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Home My WebLink About185-292MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-14 KUPARUK RIV UNIT 3F-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 3F-14 50-029-21500-00-00 185-292-0 W SPT 5750 1852920 1500 880 880 880 880 50 50 50 50 INITAL P Austin McLeod 6/28/2024 Initial after RWO 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-14 Inspection Date: Tubing OA Packer Depth 250 2020 1930 1910IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240628162014 BBL Pumped:1.2 BBL Returned:1.2 Thursday, July 25, 2024 Page 1 of 1             1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Selective Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6975'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5/28/2024 3-1/2" Packer: SLB Blue Max Packer Packer: Baker FHL Rtvbl Packer Packer: Baker FB-1 Perm Packer Packer: TIW SS Perm Packer SSSV: None Perforation Depth MD (ft): L-80 1855' 3027' 1890' 6336-6442', 6594-6618', 6637- 6680' 6843' 5837-5919', 6036-6055', 6070- 6103' 7" Perforation Depth TVD (ft): 115' 3064' 6257'6878' 16" 9-5/8" 77' 7" 6531' MD MD 115' 3064' 1890' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025632 185-292 P.O. Box 100360, Anchorage, AK 99510 50-029-21500-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5363' MD and 5078' TVD 5460' MD and 5154' TVD 6224' MD and 5750' TVD 6509' MD and 5970' TVD N/A Dusty Freeborn Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Staff Well Integrity Specialist KRU 3F-14 6332' 6522' 5981' 6522' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Contact Email: dusty.freeborn@conocophillips.com Contact Phone:(907) 265-6218 By Grace Christianson at 1:18 pm, May 28, 2024 Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2024.05.28 13:07:18-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn 324-314 10-404 DSR-5/29/24VTL 7/5/2024 SFD 5/29/2021 X &':IRU-/& Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.07.05 13:35:35 -08'00'07/05/24 RBDMS JSB 070924 3F-14 Well Work Justication & Objectives: 3F-14 was identied with having a C-sand selective leak through the Baker CMU at 6496'. A patch needs to be set over the leak to isolate the C-sands and allow A-sand injection. Risks/Job Concerns: Subsidence style RWO conducted 2024. OA cemented to surface. C-sand selective leak at Baker CMU at 6496'. 3.5"x2.875" cross over at 6505'. 2.25" CA-2 plug with dual gauges set in Camco "D" nipple at 6523'. 10-404 required post patch installation. Steps: Hal Relay or S-line with DPU 1. Pull 2.25" CA-2 plug with dual gauges from 6523'. 2. Brush and 6ush packer set depths of 6505' to 6470'. 3. Notate surface tubing pressure at the time of lower packer set. 4. Set lower 3.5" P2P mid-element at ~6503 with aluminum elongated shear out plug pinned to shear at 1800 psi di9erential pressure. (The intent is to install the lower packer so the shear out plug will be hung into the 3.5"x 2.875" cross over to ensure the plug will drop out of the tubing tail. TTS shear put plug housing may no-go out in 3.5" x 2.875" cross over.) 5. Set upper 3.5" P2P mid-element at ~6480'. 6. Perform MIT-T to 1000 psi above pressure at the time of lower packer set (last documented tubing pressure was 1300 psi). 7. If MIT-T passes, increase pressure to create ~1800 di9erential across shear plug to blow out. Increase pressure above 1800 psi in small increments as needed until shear plug is blown out. 8. Drift with 1" tool string to tubing tail to ensure blow out plug has passed 2.25" Camco "D" nipple. 9. Turn well over to operations to bring on injection. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,713.0 3F-14 1/8/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig, Set DMY. Pull B&R, RHC. Set plug w/ gauges. 3F-14 4/10/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Leak detected @ CMU SLEEVE @ 6496' 6/28/2010 lmosbor NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 11/18/1996 triplwj 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 38.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,063.6 3,063.5 36.00 J-55 BTC 7" Tie-Back String workover 2024 7 6.28 35.0 1,889.8 1,889.7 26.00 L-80 HYD 563 PRODUCTION 7 6.28 35.0 6,878.0 6,256.7 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 5,425.7 Set Depth … 5,127.1 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 Nabors 7ES RKB = 24.38' ORKB Doyon 9 RKB = 33.25' Diff = 8.87' 33.3 33.2 0.06 Hanger 7.000 3.5" FMC Gen 4 tubing hanger - H- BPV - EUE Lift threads FMC GEN IV 2.910 5,305.4 5,032.3 37.94 Mandrel – GAS LIFT 5.955 3.5" SLB MMG mandrel SLB MMG 2.920 5,362.9 5,077.6 38.00 Packer 6.276 3.5" x 7" SLB Blue max packer Vam Top x Vam Top S#CP23P-0228 SLB 1030584 59 2.885 5,398.5 5,105.6 38.04 Nipple - X 4.501 3.5" Halliburton 2.81" X nipple HALLIB URTON 2.81" X 2.810 5,418.8 5,121.6 38.11 Overshot 6.000 Baker 6" OD x 3.58" ID Non sealing overshot Spaced out 2.8' off fully located. Baker Non sealing 3.600 Top (ftKB) 5,422.0 Set Depth … 6,531.4 Set Depth … 5,987.9 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection AMB-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.8 5,137.3 38.19 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR 5.875 BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY 5.000 BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,283.5 5,796.2 39.39 PRODUCTION 6.018 CAMCO MMM 2.920 6,328.9 5,831.3 39.42 BLAST RINGS 4.500 BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C 3.500 BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing 3.500 CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.2 5,968.4 39.18 LOCATOR 3.975 TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY 3.237 TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.2 39.18 PACKER 5.813 TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE 4.480 SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE 2.875 CAMCO D NIPPLE NO GO 2.250 6,530.6 5,987.4 39.19 SOS 3.686 BAKER SHEAR OUT SUB 1.484 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) 6,496.0 5,960.5 39.19 LEAK C sand leak found on LDL. 6/28/2010 0.000 6,522.0 5,980.7 39.19 TUBING PLUG Set 2.25" CA2 plug, soft set & dual gauges (OAL 77") 4/9/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,305.4 5,032.3 37.94 1 GAS LIFT DMY RK 1 1/2 0.0 4/8/2024 0.000 6,283.5 5,796.2 39.39 2 INJ DMY RK 1 1/2 0.0 10/19/1999 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,875.2 1,875.1 0.35 Collar - Stage 8.240 CMTR,TYPE H ES-II, HYD 563 L- 80 HES II CMTR 102463867 4.370 3F-14, 5/28/2024 11:37:52 AM Vertical schematic (actual) PRODUCTION; 1,886.3-6,878.0 IPERF; 6,637.0-6,680.0 RPERF; 6,596.0-6,616.0 APERF; 6,594.0-6,618.0 TUBING PLUG; 6,522.0 PACKER; 6,508.6 LEAK; 6,496.0 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.5 Nipple - X; 5,398.5 Packer; 5,362.9 Mandrel – GAS LIFT; 5,305.4 SURFACE; 37.0-3,063.6 7" Tie-Back String workover 2024; 35.0-1,889.8 Intermediate String 1 Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 Hanger; 33.3 KUP INJ KB-Grd (ft) 41.88 RR Date 12/25/198 5 Other Elev… 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status INJ Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 3/26/2024 H2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze 35.0 1,878.3 35.0 1,878.2 Intermediate String 1 Cement Placed 55.5 BBL's of cement behind 7" casing 3/23/2024 3F-14, 5/28/2024 11:37:53 AM Vertical schematic (actual) PRODUCTION; 1,886.3-6,878.0 IPERF; 6,637.0-6,680.0 RPERF; 6,596.0-6,616.0 APERF; 6,594.0-6,618.0 TUBING PLUG; 6,522.0 PACKER; 6,508.6 LEAK; 6,496.0 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.5 Nipple - X; 5,398.5 Packer; 5,362.9 Mandrel – GAS LIFT; 5,305.4 SURFACE; 37.0-3,063.6 7" Tie-Back String workover 2024; 35.0-1,889.8 Intermediate String 1 Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 Hanger; 33.3 KUP INJ 3F-14 ... WELLNAME WELLBORE3F-14 185-292 T38924 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:26:47 -08'00' 185-292 T38901 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:48:07 -08'00' 185-292 T38901 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:48:31 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Cozby, Kelly To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:NSK RWO CM; Hobbs, Greg S; Kneale, Michael L; Morales, Tony; Turcotte, Matthew; Yearout, Paul Subject:Nabors 7ES 3-17-24 Date:Tuesday, March 19, 2024 3:17:46 PM Attachments:Nabors 7ES 3-17-24.xlsx Some people who received this message don't often get email from kelly.cozby@nabors.com. Learn why this is important Thanks, Kelly Cozby 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. .58) 37' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6975'feet 6522'feet true vertical 6332' feet None feet Effective Depth measured 6713'feet 5363', 5460' 6224', 6509' feet true vertical 6129'feet 5078', 5154' 5750', 5970' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5426' 5127' Packers and SSSV (type, measured and true vertical depth)5363' 5460' 6224' 6509' 5078' 5154' 5750' 5970' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3064' 3064' Burst Collapse Production 1855' 6843' Casing 1890' 6257' 1890' 6878' 3027' 115'Conductor Surface Tie-Back 16" 9-5/8" 77' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-292 50-029-21500-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025632 Kuparuk River Field/ Kuparuk Oil Pool KRU 3F-14 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 115' Well Shut-In 323-569 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer: Baker FHL Retrievable Packer: Baker FB-1 Permanent Packer: TIW SS Permanent SSSV: None James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-6312Staff RWO/CTD Engineer 6336-6442' (squeezed), 6348-6390', 6594-6618', 6596-6616', 6637-6680' 5837-5919'(squeezed), 5846-5879', 6037-6055', 6038-6054', 6070-6103' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:19 pm, Apr 24, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@cop.comReason: I am the author of this documentLocation:Date: 2024.04.24 11:56:05-08'00'Foxit PDF Editor Version: 13.0.0 James J. Ohlinger RBDMS JSB 043024 DSR-4/29/24 Page 1/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/14/2024 18:00 3/15/2024 00:00 6.00 MIRU, MOVE MOB P Prep rig floor to lay derrick over Pull pins and lay derrick over Prep pits for moving, warm up moving system 0.0 0.0 3/15/2024 00:00 3/15/2024 01:30 1.50 MIRU, MOVE MOB P PJSM, hook up jeep to pits and pull pits away from sub, clean up where pit sat at, unhook jeep from pits 0.0 0.0 3/15/2024 01:30 3/15/2024 04:00 2.50 MIRU, MOVE MOB P Prep sub base for move, warm up moving system, jack up sub pull rig mats out from under it, pull sub base off 3B- 16, pick up mrig mats and herculite around well Prep office, shop for move to 3F pad Hook up pits to truck, load rig mats for office, pits, shop and dance floor for rig 0.0 0.0 3/15/2024 04:00 3/15/2024 09:15 5.25 MIRU, MOVE MOB P Move shop, office and pits to 3F pad Set up office and shop Prep around 3F-14 for laying rig mats and herculite 0.0 0.0 3/15/2024 09:15 3/15/2024 11:30 2.25 MIRU, MOVE MOB P Move sub base from 3B pad to 3F pad Continue to prep 3F-14 cellar area and dance floor for sub and pits 0.0 0.0 3/15/2024 11:30 3/15/2024 13:00 1.50 MIRU, MOVE MOB P Sub base on 3F pad, hang tree in cellar, spot well head equipment in cellar, line up sub with well 0.0 0.0 3/15/2024 13:00 3/15/2024 14:00 1.00 MIRU, MOVE MOB P Spot sub base over 3F-14 0.0 0.0 3/15/2024 14:00 3/15/2024 17:00 3.00 MIRU, MOVE MOB P Lay out herculite and set mats for pits Spot pits up to sub base, berm around sub and pits Secure stairs and landings 0.0 0.0 3/15/2024 17:00 3/15/2024 18:00 1.00 MIRU, MOVE MOB P PJSM, inspect derrick, prep to raise derrick, raise derrick pin A-legs flip cattle chute, unpin bridal lines. pin top drive, hang bridal lines in derrick. 0.0 0.0 3/15/2024 18:00 3/16/2024 00:00 6.00 MIRU, MOVE MOB P Swap power to pits, R/U interconnect, R/U mud lines, B/D F/rig floor tp pits, check lines. Secure rig floor, connect the cement line, hang rig tongs, place XO's subs and elevators back on rack, remove leg brace. Complete pre acceptance checklist. 0.0 0.0 3/16/2024 00:00 3/16/2024 06:00 6.00 MIRU, WELCTL RURD P Load seawater in pits. finish installing hard line to kill tank. RU cellar to kill well. Grease crew on location to service choke and rig. Tool house working on wrapping hardline with visqueen to prevent freezing. Load and process 3 1/2" DP in pipe shed 0.0 0.0 3/16/2024 06:00 3/16/2024 07:00 1.00 MIRU, WELCTL SFTY P Crew change out, walk lines, blow air thru all lines and double check valve line up. Check pressures TBG = 1000 PSI I/A = 550 PSI 0.0 0.0 3/16/2024 07:00 3/16/2024 08:15 1.25 MIRU, WELCTL RURD P Wing valve on tree wont open, pressure locked, call out valve shop bleed valve off so it would function Obtain RKB's ULDS = 24.38', LLDS = 26.27', G/L = 27.71' 0.0 0.0 3/16/2024 08:15 3/16/2024 08:45 0.50 MIRU, WELCTL SEQP P Flood lines test to 250/2500 PSI 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 2/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2024 08:45 3/16/2024 10:15 1.50 MIRU, WELCTL KLWL P Bleed off gas cap TBG F/1000 T/350, IA F/550 T/200 Pump 33 BBLS 8.6 PPG deep clean pill 1 BPM 730 PSI Pump 294 BBLS 8.6 PPG seawater @ 2 -5 BPM 700/715 PSI 0.0 0.0 3/16/2024 10:15 3/16/2024 10:30 0.25 MIRU, WELCTL OWFF P Shut in, check for pressure TBG and IA 0 PSI Open up IA slight flow, open TBG up, well out of balance 0.0 0.0 3/16/2024 10:30 3/16/2024 10:45 0.25 MIRU, WELCTL CIRC P Pump 25 BBLS @ 3 BPM 320 PSI 0.0 0.0 3/16/2024 10:45 3/16/2024 11:15 0.50 MIRU, WELCTL OWFF P Flow check, static 0.0 0.0 3/16/2024 11:15 3/16/2024 12:00 0.75 MIRU, WELCTL MPSP P Pull tree cap, set ISA BPV, test to 1000 PSI F/10 min in direction of flow, blow down lines 0.0 0.0 3/16/2024 12:00 3/16/2024 14:15 2.25 MIRU, WHDBOP NUND P Bleed off hanger voids and void in SSV N/D tree Check hanger threads M/U blanking plug, 10 1/2 turns 0.0 0.0 3/16/2024 14:15 3/16/2024 17:30 3.25 MIRU, WHDBOP NUND P N/U 7 1/16 x 13 5/8" DSA N/U BOP, install riser and hook up lines 0.0 0.0 3/16/2024 17:30 3/16/2024 18:00 0.50 MIRU, WHDBOP RURD P R/U testing equipment, fill stack, choke and lines with water, purge air from system, obtain good shell test 0.0 0.0 3/16/2024 18:00 3/17/2024 00:00 6.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2", 4" and 7" test joints, UVBR's on 3.5" and 4" test joints, LVBR's w/7" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and 3.5" HT38 IBOP. Tested 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =15 sec, full recovery attained = 102 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 3/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/17/2024 00:00 3/17/2024 04:00 4.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2", 4" and 7" test joints, UVBR's on 3.5" and 4" test joints, LVBR's w/7" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and 3.5" HT38 IBOP. Tested 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =15 sec, full recovery attained = 102 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Adam Earl. 0.0 0.0 3/17/2024 04:00 3/17/2024 06:30 2.50 COMPZN, RPCOMP RURD P Blow down surface lines. Empty stack. Pull blanking plug. Pull BPV. PU handling equipment for pulling completion. RU To pull completion. Move GBR tongs to rig floor. RU power tongs. 0.0 0.0 3/17/2024 06:30 3/17/2024 07:00 0.50 COMPZN, RPCOMP PULL P MU 4.5" NUE X-O W/DP and screw into tubing hanger. BOLDS. Pull hanger off seat at 95K, pull hanger to floor F/5,413' T/5,385' - 80K UP 0.0 5,385.0 3/17/2024 07:00 3/17/2024 08:00 1.00 COMPZN, RPCOMP CIRC P Circulate @ 4.7 BPM 260 PSI Pump 211 BBLS 5,385.0 5,385.0 3/17/2024 08:00 3/17/2024 09:00 1.00 COMPZN, RPCOMP RURD P L/D joint 3 1/2" DP and X/overs, change elevators to 4" TBG, blow down top drive 5,385.0 5,385.0 3/17/2024 09:00 3/17/2024 12:15 3.25 COMPZN, RPCOMP PULL P POOH L/D 4" TBG F/5,385' T/4,280' 70K UP 68K DN Lay down 35 JTS 4" TBG, pulled JT #36 out Pull SSSV T/637' 5,385.0 4,280.0 3/17/2024 12:15 3/17/2024 12:45 0.50 COMPZN, RPCOMP RURD P Cut and secure control line RIH F/4,280' T/4,310' C/O elevators 4,280.0 4,310.0 3/17/2024 12:45 3/17/2024 13:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 6 1/8" mill for drifting 7" casing 4,310.0 4,318.0 3/17/2024 13:15 3/17/2024 15:00 1.75 COMPZN, RPCOMP PULD P RIH F/4,318' T/5,357' See 3K drag with 6 1/8" mill at 329' See 5K drag with 6 1/8" mill at 731' Run 6 1/2" mill T/1,045' 89K UP 75K DN 4,318.0 5,357.0 3/17/2024 15:00 3/17/2024 16:00 1.00 COMPZN, RPCOMP TRIP P POOH with 3 1/2" DP F/5,357' T/4,310' L/D BHA #1 5,357.0 4,310.0 3/17/2024 16:00 3/18/2024 00:00 8.00 COMPZN, RPCOMP PULL P POOH L/D TBG F/4,310' T/803' Recover 19 of 30 SS Bands 4,310.0 803.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 4/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2024 00:00 3/18/2024 02:00 2.00 COMPZN, RPCOMP PULL P Continue POOH with completion F/803' T/surface Recoverd 14.57' Cut joint 803.0 0.0 3/18/2024 02:00 3/18/2024 04:00 2.00 COMPZN, RPCOMP RURD P RD GBR tongs and clear floor. RU floor to RIH with DP. Move BHA pieces to floor. Set Wear ring. 7" OD 6.375" ID. 0.0 0.0 3/18/2024 04:00 3/18/2024 05:30 1.50 COMPZN, RPCOMP RURD P Load pipe shed with DP, drill collars and BHA #2 components 0.0 0.0 3/18/2024 05:30 3/18/2024 08:15 2.75 COMPZN, RPCOMP BHAH P M/U BHA #2 6" cut lip wirh 5 3/4" wash pipe for clean out run to recover missing bands and control line T/243' Tag up at 61', 131' with 3K DN , no over pull picking up 0.0 243.0 3/18/2024 08:15 3/18/2024 09:00 0.75 COMPZN, RPCOMP TRIP P RIH F/243' T/1,282' from derrick 243.0 1,282.0 3/18/2024 09:00 3/18/2024 10:30 1.50 COMPZN, RPCOMP PULD P RIH from pipe shed F/1,282' T/2,606' 75K UP 70K DN 1,282.0 2,606.0 3/18/2024 10:30 3/18/2024 11:00 0.50 COMPZN, RPCOMP SVRG P Service rig while processing DP in pipe shed 2,606.0 2,606.0 3/18/2024 11:00 3/18/2024 11:30 0.50 COMPZN, RPCOMP RURD P Finish loading and process 93 JTS drill pipe in shed 2,606.0 2,606.0 3/18/2024 11:30 3/18/2024 15:30 4.00 COMPZN, RPCOMP PULD P RIH F/2,606' T/5,412' - from pipe shed 120K UP 100K DN 2,606.0 5,412.0 3/18/2024 15:30 3/18/2024 16:00 0.50 COMPZN, RPCOMP CIRC P Locate 3 1/2" TBG stump @ 5 BPM 995 PSI Slack off to 5,422' set DN 5K, pump pressure up to 1400 PSI Pick up to 5,412' rotate 25 RPM 2500- 2800 TQ Work pipe from 5,412' T/5,422' set DN 10K pump pressure increase to 1400 PSI P/U turn off rotate slack off set DN 35K with no indication of shear pins shearing, acts like fill around 3 1/2" tubing, decide to circulate a sweep around and work pipe try to get down over tubing stump. 5,412.0 5,422.0 3/18/2024 16:00 3/18/2024 17:00 1.00 COMPZN, RPCOMP CIRC P Circulate 32 BBL hi vis sweep around Pump at 5 BPM 870 PSI Continue trying to get over tubing stump and shear pins with no success. Stand a stand back to 5,352' 5,422.0 5,352.0 3/18/2024 17:00 3/18/2024 17:30 0.50 COMPZN, RPCOMP OWFF P Flow check - blow down top drive 5,352.0 5,352.0 3/18/2024 17:30 3/18/2024 19:00 1.50 COMPZN, RPCOMP TRIP P POOH F/5,352' T/243' 5,352.0 243.0 3/18/2024 19:00 3/18/2024 20:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA #2 243.0 0.0 3/18/2024 20:00 3/18/2024 21:00 1.00 COMPZN, RPCOMP OWFF P OWFF while rigging down and prepping to rig up eline. 0.0 0.0 3/18/2024 21:00 3/18/2024 21:30 0.50 COMPZN, RPCOMP SFTY P PJSM W/AK E-Line for rigging up. 0.0 0.0 3/18/2024 21:30 3/19/2024 00:00 2.50 COMPZN, RPCOMP ELNE P RU AK E-line 0.0 0.0 3/19/2024 00:00 3/19/2024 03:30 3.50 COMPZN, RPCOMP ELNE P RIH W/Eline CBL to 3000' Hoist CBL to surface. 0.0 0.0 3/19/2024 03:30 3/19/2024 04:30 1.00 COMPZN, RPCOMP ELNE P RD E-line. Log sent off for final processing. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 5/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/19/2024 04:30 3/19/2024 05:15 0.75 COMPZN, RPCOMP RURD P Bring BHA #3 into pipe shed Move drill collars from off drillers side to drillers side of derrick for trip in with DP 0.0 0.0 3/19/2024 05:15 3/19/2024 05:45 0.50 COMPZN, RPCOMP BHAH P M/U BHA #3 Glock set plug T/21' 0.0 21.0 3/19/2024 05:45 3/19/2024 07:30 1.75 COMPZN, RPCOMP TRIP P RIH F/21' T/2,353' 65K UP 60K DN 21.0 2,353.0 3/19/2024 07:30 3/19/2024 07:45 0.25 COMPZN, RPCOMP MPSP P Set Glock set plug as per Baker Rotate to right and slack off until plug take weight, shut down rotary Set DN 30K on plug, pull 25K over repeat 3 times to pack off elements C.O.E. @ 2,350' 2,353.0 2,356.0 3/19/2024 07:45 3/19/2024 08:45 1.00 COMPZN, RPCOMP PRTS P R/U and flood lines test Glock to 3500 PSI F/10 min Pressure up to 3500 PSI, bleed to 2990 PSI hold for 10 min, loose 40 PSI in 10 min OA zero PSI Pump 2.8 BBLS, bleed back 2.8 BBLS Consult town attempt to retest to 3500 PSI, blled to 2790 in 2 min hold 2790 for 7 min OA zero PSI 2,356.0 2,340.0 3/19/2024 08:45 3/19/2024 09:15 0.50 COMPZN, RPCOMP RURD P Consult town about pressure test Stand one stand back T/2,282' and blow down top drive 2,340.0 2,282.0 3/19/2024 09:15 3/19/2024 09:30 0.25 COMPZN, RPCOMP PRTS P R/U to test plug to 1000 PSI Test to 1000 PSI F/10 min good test Pump .8 BBL, bleed back .8 BBL 2,282.0 2,282.0 3/19/2024 09:30 3/19/2024 09:45 0.25 COMPZN, RPCOMP RURD P Blow down lines 2,282.0 2,282.0 3/19/2024 09:45 3/19/2024 10:15 0.50 COMPZN, RPCOMP OWFF P POOH 2 stands to 2,092' Flow check - static 2,282.0 2,092.0 3/19/2024 10:15 3/19/2024 10:30 0.25 COMPZN, RPCOMP RURD P Rig up sand hopper and lines to dump sand 2,092.0 2,092.0 3/19/2024 10:30 3/19/2024 16:45 6.25 COMPZN, RPCOMP CIRC P Dump 20 sacks of sand on top of Glock set plug 2,092.0 2,092.0 3/19/2024 16:45 3/19/2024 18:30 1.75 COMPZN, RPCOMP CIRC P Keep hole fill pump running while letting sand settle out of DP and on top of G lock plug 2,092.0 2,092.0 3/19/2024 18:30 3/19/2024 18:45 0.25 COMPZN, RPCOMP TRIP P TOOH T/1700' 2,092.0 1,700.0 3/19/2024 18:45 3/19/2024 19:00 0.25 COMPZN, RPCOMP CIRC P Circ DP clean at 5BPM 1,700.0 1,700.0 3/19/2024 19:00 3/19/2024 19:15 0.25 COMPZN, RPCOMP RURD P Blow down lines and top drive 1,700.0 1,700.0 3/19/2024 19:15 3/19/2024 19:45 0.50 COMPZN, RPCOMP TRIP P TOOH F/1700' to G-lock setting adapter. 1,700.0 15.0 3/19/2024 19:45 3/19/2024 20:00 0.25 COMPZN, RPCOMP BHAH P LD G-lock setting adapter 15.0 0.0 3/19/2024 20:00 3/19/2024 20:30 0.50 COMPZN, RPCOMP PULL P Pull wear ring 0.0 0.0 3/19/2024 20:30 3/19/2024 23:00 2.50 COMPZN, RPCOMP NUND P Blow down, drain stack, pull riser and ND BOP's rack back ND DSA. 0.0 0.0 3/19/2024 23:00 3/20/2024 00:00 1.00 COMPZN, RPCOMP CUTP P Remove annulus outlets from tubing head in preparation to grow casing. RU Hydratight to casing head flange. 0.0 0.0 3/20/2024 00:00 3/20/2024 01:00 1.00 COMPZN, RPCOMP CUTP P Remove annulus outlets from tubing head in preparation to grow casing. RU Hydratight to casing head flange. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 6/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2024 01:00 3/20/2024 03:30 2.50 COMPZN, RPCOMP CUTP P Grow casing release compression in casing. total growth 26 3/4" Wait 30 min, monitor casing for growth R/D Hydro tight equipment 0.0 0.0 3/20/2024 03:30 3/20/2024 05:00 1.50 COMPZN, RPCOMP CUTP P M/U 7" casing spear Spear casing pick up to 150K on the hook, remove pack off, attempt to remove casing slips, unable to remove slips, some cement around body of slips. Slack off set slips, release spear, install pack off 0.0 0.0 3/20/2024 05:00 3/20/2024 06:00 1.00 COMPZN, RPCOMP CUTP P R/U wachs cutter, cut off excess 7" casing 0.0 0.0 3/20/2024 06:00 3/20/2024 09:00 3.00 COMPZN, RPCOMP NUND P N/U BOP, install riser, hook up all lines 0.0 0.0 3/20/2024 09:00 3/20/2024 10:00 1.00 COMPZN, RPCOMP RURD P Fill stack, flood lines Test BOP breaks and lines to 1000 PSI 0.0 0.0 3/20/2024 10:00 3/20/2024 10:45 0.75 COMPZN, RPCOMP BHAH P Bring BHA to floor M/U BHA #5 0.0 5.0 3/20/2024 10:45 3/20/2024 11:45 1.00 COMPZN, RPCOMP TRIP P RIH F/5' T/1,863' 60K UP 60K DN 5.0 1,863.0 3/20/2024 11:45 3/20/2024 12:00 0.25 COMPZN, RPCOMP CPBO P Locate casing collar at 2 BPM 180 PSI Find collar @ 1,868' set DN 5K 56K UP 56K DN Space out for cut, double check valve line up and BOP RKB's 1,863.0 1,878.0 3/20/2024 12:00 3/20/2024 12:15 0.25 COMPZN, RPCOMP CPBO P Cut 7" casing @ 1,878' - OA zero PSI Rotate 70 RPM 950 FT/LBS TQ free TQ 1.9 BPM 160 PSI 1050 FT/LBS TQ 3 BPM 400 PSI 1240 FT/LBS TQ 4 BPM 612 PSI 1360 FT/LBS TQ 4.9 BPM 879 PSI 1800 FT/LBS TQ - feed knifes 1K DN 5.4 BPM 790 PSI 1400 FT/LBS TQ, TQ drop to 1200 FT/LBS and pump PSI drop to 540 - feed knifes 1K 5.4 BPM 400 PSI 1000 FT/LBS TQ OA still zero PSI Turn off rotary pick up see 1-2K over and pump pressure up to 900 F/400 indicating knifes on cutter closed Pick up to 1,860' 1,878.0 1,860.0 3/20/2024 12:15 3/20/2024 12:30 0.25 COMPZN, RPCOMP OWFF P Flow check- static While rigging up on OA to circulate and double checking all valve line up 1,860.0 1,860.0 3/20/2024 12:30 3/20/2024 13:00 0.50 COMPZN, RPCOMP CIRC P Attempt to circulate down drill pipe and out OA to open top tank Pressure up to 1000 PSI no returns out OA Bleed off PSI, open rams, blow down top drive. Open OA up seems to have a little cement in it. 1,860.0 1,860.0 3/20/2024 13:00 3/20/2024 14:00 1.00 COMPZN, RPCOMP RURD P Lay down single, rig up head pin and circulating hoses to attempt to circulate OA and rock it PSI up to 1000 no returns, dump PSI, repeat 3 times R/D and blow down lines 1,860.0 1,860.0 3/20/2024 14:00 3/20/2024 14:30 0.50 COMPZN, RPCOMP OWFF P Flow check 1,860.0 1,860.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 7/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/20/2024 14:30 3/20/2024 15:15 0.75 COMPZN, RPCOMP TRIP P POOH F/1,860' T/5' 1,860.0 5.0 3/20/2024 15:15 3/20/2024 15:30 0.25 COMPZN, RPCOMP BHAH P Lay down MSC, pick up 7" casing spear 5.0 12.0 3/20/2024 15:30 3/20/2024 16:00 0.50 COMPZN, RPCOMP CIRC P Spear 7" casing Attempt to circulate P/U to 50K attempt to circulate PSI up to 2600 no flow out OA P/U to 75K, 100K, 125K,150K on hook, no pipe movement P/U to 175K on hook, pipe looked to move 1", attempt to circulate, PSI up 900 and casing pop free weight indicater go to 135K, pressure up 2600 PSI and pack off on spear leak by 12.0 34.0 3/20/2024 16:00 3/20/2024 16:45 0.75 COMPZN, RPCOMP RURD P Bleed off pressure, check for pressure under spear, release spear, P/U circulate thru top drive to move fluid, while discussing options 34.0 34.0 3/20/2024 16:45 3/20/2024 17:00 0.25 COMPZN, RPCOMP PULL P Reset spear grapple, spear 7" casing Pick up to 220K on hook, pipe start moving from 220K - 175K pick up 5' 1,878.0 1,873.0 3/20/2024 17:00 3/20/2024 22:00 5.00 COMPZN, RPCOMP CIRC P Circulate OA, PSI up to 2500, no returns out OA work pipe and pressure up to 2500 PSI continue to move pipe up hole attempting to break circulation PUW=220K weight broke back to 175K- 136K. Pull casing to floor. still unable to circulate. Blow down top drive. MU 5' Handling pup to spear. PU PUW=136K Continue to pick up 6' stick up above floor weight broke back to 105K. Broke circulation 1,873.0 1,841.0 3/20/2024 22:00 3/20/2024 22:30 0.50 COMPZN, RPCOMP SFTY P PJSM W/LRS 1,841.0 1,841.0 3/20/2024 22:30 3/20/2024 23:30 1.00 COMPZN, RPCOMP CIRC P RU LRS to cement line pressure test to 1500 PSI. line up LRS to pump down the DP up the OA 140* seawater. Circulate seawater at 2BPM at 140PSI. 1,841.0 1,841.0 3/20/2024 23:30 3/21/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service Iron Roughneck 1,841.0 1,841.0 3/21/2024 00:00 3/21/2024 00:30 0.50 COMPZN, RPCOMP CIRC P Completed circulating with LRS 1.5BPM at 140* 200 PSI. 1,841.0 1,841.0 3/21/2024 00:30 3/21/2024 00:45 0.25 COMPZN, RPCOMP RURD P RD LRS and suck back line to pump truck. 1,841.0 1,841.0 3/21/2024 00:45 3/21/2024 01:30 0.75 COMPZN, RPCOMP CIRC P Circulate 35 BBL's deep clean pill followed by seawater SxS at 90 SPM 5BPM 400 PSI 1,841.0 1,841.0 3/21/2024 01:30 3/21/2024 02:30 1.00 COMPZN, RPCOMP OWFF P OWFF for 30 minutes ZERO FLOW 1,841.0 1,841.0 3/21/2024 02:30 3/21/2024 03:00 0.50 COMPZN, RPCOMP RURD P Blow down lines and top drive. 1,841.0 1,841.0 3/21/2024 03:00 3/21/2024 06:00 3.00 COMPZN, RPCOMP NUND P ND BOPS, P/U pull slips, set stack back down and tighten up 1,841.0 1,841.0 3/21/2024 06:00 3/21/2024 07:30 1.50 COMPZN, RPCOMP RURD P "POOH F/1,841' 75K UP 63K DN L/D spear and cut joint Cut JT = 38.60' Cut JT = 10.47'" 1,841.0 1,841.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 8/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/21/2024 07:30 3/21/2024 11:30 4.00 COMPZN, RPCOMP PULL P POOH F/1,841' 75K UP 63K DN L/D spear and cut joint Cut JT = 38.60' Cut JT = 10.47' 1,841.0 0.0 3/21/2024 11:30 3/21/2024 13:30 2.00 COMPZN, RPCOMP RURD P R/D GBR equipment Clean and clear rig floor from trip out with 7" casing, artic pack 0.0 0.0 3/21/2024 13:30 3/21/2024 16:00 2.50 COMPZN, RPCOMP BOPE P Drain stack, set test plug, change out rubber on test plug, test BOP breaks to 3,000 PSI 10 Min, pull test plug, blow down lines, set wear ring 0.0 0.0 3/21/2024 16:00 3/21/2024 17:15 1.25 COMPZN, RPCOMP RURD P Mobilize BHA components to rig floor and pipe shed 0.0 0.0 3/21/2024 17:15 3/21/2024 18:30 1.25 COMPZN, RPCOMP BHAH P M/U BHA #7 8 1/2" mill, flex joint, 8 1/2" mill T/241' 0.0 241.0 3/21/2024 18:30 3/21/2024 19:30 1.00 COMPZN, RPCOMP TRIP P TIH with BHA F/241 T/1878' tagged set down 5K 241.0 1,878.0 3/21/2024 19:30 3/21/2024 21:30 2.00 COMPZN, RPCOMP CIRC P Circulate at 8BPM at 550 PSI 30 BBL 55 Vis deep clean pill to clean up casing. Sweep contained arctic pack and sand. 1,878.0 1,878.0 3/21/2024 21:30 3/21/2024 22:00 0.50 COMPZN, RPCOMP OWFF P OWFF while blowing down lines and top drive. 1,878.0 1,878.0 3/21/2024 22:00 3/21/2024 22:30 0.50 COMPZN, RPCOMP TRIP P TOOH W/DP F/1877' T/241' 1,878.0 241.0 3/21/2024 22:30 3/21/2024 23:00 0.50 COMPZN, RPCOMP BHAH P LD BHA 241.0 0.0 3/21/2024 23:00 3/21/2024 23:30 0.50 COMPZN, RPCOMP BHAH P MU BHA #2 rigid 8.5" Bar bell drift BHA. 0.0 254.4 3/21/2024 23:30 3/22/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service grease crown. 254.4 254.0 3/22/2024 00:00 3/22/2024 01:15 1.25 COMPZN, RPCOMP TRIP P TIH F/254' T/1878' Tagged top of casing stump set down 5K. 254.0 1,878.0 3/22/2024 01:15 3/22/2024 01:30 0.25 COMPZN, RPCOMP CIRC P Circulate BUS 1,878.0 1,878.0 3/22/2024 01:30 3/22/2024 01:45 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes 1,878.0 1,878.0 3/22/2024 01:45 3/22/2024 02:00 0.25 COMPZN, RPCOMP RURD P Blow down top drive 1,878.0 1,878.0 3/22/2024 02:00 3/22/2024 03:00 1.00 COMPZN, RPCOMP TRIP P TOOH with BHA #2 F/1878' T/254' PUW= 60K SOW=60K 1,878.0 254.0 3/22/2024 03:00 3/22/2024 04:00 1.00 COMPZN, RPCOMP BHAH P LD BHA F/254' T surface. 254.0 0.0 3/22/2024 04:00 3/22/2024 05:30 1.50 COMPZN, RPCOMP BHAH P MU Clean out BHA #9 with 8 3/8" wash over shoe T/263 0.0 263.0 3/22/2024 05:30 3/22/2024 06:30 1.00 COMPZN, RPCOMP TRIP P RIH F/263' T/1,870' 60K UP/DN 263.0 1,870.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 9/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/22/2024 06:30 3/22/2024 08:15 1.75 COMPZN, RPCOMP REAM P Wash down at 2 BPM 90 PSI Tag up at 1,868' with 5K DN, P/U pull 10K over, slack off tag same, pick up clean Wash/Ream down at 40 RPM 670 FT/LBS TQ 65K rotating weight Slack off work down to 1,877' stall rotary at 6.3K TQ P/U pull 20K over to 80K, Rotate at 70 RPM 1000 TQ, wash/ream down to 1,882.50', dress off 7" casing stump T/1,883.50' cut lip depth with 4 BPM 280 PSI, 70 RPM 1700 - 2800 TQ Dress off top of 7" casing stump F/1,878' T/1,879' Pick up turn off rotary wash over T/1,883.50', pick up slack off with no pumps to 1,883.50' cut lip[ depth, 7" casing stump at 1,879' 1,870.0 1,883.0 3/22/2024 08:15 3/22/2024 08:45 0.50 COMPZN, RPCOMP CIRC P Pump 30 BBL Hi vis sweep Circulate 8 BPM 570 PSI Once sweep out of hole Turn off pumps slack off confirm can go over 7" casing stump 1,883.0 1,883.0 3/22/2024 08:45 3/22/2024 09:15 0.50 COMPZN, RPCOMP OWFF P Stand one stand back T/1,870' Blow down top drive, flow check 1,883.0 1,870.0 3/22/2024 09:15 3/22/2024 10:30 1.25 COMPZN, RPCOMP TRIP P POOH F/1,870' T/263' 1,870.0 263.0 3/22/2024 10:30 3/22/2024 11:45 1.25 COMPZN, RPCOMP BHAH P L/D BHA #9 - clear floor 263.0 0.0 3/22/2024 11:45 3/22/2024 12:45 1.00 COMPZN, RPCOMP RURD P Pull wear ring, rig up GBR 0.0 0.0 3/22/2024 12:45 3/22/2024 15:00 2.25 COMPZN, RPCOMP PUTB P PJSM run 7" casing Run 7" HYD 563 as per detail T/1,843' 70K UP 70K DN M/U TQ = 9400 FT/LBS, TQ turn all connections 0.0 1,830.0 3/22/2024 15:00 3/22/2024 16:00 1.00 COMPZN, RPCOMP PUTB P M/U space out pups 5.84', 1.69', 5.89' T/1,843' Slack off F/1,843' T/1,881' S/O set DN 25K , P/U pull 30K over, S/O set DN 30K, P/U pull 85K over to confirm casing patch latched up 1,830.0 1,881.0 3/22/2024 16:00 3/22/2024 16:45 0.75 COMPZN, RPCOMP RURD P R/U to test casing and patch R/D GBR 1,881.0 1,881.0 3/22/2024 16:45 3/22/2024 17:00 0.25 COMPZN, RPCOMP PRTS P Pressure test 7" casing and casing patch T?2500 F/10 min 1,881.0 1,881.0 3/22/2024 17:00 3/22/2024 18:00 1.00 COMPZN, RPCOMP CIRC P Pressure up open cementer at 3150 PSI Circulate at 5 BPM 200 PSI 1,881.0 1,881.0 3/22/2024 18:00 3/22/2024 18:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes 0 Flow rate. 1,881.0 1,881.0 3/22/2024 18:30 3/22/2024 18:45 0.25 COMPZN, RPCOMP RURD P Blow down and de-energize Koomy 1,881.0 1,881.0 3/22/2024 18:45 3/22/2024 20:30 1.75 COMPZN, RPCOMP NUND P ND BOP split stack 1,881.0 1,881.0 3/22/2024 20:30 3/22/2024 21:30 1.00 COMPZN, RPCOMP HOSO P Set slips on 7" casing hang off 55K over string String weight 70K PU to 125K set slips. 1,881.0 1,881.0 3/22/2024 21:30 3/22/2024 23:00 1.50 COMPZN, RPCOMP NUND P NU BOPS 1,881.0 1,881.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 10/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/22/2024 23:00 3/22/2024 23:30 0.50 COMPZN, RPCOMP RURD P RU cement head. Loaded plug in cement head. verified correct plug with HES cement lead Ivan. Functioned plug launch valves 9 full rotations to open launcher fully. Rigged up to circulate down the 7" taking returns up the OA in cellar. 1,881.0 1,881.0 3/22/2024 23:30 3/23/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig 1,881.0 1,881.0 3/23/2024 00:00 3/23/2024 07:15 7.25 COMPZN, RPCOMP CIRC T Waiting on cementing crews to pump cement job at Doyon 142. Circulate well while waiting. 1,881.0 1,881.0 3/23/2024 07:15 3/23/2024 07:45 0.50 COMPZN, RPCOMP RURD P Cementers on location, shut down pumps blow down line to pits, spot cementers up to sub 1,881.0 1,881.0 3/23/2024 07:45 3/23/2024 08:15 0.50 COMPZN, RPCOMP SFTY P PJSM with crew and cementers on cementing 7" casing 1,881.0 1,881.0 3/23/2024 08:15 3/23/2024 08:45 0.50 COMPZN, RPCOMP CIRC P Pump 111 BBLS 140° water @ 3 BPM 175 PSI Shut down blow down line to tank, prime up cementers 1,881.0 1,881.0 3/23/2024 08:45 3/23/2024 10:00 1.25 COMPZN, RPCOMP CMNT P Perform cement job - Cement wet @ 08:47 HRS Break circulation W/5 BBLS F/CMT unit, shut in test lines to 1000/3000 PSI Pump 10 BBLS fresh water spacer with red dye @ 4 BPM 495 PSI Pump 88.5 BBLS 15.3 PPG Class G Lead CMT @ 3.5 BPM 615 PSI Drop closing plug Kick out with 5 BBLS water from cement unit Chase with 66 BBLS 8.6 PPG seawater Catch CMT @ 6 BPM 197 STKS 11.5 BBLS away, slow to 4 BPM 460 PSI Slow pump to 3 BPM for last 17 BBLS ICP = 820 FCP = 1100 PSI Bump plug @ 66 BBLS 1143 STKS, PSI up to 2600, see cementer tool close @ 2200 PSI, hold for 5 min, bleed off confirm cementer closed CIP @ 09:54 HRS 1,881.0 1,881.0 3/23/2024 10:00 3/23/2024 10:30 0.50 COMPZN, RPCOMP RURD P B/D and R/D cement head and cement lines Blow down out side lines 1,881.0 1,881.0 3/23/2024 10:30 3/23/2024 14:30 4.00 COMPZN, RPCOMP WWWH P Flush stack with rinse aid pill, drain stack and blow down lines, open lower pipe ram doors, blind flange on test spool clean out 1,881.0 1,881.0 3/23/2024 14:30 3/23/2024 15:30 1.00 COMPZN, RPCOMP NUND P Pick up BOP stack, cut 7" casing, move stack back out of the way, clean wellhead, install pack off, N/U TBG head Cut JT layed down from JT #45 = 28.97' 1,881.0 0.0 3/23/2024 15:30 3/23/2024 16:00 0.50 COMPZN, RPCOMP NUND P ND stack and rack on stump. 0.0 0.0 3/23/2024 16:00 3/23/2024 18:00 2.00 COMPZN, RPCOMP NUND P Set pack off and install tubing head. tested pack off to 3000 PSI for 10 minutes. 0.0 0.0 3/23/2024 18:00 3/23/2024 21:30 3.50 COMPZN, RPCOMP NUND P NU BOP's measure new RKB 0.0 0.0 3/23/2024 21:30 3/23/2024 22:30 1.00 COMPZN, RPCOMP RURD P RU to test BOP's set test plug Fill stack Purge lines 0.0 0.0 3/23/2024 22:30 3/23/2024 23:00 0.50 COMPZN, RPCOMP BOPE P Test BOP flange break at tubing head to 250/3500 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 11/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/23/2024 23:00 3/23/2024 23:30 0.50 COMPZN, RPCOMP RURD P Drain stack pull test plug 0.0 0.0 3/23/2024 23:30 3/24/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Grease D.W. 0.0 0.0 3/24/2024 00:00 3/24/2024 01:00 1.00 COMPZN, RPCOMP BHAH P MU BHA #10. 0.0 256.9 3/24/2024 01:00 3/24/2024 02:00 1.00 COMPZN, RPCOMP TRIP P TIH F/256.9 T/ 1850 Set down 5K wash down to 1866' Tagged PUW=60K SOW=60K 256.9 1,866.0 3/24/2024 02:00 3/24/2024 06:15 4.25 MILL P Mill out cement plug F/1866' T/1868' plug milled out continue to mill ahead T/1,886' Establish milling parmaeters 65 RPM PR=6BPM at 400PSI Free tq=850 Ft/Lbs Rot Wt=60K Drill out with 5-8K WOB,65 RPM 1050 TQ, 5 BPM 460 PSI Ream thru cementer 5 times insure clean with and with out pumps and rotary Pump 20 BBL Hi vis sweep, 8 BPM 800 PSI 1,866.0 1,886.0 3/24/2024 06:15 3/24/2024 08:00 1.75 COMPZN, RPCOMP TRIP P RIH F/1,886 T/2,233' Tag with 5-7K DN Wash ream down to 6 BPM 30 RPM 600 TQ, artic pack and fill from mill runs in the 9 5/8" come back Continue to wash/ream down clean sand from 2,288' to 2,310' 1,886.0 2,310.0 3/24/2024 08:00 3/24/2024 08:30 0.50 COMPZN, RPCOMP CIRC P Circulate 20 BBL Hi vis sweep around 8 BPM 800 PSI 2,310.0 2,310.0 3/24/2024 08:30 3/24/2024 09:00 0.50 COMPZN, RPCOMP OWFF P Blow down top drive, flow check 2,310.0 2,310.0 3/24/2024 09:00 3/24/2024 10:00 1.00 COMPZN, RPCOMP TRIP P POOH F/2,310' T/256' 2,310.0 256.0 3/24/2024 10:00 3/24/2024 11:00 1.00 COMPZN, RPCOMP BHAH P L/D BHA # 10 256.0 0.0 3/24/2024 11:00 3/24/2024 12:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #11 T/226' 0.0 226.0 3/24/2024 12:00 3/24/2024 13:00 1.00 COMPZN, RPCOMP TRIP P RIH F/226' T/2,310' Wash/ream down to 2,348' 5.7 BPM 770 PSI, 40 RPM 640 TQ 8.5 BPM 1550 PSI, 60 RPM 760 TQ Note stall out rotary @ 2,317' @ 6500 FT/LBS 226.0 2,348.0 3/24/2024 13:00 3/24/2024 14:15 1.25 COMPZN, RPCOMP CIRC P Circulate 2X Hi vis sweeps around, clean up hole @ 8.5 BPM 1550 PSI, 15 RPM 520 TQ Flow check, B/D top drive 2,348.0 2,348.0 3/24/2024 14:15 3/24/2024 15:15 1.00 COMPZN, RPCOMP TRIP P POOH F/2,348' T/226' Function test BOP 2,348.0 226.0 3/24/2024 15:15 3/24/2024 16:00 0.75 COMPZN, RPCOMP BHAH P L/D BHA # 11 Clean out RCJB, find chunks of aluminum from HES cementer in basket 226.0 0.0 3/24/2024 16:00 3/24/2024 16:15 0.25 COMPZN, RPCOMP BHAH P M/U BHA #12 RCJB T/40' 0.0 40.0 3/24/2024 16:15 3/24/2024 18:30 2.25 COMPZN, RPCOMP TRIP P RIH F/40' T/2,310' Wash DN F/2,310' T/2,348' @ 10.5 BPM 2280 PSI Pump 20 BBL Hi Vis sweep clean off top of Glock plug 40.0 2,348.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 12/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/24/2024 18:30 3/24/2024 19:00 0.50 COMPZN, RPCOMP OWFF P Flow check, blow down top drive 2,348.0 2,348.0 3/24/2024 19:00 3/24/2024 20:15 1.25 COMPZN, RPCOMP TRIP P POOH F/2,348' T/40' 2,348.0 40.0 3/24/2024 20:15 3/24/2024 20:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #12 clean out RCJB 40.0 0.0 3/24/2024 20:45 3/24/2024 21:30 0.75 COMPZN, RPCOMP BHAH P M/U BHA #13 , Glock retrieving head 0.0 11.0 3/24/2024 21:30 3/24/2024 23:00 1.50 COMPZN, RPCOMP TRIP P RIH F/11' T/2347.91' PUW=62.5K SOW=62.5K latched into plug, equalized and released. RIH 15' 11.0 2,347.9 3/24/2024 23:00 3/24/2024 23:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 2,364.0 2,364.0 3/24/2024 23:30 3/25/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig 2,364.0 3/25/2024 00:00 3/25/2024 01:00 1.00 COMPZN, RPCOMP TRIP P TOOH F/2364.91' T/11' 2,364.0 2,364.0 3/25/2024 01:00 3/25/2024 01:30 0.50 COMPZN, RPCOMP BHAH P LD retrieving tool and G-lock 11.0 0.0 3/25/2024 01:30 3/25/2024 02:00 0.50 COMPZN, RPCOMP SFTY P Safety stand down line of fire discussion reviewed last 2 weeks. 0.0 0.0 3/25/2024 02:00 3/25/2024 02:30 0.50 COMPZN, RPCOMP PRTS P RU close blinds and pressure test casing to 3000 PSI for 10 minutes. RD test equipemtn and blow down kill line. 0.0 0.0 3/25/2024 02:30 3/25/2024 03:30 1.00 COMPZN, RPCOMP BHAH P MU BHA #14 Clean out BHA 0.0 265.4 3/25/2024 03:30 3/25/2024 07:15 3.75 COMPZN, RPCOMP TRIP P TIH F/265.4 T/5,374' 115K UP 105K DN 265.4 5,374.0 3/25/2024 07:15 3/25/2024 09:15 2.00 COMPZN, RPCOMP WASH P Wash and ream down F/5,374' T/5,419' 3.5 BPM 360 PSI 60 RPM 1880 TQ Take 3-5K DN at 5,414' Clean out over TBG stump T/5,419' - 3 1/2" TBG stump @ 5,410' Dry drift over TBg stump with no rotary and no pumps 5,374.0 5,419.0 3/25/2024 09:15 3/25/2024 10:15 1.00 COMPZN, RPCOMP CIRC P Pump 30 BBL Hi vis sweep around, clean up casing 6 BPM 1480 PSI Turn off pumps slack off confirm tubing stump still cleaned off Stand one stand back T/5,374' 5,419.0 5,419.0 3/25/2024 10:15 3/25/2024 10:45 0.50 COMPZN, RPCOMP OWFF P Flow check, blow down top drive 5,374.0 5,374.0 3/25/2024 10:45 3/25/2024 14:15 3.50 COMPZN, RPCOMP PULD P POOH lay down pipe to shed F/5,374' T/265' 5,374.0 265.0 3/25/2024 14:15 3/25/2024 15:30 1.25 COMPZN, RPCOMP BHAH P L/D BHA clean clear rig floor 265.0 0.0 3/25/2024 15:30 3/25/2024 18:30 3.00 COMPZN, RPCOMP RURD P Pull wear ring, R/U GBR, load shed with 3 1/2" completion equipment 0.0 0.0 3/25/2024 18:30 3/26/2024 00:00 5.50 COMPZN, RPCOMP PUTB P PJSM, run 3 1/2" completion as per detail T/3931 0.0 3,931.0 3/26/2024 00:00 3/26/2024 02:30 2.50 COMPZN, RPCOMP PUTB P RIH with tubing F/3931 T/ tag at 5422' ORKB shear tattle tell screws obtained 3.2' of travel after shear. 3,931.0 5,422.0 3/26/2024 02:30 3/26/2024 03:45 1.25 COMPZN, RPCOMP HOSO P Space out completion. Laid down joints 172,, 171 and 170. Picked up space out pups 9.71' and 8.09' MU joint 170. RU circulating line to landing joint in mouse hole. MU Landing joint to tubing hanger. 5,422.0 5,394.0 3/26/2024 03:45 3/26/2024 04:00 0.25 COMPZN, RPCOMP THGR P MU tbg hanger to string. 5,394.0 5,394.0 Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Page 13/13 3F-14 Report Printed: 4/22/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/26/2024 04:00 3/26/2024 05:00 1.00 COMPZN, RPCOMP CIRC P Circulate down the tubing taking returns up the IA 3 BPM 200 PSI 5,394.0 5,394.0 3/26/2024 05:00 3/26/2024 05:30 0.50 COMPZN, RPCOMP HOSO P Land tubing hanger RILDS. 5,394.0 5,425.7 3/26/2024 05:30 3/26/2024 05:45 0.25 COMPZN, RPCOMP PACK P Drop ball and rod wait for rod to fall for 15 minutes. Pressure up to 3500 PSI for 30 minutes. 5,425.7 5,425.7 3/26/2024 05:45 3/26/2024 07:00 1.25 COMPZN, RPCOMP PRTS P Pressure test tubing to 3500 PSI for 30 minutes. Bleed tubing pressure back to 1500 PSI. Pressure up on IA to 3500 PSI for 30 mintues. (good test). 5,425.7 5,425.7 3/26/2024 07:00 3/26/2024 08:00 1.00 COMPZN, RPCOMP PRTS P Trap 1,500 psi on tubing, P/T IA T/3.000 psi, 30 min, (good test), Dump tubing to shear SOV. Set BPV, test 1,000 psi down the the IA, (good test) 5,425.7 0.0 3/26/2024 08:00 3/26/2024 14:00 6.00 COMPZN, RPCOMP SVRG P Perform BWM Lower rams swap back to 3.5"x5.5" Variables 0.0 0.0 3/26/2024 14:00 3/26/2024 15:15 1.25 COMPZN, WHDBOP NUND P N/D BOPE 0.0 0.0 3/26/2024 15:15 3/26/2024 16:45 1.50 COMPZN, WHDBOP NUND P Set BP BPV test dart. N/U adapter and production tree. Test void 5,000 psi. (good test). 0.0 0.0 3/26/2024 16:45 3/26/2024 17:15 0.50 COMPZN, WHDBOP NUND P M/U flange to wing valve, R/U to test tree and freeze protect well 0.0 0.0 3/26/2024 17:15 3/26/2024 20:00 2.75 COMPZN, WHDBOP RURD T Tree not configured properly. Broke down tree realigned configuration to correct the issues. 0.0 0.0 3/26/2024 20:00 3/26/2024 20:30 0.50 COMPZN, WHDBOP NUND P LRS on location, MIRU. pressure test surface lines to pump unit. 0.0 0.0 3/26/2024 20:30 3/26/2024 20:45 0.25 COMPZN, WHDBOP PRTS P Pressure test tree to 5000 PSI. 0.0 0.0 3/26/2024 20:45 3/26/2024 21:15 0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV. install tree cap. 0.0 0.0 3/26/2024 21:15 3/26/2024 22:15 1.00 COMPZN, WHDBOP CIRC P Circulate 70 BBL's diesel down the IA taking returns up the tubing 3 BPM at 400 PSI. 0.0 0.0 3/26/2024 22:15 3/26/2024 23:00 0.75 COMPZN, WHDBOP RURD P RD LRS. Blow down line to tiger tank. U -tube well for 1 hour. 0.0 3/26/2024 23:00 3/26/2024 23:30 0.50 COMPZN, WHDBOP DMOB P Prejob to move hook trucks up to pits. pull pits away from sub base. 3/26/2024 23:30 3/27/2024 00:00 0.50 DEMOB, MOVE SVRG P Service rig Rig: NABORS 7ES RIG RELEASE DATE 3/27/2024 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig, Set DMY. Pull B&R, RHC. Set plug w/ gauges. 3F-14 4/10/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Leak detected @ CMU SLEEVE @ 6496' 6/28/2010 lmosbor NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 11/18/1996 triplwj 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 38.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 37.0 3,063.6 3,063.5 36.00 J-55 BTC 7" Tie-Back String workover 2024 7 6.28 35.0 1,889.8 1,889.7 26.00 L-80 HYD 563 PRODUCTION 7 6.28 35.0 6,878.0 6,256.7 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 5,425.7 String Max No… 3 1/2 Set Depth … 5,127.1 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 Nabors 7ES RKB = 24.38' ORKB Doyon 9 RKB = 33.25' Diff = 8.87' 33.3 33.2 0.06 Hanger 7.000 3.5" FMC Gen 4 tubing hanger - H- BPV - EUE Lift threads FMC GEN IV 2.910 5,305.4 5,032.3 37.94 Mandrel – GAS LIFT 5.955 3.5" SLB MMG mandrel SLB MMG 2.920 5,362.9 5,077.6 38.00 Packer 6.276 3.5" x 7" SLB Blue max packer Vam Top x Vam Top S#CP23P-0228 SLB 1030584 59 2.885 5,398.5 5,105.6 38.04 Nipple - X 4.501 3.5" Halliburton 2.81" X nipple HALLIB URTON 2.81" X 2.810 5,418.8 5,121.6 38.11 Overshot 6.000 Baker 6" OD x 3.58" ID Non sealing overshot Spaced out 2.8' off fully located. Baker Non sealing 3.600 Top (ftKB) 5,422.0 Set Depth … 6,531.4 String Max No… 3 1/2 Set Depth … 5,987.9 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection AMB-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.8 5,137.3 38.19 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR 5.875 BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY 5.000 BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,283.5 5,796.2 39.39 PRODUCTION 6.018 CAMCO MMM 2.920 6,328.9 5,831.3 39.42 BLAST RINGS 4.500 BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C 3.500 BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing 3.500 CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.2 5,968.4 39.18 LOCATOR 3.975 TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY 3.237 TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.2 39.18 PACKER 5.813 TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE 4.480 SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE 2.875 CAMCO D NIPPLE NO GO 2.250 6,530.6 5,987.4 39.19 SOS 3.686 BAKER SHEAR OUT SUB 1.484 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) 6,496.0 5,960.5 39.19 LEAK C sand leak found on LDL. 6/28/2010 0.000 6,522.0 5,980.7 39.19 TUBING PLUG Set 2.25" CA2 plug, soft set & dual gauges (OAL 77") 4/9/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,305.4 5,032.3 37.94 1 GAS LIFT DMY RK 1 1/2 0.0 4/8/2024 0.000 6,283.5 5,796.2 39.39 2 INJ DMY RK 1 1/2 0.0 10/19/1999 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,875.2 1,875.1 0.35 Collar - Stage 8.240 CMTR,TYPE H ES-II, HYD 563 L-HES II 102463867 4.370 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 PACKER; 6,508.6 LEAK; 6,496.0 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.5 Nipple - X; 5,398.5 Packer; 5,362.9 Mandrel – GAS LIFT; 5,305.4 SURFACE; 37.0-3,063.6 7" Tie-Back String workover 2024; 35.0-1,889.8 Intermediate String 1 Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 Hanger; 33.3 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 PACKER; 6,508.6 LEAK; 6,496.0 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.5 Nipple - X; 5,398.5 Packer; 5,362.9 Mandrel – GAS LIFT; 5,305.4 SURFACE; 37.0-3,063.6 7" Tie-Back String workover 2024; 35.0-1,889.8 Intermediate String 1 Cement; 35.0 ftKB CONDUCTOR; 38.0-115.0 Hanger; 33.3 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:7ES DATE: 3/17/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1852920 Sundry #323-569 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2518 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T90 FP Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 7"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3050 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)15 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)102 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1100 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2050 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 30 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:8.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-14-24 2:48PM Waived By Test Start Date/Time:3/16/2024 19:30 (date) (time)Witness Test Finish Date/Time:3/17/2024 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Tested with 3 1/2", 4" & 7" test Joints. Annular tested on 3 1/2" & 7" test jnts. Fail /Pass on 3 1/2" jnt. Functioned retest good. All alarms tested. Kelly Cozby/MatthewTurcotte ConocoPhillips Dusty Pickworth/ Mark Adams KRU 3F-14 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022) 2024-0317_BOP_Nabors7ES_KRU_ 3-17-24 9 9 9 99 9 9 9 9 9 9 9 9 -5HJJ FP Annular Fail /Pass Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 185 -2 92 3F Ͳ14 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6975'2518 None Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:James Ohlinger Contact Email: Contact Phone: 907-265-6312 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng None6697' 6116' 11/8/2023 4"x3-1/2"-2.875" Packer: P2P Upper Patch Packer: P2P Lower Patch Packer: Baker FHL Retrievable Packer: Baker FB-1 Permanent Packer: TIW SS Permanent SSSV: CAMCO TRDP-4A 6878' Perforation Depth MD (ft): 6336-6442' 6348-6390' 6594-6618' 6596-6616' 6637-6680' 6843' 5837-5919' 5846-5879' 6037-6055' 6038-6054' 6070-6103' 6257'7" 16" 9-5/8" 77' 3027' 115' 3064' 115' 3064' J-55 TVD Burst 6531' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025632 185-292 P.O. Box 100360, Anchorage, AK 99510 50-029-21500-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 5404'MD/5110'TVD Packer: 5435'MD/5134'TVD Packer: 5460'MD/5154'TVD Packer: 6224'MD/5750'TVD Packer: 6509'MD/5970'TVD SSSV: 1797'MD/1797'TVD Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length KRU 3F-14 Other: Replace Tubing N/A Kuparuk River Field james.j.ohlinger@conocophillips.com CTD/RWO Drilling Engineer Size Kuparuk Oil Pool 6332' Plugs (MD): Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:55 pm, Oct 17, 2023 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2023.10.17 10:35:37-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger 323-569 VTL 11/9/2023 DSR-10/19/23SFD 10/19/2023 BOP test to 3500 psig Annular preventer test to 2500 psig 10-404X XX *&:JLC 11/15/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:59:57 -09'00'11/15/23 RBDMS JSB 111623 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 10, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3F-14 (PTD# 185-292). Well 3F-14 was drilled and completed in December of 1985 by Doyon 9 as a Producer into the C & A-sands. The well was worked over in 1996. The selective (C-sand) will be cement squeezed, and OA barriers replaced to allow for WAG injection. This will include a full subsidence repair on the 7" casing. If you have any questions or require any further information, please contact me at +1-907-229-3338. James J Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells 3F-14 RWO Procedure Kuparuk Injector RWO PTD #185-292 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests 2. Lockout SSSV 3. SBHP 4. Open lowest GLM in upper completion and straddle, dummy valves in remaining GLM 5. MIT-IA to 2500 psi 6. Pull P2P Patch (5404-5435’), and pull half patch (6495’-6525’) 7. Set Composite bridge plug in tubing tail 8. Perforate tubing in C-sand straddle 9. Cement squeeze the C-sand straddle 10. Cut the tubing at ~5422’ RKB in the middle of the 31’ joint above the DS Nipple. Rig Work MIRU 1. MIRU Nabors 7ES on 3F-14 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4” x 3-1/2” tubing down to the cut ~5422’ RKB Cleanout Run 6. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary. 7” Surface Casing Subsidence Repair 7. RU E-line: Run caliper & RCBL and log from ~5400’ MD back to surface. Confirm top of cement behind 7” casing; Estimated TOC ~ 4930’ MD (SLB CET Log 01/07/86) 8. Set RBP below TOC, pressure test or perform 30 min NFT, dump 50’ of sand on top of RBP. The tubing will be plugged off with cement from the straddle C-sand squeeze. 9. RIH with multistring cutter on DP, cut 7” casing above the TOC, POOH and stand back DP 10. Circulate out the Arctic Pack from the OA 11. ND BOPEs, ND tubing head using Hydratight, NU BOP to the casing head a. Can not retest the BOPE at this point. Retest flange break once casing is recovered 12. Spear the 7” casing. POOH and lay down the 7” casing 13. RIH w/ tandem string mills to gauge the 9-5/8” casing for the ES cementer & Sealing Overshot 14. RU casing crew and RIH w/ new 7” casing, ES Cementer, and Sealing Overshot, PT casing to 2500 psi 15. RU cementer and cement 7” x 9-5/8” annulus to surface 16. ND BOPE, pull 7” casing in tension and land in the slips. Cut excess 7” casing with Wachs cutter. 17. NU new tubing head and BOP stock. PT BOPs 18. RIH w/ 6-1/8” bit/mill to TOC, mill through cement. POOH standing back drillpipe. 19. Pressure test the casing to 2500 psi, chart for 30 minutes 20. RIH w/ wash string assembly and circulate out sand on top of RBP. POOH standing back drillpipe. 21. Pull RBP Page 1 of 4 3F-14 RWO Procedure Kuparuk Injector RWO PTD #185-292 Page 2 of 4 Install 3-½” Tubing Injection String 22. MU 3 ½” completion with poorboy overshot, packer, nipples, and GLMs. RIH to tubing stub 23. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 24. Pressure test tubing to 3,000 psig for 5 minutes. 25. Pressure test inner annulus to 2,500 psig for 30 minutes on chart. ND BOP, NU Tree 26. Confirm pressure tests, then shear out SOV with pressure differential. 27. Install BPV. 28. ND BOPE. NU tree. PT tree. 29. Pull BPV, freeze protect well, and set BPV if necessary. 30. RDMO. Post-Rig Work 31. Swap out SOV with a DV. 32. Mill out cement retainer, cement and composite bridge plug. General Well info: Wellhead type/pressure rating: FMC Gen IV (5000 psi) Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 11/08/23 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig tubing cut. Install a new 7” casing to regain all OA needed for WAG injection. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, known tubing leak ~5419’ MD MIT-IA Passed 2/12/23 CMIT-TxIA Passed 7/8/21 IC POT &PPPOT PASSED – 5/11/21 TBG POT & PPPOT PASSED – 5/11/21 MPSP: 2518 psi using 0.1 psi/ft gradient Static BHP: 3107 psi / 5886’ TVD measured 8/24/2010 3F-14 RWO Procedure Kuparuk Injector RWO PTD #185-292 Page 3 of 4 Estimated Cement Top ~ 4930 Camco TRDP-4A SSV @ 1797' MD (3.312" min ID) 4" x 3-1/2" XO @ 4958' RKB 3-1/2" Camco gas lift mandrels @ 2526', 3459', 4303', 5088', 5393' RKB 3-1/2" Camco DS landing nipple @ 5439' MD (2.812" min ID) Baker 3-1/2" PBR @ 5446' MD (3" ID) Baker FHL packer @ 5460' MD (2.89" ID) Baker EBH-22 Seal Assy. @ 6224' RKB Baker FB-1 Permanent Packer @ 6224' RKB Baker SBE @ 6228' RKB 3-1/2" Camco gas lift mandrels @ 6284' Blast Rings 4 joints w/ 116' of rings Baker CMU Sliding Sleeve @ 6496' RKB (Closed 5/20/09) 3-1/2" x 2-7/8" XO @ 6505' RKB TIW Locator @ 6506' RKB (2.507" ID) TIW Seal Assy @ 6508' RKB TIW SS Permanent Packer @ 6509' RKB SBE @ 6512' RKB Camco D landing nipple @ 6523' RKB (2.25" min ID, No-Go) Baker SOS @ 6531' RKB (1.484" ID) 9-5/8" 36# J-55 shoe @ 3064' MD 7" 26# J-55 shoe @ 6878' MD 16" 62# H-40 shoe @ 115' MD A-sand perfs 6594' - 6680' MD C-sand perfs 6336' - 6390' MD Tubing Leak @ 5419' MD Casing Leak @ 74' MD Upper 2 packers isolate 2 joints of casing at 5526'-5614' WLM with corrosion holes Planned tubing cut ~5422' RKB P2P Patch Upper Packer ~5404' MD Lower Packer ~5435' MD Half Patch Top ~6495' MD Bottom ~6525' MD 3F-14 RWO Procedure Kuparuk Injector RWO PTD #185-292 Page 4 of 4 Estimated Cement Top ~ 4930' MD SLB CET Log 01/07/86 3-1/2", 9.3#, L-80 Hyd563 Tubing to surface MMG GLV ~ 5304' RKB w/ DV SLB BluPack Packer ~5381' RKB D-landing nipple @ 5411' RKB (2.750" min ID) Non-Sealing Overshot ~5422' RKB REMAINING COMPLETION LEFT IN HOLE Baker 3-1/2" PBR @ 5446' MD (3" ID) Baker FHL packer @ 5460' MD (2.89" ID) Baker EBH-22 Seal Assy. @ 6224' RKB Baker FB-1 Permanent Packer @ 6224' RKB Baker SBE @ 6228' RKB 3-1/2" Camco gas lift mandrels @ 6284' Blast Rings 4 joints w/ 116' of rings Baker CMU Sliding Sleeve @ 6496' RKB (Closed 5/20/09) 3-1/2" x 2-7/8" XO @ 6505' RKB TIW Locator @ 6506' RKB (2.507" ID) TIW Seal Assy @ 6508' RKB TIW SS Permanent Packer @ 6509' RKB SBE @ 6512' RKB Camco D landing nipple @ 6523' RKB (2.25" min ID, No-Go) Baker SOS @ 6531' RKB (1.484" ID) 9-5/8" 36# J-55 shoe @ 3064' MD 7" 26# J-55 shoe @ 6878' MD 16" 62# H-40 shoe @ 115' MD A-sand perfs 6594' - 6680' MD C-sand perfs 6336' - 6390' MD BOT 2-7/8" Composite plug to be milled post RWO Casing Leak @ 74' MD Upper 2 packers isolate 2 joints of casing at 5526'-5614' WLM with corrosion holes PBR ~ 5446' RKB Planned tubing cut ~5422' RKB SLB BluPack ~ 5381' RKB Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Patch 5404'-5435' RKB (ME to ME) 7/8/2021 3F-14 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,404.0 5,110.0 38.06 PACKER - PATCH - UPR P2P Upper Patch Packer (ME 5404' RKB) (pkr/spacer pipe/anchor latch OAL 31.82') 7/8/2021 1.625 CPP35212 5,405.0 5,110.8 38.06 ANCHOR LATCH Spacer Pipe & Anchor Latch 7/8/2021 1.600 CPAL35092 5,419.0 5,121.8 38.11 LEAK - TUBING LEAK IDENTIFIED BY EL LDL 5/30/2021 2.992 5,435.0 5,134.4 38.17 PACKER - PATCH - LWR P2P Lower Patch Packer (ME 5435' RKB) (OAL 4.01') 7/7/2021 1.625 CPP35263 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT EXT PKG DMY RK 0.000 0.0 5/26/2021 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 3F-14, 7/9/2021 10:03:53 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 7/9/2021 10:03:54 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD 3F-14 ... WELLNAME WELLBORE3F-14 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Coberly, Jonathan To:Loepp, Victoria T (OGC) Cc:Ohlinger, James J; Hobbs, Greg S; Taylor, Jenna Subject:RE: [EXTERNAL]FW: KRU 3F-08(PTD 185-246, Sundry 323-570); KRU 3F-14(PTD 185-292, Sundry 323-569) Date:Wednesday, November 1, 2023 4:20:09 PM Victoria, Thanks for reaching out with your questions. 3F-08 & 3F-14 A similar idea has been discussed in prior conversations on other projects, but we have ultimately chosen other options like what is proposed on these wells. With the full subsidence style repair techniques outlined in the applications, we are wanting to get cement in that annuli to support the damaged surface casing. A casing patch could in theory be successfully installed in some cases where milling was minimal, but that doesn’t usually occur and I would call into question longevity of the repair with an expandable patch in a subsided zone that wasn’t supported to the best of our ability with cement. We believe the outlined subsidence repair method is the best available method to repair the issues in these wells. Jonathan Coberly | CTD/RWO Engineering Supervisor | ConocoPhillips Alaska O: 907-265-1013 | C: 907-538-8398 | 700 G Street, Anchorage AK, 99501 (ATO-678) From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, November 1, 2023 9:59 AM To: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]FW: KRU 3F-08(PTD 185-246, Sundry 323-570); KRU 3F-14(PTD 185-292, Sundry 323-569) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Loepp, Victoria T (OGC) Sent: Wednesday, November 1, 2023 9:43 AM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: KRU 3F-08(PTD 185-246, Sundry 323-570); KRU 3F-14(PTD 185-292, Sundry 323-569) James, Have you considered running an expandable patch/liner to repair the surface casing leaks? This allows for a monitorable OA on these two injectors. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-14 (PTD 185-292) Update and shut in well Date:Tuesday, March 28, 2023 8:57:58 AM Attachments:AnnComm Surveillance TIO for 3F-14.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 27, 2023 2:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3F-14 (PTD 185-292) Update and shut in well Chris, KRU 3F-14 (PTD 185-292) has continued to exhibit unexplained IA pressure increase during the extended monitor period. The well will be shut in and freeze protected as soon as possible. After which the well will be secured and diagnostics will begin. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 3F-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3F-14 2023-02-19 450 200 -250 IA 3F-14 2023-02-21 600 50 -550 IA 3F-14 2023-02-23 700 400 -300 IA 3F-14 2023-02-25 660 400 -260 IA 3F-14 2023-02-28 680 350 -330 IA 3F-14 2023-03-10 950 250 -700 IA 3F-14 2023-03-10 800 300 -500 IA 3F-14 2023-03-11 700 200 -500 IA 3F-14 2023-03-14 850 300 -550 IA 3F-14 2023-03-15 850 150 -700 IA 3F-14 2023-03-15 800 200 -600 IA 3F-14 2023-03-19 929 155 -774 IA 3F-14 2023-03-19 591 29 -562 IA 3F-14 2023-03-22 860 1 -859 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Patch 5404'-5435' RKB (ME to ME) 7/8/2021 3F-14 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,404.0 5,110.0 38.06 PACKER - PATCH - UPR P2P Upper Patch Packer (ME 5404' RKB) (pkr/spacer pipe/anchor latch OAL 31.82') 7/8/2021 1.625 CPP35212 5,405.0 5,110.8 38.06 ANCHOR LATCH Spacer Pipe & Anchor Latch 7/8/2021 1.600 CPAL35092 5,419.0 5,121.8 38.11 LEAK - TUBING LEAK IDENTIFIED BY EL LDL 5/30/2021 2.992 5,435.0 5,134.4 38.17 PACKER - PATCH - LWR P2P Lower Patch Packer (ME 5435' RKB) (OAL 4.01') 7/7/2021 1.625 CPP35263 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT EXT PKG DMY RK 0.000 0.0 5/26/2021 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 3F-14, 7/9/2021 10:03:53 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 7/9/2021 10:03:54 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD 3F-14 ... WELLNAME WELLBORE3F-14 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-14 (PTD 185-292) Update and monitor extension Date:Thursday, March 2, 2023 1:59:33 PM Attachments:AnnComm Surveillance TIO for 3F-14.pdf MIT KRU 3F-14 02-12-23.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, March 2, 2023 1:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3F-14 (PTD 185-292) Update and monitor extension Chris, KRU 3F-14 (PTD 185-292) As per the previous email 3R-14 is under monitor after being converted to injection. The well was BOI February 2, 2023 and passed as SW MITIA on February 12, 2023. Subsequent the SW MITIA the IA was left fluid packed and multiple bleeds were performed on the IA. The bleeds are believed to be a thermal expansion reaction and not AnnComm, but to ensure the IA maintains integrity prior to submitting the AA application we plan to extend the monitor period an additional 30 days. The well is currently offline for an S-riser repair, once the S-riser has been reset and the well is back online DHD will mobilize to the well to bleed fluid off the IA and install a gas cap after which an additional 30 day monitor will be started. Once the monitor period has been completed CPAI intends to apply for an administrative approval for continued water injection only due to the known surface casing leak at 74’. TIO trend, schematic, and 10-426 attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3F-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3F-14 2023-02-19 450 200 -250 IA 3F-14 2023-02-21 600 50 -550 IA 3F-14 2023-02-23 700 400 -300 IA 3F-14 2023-02-25 660 400 -260 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Patch 5404'-5435' RKB (ME to ME) 7/8/2021 3F-14 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,404.0 5,110.0 38.06 PACKER - PATCH - UPR P2P Upper Patch Packer (ME 5404' RKB) (pkr/spacer pipe/anchor latch OAL 31.82') 7/8/2021 1.625 CPP35212 5,405.0 5,110.8 38.06 ANCHOR LATCH Spacer Pipe & Anchor Latch 7/8/2021 1.600 CPAL35092 5,419.0 5,121.8 38.11 LEAK - TUBING LEAK IDENTIFIED BY EL LDL 5/30/2021 2.992 5,435.0 5,134.4 38.17 PACKER - PATCH - LWR P2P Lower Patch Packer (ME 5435' RKB) (OAL 4.01') 7/7/2021 1.625 CPP35263 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT EXT PKG DMY RK 0.000 0.0 5/26/2021 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 3F-14, 7/9/2021 10:03:53 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 7/9/2021 10:03:54 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 Down Squeeze; 6,336.0 ftKB IPERF; 6,336.0-6,442.0 RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 NIPPLE; 5,438.8 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD 3F-14 ... WELLNAME WELLBORE3F-14 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 31, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-14 KUPARUK RIV UNIT 3F-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/31/2023 3F-14 50-029-21500-00-00 185-292-0 W SPT 5750 1852920 3000 925 925 925 925 0 0 0 0 INITAL P Austin McLeod 2/12/2023 MITIA. Sundry 322-557. Injector conversion. Tested to MAIP for future AA Application. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-14 Inspection Date: Tubing OA Packer Depth 350 3300 3240 3240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230212192009 BBL Pumped:1.6 BBL Returned:1.6 Friday, March 31, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 MITIA. Sundry 322-557. James B. Regg Digitally signed by James B. Regg Date: 2023.03.31 13:39:39 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Kayla Junke at 10:07 am, Mar 24, 2023 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well ❑ Coiled Tubing Ops ❑ Other: Convert to WINJ ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 185-292 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-029-21500-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 KRU 3F-14 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): NIA Ku aruk River Field/ Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6975' feet Plugs measured None feet true vertical 6332' feet Junk measured None feet Effective Depth measured feet Packer measured 5404', 5435, 5460', feet 8897' 6224', 6508' true vertical feet true vertical 5110', 5134, 5154', feet 8118' 5750', 5970' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 115, 115, Surface 3027' 9-5/8" 3064' 3063' Intermediate Production 6843' 7" 6878' 6257' Liner Perforation depth Measured depth 6336-6442', 65946618', 6637-6580' True Vertical depth 5837-5919', 6036-6055', 6070-6103' Tubing (size, grade, measured and true vertical depth) 4" x 3-1/2" x 2-7/8" J55 6531' MD 5988' TVD Packers and SSSV (type, measured and true vertical depth) Packer: P213 Patch Packer 5404' MD 5110' TVD Packer: P213 Patch Packer 5435' MD 5134' TVD Packer: Baker FHL Rtrvbl Packer 5460' MD 5154' TVD Packer: Baker FBA Perm Packer 6224' MD 5750' TVD Packer: TIW SS Perm Packer 6509' MD 5970' TVD SSSV: Camoo TRDP4A Sfty Vlv 179T MD 1797' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 1 0 0 1 84 1 3 Subsequent to operation: INJECTOR — 3100 1 600 983 13b. Pools active after work: 14. Attachments (required Per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑+ Exploratory ❑ Development ❑ Service ❑' Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 1K Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data L GSTOR ❑ WINJ ❑' WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Digitally signed by Lynn 322-557 Aleshire Authorized Name and Lynn A es Ire Date: 2023.03.2408:36:57 Digital Signature with Date: -08100' Contact Name: Lynn Aleshire Contact Email: Ivnn.aleshirelk8conocoohillios.com Authorized Title: Surveillance Reservoir Engineer Contact Phone: (907) 265-6525 Sr Pet Eng: ISr Pet Geo: I I Sr Res Eng: RBDMS JSB 033023 Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3F-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Ifor water injection with SC leak @ 74'. 02/02/23 Well brought on injection 02/09/231 Purged OA with N2. MIT -IA PASS to 3300 psi 02/12/231 State witnessed (Austin McLeod) MIT -IA PASSED to 1820 psi. 02/28/23 Shut in and FP for S-riser rpair 03/09/23 BOL 03/02/231 Conclusion of 30-day monitoring period. Notify State of 2nd 30-day monitoring period. KUP INJ WELLNAME 3F-14 WELLBORE 3F-14 Gmisio 0�lllllp5 Alaska, Inc. ��nrry SAFETY FLOAT IPERF 6.W7.De,addi FLOAT Well Attributes I Max AngleB MD TO Fled Name WNIbore APWWI Wellhore Statue Ies" K PAR KRIVER NIT 221 IN 9.78 MD umBI 4,600.00 MBtm man, 6,975.0 Comment X3a 1ppm) Date TR�PIas( MmiNicn WO: End DNe 1011]1199fi KBGre(D) 41.88 RR Date 12/251198 OIM1et Ekv... Annotation Depth pass) 1 WNlbore End Dole Last Mad By Last Tag: SLM 6,69]A 3F-14 Tat'st09 eiplwj Last Rev Reason Annotation WeIINrt End Dole Last Mod By Rev Reason: Patch 5404'-5435RKB(ME to ME) 3F-14 P812021 spilch Notes: General 3 Safety Penetration End D. Lint Mod By NOTE: View Schematic of Alaska Schematic9.0 ➢20/2010 unam NOTE: Leak detected @ CMU SLEEVE @ 6496' N28I2010 Imosbor NOTE'. Leak Detected In TBG below CMU @ 64955 (See WSR 11I1819fi) 11118119 an mp"M Casing Strings Ceg Dee OD (in) ID I1nI mpinKln set Dept' set (moan (WD)Dfe=) Deem WIMn(l WIN Grade Topmrcaa CONDUCTOR 16 15.06 "0 115.0 115.0 6258 H-40 WELDED SURFACE 9518 8.92 3L0 3,063.E 3,Ofi3.5 36.00 JSS BTC PRODUCTION 'I 6.28 I 35.0 I 6,8T8A I 62567 I 26.00 I J-55 IFIU Tubing Strings: string max indicates LONGEST segment of string Toppmllg stl DeptM1... set D.Mai string Me... Tubing Description W geed) codeTop comeard" ID (in) 33.3 6,531.4 5,9880 4 TUBING W04'.3.5's2.8]5' 10.90 J-55 ABM-BTC 3.42 Completion Details: excludes tubing, pup, space out, thread, RK13... Topusts) Top IIVD) (PIKE) Tap Intl ('I hem Dec oD Nominal (in) tom Make Model Nominal ID IIn) 33.3 33.2 0.06 HANGER 8.000 FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETYVLV 6.100 CAMCO TRDP4A SAFETY VALVE 3.312 2,525.6 2,525.5 0.12 GAS LIFT 5.898 CAMCO KBMG 3.395 3,458.5 3.457.2 8.94 GAS LIFT 5.898 CAMCO KBMG 3.395 4,303.2 4,245.8 32.51 GAS LIFT 5.998 CAMCO KBMG 3.395 4,957.8 4,759.7 38.61 XO Reducing 4.000 CROSSOVER 4 K 3112 3.500 5,088.2 4.861.6 38.53 GAS LIFT 5790 OTIS LBX 2.920 5,393.0 5.101.4 38.03 GAS LIFT 5.968 CAMCO MMG 2.920 5,438.8 5,137.3 38.19 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR 5.875 BAKER PBR 3.000 5,459.6 5.1537 38.27 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5749.8 39.27 SEALASSY 5.000 BAKER EBH-22 SEALASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,031.3 39.42 BINST RINGS 4.500 BINST RINGS (4) 2.867 6,495.5 5.960.1 39.19 SLEEVE-0 3.500 BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 512012009 2750 6,505.4 5,967.8 39.18 XO Reducing 3.500 CROSSOVER 312 K 27/8 61506.3 5.968.5 39.18 LOCATOR 3.975 Third LOCATOR 6,50].6 5.969.5 39.18 SEALASSY 3.237 TIW SEAL ASSEMBLY 6,508.E 5,970.3 39.18 PACKER 5.813 TIW SS PERMANENT PACKER 85ll.6 5,972.6 39.18 SEE 4,480 SEAL BORE EXTENTION J2.250 6522.8 5,981.3 39.19 NIPPLE 2.875 CAMCO D NIPPLE NO GO 6530.] 5,987.4 39.19 SOS 3.686 BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top MKE) Top (ND) PRO) Topind(') Dea Com Make Model sN Run DeR 5d04.0 5,110.0 38.06 PACKER- PATCH -ORR P2P Upper Patch Packer (ME 5404' PKE)(pkrlspacer pipelanc'or latch DAL 31.821 CPP3 5212 702021 1.625 5.405.0 5,110.8 38.06 ANCHOR CATCH Spacer Pipe B Anchor Latch CPAL 35092 7/812021 1.600 5.419.0 5,121.8 38.11 LEAK- TUBING LEAK IDENTIFIED BY EL LDL WW2021 2.992 5.435.0 5,134.4 38.17 PACKER- PATCH -LWR Pi Looser Patch Packer(ME 5435' RKB)(OAL 4.0l') CPP3 5263 7O12021 1.625 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER -D' NIPPLE @ 6522' - SET ON 2.75" 04-OCK, SPACER PIPE 8 22V SEAL STINGER', O1 MIN. ID= 1.49" 11/612010 1.490 Mandrel Inserts : excludes pulled inserts Top pi Top PVD) Page) and ati Top on Incl I-) Na eery Vale Ty Fe tam Type OD (In) TRO Run ("I) Run Date Cam Make Model post Sachs) 2,525.6 2,525.5 0.12 1 GAS LIFT DMY BK 1 0.0 1119/2003 0.000 3,458.5 3,457.2 8.94 2 GAS LIFT DMY BK 1 0.0 1119/2003 0.000 4,303.2 4,245.8 32.51 3 GAS LIFT DMY BK 1 0.0 111912003 0.000 5,088.2 4,861.6 38.53 4 GAS LIFT DMY RA 11/2 0.0 10/19/1996 0.000 5,393.0 5,101.4 38.03 5 GAS LIFT EXT FOG DMY RK 11/2 0.0 W612021 0.000 0,283.5 5,796.2 39.39 6 PROD DMY RK 1112 0.0 1011911999 0.000 KUP INJ WELLNAME 3F-14 WELLBORE 3F-14 Conoc6Phillip5 Alaska, Inc. .ate 3110, 3I2LA230: le 1a PM aepfonatlens Bt Slots VwlmaoM1emetlapwu9 Top (TND) BanME)Den¢ aaol Top IDKBI Bim (M(B) g836 (nKBI Zone Dale Ian Type Oom HANGER, a3a 6,338.0 6,442.0 5,838.8 5,918J ,UnkeJ3F-1 C-0, 3F-14 211I1988 12.0 12.0 IPERF 120°Dh: 5"Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 G-4,3F-14 10/1411996 5.0 WERE 50° phasing; 41Z 51B Hyper Jet HnxcER', 3l.B-H 6,594.0 6,618.0 6,036.5 6,055.0 A-3,3F-14 01811992 6.0 APERF Zero deg. phasing; 2118"TT c..DLCTOR: 39.0.1is:o 6,596.0 6,616.0 6,038.0 6,053.5 A-3,3F-14 542811996 4.0 WERE 113V phasing; 211W EnerJet BFFETY V'; 1,7R.0 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2I1I1986 4.0 IPERF 90°ph; 4"Csg Gun Cement Squeezes Top IWD) BOB (TVD) Pomp Ben GAS JFH 25aaa Top InKBI B1m (nKEn InAS) (.KB) Gea COm ogre 6,336.0 6A420 5,836.E 5,918J Dovm FLOATCOLIAR,SER1.1- 6gneen 2.883.3 FLOAT SHOE: 3,D61.73.0MA SURFACE; 3].03,063.8- GAS LIFT: 3.453.5 GAS LIFT: 4.3M.2 GAS LIFT: EDE0.2 GAS LIFT: 5.30.0 PACKER-PATCH-UPR; S...0 LEAK -TUBING; 5,41..0 nNGHORLATCH: s.4os,a p4CKER-PATCF-.; 43EB NIPPLE: 5.4saa PER: E....8 PACKER: E...a SEAL ABBY, B,]23.5 PACKER, E2 1.3 SEE: 6.2VE PRODUCTION: 6.] 5 RPERF, 6. 363UP,04 Oovm e336 KB ERF 6 PERF I, 336 f164I2.0 SIEEVEC; SEALASSY;8,50].8 PATCH; 640.0 PACKER: 650Ba SOE;8511.8 NIPPLE'. 6.5Y1.8 505. 6.530.7 RPERF', 5,555..sIsD APERF, B,Sad.O0,61a0 WERE ',6.W].O6,6aJ.0- FLOAT DOLLAR; 6,]58.0- ILTEED FLOAT SHOE 6, 8]G68.8]8.0 PRODUCTION: 35.O6,W8.0 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852920 Type Inj W Tubing 925 925 925 925 Type Test P Packer TVD 5750 BBL Pump 1.6 IA 350 3300 3240 3240 Interval I Test psi 3000 BBL Return 1.6 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Initial MITIA post injection conversion per Sundry # 322-557 Notes: 3F-14 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3F Pad Austin McLeod Arend / Richwine 02/12/23 Form 10-426 (Revised 01/2017)MIT KRU 3F-14 02-12-23 (002) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-14 (PTD 185-292) Conversion to injection update 1/26/23 Date:Thursday, January 26, 2023 1:03:01 PM Attachments:3F-14.pdf MIT KRU 3F-14 diagnostic MITIA 07-08-21.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, January 26, 2023 8:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3F-14 (PTD 185-292) Conversion to injection update 1/26/23 Chris, KRU 3F-14 (PTD 185-292) was reported on May 25, 2021 with intent to convert the well from production to injection. Subsequent that report a tubing patch was installed and the well passed an MITIA (10-426 attached). Due to delays in the surface work the project was delayed and the previous sundry expired. New Sundry 322-557 was approved for conversion to injection. The plan is for the well to be BOI for a 30 day monitor period during which a SW MITIA will be performed. Once the monitor period and SW MITIA have been completed CPAI intends to apply for an administrative approval for continued water injection only due to the known surface casing leak at 74’. Wellbore schematic attached. No TIO trend is attached as the well has been shut in since 2010. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 III KUP PROD WELLNAME 3F-14 WELLBORE 3F-14 ConocoPhilhps Well Attributes MaX AngleBMD TD Alaska, Inc. P69 FIeN Name Wellbore APWWI WellbometabN Icl" NENT on MBim (nKB) K PAR KRIVER NIT 221 PR 9.]8 4,600.00 6,9]5.0 Cmmment X291ppn) Dale Mrondon Entl Gale KBGNIflI Ria Rekeee pate 55SV: TRDP Lest WO: 10/1]11896 41.88 11212511985 3F -t<, ]9 't8:to 53 AM I Last Tag Vneal"heme5c P -h Anrotation baronage) 1 End Data Wellbore Died MCtl By Last Tag: SLS Our', I 1/&2009 3F -Hr trii HANGER: 3].a Last Rev Reason Annotation End Date Wellbore tvi Moa By Rev Reason: Patch 5404'-5435PRE (ME to ME) ]I&2021 3F-14 spilch Casing Strings LVrvoucr0R:9enus:8 Casing De.clpticn oD gni ID gni Top (Itl(B) eH Depth (nleR) get Depth (NGL.. WtlLen p._Gnae Tup Th' al CONDUCTOR 16 1506 38.0 115.0 1150 62.58 HAO WELDED Drain. Desnio-GD lint IO lin, Top/flKB) Sel DOu"bK81 set Depin WVLenp Gratle Tap Thread SAFETY Wq V66.e SURFACE 9518 892 370 3,0630 3,063.5 36.00 J-55 BTC casing ...no-0(in) lin, ID lin, Top(ptoi Set De On lflKe, set DepM(ND,... WVLenp Gratle Tap TM1read PRODUCTION ] 6.28 35D 6,8]8.0 6,256.] 26.00 J-55 BTC Tubing Strings GAS LIFT; 2ACE.6 Tubing Description Suing Ma... 1p gn, Top(nKB, set Depth (ft.. Set Depth MEN (... M pbut Grade Top ConnMian TUBING WO 4 3.42 33.3 6,531.4 5,988.0 10.90 J-55 ABM -BTC 4"x3.5"x2.8]5" Completion Details 1,RVIE, Top Incl Nominal SURFACE, 37.Marri Tophi (flKB, m ReGea Can Ip (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,]96.] 0.46 SAFETYVLV CAMCO TRDP4A SAFETY VALVE 3.312 GAS LIFT; 9.459.5 4,9528 4,]59) 36.81 %O RetlucinA CROSSOVER 4 312 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 GAG UFT. 4.1393.2 5,445.9 5,142.9 38.21 PER BAKER PER 3.000 5,458.6 5,153.7 36.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER F&1 PERMANENT PACKER 4.000 6,227.6 5,753.0 38.28 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT. 5.093.2 6,328.9 5,831.3 39.42 BIAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE -C BAKER CMU SLIDING SLEEVE WI CAMCO NO GO; CLOSE 2.750 5120/2009 GAS LIFT; 5.993.8 6,505.4 5,9628 39.18 %O Reducing CROSSOVER 3112x2716 2.675 pi Pi Ji edeb 6,506.3 5,968.5 38.18 LOCATOR TIWLOCATOR 2.507 6,507.6 5,968.5 39.18 SEALASSY TIW5EALASSEMBLY 2.500 LEAK -TUBING; 5,410b 6,508.6 5,970.3 39.18 PACKER TINY SS PERMANENT PACKER 3.260 NNC.CNlTCH: EASED- 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 PACKER-PATCH-LwR: s.49s.e 6,522.8 51981.3 39.19 1NIPPLE ICAMCO D NIPPLE NO GO 2.250 NIPPLE 6.43eii 6530.71 5,987.4 39.19 505 I BAKER SHEAR OUT SUB 1.484 P.R;a...5 Other In Hole (Wireline retrievable plugs, valves, pumps, gsh, etc.) PACKER; 5.4596 Top Top ITV., Top Incl SEAL ASSY; 6,]29.5 PACKER;6224.3 SBE.83n.e III (nKB) l°, Des Com Run Data ID (in) SN 5,404.0 5,110.0 38.06 PACKER- PATCH -UPR P2P Upper Patch Packer IME 5404'RKB) 7/812021 (pkrlspacer pipe/anchor latch DAL 31.82) 1.625 CPP35212 5,405.0 5,110.8 38.06 ANCHOR LATCH Spacer Pipe B Anchor Latch 1/&2021 1.600 CPAL35092 5,419.0 5,121.8 38.11 LEAK -TUBING LEAK IDENTIFIED BY EL LDL 513012021 2.992 PRGDuc..Grv: e.293.5 5,435.0 5,134.4 38.17 PACKER- PATCH -LWR POP Lower Patch Packer (ME 5435' RKB) 79/2021 (0 4.01') 1.625 CPP35263 6,485.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING 11/&2010 1.490 CMU at 6495.5' DOWN OVER -D' NIPPLE 6522' -SET ON 275" C -LOCK, SPACER w o RpERF. s aaa Dr3"o- PERF; 6336oc,aaxo� PIPE 8 225" SEAL STINGER, OAL=29'9", MIN, D=1.49" A-sq,,.a:a; 6336.0 fur. � _ - perforations & Slots Top IFVO) al sur Dena (.I.done)Top B) Sort III IIRKS) (nKB) L1ne Data ("Kii ) Type Co. 8,336.0 8,442.0 5,838.8 5,918.7 C-0, 3F-14 3F-14 21111988 12.0 /PERF 120- ph 5"Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C -4,3F-14 1011411996 5.0 RPERF 60°phasing ', 41/2"516 HYDer Jet s1eEVEc; e,asss 6,594.0 6,618.0 6,036.5 6,055.0 Ad, 3F-14 211&1992 6.0 APERF Zero deg. phasing; 2118"TT 6,596.0 6,616.0 6,038.0 6,053.5 Ad, 3F-14 52&1996 4.0 RPERF 180° phasing; 2118' Enei SEAL ASSY ;Sup 6 KER. 6.593 8 a PATCR. B4as. PACKE 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 21111986 4.0 /PERE 90' ph: 4"Csg Gun SBE;8,5118 Cement Squeezes NIPPLE; B.SY1.8 Top IND) Dim(. Pump3tarl Top lRKB) B[m/flKB, /RKB) (BASS) Des Cam peh 6,336.0 6A420 5,836.8 5,818] Down Squeeze 606;8.5M.7 Mandrel Inserts at ON VeM Latch Fertilizer on Top OND) TopJ(1) R To,Ni (nKB) Incl p) Mab Metalser, Type Type (in) TRO Run WI, Run Data Com 2,525.6 2,5255 0.12 CAMCO AS LIFT DMV BK 0.000 0.0 111912003 2 3,458.5 3,4572 8.94 CAMCO AS LIFT DMV BK 0.000 0.0 11/9/2003 3 4,303.2 4,2458 32.51 CAMCO AS LIFT DMV BK 0.000 0.0111912003 RPERF; 6sa6."sto0APPRp, SeN4.os.etao 4 5,088.2 4,881.6 38.53 OTIS AS LIFT DMY RA 0.000 0.0 10119119965 5,383.0 5,101.4 38.03 CAMCO GAS LIFT EXT RK 0.000 0.0 52612021 PKG PERP 6. 57.0-ta6].o- DMV 6 6,283.5 5,]96.2 39.39 CAMCO PROD DMV RK 0.000 0.0 101191999 PRODUCTION. 35.-6,8]60 KUP PROD WELLNAME 3F-14 WELLBORE 3F-14 Cor�oc Phillips Alaska, Inc. n F 3F-11, ..I TB 0x:54 AN Notes: General B Safety V IavM1em b�ecW L Oaie FnnWaOun 2 ]IP0201010 NOTE: View S0emaiic wl Alaska BCM1emalic9.0 HANGER: 339 BOD"010 NOTELeak EMecteE @CMU SLEEVE 6496' 1111611996 INOTE: Leak Delede1l iUTBG M1elm CMU@6495; (See WSR11116196) roluLiva"GR:3anus:e 6FFETV VLV;1 ]66.0 GAa LIFT; 25Sea SURFACE,37.MBS3.6— GAS LIFT: 3.459.5 GAS LIFT: 4.303.2- .3933GAS GASLIFT: Sp93.9 GAS LIFT: 5.393.0 PACKER -PATCH -UPR; S.W4.0 mom I LEAK -TUBING, 5,4180 NNCROR LATCH; EASED— PACKER -PATCH-LN'R: 5.435.0 NIPPLE; 6A39.6 PBR: a..8 PACKER; SA.P SEAL ABBY, 8,]23.5 PACKER; ST .3 SBE; 83Y1.8 PRODUCTION; 6.]51.5 RPERF 6. W 86II6 < IPERF 6i334 P— D"_ 63360UP. Y(' Y' SIEEVEC; 6,193.5 SEALASSY; SAND PATCH; 6,465.0 PACKER; 6.5936 SBE, 6,511,6- ,5118NIPPLE; NIPPLE.6.5M.8 SOS; 8.530.7 BEER6,556.08,8160 APERF, B,SBd.08,6160 IPERF; 6G1].O6,a6].0— PRODUCTION; 35.06,860 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852920 Type Inj N Tubing 1100 1100 1100 1100 Type Test P Packer TVD 6224 BBL Pump 1.3 IA 680 3020 3000 3000 Interval O Test psi 3000 BBL Return OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3F Pad Schmidling 07/08/21 Notes:Diagnostics MITIA post tubing patch (sundry 321-274) and pre conversion to injection Notes: 3F-14 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3F-14 diagnostic MITIA 07-08-21 (002) ! " # $! % " "#&$' ($ )"" *+$ ,- +# . # /&$ 0& 1$$ " ## ! 2 -2 3 $ 4+ 56 $7 895 7 + :+5 7 + ;+5 7 , #+ :+ , #+ ;+ :5 7 5:+7 '<5:+7 /40*=$ " & < ; < ;:+5 7;+5 7 ( ." !< + >< ,- +# # ), + * !< " &6 &$' +6 /;# + ? ? ? 6@? ?"" #?&$' ! "$ ", " A " #$ ?"" #! $ & > : & 6" &&B:& =23 $ ,- 23 $ ;,+>3 # "::&&$, C,?"" + " " , ? , 0& # !# ! !# A$ +! + # #, 6 D 54807(/*%/*(* ? :+5 7 *)8)=:+*8=;+ *).*=:+*.)=;+ *)/8=:+**)=;+ /(()=:+*0*8=;+ /*84=:+*408=;+ 040=:+040=;+ + ;+5 7 A ,6E 6E&6$+?"$, ;&$"::&&$ (8"(*(18 ! "#$% >-88./8F FE44*8 &$&%$"&&$&&$&& " <F& '!$"($9 ') *)+, * -.') *)+, * /0 1 '%** 2)*/ /*.= *= .8/.= *= .8/)= /(*0=0G /G 4%*91G 00= .8(0= /101= + :+5 7 /1).= )G-.%9(G-(%091G <( < <( < <><C6 #< <><>%< <&< ;" +%) ;# /..(= //40= //= $ 8%)8. # 89(8( *, - 3/,-4*"5/04*5/0 -/ 4 *,6 "&.".& By Anne Prysunka at 1:57 pm, Sep 20, 2022 Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2022.09.20 11:21:15 -08'00' '/% ; ; '65 ; ,QMHFWLRQ RSHUDWLRQV UHTXLUH D VHSDUDWH LVVXHG $GPLQLVWUDWLYH $SSURYDO IRU FRQWLQXHG ZDWHU RQO\ LQMHFWLRQ ZLWK D NQRZQ 6& OHDN 97/ *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.04 14:55:33 -08'00' RBDMS JSB 100622 !!! " :1 --#' ('7 "; #.1 "2$,$$$ ! &# ' ' "## #(') * +,-" .#'* /' 0 /! '# 1 '.2132#2 #-. 1#- ! #.1 ' 4$, $56 . .! #2", 7 .1#! -., -#.1 ' .()+,4089 , $$5 -1# ' 1&# ." " $%%$ ( . Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2022.09.20 11:22:02 -08'00' !"#$%&'&( )*+, - .. * , ,/ 0'$1 / &22. , 3 / 3 ) . 0-. 4 , ,)* 5 ,2 ! ) 4 , 1&67"8%$6!9" !/ ) 4 , 167"8%'$6!9" ! ) 4 , 1%567"812&26!9" !/ ) 4 , 11$67"81216!9" ! ,* . 3/3. ::%:1:5:' ,&2 ,. 8* , ) ) !* ,) . 3,./;,). -0/ ) . ) 3 !-/38 3 ,. < => / , ,/ , %1267" %%6!9"( +%88&?7!!@44A"B28&'2 4 . ,7!./ )*,. ,. -:: , /;, !" # $ ! , 3<>), )* '567" 55&6!9"(!3, )) */, / ,3 -; * !'%8$C4) 3. *,.'22 @CACD2 @ CEC !5C*, 3. *,.&%2 @) CECD5% @)CC !4 ./ ,..303 , , .+E !"#$ %# & # # %! '(' )! ! " #$%"&'()*+,-%%. $$/! 01122( #$ )34 !5 60 56" " #$67&'()* +,8+ $$(!/! 11 !5 60 56" " &'()#$9%:+-*%%.,%%*69 $$1;(!/! *114)* 60 6" ,6< &'() +, $$/! 0114)*$$(!/2114) =#1" * !5 60 *;0/1! 6" 0 89%:& '()*> & '()*+,#$,6"$$(!/2 114)/6,04>%# '() !5 ' ' 60 56" 89%:&'()+,$$(!/! 114) WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϱϮϵϮϬͲ^Ğƚ͗ϯϲϭϴϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 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 #1 3F-14 50-029-21500-00 907249583 Kuparuk River Packer Setting Record Field- Final 7-Jul-21 0 12 3H-31A 50-103-20205-01 n/a Kuparuk River Plug Setting Record Field- Final 26-Jul-21 0 13 3K-22A 50-029-22759-01 n/a Kuparuk River Plug Setting Record Field- Final 9-Apr-21 0 145678910PLEASE 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:08/03/2021Wd͗ϭϴϱϮϵϮϬͲ^Ğƚ͗ϯϱϰϴϲBy Abby Bell at 2:11 pm, Aug 03, 2021 ! " # " $ %& ' ()! * '$ +, !- ."!! /, +, 01021*-1 3+ - " ' $ % $ 4 5 + 677 - 8 5+ '7 - 0 96 ' ) + - : 9 2" 8 $ ' " %& ' $ , ' (" 8 ; "$, % $ ; ;)!< = ,=; '!!3 %& ! 6 ") ' % % % !"# $ %&' (&'#) : *!"!+,%-".%/ *!"!+,%-"0%1 *,2. *)' ' '8 $ 8 > +9 01021*17021*7?020.:- $ ; #4 <8 3%4 87) ( %,@ ,@),!$;!% 5)!44))! ,510,0.32 ,675((015,80 3 2 $ !0 ! ! >" A"8 $ 8 50, $ ' )B $ $$ A&11:(1 7@//21 $$ #A ")!<"; $ " #A 19+":111#9)19+" 19+":111#9)19+" 19+": +".;(,#"%-<19+" 19+": +". 1"=19+" 19+":87331"=19+" 333:=9,13>#?- ># ># <A' B'C +/1*-(2/#*00> 6!<A' 6 1#>1> :30101 " :1' By Samantha Carlisle at 9:44 am, Jul 14, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳孺孱孴孷季孳孺孽孵學孽孷孵孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne DSR-7/14/21 SFD 7/16/2021RBDMS HEW 7/14/2021 VTL 8/9/21 ! " # $$""%"#&''()# ! * +, # ! * ", #- . ! * -! ! * "! ! *") ."$'*" # ( !-/ ! *")""$' ,)012+3456708849:;<=>9452;+? Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Patch 5404'-5435' RKB (ME to ME) 7/8/2021 3F-14 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,404.0 5,110.0 38.06 PACKER - PATCH - UPR P2P Upper Patch Packer (ME 5404' RKB) (pkr/spacer pipe/anchor latch OAL 31.82') 7/8/2021 1.625 CPP35212 5,405.0 5,110.8 38.06 ANCHOR LATCH Spacer Pipe & Anchor Latch 7/8/2021 1.600 CPAL35092 5,419.0 5,121.8 38.11 LEAK - TUBING LEAK IDENTIFIED BY EL LDL 5/30/2021 2.992 5,435.0 5,134.4 38.17 PACKER - PATCH - LWR P2P Lower Patch Packer (ME 5435' RKB) (OAL 4.01') 7/7/2021 1.625 CPP35263 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT EXT PKG DMY RK 0.000 0.0 5/26/2021 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 3F-14, 7/13/2021 3:54:44 PM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 PACKER; 6,508.6 PATCH; 6,495.0 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.6 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 7/13/2021 3:54:45 PM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 PACKER; 6,508.6 PATCH; 6,495.0 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 PACKER; 6,224.3 PACKER; 5,459.6 PACKER - PATCH - LWR; 5,435.0 ANCHOR LATCH; 5,405.0 LEAK - TUBING; 5,419.0 PACKER - PATCH - UPR; 5,404.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 KUP PROD 3F-14 ... WELLNAME WELLBORE3F-14 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6975 N/A None Casing Collapse Conductor N/A Surface N/A Production N/A Packers and SSSV Type: Baker FHL pkr 5460MD/5154 Packers and SSSV MD (ft) and TVD (ft): Baker FB-1 pkr 6224MD/5750TVD 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:6/2/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7224 Size Authorized Signature: 6/15/2021 4x3.5x2.875 Perforation Depth MD (ft): J-55 6332 6788 PRESENT WELL CONDITION SUMMARY 6187 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 5837-5879, 6037-6055, 6070-6103 Perforation Depth TVD (ft):Tubing Size: 6336-6390, 6594-6618, 6637-6680 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25632 185-292 P.O. Box 100630, Anchorage, Alaska 99508 50-029-21500-00-00 ConocoPhillips Alaska, Inc. KRU 3F-14 Kuparuk River Field / Kuparuk River Oil Pool 5439 Length TVD Burst 5987 MD N/A N/A N/A 3064 6257 3064 6843 115 115 6878 77 16 9.625 7 3027 Well Integrity Specialist Jan Byrne Jan.Byrne@conocophillips.com TIW SS pkr 6509MD/5970TVD Camco TRDP-4A SSSV 1797MD/1797TVD m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:58 pm, Jun 02, 2021 321-274 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳孹孱孳孵季孴孴孽學孺孽孷孴孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne 10-404 X DSR-6/2/21 X VTL 6/9/21 DLB 06/09/2021 00 X N/A DLB DLB dts 6/9/2021 JLC 6/10/2021 6/10/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.06.10 08:42:07 -08'00' RBDMS HEW 6/11/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 2, 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3F-14 (PTD 185-292) to install a retrievable tubing patch. Please contact me at 659-7244 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳孹孱孳孵季孴孴孽學孹孽學孶孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne Executive Summary 3F-14 is being converted from producer to injector per approved sundry #321- 249. While performing pre-conversion work TxIA communication was discovered. The plan is to install a tubing patch over the leak. The proposed Well Work Request is below. Well Work Justification & Objectives (and date required if appropriate): 3F-14 is a LTSI (shut in since 2010) gas lifted producer that is being looked at for conversion to injection. The well has a surface casing leak at 74’ (OAxATMO). The well was also suspect of TxIA communication during the last secure (2016), this will need to be diagnosed. Due to the OAxATMO leak easily allowing fluids to surface DHD injected N2 down the OA to flush the fluids out of the OA to the leak depth to mitigate fluids coming out during subsequent well work or while online. DHD also passed a CMIT TxIA to 3300 psi with no fluid returns to surface on 5/11/2021. SL set an extended packing DV at 5393', but tubing PTs continued to fail. An LDL located a tubing leak at 5419' and the caliper reported multiple tubing joints with +50% penetrations between 5200' and 5400'. This WWR is to patch the tubing leak. Risk/Job Concerns: • 9.2 GPM LLR at 3000 psi during SL diagnostics 5/26/21. • CSA-2 plug and catcher at 5439'. • Extended packing dummy valve at 5393'. • 4" to 3.5" tubing crossover at 4958'. • Surface casing leak at 74' allows fluids to surface.- while circing out 3/3/16, during MITIA 12/24/14. DHD injected N2 down OA to clear fluids out of leak and passed a CMIT with no fluid returns so this should be mitigated, but potential remains for fluid returns to surface. Plan to AA well for water injection only once BOI and stabilized. • Need approved 10-403 prior to patch installation. Steps: Relay 1. RIH to pull catcher and CSA-2 plug from 5437'. 2. RIH to brush & flush tubing and drift for patch (OD 2.72", OAL 35', run in two sections 4' and 31') down to 5435'. 3. RIH with lower P2P and set mid element at 5435'. Correlate with LDL run 5.30.21. 4. RIH to sting into lower P2P with test tool and perform CMIT TxIA to 3000 psi. Record TIOs. Pull test tool. 5. RIH with upper patch assembly to sting into lower P2P. The patch should be 31' element to element setting the upper P2P mid element at 8030'. 6. Perform MITIA to 3000 psi. Record TIOs. 7. RDMO, turn well over to Operations. 8. DHD to perform SW MITIA once well has stabilized. An LDL located a tubing leak at 5419' and the caliper reported multiple tubing joints with +50% penetrations between 5200' and 5400'. This WWR is to patch the tubing leak. 3F-14 is being converted from producer to injector per approved sundry #321- 249. While performin g pre-conversion work TxIA communication was discovered. The plan is to install a tubing patch over the leak. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TBG LEAK @5419' KB IDENTFIED BY EL LDL 5/30/2021 3F-14 bworthi1 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,419.0 5,121.8 38.11 LEAK - TUBING LEAK IDENTIFIED BY EL LDL 5/30/2021 2.992 5,436.5 5,135.6 38.18 CATCHER Set AVA catcher on plug (OAL 29" X 2.73" OD) 3/3/2016 0.000 5,439.0 5,137.5 38.19 PLUG 2.81" CSA-2 PLUG (OAL=26") (F/N = 1.75" AND 2.31") 2/24/2016 0.000 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT EXT PKG DMY RK 0.000 0.0 5/26/2021 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 3F-14, 5/31/2021 8:38:00 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 PLUG; 5,439.0 NIPPLE; 5,438.8 CATCHER; 5,436.5 LEAK - TUBING; 5,419.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Notes: General & Safety End Date Annotation 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 5/31/2021 8:38:01 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 PLUG; 5,439.0 NIPPLE; 5,438.8 CATCHER; 5,436.5 LEAK - TUBING; 5,419.0 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD 3F-14 ... WELLNAME WELLBORE3F-14 C:\Users\aebell\Desktop\May 2021 Data Drop\CPA Data Drop 06022021\2021-05-30_15784_3F-14_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15784 KRU 3F-14 50-029-21500-00 Caliper Survey 30-May-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 1852920 E-Set: 35211 Abby Bell Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, May 25, 2021 9:26 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 3F-14 (PTD 185-292) Conversion to injection Attachments: 3F,_ 14.pdf Chris, KRU 3F-14 (PTD 185-292) recently had sundry 321-249 approved for conversion to injection. The plan is for the tubing string to be dummied off, acquire a passing MITT and MITIA and bring the well online for a 30 day monitor period during which a SW MITIA will be performed. Once the diagnostics and monitor period have been completed CPAI intends to apply for an administrative approval for continued water injection only due to the known surface casing leak at 74'. A wellbore schematic is attached. This well has been shut in since 2010 so I did not include a TIO trend, but can do so if needed. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 ! " # $! % " "#&$'( )$*"" +,$ -.,# / #0&$ 1& 2$$ " ## ! 3 .3 4 $ 5, 67 $89:6 8 , ;,6 8 , <,6 8 - #, ;, - #, <, ;6 8 6;,8'=6;,8 051+0//)0122 021 +*/5 $ " & 7 = <= <;,6 8<,6 8 ) /" != , >= -. ,# # *- , + != " &7 &$',7 0<#,??? 7@? 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By Samantha Carlisle at 12:32 pm, May 20, 2021 321-249 Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.05.20 12:14:27 -08'00' NA DLB VTL 5/21/21 X X 10-404 DLB05/20/2021 X DSR-5/24/21 dts 5/24/2021 JLC 5/24/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.24 12:48:23 -08'00' RBDMS HEW 6/2/2021 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99505-3448 www.conocophillips.com May 19, 2021 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 ConocoPhillips Alaska, Inc. requests approval to convert long-term shut-in Kuparuk River Unit Well 3F-14 from production service to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approval regarding KRU 3F-14, (PTD# 185-292). If you have any questions regarding this matter, please contact me at 907-265-6525. Regards, Lynn Aleshire Staff Surveillance Reservoir Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Application Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.05.20 12:13:55 -08'00' ConocoPhillips Alaska, Inc. requests approval to convert long-term shut-in Kuparuk River Unit Well 3F-14 from production service to Water Injection service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rom:Aleshire, Lynn To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]KRU 3F-14(PTD 185-292, Sundry 321-249)Convert to WI Date:Friday, May 21, 2021 12:01:24 PM Hi Victoria, We do not plan to repair the SC leak but intend to AA the well. Our Well Integrity Engineer has discussed that process with Chris W. On 5/11/21: CMIT TxIA PASSED @ 3330/3290 psi. Next up is to pull the plug, dummy the tubing and pass MITT and MITIA. Have a good weekend, Lynn From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, May 21, 2021 9:26 AM To: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com> Subject: [EXTERNAL]KRU 3F-14(PTD 185-292, Sundry 321-249)Convert to WI CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Lynn, What are the plans to repair the surface casing leak? Please provide the most recent mechanical integrity information including MIT-T, MIT-IA and MIT- OA plus any diagnostic results. 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.Loepp@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 23FADL025632 ADL025643 19 3F-053 F - 0 43F-083F-213F-033F-183F-18A3F-18AL23F-093F-073F-103F-113F-12L1 3F-12L1- 0 1 3F-12L1- 0 2 3F-12L1- 0 3 3F-12 3F-15 3 F - 1 7 3F-193F-19A3F-203F-133F-13A 3 F - 1 6 A L 1 3F - 1 6 A L 1 P B 1 3 F - 1 6 3 F - 1 6 A L 1 - 0 1 3 F - 1 6 A 3 F - 1 4 Document Path: S:\ANC\Longterm\GKA Geoscience\geotech_projects\GKA_Wells\CPF_3_Wells\Well_3F-14\3F-14 Conversion to Injection\3F-14 Conversion to Injection.aprx 3F-14 10-403 Sundry 5/17/2021 00.2 Miles 3F-14 Well Trajectory 3F-14 Open Interval 3F-14 OI Quartermile Buffer 2 Well Pad P+A Well Active Well CPAI Lease T12N-R10ET12N-R10E Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 6,697.0 1/8/2009 3F-14 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Noted catcher set from 3/3/16 5/18/2021 3F-14 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,063.6 Set Depth (TVD) … 3,063.5 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 6,878.0 Set Depth (TVD) … 6,256.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO 4"x3.5"x2.875" String Ma… 4 ID (in) 3.42 Top (ftKB) 33.3 Set Depth (ft… 6,531.4 Set Depth (TVD) (… 5,988.0 Wt (lb/ft) 10.90 Grade J-55 Top Connection ABM-BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.3 33.2 0.06 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.46 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO Reducing CROSSOVER 4 x 3 1/2 3.500 5,438.8 5,137.3 38.19 NIPPLE CAMCO DS NIPPLE 2.812 5,445.9 5,142.9 38.21 PBR BAKER PBR 3.000 5,459.6 5,153.7 38.27 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 6,223.5 5,749.8 39.27 SEAL ASSY BAKER EBH-22 SEAL ASSEMBLY 3.000 6,224.3 5,750.4 39.28 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,227.6 5,753.0 39.28 SBE BAKER SEAL BORE EXTENSION 4.000 6,328.9 5,831.3 39.42 BLAST RINGS BLAST RINGS (4) 2.867 6,495.5 5,960.1 39.19 SLEEVE-C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO Reducing CROSSOVER 3 1/2 x 2 7/8 2.875 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR 2.507 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION 3.260 6,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,436.5 5,135.6 38.18 CATCHER Set AVA catcher on plug (OAL 29" X 2.73" OD) 3/3/2016 0.000 5,439.0 5,137.5 38.19 PLUG 2.81" CSA-2 PLUG (OAL=26") (F/N = 1.75" AND 2.31") 2/24/2016 0.000 6,495.0 5,959.7 39.19 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C-LOCK, SPACER PIPE & 225" SEAL STINGER; OAL=29'9", MIN. ID = 1.49" 11/6/2010 1.490 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,336.0 6,442.0 5,836.8 5,918.7 C-4, 3F-14 2/1/1986 12.0 IPERF 120° ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F-14 10/14/1996 5.0 RPERF 60° phasing; 4 1/2" 51B Hyper Jet 6,594.0 6,618.0 6,036.5 6,055.0 A-3, 3F-14 2/18/1992 6.0 APERF Zero deg. phasing; 2 1/8" TT 6,596.0 6,616.0 6,038.0 6,053.5 A-3, 3F-14 5/28/1996 4.0 RPERF 180° phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.8 6,103.1 A-2, 3F-14 2/1/1986 4.0 IPERF 90° ph; 4" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,442.0 5,836.8 5,918.7 Down Squeeze Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.2 8.94 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 3 4,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 4 5,088.2 4,861.6 38.53 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 5 5,393.0 5,101.4 38.03 CAMCO MMG 1 1/2 GAS LIFT OPEN 3/3/2016 6 6,283.5 5,796.2 39.39 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 Notes: General & Safety End Date Annotation 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) 3F-14, 5/18/2021 10:31:40 AM Vertical schematic (actual) PRODUCTION; 35.0-6,878.0 IPERF; 6,637.0-6,680.0 APERF; 6,594.0-6,618.0 RPERF; 6,596.0-6,616.0 SOS; 6,530.7 NIPPLE; 6,522.8 SBE; 6,511.6 PACKER; 6,508.6 PATCH; 6,495.0 SEAL ASSY; 6,507.6 SLEEVE-C; 6,495.5 IPERF; 6,336.0-6,442.0 Down Squeeze; 6,336.0 ftKB RPERF; 6,348.0-6,390.0 PRODUCTION; 6,283.5 SBE; 6,227.6 PACKER; 6,224.3 SEAL ASSY; 6,223.5 PACKER; 5,459.6 PBR; 5,445.9 PLUG; 5,439.0 NIPPLE; 5,438.8 CATCHER; 5,436.5 GAS LIFT; 5,393.0 GAS LIFT; 5,088.2 GAS LIFT; 4,303.2 GAS LIFT; 3,458.5 SURFACE; 37.0-3,063.6 GAS LIFT; 2,525.6 SAFETY VLV; 1,796.8 CONDUCTOR; 38.0-115.0 HANGER; 33.3 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/25/1985 3F-14 ... TD Act Btm (ftKB) 6,975.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292150000 Wellbore Status PROD Max Angle & MD Incl (°) 39.78 MD (ftKB) 4,600.00 WELLNAME WELLBORE3F-14 Annotation Last WO: End Date 10/17/1996 H2S (ppm) DateComment SSSV: TRDP Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J ~'z'~- _~ ~'_ Well History File Identifier Organization (done) ,~Two-Sided RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: DIGITAL DATA [] Diskettes, No, [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of vadous kinds TOTAL PAGES: ORGANIZED BY~ NOTES: BREN VINCENT SHERYL MARIA LOWELL DATE: [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IsI Scanned (done) PAGES: ~:)(~ (at the time of scanning) SCANNED BY.' BEVERLY BREN VINCEN~ARIA LOWELL RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: ~, ~~'~ DATE: /S/ "Quatity Ch~cked ldone) Rev1 NOT,Scanned.wix] • • Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617 @conocophillips.com] IZ 13 Sent: Friday, December 10, 2010 3:40 PM \: 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Sup j Subject: 3F -14 (PTD # 185 -292) Slight leak to surface report Attachments: 3F -14 Well Schematic.pdf Jim, Tom, Guy Kuparuk producer 3F -14's (PTD# 185 -292) OA sealtite repair failed, allowing a slight leak to surface. No spill incurred due to secondary containment. The well was shut in and secured on December 6, 2010 and will remain shut in till a repair can be made. Please call if you have any questions. Kelly Kelly Lyons for Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Pager 907 - 659 -7000 #909 12/13/2010 0 • KUP 3F -14 + Hips we�� 1ributies A)' I Wellbore APIIUWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 60 500292150000 KUPARUK RIVER UNIT PROD 39.78 4,0.00 6,975.0 ° Comment H2S (ppm) Date End Date KB -G A (ft) Rig Release Date Well Canfl F.1412ntztt1010:56:29Ant SSSV: TRDP 350 11/27/2009 Last WO: 10/17/1996 41.88 12125/1985 Se relic- Aet0al Annotation Depth (ftKB) End Date lAnnotation Last Mod ... End Date Last Tag: SLM 6,697.0 1/8/2009 Rev Reason: SET PLUG PRE -WO Imosbor 12/6/2010 t« 4 HANGER, 33 Cee� _ Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 H -40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,063.6 3,063.5 36.00 J -55 BTC � Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, t PRODUCTION 7 6.151 35.0 6,878.0 6,256.7 26.00 J -55 BTC 38 -115 - = Tuba rFn St $ �e ± - Tubing Description String 0... String 10 ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETY VLV TUBING 4 3.423 33.3 6,531.4 5,988.0 10.90 J -55 ABM -BTC 1,797 4 "x "x Top Depth GAS LIFT, (TVD) Top Incl Nomi... 2,526 Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 33.3 33.3 0.16 HANGER FMC GEN IV HANGER 4.000 1,796.8 1,796.7 0.45 SAFETY VLV CAMCO TRDP -4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO CROSSOVER 4 x 3 1/2 3.500 REDUCING SURFACE, = = 37 -3,064 5 ,438.8 5,137.4 38.41 NIPPLE CAMCO DS NIPPLE 2.812 - 5,445.9 5,143.0 38.41 PBR BAKER PBR 3.000 GAS LIFT, 3,458 5 ,459.6 5,153.7 38.42 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 J 6,223.5 5,749.9 39.41 SEAL ASSY BAKER EBH -22 SEAL ASSEMBLY 3.000 6,224.3 5,750.5 39.41 PACKER BAKER FB -1 PERMANENT PACKER 4.000 GAS LIFT, 6,227.6 5,753.0 39.41 SBE BAKER SEAL BORE EXTENSION 4.000 4,303 6,328.9 5,831.3 39.42 BLAST RINGS 2,992 6,495.5 5,960.1 39.18 SLEEVE -C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5/20/2009 2.750 6,505.4 5,967.8 39.18 XO CROSSOVER 3 1/2 x 2 7/8 L2.500 t REDUCING 6,506.3 5,968.5 39.18 LOCATOR TIW LOCATOR GAS LIFT, 5,088 " 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 6,511.6 5,972.6 39.18 SBE SEAL BORE EXTENTION . GAS LIFT, 6 ,522.8 5,981.3 39.19 NIPPLE CAMCO D NIPPLE NO GO 2.250 5,393 6,530.7 5,987.4 39.19 BAKER SHEAR OUT SUB 1.484 SOS NIPPLE. 5,439 other Ili I'�t)IEi!� Wke" fine,retriaN Ie (U x fllti@ ;,. tim PLUG, 5,439 Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (I Description Comment Run Date ID (in) PBR, 5,446 Iff = 5 ,438.8 5,137.4 38.41 PLUG CA -2 PLUG SET IN NIPPLE, PRE -WO 12/6/2010 0.000 PACKER, 5,460 6,495.0 5,959.7 39.18 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' 11/6/2010 1.490 DOWN OVER 'D' NIPPLE @ 6522' - SET ON 2.75" C -LOCK, SPACER PIPE & 225" SEAL STINGER; SEAL ASSY, OAL= 29'9 ", MIN. ID = 1.49" 6,224 PACKER, 6,224 _ SBE, 6,228 Perforat ton s`& Slots 2z A Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 6,336.0 6,442.0 5,836.8 5,918.6 C -4, 3F -14 2/1/1986 12.0 IPERF 120 deg. ph; 5" Csg Gun PRODUCTION, 6 ,348.0 6,390.0 5,846.1 5,878.5 C -4, 3F -14 10/14/1996 5.0 RPERF 60 deg. phasing; 4 1/2" 51 B Hyper 6,283 = Jet 6,594.01 6,618.0 6,036.5 6,054.9 A -3, 3F -14 2/1811992 6.0 APERF Zero deg. phasing; 2 1/8" TT m 6,596.0 6,616.0 6,038.0 6,053.3 A -3, 3F -14 5/28/1996 4.0 RPERF 180 deg. phasing; 2 1/8" EnerJet RPERF, - 6 ,637.0 6,680.0 6,069.7 6,103.1 A -2, 3F -14 2/1/1986 4.0 IPERF 90 deg. ph; 4" Csg Gun 6,348 -6,390 IPERF. r te` , 6,336 -6,442 Down Squeeze, Top Depth Btm Depth 6,336 (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 6,336 0 6,442.0 5,836.8 5,918.6 Cement Squeeze 10/12/1996 SQUEEZED UPPER PERFS N0 le End Date Annotation 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11/18/96) SLEEVE -C, 6,496 4/5/2004 NOTE: WAIVERED WELL: OA xOOA COMMUNIATION 4/5/2004 NOTE: MINOR IA x OA COMMUNICATION - LEAK REPAIRED WITH SEALANT. SEAL ASSY, 6/28/2010 NOTE: Leak detected @ CMU SLEEVE @ 6496' 6,508 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PATCH, 6,495 PACKER, 6,509 SBE, 6,512 NIPPLE, 6,523 Mandrel Detats Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (I Make Model (in) Sery Type Type (in) (psi) Run Date Com... SOS,6,531 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.1 8.75 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 APERF, 3. 4 ,303.2 4,245.8 32.51 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 6,594 -6,618 RPERF, 4 5,088.2 4,861.6 38.56 OTIS LBX 1 1/2 GAS LIFT DMY RA 0.000 0.0 10/19/1996 6,596 -6,616 5 5,393.0 5,101.3 38.01 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/10/2003 6 6,283.5 5,796.2 39.42 1 CAMCO I MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 IPERF, 6,637 -6,680 .. PRODUCTION, 35 -6,878 TD, 6,975 STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair well ]- Rug Perforations Stimulate Other r Set Patch Alter Casing Pull Tubing Perforate New Pool" Waiver Time Extension Change Approved Program Operat. Shutdown r Perforate Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development � Exploratory F 0 185 -292 3. Address: 6 API Number: Stratigraphic Service . P. O. Box 100360, Anchorage, Alaska 99510 ti 50- 029 - 21500 - -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 % 317 -14 9. Field /Pool(s): WA Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6975 feet Plugs (measured) None true vertical 6332 feet Junk (measured) None Effective Depth measured 6788 feet Packer (measured) 5460, 6224, 6509 true vertical 6187 feet (true vertucal) 5154, 5750, 5970 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3027 9.625 3064 3064' PRODUCTION 6843 7 6878 6257' � 16`616 Perforation depth: Measured depth: 6336'- 6390', 6594'- 6618', 6637' -6680' RECE True Vertical Depth: 5837'- 5879', 6037'- 6055', 6070' -6103' DEC 1 o 2010 Tubing (size, grade, MD, and TVD) 4x3.5x2.875, J -55, 6531 MD, 5987 TVD Alaska Oil & Gas Cons. Commi Anchorage Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKER @ 5460 MD and 5154 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 6224 MD and 5750 TVD PACKER - TIW SS PERMANENT PACKER @ 6509 MD and 5970 TVD SAFETY VLV - CAMCO TRDP -4A SAFETY VALVE @ 1797 MD and 1797 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 4 1 426 -- 150 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r- Development '`a Service Stratigraphic F r G STOR Well Status after work: Oil r' ,, Gas WDSPL Daily Report of Well Operations XXXX F_ WI NJ WAG GINJ " SUSP SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia, if C.O. Exempt: none Contact Dan Herrmann (a) 263 -4619 Printed Name n H r Title Wells Engineer J Signature Phone: 263 -4619 Date Form 10 -404 Revised 10/2010 A Submit Original Only 3F -14 Well Work Summary DATE SUMMARY • 10/30/10 DRIFT TBG 2.78" DMY PATCH AT TO 6496' RKB. COMPLETE. 11/6/10 SET HALF PATCH ASSY (2.75 CLOCK, SPACER PIPE & 2.25 SEAL STINGER, OAL: 29 9 ", MIN ID: 1.49 ") STRADDLING CMU @ 6495 & D NIPPLE @ 6522' RKB. COMPLETE. KUP 3F-14 • ' GanalPlips W_ @II Attributes _ Max Angle & MD lAWell Status MD (kKAct (kKB) 500292150000 �KUPARUK RIVER UNIT PROD 39.78 I 4,60000 69750 Com enf i � H2S (ppm) Date lAnnotation End Date I KB - Grd (ft) Rig R Date "FCµry SSSV: TRDP 350 11/2712009 Last WO. � 10/17/1996 4188 - 1 . 12/25/1985 Annotation IDepth(ftKB) End Date Annotation Lst Mod... I End Date Last Tag: SLM : 6,697.0 1/8/2009 Rev Reason: SET HALF PATCH Imosbor ] MANGER, 33 t:asm m Str s Casing Description String 0... String ID ... Top (kKB) Set Depth (f_. Set Depth (ND) .. String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 1150 62.58 H-40 WELDED �___...._ . r.. _ -- 3 Gating Descrpton String 0... String ID .. Top (HKB) Set Depth (i... Set Depth (ND) ... String Wt... String .,. String Top Thrd S _ 95/8 8.921 37.0 3,063.6 _ 3,063.5 36.00 J -55 BTC__ Gating Description String 0... String ID., Top (ftl(B) Set Depth (f... Set Depth (ND) ... String Wt... String ... SMng Top Thrd PRODUCTION UCTION 7 6.151 350 6,878.0 6,256. _26.00 J -55_ -- BTC_- - 38-115 i __ _ TU n -_.. 9ng npti n g 9 Pl - P ( _.. P ).. 9 IStrng ... String Top Thrd SAFETY VLV, 4 zBS x2.875" 4 3.423 33 3 6 531 4 5,988.0 10 90 J -55 ABM -BTC 1,797 T b I Des Strin O. Strin ID ... To ftK6) Set Depth f... Set Depth (ND St Wt.. - letion Details _ Top Depth GAS LIFT, (TVD) Top lncl N i... 2,526 To (ftK6) --n-- llem Deslxi fan __ Colfmalt ID (in) 33.3 33.3 0.16 HANGER FMC GEN IV HANGER 4.000 _ _ ---'-' 1,796.8 1,796.7 0.45 SAFETY VLV CAMCO TRDP -4A SAFETY VALVE 3.312 4,957.8 4,759.7 38.61 XO CROSSOVER 4x 31/2 3.500 REDUCING ...<: . -_ SURFACE, 5,438.8 5,137.4 38AI NIPPLE CAMCO DS NIPPLE 2.812 37 - 3,064 5,445.9 5,143.0 38.41 PBR BAKER PBR 3.000 GAS LIFT, - 5,459.6 5,153.7 38.42 PACKER BAKER FHL RETRIEVABLE PACKER 2.890 3,458 6,223.5 5,749.9 39.41 SEAL ASSY BAKER ESH -22 SEAL ASSEMBLY 3.000 6,224.3 5,750.5 39.41 PACKER BAKER FBA PERMANENT PACKER 4.000 6,227.6 5,753.0 39.41 SBE !BAKER SEAL BORE EXTENSION 4.000 GAS LIFT._ - __ - -- 4,303 6,328.9 5,831.3 39.42 BLAST RINGS 2.992 6,495.5 5,960.1 39.18 SLEEVE -C BAKER CMU SLIDING SLEEVE W/ CAMCO NO GO; CLOSE 5120!2009 2.750 6,505.4 5,967.8 39.18 XO CROSSOVER 31/2 x 27/8 2.875 REDUCING 6,506.3 5,968.5 39.18 LOCATOR - TIW LOCATOR 2.507 GAS LIFT, _.. 5,oes 6,507.6 5,969.5 39.18 SEAL ASSY TIW SEAL ASSEMBLY 2.500 6,508.6 5,970.3 39.18 PACKER TIW SS PERMANENT PACKER 3.260 6,511.6 5,972.6 39.18 SBE -- SEAL BORE EXTENTION 3.260 Gas LIFT 6,522.8 5,981.3 39.19 NIPPLE iCAMCO D NIPPLE NO GO 2.250 5,393 --- _ _ 6,530.7 5,987.4 39.19 SOS BAKER SHEAR OUT SUB 1.484 Other In Hole (reline retrievable plugs valves pumps fish, etc. NIPPLE, 5,439 Top Depth (TVD) Top Intl 1. To B (kKB) om ( °) _ _ Cment Run Date ID in -�_ -_ PBR, 5,446 - -- _ 1 6,495.0 5,959.7 39.18 PATCH HALF PATCH ASSEMBLY STRADDLING CMU @ 6495.5' 11/612010 1.490 PACKER, 5,460 ____ DOWN OVER'D' NIPPLE @ 6522' -SET ON 2.75" C -LOCK, SPACER PIPE & 225" SEAL STINGER; SEAL ASSY, OAL= 29'9 ", MIN. ID = 1.49" 6.224 PACKER. 6.224-- - _ . -.. _ Perforations & Slots ME, 6.228 - - - -'- Shot Top (ND) Btrn(ND) Dens 1 T ifK61 Btrn (kKB (ftK6) (NCB) ,- j Zone _ Date Il T CommelA _ 6,336.0 6,442.0 5,836.8 5,918.6 CA, 3F -14 2!111986 2.0 IPERF 120 deg. ph; 5" Csg Gun 6,348.0 6,390.0 5,846.1 5,878.5 C-4, 3F -14 10/14/1996 5.0 RPERF 60 deg. phasing; 4 1Y1" 518 Hyper PRODUCTION, Jet 6.283 _ _ 6,594.0 6,618 0 6,036.5 6,054.9 A -3, 3F -14 2/1817992 6.0 RPERF Zero deg. phasing; 2 1!8" TT 6,596.0 6,616.0 6 038 0 - 6 053.3 A -3, 317-14 5128!1996 4.0 RPERF 1180 deg. phasing; 2 1/8" EnerJet 6,637.0 6,680.0 6,069.7 6,103.1 A -2, 3F -14 2/1!1986 4.0 IPERF 90 deg. ph; 4" Csg Gun RPERF, 6, - -- -- 348 -6,390 Cement S q,.ueez es ""�''° �''b.' IPERF,, Top Depth St tm Depth rxv�W 6,336 -6,442 ND) (ND) Down Situ-, ( 6,336 -'� Top (ftK8) Btn (ftf(B) (ftK6) (kKB) Description Start Date Comment 6,336.0 6,442.0 5,836.8 5 918.6 Cement Squeeze 10/12!1996 SQUEEZED UPPER PERFS Notes: General & Safet End Date Annotatio 11/18/1996 NOTE: Leak Detected in TBG below CMU @ 6495'; (See WSR 11118/96) SLEEVE -c,_ 4/5/2004 NOTE: WAIVERED WELL: OA xOOA COMMUNIATION 6.496 .. _ ._ _.. T/92 NOTE: MINOR IA x OA COMMUNICATION - LEAK REPAIRED WITH SEALANT. 6/28/2010 NOTE: Leak detected @CMU SLEEVE @ 6496' SEAL ASSY, 7/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6,506__._.-- PATCH, 6,495 PACKER, 6,509 _ ME, 6,512 - NIPPLE, 6,523 Mandrel Details T� Top Depth Top Port (ND) In .1 OD V Ne Latch Size TRO Run Stn To ((tl(B (ftK8) ( °) Nake Model (in) sw Type Type (in) (pal) Run Date Cam... SOS, 6,531 --- -- {- 1 2,525.6 2,525.5 0.12 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2003 2 3,458.5 3,457.1 8.75 CAMCO KBMG G 32 1 AS LIFT DMY BK 0.000 0.0 11/9!2003 RPERF, 3 4,303.2 4,245.8 .51 CAMCO KBMG i GAS LIFT DMY BK 0.000 0.0 111912003 6,594 -6,618 - - RPERF, 4 5,088.2 4,861.6 38.56 OTIS LBX 11/2 GAS LIFT DMY RA 0.000 0.0 10/1911996 6,596 -6,616 T _ 51 5,393.01 u 5,101.3 38.01 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 61 6, 83.51 5,796.2 39.42 CAMCO MMM 1 1/2 PROD DMY RK 0.000 0.0 10/19/1999 PERF, 6,637 - 6.680 PRODUCTION, 35 -6,878 TD, 6,975 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, December 10, 2010 3:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3F -14 (PTD # 185 -292) Slight leak to surface report Attachments: 3F -14 Well Schematic.pdf Jim, Tom, Guy Kuparuk producer 3F -14's (PTD# 185 -292) OA sealtite repair failed, allowing a slight leak to surface. No spill incurred due to secondary containment. The well was shut in and secured on December 6, 2010 and will remain shut in till a repair can be made. Please call if you have any questions. Kelly Kelly Lyons for Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 -659 -7224 Pager 907 -659 -7000 #909 12/10/2010 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 3F-14 Run Date: 6/28/2010 July 3, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21500-00 L'~~a i~~ k`. ~J ~ v` A~ ~ U I It PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b - :t : ;_ ~? '> ,~ Date: ~ ~~°:~ ~: l~5 _~~a j9~~3 Signed: • . '~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 \<ò~,~q~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 sÇANNED SE? () 82006 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043,,,.~1(yOU have any questions. /// ,] //-' ",,'1' /I /Þ/ ..' ~ £/ /.' / ¡?~ð yr // iÍ /' .? ,/~1~/í~ ,? ," Z v M.J. íovela~d Sincerely, ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date '3F~O,¡L .... . A&5~~25. 0 : , NA . . .' . "" "> /a-/~1/1:~Ø,El6 '. 3F-02 ~. 24' 7.0 8/14/2006 7.5 8/21 /2006 .' ~~~~3 .: . . ·t3!~"· . . .2."3 I '. ...,::' J3/1/4¡~Ø:oß ,,:: r: . " . . ~à"þ~tJ~JIf1ß; ": . . " 3F-04 185-228 80' 22.7 1 0' 8" 8/1 4/2006 38.2 8/21/2006 3FtÐ~t~;.:, . . ',', 5.1 , ". o ,c' ,'.' :. " , ""8ìt4J2<IØ&':,,' ~ . "1'.0 ..~' :8~1~Õ:øft.. 3F-06 1 85-244 Did not modify '3~';tJ1'~ .' "., ··'f~5~~:" ,;r'> . . ....~·w, " 6;6 . S¡;t412,Q!:ra ,--" ,,' "]:.5 " .'. :8121ì2tr.Øe: " 3F-08 1 85-246 1 1 '4" 2.6 8/14/2006 6.6 8/21/2006 3F~Q~ " ' " '1Ø'5'~~ij Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21 /2006 . '3F·1'l" r, , '185~2i12 <"':'1 l" ',·,~f.··, ", ,: NA" , , . . 1.7 I '. e'J23l;2QnQ; " ". 3F-1 2 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 " " '}~~~1it:¡; :: ;'" NA " " : 2f"~ :. 'a'ì2g12~q~t.· , " =ii ~ Did not 'J,. r,;.... ". , I.,,"·. 2,:,~: ' .' ,.' ..".... """ .:Uft~J2Qd;(r:.' " ' /.al~ß'~2.fJ:Ø$ . ". 3F-16 196-151 6" NA NA 2.7 8/23/2006 '3J~IfT . .' ~ ' "1'1" . '. 3.1 '.' ' , ..' .. '81f412,O!X&, .... t· 8. "-c'·' ßl~gàtt~6:: 3F-1 8 196-112 4' NA NA 28 8/23/2006 3f,,'j,~: . .' .' ~0:'4~ft6' ", ,~j ." ']' ,', .NA : . . 8", r I:.·..., 2; . ". ::ðf2~t2QØ6L . .K~ .J'I~': . '. . 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F~2:t ' C¡" ,: 206:203 '. 45" NA , NA 31 " 8f2ff2Qbs Schlumberger Schlumberger -DCS 2525 Gam bell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # I 81- ).. / I 1 F-02 /95 ~Ð2"- 2T-23 ~ 2W-12 1~'f.l2Jf 2Z-19 Ifs-r!;o 1C-111 J..e¡'··tl.. <ð 1 C-117 ~~(- /z. f 3F-14 (~.5- '-72 2K-07 <:iJ. 2Z-12A I 0 c¡~ 07 ( { '15- /cf6 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG Date 12/14104 12108/04 12/15/04 12/04/04 12/06/04 12/06/04 12/03/04 12/05/04 12/04/04 .SG,ANNE[ !J.PR 1 8 Z005 NO. 3292 Com pany: 12/23/04 ,~6- d11Y" Alaska Oil & Gas Cons Comm ~~:;,~ Attn: Helen Warman ~il-- 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 1 1 DATE: ___j Color CD ~- STATE OF ALASKA ,z~m,~KA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS; 1. Operations Performed: Operation Shutdown__ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 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 62' FSL, 181' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1255' FSL, 1169' FEL, Sec. 19, T12N, R9E, UM At effective depth 1482' FSL, 1359' FEL, Sec. 19, T12N, R9E, UM At total depth 1567' FSL, 1430' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 6 9 7 5 true vertical 6332 Effective depth: measured 6 7 8 8 true vertical 6187 Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 02 5' 9 - 5 / 8" Intermediate Production 6839' 7" Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-14 9. Permit number/approval number 85-292 10. APl number 5o-103-21500-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet feet feet Plugs (measured) Non~ .: Junk (measured) None,~, Cemented 340 Sx AS II 900 Sx PF E & 340 Sx Class G 150 Sx Class G & 175 Sx P F C Mea~:{~l'-ae~'t~z,~it:~:-~'e vertical depth 115' 115' 3064' 3064' 6878' 6257' 6336'-6442', 6348'-6390', 6594'-661 8', 6637'-6680' true vertical 5837'-5919', 5846'-5878', 6036'-6055', 6070'-61 03' Tubing (size, grade, and measured depth) 4", 10.9#/ft, J-55 @ 4958';3.5", 9.3#/ft., J-55 @ 4958'-6505', & 2.875", 6.5#/ft., J-55 @ 6505'-6531' Packers and SSSV (type and measured depth) Packers: Baker FHL @ 5460, Baker FB-1 @ 6224', TIW SS @ 6508'; SSSV: Camco TRDP-4A @ 1797' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 11/22/96 Intervals treated (measured) ORIGINAL 6594'-661 8', 6637'-6680' Treatment description including volumes used and final pressure _ Pumped 244.7 Mlbs of 20/40,12/18, & 10/14 of ceramic proppant into formation, fp was 7100 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 6 6 130 0 1325 146 Subsequent to operation 1335 1 2 5 6 849 1346 204 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. Signed .~~~~~~ Tit, e Wells Superintendent Form l~4~4rF~ev/ ~~ - Date SUBMIT IN DUPLICATE ARCO Alaska, lng, · Post Office Box 10036(~~'''~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-14 (Permit No. 85-292) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3F-14. During the workover operations, leaks were found in the 7" casing while performing cement squeeze work within the Kuparuk "C" sand. The leaks in the 7" casing were found to be corrosion related and were confined to two joints of casing. The well was completed with a straddle packer completion to isolate the leaks and restore integrity to the 7" casing. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development RECEIVED FEB ,5 1997 Alaska 0il & Gas Cons. CommissJorl Anchorage WSI/skad " STATE OF ALASKA -. · ~LASIk'~OIL AND GAS CONSERVATION C',=,WIMISSION WELL COMPLETION OR RECOMPLETION REPORT .AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 85-292 3. Adcl~ess ' 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-21500 4. Location of well at surfaceI 1 ~ , 9. Unit or Lease Name 62' FSL, 181' FEL, Sec. 19, T12N, R9E, UM ~~--~t' Kuparuk River Unit At top of productive interval ~ 1 10. Well Number 1254' FSL, 1163' FEL, Sec. 19, T12N, R9E, UM 5~d "" "/ 3F-14 At total depth 1 1 Field and Pool 1565' FSL, 1423' FEL, Sec. 19, T12N, R9E, U M ,~ Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 93'I ADL 25632, ALK 2565 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions .... 12!.201.8.5 .. J. 12/24/85 ! 10/18/96 I N/A MSLI TWO 117. Total Depth (MD+TVD)1181 Pldg Back DePth (MD+TVD)I19, Directional SUrv'eyl20. Depth where SSSV Set[21. Thickness of permafro~s:t : ..... _6_9_7__5 ......... _63_32___F'~ 6788 6187 Fl] I-lYes [~Uo } 1797' MD/ 1465' (Approx.) 22. Type Electric or Other Logs Run 231 CASING, LINER AND CEMENTING RECORD O'ASlI~ .............. SE.Ff. iNG DEPTH HOLE ..... SIZE WT, PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED .... :16;; ............ 6~5~ ............... ~Z4~- .......... ~urf~ ....... i15;- -- 24. 340sxAS II ................ 9-5/8" 36'.0/1 J-55 Surf. 3064' 12.25" 900 sx PF 'E' & 340 sx Class 'G' 7" 26.0/1 ,J--55 Surf: -] 6-87J~-' ...... 875~' ...... 2.~i~- F~:--~-lass-i~ 8, :1--7'5- ~--PF-'-O-'- ......................................................... , 24. Perforations OPen to Production (MD+TVD of Top and Bottom 25. TUBING REcoRD and interval, size and number) ...... S~ZE ' DEPTH SET (MD) '" PACKERS~:T (M-D) 4"X 3.5" X 2-718" 4958' / 6531' 5460' & 6224' & 6509' MD TVD MD TVD .................................................................................................... 6348'-6390' 5846'-5878' 5 spf reperfed dudng 26. Ac~D, FRACTURE, CEMENT SQUEEZE, ETC. workover DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6336'-6442' down-squeezed 16 bbl Class G cement 6594'-6618' 6037'-6055' 6637'-6680' 6070'-6103' behind pipe. Frac: total proppant was Frac:6594'-6618' 251268/1, put 244678# in formation with 6637'-6680' 12/1 ppa of #10/14 @ perfs , , 27. PRODUCTION TEST Date First Produbtio~ " iMeth0d of Operation (Flowing, gas lift, ~tc.) ..... I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL : CHOKE SIZE i GAS-OIL RATIO 1/10/97 17.8 TEST PERIOD ' 994 983 720 136 i 628 FiS,~[-T-LiS-i~g- i3-~-i-~ P-i'~s-s~re ~A-L~-LA'~I~5 ~- '-Oit_;i~B~ ......... ~A~;J~-C~ ......... W-~:FR--Bi~L ..... -Oi[--~-~-V'i:r~--.~,'lS-i~(-6~RF~) .................................. Press. 199 1159 ~4-HoUR RATE 1234 774 969 23.6° ......... i28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL A~aska 0ii & Gas Cons. Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Total Volume Pumped to Date: 3437 bbls in first quarter 1986 Top Kuparuk C 6334' 5835' Bottom Kuparuk C 6439' 5916' Top Kuparuk A 6569' 6017' Bottom Kuparuk A 6684' 6106' Freeze protected annulus. !31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~_~, ~. ~ ~""-----.-~_ _ _ Title_ '~,~.t.~.r~,-_ ~-{C-w, tt~:P. Date ~'~- J{- (~ ~ Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 11/18/9~ ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3F-14 RIG:NORDIC WI: 0% SECURITY:0 WELL ID: 998632 TYPE: AFC:--998632 AFC EST/UL:$ 905M/ ll00M STATE:ALASKA API NUMBER: 50-029-21500-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:10/05/96 START COMP:10/05/96 FINAL:10/18/96 10/05/96 (C 1) TD: 6975' PB: 6788' SUPV: DLW DAILY: $ 10/06/96 (C 2) TD: 6975' PB: 6788' SUPV:DLW DAILY:$ 10/07/96 (C 3) TD: 6975' PB: 6788' SUPV:DLW DAILY:$ 10/08/96 (C TD: 6505' PB: 6505' SUPV:DLW 4) DAILY:$ 10/09/96 (C TD: 6460' PB: 6616' SUPV:DLW 5) DAILY:$ 10/10/96 (C 6) TD: 6460' PB: 6616' SUPV:DLW DAILY:$ TESTING BOPE MW:10.1 UNKNW Move from 3F-15 to 3F-14. Accept rig at 0700 hfs 10/5/96. Kill well. Freeze protect production flowline with diesel. N/D tree. N/U BOPE. Function test BOPE equipment. 43,800 CUM:$ 87,600 ETD:$ 0 EFC:$ 992,600 REPAIR DRIP PAN & FLOW LI MW: 0.0 Continue to test BOPE equipment to 250/3500 psi. Pull tubing to rig floor. Spot high vis pill @ tbg tail 6233'. Pull 3.5" tbg. 67,384 CUM:$ 222,368 ETD:$ 0 EFC:$ 1,127,368 FISHING @ 6233' FOR 3.5" MW:10.4 Continue to repair drip pan and flow nipple. Continue to pull 3.5" tubing. RIH w/fishing BHA #1 to 6220' 61,623 CUM:$ 345,614 ETD:$ 0 EFC:$ 1,250,614 PUSH "WD" PKR TO BOTTOM 6 MW:10.4 Unable to circulate past 7" packer. POOH swabbing. POOH to fish. Release overshot. L/D fish. RIH with fishing BHA %2 to 6387' Tight spot. P/U kelly work through tight spot. RIH to top 7" "WD" packer. Mill 7" "WD" packer from 6496'-6499' came free. Push 7" packer to bottom 6666' top packer. 38,700 CUM:$ 423,014 ETD:$ 0 EFC:$ 1,328,014 SET 7" BP FOR "C" SAND SQ MW:10.3 CBU @ 6666' pushing 7" WD packer to bottom. RIH w/BHA %3 3.25" spear to 6666' Tag 7" WD packer push to 6692' POOH Wet w/7" "WD" packer assemby til past top perfs @ 63~6' RIH w/7" Baker model N-1 bridge plug on 3.5" DP to 6460', set BP & shear off. 60,256 CUM:$ 543,526 ETD:$ 0 EFC:$ 1,448,526 POOH FOR RTTS TO TEST CAS MW:10.3 Circulate @ 6460' after setting 7" Baker N-1 BP. Close Hydrill and inject into 'C' sand perfs @ 6336' to 6442' Pumped cement. CIP @ 0839 hrs. Down squeeze 'C' sand perfs. RIH w/ C/O BHA #1 to 6237' hit cement stringers. Cleanout cement stringers from 6237' to 6260' firm cement, clean out firm cement to 6287' Test casing pumping away w/1700 psi. Continue to clean out firm cement form 6287' to 6450' 53,504 CUM:$ 650,534 ETD:$ 0 EFC:$ 1,555,534 Date: 11/18/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/11/96 (C 7) TD: 6460' PB: 6616' SUPV: DLW DAILY: $ DRILLING BP @ 6460 MW:10.3 RIH to 6300' with 7" Baker retriev-o-matic test packer. Set test packer. Test 'C' sand squeeze top perf @ 6336'MD. Clean out cement to 6460' and drill Baker 7" bridge plug. 33,400 CUM:$ 717,334 ETD:$ 0 EFC:$ 1,622,334 10/12/96 (C 8) TD: 6788' PB: 6788' SUPV:DLW DAILY:$ R/U SCHLUMBERGER FOR USIT MW:10.2 Clean out from 6717' RIH with 7" casing scraper to 6525' 38,898 CUM:$ 795,130 ETD:$ 0 EFC:$ 1,700,130 10/13/96 (C TD: 6788' PB: 6788' SUPV:DLW 9) DAILY: $ FISHING SWS GAUGE RING J/ MW:10.2 Run USIT w/GPIT. RIH log from 6700' up to 4900' Make two runs to reperforate 6348'-6390'. Run gauge ring 6" junk basket to 5530' stuck tool. Work & try free tool. RIH with fishing tools. 76,813 CUM:$ 948,756 ETD:$ 0 EFC:$ 1,853,756 10/14/96 (C 10) TD: 6788' PB: 6788' SUPV:DLW DAILY: $ RUN BAKER PERM PKR ON DP MW:10.2 Continue RIH to 5518' Nordic depth. Pump down DP engage fish @ 5527' Work pipe. POOH Recover gauge ring junk basket. RIH with 2-7/8" permanent packer with tail assembly. Set packer top @ 6502'. RIH with seal assembly and permanent packer 'FB-i' . 43,560 CUM'$ 1,035,876 ETD $ 0 EFC'$ 1,940,876 10/15/96 (C 11) TD: 6788' PB: 6788' SUPV:DEB DAILY:$ RACK & TALLY 4" TUBING MW:10.2 RIH with 2-7/8" seal assembly. Stab seals into TIW permanent packer. Verify seals with 500 psi. Packer set @ 6217' 33,75~ CUM'$ 1,103,380 ETD'$ 0 EFC'$ 2,008,380 10/16/96 (C 12) TD: 6788' PB: 6788' SUPV:DEB DAILY:$ MU CONTROL LINE TO TBG HA MW:10.2 BRINE Load 4" & 3.5" tubing and jewelry into pipe shed. Run 3.5" x 4" completion assembly. Latch Baker anchor-seal assembly into FB-1 packer. Set FHL packer. PBR sheared @ 2300 psi. Held 2500 psi for 30 min. 35,658 CUM:$ 1,174,696 ETD:$ 0 EFC:$ 2,079,696 10/17/96 (C 13) TD: 6788' PB: 6788' SUPV:DEB DAILY:$ RIG RELEASED MW: 0.0 BRINE Test SSSV control line to 5000. psi. Land 4" tubing hanger. Test tubing to 2500 psi for 15 min., OK. Test annulus to 2500 psi for 15 min. OK. ND BOPE stack. NU tree. Set TP. Test packoff to 5000 psi, OK. Test tree to 250 psi & 5000 psi, OK. Freeze protect well. Secure well. Release rig @ 2400 hrs. 10/17/96. 298,029 CUM:$ 1,770,754 ETD:$ 0 EFC:$ 2,675,754 End of WellSummary for We11:998632 RECEIVED FEB 5 1997 Alaska Oil & Gas Cons. Commi~i~rt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown__ Stimulate __ Alter casing Repair well __ 5. Type of Well: Development X Exploratory __ Stratigraphic __ 99510 Service__ 4. Location of well at surface 62' FSL, 181' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1255' FSL, 1169' FEL, Sec. 19, T12N, R9E, UM At effective depth 1482' FSL, 1359' FEL, Sec. 19, T12N, R9E, UM At total depth 1567' FSL, 1430' FEL, Sec. 19, T12N, R9E, UM 12. Present well condition summary Plugging __ Perforate X Other 6. Datum elevation (DF or KB) RKB 93 feet 7. Unit or Property name Kuparuk River Unit Total Depth: measured 69 75' true vertical 63 32' Effective depth: 8. Well number 3F-14 9. Permit number 85-292 10. APl number 50-029-21500 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Pedoration depth: measured 6 7 88' true vertical 61 87' Length Size feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 76' 16" 3025' 9 5/8" 6839' 7" measured 6336'-6442', true vertical 5837'-5919', 340 Sx AS II 1 15' 1 15" 900 Sx PF 'E'& 3064' 3064' 340 Sx Class G 250 Sx Class G & 6878' 6257' 175 Sx PF 'C' 6637'-6680', 6594'-6618' 6070'-6103', 6036'-6055' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 EUE to 6494', 2 7/8", 6.5#, J-55 EUE w/ tbg tail at 6528' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SAA @ 1812', PACKERS: Otis RRH @ 6265', Otis WD @ 6505' 13. Stimulation or cement squeeze summary Intervals treated (measured) SEE A'i-I'ACHED SUMMARY 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1260 450 7800 1380 250 1330 720 8100 1380 250 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 7. I here~ify that the foregoing is true and correct to the best of my knowledge. ~igned Title Wells Superintendent Form,~0'~ ~:1~,/'0o~'15/8~ - Date h---. y..-~-~/ SUBMIT IN DUPLICA ~ b ARCO Alaska, Inc. KUP~kRUK RIVER U'NIT 'k '~ '" '~g' WELL ~SERVICE REPORT Kl(3F-14(W4-6)) . . WELL JOB SCOPE JOB NUMBER 3F- 14 PERFORATE, PERF SUPPORT 0522960746.1 DATE DALLY WORK · - UNIT NUMBER 05/28/96 PERF 'A' SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES SWS-JOHNSON PAIGE FIELD AFC# CC# DAILY COST ACCUM COST - Signed ESTIMATE KAWWRK 230DS36FL $10,064.00 $16,334.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 350 PSI 350 PSI 1360 PSI 1360 PSII 1360 PSI[ 1360 PSI DAILY SUMMARY IREPERFED A3 SAND INTERVAL F/6596'-6616' (REF DIL DATED 12/24/85) USING 2-1/8" EJ W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED +/- 90 DEG F/LOWSIDE. WHP INCR 30011 FOLLOWING PERFORATING. TIME LOG ENTRY 13'30 MIRU SWS. HELD SAFETY MTG. 15'30 PT LUB TO 300041; TEST OK. RIH W/GUN#1 - WGT. BAR, MPD, CCL, 2-1/8" EJ W/BH CHARGES, 2 SPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSIDE TO SHOOT 6596'-6616' 16:45 TIED INTO DIL DATED 12/24/85: 17:00 FIRED GUN#1' POH. WHP INCR 200g Ab-TER FIRING. , 17'30 AT SURF W/GUN#1' ALL SHOTS FIRED 18:00 PT LUB TO 300Og; TEST OK. RIH W/GUN#2 - WGT. BAR, MPD, CCL, 2-1/8" F_.J W/BH CHARGES, 2 SPF, 0 DEG PH, ORIENTED 90 DEG CW F/LOWSIDE TO SHOOT 6596'-6616' 19:00 TIED INTO DIL DATED 12/24/85; FIRED GUN#2. POH. 19:30 AT SURF W/GUN#2: ALL SHOTS FIRED 20:30 RDMO. I I 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator 5. Type of Well: Development ARCO Alaska. Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 62' FSL, 181' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1255' FSL, 1169' FEL, Sec. 19, T12N, RgE, UM At effective depth 1482' FSL, 1359' FEL, Sec. 19, T12N, R9E, UM At total depth 1567' FSLr 1430' FELr Sec. 19r T12N~ R9E, UM 12. Present well condition summary Total Depth: measured 69 7 5' feet true vertical 6332' feet STATE OF ALA,SKA ~ ~: ~' ~ AL~ OIL AND GAS ~SERVATION C.,oMM~oN REPORT OF SUNDRY WELL OPERATIONS Plugging Perforate ~X __ Other 6. Datum elevation (DF or KB) Plugs (measured) Stimulate Repair well Effective depth: measured 6788' feet Junk (measured) true vertical 61 8 7' feet NOlle RKB ~t3 fee~ 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-14 9. Permit number 85-292 10. APl number 5o-029-21 500 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 340 Sx AS II I 1 5' I 1 5' 900 Sx PF 'E' & 3064' 3064' 340 Sx Class G 250 Sx Class G & 6 8 7 8' 6 2 5 7' 175 Sx PF 'C' 13. Casing Length Size Structural Conductor 7 6' I 6" Surface 3 02 5' 9 5/8" Intermediate Production 6 83 9' 7" Liner Perforation depth: measured 6336'-6442', true vertical 5837'-5919', 6637°-6680', 6594'-6618' 6070'-6103', 6036'-6055' RECEIVED Tubing (size, grade, and measured depth) MAY - 6 1992 3 1/2", 9.3#, J-55 EUE to 6494', 2 7/8", 6.5#, J-55 EUE w/ tbg tail at 652°~aska0jJ& Gas Cons, Commis', Packers and SSSV (type and measured depth) Anchorage SSSV: Camco TRDP-1A-SAA ~ 1812'~ PACKERS:Otis RRH @ 6265', Otis WD @ 6505' Stimulation or cement squeeze summary Intervals treated (measured) ADD A3 SAND PERFS: 6594'-6618' 14. Treatment description includin~ volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1260 450 7800 1380 250 1330'~ 720 8100 1380 250 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Water Injector __ Daily Report of Well Operations X Oil X Gas .. Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si~lned ~""., ~b), ~ Form 10-404 Rev 09/12/90 Title Operations Engineer Date '-,~' / '~- / ~ ~.~- SUBMIT IN DUPLICATE [on R~.._..~rt of Sundry Well Ope~_.~ons Kuparuk River Unit Well 3F-14 April 22, 1992 On February 18, 1992, ARCO Alaska, Inc. added perforations in the A3 interval of the Kuparuk Sands on Well 3F-14. The perforations were completed with a 2 1/8" HLS Dynastrip from 6594' to 6618 MD at 6 SPF, and 0 degree phasing. REEEIVED MAY - 6 992 Alaska Oil & Gas Cons. Commission Anchorage 'WELL ~ Sub$idia~ of Atlantic Ricl~field Company ~ipBDT CONTRACTOR FI ELD- DISTRICT. STATE OPERATION AT REPORT TIME I DAYS i DATE EMARKS ~r C~,r' ~, c!2.1~.1, o° 0900 103o JO~' I~.o0 PT 3 ooo l'z~ O P~ i ow{. /-.-oG Ope~ ~z~o POOI-f · 0014 I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~taska Oil & Gas Cons. Commission Anchorage Report °F °F . mile~ IWind Vel. IS~ned REMARKS CONTINUED: DI:SC RI FI'ION DAILY ACCU M_ TOTAL CAMCO -- OTIS SCHLUMBERGER . DRESSER-ATLAS i DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFL _ _- _ -- TOTAL FIELD ESTIMATE ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the .following items. Please acknowledge receipt and return one signed copy of this transmittal. 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-1 1._~ 3 A--'0 3 3H-01 2Z-19 31-12 1E-08 3M-18 Ku 3aurk Ku 3aurk Ku3aurk Ku3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku3aurk Ku3aurk Ku3aurk Ku3aurk Ku )aurk Ku )aurk Kupaurk Kupaurk Kupaurk Kupaurk Kuparuk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 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 4-20-87 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 2-20-89 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' Amerada Casing Casing Casing 3 H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron .. ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and. return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Ku~aruk Well Pressure Report Ku ~aruk Ku ~aruk Ku 2aruk Ku :)aruk Ku 2aruk Ku ~aruk Ku :)aruk Ku :)aruk Ku 2aruk Ku 2aruk Ku3aruk Kuparuk Kuparuk Kuapruk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk 10-06-88 8-29-88 Well Pressure Report I 2- 2 0 - 88 Well Pressure Report 8 - 29 - 8 7 Well Pressure Report 8 - 29 - 87 Well Pressure Report 8 - 29 - 89 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 29 - 8 7 Well Pressure Report 6 - 26 - 8 7 Well Pressure Report 1 2- 1 2 - 88 Well Pressure Report 1 2- 31 - 88 Well Pressure Report 6 - 1 I - 87 Well Pressure Report 6 - 1 1 - 8 7 Well Pressure Report 9 - 01 - 8 7 Fluid Level Report 5 - 04 - 8 7 Fluid Level Report 2 - 1 3 - 89 Fluid Level Report 2 - 1 0 - 89 Fluid Level Report 2- 1 0- 89 Fluid Level Report 6 - 05 - 8 7 Fluid Level Report 6 - 09 - 87 Fluid Level Report 6 - 1 8 - 87 Fluid Level Report 6 - 1 6 - 87 Fluid Level Report 6- 21 - 8 7 Fluid Level Report 5 - 08 - 87 Fluid Level Report 8 - 1 8 - 87 Fluid Level Report 8 - 24 - 87 Fluid Level Report 6 - 05 - 87 Fluid Level Report 6 - 2/3 - 8 7 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 - 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casin~,~_~ .~~ ~ Commissio,.] Casing Ar~chorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk. Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Acknowledged: Level Report 9 - 1 I - 87 Level Report I 2 - 0 6 - 86 Level Report - 9-11-87 Level Report I 0 - 1 I - 87 Level Report 9 - 1 6 - 87 Level Report 4- 1 I - 88 Level Report 4 - 0 8 - 88 Leyel Report 4 - 01 - 88 Level Report 3 - 26 - 88 Level Report 1 - 3 0 - 88 Level Report I 0 - 1 2 - 87 Level Report 10 - 1 5 - 87 Level Report I 0 - 28 - 87 Level Report I 0 - 28 - 87 Level Report 10 - 28 - 87 Level Report I 0 - 28 - 87 Level Report 3 - 1 9 - 87 Level Report 9- 1 2 - 87 Level Report 9 - 1 0 - 98 Level-Report 9 - 1 0 - 87 Level Report 9 - 1 0 - 87 Level Report 9- 1 2 - 87 Level Report 9 - 08 - 87 Level Report 9 - 01 - 87 Level Report 9 - 01 - 87 Level Report 9 - 0 6 - 87 Level Report 9 - 0 6 - 87 Level Report . 9 - 0 6 - 87 Level Report 9 - 0 6 - 87 Level Report 6 - 01 - 87 Level Report 5 - 31 - 87 Level Report 6 - 03 - 87 Level Report 6 - 0 6 - 87 Level Report .6 - 0 8 - 87 Level Report 6 - 0 9 - 87 Level Report 6 - 25 - 87 Level Report 4 - 1 7 - 87 Level Report 4 - 1 8 - 87 Level Report 6 - 1 7- 87 Level Report 6 - 20 - 87 Level Report 5 - 0 7 - 87 Level Report 8 - 24 - 87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & ~as Cons. ....... ¢'m~,Orage Ccrnmissjoij DISTRIBUTION: D&M State of Alaska ~ Mobil Chevron Unocal SAPC STATE Of ALASKA ~ ;. '-' ALASKA iD~L AND GAS CONSERVATION cOi~rMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of 9ervice Well OIL {~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2.Ar~acr~e/~ Op. erator. 7. Permit Number asKa, Inc. 85-292 ~.~Z~,dd,,res%, 8. APl Number ~', u. uOX 100360, Anchorage, AK 99510 50- 029-21500 , 4' L°'cati°n°flwell'atsurface62' FSL' 81 9. Unit or Lease Name FEL, Sec,19, T12N, RgE, UN Kuparuk River Unit ~'~p Producina Interval 10. Well Number FSL, 1T69' FEL, Sec.19, T12N, R9E, UN 3F-14 F~_P~hl 11. Field and Pool f~6T79tal__ 430' FEL, Sec.19, T12N, R9E, UM Kuparuk River Field 5. E~l_ev, atigp_in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool ADL 25632 ALK 2565 · dded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/24/85 1 2/25/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6975 ' MD ,6332 'TVD 6788 'MD ,6187 'TVD YESXI~ NO [] 1813 feetMD 1500' (Approx) 22. Type Electri.c or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, GR, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16:: 62.5# H-40 Surf 115' 24" 340 sx AS II ~-b/8" :~6.U# J-55 5urf 3064' 12-1/4" 900 sx PF "E" & 340 sx Class "G" 7" 26.0# J-55 Surf 6878' 8-1/2" 250 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6637' - 6680' w/4 spf 3-1/2" 6528' 6265' & 6506' 6336' - 6442' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 277/A PRODUCTION TEST Date First Production I Method of Operation {Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI[-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD. e Flow Tubing Casing Pressure CALCULATED OIL-BBE GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press· I24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 * NOTE: Tubing was run & well perforated 2/2/86. WCl/056 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~ 30. GEOLOGIC MARKEI~S -FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6332' 58:34' N/A Base Kuparuk C 6441' 5918' Top Kuparuk A 6573' 6020' Base Kuparuk A 6683' 6106' · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~(~'~ ~ Associate Engineer Signed Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injeCtion, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~,tlanticRichfieldCompany '~, Daily Well History-Final Report rnatrucllonl: Prepare and submit Ihs "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. · 'Final Rel~3rt" should be submilted also when operations are suspended for an indefinite or apl~reciable 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 Rel3ert" form may be used for reporting the entire operation if space is available. District JCounty or Parish Alaska J North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no, I Title AFE AK0529 I Completion Nordic 1 API 50-029-21500 Operator ~ A.R.Co. W.I. ARCO Alaska, Inc.I~ 56.24% Spudded or W.O. begun Date Complete 2/1/86 2/02/86 thru 2/o3/86 Date and depth as of 8;00 a.m. Complete record for each day reported IAccounting State cost center code Alaska IWell no. 3F-14 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our IPrior status if a W.O. 2030 hrs. I 7" @ 6878' 6762' WLM PBTD, Ri{ 6.8 ppg Diesel Accept rig @ 2030 hrs, 2/1/86. ND tree, NU & tst BOPE. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/6637'-6680'. Perf w/5" gun, 12 SPF, 120° phasing f/6336'-6442'. Make gage ring, JB rn to 6600'. Set WD pkr @ 6494' WLM, RD Schl. RU & rn 202 its, 3½", 9.3#, J-55 EUE 8RD IPC tbg w/WD pkr @ 6506', "D" nipple @ 6520', RRH pkr @ 6265'. TT @ 6528', SSSV @ 1813'. Set RRH pkr, tst tbg to 2500 psi. Tst pkr & SSSV. ND BOPE. NU & tst tree to 5000 psi. Displ well to diesel. 'Tst orifice vlv. RR @ 2400 hrs, 2/2/86. Old TD New TD PE~ Depth 6792 ' W~M PBTD Released rig Date K nd of rig 2400 hrs, 2/2/86 Rotary Classifications (oil, gas, sic.) I Type completion (single, dual, etc.) Oil I Single Producing method J Official reservoir name(s} Flowing I Kuparuk Sands Potential test data Well no. Dale Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date Corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Superintendent ARCO Alaska, Inc, Post Office ~ 100360 Anchorage~?AY, aska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal fl 5926 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. and return one signed copy of this transmittal. 3Q-8 CBL 2-16-87 6195-9264 2H-6 CET 1-17-86 7400-8873 2H-5 CET 1-16-86 6525-7959 3F-13 CET 1-7-86 6160-7920 3F-12 CET 1-23-86 6946-7250 2H-8 CET 1-1-86 8000-8650 2H-7 CET 1-1-86 6800-7938 3F-14 CET 1-7-86 4700-6760 3K-5 CET 7-16-86 6988-7990 3K-3 CET 7-14-86 7595-8800 3K-4 CET 7-14-86 7793-8787 3F-12 CET 1-7-86 6050-7416 Please acknowledge receipt % 0mmlss te: NSK , Drilling State (+ sepia) BPAE Chevron .., SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary o( AllartticRichlieldCornpany ARCO Alaska, Inc. Post Office B0.~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports and gyroscopic surveys for the following well s' 3F-14 3F-13 I have not yet received the Well Histories (completion details). When I do, I will forward copies to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L119 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OY' AND GAS CONSERVATION CO",~MISSION WELL COMRLI::TION OR RI:COM LI TION RI I ORT AND LOG 1. Status of Well Classification of ~;ervlce Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 85-292 3. Address 8. APl Number 50-- 029-21500 P. 0. Box 100360, Anchorage, AK 99510 ,_ ..... _ 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 62' FSL, 181' FEL, Sec.19, T12N, RgE, UM VERI~D'- Kuparuk River Unit At Top Producing Interval .S. unc. -I~, 10. Well Number 1255' FSL, 1169' FEL, Sec.19, T12N, RgE, UH B.H..,,~-~ 3F-14 At Total Depth -- 11. Field and Pool 1567' FSL; 1430' FEL. Sec.19; T12N; F~gE. UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93 ' RKB AD 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 2/20/85 I 2/2b,/RS 1 ?/?S/Re,* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6975'MD.6332'TVD 6788iMD.6187.TVD YES I~XX NO [] 1R1~ feet MDI lC;all1' (Annrn~ 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL, GR, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not yet received. 9-5/8" :36.0# J-55 Surf 3064' 12-1/4" 900 sx PF "E" & 340 sx Class "G" 7" 26.0# J-55 Surf 6878' 8-1/2" 250 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6637' - 6680' w/4 spf 3-1/2" 6528' 6265' & 6506' 6:336' - 6442' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 * NOTE: Tubing was run & well perforated 2/2/86. TEMP3/WC73 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A .: GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 6332' 6441~ 6573' 6683' 5834' 5918' 6020 ' 6106' 30. FORMATION TESTS Include interval tested, pressure ~la{a, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History; Gyroscopic $,,rv~.y (2 ~.npies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Ga.s Injection, Shut-in, Other-explain. ... Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company O, Well History - Initial Report - Daily' Inelructlone: Prepare and submit the "lnltlel 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 Field I County, parish or borough IState A':]-aska Alaska North Slope Borough I Lease or Unit IWell no. Kuparuk River ADL 25632 _ 3F-14 I Title Drill Auth. or W.O. no. AFE AK0529 Doyon 9 API 50-029-21500 Operator IARCO W.I. ARCO Alaska, Inc. ' ~ ~ Date and depth aa of 8:00 a.m, [2/2~/85 _~ l:hru 12/2.3/85 12/24/85 Complete record for each day reporlad:/ : . . : ~_~ :: .: if a W.O. 56.24% ~ divercer sys. Accept ri~.~. 1500' hrs;:~:t2/20/85~i.~_16": ~:: i15'. : Spud well ~ 1645 hfs,- 12/20/85~ DrI. S su~-~ 12~Fh01e ~o.' 308~ short trip, CiC. PO~:; RU~ r~:77 jts,.~9-5/8";36~:J-55 HF-~W: BTC csg w/FC ~ 2981'~ FS ~ 3064~'; Cm~:_w/90G-.sx:~F"E" & 34Osx: C1 "G" w/21 CaC12. CI~ ~ 2322 hrs':.12/2;1/8~;~::~ 20"%:': ~ a:: Cst BOPE. RIH wTB~, DO FC". cmt, FS.+ new: hole; to 3090', Conduct fomtion tst to 12.5 ppg ~,~ Drl t su~ 8~' hole to 4842'. 3100', Ass~ed vertical 3275', 3.3~, N39.75W, 3274.9 ~, 13.1 VS, 3.9N, 3.2W 3556', 12.0°, N46.75W, 3553.1 ~, 72.3 VS,_ 31.5N, 28.8W 4120', 26.6~, N38.75W, 4087.3 T~, 218.4 VS, 156.7N, 153.5W 4529', 39.9°, N37.75W, 4428.7 T~, 441.8 VS, 335.2N, 287.9W 9-5/8" @ 3064' 6975', (2133'), Short trip f/logs Wt. 9.8+, PV 10, YP 5, PR 9.5, WL 6.0, Sol 10~ Navi-Drl & surv to 6975', CBU, shore trip. 4750', 39.3", N36.75W, 4599.0 TVD, 582.5 V$, 447.4N, 373.1W 5380', 37.9~, N36.75W, 5091.7 TVD, 974.9 VS, 759.9N, 610.8W 6015', 38.7~, N37.75W, 5589.0 TVD, 1369.5 VS, 1073.1N, 851.1W 6331', 39.4~, N37.75W, 5834.4 TVD, 1568.5 VS, 1230.5N, 973.0W Tho above Is correcl Signature o P P I~] stributlon, see Proce~ture$ Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter 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 te~t 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 Parish I Alaska Field ~Lease or Unit Kuparuk River Aulh. or W.O. no. ITitle AFE AK0529 J Drill Doyen 9 API 50-029-21500 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Spudded I 12/20/8'5 Accounting cost center code State North Slope Borough Alaska I WoII no. ADL 25632 3F-14 Dale and depth as of 8:00 a.m. 12/25/85 thru 12/26/85 Complete record for each day reported Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 1645 hrs. 7" @ 6878' 6788' PBTD, RR 6975' (0) TD 9.8 ppg Brine Fin short trip to 3200', wsh & rm 6912'-6975', C&C, POH, had gas cut mud off btm, POH f/logs. RU Schl, rn DIL/SFL/SP/GR f/6966'-3059', GR f/3059'-1700', FDC/CNL f/6940'-6100', CAL f/6940'-3059', RD Schl. RIH to 6900', C&C, 20 std short trip, POH. RU & rn 158 jts, 7", 26#, J-55 BTC csg w/FC @ 6788', FS @ 6878'. Cml w/250 sx C1 "G" .6% FDP-C344 & .25% HR-5. CIP @ 1517 hrs, 12/25/85. NU & tst tree to 3000 psi. Ri{ @ 1800 hrs, 12/25/85. 6910', 39.5°, N37.75W, 6281.5 TVD, 1936.4 VS, 1521.5N, 1198.3W Old TD New TD Released rig Date 1800 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential lest data Depth 6975' TD IKind of rig 12/25/85 I IType completion (single dual, etc.) S ingle ' Official reservoir name(s) Kuparuk Sands 6788 ' PBTD Re tary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ;Effective date corrected The above is correct Signature~ ~ I /~"/"~' ~'/~'''/~1 Date JTJtle For form preparation and ~istribution, - ' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent $UB.~URFACE DIRECTIONAL ~URVEY [~UIDANCE F~ONTINUOUS r'~OOL Company , Well Name ,, Field/Location ARCO ALASKA INCORPORATED WELL 3F-14 (62' FSL, 181' FEL, S19, T12N, R9E) i II I ii KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71174 SARBER i ~'~ Dat. e Computed,, ,By: OGDEN GCT DIRECTI]N~L SIJRV=Y ~USTDHER L!STIN$ ~RC] &L~SK~, IN'. 'DF-I~ KUP&RUK METHODS O~ CDqPU[~TION TOOL LDCATI2N: T~NSENTI~L- INTERPD~TI]N: LINEAR VErTICaL SECTION: ~ORIL. DIST, NORTH SURVEY DATE: 08-J~N-86 ENGINEEr: G. S&RBER DEVIATION &,NL~ PROJECTED OWT'3 ,~ T~RG:"-'T aZI~IdTH .aZIMUTH OF ~I3R T-i 17 ARCO fiLASKA, INC, 3=-14 KUPARU~ N3RTH SLOPE,AL4SKfi DATE: 24-J ~N-,.q 5 INTERPOL~T=_D V~LJES ,=OR :VEN 100 FEF-T OF '4Ea, SURE TRUE SiS-SE& MEASURED VERTICAL VERTIC&L DEPTH DEPTfl DEPTH C3JRSE V=RTICAL D3S_EG RECT~'J DEVI&TIDN &Z!MUTfl SECTION SEV:RiTY NTRTH/ DEG MIN DEG MI~ FE:T DES/lO0 0,00 0,00 -93,00 1DO,OD 100,00 ?,00 ZO0,O0 200,00 107,00 3DO,OD 300,00 20?,00 400,00 399,99 306,99 500.00 499.99 405.99 SDO.DO 599.99 505.99 730.00 699.99 535.99 800.03 799.98 705.98 900.00 899.97 805.97 0 0 N 0 0 E 0,00 0 11 S 53 47 E -0,09 0 13 S 18 50 E -3.43 0 21 S 39 3 E -0,93 0 29 S 45 49 E -1,67 0 28 S 50 ? E -2,48 0 27 S ~8 20 E -3.28 0 27 S 51 43 E -q.06 0 ,36 S 53 38 E -5.00 0 ~3 S 56 21 E -6.12 lO00.OO 999.96 906.96 llDO.O0 1099,96 1006.96 1200.00 1199.95 1105.95 1300,00 1299.95 1206.95 1400.00 1399.95 1305.95 1500,00 1499,94 1~05,9¢ 1600,30 1599,94 1505,94 1TO0.O0 1699.93 1605.93 1BDO.D0 1799.~3 1705.93 1900.00 1899.93 18016.93 0 ~.5 S 59 52 ~ -7,35 0 ~+2 S 62 2 E -8.56 0 26 S ~0 1 E -9.45 0 25 S 33 5 E -10,21 0 Z5 S ~G 2'7 E -10,95 0 28 S 70 5 E -11,88 0 32 S 7.5 ~ E -12.41 0 36 S 53 14 = -13.24 o 27 s ~2 ~ ~ -1~.3o o 19 s 21 52 ~ -1~.91 2000,00 1999,73 1905,93 2100,00 2099,)2 2006,92 Z2DO,O0 2199,92 2105,92 2300,0D 2299,92 2206,92 2~00,00 2399~82 2305,92 2500,00 2499,92 2~06,92 2600,00 2599-92 2505,92 2700,00 2699~92 2605,92 28~0.00 2~9~,'92 2705.92 2900.00 Z,~,99.91 Z805.91 0 13 N 69 18 6 -15,27 0 17 N 68 18 E -15.45 0 13, S 28 2t 6 -15.49 0 5 S 81 Z? W -16.56 0 7 ~ ~ 53 E -15,~0 0 5 N I 5~ ..: -15.32 0 7 N 6~ .31 = -15,19 0 22 S 57 Z'~ E -15.53 0 27 S 60 2~ E -17.30 25 S 52 55 ~ -1M.05 10 S 17 3?+ E -18.5/+ 5 N 78 23 W -18.76 54 N ~2 2T ~ -15.97 16 N 39 12 W -6.30 6 N ?+5 7 W 8.67 25 N 45 35 W 28.93 30 N 45 29 N 53,91 1 N ?+9 38 W 81.48 4 N 48 ~3 N 111.93 3000.00~ Z905.91 3100.00 3006.91 3200,0D 3:1 3105.91 3300.00 32'99~85 3205.85 3400.00 3399,36 3306.36 3500.00. 3498,22 3405,22 3500.00 3596,10 3503.10 3?OD.OD 3692,87 3599.87 3800,00 3788.91 3595.91 3900.00 3883.97 3790.97 0 0 0 3 7 10 13 15 17 19 0.00 O. 0.53 O. 3.11 O. 0.2~ O. 2.25 !. 0.09 1. 3.08 Z. 0.05 2. 0.10 3. ,3.08 3.18 4. 3.23 O.lq. 6. O.ZZ 6. 0.18 0.15 7. 3.22 7. O. 67 0.55 0.17 9. 0.27 9. O.Z~ 0.22 0.51 10. 0.25 lO. 3.07 9.3,5 9. 0.55 9. 0.41 0,07 10. 0.28 10. 0.83 10. 0.97 11 · ~+.14 9. 2.67 1 · 2.50 9. 2.61 23. 1.69 41. Z. 55 59. 2.49 79. K-LLY 3USqIN" ENGINEER: ~. FT SJL~2 CO SOOT~ T F O0 N Z 6 S 71 S 24 S 1'8 S 31 S ,33 S ~2 S 7~ S ~ 1 S 01 S 1) S 51 S 77 S 1 03 S 1 89 S 1 50 S 1 7i S 1 55 S 1 5 ? S I 21 S 1 17 S 1 06 S 1 ~:9 S ! 73 S 1 ~6 S 1 30 S 1 ?o s 95 S 1 2~ S 1 21 S 1 93 S 29 N 47 N 1 07 '~ 3 79 q 5 56 ~ 7 ,]ROI'.JAT:S ,ERIZ. 3EmqRTURE S.T/WEST 9'ST~ , AZIqUTH EET FEST '3~3 0 O0 : 0 O0 0,15 = 0.15 0.37 rZ 0.45 0.50 r. 0.93 1.12 E 1.67 1.75 E 1.49 2.35 E 3.30 2.'~5 r. 4.09 ~.65 E 5.20 5.78 E 7.50 6.90 E ~.77 7.58 E 9.67 -3.07 E 10.~2 i{.58 ~ 11.16 :~.2.? E 11.93 O.11 E 12.75 1 04 : 13 68 · ,,: · !,72 : 14.71 1.9~ E 15.26 2.26 2.72 3.32 3.7 Z 3.69 3.68 4.05 4.72 5.44 E 5.91 E 5,90 E 3,97 E 7,59 E 2.33 W 7,00 W 4.94 W 5,59 W 9.40 W N O 0 E ~J 34 2'3 -' S 55 30 E S 43 32 E S 44 2 S 45 27 ~ S 45 13 ~ S 47 17 6 S 4.~ 33 E S 53 23 : S 51 53 : S 51 37 S 50 45 : S 30 14 E S 53 59 E S 52 27 :_ S 53 ~9 ~ S 52 49 'E S 51 30 1'~.78 S 55 17 E 19.31 S .55 27 ': 1~.47 S 5~ 45 ::-_ 1,5.73 S 55 36 F 7.83 S TS 42 ,:J :-).58 ',~14 4 W 28.9~ N 35 54 ~ 53.9~ q 40. 23 W 81.54 ~ 42 54 W ARCO ~LASKA, INC. 3-'-14 KJPARUK NDRTH SLOPE,ALASKA TRUE ME~SURE2 VERTICAL DEPTq DEPT~ 4000.00 3977.75 4100.00 %068.90 '4200.00 4157.37 4300.00 4243.17 4400.00 4326.03 4500.00 4405.30 4590.00 %482.11 4730.00 4559.14 4800.00 ~636.48 4900.00 4714.36 5DDO.O0 4792.52 5100.00 %870.72 5200.00 4949.16 5300.00 5027.36 5400,00 5106,78 5500.00 5185.37 5500.00 5263.76 5?00.00 5342.00 5800.00 5420,08 5900,00 5498.16 6000.00 5576.14 6100.00 5654.04 6200.00 5731.74 6300.00 5809.07 6400.00 5886.18 6500.00 5903~77 6600,00 $041-23 6700. O0 $1.1.8' '?3 6~00.00 ~1,' 69 D 0 · 00 l~;' '6 ? 697~.oo r , COMPUTaTI]N DETE: INTERPOLqTEO VaLJES ~DR EVEN lOD SJB-SE~ COJRSE VERTICAL VERTICAL DEVIATION ~ZIMUTq SECTION DEPTH lEG MIN DEG MIN FEET 3884.75 22 1 N 42 54 W 145.35 3975.90 26 15 N 40 20 W 187.39 %06%.37 29 19 N 38 4 W 233.96 4150.17 32 23 N 37 25 W 285.27 ~233.03 35 50 N 38 38 W 341.19 4312.30 39 20 N 39 5 W 402.11 ~389.11 39 46 N 3~ 55 W 455,15 %466.14 39 27 N 35 52 W 529.91 ~543.48 39 T N 38 4~ W 593.30 4621,36 38 40 N 38 53 W 655,0~ %599.52 38 34 N 38 45 W 718.41 ~777.72 38 31 N 38 35 W 780.72 4855.16 38 8 N 3~ 39 W ~42,75 4934.96 37 55 N 38 39 W 90¢.31 5013.78 38 2 N 3~ 48 W :955.86 5092,37 38 25 N 38 41 W 1027.69 5170,76 38 25 N 3~ 54 ~ 1089,76 5249,00 38 37 N 39 2 W 1152,05 5327,08 38 ~9 N 39 12 W lZ14,53 5405,16 38 42 N 39 1~ W 1277,00 5483,14 38 %9 N 39 34 W 1339,61 5561,04 38 52 N 39 50 W 1402,30 5638,74 39 13 N 39 55 W 1465,25 5715,07 39 24 N 39 5~ W 152~,65 5793.18 39 25 N 39 43 W 1592.33 5870,77 39 10 N 39 41 W 1655,41 594~.23 39 13 N 3~ 5~ W 1718.63 5025,73 39 3 N ~0 1 W 1781.83 5103,20 39 13 N 40 1 W 1845,06 5180,67 39 13 N 40 1 W 1908,29 5238,77 39 13 N 40 1 W !955.71 24-JIN-85 D~TE 0= SURVEY: KELLY ~lJSfli~3 ~SINEE~: G. Z = T FEET OF MEaSURS] DEPTH DOGLEG RECTaNGUL.~R COORDINATES ~3RIZ. SEVERITY NORT:q/SDUT~ EaST/WEST DIST. DES/lO0 ~EET FEET FE~T ~.74 103.77 ~ 104.29 W 147.12 3.17 134.52 N 131.51 W 1~3.12 3.35 170,54 N 160,9~ W 234,54 2.84 211.43 N 192.98 W 235.55 3.14 255.43 ~ 225.55 ~ 341.~6 2.33 302.54 N 25%.85 W ~02.~3 0.29 352.52 ~q 305,17 W ~56.33 0.23 ~02.22 '~ 345.23 W 530.06 0.53 ~51.50 ~ 3:~.')8 ~ 593.~2 3,24 500,44 ~ 42~.35 W 555,14 0.15 549,04 N 453.45 W ?1~.50 0.21 597,70 N 502.38 W 780.79 0.35 546.17 N 541.10 W ~42.31 0.12 594,22 N 57~,58 W 904.35 0.42 742.27 N 61~.05 W ~65.'~0 9.35 790,47 N 655,77 W 1027.72 0,22 838,54 N 695,69 W 1039,79 0,14 ~87,26 N 734,87 W 1152.07 0.20 ~35.73 N 77~.30 W 1214.55 0.18 9~4.10 N 813.~4 W 1277.02 3.63 1032.45 N 853.50 W 133~.62 0.23 1080.58 N 893.57 W 1402.~3 0.38 1128.9.4 N 934.03 W 1~55.27 3.27 1177,52 N 974.71 W 152~.57 1.72 1226.~9 N 1015,54 W 1592.36 0.15 1275,0.5 N 1055,30 W 1555,44 0,5~ 1323,52 >4 1096,29 W 171B,57 !,61 1372,03 N 1136,92 W 1751,B7 O,OO l~20.&5 N 1177,59 W 1~45.10 0,00 1~68.87 N 1218,25 W 1908.33 aZI~UTW DES ~I~ ~ 40 2 .~ ~ 3) 56 ~ N 39 51 ~ N 39 4,5 ~ ~ 3'.9 37 W N 39 3,6 ~ ',J 39 35 ~ D.OD 1505.19 N 1248.75 W 1~55,76 ~ 39 &O w aRCO ~L~SKa, INC. 3F-14 N]RTH SLOPE,ALaSKA TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 999.96 2000.09 1999.93 30DO.O0 2999.91 4000.90 3977.75 5090.90 ~792.52 6000.00 5576.1~ 6975.09 5331.77 COmPUTaTION O~TE: 24-J~N-g5 [NTE]POL~TED VALJES FOR EVEN 1003 FEET SJB-SE& COURSE V~RTtCAL DOGLEG V~RTIC.&L DEVIATION ~ZIMDTq SECTION SEV':~iT¥ DEPTH OSG ~IN OEG MIN =E~T 3E3/100 -93.00 906.95 1905.93 Z905.91 388%.75 ~59'~.52 5483.1~ 5238.77 0 0 N 0 0 E 0.00 0.09 0 ~5 S 59 52 : -7.35 0 13 N 59 19 E -15.27 0.27 0 25 S 62 55 5 -18.05 0.2~ 22 1 ~ ~Z 5~ W 1~5.35 ~.7~ 38 34 N 38 45 ~ 718.41 0.15 38 ~9 N 39 3~ ~ 1339.61 0.63 39 13 N ~0 1 W 1955.71 3.00 gATE 3= 'SJRYEY: O,~-J~'~-'~5 K~LLY 6USHi'~S ELTV~T:7~: ~NGiNE~: S. S~;SE~ FT :3 OE~T R "' ' T &,'.Jg'J L ~ R CD ]R'] I~.~T'E S H~RTH/'SO,JTH ~EZT FEET O.O0 N O.O0 4.7~ $ 5.73 9.71 S 12.!5 10.70 S 15.~ 103.77 N 10~.£9 5~.0~ ~ ~,53.a6 1332.45 '1 953.S0 150=.!9 q 1Z~.75 2ZI~UTW 7.50 S 53 23 z 15.64 S 51 37 c 18.75 S 5~ 17 ~ 147.12 ~ 45 ~ ' 715.5,3 ~: ~O 1 133~.$1 ~ 3~ 3~ W 1955.76 'q 3~ 40 W ARCO ALASKa, IqC, 3;-14 KDP~RUK NgRTH SLOPE,AL~SK~ COMPUT~TIgN DATS: 24-J&N-85 INTERPOLATED VALUES FOR EVEN 100 FEET TRUE SOB-S:~ MEASURED VERTICAL VERTICAL 3EPTH DEPTW DEPTH 0,00 0,00 -93,00 93,00 93,00 D,O0 193,00 193,00 lOD.O0 293.03 293.00 203.00 393,01 393,00 300,00 493,01 493,00 400,00 593,01 593,00 500,00 693,01 693,00 600,00 ?93.02 793,00 700,00 893,03 893.00 800.00 993,03 993.00 900,00 1093,04 109.3.00 1000,00 1193.05 1193.00 1100,00 1293,05 1293,00 1200,00 13.93,05 1393,00 1300,00 1493.05 1493.00 1400.00 1593,06 1593,00 1500,00 1593,07 1693,00 1600,00 1793,07 1793,00 1700,00 1893,07 1893,00 1800,00 1993.0T 1993.00 1900.00 2093.08 2093.00 2000.00 2193.08 2193.00 2100.00 2293.08 2293.00 2200.00 2393,08 2:393,00 2300,00 2493.08 Zt~93-O0 2400.00 2593.08 2~93,00 2500,00 2593.08 2693-00 2600.00 2793.08 27! ,.00 2700.00 2893,09 0 2800.00 ," 2 COJRSE DEVI~TIgN AZIMUTH 2=G MIN DEG MIN 0 0 N 0 D E 0 10 S 53 31 E 0 13 S 20 18 t- O zo s 37 4~.~ 0 29 S 45 49 =_ 0 27 S 49 49 0 26 S 4~ 25 E 0 Z? S 52 ~ E 0 36 S 53 32 E 0 ~2 S 55 55 E 0 46 S 60 T E 0 ~3 S 61 45 E 0 26 S 40 1I E 0 25 S 36 56 E 0 25 S 4.3 23 E 0 28 S 69 3 E 0 32 S 75 31 E 0 35 S 66 35 E 0 28 S 23 43 E 0 19 S 20 41 E 0 14 N ?3 25 E 0 17 N $9 29 E 0 25 S 54 0 E 0 15 S 35 30 E 0 5 S 73 8 W 0 7 N 2 9 W 0 5 N 13 55 E 0 5 N 4~ 55 E 0 21 S 5~ 50 E 0 27 S 59 55 E 0 25 S 62 45 E 0 10 S 31 2 E 0 4 S 75 27 W 3 37 N ~2 34 W 7 6 N 39 33 W 9 58 N .44 53 W 13 20 N 45 37 W 15 30 N 45 29 W 17 6 N 49 50 W 19 .16 N 48 19 W 2993.09 2900.00 3093.09 3000.00 3193.09 3100.00 3293,14 3200,00 3393,59 :339'3-00 3300,00 3¢94,?0 3493.00 3400.00 3596,81 3593,00 3500.00 3700.13 3693,00 3500.00 3804,28 3793.00 3TO0,O0 3909,56 3893.00 3800,00 VERTICAL DOGLEG SECTION SEV:~,ITY FEET 9ES/100 0,00 0,00 -0.07 0.53 -0.41 0.11 -0.89 0.22 -1.61 0.23 -2.43 0,07 -3,22 O, 05 -4.01 0,0~ -4,93 0,13 -5.03 0.05 -7,28 0,07 -3.48 3.13 -9.40 0.11 -10.16 0.21 -10.90 0,13 -11.63 0,16 -12.36 0.12 -13.17 0.64 -14.24 3.57 -14.87 0.13 -15.26 0,29 -15.44 0.28 -15.81 0.20 -15.46 ~.45 -15.57 0.21 -16.41 O.ZO -16.33 0.30 -16,19 0.44 -16,48 0,62 -17,24 9,05 -1B,O1 0,12 -18.53 1.07 -l~.7T 0.93 -16,44 5,09 -7.11 3.02 7.75 2.58 28.18 2.67 53.94 1,69 82.70 2,58 115.02 2.48 PaGE 3&TE DF SJq¢~Y: O'3-J~N-35 KELLY ~US~ING EL~V&TION: ENGIqEER: '3. S.~Eq 4 ./ =T SUS-SE~ OEPTH RECT~N'3'JLAR C33ROiN~TES H]RIZ. N]RT~/SOJTH EAST/~EST giST. :EET. F~ET. '--E~T O,O0 N 0,00 E 0.00 0.03 N 0.1~ c 0.14 0.57 $ '0.53 E 3.89 1.20 S 1.O~ E 1.51 1.75 S 1.73 E 2.44 2.28 S 2.31 E 3, .24 2.80 S 2.91 E 4,04 3.3,3 S 3.55 c 4.05 S 4.57 6 5.11 4.7~ S 5.70 E 7.~+1 5.37 S 6.82 E :3.63 5.96 S 7.55 5 9.62 6 55 S 8 04 : 10 37 · m _. . 7.10 .S 8.54 ? 11.11 7.49 S 9.22 E '11.93 7.75 S 10,05 E 12,.59 8,34 S 10,97 E 13,50 8.84 S 11.79 E 14.55 9.&6 S 11,93 E 15.22 9.71 S 12.23 E I~.$2 9.57 S !Z.59 L= 15.'39 :~,55 S 13.23 E 16.37 9.~'] S 13.30 ~ 17.03 lO.1T S 13.73 E 17.09 13.07 S 13.60 E 1,5.92 ~. 9 O S 13.69 E 1,5. 39 9.74 S 13.67 '~: 16.73 9.63 'S 14.01 E 17.12 lO.Z~ s .14.67 E ~?.~1 10.57 S 15";3~ E ~3.73 10.93 S ,15-90 E 1~.30 11.,.~4 S 15.90 E 19.47 9,55 S 14,29 E 17.19 2.56 S 8.10 E 8.49 3.54 N 1.57 W 3.30 22.94 N 16.45 W 2,3.23 41,09 N 34,96 W 53,95 60.50 N 56,5~ 81,73 N 81,75 W 115.60 CO~PUT~TI3N D~TE: 24-J~N-B5 P~3E ~ ~RCO AL.~SKA, INC. 3F-14 NORTH SLO~E,~L~SK~ TRUE ME~SURE] VERTICAL DEPTH DEPTH 4016.50 3993.00 41Z6.99 4093.00 4Z~l.ll %193.00 4359.54 4293.00 4484.18 4393.00 4514.17 ~493.00 4743.8~ ~593.00 4~72.$4 4693.00 5000.6Z 4793.00 5128.45 ~893.00 5255.58 4993.00 5382.51 5093.00 5509.75 5193.00 5537.3~ 52'93.00 5755.32 5393.00 5~93.3~ 5493.00 60Zl.6~ 5593.00 $150.0? 5693.00 6~79.19 5793.00 6408.83 5893.00 6537.72 5993.00 6056.81 6093.00 6795.87 5193.00 6~24.95 6293.00 6975.00 6331.77 ,: INTERPOLATED V~LUES FOR EVEN 100 mEET DF SJB-S~& VERTI=&L DEPTH C~URSE VERTICAL D3GLEG DEVIATION ~ZiMJTq SECTION SEVERITY O:G ~IN DE~ MIN FEET DE3/IOO 3909.00 4000.00 4100.00 4300.00 ~409.00 4500.00 ~500.00 ~700.00 4800.00 22 45 N 42 20 W 152.65 4.79 27 1 N 39 41 ~ 199.53 2.94 30 36 N 37 22 W 254.46 3.21 34 ~0 N 38 9 W 317.~4 ~.5~ 38 '~7 N 39 5 W 392.17 3.39 39 ~4 N 38 55 W 475.22 9.31 39 22 N 38 50 W 557.75 0.24 38 ~4 N 38 5¢ W 538.92 0.35 38 34 N 38 44 W 71~.79 0.15 38 25 N 38 35 W 798.43 0,40 ~900,00 5000,00 5100,00 5200,00 5300,00 5400,00 5500,00 5500.00 5700.00 5803.00 37 57 N 38 42 W 877.08 3.37 38 1 N 38 45 W 955.09 0.39 38 Z4 N 38 4! W 1033.76 3.47 38 29 N 33 57 W 1112.99 0.14 38 ~0 N 39 9 W 1192.85 D.27 ,33 ~2 N 39 lB W 127Z.37 0.22 38 ~9 N 39 38 W 1353.23 0.66 39 0 N 39 57 W 1433,75 0,49 39 23 N 39 51 W 1515,42 0,45 39 ~1 N 39 42 W 1597,93 1,71 5900.00 6000.00 $100.00 5200.00 5238.77 39 11 N 39 45 W 1579.25 0.i~ 39 13 N 39 59 W 1760.~8 0.52 ]9 13 N ~0 1 W 1842.45 0.00 39 13 N 4~ 1 W 1924.06 0.09 39 13 N ~O 1 ~ 1555.71 O.CO 3~Ti~ DF SJqVEY: ]~-J~q-.~5 KELLY SUS-SE~ DEOT~ .R E CT '.1N:..qU L 2 R NS~Td/SC~UTq FE-_-T CgORDZq~,TES HJRiZ. 3~P~,RT'JRE E~ST/'dEST 3157. F=~T F-=jT 3~.~ 108.45 143.'{5 237.20 295.13 359.57 423.90 4~7.13 549.34 511.~4 108.51 W 153.~1 N ~5 0 W 139.2) ~ 200.23 '~ 44 4 4 173.42 W 25~.~6 q 42 51 W 212.02 ~4 31,~.15 q 41 47 W 258.53 W 392.40 '~ ~1 IS--' 310,~7 W &75.39 ~ 43 5t.~ 362.69 W 557.8) '~ 42 33 W 413.,50 w 53~.03 q 40 19 W 463.~0 W ?18.~8 q ~9 i0 W 572.96 733.98 795.21 856.91 918.94 10~2.95 1104.80 1167.47 1230.~0 562.56 W ~77.13 611.30 N 955.12 N 560.57 W 1033.7:~ 710.2~ W 1113.01 760.61 W 119g.:~8 N 811.22 W 1272.~9 862.2~9 W 135].25 913.84 W 1433.77 966.23 N 1515.45 019.12 W !597.96 1293. ~0 1355.97 1418 .~5 1595.19 1071.03 W I$'7}.Z3 q 3'~ 37 1123.45 W 17,50.~1 q 39 3.3 1175.91 W 1',541.~9 "l ,5~ 3'9 124,~.75 W 1~5'5. 75 ',~ '3'~ ~'3 ,( ARCO ~L~S~A, INC. 3=-14 KJPARJK N3RTH CO~UT~TI3N D~T~: 24-J ~:'J-95 ~T MA~K:_R TOP KUPARUK ~ BASE KUDARUK C TOP KUP6R~K ~ BASE KUP~RUK A PBTD INT~RDOL~TED VAL~E$ FOR ~EASJRED DEDFH 5ELO~ KB 6332.00 6~1.00 5573.00 6683.00 6738.00 6~?$.90 'HDSEN HDRIZDNS FROM ]RISIN= 52' =SL, TVD KB SJ3-SEa 5833.~1 591T.97 6105.54 5186.90 5331.77 5740.~1 5B2~.97 5927.3~ 5312.54 5093.90 523~.77 SJR~iZ{ .3C4 ~T =EL, SzC 19, T1ZN RECT&NGULAR COO NORFH/S]IJT~ ~ , RgE, dM RDIN~TSS 1193.15 1 ZF+5.43 "4 13~Z.34 1310.53 135~.~t N li30.D~ 141~.6~ 1505.19 N 12~'3.75 ~.~ A~CO ALASKA, INC. KOPARUK N3RTH SLOPE,AL&SK~ COMPUT.~TION DATE: 2z+-J~N-85 M~RKER TOP ~ASE TOP BASE PBT3 TO KUP&RUK S KUmARUK C KUP~RUK ~ KJm~RUK A (:AULTED ~SE) FINAL WELL L3CATI3N &T TD: TROE SUB-SEA ~EASURE3 VERTICAL CERTI2AL DEPTH OEPTH DEPTH 6975.00 533'1.77 5238.77 ]RI3IN= MEASORED DEPTH TVD BELgW KB ~ROM KB 52' =SL, SJB-S:~ 5332.00 5833.91 57&0.~1 6~41.00 5917.97 5824.97 ' 5573.00 5020.3~ 5~27.34 65B3.00 5105.5~ 5~1Z.5~ 5788.00 6186.90 5093.90 5975.00 5331.77 5238.77 HgRIZONTAL 3EP&RTURE DISTANCE ,&ZIMUTH FEET 195.5.75 q 39 40 W ~EL, REC N3 SJ~FA SEC 1 T~NGU RT~/S 193.1 2~5.~ 310.5 353.5 414.5 5D5.1 gE tT 9, T12;'4, RgE, UM L~R ]UTq ~aST/REST FT SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3F-14 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 00007~174 W~LL 3F-14 (62' FSL, 181' FEL, S19, T~._.., R9E) HORIZONTAL PROJECTION N0~H ~000 REF OO00?! 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'~4. - ~---?---~.-.~.4-~--X.4-.,L.4..4--4.-.?-..{.4-.4-.4.-~4.--{.....-h..~.--=...~.-- t ...... ....... ?' ....... ................... ..... ..... ........... :--. t PROJECTION ON VERTICAL PLANE 320. - 140. SCALEO IN VERTICAL rlEPTHS HORIZ SCALE = 1/S00 IN/FT '7¥ Completion Report Required ~ate Received ,' Rema ~ell'llletory · .qnmple~ __ .. Log "· Core Cbr~'Deecription · Regiatered gurvey Plat lnell,atton flurvey - , ~ / ' . Log Run ARCO Alaska, Inc. ~.:: ...-! Post Office BOx~'100360 Anchorage, ~Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Dear Mr. State Reports Chatterton- Enclosed are the DeCember monthly reports for the fOllowing wells' 1A-7 2H-6 3A'13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 ~'P~14~ 4-23 16-19 L3-!9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 L~-I~ 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, . Gruber /~ssoci ate Engineer JG/tw GRU13/L05 Encl osures RECEIVED JAN 1 4 1986 Oil & Gas Cons. Alaska. Inc. is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO'w~VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-292 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21500 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well 62' FSL, 181' FEL, $ec.19, T12N, R9E, UN at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25632 ALK 2565 10. Well No. 3F-14 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0il Pool December 85 For the Month of. ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1645 hrs, 12/20/85. Drld 12-1/4" hole to 3080'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6975'TD (12/24/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 6788'. Secured well & RR @ 1800 hrs., 12/25/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests · 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Conductor report not yet rec'd. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3064'. Cmtd w/900 sx PF "E" & 340 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6878'. Cmtd w/250 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/6966' - 3059' FDC/CNL f/6940' - 6100' GR f/3059' - 1700' Cal f/6940' - 3059' RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data None JAN 1 4 1986 0il & ~as {;o~. ~lnll~iSs{oR Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE NOTE--Report is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TEMP/MR09 Submit in duplicate ARCO Alaska, Inc. Post Office Bo~ '0 Anchorage, Ala~'a 99510 Telephone 907 277 5637 PJ~TLSLN TO: Date: 01-07-86 Transmittal No'5504 · ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. BOX 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acP~owledge receipt and return one signed copy of. this transmittal. Open Hole LIS Tapes ,Plus.Listings-.-One copy of each Schl - '"-~2H-6 · 12-28-85 Run #1 2 00.0-9016.0- , 3A-16 12-26-85 Run 91 1890.0-9142.0-~.~/ -~--~~-- /~ - ~/~ ~ 3F-13 12-19-85 R~ ~1 3F-14 12-24-85 Run 91 1700 0-6966 Receipt Acknowledged: · 'B. Currier Chevron Date: DISTRIBUTION Drilling Geolog~L.Johnston W. Pasher Lw_xcn Scnzo Mobil Phillips Oil Union D & M NSK Drill Clerk J. Ratb~ne!l K. Tulin/Vault MEMORANPUM State of Alaska ALASKA OIL A~D GAS CONSERVATION COMI~IS.S'z~N TO: cC~~erton DATE: December 30, 1985 FI hE NO.: ? . THRU: Lonnie C. Smith ~/C~/.'i TELEPHONE NO.: D.HRH. 97 Commissioner SUBJECT: FROM: Harold R. Hawkins Petroleum Inspector BOPE Test ARCO KRU DS 3F- 14 Permit 85-292 KuparuJr. River Field Sunday, December 22., 1985: i left ARCO's DS 3A-16, subject of another report to ARCO's DS 3F-14 to witness a BOPE test. · ~ I witnessed the BOPE test on ARCO's KRU 3F-14, there were nO fail- ures. I filled out an A.O.G.C.C. Report which is attached. In summary, the BOPE Test that Doyan 9 crew performed for ARCO on DS 3F-14 was satisfactory. Attachment I02-001 A ( Rev 10-84) o&~ ~4 - 5/84 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report , J Well Location: Sec /.~ TI4~ Rf~r M Drilling Contractor ~~ / Location, General ~ Well Sig~/~ General Housekeeping ~/~ Rig ~j~ Reserve Pit ~/~ Mud Systems Visual Audio Trip Tank Pit.Gauge Flow Monitor Ga~ Detectors BOPE Stack Ri Annular Preventer Pipe Rams Blind Rams Choke Line Valves · H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Representative/~// /}.,',~.X,~/f~:~ ACCUMULATOR SYSTEM Full Charge Pressure ?~~ psis '-- , Pressure After Closure /~~ psi~ Pump incr. clos. pres. 200 psis -- min.~ sec. . Full Charge Pressure Attained: ~ minfl~- sec. Controls: Master ~/~ Remote ~/~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves No. flanges ~ Adjustable Chokes ~/~ Hvdrauically operated choke Test~Time ' / hrs. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure .. Repair or Replacement of failed equipment to be made within '---~---~days and Inspector/ Commission office notified. Remarks:. Distribution orig. - AO&GCC cc - Operator cc - Supervisor November 29, 1985 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River .Unit 3F-14 ARCO Alaska, Inc. Pe~nit No. 85-29.2 Sur. Loc. 62'FSL, 181'FEL, Sec. 19, T12N, R9E, t~M. Btmhole Loc. 1498'FSL, 1355'FEL, Sec. 19, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above reference well. The permit to drill does not inde~mify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout pre- vention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~.ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~~~. ~trV~y~-ypur § ' ~ C. V. Chatterton Chairman Alaska Oil and Gas Conservation Comm~ission BY ORDER OF THE COMMISSION be Enclosure cc.- Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. lv~r. Doug L. Lowery ARCO Alaska, Inc. Post Office Bc~._~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-14 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3F-13, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot ° Diagram and description of the surface hole diverter system ° Diagram and description of the BOP equipment We estimate spudding this well on December 15, 1985. any questions, please call me at 263-4970. Sincerely, R~~.~~gional Drilling Engineer JBK/LWK/tw PD/L193 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC~VIISSION P :RMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL C~X DEVELOPMENT GAS [] SERV,CE [] S~NGLE ZONE 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 62' FSL, 181' FEL, Sec.19, T12N, R9E, UM At top of proposed producing interval 1238' FSL, 1143' FEL, Sec.19, T12N, RgE, UH At total depth 1498' FSL, 1355' FEL, Sec.19, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 93', PAD 56' ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) ~ederal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3F-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 62' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6807' MD, 6213' TVD fec. t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLE 38 oI (see 20 AAC 25.035 {c) (2) 15. Distance to nearest drilling or completed 3F-13well 20' (~ 940'TVD feet 18. Approximate spud date 1 2/15/85 2715 3118 psig@ 80°F Surface psig@ 6056 ft. TD (TVD) 21 SIZE Hole Casing 24" 16" 12-1/4" 9-5/8" !8-1/2" 7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling Length H-40 ] Weld 80 -55/HF-EtW BTCI 3008 -55/HF-EIW BTCI 6773 SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 35' I 35' I I I 34 I I 34' 35' 35' M D BOTTOM TVD 115t 115' 30431 3043' I 68071 6213' 1 I (include stage data) + 200 cf 810 sx PF "E" & 340 sx PF "C" 300 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6807' MD (6213' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-~/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2715 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-14 will be 20' away from 3F-13 at 940'TVD. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby c?~-f~/ that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Regional Drilling Engineer DATE The spac is~lon use CONDITIONS OF APPROVAL Samples required Mud log required I--lYES .,,~O i--]YES Permit number ~ ~)~-- ~1~(~ I._ Approval date 11/29,/85 Form 10-401 (LWK) PD/~i~3 / / IR ~ 7-1 -RI] Directional Survey required APl number ~-Y-ES []NO 50- 6 'b~ .'~/~"-O SEE COVER LETTER FOR OTHER REQUIREMENTS November 1985 ,L, OM[vi ;dS I ON ER DATE ~"~'' by order of the Commission Submit in triplicate PERMIT TO DRILL 3F~14 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED l Alaska Oil & Gas Cons. commlsstor~ ~chorage 1 , , , __BASE_F~ERMAFR. OST- · ..... ~'-~ ........... K- 1 2 --TVD=2843 ........ -i ;='9--5-/'8--'OSG ,- ,, , ....... ' -~ ...... r-" .... -/'~'? ......... ~m ........ -LKOP. '..T.V D~3200 LTI"ID4T 200/4~EP=O-; .... '-' -".-'1 .......................... ff ....... j 'HD-643~ NORTH WEST: I I iii KUP~RUK RI VER UNTT 20" .DIVERTER SCHEMATIC DE SCR I PT I ON i. 16' COI~I~CTOR. 2. TANKO STARTER HEAD. 5. TANKO SAVER SUB. 4. TAI~O LO~R QUICK-C~CT ASSY. 5. TANKO UPPER QOI CK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I0' OUTLETS. 7. I0' HCR BALL VALVES W/lO' -/ DIVERTER LINES, VALVES OPEN AUTOMAT I CALLY UPOt~i CLOSURE OF' AlUM_AR PREVENTER. 8. 20' 20(X) PSI AhI~LAR PREVENTER. MAINTENANCE 8, OPERATION RECEIVED NOV ~ 1 IS~ I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AI~,IULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. :5. CLOSE AI~IULAR PREVENTER IN THE EVENT THAT AN II, lUX OF WELLB~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAI~IALLY OVERRIDE AI~) CLOSE APPROF~ I ATE VALVE TO ACH I EVE DO~I hID DIVERS I DO NOT SHUT IN ~LL UNITE ANY C I RCUIVE;TANCES. AJas~ 0~1 & Gas Cons. Gommission Anchorage 6 5 ACDDJVIJLATOR. CAPACITY T~S"F I. O-E~ AND FILL A~TC:R RE~E~OIR TO ~ WITH NYDRAU. IC FLUID. 2..~ THAT AC'~__M.J. ATC~ ~ IS ~ PSI WITH 3. {:EtSE:RVE TII'~._ Ti,-E:N O..OSE ALL L.t4ITS ALL LIMITS ARE C. OSED WITH 04ARGINS PLM~ ~'F. 4. R~CX:RD Ct~ NAD: REPO~. ~ ACCE:'TA~LE LO~R IS 45 ~C~DS O. OSI~ TIk~ AND $2DD PSI 4 3 2 - 13.--5/8" BC~, STAOt FILL ~ STAO< A~D 040<E 't~EF~ WITH ARCTIC 2. O-E~ TidAl ALL LDO( DOt~ ~ IN l~t I I-F-AD AR~ l~..Y RETRA~. S~AT TE::ST PLUG IN LIhE VALVES ADJACENT 'ro ~ STAO<. ALL OT]-ER 4. PRESSLI:~ UP TO 250 PSI AND t,¢I.D F{::R i0 NEN. ]:N-- CREASE ~ TO 3000 PSI ~ ~ FI:DR I0 I~N. ~UK-nh ~ TO 0 LINE VALVES. Q..OSE TIP PIPE RAMS AhD ~ VALVES 6.' TEs'r. TO P.50 PS]: AND 3030 PS]: AS :IN STEP TEST Bol'r~ PIPE RAN~ TO 250 PS]: AND SOD PS]:. I0. .O,_OS~ ~L/ND RAMS AND ~ TO 250 PSI A~D 5000 · PSI.. ' " F~_U.T.D. ~ A/.L VALVF..S IN DRZLI.ZI~ '--IZ: TEST'STANDPIPE VALVES, KELLY, l,'m~Y COiXSo I::RILL . . .'PIPE: SAFETY VALVE, ~ INSIDE ~ TI:) 250 PSI AN3 30:D PSI. E.. E I-V E D ,,. '~,-,v 2.. ~ ~ -" Ahska Oil & Gas ConS; Commission ': Anchor~§a" -_ - . . _ ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3F Pad Well s 1-16 · Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, - ~ Gruber Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 i 85 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfield'Company AS iilU: .CONDUCTORS !-~I IN SECTION 29 ~--'~ 1- Y=5,"~'~5.734.98 LAT=70°22'20.O858,, X= 508,662.35 LONG=149°55' 46. 549'' 89 FNL, 162 FWL, 52 O.G., 56.1 PAD- 2- ¥=5,985,745.10 LAT=70°22,20. 1856,, X= 508,638.99 LONG=149°55' 47. 233'' 78 FNL, 139 FWL, 52 O.G., 56.3 PAD 3- Y=5,985,754.79 LAT=70o22 ' 20. 2812" X= 508,616.29 LONG=149°55' 47. 896'' 69 FNL, 116 FWL, 52 O.G. 56.3 PAD . 4- Y=5,985,764.77 LAT=70°22' 20. 3796'' X= 508,593.66 LONG=149°55' 48. 558" 59 FNL, 93 f'WL,. 52 O.G. 56.2 PAD 5- Y=5,985,774.87 LAT=70°22 ' 20. 4792'' X= 508,570.43 LONG=149°55' 49. 237 M~I~ 49 FNL, 7O FWL, 52 O'.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22'20.5776'' I[ X= 508,547.58 LONG=149°55' 49. 906'' NOTES' 39 FNL, 48 FWL, 52 -O.G. 56.1 PAD I. COORDINATES ARE A.S.P., ZONE 4. 7- Y=5,985,794.93 LAT=70°22'20.6771'' 2. SECTION LINE DISTANCE, ARE TRUE. X= 508,524.44 LONG.149°55 ' 50. 582', 28 FNL, 24.FWL, 52 O.G.,55.9 PAD 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22 ' 20. 7744'' ON MONUMENTS SF-MIDDLE &3F-EASTPERL.H.D&ASSOC. X= 508,501.41 LONG=149°55'51.256'' 4.0.G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 O.G.,55.9 PAD C ED-RIXX-303ORE.~V.~.'~_,,~... AS ,UILTCONDUCTOR, 9-,,,, S E C TI0, l, _4,.~._ O A/../'~ ~,,. 9- ¥=5, 85,834.85 LAT=70°22'21.0708'' · ~ ~?" "-:0~' ~ X-- 508,432.81 40NC=149°55'53.26~'' ~..- _L~ -.~-~ ' ~ ~s;, 6~ ~;.;, ~.~ o.o., ~.~ ~A~ . .'~.-.' 49~'~ "..~*I ~0- Y=5, 985, 844. 70 ~.,~=70°22,21.~678,, · ~,-, ~,..-o-.-, ~,.,~V- ...... ~ , . · x: 21-FSL, 89 FEL, 51.20.G., 56.2 PAD ~.~:..OWA,~.'."~""^" · ,~ . 11' Y=5,985,855.14 LAT=70°22'21.2708'' · . ; ,i.~ -- ?.~s_ · 4=8o-s .- .-~_ X= 508,387.41 LONG=149°55' 54. 590" ,,'~-.... ...- · w~:q~z~-:.....:,.-,,~,,~ ~. 32 ESL, 112 FEL, 51.20.G., 56.3 PAD - R ~~ ~.~,~~ 12- Y=5,985,865.19 LAT=70°22' 21. 3699'' '~~,'~' X= 508,364.05 LONG=149°55' 55.273" I HEREBY'CERTIFY THAT I AM I~ROI~RLY RE~IITERED 42 FSL, 136 FEL, 51.10.G. 56.2 PAD AND.LICENSED TO PRACTICE LAND ~t~IYEYIN'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE .STATE OF ALASKA, THAT TI, Ill I~,.AT REPRESENT8 X= 508,341.36 LONG=149°55' 55.937" A SURVEY MADE UND. ER MY DIRECT SUPERYIIION AND. 52 FSL, 158 FEL,51.10.G., 56.3 PAD THAT CONDUCTORS I THR(I S ARE.CORReCT. Al OF '14- Y=5,985,885.08 LAT=70°22'21.5660'' SEPTEMBER 19,19B~ AND.CO41N~CTQ41~ S THRU 1~ ARE CORRECT A8 OF SEPTEMBER ~t, ltll. X= 508,318.27 LONG=149°55' 56.612'' 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD 19STU~-Y 2 X= 508,295.72 LONG=149°55' 57. 271'' ,~~~ 72 FSL, 204 FEL, 51 O.G. 56.1 PAD ~0 ~]. 2 X= 508.272.74 LoNG=149°55'57.943'' ~ -- rl[ ...... c~82 FSL~ 227 EEL. 51 O.G. 56 PAD ~ ~ a~s < -CONDUCTOR AS BUILT' 6 t // ::::i LOCATI~ SEC. 29, T. IEN.,R.9 E., U. MER. ] Date: October 11,1985 $eal4: N.T.S. CONDUCTORS 9 THRU 16 LOCATED IN pROTRACTED SEC. 19, T. 12N.,R. gE.,U. MER. .,,,~-.,,,,,,m~ Drafted by: Sydney2 D~. Ne. N~K85-26 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /(~.. /~ ~ ITEM APPROVE DATE (1) .... (2 thru 8) ~3f~- ' ';'"~ '?: 9. (3) Admin v (9 thru 12) 10. (10 and 1~) / 12. (4) Cass ~.~, ~/-~'-~.~' (13 thru 21) (22 thru 26) (6) Add :.~.~ 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 1. Is the permit fee attached ................ 2. Is well to be located in a ~e~ ~o~ i . .ii .... iiiiiiiiiii 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells .... [ ii~iii i'~ 5. Is Sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is wellbore plat included ............. 7. Is operator the only affected party .............................. 8. Can permit be approved before ten-day wait ............ ........... YES NO '' ' : Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ......................... ' ............ Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ......... ~ ........... Will surface Casing protect fresh water zones ............ · Will'all casing give adequate safety in collapse, tensign'~d bu~sti~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ........ .~ Does BOPE have sufficient pressure rating - Test to .~dD~ psig .. ~Z Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ' ee®®eee®.eeeee®eeeeeeeeeeeeeeeeeee.eeeee.~eee REMARKS Additional Remarks: Geology_: Eng~eerin$: LCS WVA ~ MTM ~ HJH -- rev:' 03/13/85 6.011 INITIAL CEO,I UNIT ON/OFF POOL CLASS STATUS AREA! . NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically ~ -: . .. organize this category of information. N:--.-SCHLJ'MBERGE~- --:~ LIS T,~PE ~'ERIFIC,~ION LIS?IN'G LVP OlO.H02 VERIFICATI3q LISTIN~ PAGE i ,~:=;'- REEL HEAD:R. ,-"'"'-,- SERVICE N&ME :EDIT DATE :85/12/28 ,SRI3IN : REEL NAME :149257 CONTINU~TIDN ~ :01 .~REVIOUS R:EL : COMMENTS :LIBRARY TAPE ,--~ TAPE HE&DER.~-.- SERVICE NAME :EDIT DATE :85t12/28 DRI$1N :0000 TAmE NAME :1117 CONTINUA'TI3N ~ :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE · , .... FILE HEAD:R FILE NAME :EDIT SERVICE NAME ~ILE TYPE PREVIOUS FILE .001 1024 INFORMATION' RECORDS MNEM CONTENTS CN : ARCO AL~SK.A WN : 3F-14 FN : KUPARUK RAN2: 9E TOWN: 12N SECT: 19 CO~N: N. SLOPE ST&T: ALASKA ,~,TRY: U'S~ MNEM CONTENTS PRES: E :)=:-' COMMENTS ..... ,.-~- I' N C UNIT m. ~....., .,.,~ UNIT TYPE 000 000 OOO O00 000 000 000 000 TYPE 000 000 000 DO0 gO0 O00 000 O ,00 000 000 C A T E 000 SIZE 018 005 008 002 OOG OOZ 012 005 00~ SIZE 0 0 i CODE 065 065 065 065 065 065 065 065 065 C O O E 055 ,,. , LVP OiO.HOZ VERIFICATION LISTING P4GE Z :Y' S CHLU M~ E'R GER ~,, ~ ALASKA COMP~TINS CENTER ~OMP,~NY : ARCO ~L~SKA INC WELL = ~F-I~ FIELD = KUPARUK CDUNTY = NORTM SLOPE BOROUGH STATE : JOB NUMBER AT ACC: 71117 RUN ~BNE, DATE LOGGED: Z4-DEC-85 LOP: M. OGDEN CASING : 9.625" ~ 3054.0' - BIT SIZE : 8.5" TD 6975.0' TY~E FLJ'IO : WEIGHTED POLYMER DENSITY : 9.90 LB/G RM : ~.130 @ 84.0 OF VISCOSITY : ~0o0 S RMF : ~.4BO 2 84.0 DF PM : 9.5 RMS : ].2~O 2 84.0 DF ~L2ID LOSS = ~.6 C~' RM ~T ~HT = 2.557 @ 140. DF MATRIX SANDSTONE ~'~'~ THIS DATA HAS NOT BEEN DEPTH SHIFTED- OVERLAYS FIELD PRINTS ~~ LVm OiO.H02 VERIFIC~TID~ LIST!N~ P~$E 3 SCHLUMBERSER LOGS INCLUDED WITH T'tIS M4GNETIC TAP:: ~ DJAL INDUCTiD~ SPHERiSALLY FOCUSED LOG (DZL) ~= D&T~ AVAILABLE: 6955.0' TO 3050.0' ~ F]RMATiON OE~SITY CDMmENSATED, LOG (FOND ~: CJMPENS~TED NEUTRON L]G (FOND ~ DATA AVAILABLE: 69~0.0' TO 6100.3' ¢ G~MMA RAY IN CASING C~R.CNL) :~ DATA AVAILABLE: 30B4.0' TO 1700.0' .,- .~. ~ .... ~ :~" -,- ~'.,-~' :x -,- ;- NOTE: FIELD DATA (OIL) 22' LESS THAN THE BLUELINE DEPICTS. (IN CASING) ~ gAT~ FORMAT RECORD ~¢ ENTRY 5LOCKS' TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ 1 66 1 LVP OlO.H02 VERIFICATION LISTING P.aG5 4 9ATjM SPECIFICATION MNEM SERVICE SERVICE ID DRDER # DEPT SFLU DIL ILO DIL ILM gIL SP DIL ~R DIL GR FDN CALI FDN RH2S FDN DRHD FDN NR~T F~N RNR& FDN NPHI F~N NCNL FDN FCNL FDN 15 BLOSKS UNIT &PI APl &Pl LOG TYPE CLASS FT O0 000 3qMM O0 220 3HMM O0 120 45 OqMM O0 120 MV O0 OlO O1 2~PZ O0 310 01 G~Pi O0 310 01 Iq O0 280 O1 S/C3 O0 350 02 $/C3 O0 356 O1 O0 420 O1 O0 000 O0 Pd O0 890 O0 CPS O0 330 31 CPS O0 330 30 73 API FILE ~Og ~0. O 0 0 0 0 0 0 0 0 0 0 O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 Si 5O .liN 1 ZE SPL REPR C3DE ~ 1 68 4 1 58 ~ 1 58 4 ! 6B 4 i 58 4 I 59 4 1 58 4 1 68 4 1 58 4 ! 58 4 1 68 O00000O OOOO000 0000000 0000000 0000000 0000000 OOOO000 0000000 0000000 OOOO000 0000000 OOO0000 0000000 0000000 0000000 PR (3 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 OCESS CTAL) 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 DATA SP RHO5 NPHI 6995.0000 -22.5889 .2.4670 39.7949 DE*T SP RH3B 6900.0000 ,-26'5732 2.4'749 37.40,23 DEPT SP RHgB NPHI 6800.0000 -33.0820 2,¢551 38.8572 DEPT: SP RHOB NPHI 6700.0000 -36.0195 2.~221' 40.3320 DEPT SP RHOB NPHI 6600-0000 -62.6758 2.1995 30.1758 DEDT. SP RHOB 6500.0000 -46"98B3 2,..3889 SFLU SR NC N 'L SFLd NCNL SFLU' G,R ORH3 NCNL SFLJ' GR DRHD SFLJ' DRH'~ NCNL SFLJ' GR DRHD 3.5018 ILD 116.7148 ~R 0.121-6 NR'AT' 1997.6875 FCNL 2.8752 ILD 113.8398 GR 0.1333 NRAT 2071.5000 FCNL. 3.0803 iLD 110'7148 GR '0.0503 NRIT 2055.5D00 FCNL 3.9905 ILD 103.5898 GR 0.0088 NRAT 1928.6875 FCNL. 11.4,152.3 ILD ~$'1357~ GR 0.0073' NRAT. 2963.5000:: FCNL 9.10'35 ILD BO. 52'73 GR O' 0342 NRA'T 2.7,539 ILM~ 1i6.7148 CALI 3.3147 RNR& 556-81125 2.658.2 !LM 113.8398 CALI 3.2366 RNRA 569.3125 2 110 3 $1 T 3 103 3 5 22 .9534. !LM .71,48 CALI .2991 RNRA .3125 .4006 ILM .5898 CALI · 3928 RNRA .8!.25 26.4111 !LM ~8.1367 C. ALI 2.781:5 RNR&. 101~.8125 7.508:5 ILM 80.5.273 CALI 2.9026 RNR~ 3.2112 8.5020 3.5881 12,.85'16 9.1348 3.8370 3.14,67 8.9238 3.3284 3. 6428 9.0957 3.6897 34.5430 8,8457 2.9182 8.1895 9.4082 2.9709 LVP OlO.HO2 VERIFICATION LI$TIN$ PAGE 5 NPHI OEPT SP NPHI DEPT SP NPHI DE~T SP RH]B NP~I DEPT SP NPHI DEPT SP RH3B NPHI DEPT SP RHD5 NPHI SP RH~B NPHI DEPT SP :RHDS NPHI DEPT SP NPHI DEPT SP NPHI DEPT SP 31.2988 NCNL 5~00.0000 SFL~ -70.0977 SR 2.1509 DRH] 33.7'891 NCNL 5300.0000 SFLJ -49.0820 GR 2.3342 DRH3 44.5289 NCNL 6200.0000 SFLJ -57°0820 GR 2.3948 DRS] 43.1152 NCNL 6100.0000 SFLJ -58.3320 GR 2.3772 DRH3 40.8591 NCNL 6000.0000 SFLJ -55.5195 GR -999.2500 DRM] -999.2500 NCNL: 5900.0000 SFLU -67.7852 GR -99'9.2500 DRH] -999.2500 NCNL 5800.0000 SFLO' -28.$51~ -9'99.2500 DRHO -999.2500 NCNL 5700.0000 SFLd -33-4883 GR. -999.2500 DRHD -999.2500 NCNL 5600'0000 SFL~ -35.4883 GR -999.2500 DR~2 -999.2500 NCNL 5500'0000 SFLU -43.2695 ~R -999.2500 ORHD -99'9.2500 NCNL 5~00'0000 SFL~ -37'3008 GR 2501. 51. O. 23~7. . 121. O. 1639 · 122. O. 1681 · . 156. O. 18~5. .4. 238. -999. -99'9. . 179· -999 · -999 · tl 1 · -99'9 · -999. · 102. -999. -999. 4.. 115. -9)9. -999. 96. -999, -9)9, .133. 500O 1992 1367 0034 5000 4651 5523 0259 6875 6057 5273 03B6 5875 9768 9375 0107 6875 0085 5525 2500 2500 3992 5525 2500 2500 0554 9023 2500 2500 2625 2500 2500 0945 ~023 2500 2500 5.320 6523 2500 2500 2312 3398 FCNL ILO ,R NRAT FCNL GR NR~T FCNL ILD GR NRAT FCNL ILD GR NRAT FCNL ILO GR NR'AT FCNL ILD NRAT F C N L · ILO GR NRA T: FC NL ILD GR NRAT FCNL ILO GR NR~ T FCNL ILO ,R NRfiT FC~L ILD GR 841,3125 39.5430 55.13.57 3.0588 585.8125 2.1389 121.6523 3.6565 404.3906 2,3088 122.5273 3,5940 439,1406 2.9905 146.9375 3.4512 49.2.8906 2.8030 -999.2500 -999.2500 -9'99.2500 3.4768 -999.2500 -999.2500 -999.2500 4.7117 -999.2500 -9'99.2500 -999.2500 3.7424 -999.2500 -999.2500 -999.2500 3.5959 -999.2500 -999.2500 -'9i~9.2500 4,2937 -999..2500 -999.2500 -999.2500 3.8~20 -999.2500 !LM CALl RNRA ILM CALl RNR~ iLM CALI RNRA ILM CALI RNRA ILM CALI RNR6 I.LM CALI RNRA ILM CALI RNRA ILM CALI RNR4 ILM CALI RNRA ILM C AL I ILM CALI ¢3.0&30 9.3591 3.3772 2·2034 9.4529 4.0515 2.~280 9.7129 3.828~ 3.3010 9,5645 3.7444 3.0745 -999.2500 -999.2500 3.76,20 -999.2500 -999.2500 4.7117 -99'9.2500 -999.2500 4.1101 -999.2500 -999.2500 3.7620 -999.2500 -999.2500 4.6882 -999.2500 -999.2500 4,1335 -999.2500 LV? OlO.HO2 VER[FICATi3~ LiSTIN:$ PAGE RHgS NPHI DEPT SP RH]B DE~T SP RHgB DEPT SP NPHI DEPT SP RHOB NPHI DEPT SP RH05 NP~I DEPT ,SP RHOB NPHI DEPT SP RHOB NPHI 3EPT: SP RHOB NPqZ DEPT SP RH~B NP~I DEPT'~ SP RHDB NPHI DEPT -999.2500 -999.2500 5300.0000 -39.5508 -999.2500 -999.2500 5200.0000 -33.2595 -999.2500 -999.2500 5100.0000 -~5.7595 -999.2500 -999.2500 5000.0000 -52.3633 -9'99.2500 -999.2S00 ~900.0000 -44.2595 -999.2500 -'999.2500 4800.0000 -39.98.83 -999.2500 -'999.2500 4700.0000 -42.2595 -9'99.2500 -999.2500 4600.0000 -42.8320 -999-2500 -999.2500 4500.0000 -50.5195 -999.2500 -999.2500 ,4~00'0000 -49.0820 -999.2500 -999.2,500 4300.0000 DRH] NCNL SFLJ ORH2 NCNL LJ SF GR DRH2 NCIL SFLg GR ORqJ NCNL SFL~ GR DRHD NCNL SFLU GR DRH3 NC N L SFLU GR DRHS NCNL SF'Ld GR DR~q:D NCNL SFLJ ~R DRHO NCNL SFLU DRH2 NCNL SFLJ DRHD NCN'L SFLg -999.2500 NRAT -999.2500 FCNL 3.7073 ILD 104.9023 GR -999.2500 NR~T -999.2500 FCNL 1.9356 ILD 1D9.8398 GR -999.2500 NR~T -999.2500 FCNL 4.1609 ILD 126.9548 GR -9~9.2500 NRAT -999.2500 FCNL 4.1509 ILD 161.6875 GR -999.2500 NR~T -999.2500 FCNL 3.5120 ILD 153.6875 GR -999.2500 NR~T -999.2500 FC~L 1-6143 iLO 199.3125 GR -999.2500 NR~T -99'9.2500 FC~L 1.5977 ILD 146.9375 SR -999.2500 NR~T -999.2500 FCNL 2. 0784 ILO:, 1 59. 0625 GR -999. 2500 NR~T -999.2500, FC'qL 2.. 35'77 ILD 116.5898 GR -999. 2500 NR~T -999. 2500 FCN,L 2.2209 ILD 108.46~8 GR -999.2500 NRAT -999.2500 FCNL 2.3362 I L D -999.2500 -999.2500 3.6357 -999.2500 -999.2500 -999.2500 2.3254 -999.2500 -999.2500 -999.2500 3.3~70 -999.2500 -999.2500 -999.2500 3.7971 -999.2500 -999.2500 -999.2500 2.1311 -999.2500 -999.2500 -999.2500 1.9571 -999.2500 -999.2500 -999.2500 1.8,311 -999.2500 -999.2500 -999.12500 1.9688 -999,2500 -999.2500 -999.2500 2.2991 -999.2500 -999.2500 -999.2500 2.3127 -999.2500 -999.2500 -999.2500 2.3030 RNR6 !LM C~LI R NR ,4 ILM CALI RNR~ ILiM CALI RNRA ILM CALI RNR~ CALI RNR,6 iLM CALI RNRA ILM CALI RN'RA ILM C~Lt 'RNR~ ,ILM, CALl RNR,4 I'LM CALI R:NR4 ILM -999.2500 3.7717 -999.2500 -999.2500 2.4534 -99'9.2500 -999.2500 3.6135 -999.2500 -999.2500 3.9084 -999.2500 -99'9.2500 2.5608 -999.25,00 -999.2500 1.9278 -999.2500 -99'9.25 O0 1. 9034 ,-999.2500 -999. 2500 2.03154 .-99'9.2500 -999,.2500 2.3928 -999.2500 -999.2500 2.3752 -999.2500 -999.2500 2.3 811 LVP 010.q02 VERIFICATZ3~ LISTIN3 PAGE 7 SP RH3B NPHI DEPT SP RH2B NPHI DEPT SP NPHI DEPT SP RHOB NPHI DEPT SP RHSB NPHI OEPT SP NPHI DEPT SP RH3B NP.HI DEPT SP RHDB NPHi SP ~PHI DEP~ SP RH3B NPHI DEPT SP RHOB NPHI -55.3633 GR -999.2500 DRHD -99'9.2500 NCNL 4200.0000 SFLJ -54.5195 GR -~99.250'0 DR~3 -999.2500 NC~L 4100.0000 SFLJ -55.5195 GR -999.2500 DRH3 -999.2500 NCNL 4000.0000 SFLU -24.2451 GR -999.2500 DRHO -999.2500 NCNL 3900.0000 SFLU -26.4951 -999.2500 ORH3 -9'99.2500 NCNL 3800.0000 SFLU -30.2451 -999.2500 9RH3 -999.2500 NCN~ 3700'0000 SFL~ -34.4883 GR -999.2500 DRY3 -9'99.2500 NCNL 3500.0000 S'FL~ -35.488.3 GR -9'99.2500 DRH3 -999.2500 NCNL 3500.0000 SFL!J -39.2383 GR -999,2.500 OR.~ -999.2500 NCNL 3400.0000 SFL,U -40.~883' GR -999.2500 DRH~ -999.2500 NCNL 3300.0000 SFLJ -41.2383 GR -999.2500 '-99'9.2500' N:CNL 111.1523 GR -999.2500 NR~T -999.2500 FCNL 2.5901 ILD 107.9023 GR -999.2500 NR~T -999.2500 FCNL 2.7170 ILD 108.2773 GR -999.2500 NR~T -999.2500 FCNL 2.6584 ILD 115.9023 GR -999.2500 NRiT -999.2500 FCNL 3.6750 ILD 107.4023 GR -999.2500 NRAT -999.2500 FCNL 2.1526 !LD 105.7773 GR -999.2500 NRAT · -999.2500 FCNL 3.0567 ILO 10'7,7'773 GR -9~9.2500 NR~T -999,2500 FCNL 2.6038 110.4548 -999.2500 -999.2500 :IL D GR' NRAT FCNL. 1-9610 ILO 93.9648 GR -999.2500 NRAT -999.2.500 FCNL 3,6018 106. '9648 -9 ~9.25 O0 -999,2500 I L D GR N R A T FCNL 3-357? ILD 100.2148 GR -999.2500 NR'aT -999.2500 FCNL -999,2500 -999.2500 -999.2500 2.4729 -999.2500 -999.2500 -~99.2500 2.6096 -999.2500 -999.2500 -999.2500 3.4026 -999.2500 -999.2500 -999.2500 3.6350 -9')9,2500 -999,2500 -999.2500 2.2131 -999.2500 -999.2500 -999.2300 3.1%28 -999.2500 -999.2500 -999.2500 2.6819 -999.2300 -999.2300 -9~9.2500 3.0549 -999.2500 -999,2500 -999,2500 3,43'97 -999,2500 -999,2500 -999.2500 3.3?52 -999,2500 -999.2500 -999,2.500 CALI RNR4 ILM CALI RNR~ ILM CALI RN~ ILM CALI RNR& ILM CALl RNR~ iLM CALI RNR4 ILM CALI RNRA ILM C4LI RNR4 ILM CALl RNR~ ILM CALI RNR4 ,ILM CALI, RNRa -999.2500 -999.2500 2.5627 -999.2500 -999.2500 2.6975 -999.2500 -999.2500 3.2288 -999.2500 -999.2500 3. 6272 -'999. 2500 -999.2500 2.2405 -999.2500 -999.2500 3.1467 -999.2500 -999.2500 2.6563 -999.2500 -999.2500 2.8,674 -999.2500 -9'99.2500 3.5139 -999.2500 -999.2500 3.4202 -999.2500 -9'99.2500 LVP OIO.H02 VE~!FICATIDN LISTINS P~$E DEPT 3200.0000 SFLU SP -44.9883 GR RHS5 -999.2500 DRH] NPHI -999.2500 NCNL DE:T 3100.0000 SFLJ SP -47.4883 ~R 2HOB -999.2500 ORH3 NPHI -999.2500 NCNL gEPT 3050.0000 SFL~ SP 0.?544 GR RHgB -999.2500 DRH3 NPHI -999.2500 NCNL 4.3~45 ILO 96.1523 GR -999.2500 NR&T -999.2500 FCNL 5.6375 ILO ~8.7773 GR -999.2500 NR~T -999.2500 FCNL 0.8271 iLO 50.9180 GR -999.2500 NR~T -999.2500 FCNL 4.1587 -999.2500 -99'9.2500 -999.2500 5.6023 -999.2500 -999.2500 -999.2500 57.9~05 -999.2500 -999.2500 -999.2500 ILM CALl RNR4 ILM CALI RNRA ILM CALl RNR4 4.1257 -999.2500 -999.2500 5.3289 -999.2500 -999.2500 2000.68'75 -999.2500 -999.2500 ,-~ miLe TRaiLER %~-~ FILE NAME :EDIT .001 SEq~ICE NAME : VERSION m : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME :. ~, FILE HE~DER $* FILE N~ME :EDIT .002 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH :. 1024 FILE TYPE : PREVIOUS FILE : '~"m DATA FORMAT RECORD ENTRY BLOCKS TYPE ¢ 15 0 DATN'M SPECIFIICAT!ON'BL~'CKS MNEM SERVICE SERVICE UNIT 6PI ID ORDER # LOG GR CMl G6P'I O0 SIZE REPR CODE I 65 1 66 4 1 66 API API aP1 FILE TYPE CLASS MOO NO,. 000. 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