 89 27 2248 O0 3700,00 45 46 $ 89 54 W 2352 O0 3800,00 45 22 N 89 37 W 2454 2900,00 45 41 N 89 32 W 1535 64 3000,00 46 7 N 89 34 W 1639 90 58 0 96 24 0 36 0 2 29 068 3850 N ~ 24 W 617 45 N 863 ~5 W 4226 N 11 W 710 37 N 86 5 W 4.7 08 N 795 w 79648 N 86 36 w 52 65 N 885 ,2 W 886 88 N 86 35 W 59 06 N 978 55 W 980 33 N 86 32 # 81 45 N 1253 94 ~ 1256 58 N 86 17 ~ 90 20 N 1345 41 W 1349 43 N R6 9 # 56 1 27 112 41 113 17 N 1844 75 1944 35 ~ 2044 60 2145 30 ~ 2248 93 N 2352 11N 2454 40 W 1847 2251 05 W 2354 17 N 2456 29 N 86 47 W 28 ~ 86 N 86 5 8'/ 76 N 87~ ~/ 77 N 87 25 ARCO AbASKA, INC, $ 0-10 KUPARUK NORTH SbOPE,AbASKA CORPUTATION DATE{ 13-JUL-88 DATE OF SURVEY :$9-JUN~88 KELLY BUSHING EbEVATZON~ 59,00 'let ENGINEERI M,. MCBRIDE INTERPObATED VAbUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICATa DOGLEG RECTANGULAR COORDINATES HORIZ, DE.PAR~URE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN FEET DEG/IO0 FEET FEET fEET D~G NIN 492235 3959 O0 3900.00 4516 8849 2555.51 0,32 114,46 2555,32 2557,88 ~ 7 2657, 2655,05 116, 2655 0,60 89 13 ,25 5204 15 4159 O0 4100,00 44 54 ~ 89 26 2754,03 0,42 117,50 2753,83 2756' 87 5346 07 4259 O0 4200,00 45 27 89 20 ~ !18'57 2854,52 2856, 0,32 54 4400.00 45 4459 O0 5~ 29 3!62.20 2,35 119, 86 : 3263* 591734 4659 O0 4600.00 455'~ S 8526~ 3262 O.a~ I11,62~ 3262,03 ~ 88 3461.08 3462. 620007 4859 O0 4800e00 45 76 ~456 594 96 495~: 21 505 42 55 405359 ~0 5459 2 5559 3 5659 9 5759 50 5859 O0 4900,00 45 18 O0 5000.00 45 20 O0 5100,00 45 19 O0 5200,00 44 25 O0 5300,00 43 25 O0 5400,00 43 19 O0 5500.00 43 0 O0 5600.00 43 28 O0 5700,00 4338 O0 5800,00 4344 S 84 19 W 3561 S 84 14 W 3662 S 84 4 W 3762 S 8355 ~ 3862 S 83 49 N 39 57 88335 W 4051 S 83 3 W 414 4 S 849 ~ 4237 S 8350 W 4332 S 833O N 4427 41 O6 62 57 38 47 49 66 17 014 0 O0 004 230 019 040 024 032 046 024 84 24 N 3561 74 14 N 366 63 53 43 32 21 7i,53 6059,00 6000,00 43 54 S 82 48 W 4617,36 ~:23 32 B009,97 6159,00 6100,00 43 30 S 82 27 N 4712,29 54 44 8t47,40 6259,00 6200,00 43 10 S 82 15 N 4805,70 0,42 57 8283.93 6359,00 6300.00 4232 ~ 825813 ~ 48974987.~ ~'04 69 81 8552,56 6559.00 6500,00 41 39 ' Bi 20 75' -.41 94 8830.00 6766.47 6707.47 41 36 ~81 22 : ~57.'I~ 0.00 122 84 N 3762 32 N 3862 19 N 3957 85 N 4051 95 N 4144 35 N 4237 40 N 4332 09 S 4427 27 w 3562 93 N 3662 N 3862 31 ~ 395I 42 ~ 405 46 N 414 65 N 423~ 17 W 4332 13 W 4427 It S 4522 07 W 4522 12 S 4617 42 W 4617 54 S 89 40 S 4712 38 W 4712 59 S 89 27 W ~t $S 14805897 g~ W 4806~ ~898 42 9750 ' 82 ~ 0~548 71 ~25757 ~ ~076 ARCO AbASKA,, INC, tO NORTH ,SLOPE ~,AhASKA MkRK~R TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATEI 13-JUb-88 DATE OF &URVEYI ENGINEERt PAG£ 7 19"dUN"B 8 59,00 FT M,. MCBRIDE INTERPObATED VAbUES FOR CHOSEN HORIZONS MEASURED DEPTH BELON KB 8441 O0 845~ O0 847 O0 8613 O0 873 O0 883~ O0 SURFACE bOCATION AT ORIGIN= 975 FN6, 1986 FWb. SEC. 22. Tl~N~ ~9E~UM TVD RECTANGU6AR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/~EST 6475 61 6483 08 6498 78 6604 7 6693 ~4 6766,47 83.89 5oo ; 6 w 6424,08 B4,84 $ 500B.-74 W 6439,78 86,B4 $ 502~,54 W 6545.17 ,00.~ S $'1',17 " 6634.94 112. S $t93.,86 W 6707,47 122.~ & $257,57 W ARCO AbASKA, ZNC, 3 KUPARUK NORTH SK~OPE,ALA&KA COHPUTATION DATE: 13-JUb'88 KELb¥ BUSHING EIaEVATIONt 59,00 IrT ENGZNEERI' t¢', HCBI~%DE TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD ************ STRATIGPAPHIC MEASURED DEPTH BELO~ KB 8441 O0 8451 O0 8472 O0 8613 O0 8733 O0 8830 O0 SUMMARY SU~FACE.bOCAT~ON AT ORIGIN~ 975 FNb~ 1986 FNL~ SEC.' ~2~ T~3N~ Rg~,UM ~'~D RECTANGUbAR COORD~NATES FROM NB SUB-SEA NORTH/SOUTH 6475 61 641b 61 83 89 $ 5002,:16 W 6483 08 6424 08 84 84 $ 500~.'74 W 6498 78 6439 78 86 84 $ 502 6766 47 6707 47 45 $ FINA6 WEb6 60CATION AT TDI TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZUNTA~ DEPARTURE DISTANCE AZIMUTH FEET PEG 8830e00 6766,47 6707,47 5258,99 S 88 39 b SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. 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'..4-~-,* ...... +...~ .... ~ ......... *.-.~-. -.~-. ++e ..... ~..-e~-~--+-~'-~ .......... ?'~-'"~"~ '~'T"-~T--'~' I- T , ~ , ~ I T I ! T T · ~ .tt, ~,,,~ ,,~. { ..... ~, ,, T ,,t ..... ~ .......... ~.~ .~..~ .... ~...,..~ ~4-.~- ~-~-~ ~- ~-~--&4.-~ ~-~-~"-~- i-.--~-~-~ -$-~ -~- ~-~ ~-~-~- ~-4-~-~-~- --i.--~-~-e--.-..+-+--+..~ .... t.-+--f-5-' '~"f"'f-t'~'-r"t?"~ ~-4-+4 ..... b~.--~ ..... k~--&+.4~-4.4~-.{---4-~++--rH-t~'-~"t~'"T'-t' · , , ~, , T, ~ ~ ~, t l ? ,~ ?OOD WESl PROJECTION ON VERTICAL PLANE WEST - EAST SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/I000 IN/FT STATE OF ALASKA ALA$,,A OIL AND GAS CONSERVATION COM~,..$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] PerforateX3 Pull tubing Alter Casing [] Other [~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 59' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number 30-10 4. Location of well at surface 975' FNL, 1986' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1059' FNL, 2264' FWL, Sec.21, T13N, R9E, UM At effective depth 1088' FNL, 2072' FWL, Sec.21, T13N, R9E, UM At total depth 1097' FNL, 2008' FWL, Sec.21; T13N, R9E, UM 8. Approval number 8-540 9. APl number 50-- 029-21823 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 8830 ' MD 6766 ' TVD Effective depth: measured 8733 'MD true vertical 6694 'TVD Casing Length Size Conductor 80 ' 16" Surface 4970 ' 9-5/8" Production 8783' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 175 sx AS Ii 1750 sx AS III & 325 sx Class G 300 sx Class G Measured depth 115'MD 5005'MD 8816'MD True Vertical depth 115'TVD 4018 ' TVD 6756'TVD Perforation depth: measured 8542'-8562'MD 12. true vertical 6551 '-6566'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8358' Packers and SSSV (type and measured depth) HB pkr ~ 8286' & FVLD SSSV ~ 1781'¢ Stimulation or cement squeeze summary N/A Intervals treated (measured) R EC P An,:;horaga 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 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well Hi~tory w/Addendum, dated 6/29/88) Daily Report of Well Operations [~ CoPies of Logs and Surveys Run .~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed LLL.L,t~ Form 10-404 Rev. 12-1-85 Title Associ ate Engineer (Dani) SW03/021 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Reporl" form may be used for reporting the entire operation if space is available Accounting cost center code District ] or Parish State ARCO ALASKA INC. county NORTH SLOPE AK Field I Lease or Unit I Well no. I KUPARUK RIVER FIELD ADL: 25513 30-10 Auth. or W,O, no. JTitle AK3021 J COMPLETE AND PERFORATE API: 50-029-21823 Operator 1A'R'C°' w'l' Icostrr°tal number °f wells (active °r inactive) °n thisIcenter prior to plugging and ARCO 56. 0000 labandonment of this well Spudded or W.O. begunACCEPT IDate 06/27/88 I 0030 HRS IH°ur JPrlor status if a w.o. Date and depth as of 8:00 a.m. 06/27/88 ( TD: 8830 PB: 8720 SUPV:DL/KR 06/28/88 ( li TD: 8830 ?B: 8720 SUPV:DL/KR Complete record for each day reported NORDIC 1 Old TD 1 New TD Released rig Date Classifications (oil, gas, etc.) Producing method RIH W/COMPL. ASSY 7"@ 8816' MW:10.0 NACL/NABR MOVED RIG FROM 30-12 TO 30-10. ACCEPTED RIG @ 0030 HRS, 6/27/88. ND TREE. NU BOPE & TESTED TO 3000 PSI. RU SOS. PERFORATED 'A' SAND W/8 SPF, 45 DEGREE PHASING, F/8542'- 8562'. RD SOS. RIH WITH COMPL. ASSY. DAILY:S37,575 CUM:$806,957 ETD:S806,957 EFC:$1,340,000 RELEASED RIG 7"@ 8816' Mw: 6.9 DIESEL SERVICED RIG. FINISHED RIH WITH 2-7/8" COMPLETION ASSY WITH TAIL @ 8358', SSSV @ 1781', BAKER 'HB' PACKER @ 8286'. TESTED TUBING TO 2500 PSI. TESTED SSSV TO 1500 PSI. SET BPV. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. SET BPV. SECURED WELL AND RELEASED RIG @ 1900 HR, 6/27/88. DAILY:S123,624 CUM:$930,581 ETD:S930,581 EFC:$1,340,000 I IKind of rig IType completion (single, dual. etc,) Official reservoir name(s) Potential test data Well no. [~ate' Reservoir Producing Interval Oil or gas Test time ' Production Oil on test Ga~ per day , Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ·, Signature IDate ITitle For form preparation a,~_distribution. see Procedures Manual. Section 10, ' Drilling, Pages 86 and 87. ASSOCIATE ENGINEER ADDENDUM WELL: 30-10 6/19/88 Rn CET f/8720' -7346' Rn gyro f/8720' - surf. Drillin~ sUperVisBr ,, ARCO Alaska, Inc. Date' July 15, 1988 Transmittal #: 7223 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 11 OH LIS Tape and Listing 7 - 0 8 - 8 8 9 5 2 - 7 7 81 30-10 OH LIS Tape and Listing 7-09-88 854-8843' 3 O- 0 6 OH LIS Tape and Lising 7 - 1 2 - 8 8 4 8 0- 81 31.5 9 Receipt Acknowledged' ........................... Date' DISTRIBUTION: State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. t30-15 Kuparuk Fluid Level Report 7- 1 I - 88 · 3 O- 10 Kuparuk Fluid Level Report 7- 1 1 - 88 e 2 D- 15 Kuparuk Fluid Level Report 7- 1 2 - 88 · 2 A- 06 Kuparuk Fluid Level Report 7 - 1 2 - 88 ,, 1 G-07 Kuparuk Fluid Level Report 7 - 0 8 - 88 · - 1 G-08 Kuparuk Fluid Level Report 7 - 08 - 88 ~ 1 G- 15 Kuparuk Fluid Level Report 7 - 08 - 88 ' 31 - 01 Kuparuk Fluid Level Report 7- 08 - 88 ~ 31 - 1 2 Kuparuk Fluid Level Report 7- 0 8 - 88 - · 2A- 03 Kuparuk Fluid Level Report 7- 06088 ~ 3 H - 1 4 Post Frac Job Report 7 - 09 - 88 ~ 2 B - 1 6 Bollom Hole Pressure' Survey 7 - 03 - 88 ,, 3 J - 1 0 Kuparuk Well Pressure Report 3 - 08 - 88 Tubing Tubing CasIng Tubing Casing Casing Casing Tubing Tubing Casing AIIo Frac A-10 PBU Amerad Receipt Acknowledged: --'- ........................ Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ARCO Alaska, Inc. Date: Transmittal #: 7208 July 1, 1988 RETURN TO: ARCO Alaska, Inc. ~ Attn: Brenda K. Miernyk~ , Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-10 2" Dual Induction 6-16-88 5004-8830 30-10 5" Dual Induction 6-16-88 5004-8830 30-10 Cyberlook 6-1 6-88 5004-8830 30-10 2" & 5" Raw FDC 6-16-88 5004-8813 30-10 2"& 5" Prorsity FDC 6-1 6-88 5004-8813 Receipt Acknowled NSK Drilling Franzen Standard(vendor package) D & M State of Alaska(+sepia) L. Johnston(vendor package) ARCO Alaska, Inc. Date: Transmittal #: 7209 July 1, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 1 0 Cement Evaluation Log 6 - 1 9 - 8 8 7 3 4 6 - 8 71 5 3 O- 1 1 Cement Evaluation Log 6 - 1 9 - 8 8 5 9 71 - 7 6 4 2 3 O- 1 2 Cement Bond Log 6 - 1 7 - 8 8 4 7 9 8 - 6 8 6 0 3 O- 1 7 Cement Evaluation Log 6 - 1 7 - 8 8 7 5 9 5 - 9 0 8 7 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(+sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS ~ 9~¢- 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing C] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order .~. Perforate r~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 59' 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 975' FNL, 1986' FWL, Sec. 22, T13N, R9E, UM 7. Well number 30-10 At top of productive interval '996' FNL, 2202' FWL, Sec. 21 , At effective depth 925' FNL, 2058' FWL, Sec. 21, At total depth 905' FNL, 1993' FWL, Sec. 21, T13N, R9E, UM (approx) T13N, R9E, UM (approx) T13N, R9E, UM (approx) 8. Permitnumber 88-59 9. APInumber 50-- 029-21823 lO. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 8830'MD 6748'TVD Effective depth: measured 8733 ' MD true vertical 6676' TVD Length 80' 4970 ' 8783 ' Casing Conductor Surface Producti on feet feet feet feet Plugs (measured) N o n e Junk (measured) None Size Cemented Measured depth 16" 175 sx AS I I 115'MD 9-5/8" 1750 sx AS I II 5005'MD & 325 sx Class G 7" 300 sx Class G 8816'MD ~ue Verticaldepth 115'TVD 4003'TVD 6737'TVD Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None None RECEIVED :::' 1988 Cons. C0mmfssf0n 12.Attachments WFI I HI.~TO~Y 13. Estimated date for commencing operation June~ 1988 ~-~ 14. If proposal was verbally approved Name of approver Description summary of proposal [] Detailed operations program [] Date approved BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~"'Y')J~,~' ~l~lx~/.~,A ,-, Title Associate Engineer . Commission Use Only (SA3/0012 ) Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel. Approved Copy ORIGINAL SIGNED Returned 8Y f. ONN,E c. SM,TH ~ - by order of Date (Dani) Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate(~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday efte~ a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only, District ARCO ALASKA INC. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK3021 ICounty, parish or borough , NORTH SLOPE Lease or Unit ADL: 25513 Title DRILL 30-10 IWell no. API: 50-029-21823 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 06/11/88 ( TD: 216'( SUPV:LWK 06/12/88 ( TD: 2423'( SUPV:LWK 06/13/88 ( TD: 5023'( SUPV:LWK 06/14/88 ( TD: 5023'( SUPV:LWK 06/15/88 ( ~ TD: 7666'( 2, SUPV:LWK 06/16/88 ( TD: 8830'( 1 SUPV:SC 06/17/88 ( 7 TD: 8830'( SUPV:SC JDate IHour 06/11/88 0430 HRS Complete record for each day reported DOYON 14 IARCO w.I. 56,0000 Prior 'status if a ) 16) DRLD 16"@ 115' MW: 8.7 VIS: 90 NU DIVERTER AND FLOWLINE. ACCEPT RIG AT 0230 HRS, 06/11/88. MU BHA AND ORIENT SAME. FILL DIVERTER AND TEST. DRLD 12-1/4" HOLE F/ 115' TO 216'. SPUD AT 0430 HRS, 06/11/88. DAILY:S42,400 CUM:$42,400 ETD:S42,400 EFC:$1,340,000 ) O7) DRLG 16"@ 115' MW: 9.2 VIS: 57 DRLD 12-1/4" HOLE TO 2073'. SURVEY. CBU. POOH. CHANGE BHA AND RIH. WASH TO BTM. DRLD 12-1/4" HOLE F/ 2073' TO 2423'. DAILY:S56,872 CUM:$99,272 ETD:S99,272 EFC:$1,340,000 ) ;00) SHORT TRIP 16"@ 115' MW: 9.5 VIS: 64 DRLD 12-1/4" HOLE TO 5023' CIRC AND SURVEY. SHORT TRIP. ) O) DAILY:S43,350 CUM:$142,622 ETD:S142,622 EFC:$1,340,000 MU BHA 9-5/8"@ 5005' MW: 9.2 VIS: 46 RIH. CBU. SURVEY. POOH. LD BHA. RU AND RUN 9-5/8" CSG W/ FS AT 5005'. CMT W/ 1750 SX OF AS III AT 12.1 PPG AND 325 SX OF CLASS G AT 15.8 PPG. CIP AT 2230 HRS 6/13/88. NU BOPE AND TEST SAME. PU BHA. DAILY:S206,664 CUM:$349,286 ETD:S349,286 EFC:$1,340,000 3) DRLG AT 7666' 9-5/8"@ 5005' MW: 9.3 VIS: 35 CHA/qGE TURBINE. MU AND ORIENT MWD. RIH. TEST CSG TO 2000 PSI. DRLD OUT CMT. TEST FORM TO 12.5 EMW. DRLD 8-1/2" HOLE TO 7666' DAILY:S58,557 CUM:$407,843 ETD:S407,843 EFC:$1,340,000 64) PREP TO OPEN HOLE LOG 9-5/8"@ 5005' MW: 9.9 VIS: 41 DRLD TO 8830'. CIRC. PUMP PILL. SHORT TRIP. CIRC. SURVEY. POOH. DAILY:S50,244 CUM:$458,087 ETD:S0 EFC:$1,798,087 RUN 7" CSG 9-5/8"@ 5005' MW: 9.95 VIS: 40 POOH. LD KELLY AND SPINNER. LOG W/ OH LOGS F/ 8830' TO 5004' RIH. CIRC. POOH. LDDP. RUN 7" CSG. il.! I.. I ,.: j,:]~8 Oil & ~as Cons, Commission AP,,,;;,~.~ a~e The above is correct For form pr, e/~aration and distribution, see Procecl[uj~es Manual. Section 10 Dr Iling. Pa~'es 86 and 87. IDate 7-1o -~ Title ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District J Stat~K ARCO ALASKA INC. Field County or Parish NORTH SLOPE ILease or Unit ADL: 25513 Title DRILL KUPARUK RIVER FIELD 30-10 IWeH no, Auth. or W.O. no. AK3021 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 06/18/88 ( TD: 8830 PB: SUPV:SC IA.R.Co. Date Complete record for each day reported DOYON 14 56.0000 06/11/88 50-029-21823 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prlor status if a W.O. I 0430 HRS RIG RELEASED 7"@ 8816' MW: 0.0 RUN 222 JTS OF 26# J-55 BTC 7" CASING. FS @ 8816'. CEMENT CASING WITH 100 SX OF 12.0 PPG 50/50 FLY ASH LEAD FOLLOWED BY 200 SX OF 15.8 PPG CLASS G TAIL. CIP @ 1400 HRS 6/17/88. NU TREE. RELEASE.RIG @ 1900 HRS 6/17/88. DAILY:S159,769 CUM:$769,382 ETD:S769,382 EFC:$1,340,000 E C E IV E D Oil & Gas Cons. Commission Anchorage Old TD Released rig INew TD PB Depth Date Kind of r g Classifications (oil, gas, etc.) Producing method Potential test data Type completion (single, dual, etc.) Official reservoir name(s) Weii no. Date I Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedure~,.lanual, Section 10, Drilling, Pages 86 and 87. JDate ITitle ASSOCIATE ENGINEER $2cATI~ OF Id~ASF, A ~AS}~ O1L /, GAS CONSi!2RV/,ilO){ CO?IMISSION- . B.O.P,E. lnsi, ecilonil~eport lmspec ~. C0ntr~ctor Ri L~tio~, ~eneral ~ ~ell Sign_~._ Ce~eril ~sekeep!ng ~ Rig. Re~erve 'Pi~ }~~ Visual Audio · . -~ :~ - . B~E Struck Test Pressure _ -. ~ _ ~-~---' '~ ~ -- I ...... W*~l~ i-; ~ O'tO' '- .- .-. '.. . - . ',...... ~Eastn8 Set *~=0~_ _ft.~ t~ti~ ~ - ACCU~LA~R SYST~ Full Charge Pre~sur~__~D~ _ pslg ............... Pressure After C3os*r~J~~ psig_ Pump incr. c~os. pres. 200 pslg~ mina,_sec. ~ - Full Ct~a.rge ~ressure Attatned~__~2in.~.~_sec. Controls: M~ter . Ball Type _.'J. _Test Pressu~re ~O/~t~_ ...... lns~de BOP~Tes~ Presser_ e_~ ~_OOC) .... Chok~ Mant~ld~Test Pr_~ssure ~000_ lt.C.lt, ~alve _.- J. _ No. Valves ~ L~ - Line Yalves ~_, · .,_~~ No. flanges .:,, ~ " , _. t =~ , _ _ _ , ~ ... _ ~:~tts: Failures , . MOu ~ Test T~e ~hrs. : ~ait or Replacement of failed equt~int to-be made within ,days and Inspector/ June 9, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re. Kuparuk River Unit 30-10 ARCO Alaska, Inc, Permit No. 88-59 Sur. Loc. 975'-FNL, 1986'FWL, Sec. 22, T13N, R9E, UM. Btmhote Loc. 966'FNL, 1981'FWL, Sec. 21, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To. aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention 'equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so .that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY ORDER OF THE CO~SMISS!ON dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..... STATE OF ALASKA ~ ALASKa-, OIL AND GAS CONSERVATION ~ JMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E31 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil T~ Re-Entry [] Deepen©1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513 ALK 2554 Location of well at surface 7.. Unit or. pr,,operty Name 11._Type Bond (see 20 AAC 25.025) 4'975'FNL,1986'FWL,Sec.22,T13N,R9E,UM r, uparuK t~ver Unit 5tatewide (~ target) At top of productive interval 8. Well nu .tuber Number 996' FNL, 2202 ' FIA/L, Sec .21 ,T1 3N,R9E,UM 30-1 0 #8088-26-27 At total depth 9. Approximate spud date Amount 966'FNL,1981 ' FI/V'L, Sec. 21 , T1 3N, R9E, UM 06/10/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthIMD aod TVD) property line DS 30-11 8786' iv/L) 1 981 ' (~ TD feet 25 ' ~ surface feet 2560 6680 ' TVb feet 16. To be comple,te,~ for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth buu feet Maximum hole angle 450 Maximum surface 2 3 73 psig At total depth (TVD) 31 41 psig 18. Casing program Setting) Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" I 6" C--,? R.~ H-~.C) W~I H RI' , q, , R" ' I I ' I I ~ +?nFl cf 12-1/4" 9-F~/R" RR.~q# .I-R~ RTl' ~q7~' R , Re, c, B1 ' b.n~qq, 1750 s~ AR ]]! F-ER~, 375 sx Class 8-1/2" 7" 26.0# J-55 BTC 8752' 3z ' 3~ ' 878 ' 6680 100 sx 50/'50 Poz Lea F-ERIA 200 sx Class C tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Top of C 500' above Present well condition summary Kupa ruk Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural · . Conductor ~'~ iJ:i iil}~.' :: ;¥{.? Surface - , Intermediate ¢. . ' Production Liner '. :.'i, ? ";:;...; Perforation depth: measured :' '" '? true vertical 20. Attachments Filing fee ~ Property plat (~ BOP Sketch [] Diverter Sketch ~ Drilling program ~L Drilling fluid pr~o~.,~,am ~3 Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby cye'Ftify]that the f~,r,e'g~ing~ true and correct to the best of my knowledge .~ / / ~'!,,~'~'4/'~z/'4-~¢~-'~ ¢//'c¢~L'~'" ' --"- -'"" - Commission U's~ unly (TE~) P~3 /2 ~'~-~ Date./~ / Signed Permit Nurr~er f I APl number I Approval date I See cover letter I 50-o:9-2,9z I06/09/88 I for other requirements Conditions of approval Samples required [] Yes [~. No Mud Icg required E3 Yes l~ No Hydrogen sulfide measures [] Yes~ No Directional survey required l~f Yes [] No Required working pr~re f~~O~ /E~,CJ~; ~ 31Vi; ~i 5M; [] 10V; [] 15M Other: Y/~"~7/ ~~ by order of Approved by ( ~ ,~/,¢ ( ~'~,~'~'~'~"~ Commissioner the commission Date -- . /.. q ,,~ ..... triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1 ) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" s'urface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casings,~ Pressure test to 3500 psig. 11) Downsqueeze Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC · Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator,(Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardoUs fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by~arcti~ pack Upon completion of the fluid disposal. ~i~!i~ ,..~ ~ ~ ~"~ !i' ~~ ,~ ,? ~ ~ LWK5 / ih 20' DIVERTER SCHEHATIC III DESCRIPTION_ I. 16' COfllXKTC~I 2. FtC SLIP-ON ~ S?ARTII~ lEAD 3. Ft'IC DIVERTER ASSS'IBLY WITH ~ 2-I/!6' 2000 PS1 BALL VALVF~- 4. 20' 2000 I~1 DglLUI~ $. 10" HCR BALL VALVr~ ~/I0' OlV~ LINF.~, A SINeLE VALVE I~[I'IOTELY CoN'rg~ TO DIVF. RSI~. ~. 20" 2000 PSI AI~C:O ALASKA, INC., REgJ~$~ ~,kL OF THIS DIVERTER ~/$1'~1't AS A VARIANCE FR0r~ 20AAC25.035(b) MAINTENANCE & OPERATION 2 · - I ! UPON INITIAL INSTALLATION. CLOSE PI~VENTEI~ VERIFY TI-lA T VALVE OPENS PR~Y. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR TH~0UGH DIVEI~TEI~ LINES EVERY 12 CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WE:LLB01~ FLUIDS OR I}AS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUt'ISTANCE$ 7 6 g D~AGIt4~ #! 1~-5/'~' ~ 1~3! ~ i~ STACK I. 16' - 2000 I~l T/M~CO ~%~1'11~ ~ KILL kI~8 7. 1~5/8~ - ~ ~I ~ ACC~f~LATC~ ~ACIT~ TEST :1. O-ECK At~D FILL ACOJMJ. ATCR RESERVOIR TO PRCI~.R LEVEL WITH HYORALLIC FLUID. 2. ~ THAT ACO,MJ. ATCI~ PRESSI.~E IS ~000 P~I WITH 1500 PSI 1~3M~ISTRF. AM CF THE REGLLATCI~. :3. CI~SERVE TIkF,, TFEN O.O~E ALL UN/TS SIMJLTAI~E(3JSLY N~D RE~ THE TIHE ~ ~ REMAINING AFTER ALL UN~TS AI~ O.~D WITH CHARGIN~ ~ CFF. 4. RECORD ON MM~ REPORT, THE ACCEPTABLE LOVER LII~T IS 45 ~E~ Ct. C6II~ TIKE: AM) 1200 PSI ~#kII~NG LI 5 4 3 2 L_ I$. 14. 1:::5--5/~" ~ STACK .TEST I. FILL BCP STACK ~ C3-1:]<E IvI~J~FCLD WITH ARCTIC DIESEL. 2. OECK THAT ALL LOCI( EOfl~ SCREI~ IN V~I. LFE/~ ARE FLLLY RETRACTE~ SEAT TEST PLUG IN WITH RM~IkG JT N~) ;aN IN L(X]<[:O~ SCRE~ :3. CLOSE ~ PI~'VENTER ~ 1141,NJAL KILL ~ L]HE VALVES ADJACENT TO BCP STACIC ALL OTHER vALvEs ~ Q-IOKES ~ BE ~ 4. PRESSLRE UP TO 250 PS! ~ I-I~LD F~R I0 MIN. CREA..~ PRE~ TO ~0 P~! ~ ~ FIR I0 ~N. BLEED P~~ TO 0 5. OPEN ~ PRE'V~NTER ~ ~ KILL /~) ~ LI~E VALVES. CLQ~ TQ= PIPE ~ ~ HCR VALV~ 6. TEST TO 25O PS! ~ ~ PSI AS ~N STEP ~. 7. C~NT~.~ T~-~'r~N~ ~L VALVES. LI~&, R{)~S 8. ~ TC~ P~F~ R~J~6 ~ Q.QSE BOTTOU PI~ TE~T BOTTOM PIP~ ~ TO 250 PSI ~ ~ PSI. IQ. CLO~I: BLIN) ~ ~) TEST TO 250 PS! ~ ~ PSI. I~AIFCLD /~D LIl~r~ ~ FLU. CF ~EZING FLUID. ~ET ALL VALVI'~ IN CR~LLING F~SITICN. 12. TEST b-'I'~IPE VALVEI~, KELLY,, KI~LLY CCX](S. C:PILL PIPE SAFETY VALVE, AN3 II~II~ ~ TO 250 PSI A/~ 3000 PSI. RE~ TEST II~FCRM~TICN CN BL(]fJ3JT PREVE]~ER TEST FORM, SIGN, At~) 5E]~ TO CRILLING SLI:F. RVISOR. YEEKL.Y THEREAF'11~ FLNCTICNALLY C~:RATE BCPE .......... AROO~,AEASK.'k.-~--!I n · · ' Kupe~uk Fte'l'd._~L.North SI!ope, Alee~ke ._~__._.____i .... : __ i ~ ! 33 ' Et ! pE:RHAFRO~T TVO-171 g TI~)-I ?g6 DEP-362 ~%___~ EOC T VD-,9,O THO-2099 DEP-559 j. - ...... 4000 T/ UG~u sHOs TVD-2679 Tfl0"3130 0£P'1287' AVERAGE ANGLE --- 45 ..... DEG ~ . : . "'I .................................. '; ............... *~ ............... ! K-5 TVD-5?$9 TI'K)-?484, ,DEP-4365- d~ I ,__~ ..... :__6.000, ' ' J _ _: ' i. ~ T/ ZONE D TVD-6319 Tlll)-8275 DEP-4924 i i T! ZONE C TYD-$379 T1~-8360 DEP-4984 i .......... ~ .......... l/_ ZONE A -TV0-6433 T1"10-8437'. 0EP-5038 j .....j. TARGEI CNTR TVD-6459 TI10-847'3 DEP-5064 , ' B/ KUFI SND8 TVD-6539 Tt'ID-S586 DEP-5144 1 TD (LO0 PT); TYD-6680 T1'~-8786 DEP-$~8$ , - ~ 0 ~ /1000 . . ~000 · $000 4000 i i .............. i_..5. I .......... ¥[R?I~N..~ 8[¢1'I0#--' . T/ I,I SAK SNDS TVD-338g TIID-41:34 DEP- 1 gg? K-12 TVD-380g THD-4727 DEP-2416 9 5/8' 'CSG PT TVD-4009 THD-5010 DEP-2616 $000. ' 6000 8001_ _ 8.5O'_ 900::_.. 95Q_ . i 2000' 2050! 2100 .............. ] ....... 950 1 000 _ I .. ,.....,,=.~.. 600. . _ 1001 . ~ _ - _ _ ... ---- -,',--.,-2.90o---~o~,,.,zr uu ,i ~ :~ ..:,j~o~. _ .... 3., 6-o 3ooo !soo , I xa-l- .,',moo . . ~ ! 490 . ' i i 1 800 ,1 850: 1 900. 1 950. 2000 2050 21 O0 . . · . . ....... ........................ ~ ......................... . ............................... , ..- 800,~ .- 850_ '~' 0 I ................ A3 0 ..... I i oo0 ..................... ~ ................ t 3~00 , I ~, ! 3800 ! ...... 1600[ · 2Ooo : . -} . I000.. HOR [.ZONT L PROJECT ION .... ~ ..... ) ..... ~ ~ C ~ ~ I ~ ~ ~ 1000 F~t d 30, W_~II No~ 10 upir,uk, Fl~ld. North 1000 5000 5000 i Slop · 4000 2000. , , WEST-EAST ~ooo i, i 000 , CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE <2 thru 8) ~.~'.~. ~- v- mn (8) 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~~/</ ~-7o~ (14 thru 22) (23 thru 28) Company //~/~,.CC'~ YES Is the permit fee attached .......................................... ~ Lease & Well No. NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. ~ Is.a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ,~ Does the well have a unique name and number ......................... ~ 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~; psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............. · .................... < (29 thru 31) For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. ,.,..,. /~ 30. Are seismic analysis data presented on shallow gas zones ... 31 If an offshore loc., are survey results of seabed conditions p~~r~nted REMARKS O ~Z (6) Add: ~~. /~-?-$$ 32. Additional requirements ............................................. Geology: Engi~n~ering: ~ ww~ ~F LCS f~EW /~ BEW ~ MTM'/~ k~D ~ rev: 02/17/88 6.011 INITIAL GEO. i UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE ftgo[c~o .DEc,'-/ olc ~9c-~ l l/~o Old Additional Remarks: 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. ~ ~uq3 ~W'P, $0-/0 LIS T~PE VSRIFT~CA'TT. ON LISTING VP OIO.HO~. VEDI~-I~ATI3N LT. STING Ph~:~E I :~ REEL HE,~Dc_D ;ERVZCE NA ~'4E : ~ATE :98/07/ 9 ~RIG!N ::LIC :EEL NaME :72822 .ONTZNUATION ~ : 'REVZOUS REEL : ;OM~ENTS :LIS :, TBp'c ~ H'~Ag:'R. "'"' ',ERVZC~ NAME : iATE :8810'7/ 9 IRIGIN :FLIC 'APE N~ME :T2822 :ON'TiNUATZON ~ :1 'REVIOUS TAP'E :OMMENTS :LIS TAPE~ ~RCO KUPBRUK 3 0-10~ ~PI #50-0£9-218'7] FILE HE~D'ER -~'~-~. :ILE NAME :CD~T .001 ;ERVIC;E ?~ A"4 E :~LtC 'ERSZON ~ :O01~OZ lATE :88/0T/ 9 tAXIMU)'q LENGTH :1024 :ILE Typ~ 'LO 'REVIOUS FZL:,... : COMHENTS SCHLUMBERGER ~LASKA COMPUTING C,i:NTER O~PANY = ARCO .LASK~, INC tELL = ~ 0-10 :IELD : K.U P,~RUK 'OUNTY = NORTH SLOP~ BOROUGH ~TAT'E = ~L~SK~ 106 NUMBER AT AK~CC: 72'82:2 ~UN ~1, DATE LOGO:ED: 16-JUN-88 VP OlO.H02 V=~I=!CaTIDN~_ , LISTI~,~G~ ~Am~: 2 DP: J. KgHRZNq ~ATE C3~PUTEg: O~'-JUL-3~ ,ASING 'YPE FLUZg tENSITY 'ISCOSITY 'H :LUID LCSS 9.625" ~500¢'(LOG'~EO) - BIT SIZ5 : 3.5" TO 3836'(LOGGER) LSNO 9.9 L~tG R~ : ~.98 @ 70 DF 41.0 S RMF : 3.54 @ 70 DF 9.0 RMC = Z.67 .@ 70 DF 4.6 C? RM ~T EHT = 2.442 @ 150 gF :IELO REMARKS: 1/2" STANDg~ USED ON OIL S~NDE; M&TRIX gENSiTY = SAND (2.65); EHS = OPEN; LUI] DENSITY : 1.0 G/C3; HOLE CORRECTION : CALIPER. 'agL TYPES/NUM'BE~S: DIS 2140 SGC 3109 D!C 2190 PGS 50~ CNC 123~ PQH 1168 SCHL!.J~'BERGF~ L']G,S !NCLUD~.O WITH THIS FILE (~OI'T.OOI'): ~ <.S~-E FtLm,,.. EDIT, o002 FOR 1.2'" SAMPLED FDC/CNL DAT~,> =k V~ 010.H02 VE~Z=ZC,~TIgN LiSTIqG [;U~L INOUCTiON SPHERICALLY ~OCUSEn., LOG (.OIL) FIRST TC L,~ST REaD. IN~S: F~PM~T!ON DENSITY COMmENSBTE~ LOG (.FON) ~IRST TO L~ST READING: 8313' Tg 8138' COMP~NS&TEO NEUTRON LOG (.CNL) mIRST TO L~ST RE~DING: 8796' Tg 3138' ~MM~ R~Y IN C~SING (.CHL) :Z~ST TO LAST :~E&D!NG: ABLE TY°'r' 'CONq M ~J E M CN FN WN N ~ STAT C OUN S~CT TOWN R L ~ T '! L~NG O~E~ SON APIN 3 0-10 WELL N~ME U. S. ~. N~TION ALaSKa, STAT~ OR P~OVI'~ NORTH SLO:~ ~C'OU NT ~ 22 SECTION 13N TOWNSHI~ gE R~N:SE 975' ~NL LATITUDE 1985' FWL LONGITUDE OPeRaTOR'S C.,~.D~ 5~0795 SERVZC'E ORDER 5 O-02~-Z'l 873 API SE:RI,~L N~JN~ ~ABLE TYPE :CUPV MNEM D;E~I VP OlO.H02 VE~!mICaTIQN LISTIMG PAGE 4 DEPT gE~Tq CHANNEL TENS TENSIgH SFLU SFL ':JN ~V E R ~G E D ;','- ILM IL-.~=gTUM ILD ZL-OEE~ RESIST~ SP SPONTANEOUS GR G.~M~ R~,Y TENS TENSION D~HI DENSITY ~oOROSI~ DRHO DELTA RHO RHOB P!JLK OENS~T¥ CAL[ C~LIPER GR G ~i,~ ~ R~Y TENS TENSION N~H'I NEUTRON oOoOSI"',, TNR6 C~LiBR~TEg THE~ RTNR RAW THERMAL NE~ RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC C AL ] C 6L!PER GR G ~S~ R,~,Y TENS TENSION DATA FORMAT RECORD ~ !NTRY 8LOCKS 'TYPE SIZE REgR CODE ENT:RY 1 I 65 0 Z ~ ~6 0 3 4 77 100 4 1 6,5 1 9 4 6 5 FT 11 ~ ~ 10 13 1 66 0 ~.4 4 65 ~:T 15 I 65 68 16 1 66 1 0 I 6 S 0 0.5900 )ATUM SFEC~FIC~TIOT',~ 'BLOCKS qNEM S'ERV]CE SERVICE UNIT A~! API APl ~PI ~!LE SIZE SPL REPR ID ORDER ~' LOG TYPE CLASS ~qOg N3. )EPT 530795 FT O0 OOO O0 0 1 FENS DIL 530795 LB O0 OOO O0 0 1 ~FLU OIL 530795 OH~'4NI O0 [LM Dlt 530795 DH'MM O0 000 O0 0 1 [LD OIL 530795 gH~M O0 gOO gO 0 1 ~P DIL 530795 MV O0 goo O0 0 I 4 ;R OIL 530795 GAOl O0 OOO O0 O rENS ~DC 530795 LB O0 000 O0 0 1 4 PROCESS CODE (OCT~L) 68 O00OO00OO00OO0 58 OOO000000OO00O $8 O00OOOO00OOOOO 68 OgO00000000000 68 OOO00OO000000O 68 O00000000OO000 58 O0000OO0000000 68 OOO00000000000 .VP OIO.HO2 VERT=IC~TI2N LISTING iPHi FPS 5]0795 oU ~RHO =gC 5]079~S G/C3 :HOB FDC Y30795 5/C3 O0 · ~LI FOC 5~07~5 !N 90 ,R FDC 530795 GAoI O0 'ENS CNL 530795 Le O0 IPHi CNL 530795 PU 00 'NRA CNL 5307~5 O0 ',TNR CNL 5 30795 ~CFT CNL 53079~ CPS 90 ',CNT CNL 530795 CPS 0O 'FTC CNL 53gTg5 CmS 00 'NTC CNL 530?95 CPS 'ALI CNL 530T95 IN ;R CNL 53079~ G,BoI O0 'ENS CHL 5~0795 LB O0 ;R CHL 5 ~0795 G~Pl ~* O A T 6 F 0 R ~ ,~ T P. E C 0 R 'g ""-,-.,,."' !N'T RY BLOCKS TYPE 1 3 4 9 !! t4 15 !6 0 )ATUM SPECIFICATION 'SLOCKS ~NEM SERVIr=,~=_ S:RVICE, .... UNIT ID O~RDER )EPT 530795 FENS OIL 530795 LB SFLU OIL 530'795 ILM OIL 530?95 griMM !LO OIL 5.30795 OH'4M SP OIL 530'.795 MV TENS FDC 530795 LB DPHI FDC 53079S PU DRHO FDC 530795 G/C3 RHDB ~DC 5'~079 S ~G/C 3 C,~LI FDC 530795 IN G ~ ~ D C 530 .79 S G A TENS CNL 530795 LB NPHI CNL .5~079S ~U TNRA CNL 5~0795 RTNR CNL 530795 SIZE 1 i 4 ! 4 4 1. 1 4 I 1 ! OOO O0 0 gO0 90 0 gOO O0 0 900 ~0 0 1 gOO O0 0 gOO O0 0 1 gO0 gO 0 ! 900 O0 0 gOO 90 0 ! OOO O0 0 1 OOO OO O 1 900 O0 O I OOO 90 0 1 OOO O0 0 900 O0 0 1 OOO O0 0 1 000 O0 0 AP1 APl Apl LOG TYPE CL.6SS gO gO0 O0 O0 000 O0 O0 gO0 O0 O0 O00 O0 O0 000 O0 O0 OOO O0 O0 000 O0 O0 gO0 O0 O0 OOO O0 O0 gOO O0 O0 000 O0 90 go0 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 gO0 O0 O0 000 CO REPR CODE 66 66 73 66 65 66 66 65 66 66 66 ,,~PI >=ILE ?~OO NO. 0 1 0 0 0 I 0 1 0 1 0 I 0 1 0 1 0 0 1 0 1 0 0 1 0 1 SI ENTRY 0 0 ~00 1 FT 10 0 =T 68 1 ! ZE SPL 4 4 1 4 1 4 1 4 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 68 O0000OO0000000 58 OOO000000000OO 68 O000000000000O 68 00000000000000 58 00000000000000 68 OOO00OO0000OO0 68 09000000000000 68 00000000000000 1 1 1 1 1 1 1 I 68 00000000000000 ! 68 OOO00000000000 1 6~ OOO000000OO000 1 58 O0000000000OOO 1 68 O0000OO0000000 ! 68 03000000000000 1 68 OOO00000000000 I 68 OOO0000000000O 1 68 OOO0000000000O O.EO00 REPR COO6 68 68 68 68 68 PROCESS (OCTAL) O00OOOO0000OOO 00000000000000 O0000OO0000000 00000000000000 OOO00OOOOOO00O OOO000000OO000 O0000OO0000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 OOOOOOO00OOOO0 68 00000000000000 68 O0000OOOO00000 68 OOOOOOOOOOOOO0 68 O0000OOOOOO000 68 O000000OO00000 VP OlO.q02 V~q!~IC~T!ON LISTING PAGE 6 CFT CNL 530795 CPS O0 gO0 O0 0 1 4 I 68 O0000OO0000OO0 CNT CNL ~'30795 CPS O0 O0O O0 O 1 ~ I 60 0O00O0000O0O00 FTC CNL ~30795 CPS O0 gOO O0 O I 4 I 68 O00OOO000OOOO0 NTC CNL 530795 CPS O0 gO0 gO 0 1 4 ! 68 OOOOOOO0000000 ALI CNL 5307~5 IN O0 goo gO 0 I 4 I 68 O000000000000g R CNL 530795 G~! O0 go0 O0 O ! a 1 68 O000000000000O ENS CHL 530?95 L~ 90 007 O0 0 t ~ I 58 OOO00000000000 .R CHL 5~0795 GAP! 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PRINTS VP 010.H02 V.=eI:ICATION LISTI~4G P~GE 19 SCHLUM&ERG:R LOGq_ INCLUD:D W~TH THIS FILE (EDIT.O0~):- ~ <SEE FILE ~OIT.OO! ..:OR $" SAMPLED DIL/FDC/CNL/GR OAT~> ~ FOrMaTION D:NSITY COMPENSAT~B~_ LOG (.FOH) · m!~ST TD LiST RE~DING: 8813' TO alSO' g CnMPENSITED NEUTRON LOG (.CNH) ~ ~eST TO L.~ST REIDING: 8796' Tg ~1S0' ~ iNFOR~ATI gN R:COROS 'TYPE :CONS MNEM CN FN WN NATI STAT COUN SECT TOWN R~NG LATZ LONG OPER SON T U N I V :,~ L U O r-_ F Z ~PCO ALASKa, I$ COMPANY N~E KtJP ~RtJK FIELD N~NE 0-10 WiELL NAME U.S.~. N.~TION ~LASK~ STA. TE OR PRgVI~ NgRTH SLgPE COUNTY 22 S~C'T~gN 1 ON TOWNSHIP 5' ~NL L~TITUDE 1986' ~WL LONGZ'TUOE OP.ERATOR'S CgD~ 53079:~ SERVIC: ORDEe ~ VP 010.HOZ VE~T:IC~TZgN LISTING PAGE 20 ~&PIfl A~LE TYPE :CUqV 59-0Zg-2!373 ~PI SERIAL NUM, M N E ~,'~ D~F'Z DEP'T 0FPTH CHANNEL T~N S T ~N SION DPHI DENSITY ~OROSI* DRHO ~ELT4 RH02 BULK ~ENSZTY CALl C~L!PER G~ G~MMA T~NS TENSION NPHI NEUTRON POROSI, TNR~ C~LI~RATED THE~ RTNR R~,W THERMAL RCFT RC~T RCNT RCNT CFIC CFTC C N T C C N T C GR G ~M',~A ~ ~Y DATA FORMAT R~:C!]RD,.. "'"',-.,- !NTRY BLOCKS 'TYPE SIZE RE.OR CODE t ! 65 2 1 66 3 4 73 4 ~ 6 5 ;8 4 68 1 1 I 56 13 1 66 14 4 65 15 1 65 16 1 66 0 1 $ 6 ENTRY 0 0 64 1 -0.0000 ~T ~T 16 0 68 1 1 )ATUM SPEC!FIC~!TION qLOCKS ~NEM SERVICE S'E~VICF UNIT APl AP'! Ami IPl ~ILE SIZE SPL REPR ID ORDER ~ LOG 'TYPE CLASS )EPT 530795 F'T O0 goo O0 FENS FDH 530795 LB O0 gOO 00 )PHI FDH ..530'795 .DU O0 900 O0 )RHO FDH :30'795 ~' ... ~_~./'u 3 O 0 O 0 O 00 ~HOB 'FDH 53079~ GtC3 00 000 00 ;~L'I FDH 53079'5 IN O0 O00 00 ;R FDH 53079 ~ GADI OO 000 OO FENS CNH 530795 LB O0 000 00 4PHI CNH 530'795 ~U O0 DO0 O0 FNmA CNH 530-'., 9 ~ OD 000 O0 ~TNR CNH :F30795 OO 000 O0 CODE (OCTAL) 68 00000000000000 58 00000000000000 58 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6~ 00000000000000 68 00000000000000 68 00000000000000 58 00000000000000 68 00000000000000 VP OlO.H02 VERI=ICA~I?N LISTING o~GE 21 CFT CNH F30T95 CPS OO gOO 90 O 2 CNT CNH 5?0?95 CPS O0 OOg O0 0 2 FTC CNH 530795 CPS O0 OOO O0 O 2 NTC CNH 530?95 CPS O0 gOO O0 0 2 R CNH 530795 GAPI Og 000 O0 0 2 1 68 O000000OO00000 I 58 O00OOOOOOOO00O 1 $8 OOOOOOOOO0000g 1 58 0,3000000000000 1 68 O0000000000OO0 , D~TA FORMAT q~CORD NTRY BL3CKS TY°E SIZE REPR CODE ~ I 65 2 1 66 3 /, 73 4 I 66 8 4 63 9 4 65 11 1 66 13 1 66 14 4 65 15 1 66 16 1 6 $ 0 I 6.6 ENTRY 0 0 54 1 -0.0900 SPECIFIC&TION ~LOCKS FT 16 0 68 1 1 )A'TUM INEM SERVICE SERVICE UNIT API API ~PI API mILE SIZE SPL IO gPOER ~; L3G TYPE CL,~SS MOD NO. tEPT 530795 FT OO 000 O0 0 2 'ENS FgH 5B0795 LB O0 000 O0 0 2 4 1 )PHI FDH 530795 PU O0 OOO O0 0 Z 4 1 [HOB FDH 5~079S G/C3 gO OOg O0 0 ~ ~ 1 ;ALI 'FOH 530795 IN O0 OOO O0 0 2 :~ 1 ;R FDH 5~0795 G~PI O0 OOO O0 0 2 4 1 r~N5 CNH 5307~5 t~ 00 000 00 0 2 4 1 ~PHI CNH 5~0795 ~U O0 OOO O0 0 2 4 1 ~N~A CNH 5~0795 O0 OOO O0 0 2 ~ 1 ~TNR CNH 5~0795 O0 000 gO 0 Z 4 1 ~CFT CNH 530795 CPS O0 000 O0 0 Z 4 1 ~CNT CNH '5)0'795 CPS O0 000 O0 0 Z 4 1 :FTC CNH 530795 CPS O0 DO0 gO 0 2 4 1 ;NTC CNH 530795 CPS O0 go0 O0 0 2 ;R CNH 530795 GAPI O0 goo O0 0 2 4 1 REPR CODE 68 ,68 68 68 68 68 68 68 68 PROCESS (OCTAL) 00000000000000 O00000OO000000 OOOgO0000OO000 00000900000000 00000000000000 00000000000000 O00000000OO000 O0000OO00gOOO0 O00000OO000000 00000000000000 68 00000000000000 68 O0000OOOO00000 OOO00000000000 68 O00OOOO0000000 68 O00OO00000000O 68 00000000000000 )EPT 8'840.0000 TENS 4.649.0000 DPHI 6.4.5876 DRHO -0.0108 ~HOB 1.5843 CALI 7.5234 GR 102.5000 TENS 4640.0000 ~PHI 32.5752 TN~.A 2.3365 ?TNR 3.0653 RCFT 62'3.7759 ~CNT 1936.~369 CFTC 703.3533 CNTC 1957.7615 GR 102.5000 3EPT 8800.2988 TENS 6260.0000 OPHI 54.6560 ORHO 0.0302 ~HOB 1.7482 CALI 7.~648 GR 102.5000 TENS 6260.0000 ~PHI 3 Z. 6276 TNRA 2. 8365 ~TNP 3.06...53 RCFT 62.3. 7759 RCN'T 1936. 3369 C~'TC '703.3533 CNTC 1957.7615 GR 102. 5000 VP O1D.HOZ VEqZ:TCATZON Lr. STING PAGE EPT 870 O. 2988 TENS HOB 2. 3848 C~LI PHI &O. .~_'~71o. TNq~ CNT 2019.61.43 C=TC EPT 8500.2938 TENS HOB 2.5052 C&LI ~PHI 31.39'39 TNRA CNT 2175.23'73 CFTC ~EPT 8509.2988 TENS HOB 2.3971 CALI IPHI 29.8201 TNRA :CNT 2276.:1~$2 CFTC ~EPT 8~00.29~8 'TENS :HDB .2.5068 CALI IPHI 32.0476 TNRA ICNT 1984.08'1~ CmTC )EPT 9300. 2988 TENS ~HOB 2.3030 CALl IPHI 53.94?0 TNRA ~CNT 1 729. 4209 CmTC )EPT 8200.2998 TENS !HOB 2.3457 CALl ~PHI 47, S983 TNRA ~CNT 1505.4Zg7 CcTC )EPT 8 14 9. 7998 TENS tHg8 2.4397 C~LI ~PH! 46. 5838 TN~ ~CNT 18'98. 5110 CFTC 654B.0000 3.3702 571.4617 5912.0000 B.9531 2.8695 802.5153 6220.0000 ~.7344 2.7457 B75.1987 60~4.0000 9.343B 2.9452 743.~529 5~12.0000 8.8359 ~.1141 480.5207 566~.0000 8.~+531 3.7358 473.B378 5650.0000 8.9531 3.7215 512.1553 OPHI qTNR CNTC OPHI RTNP CN*C OPHI RTNR CNTC 3PHI ~ R RTNR CNTC OPHI RTNR CNTC OPHI GR RTNR CNTC ~R RTNR CNTC 15.0713 DRHO 94.1875 TENS 3.7154 RCmT 1880.9951 GR ~.7756 DRHO 83.~375 TENS 3.2143 RCFT 2331.5757 GR 15.3269 DRHO 75.2500 TENS 3.1750 RCFT 2407.0728 GR 8.5785 DRHO 12~.1250 'TENS 2.9722 RCFT 2104.5928 SR 21.0319 ORHO 11~.!,250 TENS 3.5000 RC~T 1B02.9490 GR 15.4447 ORHO 122.5250 TENS 4.0000 RCFT 1714.5649 GR 12.~06,4 9RHO !!8.5000 TENS 3.6667 RCFT 1851.1040 GR 0.0676 6548.0000 530.9700 94.1875 -0.0153 5912.0000 798.3333 83.9375 0.0242 6220.0000 722.1378 75.3500 0.0943 6064.0000 671.0801 124.1250 0.0296 5812.0000 435.6906 118.1250 0.0587 5668.0000 378.6201 122.6250 0.060~ 5660.0000 413.3013 118.5000 ~.- FILE TRAILr-R,., .,."i-. :ILE NAME :EDIT .002 ;ERVICE NAME :~LIC IERSION ~ :O01Ag2 )ATE :8810'?/ 9 4AXIMU~ LENGTH :1024 :ILE TYPE :LO ~EXT FILE .NA'~E : ,"-'-~ TAPE TRAILER '~"'-,--,- 5EiRVIC'5 NAME :ECIT )~TE :88/07/ 9 ]R~GIN :'FLOC rAPE NAME :72322 ]ONTINUA'TION '~. :1 VP OlO.HCI V~'..$!=IC~T!ON t!STlqG P~SE 23 ON~=NTS :LIS TAo,=, ~CO KUP&PUK ] 0-10, ~oI ~50-029-2t873 ~ REEL T°~ILF. 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