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Home My WebLink About188-124Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2Z-20 50-029-21876-00 910220628 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 12 2Z-20 50-029-21876-00 910219502 Kuparuk River Packer Setting Record Field- Final 12-Aug-25 0 13 3K-102 50-029-23378-00 910262525 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 14 3M-13 50-029-21720-00 910219405 Kuparuk RiverLeak Detect LogField- Final 8-Aug-25 0 15 3M-13 50-029-21720-00 910219403 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-25 0 16 3M-13 50-029-21720-00 910219405 Kuparuk River Plug Setting Record Field- Final 8-Aug-25 0 17 3Q-07 50-029-21682-00 910180539 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-25 0 18910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:188-124207-165187-040186-194T40834T40834T40835T40836T40836T40836T408378/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:54:51 -08'00'188-124207 1652Z-2050-029-21876-00 910220628Kuparuk RiverMulti Finger CaliperField & Processed5-Aug-250122Z-2050-029-21876-00 910219502Kuparuk RiverPackerSetting RecordField- Final12-Aug-2501 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govDecember 20, 2024 Erika Livingston Interventions & Integrity Supervisor ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-24-036 Notice of Violation – Closeout High Outer Annulus Pressure KRU 2Z-20 (PTD 188-124) Dear Ms. Livingston: ConocoPhillips Alaska, Inc. responded to the above referenced notice of violation by letter dated December 17, 2024. The letter identified specific actions to prevent recurrence of the notice of violation, notably the implementation of additional training for drill site operators specific to bringing wells online with fluid packed annuli as well as a review of alarm and radio protocols. The corrective actions outlined in your letter address the operational and procedural concerns identified in the notice of violation. The Alaska Oil and Gas Conservation Commission does not intend to pursue any further enforcement action regarding the high outer annulus pressure excursion on KRU 2Z-20 (PTD 188- 124). Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner ecc: Jamie Bronga (Jaime.Bronga@conocophillips.com) Greg Hobbs (Gregg.S.Hobbs@conocophillips.com) AOGCC Inspectors Phoebe Brooks Jim Regg Victoria Loepp Jack Lau Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.20 07:55:27 -09'00' Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.20 08:01:32 -09'00' December 17, 2024 Gregory Wilson Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 Jessie Chmielowski Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 VIA E-MAIL (samantha.coldiron@alaska.gov) Re: Docket Number OTH-24-036 Notice of Violation – Request for Information High Outer Annulus Pressure Kuparuk River Unit 2Z-20 (PTD 188-124) Commissioners Chmielowski and Wilson: This letter responds to the Commission’s November 26, 2024, notice of violation and request for information (NOV–RFI). The Commission’s November 26 letter states that ConocoPhillips Alaska, Inc. (CPAI) failed to comply with Conservation Order (CO) 494, Rule 6 with respect to Kuparuk River Unit (KRU) producer well 2Z-20. At CPAI’s request, the Commission extended the deadline for CPAI to respond until December 17, 2024. In its November 26 letter, the Commission accurately states that on November 14, 2024, when well 2Z-20 was being brought online, the well’s outer annulus (OA) pressure reached 1850 psi. This pressure exceeded 45% of surface casing burst pressure. When this occurred, CPAI bled the OA and reduced the pressure, and CPAI notified the Commission of the event. The Commission’s letter requires that CPAI “describe specific steps that have been or will be taken to prevent the recurrence of this violation.” The Commission’s letter cites CO 494, Rule 6. Relevant provisions of CO 494, including Rule 6 are: Mike Timmcke GKA Operations Manager 700 G Street, ATO-1026 Anchorage, AK 99501 (907) 263-4631 (office) michael.d.timmcke@conocophillips.com By Samantha Coldiron at 11:12 am, Dec 17, 2024 2 CPAI’s normal practice, in accordance with Rule 3, is to notify the Commission by email when sustained well pressure exceeds the OA or inner annulus (IA) limits specified in Rule 3 (2000psi for the IA and 1000psi for the OA). That did not happen in this case. CPAI has determined that this pressure exceedance, while it remained at all times well below burst pressure, was due to drill site operator miscommunication and training issues. Specifically, work was delegated to a less experienced operator, who did not bleed the well prior to bringing it online or remain on site until the well was fully online. In addition, a pressure alarm (set at 950psi) was not timely communicated to the drill site operators by the CPF control room. To prevent the recurrence of these issues, CPAI has implemented the following measures: x CPAI is clarifying its integrity engineering written protocols to ensure that all Rule 3 notifications are made timely to the Commission. x CPAI is implementing additional training for drill site operators, emphasizing the importance of bleeding a fluid charged well before bringing it online and closely monitoring the well on site until it is fully on line. x CPAI is reviewing its alarm and radio protocols to ensure that alarms are timely communicated to drill site operators and that alarms are set at appropriate pressure levels relative to applicable Rule 3 and any associated temporary operational pressure limits. If the Commission has any questions or concerns with this plan, please contact me or Greg Hobbs (Greg.S.Hobbs@cop.com) at any time. Sincerely, Mike Timmcke GKA Operations Manager ConocoPhillips Alaska, Inc. 3 cc: Jack Lau (Jack.Lau@alaska.gov) Jim Regg (jim.regg@alaska.gov) Phoebe Brooks (phoebe.brooks@alaska.gov) Victoria Loepp (victoria.loepp@alaska.gov) From:Lau, Jack J (OGC) To:Coldiron, Samantha J (OGC); Livingston, Erica J Cc:Bronga, Jaime; Hobbs, Greg S; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC); Loepp, Victoria T (OGC) Subject:RE: NOV RFI KRU 2Z-20 (PTD #188-124) Date:Tuesday, November 26, 2024 2:25:25 PM Erica, Your request to extend CPAI’s response date from within 14 days to within 21 days is granted. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell From: Coldiron, Samantha J (OGC) <samantha.coldiron@alaska.gov> Sent: Tuesday, November 26, 2024 10:58 AM To: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Cc: Bronga, Jaime <Jaime.Bronga@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: NOV RFI KRU 2Z-20 (PTD #188-124) Docket Number: OTH-24-036 Notice of Violation – Request for Information High Outer Annulus Pressure KRU 2Z-20 (PTD 188-124) Samantha Coldiron AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govNovember 26, 2024 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7017 2400 0000 5648 0688 Erika Livingston Wells Chief Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-24-036 Notice of Violation – Request for Information High Outer Annulus Pressure KRU 2Z-20 (PTD 188-124) Dear Ms. Livingston: On November 18, 2024, the Alaska Oil and Gas Conservation Commission (AOGCC) was notified by ConocoPhillips Alaska, Inc. (CPAI) that on November 14, 2024, the outer annulus 1 pressure of 1850 psi on well KRU 2Z-20 (PTD 188-124) exceeded both 45% of surface casing burst pressure of 1584 psi and CPAI’s internal Do Not Exceed (DNE) limit of 1400 psi. Well KRU 2Z-20 has known inner annulus (IA) by outer annulus (OA) communication through a leaking inner casing packoff. The well was put online on November 14, 2024, with a fluid packed OA and without sufficiently bleeding down annulus pressures. The OA pressure reached 1850 psi before CPAI operations personnel responded and bled the annulus below the DNE pressure. A copy of the email notification to the AOGCC is attached. The facts reported by CPAI indicate a failure to operate this well in accordance with the requirements of Conservation Order 494, Rule 6: “… before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a) that the inner annulus pressure at operating temperature will be below 2000 psig and (b) that the outer annulus pressure at operating temperature will be below 1000 psig.” Failure to operate in accordance with CO 494 is a violation. 1 The casing strings surrounding the outer annulus of well KRU 2Z-20 are 7” 26# J-55 casing and 9-5/8” 36# J-55 casing. Docket Number: OTH-24-036 Notice of Violation and Request for Information November 26, 2024 Page 2 of 2 Within 14 days after receipt of this letter (next business day if the due date falls on a weekend or holiday), CPAI is requested to describe specific steps that have been or will be taken to prevent the recurrence of this violation. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jack Lau at jack.lau@alaska.gov or (907) 793-1244. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Jamie Bronga (Jaime.Bronga@conocophillips.com) Greg Hobbs (Gregg.S.Hobbs@conocophillips.com) AOGCC Inspectors Phoebe Brooks Jim Regg Victoria Loepp Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.11.26 09:43:36 -09'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 10:53:05 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from jaime.bronga@conocophillips.com. Learn why this is important From:Loepp, Victoria T (OGC) To:Lau, Jack J (OGC) Subject:FW: KRU 2Z-20 (PTD #188-124) OA DNE Excursion Date:Monday, November 18, 2024 8:16:41 AM Attachments:AnnComm Surveillance TIO for 2Z-20.pdf Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, November 18, 2024 7:50 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2Z-20 (PTD #188-124) OA DNE Excursion Hi Victoria, KRU 2Z-20 (PTD #188-124) is a production well with an internal CPAI waiver for IAxOA through a known wellhead packoff leak. On restarting the well on November 14, 2024 after some gas lift valve work, the OA exceeded its DNE of 1400 psi. The OA reached 1850 psi before onsite Operations personnel responded and bled the well. The OA was fluid packed and pressured up rapidly. Operations has discussed fluid packed annuli with the personnel involved. The surface casing is 9-5/8” 36# J-55 with a burst rating of 3520 psi. 45% of casing burst is 1584 psi. The well passed an MIT-OA to 1800 psi on 2/20/24 as part of its internal waiver compliance testing. The well is currently online and the OA pressure has stabilized below its DNE. Please let me know if you would like me to file a 10-403 or if this email will suffice as there are no planned actions at this time. The schematic, TIO plot, and bleed logs are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2Z-20 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2Z-20 2024-11-14 1850 625 -1225 OA 2Z-20 2024-11-15 1350 800 -550 OA 2Z-20 2024-11-17 1380 530 -850 OA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM, EST. 34' RATHOLE 7,619.0 2Z-20 4/24/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set TTS test tool. Replaced OV 2Z-20 10/30/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: PULLED 3.5 WFORD SFTY RELEASE & SNAP LATCH ASSBY @ 7196' RKB (DID NOT RECOVER ELMT FROM UPPER 10/16/2016 pproven NOTE: PULLED UPPER STRADDLE FPJP ASSEMBLY @ 7238' RKB (MISSING ELEMENT & TOP OF PKR DAMAGED) 10/15/2016 pproven NOTE: PULLED TEST TOOL, MISSING 2 OF 3 SEALS. RAN BRUSH THROUGH PACKER BUT DID NOT RECOVER SEALS 1/31/2016 pproven NOTE: View Schematic w/ Alaska Schematic9.0 1/17/2011 ninam NOTE: WAIVERED WELL: IA X OA COMMUNICATION 1/20/2003 WV5.3 Conversio n NOTE: Unable to pass OPLN NO-GO lugs @ 7386' RKG w/2.765' SWG 6/3/1998 WV5.3 Conversio n NOTE: Otis Ported Nipple is Flow Cut & Prevents 'C' Sand from being Isolated. 5/9/1997 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 3,690.6 3,471.3 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 7,809.0 6,253.3 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 7,447.6 Set Depth … 5,998.5 String Max No… 4 Tubing Description TUBING 4"x3.5" @ 4007' Wt (lb/ft) 11.00 Grade J-55 Top Connection DSS-HTC ID (in) 3.48 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 31.1 0.09 HANGER 9.000 FMC GEN IV TUBING HANGER 4.000 1,816.7 1,813.6 8.67 SAFETY VLV 5.900 AVA SIDEGUARD SAFETY VALVE (UNLOCKED 8/18/89) AVA 3.250 2,593.2 2,562.5 25.35 GAS LIFT 5.850 MERLA TMPD MERLA TMPD 3.351 4,007.2 3,672.4 50.95 XO Reducing 4.000 CROSSOVER 4" x 3.5" 3.500 4,242.8 3,820.6 50.82 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 5,002.5 4,319.8 47.72 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 5,440.4 4,612.8 47.41 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 5,877.9 4,911.2 46.96 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 6,309.4 5,208.0 46.38 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 6,714.4 5,488.0 46.21 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 7,116.5 5,766.5 45.60 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 7,166.7 5,801.6 45.70 PBR 4.000 AVA PBR AVA 3.000 7,180.3 5,811.1 45.73 PACKER 6.156 AVA RHS-XL AVA RHS-XL 3.000 7,225.6 5,842.7 45.60 GAS LIFT 5.312 CAMCO KBUG CAMCO KBUG 2.920 7,231.9 5,847.1 45.56 BLAST RINGS 4.500 BLAST RINGS (4) 2.867 7,386.2 5,955.5 45.60 NIPPLE 4.520 OTIS PORTED LANDING NIPPLE OTIS PORTE D 2.310 7,417.6 5,977.5 45.63 LOCATOR 4.000 TIW LOCATOR TIW 3.351 7,420.4 5,979.4 45.62 PACKER 6.156 TIW SS-BB PACKER TIW SS-BB 4.000 7,424.1 5,982.0 45.61 SBE 4.000 SEAL BORE EXTENSION 3.351 7,437.2 5,991.2 45.58 NIPPLE 4.520 OTIS XN 2.75" NIPPLE 2.635"NO GO, AVA nipple reducer pulled out of XN nipple located @ +/- 7404 RKB- NIPPLE UNUSABLE! OTIS XN 2.635 7,447.1 5,998.1 45.55 SOS 4.000 AVA SHEAR OUT SUB AVA 2.984 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,070.0 5,734.0 45.87 LEAK LEAK 1/6/2016 7,116.0 5,766.1 45.60 LEAK SMALL LEAK IN VICINITY OF OV @ 7116' RKB (RK LATCH BROKEN OFF 1994) 7/17/2012 7,214.0 5,834.6 45.68 OTHER Set TTS test tool in patch top ( 55" OAL) 10/30/2024 0.000 7,217.0 5,836.7 45.66 STRADDLE PATCH 21.35' FPJP STRADDLE PATCH ( 2.72" P2P, SPACER PIPE, JET PUMP <14X RATIO / PH-1107), SPACER PIPE, JJ TIEBACK # CPTB35032, & ANCHOR LATCH # CPS35042) (1.62" ID) CPP3 5106 10/19/2016 1.620 7,237.7 5,851.2 45.52 PACKER 3.5" ECLIPSE PACKER 2/5/2008 7,381.0 5,951.9 45.57 PATCH HES tubing patch 8/21/98, top @ 7381', bottom @ 7393' 8/21/1998 2.310 7,386.0 5,955.4 45.60 LEAK 'C' SAND JEWELRY LEAK AT PORTED NIPPLE 6/2/1997 2Z-20, 11/1/2024 2:49:34 PM Vertical schematic (actual) PRODUCTION; 33.0-7,809.0 FISH; 7,682.0 FISH; 7,682.0 IPERF; 7,598.0-7,614.0 APERF; 7,543.0-7,572.0 RPERF; 7,549.0-7,565.0 APERF; 7,522.0-7,532.0 RPERF; 7,523.0-7,530.0 SOS; 7,447.1 NIPPLE; 7,437.2 SBE; 7,424.1 PACKER; 7,420.4 LOCATOR; 7,417.6 SLEEVE; 7,387.0 NIPPLE; 7,387.0 NIPPLE; 7,386.2 LEAK; 7,386.0 PATCH; 7,381.0 IPERF; 7,266.0-7,350.0 PACKER; 7,237.7 GAS LIFT; 7,225.6 STRADDLE PATCH; 7,217.0 OTHER; 7,214.0 PACKER; 7,180.3 PBR; 7,166.7 GAS LIFT; 7,116.5 LEAK; 7,116.0 GAS LIFT; 6,714.4 GAS LIFT; 6,309.4 GAS LIFT; 5,877.9 GAS LIFT; 5,440.4 GAS LIFT; 5,002.5 GAS LIFT; 4,242.8 SURFACE; 35.0-3,690.6 FLOAT SHOE; 3,688.9-3,690.6 FLOAT COLLAR; 3,609.9- 3,611.6 GAS LIFT; 2,593.2 SAFETY VLV; 1,816.7 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.5 HANGER; 31.1 KUP PROD KB-Grd (ft) 40.99 RR Date 11/22/198 8 Other Elev… 2Z-20 ... TD Act Btm (ftKB) 7,993.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292187600 Wellbore Status PROD Max Angle & MD Incl (°) 51.17 MD (ftKB) 4,100.00 WELLNAME WELLBORE2Z-20 Annotation Last WO: End DateH2S (ppm) 100 Date 12/5/2018 Comment SSSV: TRDP Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,387.0 5,956.1 45.61 NIPPLE AVA 2.31" Ported nipple in patch. 8/21/1998 2.310 7,387.0 5,956.1 45.61 SLEEVE CII SLEEVE 5/26/2004 1.870 7,682.0 6,163.4 44.99 FISH Packing Ring for Sleeve Left in Well 2/19/1989 7,682.0 6,163.4 44.99 FISH 10" Bull Nose from Strip Gun Left in Hole 9/10/1989 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,593.2 2,562.5 25.35 1 GAS LIFT GLV BK 1 1,300.0 2/1/2017 9:00 0.156 4,242.8 3,820.6 50.82 2 GAS LIFT GLV BK 1 1,333.0 2/1/2017 5:00 0.188 5,002.5 4,319.8 47.72 3 GAS LIFT DMY BK 1 0.0 6/25/2004 11:30 0.000 5,440.4 4,612.8 47.41 4 GAS LIFT OV BK 1 0.0 10/30/2024 11:30 0.188 5,877.9 4,911.2 46.96 5 GAS LIFT DMY BK 1 0.0 8/25/1998 2:30 0.000 6,309.4 5,208.0 46.38 6 GAS LIFT DMY BK 1 0.0 2/1/2017 11:30 0.000 6,714.4 5,488.0 46.21 7 GAS LIFT DMY BK 1 0.0 1/31/2017 8:00 0.000 7,116.5 5,766.5 45.60 8 GAS LIFT OV RK 1 1/2 0.0 8/24/1994 6:00 Broke Latch 0.250 7,225.6 5,842.7 45.60 9 PROD OPEN BK 1 0.0 1/21/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,266.0 7,350.0 5,871.0 5,930.2 C-4, C-3, C-2, C- 1, 2Z-20 2/9/1989 12.0 IPERF 5" Omni Kone; 120 deg ph 7,522.0 7,532.0 6,050.7 6,057.7 A-5, 2Z-20 9/10/1989 8.0 APERF 2 1/8" Silver Jet; 60 deg. ph 7,523.0 7,530.0 6,051.4 6,056.3 A-5, 2Z-20 8/8/1994 1.0 RPERF 16' SWS Enerjet; 0 deg. ph 7,543.0 7,572.0 6,065.4 6,085.8 A-4, 2Z-20 9/10/1989 8.0 APERF 2 1/8" SIlver Jet; Post Frac Perfs; 60 deg. ph 7,549.0 7,565.0 6,069.6 6,080.9 A-4, 2Z-20 8/8/1994 1.0 RPERF 16' SWS Enerjet; 0 deg. ph 7,598.0 7,614.0 6,104.1 6,115.4 A-3, 2Z-20 2/9/1989 8.0 IPERF 120 deg. ph; 5" Omni Kone 2Z-20, 11/1/2024 2:49:35 PM Vertical schematic (actual) PRODUCTION; 33.0-7,809.0 FISH; 7,682.0 FISH; 7,682.0 IPERF; 7,598.0-7,614.0 APERF; 7,543.0-7,572.0 RPERF; 7,549.0-7,565.0 APERF; 7,522.0-7,532.0 RPERF; 7,523.0-7,530.0 SOS; 7,447.1 NIPPLE; 7,437.2 SBE; 7,424.1 PACKER; 7,420.4 LOCATOR; 7,417.6 SLEEVE; 7,387.0 NIPPLE; 7,387.0 NIPPLE; 7,386.2 LEAK; 7,386.0 PATCH; 7,381.0 IPERF; 7,266.0-7,350.0 PACKER; 7,237.7 GAS LIFT; 7,225.6 STRADDLE PATCH; 7,217.0 OTHER; 7,214.0 PACKER; 7,180.3 PBR; 7,166.7 GAS LIFT; 7,116.5 LEAK; 7,116.0 GAS LIFT; 6,714.4 GAS LIFT; 6,309.4 GAS LIFT; 5,877.9 GAS LIFT; 5,440.4 GAS LIFT; 5,002.5 GAS LIFT; 4,242.8 SURFACE; 35.0-3,690.6 FLOAT SHOE; 3,688.9-3,690.6 FLOAT COLLAR; 3,609.9- 3,611.6 GAS LIFT; 2,593.2 SAFETY VLV; 1,816.7 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.5 HANGER; 31.1 KUP PROD 2Z-20 ... WELLNAME WELLBORE2Z-20 • • ,4V*6 - '2-44 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender REC 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 1-EB 1 0 2016 2 P� Kz BENDER ''°°''�� . A000J RE: Multi Finger Caliper: 2Z-20 Run Date: 1/9/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-20 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21546-00 Multi Finger Caliper(Field Log) 1 color log 50-029-21546-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 SCOW ' Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:. ✓aAuN'icv • • .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r- Performed: Suspend r Perforate Other Stimulate Alter Casing r g r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Tubing patch W 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory r 188-124 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21876-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025646 KRU 2Z-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7993 feet Plugs(measured) None true vertical 6384 feet Junk(measured) None Effective Depth measured 7655 feet Packer(measured) 7180, 7420 true vertical 6144' feet (true vertical) 5811, 5979 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 3656 9 5/8 3691 3471' PRODUCTION 7776 7 7809 6253' _ VED SCANS, ivk.°,rt' rt '; FEB 10 2016 Perforation depth: Measured depth: 7266-7350, 7522-7532, 7523-7530,7543-7572, 7549-7565,7598-7614 g'`" GCC True Vertical Depth: 5871-5930, 6051-6058,6051-6056,6065-6086,6070-6081,6104-6115 AO GCC (size,grade,MD,and TVD) 3.5,J-55, 7447 MD, 5998 TVD 3.5"SOS Paragon retrievable patch from 7106-7132 Packers&SSSV(type,MD,and ND) SAFETY VLV-AVA SIDEGUARD SAFETY VALVE(UNLOCKED 8/18/89)@ 1817 MD and 1814 TVD PACKER-AVA RHS-XL @ 7180 MD and 5811 TVD PACKER-TIW SS-BB PACKER @ 7420 MD and 5979 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Brent Rogers/Kelly Lyons Email: N 1617(C�Conocophillips.com Printed Name Brent Rogers Title: Problem Well Supervisor Signature ! /tic-- v V Phone:659-7224 Date 02-09-16 Form 10-404 Revised 5/2015 d,7 0,t( RBDMS LL FEB 1 0 2016 Submit Original Only • • ~V • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 9, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. KRU injector 2Z-20 (PTD 188-124). The report is for a 26' TTS retrievable tubing patch that was set to repair a tubing leak above the packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • 2L-310 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/31/16 SET LOWER 2.72" PARAGON II PACKER @ 7132' RKB (MID ELEMENT). SET TEST TOOL IN SAME. LRS PERFORMED PASSING MIT-T TO 2500#. PULLED TEST TOOL, BUT WAS MISSING 2 OF 3 SEALS. RAN BRUSH THROUGH PACKER BUT DID NOT RECOVER SEALS. SET UPPER PATCH ASSEMBLY(2.72" PARAGON II PACKER, SPACER PIPE, LATCH SEAL ASSEMBLY; OAL-26.41') @7106' RKB (MID ELEMENT) *JOB IN PROGRESS UPPER PARAGON II PACKER SER#CPP35044 LATCH SEAL ASSEMBLY SERIAL# CPAL35019 LOWER PARAGON II PACKER SER#CPP35009 LRS PERFORM MIT-T TO 2500#. PRE: 750/500/25 INITIAL: 2500/550/25 0.6 BBLS TO PRESSURE UP. 15 MIN: 2400/560/25 30 MIN: 2375/560/25 02/01/16 SET TEST TOOL IN TOP OF PATCH @ 7106' RKB, SET CATCHER ON TOP OF TEST TOOL, PULLED 1" DMY VLV FROM ST#7 @ 6714' RKB AND SET 1" OV(1/4" PORTS) IN SAME. LRS ATTEMPTED MIT-T TO 2500#, BUT FAILING BY LINEAR PRESSURE LOSS. PULL OV FROM ST#7 @ 6714' RKB, SET 1" OV(1/4" PORTS, HIGH SEALABILITY PACKING) IN SAME. LRS ATTEMPT MIT-T TO 2500#WITH SAME RESULTS AS PREVIOUS ATTEMPTS. SUSPECT LEAK IS BY TEST TOOL OR UPPER PIIP. RIG DOWN DSL FOR HIGH PRIORITY RIG JOB. *JOB IN PROGRESS; ***CATCHER IN WELL***TEST TOOL IN WELL*** 02/04/16 PULLED CATCHER SUB &W/ PARAGON TEST TOOL STUCK ON BOTTOM @ 7103' RKB; SET HOLEFINDER ON TOP OF PATCH @ 7106' RKB &OBTAIN GOOD 2000 PSI TBG TEST; LD DOWN DUE TO HIGH WINDS. IN PROGRESS. 02/05/16 WEATHER DELAYED START. RAN PARAGON TEST TOOL&TESTED UPPER PARAGON PKR @ 7106' RKB (MITT TO 2500/PASS); JOB COMPLETE MIT-T 2500# INITIAL= 1000/450/40; F/L= 190 START=2550/525/40; F/L=190 15 MIN= 2450/525/40; F/L= 190 30 MIN=2450/525/40; F/L=190 Summary A 26'element to element SOS Paragon retrievable patch was set from 7106'to 7132'. • Pio1130-12- 1- Loepp, b' - J11'Loepp, Victoria T (DOA) From: Manoppo, Elan Rizaldi <Elan.R.Manoppo@conocophillips.com> Sent: Monday,January 11, 2016 9:10 AM To: Loepp, Victoria T (DOA) Cc: CPF2 Prod Engrs; Cecil-Cockwell, Tess M Subject: RE: 2Z-20 Well Test and Well Integrity issues(PTD 188-124) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you. SCANNED MAY 1 9 2096 Regards, Elan. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@aalaska.gov] Sent: Monday, January 11, 2016 8:07 AM To: Manoppo, Elan Rizaldi Subject: [EXTERNAL]RE: 2Z-20 Well Test and Well Integrity issues Elan, A waiver from the 30 day well test requirement until barriers are confirmed and the well can be brought on in a safe manner is granted for Well 2Z-20 for January, 2016. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppt alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Manoppo, Elan Rizaldi [mailto:Elan.R.Manoppo@lconocophillips.com] Sent: Monday, January 11, 2016 7:41 AM To: Loepp, Victoria T(DOA) Subject: FW: 2Z-20 Well Test and Well Integrity issues Victoria, Liz asked me to follow-up with you on our well test waiver request for 2Z-20 below. 1 • Would there be additional information that you need from us to progress it? Thank you for your kind attention and time. Regards, Elan Rizaldi Manoppo (Liz Jolley DOA) Tarn Development Team Lead ConocoPhillips Alaska P+1 (907) 263 4323 F+1 (907) 263 4945 From:Jolley, Liz C Sent:Tuesday,January 05, 2016 11:44:51 AM To: Loepp, Victoria T(DOA) Cc: Cecil-Cockwell,Tess M; CPF2 Prod Engrs; Manoppo, Elan Rizaldi Subject: 2Z-20 Well Test and Well Integrity issues Hi,Victoria, We have a well that was shut in for water and gas handling in November on the 2Z drillsite and now has well integrity issues and will likely not be able to be tested within the 30 day requirement until the well integrity issues are resolved. Here is a summary of the activity for 2Z-20 and the plan forward. ConocoPhillips is requesting a waiver for the 30 day well test requirement until barriers are confirmed and the well can be brought on in a safe manner. We are currently working to secure the well to perform more diagnostics. 2Z-20 was shut in for low oil production and gas handling on 12/08/2015. The most recent well test before the DS 2Z Test Separator was taken out of service for maintenance was on 11/04/2015: 9 bopd, 1604 bwpd,99%WC, 1613 blpd, 1275 mscf. The DS 2Z Test Separator,for which a testing waiver was granted for December 2015 and January 2016,was back in service 12/12/2015. On 01/01/2016,the Well Integrity group found gas coming out of the 2Z-20 conductor. The Well Integrity group has been working to diagnose the problem since, with additional TxIA suspected 01/04/2016. 2Z-20 is already waivered for IAxOA communication, and will not be brought online for testing until barriers are confirmed. Time Line of Events: • 11/04/2015—Most recent 2Z-20 well test: 9 bopd, 1604 bwpd, 99%WC, 1613 blpd, 1275 mscf. • 11/11/2015—2Z-20 SI for water handling • 11/15/2015—2Z-20 Brought on line • 11/16/2015—2Z-20 shut in for gas handling • 11/19/2015- DS 2Z Test Separator out of service for maintenance. Testing waiver granted for December and January. • 12/02/2015—2Z-20 Brought on line • 12/08/2015—2Z-20 Shut in for gas handling. • 12/12/2015—DS 2Z Test Separator back in service • 01/01/2016—Gas found coming out of the 2Z-20 conductor 2 • • • 01/01/2016 (&ongoing)—Diagnostics of annular communication.Additional TxIA suspected 01/04/2016. Well is already waivered for IAxOA Communication. • 01/07/2016—2Z-20 30-day well test due; well will not be BOL until barriers are confirmed. Please let me know if you have any questions. Regards, Liz Liz Jolley CPF2 Devlopment Supervisor ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 3 • ,�5 WELL LOG TRANSMITTAL PROACTIVE DiAgNosric SERVICES, INC. To: AOGCC Christine Shartzer 333 West 7th Avenue Suite 100 %AWED APR 0 8 2Q16 Anchorage,Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ WIT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1] Leak Point Survey 10-Sep-12 2Z-20 1 CD 50-029-21876-00 2) Leak Pointe"Survey 12-Sep-12 2V-10 1 CD 50-029-21310-00 Signed : i Date : `2-i(\Z Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(4�MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Archives\Distribution\TransmittalSheets\BP Transmit.docx `r6 2�`5Zc7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 0 8 Nib. RE: Multifinger Imaging Tool (MIT)/Leak Detect Log: 2Z-20 Run Date: 8/27/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z-20 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21876-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: q <f) ix 2 Signed: / I V1) Imag'~Project Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / 7.,7 RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [] Diskettes, No. [3 Maps: n Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: .~, OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [3 Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanning Preparation ._~.'x 30 = ~..~__ + = '~OTAL PAGES ?D BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning Stage1PAGECOUNTFROMSCANNEDFILE: ~ Y~ES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BYi BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN ~IDIVlDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) /SI ReScanned (individual page [special attention] scanning completed) RESCANNEDBY~ 'BEVERLY BR~HERYL~ MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned,wpd ~ ~/ • . ConocoPhillips Al~ska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ ~~~~1~~~ ~C~~ 1 ~ ~(~t~~ ~ska Qil ~ Gas Cons. Con~rr-issian Anchoraqe October 12~', 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~ ~ ~~ ~~ ~ ~ y'1 rl --~ i ~;; °~"~~Gi.~~~~'' ~`~ `r i. ~' ~,~~~~ ~~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. 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 September 2"d, 2009 and the corrosion inhibitor/sealant was pumped September 4~', and September 5~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. ely, Perry ConocoPhillips Well Integrity Projects Supervisor .. . .; • . i. ConocoPhiliips Alaska Inc. SurFace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 70/5/2009 ~i ~ ~ ~~ ~en Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-04 50029212700000 1850070 10'5" 1.5 6" 9/2/2009 1.27 9/5/2009 2U-11 50029213030000 1850400 6' 1.00 9" 9/2i2009 1.9 9/5/2009 2Z-08 50029209240000 1830380 5' 1.50 24" 9/2/2009 2.5 9/4/2009 2Z-09 50029213770000 1851360 4'6" 0.70 22" 9/2/2009 6.3 9/4/2009 2Z-20 50029218760000 1881240 6' 0.80 30" 9/2/2009 8.9 9/4/2009 2Z-29 50029218810000 1881290 26'5" 3.50 24" 9/2/2009 8.9 9/4/2009 Scblußlbepgel' 12/19/06 Œ~ NO. 4077 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ 1 ZOO(3 Cflrm!1Ît\~iD!l ... ...... A. 1\\N):.; ~ > \;if ~'~~~~:'\J_ >~~~,_;--/ ¡;~i~ "";.¡ ~, ç., () Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Anchorng~ 11J~ -10<'( Field: Kuparuk Well Job# Date BL Color CD Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1 J-136 11534188 USIT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1 F-1 0 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 iF-OS N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1 H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 1, 2000 THRU: Tom Maunder, ,,,.,--"/~.~ '-~ P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2Z Pad Friday, December 1, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2Z Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with two failures observed. The surface safety valve on wells 2Z-7 and 2Z-10 had slow leaks when pressure tested. These two valves will be serviced and retested by the operator. -Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary:. I witnessed the semi annual SVS testing at 2Z Pad in the Kuparuk River Field. KRU 2Z Pad, 12 wells, 24 components, 2 failures 8.3% failure rate Attachment: SVS KRU 2Z Pad 12-1-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2Z Pad 12-1-00 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Schcve Date: Operator Rep: Emie Barndt Field/Unit/Pad: Kupauk / KRU / 2Z Pad AOGCC Rep: Chuck Scheve Separator psi: LPS 100 HPS 12/1/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed CAS or CYCLE 2Z-01 1830730 100 70 70 P P OIL 2Z-02 1830800, ' 2Z-03 18308501 2Z-04 1830860 2Z-05 1830760 100 70 70 P P OIL 2Z-06 1830770 3700 2000 2000 P P WAG 2Z-07 1830640 100 70 65 P 4 OIL 2Z-08 1830380 2Z-09 1851360 2Z-10 1851370 100 70 70 P 4 OIL 2Z-11 1851380 2Z-12A 1951480 100 70 501 P P OIL 2Z- 13 1851060 2Z-14 1851070 2Z-15 1851080 3700 2000 1700 P P WAG 2Z-16 1851090 2Z-18 1881330 100 70 65 P P OIL 2Z-19 1881300 100 - 70 65 P P OIL 2Z-20 1881240 100 70 100 P' P OIL 2Z-21 1881250 100 70 70 P P OIL 2Z-22 1941470 2Z-23 1950100' 2Z-29 1881290 100 70 70 P P OIL 2Z-WS1 1851580 Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% [390 var Remarks: Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the operator. 2/4/00 Paee I of I SVS KRI 1 27 Pad 19_-1-00 c.q xl.q THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LORrxMFILM.DOC E E L E W A T E R IA L U N D ER TH I.S MARKER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate ...... Plugging Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O: Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1903' FSL, 647' FEL, Sec. 11, T11N, R9E, UM At top of productive interval o. sec. 11, 11N, R E C £1V E D At effective depth 301' FSL, 72' FWL, Sec. 1, T11N, R9E, DM At total depth DEC- 11994 481' FSL, 104' FWL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: Perforate X Other 6. Datum elevation (DF or KB) RKB 109' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-20 9. Permit number/approval number 88-124 10. APl number 50-029-21876 11. Field/Pool ~,,Kuparuk River Field/Oil Pool measured 7992 feet A, 13[~~nehnr:' (measured) true vertical 6188 feet Effective depth: measured 7728 feet Junk (measured) true vertical 6188 feet Casing Length Size Structural Conductor 80' 1 6" Surface 3656' 9 5/8" Intermediate Production 7776' Liner ? Perforation depth: measured true vertical Cemented Measured depth True vertical depth ii 205 sx AS II 115' 115' 800 sx AS III & 36 91 ' 3473' 400 SX CLASS G & TOP JOB w/30 sx ASI 250 sx Class G 7 8 0 9' 6245' 7266' - 7350', 7598' - 7614', 7522' - 7532', 7543' - 7572' 5872'- 5931', 6104'- 6116', 6051'- 6058', 6066'- 6087' Tubing (size, grade, and measured depth) 4" 11#/ft J-55 @ 4006' & 3.5" 9.3 #/ft J-55 @ 7447' Packers and SSSV (type and measured depth) AVA 'RHS-XL' PKR @ 7180', TIW 'SS-BB' PKR @ 7420', AVA 'Sideguard' SSSV @ 1817' 13. Stimulation or cement squeeze summary REPERFORATE A SANDS @ 1 SPF 0° PHASING Intervals treated (measured) 7523' - 7530' & 7549' -7565' Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 630 505 147 1000 260 660~/544 170 800 240 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date ~'~...~' ~'J~' ~,~ SUBMIT'~N DUPLICATE ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL ?_'7_ --LO DATE ~5-~-~ DAY TIME DESCRIPTION OF WORK I~ECEiVED CONTRACTOR/KEYPERSO. DEC - ] 1994 ~ ~ \,., -- ~,..~c~... I ..-~' ,.I,., ~ ~. ~ ~ Alaska 0il & Gas Cons. Commission OPERATION AT REPORTTIME FIEi~J~,[ :' ¢ , COMPLETE [] INCOMPLETE $ l ~ ~-~ 7. ~ ~ AFC/CC ACCUMULATED COST $ 2_?.. 4-8Z5, 55 [7.: CHECK THIS BLOCK IF SUI~MARY CONTINUED ON IBACK %?othrte, I Temp.. °F'I Chill Factor °F'I Visibility ..n~iles l Wind Vel. AR3B-7031 knots I s'wd& --r:-. REMARKS CONTINUED: ACCUM. SERVICE COMPANY SCA # DAILY TOTAL . ~ ~ ~ ~ ~ ....... ~ ,, STATE OF ALASKA ALA~bKA OIL AND GAS CONSERVATION COMMIbkSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well .... 2. Name of Operator ARCO Alaska, Inc. 3. Address 5. Type of Well: P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1903' FSL, 647' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 0' FNL, 30' FEL, Sec. 11, T11N, R9E, UM At effective depth 301' FSL, 72' FWL, Sec. 1, T11N, RgE, UM At total depth 481' FSL, 104' FWL, Sec. 1, T11N, R9E, UM Development X, Exploratory _ Stratigraphic _ Service 12. Present well condition summary Total Depth: measured true vertical 7992' feet Plugs (measured) 6 1 8 8' feet Other 6. Datum elevation ([~F or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-20 9. Permit number/approval number 3-124 10. APl number 50-029-21876 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7728' feet Junk (measured) true vertical 61 88' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 2 0 5 SX AS II 1 1 5 1 1 5 Surface 3656' 9 5/8" 800 sx AS III & 3691' 3473' Intermediate 4 0 0 SX CLASS G-TOP JOB w/30 sx ASI Production 7 7 7 6' 7" 2 5 0 Sx Class G 78 0 9' 6 2 4 5' Liner Perforation depth' measured 7266'-7350'M 7598'-7614' '~ ~ C E I V'~ true vertical 5872'-5931 ' 6104'-61 16' Tubing (size, grade, and measured depth) 4"/3 1/2", J-55, tbg w/tail & Corem Packers and SSSV (type and measured depth) AVA 'RHS-XL' PKR ~ 7180', TIW 'SS-BB' PKR ~ 7420', ~VA 'Sideguard' SSSV ~ 1817' 13. stimulation or cement squeeze summary 'A' SAND FRACTURE STIMU~TION Intervals treated (measured) 7598' - 7614' Treatment description including volumes used and final pressure SEE ATTACHED SUMMARY 14. Pre ssure R. epresentative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation 537 455 497 188 Subsequent to operation 961 974 1210 268 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector Daily Report of Well Operations X.. Oil X Gas Suspended i7.' I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-~, ~~ Title Zi~ E i,~ ,'¢~r'- Service Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE .~,~:~a,..~v~.¢. :-.. : : :.:: :~ ~ -:~ PARUK STIMULATION SUMMARY ~~S; ~1o~ ~K~ CONTRACTOR: ~ ~0 · PEaFS: ~, ~ aac0 aEe: ~~/~/~~ HOLE aNGLE ~-PERFS: 4~ o AFE ~: ~~ ~1 ., SAND P~llF INTERURL CDMPRN¥ TVPE DENSITY P#RSINB RCTURL UOLUME RATE PRESSURE PROP. PROP. ANN. -- i SLURR. ~ ~ ' . ..... . , EFF. PROP. Z . ~0 · HTFN: ~ / ~/A_~~ FNNC 6'RND: ~,-F~ / DESIGN UOLUME TBI.FRI¢: -/5"0 PERF FRIC:~IO/ / LEAK OFF: 5 MIN. ~IA - ~crce ^ o~'~c. I 0 MIN. LOS INTERURL: ,,v/~- ~/o FLUID TEMP: C~l ° FLUIDUISC: ~IcR _~ 15 MIN. --- ADDENDUM WELL 2Z-20 8/13/89 Frac Kuparuk "A" sand perfs 7598'-7614' in thirteen stages as follows. Stage 1: Pmp 80 bbls Bora Gel 1400; 40# Data Frac@ 20 bpm 5120-4730 psi Stage 2: Prop 50 bbls Bora Gel 1400; 40# Data Frac@ 5-20 bpm 5850-5075 psi Stage 3:50 bbls Bora Gel 1400; 40# Data Frac.@ 5-20 bbm 5000-5550 psi Stage 4:50 bbls Bora Gel 1400; 40# Data Frac@ 2-20 bpm 6400-4715 psi Stage 5:200 bbls Bora Gel 1400; 40# Data Frac@ 20 bpm 5450-3960 psi Stage Stage Stage Stage Stage Stage Stage Stage Screen out 23 bbl short of flush. and 80 bbl Gel Water flush @ 20 bbm 3400-4300 psi 6:180 bbls Bom Gel pad @ 20 bpm 3400-4300 psi 7:18 bbls Bora Gel w/2 ppg 16/20 Carbolite @ 20 bpm 4300-4050 psi 8:17 bbb Bora Gel w/4 ppg 16/20 Carbolite @ 20-19 bpm 4050-3600 psi 9:20 bbb Bora Gel w/6 ppg 16/20 Carbolite @ 19-20 bpm 3600-3150 psi 10:22 bbls Bora Gel w/8 ppg 16/20 Carbolite @ 20 bpm 3150-2610 psi 11:24 bbb Bom Gel w/10 ppg 16/20 Carbolite @ 20 bpm 2610-2520 psi 12:13 bbb Bom Gel w/12 ppg 16/20 Carbolite @ 20 bpm 2520-2500 psi 13:57 bbls Slick Diesel flush @ 20-19 bpm 2500-6300 psi Fluid to recover: 911bbls Sand in zone: 28256 lbs Sand in csg: 11,167 lbs Avg pressure: 3600 psi RECEIVEi , ,, APR o ]9? .Oil,& Gas Cons. Commission : Anchoraff~ ~Supervisor Date STATE OF ALASKA ,$KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r~ GAS ~ SUSPENDED [~ ABANDONED r'"] SERVICE r-~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-124 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21876 ~-'-~~ .. !9 Unit or Lease Name 4 Location of we,, at sur, .ce lg02' FSL, 647' FEL, SEC 11, T11 N, RgE At Top Producing IntervalUM~ ~.~4. -~'~'~-~-~['~;m · j~.~j "/Et{IFI~FA) : 10 Well NumberKUPARUK RIVER UNIT At Total Depth ~ 1 Field and Pool 495' F.SL, 33' FEL, SEC 1, TllN, ROE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Desionation and Sedal No. KUPARUK RIVER OIL POOL I RKB 109' ADL:.2.,5~ AKL: 2674 12 Date SpuddedNov 13 1988 13 Date T. Di' ReachedNov 18 1988 ,14 Date Comp., Susp. or Aband.,~A.~7~o.8~;j~ I15 water Depth' if °ffsh°reNA feet MSL!16 N°' ~°f c°mpleti°nsl 17 Total Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 7992' MD & 6384' TVD 7728' MD & 6197' TVD YES ~'~ NO r'"]I 1817' feet MDI 1400' (approximate) 22 Type Electric or Other Logs Run DIL.:SFL, GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 205 SX CS II 9 5/8" 36# J-55 SURF 3471' 12-1/4" 800 SX AS III & 400 SX CLASS G ,, 7" 26# J-55 SURF 6254' 8-1/2" 250 SX CLASS G & 200 SX AS 1 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 (MDI 7226'-7350' MD, 5" W/12 SPF 5872' - 5931' TVD 4"/3-1/2" 7392' 7366' 7598'- 7614' MD, 5" W/8 SPF 6104'-6116' TVD 7522' - 7532' MD, 2-1/8" W/8 SPF 6051' - 6058 TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7543'. 7572' MD, 2-1/8" W/12 SPF 6066'. 6087' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ... 7598'-7614' 28,256 lbs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,,~ FI0w Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) !Press. ~24-HOUR RATE ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 ubtnlt m duphcate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS =,, NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 7264' 5870' NA BOTTOM KUPARUK C 7364' 5941' TOP KUPARUK A 7512' 6044' BOTTOM KUPARUK A 7693' 6172' 31. I"IST OF ATTACHMENTS 32. I hereby certify that the foregoing is irue and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 December 15, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-80136 Well: 2Z-20 Field: Kuparuk Survey Date: December 3, 1988 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure ' OF:'MED NL Sperry. SunlNL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA, _~.~-20 .... KUPARUK ALASKA SPERRY-SUN WELL SURVEYING COI~F~:)NY .. , PAGE ' 1 '' ' '~ " ;~?: .~ :~ ..: ~:~.:.:.....~: :. · ~. ANCHORAGE ALASKA -" "..::.' ' ..... :"'?"~" ..... ~..?'~J i.:..' ': ::~i:' ':r ?"'":"~:'.:'i:~i.....i:::: ~"'i':/::': :~...~:~::~ '. i?!!ili~ i/:~!i::~i:~::~i:J:~i~J''~:'' INC. DATE OF SURVEY DECEMBER ~,':,.19 8:' '. ' ooMPUTATION..DATE:,:.'. :.. :..: :.BOSS' GYROSCOPI.C SURVEY':,`: : ... "~:.i-;;:. ' DECEMBER 6, 1.988 ._lOB NUMBER AK-BO-80136 KELLY BUSHING ELEV. = 10~,.00 FT. OPERATOR-HARGER VERTI'CAL'::SE~:Z'~'N CALCULAT~D..:ALONG?.~OLOSURE.'~. ~::'"~.~:.~:..'~'.:~:? ./i~:":~'~.'r' '::.'"'~ ~:'.~'.' ~.:":~::~'..:~'"" ~ .:.:~....~::.:~ .... ~:: · >: :'.. ~.'~:~:~:~.~.:~ :'..:::~::~::::.~:....:...:...... ~,.:.~?.: .):: :::: . ::-. · :....:. MEASURED VERT I CAL VERTICAL INCLINATION DIRECT I ON SEVER I TY RECTANGULAR COORDI NATES VERTICAL DEPTH DEPTH DEPTH BEG MIN DEGREES BEG/100 NORTH/SOUTH EA..T/WEoT SECTIOn' ) 1 O0 100. O0 -9. O0:/::'::- 0 !:ii:::::18'?"~ S '67.19 E O. 31 200 200,00 91,00 0 18 S 79,19 E 0.07 O. O0 O. O0 0.10 S 0.25 E 0.26 S 0.76 E o, o0 =0.06 -0.12 300 300.00 191, O0 0 -.:,.'-"" S 60.8.9 E O. 14 O. 47 S 1.~0 E -0.24 400 3'.~9.9.9 2.90.99 0 33 S 65.80 E O, 18 O. 83 S 2.03 E -0.46 500 4.9.9.99 3.90..99 0 44 S 76. 0 E O. ~'--' . . ~.'- 1 18 S 3 0.9 E -0.63 600 700 800 ~00 1000 1100 1200 '~Oo ~4oo 1500 · 799.94 !.: ::6:~0~ ':::,94:'~/'~' ': :':i::': 1 21:/ :: '::S:'75~"39'E ' 0'31 2~53 S 8,21.._ E -!,07 8.9.9.91 790..gl 1 27 S 74.8.9 E O. 10 o.'" 16 S 10.5.9 E -1 . 28 .99.9.87 8.90.87 1 37 S 71.30 E 0.1.9 3,.94 S 13.16 E -1.61 !09~,83 .9~0,83. I 51 S ~7.8~ E 0.26 5.01 S ~6,00 ~ -2.17 ~ ,~/1 i~.~76'~:~ ~ ~?.:: ~o~o ' 7~::~ ~2/':~.~' les?~?8~.~o~ ~:~:~:~' ?:' ~:~: o~ ~ :~ ~. ~:~. /~5~ s' ': :~. i ~, 50 ~"' ::.' :: 1~, ~0 ' ::::::::::::::::::::::::::::::::: N"68-60::'.E ~:.. :~": ::':::;:: O, : ' ::.. ~.. :1,28.. ~: ...... :.:. 3~, 20 .~ :.:' J4~8.7e ~38~, 78 s 21 N 70, J~ E ' o' ~2 J. ~5 N 41.7e E ~, 1 1600 1700 1800 1900 2000 2100 2200 2300 2400 2450 1598.34 1489,34 5 26 N 74, 0 E 0.37 4. 16c)7, 86 1588,86 ............... 5 .... 48 .......... lY., .7..37.30..,. E ................. 0,38 .................. ::' 1797, 06 1688, 06 :::i ~:.~:: ~::' 8 :: 34 :~ :: ~/. ~N .J 6:7" 19 E '.' ii:::::' .: 2.87 11. '"~':?::" ~995, 86 'i::'1786~96'~::i ::::::::::::::::::::::: 1 ~?:?. N ::'68:, ~.9,~ E .;:~: "?..::. ::0; 6S ii 17, ': '' ::' ' · .i ..' .' · , ' !974,49 ~ 1885,.4~i . :'i' "_911::ii'.4.7. : N'70, lO.i':E"ii;;. ;:... i ;: 0' 64 ::: : :: '... 23, 20.g2.86 1.983.86 10 52 N 6.9.10 E 1 . 0.9 29 2190,48 2081,48 14 14 N 56.19 E 4.36 40. 2287.10 2178.10 15 48 N 3.9.60 E ..4,5..6. . 57, .. . 2382.96 2273,96 17' 25. ::. : N 26. 0 E : 4.20 81.30 N 2430.46 2321.46:1.'::i: iS) ':' 1 ~.iN'15.50 E :' : 7, 28 .95,89 N 84 N 60 N 94 .:N 74 N 53 N 7.9 N O0 N 34 N 50.74 60,~14 71~87 .... :1o1. 118. 137. 156. 171. 177. 2500 2600 2700 2800 2477.26 2368.26 22 I0 N 1 I. 60 E 6, 87 112,.78 2568.6.9 2459.6.9 25 ,~5 N 12.60 E 3.44 152,56 N 2658.26 2549.26 27 11 N 14.10 E 1.74 1~5.80 N 2746.80 2637,80 28 !0 N !4,10 E 0, .98 .-.-4C 87 N 181, 18~. 19.9. 211, E 13.53 ~. .................. 17.88 1.9 E :" i' ~:~2;i~?:;~:: 62 E ... :.:40, 42 E 49.81 46 E 63.1 37 E ~', 50 ...... 62 E 109.74 ' 08 E 125.05 1._6___E .... 142.60~ 66 E 183.04 .~4 E 227.41 2~. £__. . 273.76 SPERRY-SUN WELL SURV£YIN~ COMPANY = ~ ~= . '~. DATE oF. SURVEY DECEMBER ARCO ALAS~A,'INC. KUPARUK DECEMBER 5, 1988 dOB NUMBER AK-BO-8013~ ALASKA KELLY BUSHING ELEV. = 109.00 FT. MEASURED VERTICAL DEPTH DEPTH VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR DEPTH DEG MIN DEGREES DEO/IO0 NORTH/SOUTH 2900 28~5-'45 2726'":45' ::i:::::.:26'.:::.::58:::: 'Ni:::/8,60 E 2 81:' 286.20 N COORDINATES EAST/WEST VERTICAL SECTIOn') :::.: · .: ..... :-:-::.=. :..~ .-,:~ ,,~ 3100 1.75 380.84 N 22:0. :41 E, ', :;:: 319"99 235.08 E 4!5.74 : 3200 3096 86 2987.86 ~' . · ~1 19 N 11.19 E 1 38 431.23 N 3300 3181.25 3072.25 33 31 N 11.~0 E 2.20 483.81 N 3400 3263.53 3154.53 35 42 N 10.69 E 2.21 539.57 N 244.25 E 466.95 254.71 E 520.56 265. =' ~,4 E ........... 577, 3q ...... 3600 3411· 89 3302.89 48 40 N 11 · 50 E 8.03 671 .08 N _.__ ~.~,_o.~n. 71 E 710. 88 3700 3477.12 3368.12 49 52 N 12.39 E 1.38 745.22 N 304.41 E 786.61 3800 3541.11 3432.11 50 33 N 12.50 E . 0,67 820.25 N 320.97..~ 863.39 · :3900 :::: ii !73604'501 34'.'25 ;:5'O::.!i':i!,:,J:: j~, :? ~0 ? ~:.46~ :~:~/:?~:N. ~:~ ~ ;'::.~0: ~E.::~ ~ ~ ~ ~ ~ ~: ~':.'~ 0 e~, 7~/N: ::?;~:' ~'.~:::~:. ~37 ~0 :4000~::: :: ::~ ::~ :: 3667 '" .... :::::~ ~::~ '::': ~ ~:~:?':' :::~' : ~ : ": ~' ~ : . .~ ' :: ' 62 ::::::::::::::::::::: 558, 62:?::~? :::: ::~?.~:::,::50::756 :. :::~:: ~:::~ N 12.:6C E'~ ::::::~ :.~;':. :.::.::.:' O. ~ .... .y71.. 52:: N :; :::.:~ :~.. 3.4.- O. E: : :~: ~I 0 ~ 8.:1 ~ 4100 3730. '47 362 i ~:4 i:?~::~ :10~?~:. ;::: ~ :' N.~12~:6~:!E ~: :' : 0~ 2~'::. ~ :1047~ ~2:. N 4200 3793 '~ 3684.34 50 54 N ~2.60 E 0.28 zl.~.oo N ........ . 4300 3856.52 3747.52 50 43 N 12.50 E 0.20 1198.96 N 405.21 E 1250.95 4400 3919.75 4500 ii '3984"62:5":" 4600 4700 :::4051.02 :::::, 41~ 17,_4_5_ :. 4184.07 4250.80 4317.82 4800 4900 5000 5100 4384.96 5200 4451.71 5300 4518.14 4585.12 3810,7~ . , 50. ~g N 11.50 E 0.78 1274.73.. ~e75 ;'~,~ 4e':::~,iii: ': 16 :::~: ~.' 'i':.ii:ii:N 'ii.::e; 8~'::::'E"!:::':I :" i'=: :.:.:: :~ ~ 24:~ ':' '":::: 7 ~ 349 ~':'61 5400 5500 ,.. _,(.)(..) 4008, 4.5 4075.07 48 11 N 9. 0 E 0.23 4141.80 4::3 6 N 8.50 E 0.38 4208.82 47 43...: · .. 4275.96 ' 47 ~ 55 N 7, 50 E O, 56 4342, 71/ .::.i :48::' 18 N' 15.89' E ...:: 1·25 4409.14 : :48 26 N ',:,6.1,0. E 0.2_0. 4476.12 47 26 N 5.30 E 1.15 N .... 421.32 E .. 1328.37 N"-::':~'"'": 434.82 E :" .: 1423·49 N 446.33 E 1479·2 _'1497 37 N 45~7_._Z0_~ . 1553 1571.06 N 469.17 E 1628.50 1644.67 N 480.50 E 1702.97 1.718,10 N .... 4~1.28 E ............. !777,1& 1791,52 N 501.40 E 1865.4~ N 510.08 E 1939.80 N 517.90 E ~'T~ 2013. ~8 N ~.~5.27 2085.99 N 532.01 E 2160..0~ N ..... 538.85 E 4652.80 4543.80 47 22 N 5.19 E ~7.2 . ._4611·.72 47 ~.: ...... .N .... 5,~'~LE. 0.11 _0.38 1851,22 1925,55 2000.12 2074.16 2147.53 2220.~9 KUPARUK DECEMBER 6, 1988 dOB NUMBER AK-BO-8013~, ALASKA KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER VERTIC~AL '~..EL:TION CALCULAT£D~.iiALONG~i~LOSUREi.~ ~r~.41. :~ ~ ~;:'~ i~ili~ i '~ ~ .... 'i~.~c~~ ~ .i~i~i. ~'~'~'~'~'~ ~ ~'~' ~'~ MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTIO"] 5700 5800 5..0OO 6000 6100 6200 6300 6400 6500' 4789 4857~ 4925. 4748, N:::~:i'5: ~.SE:~:~': O' 1 O: 2305':'25 .553, 22 E 2366" 18':~ 82 4816" 82 ::.;:'? 0'::'~ N ' 5.60 E O. 18 23_7_7, 94 N: 560.4! E ' :': :;'"~439,' OX 4994.17 4885.17 46 46 N 5.60 E 5062.95 4953.95 46 19 N 5.39 E 5132.00 5023.00 46 20 N 5.19 E 5201. 5269. 523° 6600 5408.33 5299.33 46 13 N 4.80 E 6700 5477.52 5368.52 46 13 N 4.60 E 0.23 2450.59 N 567.53 E 2511.80 O. 47 2522.84 N 574.49 E 2584.17 O. 15 2594.87 N 581.17 E _~'656,,~.7,. · 0.15 i: 2666' 96::N ''~' .:i'ii 587.60 E 0.22 2739.0~ N ~593.72 E 0'20 i: 2811~N '__~5=gtS' 65 E 2872.'44.' : O. 09 2883.04 N 605.62 E 2944.32 0.14 2955.00 N 611.54 E 3016.22 6800 5546.74 5437.74 46 9 N 4.30 E 0.22 3026.94 N 617.14 E 3088,06 ....... 7 2mb 0 mS e ~ 5 : 5 ~ ~7 j g : s g m 4 S '4 ~ ' m N .... S ' ~ 0 E 0'29 3313'03 N 637'33 E .... 3373'L ~'-- 7300 5895.71 5786.71 45 7 N 3.80 E 0.66 3384.15 N 641.93 E 3444..17 7400 7500 7600 7700 7800 7?00 7992 HOR I ZONTAL DISPLACEMENT :::= · : 5965.92:..~.~..:..5856, 92 ..... .. 45 ....... 41 ................ N .... 3,.60....E; ............ Q,.58 ............ 3zj.55,21.. N 6035.95 5926.95~ ' ~: 45:24 '?'::'? N~';"3"'60 E :i:?''"~:,~ ' 0" 28 7' !:~i: ~ :. :3526 '46 N 6106.23 .. ii.~i 5997.23.?::: !i:~:;:i~.~.~:~::45 :~16 (:iii~-:~.:il N ;:4.39.:E: .:: : .... 0.59. 3597.41.. N 6247.60 6138.60 44 56 N 5. 0 E O. 6318.39 6209.39 44 56 N 5. 0 E O. 638C~,51 ........ .627~_,51.. 44 56 N 5. 0 E O. .: -. . ....... . _ : .... :. = : - , . . 3932'68:':"FEET AT NORTH ................... 646.53~ ';:!' .... 651.01 ~655,97 .i 661'77 02 3738.38 N 667.93 E 02 3808.75 N 674.09 E 02 . 3873.49.N ....... ~. 679~75 E ~ .... 3514.96 : ..... .:~ :' ':: · ." :": ":.~:.:.::: 7' ::.:' E ~ 3585;~'~17 3797.56 3867.94 . .3932~68 9'DEG, 57 MIN. EAST AT MD = 7992 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ~PERRY-SUI~ WELL_ SURV~MPANY ......... p~GF' - 4 9°:'~ ,..lOB NUMBER AK-BO-8013~., KLIPARUK DECEMBER 6, 1. ~ ALASKA KELLY BUSHING ELEV. = 10~.00 FT. ......... OPERAT~,HARGER TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 2000 1994.49 1885.49 23 · 53 N 101 · 62 E 5.51 5.38 3000 2923.91 2814.91 332.29 N 227.38 E 75.09 70.58 4000 3557.62 3558.62 971.52 N 354.30 E 332· 38 256.29 :.:4~17,, 82?.,::::::: 420~. 82:: :~: .: :,,:~:,::,:! ~:::,: ~: 49.1 · :~i~::i:i g: : ' ::' :::' "'t:ii::i~!ii itiiti 6000 49, 4~ 1:7:::~::: ~::~::::4885.~I 7992 $383.51 $274.51 387:3.49 N $79.75 E 1608.49 294.18 THE CALCULATION PROCEDURES ARE BASED ON THE..,.USE::OF::.:THREE.DIMENSIONAL RADIUS OF CURVATURE METHOD.. ARCO KUPARUK DECEMBER 6, 1988 ALASKA PAGE -5 dOB NUMBER AK-BO-80136 KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 109 209 309 409 509 609 709 809 90.9 209.00 100.00 0.27 S 0.80 E 309.00 200.00 0.50 S 1.36 E 409.00 300.00 0.86 S 2.11 E O0 :: :~400.00 ' 1.21 S : 3 O0 :: :.;500.00. 1"59::::$ '::. '::::' i:: 42 21 65' EE O0 ':: 600,.00 ::..: : 2.04 ,'3' 6.33 E O. O0 609, 709. · lOO9 ,1 1109 13o9 i 1409 1 1510 1 1610 1 1711 1 1812 ' i::.1 .. 0.00 0.00 0.00 0.00 o.o! .... o,oo ....... 0.01 0.01 0.03: : 0.01 O. 04 0.02 809.00 700.00 2.58 S 8.42 E 0.06 0.02 909.00 800.00 3.22 S 10.81 E 0.10 0.03 409. O0 1300. O0 O. 95 S 34.03 E O. 84 509. O0 1400. O0 2.28 N 42.70 E 1 . 26 609.00 1500~. O0 ................... 5,,12~,, N .................... 51.,. 71_ E ........... 1.71. .. 70c) 00'" ::;':i 1600.00: . :: :::~::::: , 7, 96 61"27 E :. .: . 2.21 · '. : : :' . ·' ' i :i:" i ' : : .' ii' *1 .. O. 38 0.43 O. 45 O. 50 O. 87 ARCO ALASKA' .I KUPARUK DECEMBER ALASKA KELLY BUSHING ELEV. = 109.00 FT. TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL [!.E_~.T_H DEP__TH DEPTH NORTH/8OUTH EAST/WEST D I FFER_'.ENCE C:ORR..E..C:.T_L.ON 1913 1909'00 1800.00 I8.51 N 88.17 E 4.31 1.24 2014 2009. O0 1900. O0 24.38 N__ 103.97 E 5.73 !, 4 ! 2116 2109.00 2000.00 31.01 N 121.37 E 7.45 2219 2209.00 2100.00 42.75 N 141.31E 10.12 2322 __2309.00 2200.00 62.29 N 160.20 E 13.78 2427 2409.00 2300. 2534 2509.00 2400. 2644 2609.00 2500, 2757 2709.00 2600. 2870 2809.00 2700. 2983 2909.00 2800. 3097 3009.00 ' 2900. 3214 3109.00 3000. 3333 3209.00 3100. 3457 3309.00 3200. 3595 3409.00 3300. 3749 3509.00 3400.00 007 ' 89.05 N : : 174.84 E · : O0 126,04 N 183'89 E O0 .__ !7.1~.46 N ' __ .1~._~2 E ...... O0 221.25 N 206.34 E O0 272.82 N 218.16 E O0 324.26 N 22~.16 E , 00: 379.69'N :::~::::: :234'89 E' 00 .::: : ::'~: .:::: ' ': 438' 47 N 245.68 E O0 50!.84.,.N ...... 258.31 ....E O0 574.05 N 271.62 E O0 667.94 N 288.09 E 3907 3609.00 3500.00 4065 3709.00 3600.00 18, 36 25.43 .~ ,_Z 3 48.13 61.2Y , ,74.02 88.70 105.21 148.39 186.69 782.25 N 901.17 N 1021.40 N 312.5& E 338.76 E 365.47 E ~ 24q~_~_4 _ ,, 298.11 356.76 1.72 2.67 4.59 7,07 12.40 13.14 12.75 14.68 16.51 .1_~._~8 24.11 38.30 , ~3.8~ 57.57 58.64 ARCO ALASKA. 2Z-20 KUPARUK ALASKA INC. ANCHORAGE ALASKA . DECEMBER 6, 1988 PAGE 1988 JOB NUMBER AK-BO-80136 KELLY BUSHING ELEV. = OPERATOR-HARGER 109.00 FT. INTERpoLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERT I CAL DEPTH. DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4224 3809.00 4382 3909.00 4536 4009.00 4687 4109.00 4837 4209.00 4986 4309.00 5135 4409.00 3700.00 1142.11 N 392.57 E 415.84 3800.00 1261.80 N 418.68 E 473.98 3900.00 1376.64 N 439.05 E 527.64 4000.00 1488.02 N 456.27 E 578.32 4100.00 1598.58 N 473.53 E 628.39 4200.00 1708.49 N 489.89 E 677.88 4300.00 1817.93 N 504.88 E 726.88 59.08 o8.14 53.66 50.68 50.07 49.50 49. O0 5286 5435 5582 5729 45.QP:.QO ..... ..4_400...__Q0 4609. oo 4500. oo 4709. oo 4600. oo 4809. oo 4700. oo !227,_.~5.. _N 51 · -,O'~.u 58 N 527.6:_-': 2147.~,~='=' N 537.65 2253.82 N 548.08 5875 4909.00 4800'00 6021 5009.00 4900.00 6166 631i 5209,00 5100.00 6456 5309.00 5200.00 6600 5409.00 5300.00 2359.99 N 558.65 2466.29 N 569.07 _~Zg~_TJ ..... 2675.32 N 588.34 2779.83 N 597.07 2883.73 N 605.68 6745 5509.00 5400.00 2987.74 N 614.16 6889 5609.00 5500.00 3091.55 N 621.94 E 777,~2 .................. 50,_~ .......... E 826.31 49.09 E 873.79 47.48 E 92Q~_1_!= ~ 46.32 E 966.34 46.23 E 1012.65 46.32 E 1102.59 44.90 E 1147.50 44.91 E 1Jgl~ ........... 44.45 E 1236.50 44.54 E 1280.85 44.34 ARCO ALASKA, INC. ~Z-20 KUPARUK ALASKA ANCHORAOE ALASKA COMPUTAT I ON_IL~IE DECEMBER 6, 1988 DATE OF SURVEY DECEMBER. ~, '~ 1988 · dOB NUMBER AK-BO-80136 KELLY BUSHING ELEV. = 109.00 FT. INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL 7033 5709.00 5600.00 7176 5809.00 5700.00 731~ 5909.00 5800.00 3194.14 N 629'37 E 1324.31 3296.05 N 636.27 E 1367'25 3397.47 N 642 ~'~ .~ E 1409.~.3'~'- 43.46 42.95 42.58 7461 6009.00 5900.00 7603 6109.00 6000.00 3499.18 N 64~ 29 E 14.~.61 3600.20 N 656.18 E 14~4.~3 42.78 42 '~'v 7745 6209. O0 6100. O0 3700, O1 N &64.57 E 1536.47 7886 6309.00 6200.00 3799.42 N 673.27 E 1577.74 .......... ~:~9~ ......... ~3__8~.51 6274.51 3873.49 N 679.75 E 16C!~.__zJ9__ THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 41.54 41.27 3.0.. Z5 )- ARCO ALASKA, KUPARUK ~ALASKA INC. SP~BR¥-SUN WELL SURVEYIN~'.~_I~NY PAGE ANCHORAGE ALASKA . ~ ,!:.~.~DATE:oF sURVEy . COMP__LLT~-ION.._~A~E DECEMBER 6, 1 ~.o dOB NUMBER AK-BO-80136 KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER ~ ~:~'.i~ ?::~ ' INT£RPOLATED VALUES FOR' SPECIAL sURVEY POINTS MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES \ / DEPTH NORTH/SOUTH EAST/WEST MARKER .- 7264 5870.32 5761.32 7364 5940.77 5831.77 7512 6044.37 5935.37 7693 6171.86 6062.86 7700 6176.82 6067.82 3358'69 N 640.24 E 3429.50 N 644.91E 3534.99 N 651.55 E 3663.09 N 661.34 E '3668.01N 661.77 E TOP KUPARUK C BASE KUP_A_R...UK. C TOP KUPARLIK A BASE KUPARL~K A SURVEY DEPTH 7728 6196.64 6087.64 3687.72 N 663.50 E 7992 6383.51 6274.51 3873.49 N 679.75 E PBTD TD ARCOALAsKA , INC. : 2Z-20 ~ · STRATIGR~Pit!.C._SU~MARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA __ ':lTzOO bltlTES ............... 'MARKER- MEASURED DEPTH BKB '-'-~--TVD TH I CKNESS . BKB SUB-SEA VERT I CAL WITH REF · TO. WELLHEAD (ORIGIN- 647FEL 1902FSL) . '.~E6d_l' Tiibl ~ROgE __ TOP KUPARUK C BASE KLIPARLIK C 7264 5870.32 5761.32 7364 5940.77 5831.77 .24.3J~ · 69N 6,40 · 24F -\ c,~.-,,:~ 5(')N , 4 '---/ TOP KUPARUK A 7512 6044.37 .59'35.37 BASE KLIPARUK A 76,93 6171.86 6062. S6 PBTD 7728 6196.64 6087.64 3534.99N 3663, 09N 3687, _7.~N 651.55E 661.34E 663.50E 7992 6383.51 6274.51 3873.49N 679, 75E -i-)' FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONRL RADIUS OF CURVATURE, DRT~_.__C_'~_LCL_~L~T_!.._O.N_.__~ND._!.N.T_E:_R..P.O_L_~TION BY RADIUS OF CURVAT_URE BATE OF' SURVEY [!E~jgM_BE~ 3,, 1".;'8;~: COMPUTATION DATE DECEMBER 6, 1988 JOB NUMBER AK-BO-80136 KEL_LY_BUS~J ! N_!-]_ELEV ,_=._ 1Q~, O(L FT.. SPERRT -,..SUN SCALE :- t INCH TO tO00. O0 / 1000.0 KUPARUK 22-20 RK-80-80136 TRUE NORTH ARCO ALASKA. INC. OECENOER 3. 1988 7992 O0 -lobo. oo I -looo. oo HOB I ZONTRL PROJECT I ON SPERRY -SUN 0.00 5CRLE :- KUPRRUK 2Z-20 RK-80-80138 INCH TO I500.00 / 1500.0 ARCO ALASKA. INC. OECEMBER 3. 1988 1500.00 3000.00 4500.00 6000. O0 7500.00 i 636~. 5t 7992 ~sbo. oo soho. oo 45bo. oo VERT [ CRL PRCIJECT 113N ARCO Alaska, Inc. Date: December 8, 1988 Transmittal #: 7367 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. 1Y-26 2Z-20 2Z-21 OH LIS Tape and Listing OH Edit Tape and Listing OH Edit Tape and Listing Please acknowledge receipt and return 11-29-88 #72957 12-05-88 #73028 12-02-88 #73007 Receipt Acknowledged: DISTRIBUTION; State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7355 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 2Z-21 2"&5" Raw FDC 11- 2Z-21 2"&5" Porosity FDC 11- 2Z-21 Microiog-GR 1 1 - 2 Z- 21 Repeat Formation Tester 1 I - 2 Z- 21 5" Dual Induction 1 1 - 2 Z- 21 2" Dual Induction 11 - 2Z-21 Formation Microscanner (4-Pad) I 1- 2 Z- 21 Cyberlook 1 1 - 2Z-20 2" Dual Induction 11- 2Z-20 5" Dual Induction 1 1- 2 Z- 20 Cyberlook 1 1-- 2Z-20 2"& 5" Raw FDC 1 1 - 2 Z-. 20 2" & 5" Porosity FDC 1 1 - 2Z-20 Microlog-GR 1 1- Receipt Acknowledged: 10-88 4453-7716 I0-88 4453-771 6 10-88 7050-7746 10-88 7264-751 7 10-88 1 000-7742 10-88 1 000-7742 10-88 7050-7600 10-88 7050-7650 20-88 3690-7972 20-88 3690-7972 20-88 7000-7972 20-88 3900-7946 20-88 3900-7946 20-88 7000-7964 DISTRIBUTION: State of Alaska(+sepia) D&M NSK Drilling L. Johnston(vendor package) Franzen STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMM~,.~ON REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Plugging Perforate ... Repair well Pull tubing .. 1. Operations performed: Operation Shutdown __ Pull tubing X Alter casing 2. Name of Operator 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at surface 1902' FSL, 647' FEL, Sec. 11, T11N, At top of productive interval 19' FSL, 7' FEL, Sec. 11, T11 N, At effective depth 310'FSL, 17'FEL, Sec. 1, T11N, At total depth 495' FSL, 33' FEL, Sec. 1, T11N, R9E, UM R9E, UM R9E, UM R9E, UM 9 9 2' feet Plugs (measured) 3 8 4' feet Other feet 6. Datum elevation (DF or KB) 12. Present well condition summary Total Depth: measured 7 true vertical 6 Effective depth: measured 7 72 8' feet Junk (measured) true vertical 6197' feet Size Cemented 1 6" 205 SX CS II 9-5/8" 800 sxAS III & 400 sx Class G top job 7" 250 sx Class G & 200 sx AS I 7598'-7614' 6104'-6116' Casing Length Structural 8 0' Conductor Surface 3 6 5 6' Intermediate Production 7 7 7 6' Liner Perforation depth: measured 7226'-7350', true vertical 5872'-5931 ', 109' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-20 9. Permit number/approval number 88-1 24/9-626 10. APl number 50-029-21876 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 1 1 5'm d 11 5'tvd Tubing (size, grade, and measured depth) 4" & 3-1/2" J-55 tbg W/ tail @ 7448' Packers and SSSV (type and measured depth) 3471 'md 3471'tvd AVA 'RHS-XL' pkr @ 7180, TIW 'SS-BB' pkr @ 7420' & AVA 'Sideguard' SSSV @ 1817' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Re.oresentative Daily Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Service Tubing Pressure 14. 16. Status of well classification as: Water Injector__ Oil ~. X... Gas Suspended Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Dri!ling Engineer Signed ~ '~ ~ Form 10-404 Rev 05/17/89 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. o District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3421 ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 AKL: 2674 Title WORKOVER IStat~K 2Z-20 ]Well no. Operator ARCO Spudded or W.O. begun ~Date ACCEPT I 08/05/89 Date and depth as of 8:00 a,m. 08/06/89 ( 1 TD: 7809 PB: 7728 SUPV:CD Complete record for each day reposed NORDIC RIG 1 ARCO W.I. IHour J 56.0000 I Prior status if a W.O. 18:30 RUN IN LOCK DOWN SCREWS 7"@ 7809' MW: 9.0 NABR/CL ACCEPT RIG FROM 2Z-21 AT 1830 HR 8/5/89. R/U AND KILL WELL WITH 9.0 PPG BRINE MONITOR WELL. N/D TREE AND N/U AND TEST BOP. BACK OUT LOCK DOWN SCREWS AND PULL TUBING HANGER TO RIG FLOOR. CHANGE OUT SAME. DAILY:S25,408 CUM:$1,608,465 ETD:$1,608,465 EFC:$1,441,000 The above is correct For form proparafi~12~an~ distributi~..~ see Procedures,M'li~ual, Section 10, Drilling, Pages ~nd 87. Date / $ I Title AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Pre0are 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. District IAccounting cost center code Stat~%.K ARCO ALASKA INC. County or Parish I NORTH SLOPE I tease or Unit KUPARUK RIVER UNIT I ADL: 25588 AKL: 2674 2Z-20 I Title I WORKOVER IWell no. Field Auth. or W,O. no. AK3421 .Operator ARCO Spudded or W.O, begun ACCEPTED Date and depth as of 8:00 a.m. 08/07/89 ( TD: 7809 PB: 7728 SUPV:LK IA.R.Co. W.I. 56,0000 Date 08/05/89 Complete record for each day reported NORDIC RIG 1 Iotal number of wells (active or inactive) on this oat center prior to plugging and I bandonment of this well I our ~Prlor status if a W.O. I 18:30 RIG RELEASED 7"@ 7809' MW: 6.8 DIESELL FINISH SECURING NEW TUBING HANGER AND RUN IN LOCK DOWN SCREWS. SET BPV. N/D BOP AND N/U TREE. SET TEST PLUG AND TEST TREE TO 5,000 PSI. PULL TEST PLUG. DSISPLACE WELL TO DIESEL. SET DUMMY VALVE IN GLM AT 7,116'. SECURE WELL AND RELEASE RIG AT 1500 HR 8/6/89. WORKOVER C0ST$42,760. DAILY:S19,352 CUM:$1,627,817 ETD:S1,627,817 EFC:$1,441,000 Old TD I New TD Released rig I Date IPB Depth Kind of rig Classifications (oil,. gas, etc.) Type completion (single, dual, etc,) Producing method I Off cial reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Eflective date corrected ove.~correct Date AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well, IPage no. DIvlNon of AtlsnflcRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ' 1. Type of Request: Abandon ~ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time extension ~ Stimulate __ Change approved program __ Pull tubing ._¢_ Variance __ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1907..' FSL, 647' FEL, Sec.ll, T11N, R9E, UM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-20 9. Permitnumber 88-124/8-984 10. APInumber 50-- 029-21876 19' FNL, At effective depth 310' FSL, At total depth 495' FSL. 33' FWL 12. Present well condition summary Total depth: measured true vertical 7' FEL, Sec.11, T11N, R9E, UM 17' FWL, Sec. 1, TllN, RgE, UM 7992'MD 6384'TVD UM feet Plugs (measured) None feet 11. Field/Pool Kuparuk River 0il Pool Effective depth: measured 7728 'MD true vertical 6197 ' TVD feet Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 3656' 7776' 16" 205 sx AS II 115'MD 115'TVD 9-5/8" 800 sx AS III & 3471'MD 3471'TVD 400 sx C]ass G - Top job w/30 sx AS I 7" 250 sx C]ass G 6254'MD 6254'TVD 200 sx AS ! measured true vertical 7266'-7350'MD, 7598'-7614'MD 5872'-5931'TVD' 6104'-6116'TVD RECEIVED feet Tubing (size, grade, and measured depth) 4"/3½", J-55, tbg w/tail @ 7448 Alaska Oil & Gas Cons, 60mmiss]¢ Packers and SSSV (type and measured depth) Ancl~0rage AVA 'RHS-XL' pkr ~ 7180'~ TIW 'SS-BB' pkr (~ 7420' & AVA 'Sideguard' SSSV @ 1817' 13. Attachments Description summary of proposal "v/ Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation Gas __ Suspended __ '$A1/11 Commissioner Date j Approval No. ~._ ~'c~ ~' Approved Copy Returned 16. If proposal was verbally approved Oil V' Name of approver Date approvedI Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed P,.-.~" ~ Title ~,.~,~ n,.~,81~L~Engr ¢/ FOR COMMISSION USE - Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Te~t __ Subsequent form required 10- Date Approved by order of the Commission SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 KUPARUK RIVER UNIT WELL 2Z-20 WORKOVER SUMMARY The purpose of this workover is to change out the tubing hanger which has a junk stuck in it. The well will be killed with brine prior to removing the tree and installing the BOP stack. KRU 2Z-20 was completed as a single selective in February, 1989. During rig-up operations for a frac job in the first part of July the tree saver became stuck in the tubing hanger due to an oversized lower seal mandrel. During the attempt to free the tree saver the tool parted leaving approximately 1' of the tool in the hanger. To repair the existing problem a workover is planned to change out the tubing hanger. No other equipment change out is anticipated at this time. The tool has a 2-1/4" minimum inside diameter and will not pose any problem to killing the well by bullheading down the tubing. KUPARUK RIVER UNIT WELL 2Z-20 WORKOVER 4"x 3-1/2" SELECTIVE SINGLE COMPLETION AFE #AK3421 1. Set BPV. MIRU Nordic #1. Fill pit with unviscosified brine. . , . . Pull BPV. Kill well by bullheading brine down tubing. Do not exceed frac gradient of the "A" sand. Set BPV and ND tree. NU BOP. Pull BPV and set test plug. Test rams, annular, and choke manifold to 3000 psi. (Notify AOGCC prior to NU BOPE.) Screw into tubing hanger with 4" tubing with x/o to 4-1/2" NU lift thread. Back out lock down screws. Pressure up on tubing to 200 psi if possible. Close annular and strip out tubing until the seals are out of the PBR. Circ out diesel packer fluid on choke the long way. Ensure well is dead and stable. 6. Pull tubing hanger to rig floor. Disconnect SSSV control line and change out tubing hanger. 7. Re-attach control line to the new tubing hanger and test to 5,000 psi for 10 minutes before landing tubing. 8. Drain stack and land tubing. Run in lock down screws. Test back side to 1,000 psi. 9. Set BPV. N/D stack. N/U and test tree to 5,000 psi. 10. R/U slickline and pull dummy valve from 1-1/2" GLM above packer. 11. 12. 13. Displace annulus and tubing with diesel. Record SITP and SICP. Re-set dummy valve in GLM and test annulus to 1,000 psi. Set BPV and release rig. COMPLETION SCHEMATIC 2Z-20 AS-RUN COMPLETION SELECTIVE SINGLE COMPLETION 7180' "C" SAND PRE- FRAC PERFS: 7266'-7350" PERM PKR AT 7421' WLM "A" SAND PRE- FRAC PERFS: 7598'-7614' 1 '"' I 12 16 I_ ,17 21 1. 4", 11.0#, J-55, DSS-HTC, IPC TUBING 2. 4", AVA "Sideguard' SSSV, 5.900"OD, 3.250"1D (DSS-HTC) . 4", 11.0#, J-55, DSS-HTC, IPC TUBING 1 - 4" X 1" TELEDYNE MERLA GLM WITH DUMMY VALVE AT SPECIFIED DEPTH, USE BK-2 LATCH (DSS-HTC), 5.850"OD, 3.125"1D 4. CROSSOVER, 4" DSS-HTC BOX X 3-1/2" EUE 8RD PIN @ 4007' MD . 6o 3°1/2", 9.3#, J-55, EUE 8RD AB Mod IPC TUBING 6 - 3-1/2" X 1" CAMCO "KBUG" GLMS WITH DUMMY VALVES AT SPECIFIED DEPTHS, USE BK-2 LATCHES, (BTC AB MOD), 5.359"OD, 2.867" ID 3-1/2" X 1-1/2" CAMCO "MMG-2' GLM WITH DUMMY VALVE, WITH RK LATCH (EUE 8RD AB-MOD) 5.793"OD, 2.920"1D 7. 1 JT 3-1/2", 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 8. 3-1/2" AVA PBR BBL ID = 3.90" PBR SHEARED. 9. 3-1/2" X 7" AVA RHS-XL PACKER 5.955"OD, 3.00"ID 60,000# REL 10. 1 JT 3-1/2% 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 1 1. 3-1/2" X 1" CAMCO 'KBUG' GLM WITH DUMMY VALVE (EUE 8RD) 12. 1 JT 3-1/2", 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 13. CARBIDE BLAST RINGS (WITH 5' OVERLAP ACROSS 'C' SAND PERFS) 14. 3-1/2" X 10' PUP JOINT 15. 3-1/2" OTIS PORTED LANDING NIPPLE 4.50"OD, 2.813" XN PROFILE WITH ISOLATION SLEEVE 2.35"1D (EUE 8RD) 16. 3-1/2" X 10' PUP JOINT 17. TIW LOCATOR SEAL ASSEMBLY 18. 3-1/2" X 7" TIW 'SS-BB' WL SET PACKER WITH 5' SEAL EXTENSION XO TO 3-1/2" EUE 8RD 19. 3-1/2" X 8' PUP JOINT - 20. 3-1/2" OTIS "XN" NIPPLE 2.750" X 2.635" 21. 3-1/2" X 8' PUP JOINT 22. 3-1/2" AVA SHEAR OUT SUB (SHEARED) TUBING TAIL @ 7448' TUBING MEAS. FC @ 7728' JTZ 7/17/89 ,. p ANNULAR PREVENTER § PIPE RAHS' 4 BLIND RAHS HEAD 2 1. 16" CONDUCTOR SWAGED TO 10-`3/4" 2. 11"-`3000 PS1 STARTING HEAD `3. 11 "-`3000 PSI X 7-1 / 16"-$000 PSI TUBING HEAD 4. 7-1 / 16" - 5000 PSi PlPE RAMS 5. 7-1/16" - $000 PSi BLIND RAMS 6. 7-1 / 16" - 5000 PSi ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ,3000 PSI WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. ,3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REHAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PiPE RAMS. 7. INCREASE PRESSURE TO `3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH ~5000 PSi UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PiPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR I0 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO `3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSi WITH KOOMEY PUMP. 1`3. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. dO dULY 28, 1986 ARCO Alaska, Inc, Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 11, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 .Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2Z-20 Fracture July, 1989 2Z-1 9 Fracture July, 1989 2Z-21 Fracture July, 1989 2Z-29 Fracture July, 1989 1A-09 Conversion July, 1989 1 A- 1 5 Conversion July, 1989 1 A- 1 1 Tbg. Leak July, 1989 2G-1 I Refracture July, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. ~'~allwood Senior Operations Engineer JUL ! 2 cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1,4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 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, In(~. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1903' FSL, 647' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 0' FNL, 30' FEL, Sec. 11, T11N, R9E, UM (approx.) At effective depth 301' FSL, 72' FWL, Sec. 1, T11N, R9E, UM (approx.) At total depth 481' FSL, 104' FWL, Sec. 1, T11N, R9E, UM (approx.) 12. Present well condition summary Total Depth: measured 7992' feet Plugs (measured) true vertical 6378' feet None 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit feet . 8. Well number 2Z-20 .?/(. ~J ,., ¢~ . 9. Permit number 88-1 24 10. APl number ~0-029-21876 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7728' feet Junk (measured) true vertical 6188' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" 3656' 9 5/8" 7776 7" Measured depth True vertical depth 205 Sx AS II 115' MD 115' TVD 800 Sx AS III & 3691 'MD 3473'TVD 400 Sx Class G - Top job w/30 sx ASI 250 Sx Class G 7809'1~ ~ measured 7266'-7350' MD, 7598'-7614' MD true vertical 5872'-5931' TVD, 6104'-6116' TVD Tubing (size, grade, and measured depth 4"/3-1/2", J-55, tbg w/tail @ 7448' Packers and SSSV (type and measured depth) JUL ! 2 Alas = Oil & Cons. 13. Fracture A Sand !'14. Estimated date for commencing operation 15. ' July, 1 '16. If proposal was verbally approved f Name of approver L.. ~/~l, ~ ~ Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed r//~ "7 ~) "~:~/~1'"t'~"~'~?~c'~¢'"-"~ TitleFoR COMMISSIoNSr' OperatiOnSuSE ONLyEngineer AVA 'RHS-XL' pkr @ 7180', TIW 'SS-BB' pkr @ 74,20' AVA 'Sideguard' SSSV .@ 1817' Attachments Description summary of proposal X Detailed operation program _ BOP sketch Status of well classification as: Oil X Gas ~ Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED' BY LONNIE Cl~ SMITH Form 10-403 Rev 5/03/89 Commissioner IApproval No. Approved Copy Returned SUBMIT IN TRIPLICATE KUPARUK RIVER WELL 2Z-20 FRACTURE STIMULATE THE A SAND · . , No workover fluids will be used during the fracture treatment. No BOP's will be used during the fracture treatment. The estimated maximum surface treating pressure is 6,500 psi. The estimated A Sand bottom hole pressure is 2,600 psi. ARCO Alaska Inc, is a subsidiary of Atlantic Richfield Company AR3B-6001-A A Kuparuk Well 2Z-20 Sand Fracture Stimulation AFE #AK3421 May 12, 1989 Pre-Frac Slickline Work 1. MIRU Slickline Unit. 2. Tag bottom. 3. (If applicable) Replace GLV's with dummy valves. . Pull Otis commingling sleeve with blanking plug from Otis ported landing nipple at 7386' RKB and replace with isolation sleeve. . RIH with standing valve and set in Otis ported landing nipple at 7386' RKB. Pressure test tubing to ensure DV's are set. Pull standing valve. 6. RDMO Slickline unit. Fracture Stimulation 7. MIRU fracturing equipment and related flowback equipment. 8. Re. rd the total weight of the pro.ant. 9. Perform all standard quality control procedures (On-site Operations Engineering). 10. Install largest diameter 'tree saver' available for 4", 11.0# tubing. Pressure test lines. Pressure up the annulus to prevent tubing buckling and maintain throughout job. 11. DATA FRAC - Pump 80 BBLS crosslinked gelled water at 20 BPM. Shut down and monitor pressure decline for 10 minutes with ARCO's quartz surface pressure gauge. Pump 50 BBLS crosslinked gelled water at 20 BPM. Shut down and monitor pressure decline for 10 minutes. Pump 200 BBLS crosslinked gelled water at 20 BPM followed by 80 BBL$ of non-crosslinked gelled water as flush. Shut down and monitor pressure decline for 30 to 40 minutes. Note: If treating pressure is excessive (greater than approximately 5,500 psi), ball out the perfs. (Halliburton should come prepared for a ball out). Perf size is approximately 0.4~ and the total number is 128. 12. Pump the fracture stimulation as per the attached pump schedule. Ramp between stages. Obtain representative fluid samples of the pad, slurry, and flush stages during the treatment. Place frac fluid samples in 140° water bath. The estimated treating conditions are as follows: WHTPE: Fracture Gradient: Tubing Friction: Tubing Friction: Recommended maximum treating pressure 3,600 psi O.72 psi/ft 140 psi / 1000' (4") 220 psi / 1000' (3.5") 6,500 psi 13. Record ISIP and 5 minute, 10 minute and 15 minute shut-in pressures. 14. 15. 18. 19. SI well, bleed down annulus, and rig down frac equipment. Record the weight of proppant not pumped. MIRU E-Line unit as soon as possible after frac. RIH w/temperature tool. Log as required to determine fracture height growth. RDMO E-Line unit. Flowback Schedule 20. Begin flowback at the designed break time after verifying that gelled water samples in the water bath have broken. Contact Operations Engineering in Anchorage and do not begin flowback if gelled water samples have not broken. 21. Flowback the well at 5 to 10 BPH. At bottoms up verify that the gel has broken. Record tanks straps, choke settings and WHP°s during flowback period. Inspect samples for proppant. If excessive proppant is produced, reduce rate and contact Operations Engineering. 22. 23. After 24 hours of flowback at ,5 to 10 BPH, decrease the wellhead pressure in 50 psi increaments every two hours until the well is producing at header pressure. Continue to monitor for unbroken gel or excessive proppant throughout flowback. Once well has completed flowback, obtain a 24 hour well test. KUPARUK WELL 2Z-20 A SAND FRACTURE PUMPING SCHEDULE 5/12/89 STAGE FLUID CLEAN VOLUME PUMP RATE DESCRIPTION BBLS BPM PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS PPG DESCRIPTION LBS STG/CUM @ BBLS 1 GW DATA FRAC 80.0 ..................................................... SHUT 2 GW DATA FRAC 50.0 ..................................................... SHUT 3 GW DATA FRAC 200.0 4 GW FLUSH 80.0 ..................................................... SHUT 5 GWPAD 180.0 6 GW w/2 PPG 18.4 7 GW w/4 PPG 17.0 8 GW w/6 PPG 19.8 9 GW w/8 PPG 22.2 I 0 GW w/10 PPG 24.3 11 GW w/12 PPG 13.1 1 2 SLICK DIESEL FLUSH 78.0 +SV 2O 0 0 DOWN FOR ISlP AND PRESSURE DECLINE 20 0 0 DOWN FOR lSlP AND PRESSURE DECLINE 20 0 0 20 0 0 DOWN FOR ISIP AND PRESSURE DECLINE 20 0 0 20 2 16/20 M CARBO-LITE 1544 20 4 16/20 M CARBO-LITE 2856 20 6 16/20 M CARBO-LITE 4982 20 8 16/20 M CARBO-LITE 7452 20 1 0 16/20 M CARBO-LITE 10203 20 1 2 16/20 M CARBO-LITE 6593 20 0 -- 0 80/ 80 82 50/ 5O 162 200/ 200 212 -~ 80/ 80 412 1 80/ 260 492 20/ 280 672 20/ 30O 692 25/ 325 71 2 30/ 355 737 3 5/ 390 767 20/ 41 0 802 78/ 488 ....... ~ 822 TOTAL GELLED WATER -- 677.4 BBLS 16/20 M CARBO-LITE = 33632 LBS '~, ~) '-~ TOTAL DIESEL = 27.3 BBLS ~,- Od ~ ~'~ TOTAL FRAC FLUID= 704.7 BBLS ~ ~, ~ -~ TOTAL DIESEL FOR FLUSH = 78.0 BBLS + SV ~,~ ~ ~, ~ 1. All fluids should be maintained between 85 F and 90 F on the surface. ~"'~ 2. Stages 1 and 3 are crosslinked 40~1,000 gal gelled water with 2% KCL by weight and 5% diesel by volume and enough breaker for an 8 ~reak. ' ~t 3. Stage 4 is a 40#/1,000 gal gelled water flush with 2"/0 KCL by weight (no crosslinker). ~ 4. Stages 5 and 7 are crosslinked 40~/1,000 gal gelled water with 2% KCL by weight and 5% diesel by volume and enough breaker for an 8 hour break. 5. Stages 8 through 11 are the same as above but without diesel. ~ 6. Reduce pump rate to 15 BPM if treating pressure rises to 6,000 psi. Shut down at 6,500 psi. 7. Stage 12 (flush) should include a volume adjustment for surface equipment between the wellhead and densirneter. 8. This job is intentionally underflushed by 4.0 bbls. The blender tub should be bypassed at flush. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing Alter casing __ Repair well __ Perforate ,.' Other ~-- Comp1 el;:¢ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development ~" Exploratory __ Stratigraphic __ Service __ 4. Location of well at surface 1902' FSL, 647' FEL, Sec.11, T11N, R9E, UM At top of prod uctive interval 19' FNL, 7' FEL, Sec.11, TllN, R9E, UM At e~ff~Qtive..c~.epth 5IU' I'bL, 17' FWL, Sec. 1, T11N, R9E, UM At total depth 495' FSL, 33' FWL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7992'MD 6384'TVD 7728'MD 6197'TVD feet feet feet feet Plugs (measured) No ne Junk (measured) None 6. Datum elevation (DF or KB) feet RKB !09' 7. Unit or Property name 8. Well number 2Z-20 9. Permit number/approval number 88-124/8-984 10. APl number 50-- 029-21876 11. Field/Pool Kuoaruk ~iver 0il Pnnl Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented MeasUred depth True vertical depth 80 ' 16" 3656' 9-5/8" 7776' 7" 205 SX AS il 115'MD 800 sx AS III & 3691'MD 400 sx Class G - Top job w/30 sx AS I 250 sx Class G & 7809'MD 200 sx AS I measured 7266'-7350'MD, 7598'-7614'MD ll5'TVD 3471'TVD 6254'TVD true vertical 5872'-5931 'TVD, 6104'-6116'TVD Tubing (size. grade, and measured depth) 4"/3-1/2", J-55, tbg w/tail ~ 7448' E~c, ~.a~ d.$$SV.(typ^e ac d.m ea ~'lwured depth ~wke'r~-,',~-p~<r't~/-,uu', 'SS-SS' pkr e 7420' AVA 'Sideguard' SSSV e 1817' <.i:CEIVED,, 13. Stimulation or cement squeeze summary Intervals treated (measu red) 7230 ' -7232 ', 7400 ' -7/-,02 ' Treatment description including volumes used and final pressure ~ hbl c~ent~31.5 bb! 14. N/A Oil & Gas Cons. Com~ Anchorage ' Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Gy r o 116. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ * I Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Seiwe~: Form 10-404 Rev 06/15/88 Title Area Drilling Engr. Date * Completion Well History (Dani) SW04/017 SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ._ District ICounty. parish or borough A[;{,CO ALASKA liNC. I NORTH ST,OPE Field ILease or Unit KUPARUK RIVER UNITI ADL: 25646 Auth. or W.O. no. Title ~K342] COMPLETW. State A~ 27.-20 lWell no. Operator ARCO Spudded or W.O. begun [Date I ACCEPT Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC RIG 1 02/06/89 ( 11 API: 50-0~¢-21876 POOH WITH GAUGE RING 02/05/89 ARCO W.I. 56.0000 7"@ 7809' MW:10.7 BRINE TD: 7809 PB: 7728 SUPV:DLJB 02/07/89 TD: 7809 PB: 7728 SUPV:DLJB 02/08/89 ( 13 TD: 7809 PB: 7728 SUPV:DLJB 02/09/89 ( 14 TD: 7809 PB: 7728 SUPV:CD 02/10/89 ( 15 TD: 7809 PB: 7728 SUPV:CD 02/11/89 TD: 7809 PB: 7728 SUPV:CD MOVE RIG FROM 2Z-19 TO 2Z-20. ACCEPT RIG AT 2130 HRS 2-5-89. ND TREE, NU BOPE AND TEST. RU E-LINE. RIH WITH SQUEEZE PERF GUN AND PERF 7230-7232 & 7400-7402 4SPF. RIH W/ 6.125" GR/JB TO 7725' DAILY:S59,225 CUM:$1,066,682 ETD:S1,066,682 EFC:$1,441,000 SQUEEZE 7230-7232 7"@ 7809' MW:10.7 BRINE RIH & SET BP AT 7430',POOH. RIH & SET CMT RETAINER AT 7250'. POOH RD E-LINE. PU CEMENT STINGER, RIH TAG RETAINER AT 7247'. EST INJECTION RATE 2 BPM 1800PSI SQUEEZE 31.5 BBLS CLASS 'G' CMT INTO PERFS AT 7400-02. FINAL SQEEZE PRESS 2800 PSI. PU REV CIRC DP VOL. EST INJECTION RATE IN PERF AT 7230-32, 1BPM 1800 PSI, SPOT 15 BBLS CMT ACROSS PERFS AND BRAIDEN HEAD SQUEEZE CMT IN PERF. HESTIATE AND SQUEEZE CEMENT. DAILY:S42,983 CUM:$1,109,665 ETD:S1,109,665 EFC:$1,441,000 DRILLING CEMENT 7"@ 7809' MW:10.7 BRINE FINISH HESTIATING AND SQUEEZE CEMENT INTO PERFS AT 7230-32. PUMPED TOTAL OF 13 BBLS CEMENT INTO PERFS & 2 BBLS IN CSG. INITIAL SQUEEZE PRESS = 1550 PSI, FINAL PRESS=2650. HOLD PRESSURE FOR 4 HOURS. REV CIRC ONE HOLE VOL. POOH LD STINGER. MU BIT AND BHA, TIH TAG CMT AT 7221'. DRILL CEMENT TO 7244', TEST PERF TO 1500 PSI. DRILL CEMENT RETAINER AT 7244-7247'. DRILL CEMENT. DAILY:S27,600 CUM:$1,137,265 ETD:S1,137,265 EFC:$1,441,000 POOH W/ BIT/SCRAPER 7"@ 7809' MW:10.7 BRINE DRLG CMT TO BP @ 7421',TEST SQUEEZE PERFS TO 1500 PSI. DRLG BP AND RIH TO 7722 POOH. MU BIT AND 7" CASING SCRAPER. TIH TO PBTD, FILTER BRINE. POOH TO PERF. DAILY:S29,828 CUM:$1,167,093 ETD:S1,167,093 EFC:$1,441,000 POOH WITH DRILL PIPE 7"@ 7809' MW:10.7 BRINE FINISH POOH. RU E-LINE AND PERF 'A' SAND 7614-7598 8SPF AND 'C' SAND 7350-7266 12 SPF, TOTAL OF 5 RUNS. AFTER LAST RUN, WELL STATRED FLOWING. TIH WITH DP TO 7609', CIRC WELL ON CHOKE, INCREASE WEIGHT TO 10.7 PPG, MONITOR WELL, STATIC POOH WITH DRILL PIPE. DAILY:$39,985 CUM:$1,207,078 ETD:S1,207,078 EFC:$1,441,000 RUNNING COMPLETION 7"@ 7809' MW:lO.8 BRINE FINISH CIRC CONDITION, INCREASE WT TO 10.8 PPG. POOH. RU WL RUN GR/JE TO 7500' POOH. MU TIW SS-BB WL SET PERM PACKER AND TAIL PIPE, RIH AND SET PKR AT 7421' WLM. POOH. RD WL. RU AND RUN 3-1/2" X 4" TUBING COMPLETION. (AVA 'SIDEGUARD' SSSV @ The above is correct aration and ~AU]ibution, s Manual, Section 10, 1817', AVA 'RHS-XL' PKR @ 7180', TIW 'SS-BB' PKR @ 7420', & D~,I~.Y:$Z06,2f0 c0~:$Z,313,3t8 ETD:~'Z,§13;318 EFC:$1,~41,000 Drilling, Pages 86 and 87. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. iPage no. 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 werl is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable rength 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. Accounting cost center code State District ARCO ALASKA INC. county or P~'~i~T.['[ SLOP~- AK 2Z-20 lWell no. Field KUPARUK RIVER UNIT Lease or U~DL: 25646 Auth. or W.O. nq~3421 T t e COMPLETE API: 50-029-21876 Operator ARCO A.R.Co. W.~6' 0000 Spudded or W.CA(~I~T Date 02/05/89 Date and depth as of 8:00 a.m. Old TD Released rig Complete reco%gd~gi~ ~Up~ted 02/12/89 ( TD: 7809 PB: 7728 SUPV:CD Classifications (oil, gas, etc.) Producing method Potential test data Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I I Prior status if a W.O, our 2130 .7) RIG REL 1500 HRS 2-11-89 7"@ 7809' MW: 6.9 DIESEL FINISH RUNNING TOTAL OF 98 JTS 4" 11# J-55 DSS-HTC IPC R-3, 97 JTS 3-1/2" 9.3# J-55 EUE 8RD ABM IPC R-2 AND 4 JTS 3-1/2" 9.2# J-55 BTC R-2 TUBING. STAB INTO PERM PKR, MU HANGER LAND TBG SET RET PKR AT 7180'. TEST TBG TO 2500 PSI SHEAR PBR. TEST ANNULUS 2500 PSI, TEST SSSV TO 1000 PSI, SHEAR OUT AT 3000 PSI. NDBOPE, NU FMC 4-1/16" 5000 PSI GEN IV TREE AND TEST TO 5000 PSI. DISPLACE WELL WITH DIESEL. SITPz 300 PSI, SICP= 0. ORIFACE VALVE HOLDING. SET BPV. RELEASED RIG 1500 HRS 2-11-89. DAILY:S269,739 CUM:$1,583,057 ETD:S1,583,057 EFC:$1,441,000 '" '~chora..qo PB Depth K nd of rg JType completion (single, dual, etc.) Official reservoir name(s) New TD Date Well no. Date Reservoir Producing Interval Oil or gasTest time Production Otl on test Gas per day Pump size, SPM X length Choke size T.P. C.P. ! Water % GOR Gravity Allowable Effective date corrected The a~.~e is correct · ' Date~ / For form pr~io~ an~distri~, s~, ~nr;,~:~,~,;~n~c,,on ,0, AR3B-459-3-C INumber all daily well history forms consecutively I Page no, as they are prepared for each well. I Division of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: February 23, 1989 Transmittal Ct: 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 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kuparuk Well Level Re Level Re Level Re Level Re Level Re Level Re Level Re Level Re 3ort 3oft 3orr 3oft 3ort 3ort 3ort 3ort Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report 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 12-03-87 12-18-87 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 · 4-2O-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-2O-89 2-20-89 2-19-89 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' BHP Amerada Casing Casing Casing Casing Tubing Tubin~ Casin~Z Casing 3H-01 3B-13 I E-29 lC-05 3M-17 2Z-20 30-10 31-12 3H-10 Receipt Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kupaurk Fluid Level Report BHP Report Acknowledged: 2-15-89 2-17-89 2-15-89 2-18-89 2-16-89 2-18-89 2-16-89 2-20-89 2-13-89 Date- Casing Casing Casing Casing/Tubing Casing Tubing Casing Tubing BHP DISTRIBUTION: D&M _State of Alaska SAPC Unocal Mobil Chevron STATE Of ALASKA Ab ,aKa OIL AND GAS CONSERVATION COMMI,.,,AON APPLICATION FOR SUNDRY APPROVALS , ~ 1. Type of Request: Abandon __ Suspend __ Operation ShutdOWn % Re-enter suspended well_ Alter casing Repair well ~ Plugging ~ Time extension __ Stimulate m Change approved program ~ Pull tubing ~ Variance m 2. Name of Operator I 5. Type of Well: ~ ARC0 Alaska, Inc. ~ Development"' ~ Exploratory m ' 3. Address / Stratigraphic ~ P. O. Box 100360, Anchorage, AK 995101-0360 Service__ / Perforate ~ Other 6. Datum elevation (DF or KB) 109' RKB 7. Unit or Property name Kuparuk River Unit 8. V~l_n~n ber 9. Permit number 88-124 10. APl number 50--029-21 876 11. Field/Pool 4. Location of well at surface 1903' FSL, 647' FEL, $ec.11, TllN, R9E, UM At top of productive interval 0' FNL, 30' FEL, Sec.11, TllN, R9E, UM (approx.) At effective depth 301' FSL~ 72' FWL, Sec.1, T11N, R9E, UM (approx.) At total depth 481' FSL, 104' FWL, $ec.1, TllN, R9E, UM (approx.) Kuparuk River Oil feet 12. Present well condition summary Total depth: measured true vertical 7992'MD feet Plugs (measured) 6378'TVD feet None Effective depth: measured true vertical 772 8 ' M D feet Junk (measured) 61 88'TVD feet None Casing Length Size Structural Conductor 80 ' 16" Surface 3656 ' 9-5/8" Intermediate Production 7776 ' 7" Liner Perforation depth: measured None Cemented Measured depth True vertical depth 205 sx AS II 115'MD 800 sx AS I!1 & 3691'MD 400 sx Class G--Top Job w/30 sx AS 250 sx Class G 7809'MD 115'TVD 3473 'TVD I 6245 'TVD true vertical N o n e Tubing (size, grade, and measured depth) N o n e Packers and SSSV (type and measured depth) N o n e 13. A~aeC~r~e~t~8s t or y Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver 15. Stato;S of well classification as: __ Gas __ Suspended __ Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~O ~' ~,~.(....j/~8.~ / Area Drilling Engineer Title FOR COMMISSION usE ONLY[ DAM ) SA~./U55 Conditions of approval: Notify Commission so representative may witness Pool Plug integrity __ BOP Test __ Location clearance --/¢/ ~ Mechanical Integrity Test __ Subsequent form required 10- . -~pp;'oved Copy OF~'"'!~:~L SIGNED BY Returned Approved by order of the Commissioner LONN!?: C, SM!TH ........... Commissioner jApprovalNo. ~--'~Fd~y Form 10-403 Rev 06/15/88 Subsequent Worl( Reported on Date SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel)~rt" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only, District I County, parish or borough I ~_o ~T.~,.~, TNC~ I NORTH SLOP~ Field Lease or Unit ~cr~p~,~n~ ~a?~'q~R r3~TT ADL; 25646 Auth. or W.O. no; IT t e ~w'~a91 I D[~TLL etaL 27,-20 Jwe. no. Operator Spudded or W.O. begun IDate I Date and depth as of 8:00 a.m. 11/13/88 ( TD: 856'( SUPV: 11/14/88 ( TD: 3705'( 2 SUPV:BB 11/15/88 ( TD: 3705'( SUPV:BB 11/16/88 ( TD: 5909'( 2 SUPV:BB 11/17/88 ( TD: 7330' ( 1 suPv:Ev 11/18/88 ( TD: 7330'( SUPV:EV 11/19/88 ( TD: 7992'( SUPV:EV Complete record for each day reported DO¥ON 14 API: 50-029-g~876 I IARCO W.I. ~,OOO0 I Hour Prior status if a W,O. 11/13/88 00:00 ) :56) ) 49) ) 0) ) ~04) ~) [21) ;) 0) ~) ;62) DRILLING MW: 8.5 VIS: 69 MOVE RIG FROM 2Z-21 TO 2Z-20, ACCEPT RIG 1900 HRS, 11-12-88, NU DIVERTER SYSTEM, MIX SPUD MUD, SPUD WELL @ 0000 hfs, 11/13/88. DRILL & MWD SURVEY W/ MOTOR TO 856'. DAILY:S122,250 CUM:$122,250 ETD:S122,250 EFC:$1,441,000 CIRC AY 9-5/8" CSG PT MW: 9.2 VIS: 48 DRL AND MWD SURVEY F/ 856' TO 3705'. DAILY:S48,301 CUM:$170,551 ETD:S170,551 EFC:$1,441,000 NIPPLE UP BOP 9-5/8"@ 3691' MW: 9.5 VIS: 43 CIRC BU, SHORT TRIP TO HWDP, RETREIVE SURVEY, TIH, CIRC BU, DROP SURVEY, TOH, LD BHA, RU & RUN 95 JTS 9-5/8" 36# J-55 CSG, LAND ON MANDREL, CEMENT W/ 800 SX AS III & 400 SX CLASS G, DISPLACE W/ 279 BBLS WATER, BUMP PLUG, FLOATS HELD, DO TOP JOB W/30 SX AS I. NIPPLE DOWN DIVERTER, INSTALL BRADENHEAD, NIPPLE UP BOPE. DAILY:S178,773 CUM:$349,324 ETD:S349,324 EFC:$1,441,000 DRLG 9-5/8"@ 3691' MW: 9.2 VIS: 32 NU AND TEST BOPE TO 3000 PSI. PU BHA AND RIH. DRL FC AND CMT TO 3670'. TEST CSG TO 2000 PSI. DRL CMT AND FS AND 10'NEW HOLE. PERFORM LOT TO 11.5 EMW. DRL AND SURVEY TO 5909'. DAILY:S68,531 CUM:$417,855 ETD:S417,855 EFC:$1,441,000 POOH 9-5/8"@ 3691' MW:10.7 VIS: 44 DRLG F/ 5909' TO 7320'. WELL BEGAN TO FLOW. SHUT IN AND CIRC 10.7 PPG MUD. DRLD F/ 7320' TO 7330'. BEGAN LOSING MUD. BUILT VOLUME AND SPOT LCM PILL. HOLE STANDING FULL. :"BUILD MUD VOLUME AND POOH. DAILY:S63,273 CUM:$481,128 ETD:$481,128 EFC:$1,441,000 CIRC AND WASH TO BTM 9-5/8"@ 3691' MW:10.7 VIS: 47 FIN POOH. LD BHA. PU NEW BHA AND TIH TO BTM OF CSG. CBU. LOST 8 BBLS WHILE CIRC. FIN TIH TO 7230'. LOST APPROX 8 BBLS. REAM F/ 7230' TO 7330'. LOST APPROX 30 BBLS WHILE REAMING. BUILD LCM PILL. SPOT PILL. BUILD MUD VOLUME AND WAIT ON MUD TO HEAL. CIRC OUT HEAVY SLUG AND LCM PILL. REAM F/ 7230' TO 7330'. FULL RETURNS. DAILY:S80,202 CUM:$561,330 ETD:S561,330 EFC:$1,441,000 SHORT TRIP AT TD 9-5/8"@ 3691' MW:10.7 VIS: 45 DRILL FROM 7330' TO 7992', CIRC AND COND HOLE, SHORT TRIP AT TD. DAILY:S55,795 CUM:$617,125 ETD:S617,125 EFC:$1,441,000 The above is correct For form p~'ep~ration an~ ~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date AR3B-459-1-D [Number all daily well history forms consecutively las they are prepared f ..... h well. iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District J]C°unty or Parish I stat~K ARCO ALASKA INC. I NORTH SLOPE Field ~Lease or Unit KUPARUK RIVER UNIT I 2Z-20 ! Complete record for each day while drilling or workover in progress DO¥ON 14 Date and deptl~ as of 8:00 a.m. 11/20/88 ( TD: 7992'( SUPV:EV 11/21/88 ( TD: 7992'( SUPV:EV 3) 0) ~) o) LOGGING 9-5/8"@ 3691' MW:10.7 VIS: 49 FINISH SHORT TRIP,CBU, TOH TO LOG, RU SCHLUMBERGER, COULD NOT GET TOOLS BELOW 5080',TOH, DAILY:S50,601 CUM:$667,726 ETD:S667,726 EFC:$1,441,000 RUNNING 7" CASING 9-5/8"@ 3691' MW:10.7 VIS: 39 LOG 8-1/2" HOLE W/DIL/FDC/CNL/GR/CAL, FDC/CNL, GR, ML. MAKE UP BHA, TIH FOR WIPER TRIP, CIRC AND COND, TOH, RU TO RUN CSG, RUN 7" CSG. DAILY:S141,110 CUM:$808,836 ETD:S808,836 EFC:$1,441,000 IWell no. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively ~Page no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: 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. · District ~County or Perish ARCO ALASKA INC. I NORTH SLOPE Field iL ...... ~,: KUPARUK RIVER UNIT 25646 Auth. or W.O.AK3421n°' ITM DRILL .z~!: 50-029-21876 Operator A.R.Co, ARco %~. oooo Spudded or W.O. begun Date SPUD 11/13/88 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 11/22/88 ( 1 TD: 7728'( SUPV:EV Accounting cost center code State AK 2Z-20 IWell no. Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 00:00 IPrlor status if a W.O. I 3) 0) RELEASED RIG 7"@ 7809' MW: 0.0 VIS: RUN 7" PRODUCTION CASING AND SET AT 7809',LOST PARTIAL RETURNS AT 4200' WHILE RUNNING, LOST COMPLETE RETURNS AT 6000', RU DOWELL AND CIRC WITHOUT RETURNS. MIX AND PUMP SPACERS AND 200 SX CLASS G W/ ADDITIVES, DISPLACE W/ BRINE, BUMP PLUG, FLOATS HELD, ND BOP, SET SLIPS, INSTALL PACKOFF, NU TREE AND TEST SAME, FREEZE PROTECT ANNULUS AND RELEASE RIG 2130 HOURS, 11/21/88. DAILY:S198,621 CUM:$1,007,457 ETD:S1,007,457 EFC:$1,441,000 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data PB Depth K nd of r g Type completion (single, dual, atc,) Offic al reservo r name(s) !Well no. Date Reservoir Producing Interval Oil or gasTest 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 Signat ..... , Date ,- For form preparation and distribution, /'~ see Procedures Manual, Section 10, - Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. no. Division of AtlantlcRIchfleldCompany Location~ General.. ~ Well Slgn~ ~e~eril Hbusekeeptng~' Rig .... Visual ~udio Reserve Pit T'rtp Tank ' I:it Caoge Ft~t; Monitor Ge.m Detecto~ ,BOFE Stack Armular Pr even t er.__/_.~ Pipe Rams B! ind Rams ..... Choke Line ~'alwes_~ H,C,R. Valve Kill, Line Wa:ives C'heck Valve~, Test Pressure Te~t Results: 'Faiiures__~/L~.~--- .... Repair or Replacement of failed equipment ACCUP~3LATOR SYSTF~q Full Charge Pre. ssure P~es~'~rr.' After Cio.sure Putnp incr, c].cs~ pre~ 200 psig Full Charge'F~-essure Attair~e~: Controt~: Nester ~ - _ ,_~~ "~,emote ~"Bl~nds switch cover~~" ..... ~res~ur%___. ~F____O_.O ~ ............. Xel. ll and F19pJL. S_~a~'~Di v__!i, ve~ Upper Lower Kelly. / Test Ball Type ,~ Test Inside BOF~ ........ Te~t Choke Ma, hi fold_ff Test No. f ] anges~,,~~ Adjustable Cboke~ / -- ~fdrauic. a~~~ra t.e~ .... c'hoke ... ' Test T~e.. ~:_~hrs .... ~_~~~ day~ and Inspector/ Dl~tribution orig, - AO&GCC cc -. Operat. og CELV. E.D NOV 1 !:5 198.8 Aiaska Oil & Gas Cons. Commissio[~: ' Anch°rag~nspec tot , October 31, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P, O. Box 100360 b~.chorage, Alaska 99510-0360 Re: Kuparuk River Unit 2Z-20 ~ ~ . Inc ARCO A~asma, . Permit No. 88-124 Sur. Loc. 1903'FSL, 647'FEL, Sec. I1, TI!N, R9E, tN. Btmhole Loc. 493'FSL, 60'FWL, Sec. 1, T!IN, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indem~ify you from the probable need to obtain additlo al pemnits required by law from other gover~maental agencies prior to con~nencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing 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 s° that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ truly y_o~urs, / /'~ ..... ?..: :' /:,; ,/ /: C, V, ChJt-t~rt6n" Chairman of Alaska Oil and Ga~ Conservation Co~ission BY ORDER OF THE CO~R~fISSION dif Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK;'-, ,.)IL AND GAS CONSERVATION L,,,~MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redr, ll I-11 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 3. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. RKB 109', PAD 73'GLfeet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25646 ALK 2577 4. Location of well at surface 7. Unit or property Name 11. Type BOnd(see 2o AAC 25.025) 1903'FSL, 647'FEL,Sec.11,T11N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(¢ target) 8. WelI nu.mbe'r Number 0'FNL, 30'FEL,Sec.ll,TllN,R9E,UM 2Z-20 #8088-26-27 At total depth 9. Approximate spud date Amount 493'FSL, 60' FWL,Sec. 1 ,Tll N,R9E,UM 11/09/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 2Z-4, 2Z-3 8026 'MD 4787' ¢TD feet 30' ~ surface feet 2560 6313'TVD feet ,, , 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2100 feet Maximum hole angle 500 Maximum surface 2063 psig At total depth (TVD) 3414 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". 1 6" 62.5# H-40 . We] d Ri0 .%6 _%6; ' I I R I I R ' +?¢)f) CF 12-1/4" 9-5/8"36# J-55 BTC 3612 36 $6' 3648 :~4(i4' 800 ~x AS III & ~F-ER~ 400 sx Class G 8-1/2" 7" 26# J-55 BTC 7991 35 35' 8026 6313' 200 sx Class G tail {F-ER~ Top of G 500' above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Kuparuk Present Well condition summary 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 ~;u°rr~;;tOr RECEIVED Intermediate Production OCT 1 9 1988 Liner Jl~Ja$_~ 0il.& Gas Cons. Commission Perforation depth: measured '~.~i.~ch0rage" 'true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch ~' Diverter Sketch ~ Drilling program ~' Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby cgcti'~that the foregoing is true and correct to the best of my knowledge // Signed( //.~--~/,,¢z,~ ,~~~,~'~ Title Reoional Drillino Enoineer Date ,o-/' ¢.~ b~er /-",/ ' ' "'- Commission Use Only..-~/iJ~,l/j (TEM) PD3/028 Permit Nu ' APl number ]Approval date I See cover letter ~--'/.2. ~Z 50-- (D ~ ~ - ~-- / ~' 7~'"] 'l 0 / 3 ]. / 8 8J for other requirements Condition8 of approval 3amples required [] Yes ~ No Mud log required Lq Yes ~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required ..~Yes [] No R equiredwork~~)¢/~~~ [] 5M; [] l OM; [] 15M Other: by order of Approved by ~,,,.. ~ ~. /, ([.. ~' ~__~~'~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Subr~ll :riplicate md 2Z, Well No8 20 Propoeed Kupmruk Field, North Slope. Almmkm 4000. 3000 o 200.0 _ 1000. _ __ 1000 _ gURFACE LOCAT ION* 1~03' FSL. (S47' FL'L' SEC. II, TIIN, RgE .1000 1000 2000 I I WEST-EAST 0 TO LOCAT ! ON * 4g~3' FSL, ~0' FWL SEC. !. TIIN. RGE RECEIVED .OCT 1 9 1988 Oil & ~a$ Cons, ¢ommi~ion '-, Anchorage N 10 DE9 21i MIN E 34~D;' (,TO ~AR(;ET) Pad '2Z, ~/ell Not 20 Propo.ed .K_upae.uk F_l_.e! d.,i_ North S.l.!op_e~ .... Al_a.ika 0 .. RKB EL£VATI ION ~ !:09' ... 1 000_ 2000. 3000. 4000 _ 5000. B/ PERHAFROST TVD. 1609 KOP' 'TVD-i2-1'O'O TMDi2100-"DEP~O ! 3 T/ uGNu SNDS T~fD=2239 THO=2239 DEP-5 9 BUILD '3 BEg-- " 15 PER 100 FT :2t T/ 14 SAK SNDSi TVD"2819 THD=2837 DEP=.141 3e K- 1 2 TVD=3.284 TI'ID=33Z7 DEP-411 i , 4S '9_.~/8" C~_G PT .... TVD.=348_4...I._/ID_.~_~.$ DEP-594 .......... [ ............. EOC -i"i/ID=3558 THD=375g DEP 6Z? .... "- ~ AVERAGE ANGLE 49--D~E-G 47 HIN ?000 K-5 TVD-4919 THD=S86Z DEP-2285 tARGET TVD-5889 THD"7369 DEP-3433 T/ ZONE ^- TVD-6059 THD=7632 DEP-3634 I/ KUP"-$NDiS 'T'VD-618~-'TMD=78261DEP-3782 TD (LOG PT~ TVD-631:3 THD-8026' DEP-3934 i / i l ooo 2000 3000 .... VERT I-CAL, SECT[ON ..... 4000 2250 2200 f3U 700 850 600 ! 3100 550 t t800 ! ! / / / / / / / / ! ! / / ~ 3700 / / / ! 3500 400 350 ! / / / 3900 t '4~oo //I \ ', / !" !/ i I I I I I I I I { I I I 750 700 650 600 550 500 450 400 350 .22.50 _ 2200 _ 2150 ,. 2t00 - 2050 _ 2oOo 950 900 . 1850 800 .1750 E 'd EI :r=l 88/I~/0I 8Et~O~ 39~.~0H31'1~ WO~td 650 2500 i ~ I % ! 9oo I 2450 24O0 2350 2300 2250 2200 2150 2100 2050 20O0 I t I I 600 I 2900 550 500 450 400 350 300 ! ! t I I I %I I \ \ I I 3300 · ', 1700 \ \ ~t 5oo \ \ I I ! 65O 600 550 250 I .,, ! ! / / I / ? 4ZOO ! / / / / 4go0 / 2500 _ 2450 . 2400 2350 _ 2300 2250. . 2200 2150 2100 2050 2000 C 'd 3l:c:;l BB/TE/'OI BCl~Ott 3~tJ~JOH:DNI~ tdO~d 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" surface 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 logging 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" casing. 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. MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.7 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-50 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 9.0-10.5 % Solids 10-+ 4-7 12-15 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 204' of departure, there are no well bores within 200' of this proposed well. TWM/ih 10/12/88 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 arctic pack upon completion of the fluid disposal. KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC .I !.. DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~:)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/lO' OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASK~ INC., REQUESTS APPR(:~VAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENAN(~E & OPERATION 3 I ! 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT ~HUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 'l 7 G 5 4 2 DI~ #1 5000 I:::~! ~ I~P 'STACK A~TCR r.j~PACITY TEST I. a-~CK /lt43 FILL ACID. IiI. ATCR RliSERVOIR TO I:~CPER LEVEL WITH HYDP344.1C FLUID, 2. ~ THAT ACO. III. ATCR ~ IS 3000 PSI WITH 1500 1=5I ~TI~ (Ir T~'~ REGLLATCI~. 3. C85ERVE TIIvE, TFEN ~ ALL UNIT~ $IMJLTAI~ECIJSLY ~ RECC;~) T~E TIM[ AN3 ~ REMI~ININ~ AFTER 4. RE~ (IN ~ REPiIRT. ~ ACCEP~IIILE LO!~ER LIMIT IS 45 5E~ CL(II~IN~ TIIVE ~ 1200 PSI REI~I~I~ 13-5/8" B(]= STACK TEST I, FILL BCP STAG( AN3 CI-O<E btlNIF~ WITH ARCTIC DIESEL, 2. (]~CK THAT N.L LOCK [X]V~ SCRENS IN V~t. LFE/~ ARE FULLY RETRACTED. SEAT TEST PLUG IN ~Ei..L~D WITH ~.I~¢ING JT ~ ~ IN L(X](I:X3V~ SC;ER 3. C1.09i'__ ~J~LLAR PI~EVENTER Lithe V/~.VES ~~ TO ~ ST~ ~ ~R 4. ~~ ~ TO ~ ~~ TO ~FED ~~ TO 0 ~I. LI~ V~S ~ T~ PI~ ~ ~~ V~ ~KI~ ~~ LI~. ~T TO ~~I ~~ ~I ~ IN ~ 4. 7. ~I~ ~I~ ~L V~ LI~ ~ A ~~) L~~~~) HZ~. ~ST ~ iN ~ 4. ~ ~T ~TI~ ~1 ~E~ ~T ~ ~i F~Y ~. 8. ~ T~ PI~ ~T ~~ PI~ g. ~N ~TT~ P)~ ~I. II. ~N ~I~ ~ ~F~D ~ LI~S ~ F~ ~ ~~I~ ~UI~ ~T ~L V~ IN ~I~I~ ~ITI~ 12, ~ST ~~I~ V~ ~ly, PI~ ~ETY V~ ~ ~I. I~ ~~ TEST I~~TI~ F~ SI~ ~ ~ TO ~ILLI~ ~RVI~. 14. ~~ ~~ ~E~Y T~~ F~I~LY ~~E ~ ~ILY. ARCO Alaska, Inc. Post Office ~'~00350 Anchorage..~,_.,~a 99510-0360 Telephone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: Conductor AS-Built Location Plat -'~2Z'~Pad (Wells 18 - 21, 29) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you hav~ any questions, please call me at 263-4944. Sincerely, d. Gruber ^ssociate £ng~neer JG'hf Enclosure GRU13/1.2 ARCO Alaska. Inc. is a Subsidiary o! AllanticR~chlieldCornl3any i ~ .8. . ~ , ALL WELLS IN THI .t~ NOTES: ~5-BUILT ~CATED IN ~- ~ I. COORDINATES ARE ~S.E ZONE 4. SECTION II, ~ I I N., R. 9 ~., ~ ~ 8. ALL DISTANCES SHOWN ARE TRUE. UMI~T MERIDIAN.~ 5. ELEVATIONS ARE B. RM.S.L. 4. REFERENCE FIELD BOOKS~ L-88-52, p~ 70-74,77, L-88-54~ pg. Z-5 ~ L-88-56~ pg. 5-4. I ~ 5. QG. ELEVATIONS ~OM NSK-5.25.6-8, rev. I PROTRACTED SECTION CORNER 14] 15 6. HORIZONTAL POSITION B~ED ON 2-Z CONTROL I MONUMENTS PER LHD end ASSOCIATES. , " " No Y X LATITUDE LONGITUDE EE.L. E S.L Elev. Elev. 18 '5,966,55z.92 529,117.01 70° 19' 10.907" ~ 149°45'50.250'' ~ 591' 1796' 65.0' 72.6' 19 5,966,605.96 529,088.86 70°19'11.450' ~ 149o45'51.065'' ~ 619' 1849' 67.8' 72.5' 20 5,966,658.89 5~9,060.86 70°19'11.952" ~ 149°45'51.877'' ~ 647' 1902' 68.0' 72.6' ~ ~,9~,~.o~ s~,~.~ ~ool~'l~.~9~" ~l~o~s.'~.~', ~' ~o~' ~.~' ~l.~' 29 5,965,916 . 58 529,455.15 70~19'04.65~'' 149°45'40.51~'' ~ 258' 1158' 67.~' 71.1' , " I HEREBY CERTI~ THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE ALASKA AND THAT THIS PLAT D.S. 2'Z D~[.s~o.s ~.o OT.[R D~ ~ C.A,~ ARE CORRECT AS OF 8/Z9/88. ~ .'_~ WELL CONOUCTOR AS-BUILT ~ev.. 8~ ~e~e Dex~r/~f/o~ ~Ie.' 8-29-8.8 ~.~ 'NSK 6.226. d5 No Y X LATITUDE LONGITUDE EE.L. E S.L Elev. Elev. 18 '5,966,552.92. 529,117.01 70° 19' 10.907" 149045'50.250'' 591' 1796' 65.0' 72.6' 19 5,966,605.96 529,088.86 70°19' I 1.430" 149°4§' 51.065'' 619' 1849' 67.8' 72.5' 20 5,966,658.89 529,060.86 70°19' I 1.952" 149°45'51.877'' 647' 1902' 68.0' 72.6' 21 5,966,827.08 529,:579.34 70o19' I :5.594" 149o45.'42.56:5.' 327' 2069' 66.5' 71.6' 29 5,965,916.38 529,45:5.15 70019' 04.633" 149°45'40.515.' 258' 1158' 67.3' 71.1' CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE 'DATE (2) Loc (8) (3) Admin ~p~ z / ,2_ 9. (-9 thru ~ I0. (10 and 13) 12. 13. (4) CasB ~ /~-2~-&8 (14 thru 22) (5) BOPE (23 thru 28) thru 31) Geology: Eng '.%neering: er: 08/11/88 .01i w zz - YES NO Is the pem: fee a=tached ~ ' ' , . , 2. Is well to be located in a defined pool ................ 4, Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well :o be deviated and is wellbore plat included ................ ~f~ ....... 7. Is operator the only affected party .................... 8. Can permit be approved before fifteen-day-wait ...................... ~_~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is adm/nistrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ........................ : 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 3~. 32. Is conductor string provided ~ ~. ,,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~ 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 ..................... ~x~ ., Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an ex/sting 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,4~A. Are necessary diagrams and descriptions of diverter and BOPE attached.~j~_ Does BOPE have sufficient pressure rating - Test =o ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .... ' ............. Is the presence of H2S gas probable ................................. eXPloratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seism/c analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements. ............................................. { INITIAL POOL CLASS STATUS GEO. AREA UNIT NO. ??I G~ ON/OFF SHORE , 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 specialeffort has been made to chronologically organize this category of information. .o DEC .t 3 1,988 l~il a Cas Cons..Comr~as[on "~'~i ''''~ re_ . . CCIMPAN¥ rI'E.b~ 'tqAME: LIS ?ape Verification l.,istino $chl. umberger Alaska Compu~inO Center 5-DEC-~198~ 13:27 **** REEL HEADER **** ORICI~ : FblC R~EL NA~E : 7302~ CON?I~UATION # : P~EVI~U$ RE~L : CO~ENT : LIS TAPE:, ARCO KUPARUK 2Z=20, API#50~029-21876 **** TAPE HEADER **** SERVICE NA~E : EDIT D~T~ : 88/12/ 5 PREVIOUS TAPE CO~ENT : bis TAPE, ARCO KUPARUK 2Z-20, API#50-o2g-21876 EDYT ,001 FLIC 00!A02 88/12/ 5 PAGEm .ARCO ALASKA INC. 2Z' 20 KU':PAR!UK NORTH SLOP~ 5'0 029 21876-00 903" F&L & 647' FEL 'T i' ' 11 ..O NiiHIP{ lin ]RAN ~E~ gE P~R ANENT DATUM:t LOG MF.3AE, LRED FROM R~iB 109, AROVE: PERMAItE~N'I DATUM ( Tape Verification Listinq SChlum~erqer Alaska Computlnq Center 5-DEC-198B 1~:27 PAGE~ ELEVATIONS DATE LOGGED! RUN NUMBERt TD DRIbbERI TD LOGGERI CA$IN~ ti 109. 20'NOV-88 DF: I08, GL: 68. 9 9/8" 36 LB ~ DRILLER DEPTH OF 369! AND LOGGER DEPTH Or 3690 BIT SIZE Il 8 1/2" $ 7993, TYPE FLUID IN HObEI WEIGHTED POLYMER ISTIVITY[ 3,05 · 66, ,34 ~ ,91 ~ 66, I 0000 20NOV 0330 20NOV 134, lNG DZSTRICTI ENGINEERI PRUDHOE BAY FLETCHER/COPELAND TOOL NUMBERSI DIS 11440 SET 3 SGC 3533 CNC F~ELO REMARK$t 1,5" STRNDOrF ON I'N~UCTZO~ SONDE, , MDEN~2,65, MArTR2X~SAND, BHSaOPE~, HC=CAbIPER, STARTED 3'0'NOV'88 73028 THIS DATA HAS NOT BEEN DEPTH SHIFTED-OVERLAYS FIELD PRINTS ****, $ SCHLU BERGER bOGS INCLUDED WITH THIS FILE 00!}i ~ * <SEE FILE EDIT,002 FO~ 1,2" &A~PL ~ , · 'c : * .' 'T.O :3670 * FORMATION DENSITY * FIRST TO LAS~ ( ( 5-DEC-1988 13:27 NSATED NEUTRON LOG (.CNL) CO~PEFIRST TO bAST'READXNGI 8006 6990/4]08 ~ICROLOG (,~L~) . FIRST TO LAST READING{ ?$07,5 6992,0' GAMMA RAY IN CASING (.CHL) FIRST TO LAST R~ADING{ 3717,0' TO 959,5' TABLE ?YPE t CONS TUNI VALU DEFt NORTH SbOPE ;~mpQny Name ~e, li ~am, e arson State or Province ~Qunty ~ect:lo~ TABLE TYPIC = CURV DEF! . . CHANNEL N O t t ~: ,P 0 r o: s i t ¥ a tho Tape Verification Listing $Chlt]mberger Rlaska Computing Center 5-~EC-198~ 1]:27 DEF! ~TC Tensto. Tension mall Ar~ 'UD RESXST VXTY Hole Diameter Large Rrm DATA FORMAT SP~C{FZCATION RECORD ,~ SET TYPE - 64EB *$ 0 66 0 SET TYPE - CHAN ~, . .' ,XD :ORDER ! LOG TYPE CLA, ¥ r( LIS Tape verttlcatton L~Stlnq $c~Iom~er~er Alaska Co~ uting Center DIL GAPI 5 ~61 07 310 Ol 0 I 1 I 4 61 0000000000 rOC be ~ ~t 07 3t0 O1 0 1 1 I 4 6~ 00006~0~0 Ig~ ~/C3 ,6t 07 ~iO Ot 0 G/C3 ~61 07 3i0 O1 9 i t i 4 61 O000000000 ~ es oooooooooo rDC Z~ ~el 07 ~t~ O~ O ~ ~ ~ ~ ~ 0000000060 ~DC GAPl ~61 09 310 OS 0 I 4 6e 000~000000 el o~ i~o ot o I ~ es ooo, 4 6~ 000 RI C~ R, ~ ~ ~ 6 07 0 Ot 0 i o, oi o i '.-07 ,.~0 Ol 0 OH, , i5' 000 O0 0 I~ I..' 280 ** DA?A ** D D 800 O0 DR~ PAGEI Sc~! ~. erger ~l~a computing center G~ FDC DPH~,FDC R GR,FDC 7900 000 3 599 10 948 -999 "°! 000 ;j ooo 7700,000 0 ' 44 I ~?. 7600 DI 750~ 8 000 DRHO.FDC TEN$,CNb RCFT.CNb GRtMbb TENS. DRNO,FDC TEN$.CNb REFT, Nb GR,~NB GR,~LG T£N$.DZb TE~$ DRHO GR 5-DEC-1988 13:27 5608.000 SFLU -14.7~! GR 0,024 RHOB 5~.000 NPH, .032 ~CNT '999,250 LA 0 0 0 040 538, 000 60~ 8 000 5284 5284 462 90 49 RHOB RCNT 8A SFGU GR RHOB DDI6 FDC ,rOC .Cgb :b 0:00 SFbU~.DIb bA NT ~ 4 -999 ! -9 364 500 469 CAbZ,PO¢ TNR&,CNb CFTC,tNb PAGEI 560~ '738 ,000 ,5t6 , 0 c~l~be~Ger AI~SK~ CO~pU~ no Center 5-DEC-]gR~ 1]:27 DEP?, G~,FDC RTN ,CNL C~TC,CNL MTE D~P? l... KDC CN'TC Nb T~N$ M?EM NLL XL RT 7300,000 TEN$,~{~ 4960, 251761 SP, -49,~ TEN$,CNL 6 .53~ FDC 496~:~33 GR,CNL ,125 HD,~Lb 7200 000 t12 125 ,0 129 125 000 999 999 **999 250 TENS SP DRHO FDC TEN~ CNL RCFT CNL OR CNL GR MLL HD MLL TENS tL HD b HO MLL 5O6O 000 ,-44 '78 o O0 43I '3~8 48: 8FLU D b GR bib RHOB roc RCNT TEN8 SA MLL LA MLL SFLU,DIL NPHleCNb RCNTeCNL TENS;CHL SA*MLL 8FLU GR SFLI ~ 8FL O LA {il 021 { Tape Verification Listing c~lum~erger Alaska Computng Center DEPT DPHI FDC GR FDC RTNR T~NS MLL DKPT, ILD,DIL DPHZoFDC _G~'FDC RTN.mCNL TEN$,MLL Plh Mbb 6700,000 .99~'118 -999, 0 o° '999~ 600,000 99~'$10 ,~$0 , 0 , 0 -99 ,, 0 .99~; o '999,250 650i ~9 TENS DIL SP DIL DRHO FDC TENS GR HD TENS OIL DRHO XD ~LL ~N FDC oo 6200 ~00 TENS '999: HO 999, -999, '99'9, SFLU,DIL GR,DXL RHOB,FDC ,PHI,CNL RCNT,CNb TENS,CHL LAeMLL SFLU,DIL RCNT, ~ LA,~ 45t SF 0 LA IL 4 2 '5 0 LA iO iLlq PAGEI LIS ?aue Verification Llstlno Schlumberger Alaska ¢omputinq Center D~T T N8 MLL MTEM M~ D~PT DIL Ib 6t00 -999;.250 6000 000 -999 i "999 590 5800 '999 0 570~ TENS SP DiL DRHO rD'C TENS CNb RCrT CNb GR CNL GR NLL HD MLL TENS,DIL 8P,DIL DRHO,FDC TEN&, Ga,tNb HD,M~b DRH RC~ 436O "99'9 '999 "999 41 $0 SFLU RHOB FDC NL NPHZ ~NL RCNT TENS CHh $ NLL L~ MLL SFLU DIL G'R DXL RHDB FDC NPHI Nb RCNT ~Nb SFL{ LA¸ 3,026 IbM DIL .141,625 TENS FDC 999,250 CALl ~O~ o99~,250 TNRA CNL -999,250 NRE8 NLL TNRi CPTi '9 5 60 0 '999 250 T{ HD 41 5'0 LA Lb LIS ?ape Verlttcatlon histln~ $c~lumberqer Alaska Computtno Center PAGEi 10 DFPT DPH! RgG~ D~PT OIL 5500,000 rOC -999, 0 ~t~ -999.0 -999, 6 lq b "999, M~b -999, CNL 40~ 000 '999 "999 $, ~0 $200 000 51'00 5000 -9 TENS DI~ SP DI TENS SP DRHO FDC TEN& ~NL RCFT Nb HD T~N O HO MLL D HO MbL 4108 000 ., GR RHOB ~PHI RCN~ TENS LR SFLU 3 000:: 5FLU 0 L -'999 IL, Pi WI DE:PT DPH! FDC R?NR DI~PT PILL MTE~ 4900 999 I 0 '999 -999 '999 4800,000 ~ ~ 0 -99 ,, ~0 ~999 ~ 2'50 . 4600 0 45O TENS PZb SP VIb DRHO FDC TENS CNL RCFT CNL OR CNL GR MLL HD MLL TENS,DIL DRHO,FDC TEN$,CNL RCFT,CNL GR,CNL GR,MLL HD,MLL TEN TEN GR ML! HD lqbb T L H:D 5-DEC-1988 13127 3650 -999 -999 -999 -999 ~999 -999 3404 -44 '999 '999 000 844 5O 8FLU OIL RH FDC RCNT Nb TENS SAeMLL LA,MLL SFLU,O'IL GR*OXb RHOe,FOC L.h,Nbb SFLU LA PAGEt -999 -999 556 000 TENS 50 50 $OTNRA CFTC 250 GR DC FDC C~NL ,CNL MIlL '99g. -999, ILM,DIL CALX CNL ll LIS ?ape Verification bistin~ Schlumberger AlasKa ¢ompu:inq Center PAGE: 12 DEPT OPH! FDC GR FDC ~?NR CN?¢ T N DEP? TENS MLL DXL bt, 4300 000 4 205 $ 4200,000 19.9 '999 250 410~ 4000 -999 3800 000 0 TEN& DIL SP DRHO FDC RCFT GR GR TENSeDXL GR,CNL GR,MLL HD,MLL DRHO TE~$ DRHO FDC CNL ~LL TENS ~905 295~'~34 2930.000 '999, 2$'X 0 SFLU {b RHOB FDC NPHI Nb SFLU,DtL RCNT, LA,MLL SFLU 1 t111' 3 7, 1.2 HR PIb DC PILL )IL OIL 295~ 9 .50~ 2 5' S 24 '58 LIS Taee Verification Listinq SChlumberger ~Iesl<a Computing Center ~AGE~ 1¸3 DPH~ T~N8 MTEM Mb TE~$ ~5 DIL D D XL D~PT 370000 0 0999 0 °999 0 -9~9 3600 0 -99! o9! ~0 0 -999 0 TENS 8P ORHO TENS TENS TEN TEN R TENS H,D¸ DIL Olt, troc CNt, Mbt, RHOB,FDC RCNT,CNt, TEN$,CflL SAeMLL LA,NbL SFLU ,OIL LA MLL :b ,¸9 GR' 'N MRESoMLL '9' Tape YeriftcatXon Listing SchlUmberger AlasKa Computln~ Center 5-DEC-~988 13{27 PAGE{ 14 DEPT, 3100,000 TENS,DXb tLD~VIh -9~9~250 DRHO,FDC DPHX,FD¢ -999, ~0 SP;DZb GR,FDC -~99, 0 TE~S,CNb CNTC,CNh "999, GR,CN~ D~PT RT DP D 3000 000 "999 ~999 '999 iO 2 -99'9 2600 TENS DZL SP DIL DRHO FDC CNL GR CNL GR HD TEN S iL HD TENS HD 99 '999 *999 '999 '999 '99~ '999 RHOB FDC NPH! 8FhU OIL ~PHl .Nb RCNTIHbNb LA SFLU bA -99~ 2: -999 99:9.250 99 XLN,DZL TENS FDC CAb{ FDC TNRA ~RES MLL ILM,DIiL CALZeFDC TNRA,CNL CFTC,CNL GR,CHL NLL '999,250 '999,250 '999,250 '999,250 "999~2~0 44~625 '999~250 PAGEI 15 DEP?. ~500,000 TEN;SeDIb iLD.DIL 999,250 81 DIL DPHY,FDC -g99,250 DRH~FDC TGR"FbC -999,250 TENS,CNC R N~.CNL -999,250 RCrT,CNb C~?C.~NL -999,250 GR,C~ T[NS,Nbb -999,250 GR,NbL ~T£~,~Lt, -999,250 HD,~bb DEPT, R?~ FDC D~ 240O 000 "999, '999, '999, '999,2~0 '99~ ~99 2 0 "'9 0 . 20~ ',999 ORHO FOC HD NLL T{ IFC c. NL LL TEN&. "'"J'~M tl -999, ~9~9~ '999 2~0 '999 ~50 '999 ~0 SrbU,Oib RHOB,rDC NPHI;¢N~ RCNT,CNL TEN$,C~L SA,MLL LA,MLL SFLU OIL R GR ~ HOB ~ '999 } 8F 0 :LA -9 191 -999 :999 999 A Crm'C;CNL GR,.CHb !,{00 HRE$.MLL 50¸ '9 .I I$ Tape Verification 6isting chlum~erger Al, aska Computing Center 5-DE;C,,1 g8 B 13~27 PAGEI DEPT, ~bDtDIb R?N~eCNb C~TC,CNb T~NS,Mbb .rOC DP "999'I0 "999e "999 "999, 1800 000 "999 :-' 999 -999 ~999 .250 TENS DIb SP DIb DRHO ? C TENS C~fi T~NS.D b RCFT, 'N" HD,MLL TEN TENS.~ 0999, "999,'i::~0 TENS -999 "999 0 t ,,,999 0 IbM DIL "999e' -9! 0 D~PT. ~LD.DIL OPH~,FD RTNR.CNb EN8 MLL 1300.000 "999;150 -999. ~ '999, '999~0 o9~, 1200.000 :999,2S0 999o250 -999~25o I 25:0 $0 50 END OF ~ATA ** SP D~L DR'HO FDC RCrT Nb Ga GR MLL fiD MLL 99~ 250 -999 250 ~999 5 -99~ 50 TENSeDXL °999 2i0 SP,DZL "999 I~ DRHOeFDC "g99 ~ RCFTeCNL *' ~ ~R,CNL GR..Lb -, ~g HDe~LL *9'99 250 MLL T E: N DR SFLUeDZL GR,DZL RHOB,FDC NPHX.CNL RCNToCN~ T£~$,CHL LAe~bb SrLU LA Sr ) Srbi -999 ,0 CrTC,CNL GR,CHL 250 XLMeDXL '50 ~$6 TEES, CALY, -99~ o LIS Tape Verification Llstina S~hlu~herger AlasKa Co~putino Center **$* FILE TRAILER $*** FILE NAME ~ EDIT ,00! S~RVICE { FLIC V~R$ION { O01A02 DAT~ ! 88/12/ 5 LiST FILE { **** F{LE HEADER F~L~ S~RVICE { ED]Y ,002 V,RSXON { O0iA02 DAT~ ~ 89/12/ 5 IZ~ { 1096 5-DEC-1988 13{27 PAGE{ SCHLUMBERGER $ ¢SEE FY~:E EDXT , BO01' ?0: 6994,5" $ TABLE TYPE '. CO~$ TU.! ' :D~:F! : 2[NC, ~O~P:.an¥ Name Fi.e'l~a~e Schlumberger Alaska ¢omputinq Center 5-DEC-1988 13127 TUN! VAbU DEF! NAIl well Name NatLon $?~? Ab~$KA state or Province C~UN NOR?H SbOPE SEC? County TOWN l! Section RANC ~IN Town, htp 1903' FSb & 647' FEb R~ [~G! MALLAR¥ ~ ~on Name Order ?IB~E TYPE I CUEV DEF! DEPTH CHRNNEb NAME '~ ' ' r Porosity G&mmaRa¥: TYP~ R:'~PR CODE VA~U:E Tape Verification Listinq chlumberger Ala$~8 Computing Center PAGE: 2O TYPE REPR CODE V~bU~ ? 65 8 68 0.099 66 0 15 66 68 16 66 0 66 ~ SET TYPE UNIT SERVICE APlA~I APl APl rlbE NUMB NUMB SIZE REPR PROCESS CbAS8 MOD NUmB &AMP ELEM CODE (HEX) F? F'DH I I i )00 · :~ DATA 'DH C:N:H 800 H H GR CNH NH NH LIS Tape Verification Listinq $chlomuerqer Aia$~ca ¢omputinq Center 5-D~:C-} 988 13t27 PAGE[ 2t D~PT RHOB:FDH .CNH CNTC.CNH EPT, OB.rDH GR.FDH RTNR,CNH CNTC,CNH R;NR CNH C~?C C~ FDH R' FDH 'C CN'H IrDH 790~,000 t ! .250 ,969 215 .028 O0 20t; 870 I"/O0 000 2 541 64 6'/5 ! 76; 577 115 7500 21o 4 740~ 300, 5~ ~936 RD~?, 72020000 CNTC.CNH ~ 958 ooo ~ , FDH 3!9 CNTC !694, 549 TENS II'DH NFDC FDH TENS CNH, RCFT CNH GR CNH TEN$,,FDH NFDC;FDH TI~NS, CNH RCFT, CNH GR,CNH TEN$,FDH NFDC, FDH TENS,CNH RCFT,CNH GR,CNH TENS FDH NFDC FDH ReFT GR C'NH NH NH -OR NH -O CNH TEN$,FDH TEN$,CNH RCFT, CNH GR,CNH GR CNH GR CNH 5352,000 669,000 5352,000 677,960 i12,250 5244 000 57 ! 500 482'6~5 84, 4932 0 0 49S 52.64 605 4~ 4 4 9.9 8 FDPHI. FDH FDC,FDH NPHI.CNH RCNT.CNH DPHX,FDH PFDC,FDH NPHX,CNH RCNT*CNH ,FDH RENT, DPHZ, FDH IFF'DC, FDH ~ :NH NIPH[*~N,H RCNT, PH ', FDH 9, 36 DRHO,FDH 529, O0 CALZ.FDH' 2102,966 CFTCeCNH ~AL:[,FDH 1863~',898 "RA.CNH 385 CFTC~CNH '{§0 DRHO,FDH 29~. CALI,FDH 1741~.586 TNRA,:CNH .254 CF?C,CNI.! DH DH NH NH :: CNH 6 16 O, 0 98 6,344 3,939 7560082, I8 Tane Verification Listing chlumberger Alaska Computing Center 5-0EC-lg~B 13:27 PAGE: 22 DF. PT, ~HO~,FDH GR, FDH RTN~CN. 7000,000 TEN$,FDH 2.335 NFDC,FDH 539 GR,CNH 699~,$00 TEN$,FPH ,?S0 TENS'CNH 14~,355 "FDC, FDH ,792 RCFT,C~H 1805,731 GR.CNH ** END OF DATA ** 4752,000 DPHI,FDH 441.~ CNH 133,~50 4852,000 DPHI.FDH Se1;500 FrD¢;FD. 397.44~ RCNT.CNH I46,7$0 19,100 DRHO,FDH 639.000 CAI, I,FDH 45,749 TNRA.CNH 1673.707 CFTC'CNH TNRA, CNH 47.59~~ CAbI.FDH 1813' CFTC.CNH 0,O20 10,016 3,763 473,343 "0,,006 10.133 50 ; 460 ***.$ F~LE TRAI~.ER : EDI ,002 : r6I~ ! 001~02 : 88/ 2/ 5 : bO I ,003 ON 5 ,ye*********************************************************************~,*** , , , , , * , , $ , , , , , : $'CHL~BERGE:R ,LOGS ~NCLUDE:D FILE · ** F'T~E, ~A~E ~ EDIT,O03 = <i., · bE: 78 ,7:,5::,:0 ' TO 6992::,0' , , , , , , , , , , , , , , , * , , , , ,,, e',~lu~erqer AlaSKa Computln~ Center 5-DEC-1988 I]:27 TABLE TYPE : CONS TONI VALU DEFI ARCO ALASKA ZNC, ~ K ~RU~ 2~ 1eld ame 20 Well Name aLASKA state or ProvLnee NORTH 8LOPE 1! ~ ~. ;! MAL~ARY 530861 ~ 50~029~21~76~00 TAGLE TYP~ : CORY DEF! ~ D:ATA FO:R~A? $'PEC~'FICATION RECORD 0 S Tare Verification Listing chlumberger Alaska ¢omputinC Center 5-DEC-1985 13:27 PAGE~ 24 TYPE REPR CODE VAhUE 14 65 PT 15 66 68 16 66 0 66 I $$ SET ?¥PE - CHAN $$ UNI? SER¥ICE APt APl APl AP! r~bE NUMB NUMB SIZE REPR PROCESS ORDER # bO TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) ~, ,,o,,, ooo~o oo o , , , , ~,oooooooooo °'" ~I°*~ ~ ~ ~ ~t ° ~ , ~ . ,~oooooooooo OHM. ~ oe61 Is5 o ~ i i 4 6~oooooooooo EB 30861 15 000 O0 0 ! I 4 68 0000000000 · 0 DATA ** DEP?. 7807,633 MIN¥,Mbb DEP?~ 7800.000 MI. NV,M~b DF/PT, 7700,000 MINV,MLL D~P~, 7600~000 ~INV,MLL DEP?, 7500,000 MINV.MLb DEP?, 7300,000 MIN¥,Mbb DE:P?e 7200,000 ~INV,Mbb D~P?, 7100,000 MINV,Mbb D~P~, ~0'00,000 M~NV~MLL 098 M NOR, Mbb 328 MNOR, Mbb 456 MNOR, Mbb .,. 188 MN:OR, MLL 396 MN:OR,MLL 4.605 MN:OR, Mbb 893 M NOR, MLL 2~023 MNOR,Mbb 2,127 MNOR,MbL 3-556 MNOR,Mbb 4,300 MNOReMbb 2.605 H?E~N -M[,b 202.3?5 2,,534 H?EN -l~lbL 161,266 2-200 H~EN.~bb 286,,00o 2.87 t H~gN, MbL 2:44.0:0'0 6,547 H~E:N, ~bb 1 t MLL i, 7 25 500 i, 713 H~E~. ~bb ~ 52 ~ 00:0 2,890 ,MbL 164.406 ~ ~ 269 H~EN.Nbb ,-999 END OF DATA LIS Ta~e verl,:tcat~o~ Llstl~c Schlumberger Alaska Computlnq Cen~er PAGEt 25 **** FILE TRAILER V[R$ION t O01A02 MAX REC $~Z~ I 1096 FILE TYPE I LO LaST FILE **** TaPE TRAILER **** R~ICE NAME I EDIT IN : FL, lC TaPE NAME I 73028 CON?XNUATXON # ~REViOUS TAPE COMMENT t ~l$ TAPE, ARCO KUPARUK 2Z-20, APXt50-029-21876 REEL TRAILER **$* t '73028 t LIS TAPE, ARCO KUPARUK 2Z-20:, APX~50-'029-2~8'7'6