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Home My WebLink About184-230MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 26, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2E-10 KUPARUK RIV UNIT 2E-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2024 2E-10 50-029-21246-00-00 184-230-0 W SPT 5903 1842300 1500 1700 1700 1700 1700 120 360 360 360 4YRTST P Adam Earl 7/1/2024 MIT IA 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 2E-10 Inspection Date: Tubing OA Packer Depth 270 2500 2380 2360IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240703133707 BBL Pumped:2.2 BBL Returned:2 Friday, July 26, 2024 Page 1 of 1              TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2E-10 KUPARUK RIV UNIT 2E-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 2E-10 50-029-21246-00-00 184-230-0 W SPT 5903 1842300 1500 1950 1950 1950 1950 385 520 520 520 OTHER P Bob Noble 9/16/2023 MIT-IA post BiSn packer repair per Sundry 323-364 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 2E-10 Inspection Date: Tubing OA Packer Depth 780 3300 3180 3150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230916155925 BBL Pumped:2.3 BBL Returned:2.2 Tuesday, October 17, 2023 Page 1 of 1            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: BiSN Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6661'feet None feet true vertical 6407' feet None feet Effective Depth measured 6489'feet 6156'feet true vertical 6235' feet 5903' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" J-55 6185' MD 5932' TVD Packers and SSSV (type, measured and true vertical depth) 6156' MD N/A 5892' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 3309' 3248' Burst Collapse Production Liner 6575' Casing 6356'6610' 3271' 110'Conductor Surface Intermediate 16" 9-5/8" 72' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-230 50-029-21246-00-00 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: ADL 0025658 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2E-10 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 110' ~ ~~ INJECTOR ~~ ~ 323-364 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: Brown HB Packer SSSV: Camco TRDP-1A Sfty Vlv Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-6718Well Interventions Engineer 6302-6322', 6344-6352', 6381-6389' 6049-6069', 6091-6099', 6128-6135' 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 4:15 pm, Oct 12, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips , OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.10.12 15:36:03-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 7/28/2023 ACQUIRE DATA CONDUCTED CBL WITH SCMT TO EVALUATE THE IA PRE BISN TREATMENT. LOGGED FROM 6200' TO 1850' AT 30FPM. FLUID LEVEL IN TBG AT 1860' (SCMT INOPERABLE IN GAS). NO OBSTRUCTIONS DISCOVERED IN IA. JOB COMPLETE. 8/16/2023 ACQUIRE DATA SET 2.28'' CATCHER @6173'RKB,PULLED ST#6 @6103'RKB 1''DMY & REPLACED W/1''OV(1/4''PORT) BK LATCH,PULLED CATCHER @6173'RKB. JOB COMPLETE 8/20/2023 ACQUIRE DATA IA INJECTIVITY TEST FOR BISN PUMPED 20 BBLS DIESEL DOWN IA FOR INJECTIVITY TEST 0.75 BPM @ 1450 PSI JOB COMPLETE 8/20/2023 ACQUIRE DATA PUMPED BISN BEADS DOWN IA PER DIRECTION OF LEAD. PUMPED AT 750 PSI AND .4 BPM AND UP TO 2500 PSI. AT .1 BPM FOR A TOTAL OF 2.1 BBLS. TOTAL BISN BEADS PUMPED 265 LB BASE SHOT, 551 LB SEAL SHOT 8/21/2023 ACQUIRE DATA CONDUCTED CBL WITH SCMT TO EVALUATE THE IA POST BISN TREATMENT. LOGGED FROM 6200' TO 1550' AT 30FPM. FLUID LEVEL IN TBG AT 1550' (SCMT INOPERABLE IN GAS). DATA UPLOADED FOR ANALYSIS. GR OVERLAY SHOWS NOTIBLE DROP IN GR BETWEEN 6130'-6140', JOB COMPLETE. 8/24/2023 ACQUIRE DATA HOIST BISN PRT HEATER TO MELT BEEDS IN IA, HEATING ELEMENTS PLACED AT 6130'. JOB COMPLETE, READY FOR SL (WILL PERFORM POST BEAD MELT CBL AT A LATER DATE) 8/26/2023 ACQUIRE DATA SET 2.28" JUNK CATCHER IN 2.25" D-NIP @ SET 1" DMY VALVE IN GLM @ 6103' RKB, OBTAINED PASSING MITIA TO 2500 PSI. LDFN HIGH WINDS, JOB IN PROGRESS 8/27/2023 ACQUIRE DATA PULLED 2.28" JUNK CATCHER FROM 6173' RKB. JOB COMPLETE 9/4/2023 ACQUIRE DATA (PRE-SW) BLEED/ADJUST IA DP'S FOR UPCOMING SW MIT-IA 9/16/2023 ACQUIRE DATA (SW) WELL #10 STATE WITNESSED (BOB NOBLE) MITIA (PASS) @ 3300 PSI. Initial T/I/O= 1950/780/385. IA FL @ SF. Pressured IA to 3300 psi w/ 2.3 bbl's of diesel. SI for 30 min monitor. Initial T/I/O= 1950/3300/520. 15 min T/I/O= 1950/3180/520. (-120) 30 min T/I/O= 1950/3150/520. (-30) Bled IA back to 780 psi. (2.2 bbl's back) Final T/I/O= 1950/780/385 2E-10 BiSN Repair Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (~100' of Rathole) 6,489.0 2E-10 4/18/2021 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added BiSN "packer" at 6130' RKB 2E-10 9/26/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: 1/1/2021 pproven 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 38.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.8 3,308.7 3,247.6 36.00 J-55 BTC PRODUCTION 7 6.28 34.8 6,610.0 6,356.0 26.00 J-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.1 Set Depth 6,185.0 Set Depth 5,932.0 String Max No 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RD ID (in) 2.44 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) 33.1 33.1 0.07 HANGER 6.000 MCEVOY TUBING HANGER 2.875 1,869.3 1,869.1 2.11 SAFETY VLV 5.125 CAMCO TRDP-1A SAFETY VALVE (LOCKED OUT 9/21/04) CAMCO TRDP- 1A 2.312 1,911.1 1,910.8 2.12 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 3,325.3 3,262.3 27.61 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 4,488.7 4,299.7 25.32 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,293.3 5,047.3 13.07 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,697.4 5,446.2 6.64 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,103.1 5,850.3 3.78 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,144.6 5,891.7 3.78 PBR 4.750 BROWN 10' PBR BROWN 10' 2.500 6,156.3 5,903.4 3.78 PACKER 5.937 BROWN HB PACKER BROWN HB 3.000 6,172.7 5,919.8 3.78 NIPPLE 3.668 CAMCO D NIPPLE CAMCO D 2.250 6,184.3 5,931.3 3.78 SOS 3.750 BAKER SHEAR OUT SUB BROWN 2.441 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) 6,130.0 5,877.1 3.78 OTHER BiSN BEADS MELTED FROM 6130' TO APPROX 6140' RKB (ANNULUS OF 7" X 2-7/8") 8/24/2023 2.875 6,156.3 5,903.4 3.78 LEAK - PACKER Brown HB Packer potential TxIA, TxForm, IAxForm leaks 7/4/2020 2.875 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) 1,911.1 1,910.8 2.12 1 GAS LIFT DMY BK 1 0.0 1/15/2015 0.000 3,325.3 3,262.3 27.61 2 GAS LIFT DMY BK 1 0.0 1/15/2015 0.000 4,488.7 4,299.7 25.32 3 GAS LIFT DMY BK 1 0.0 1/16/2015 0.000 5,293.3 5,047.3 13.07 4 GAS LIFT DMY BK 1 0.0 1/16/2015 0.000 5,697.4 5,446.2 6.64 5 GAS LIFT DMY BK 1 0.0 11/10/2006 0.000 6,103.1 5,850.3 3.78 6 GAS LIFT DV BK 1 0.0 8/26/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,302.0 6,322.0 6,048.7 6,068.7 A-5, 2E-10 6/7/1985 4.0 IPERF 4" Jumbo Jet 6,344.0 6,352.0 6,090.6 6,098.6 A-4, 2E-10 6/7/1985 4.0 IPERF 4" Jumbo Jet 6,381.0 6,389.0 6,127.6 6,135.5 A-4, 2E-10 6/7/1985 4.0 IPERF 4" Jumbo Jet Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,302.0 6,389.0 1 A-SAND FRAC 11/4/2006 0.0 0.00 0.00 2E-10, 10/10/2023 1:03:33 PM Vertical schematic (actual) PRODUCTION; 34.7-6,610.0 IPERF; 6,381.0-6,389.0 IPERF; 6,344.0-6,352.0 A-SAND FRAC; 6,302.0 IPERF; 6,302.0-6,322.0 PACKER; 6,156.3 LEAK - PACKER; 6,156.3 OTHER; 6,130.0 GAS LIFT; 6,103.1 GAS LIFT; 5,697.4 GAS LIFT; 5,293.3 GAS LIFT; 4,488.8 GAS LIFT; 3,325.3 SURFACE; 37.8-3,308.7 GAS LIFT; 1,911.1 SAFETY VLV; 1,869.3 CONDUCTOR; 38.0-110.0 KUP INJ KB-Grd (ft) 41.90 RR Date 12/29/198 4 Other Elev 2E-10 ... TD Act Btm (ftKB) 6,661.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292124600 Wellbore Status INJ Max Angle & MD Incl (°) 28.07 MD (ftKB) 3,400.00 WELLNAME WELLBORE2E-10 Annotation Last WO: End DateH2S (ppm) 80 Date 10/29/2014 Comment SSSV: LOCKED OUT 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: BiSN 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 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): 6661'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: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/25/2023 2-7/8" Packer: Brown HB Packer SSSV: Camco TRDP-1A Sfty Vlv (locked out) Perforation Depth MD (ft): 6302-6322', 6344-6352', 6381-6389' 6575' 6049-6069', 6091-6099', 6128- 6135' 7" 16" 9-5/8" 72' 3271' 110' 3248' 110' 3309' 6356'6610' J-55 TVD Burst 6185' MD ConocoPhillips Alaska, Inc. Length Size Proposed Pools: Kuparuk River Field Kuparuk River Oil PoolKuparuk River Oil Pool Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025658 184-230 P.O. Box 100360, Anchorage, AK 99510 50-029-21246-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6156' MD and 5903' TVD 1869' MD and 1869' TVD Katherine O'Connor 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: katherine.oconnor@conocophillips.com (907) 263-3718 Interventions Engineer KRU 2E-10 6407' 6489' 6235' None 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 4:09 pm, Jun 29, 2023 323-364 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.06.29 15:32:13-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor X X DSR-6/29/23VTL 7/4/2023 MDG 7/17/2023 10-404 JLC 7/17/2023 07/18/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:10:28 -05'00' RBDMS JSB 071823 Well: 2E-10 Date: 6/29/23 Proposed Start Date: 7/25/23 Written By: Katherine O’Connor Well History & Objective 2E-10 is an alternating water injector with a packer leak that was not fixed after installing a patch. The packer leak is too minor to get a LLR. Plan is to install a ~5’ BiSN packer in order to regain integrity of the well and put it back on injection. Procedure: Eline 1. Run baseline CBL survey 2. Pump bismuth beads down the IA (aim is to get 5’ worth of beads above packer) 3. Run CBL to survey bead settling depth 4. Pump down IA if needed to push beads to depth 5. Run heater to melt beads into solid patch 6. Run CBL to survey BISN bismuth packer top (expected about 6150’ RKB, might be a bit shallower due to fill on top of packer) DHD 7. Perform MITIA to confirm well integrity barriers 8. If passing pressure tests, RDMO and hand well over to operations to bring online 9. After well is brought online and stabilized, perform AOGCC witnessed MITIA to (give 24 hr minimum notification before pressure test) Expected top ~6150’ RKB Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/01/2021 PTD: 1842300 E-Set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y Jody Colombie at 2:53 pm, Feb 05, 2021 'LJLWDOO\VLJQHGE\'XVW\)UHHERUQ '128 $.:(//62 &RQRFR3KLOOLSV&1 'XVW\)UHHERUQ ( GXVW\IUHHERUQ#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ$QFKRUDJH$ODVND 'DWH )R[LW3KDQWRP3')9HUVLRQ 'XVW\)UHHERUQ ; ; 97/ ; '/% '65 2/8/21 dts 2/6/2021 JLC 2/8/2021 Jeremy M. 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Supervisor �l'«> FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alasks Oil and Gas Conservation Commission DATE: Thursday, July 9, 2020 SUBJECT: Mechanical Integrity Tests ConomPitillips Alaska, Inc. 2E-10 KUPARUK RIV UNP[ 21-10 Ste: Inspector Reviewed By: P.I. Supry 1 Comm Well Name KUPARUK RIV UNIT 2E-10 API Well Number 50-029-21246-00-00 Inspector Name: Adam Earl Permit Number: I84-230,0 Inspection Date: 7/4/2020 - IUsp Num: mitAGE200709101847 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2E-10 - Type Inj W , TVD 5 5903 Tubing 27K _ 2700 - z7oo - z7oo -7F--2 --- FBL 1842300 _ Type Test sPr Test psi 1500 - IA 1900 2210 - 2170 - 2135 2145 - umped: a.z 'BBL Returned: 0.7 " OA 470 470 470 - 470. 470 el 4YRTST P/F F Notes: Second NET. Well was shut in for evaluation. ✓ Thursday, July 9, 2020 Page I of I MEMORANDUM State of Alaska Insp Num: mitAGE200705092842 Alaska Oil and Gas Conservation Commission TO: Jim RegBDATE: P.I. Supervisor \� t � I ^I f -3I -rano Thursday, July 9, 2020 SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial ConomPhillips Alaskm Inc. Well 2&10 FROM: Adam Earl KUPARUKRIVUNrr2E10 Petroleum Inspector 5903 - Tubing Src: Inspector 2700 Reviewed By: 2700 - P.I. Supry p�7 NON -CONFIDENTIAL. Comm Well Name KUPARUK RIV UNIT 2E-10 API Well Number 50-029-21246-00.00 Inspector Name: Adam Earl Permit Number: 184.230-0 Inspection Date: 7/4/2020 s Insp Num: mitAGE200705092842 Rel Insp Num: Packer Depth Pretest Initial 15 Mia 30 Min 45 Min 60 Min Well 1 -10 ' Type Inj I W TVD 5903 - Tubing 1 2700 2700 2700 2700 - 2700 ' PTD 1942300 Type Test sPT Test psi 1500 - IA 1460 2000 1960 930 1900 BBL Pumped: 0_a BBL Returned: OA aao azo ala . a7o - a7o Interval 4YRTST P _IP/F Notes: No signs of stabilization. A second 45 min test was performed (see mitAGE200709101847). Thursday, July 9, 2020 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, July 5, 2020 7:57 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 2E-10 (PTD #184-230) Failed MIT -IA Attachments: 2E-10 90 day TIO plot.pdf, 2E-10.pdf; 2E-10 10-426 4 July 2020.xlsx Chris - 2E -10 (PTD #184-230) failed an MIT -IA yesterday. The well was shut in and freeze protected shortly after the failure. DHD is scheduled to conduct the initial set of diagnostics today. Additional interventions/diagnostics will be performed according to the results of the initial diagnostic testing. The proper paperwork for continued injection or repair will be submitted once diagnostics have been completed. Attached is a 10-426, a well bore schematic and a 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 ELLS TEAM WM • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday,July 10, 2017 4:23 PM To: Wallace, Chris D (DOA) Subject: RE: [EXTERNAL] RE:2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17 Chris, That sounds like a fantastic idea! We will operate 2E-10 under an internal waiver only which will limit the well to only produced water injection. To make it official, CPAI would like to rescind the Administrative Approval application that Brent submitted on July 2. With this in mind, I plan to also send in AA cancellation requests for the two 2D wells(2D-02 and 2D-04)which are already waivered for TxIA communication, but which appear to demonstrate the same temperature-dependent leak type as 2E-10. They were initially AA'ed without understanding fully the underlying failure mechanism. Going forward, these wells will also be operated under an internal waiver to limit them to produced water only injection. Let me know if you see a problem with this. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 AU 017 Mobile Phone (907)943-0170 SCANME® From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday,July 10,2017 3:34 PM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: RE: [EXTERNAL] RE: 2D-02 (Al0 2B.052, PTD 184-152)and 2E-10(PTD 184-230) update 07-02-17 Brent, Kelly, Looking this over I am struck with the thought that AOGCC shouldn't get that restrictive for a water well with temperature sensitivity. I mean,we do not have a way of recording a pressure test with seawater vs.differentiate from a produced water test. What about CPAI doing an internal requirement to restrict to produced water and then you could continue (without additional AOGCC restriction and without the 2 yr MIT)? If the packer leaks on produced water you would see the pressures and CPAI would need to act at that point. Maybe that is the better approach here. Regards, Chris From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent:Thursday,July 6,2017 7:30 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152)and 2E-10(PTD 184-230) update 07-02-17 1 i • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,July 2, 2017 6:28 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: RE:2D-02 (AIO 26.052, PTD 184-152) and 2E-10 (PTD 184-2301 update 07-02-17 Attachments: 2E-10 AA Application 07-02-17.pdf;2D-02 1 month TIO plot.JPG Chris, The 30 day injection test on produced water for 2D-02 and 2E-10 has ended. 2D-02 did not display any signs of TxIA communication while on produced water. There were a couple of IA pressure rises but one can be attributed to a thermal response and the other was due to an increase in rate and wellhead pressure. This well will remain online and continue to follow the provisions under AIO 2B.052 at this time. Attached for reference is a 1 month TIO plot to cover the test period. 2E-10 did not display signs of TxIA communication while on produced water injection as well. The plan is to apply for an AA for produced water injection only allowed. I have attached a copy of the AA application for reference and the paper copy is in the mail. The well will remain on injection while the AA is being processed. Please let me know if you disagree with these plans. Brent Rogers/Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Cell Phone(907)394-0402 411WELLS TEAM C onoc tialps SCA V1N a1UI 142 0 1 . From: ell Integrity Supv CPF1 and 2 Sent:Saturday, 18,2017 9:26 PM To: 'chris.wallace@alaska _, '<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Sen•:•@conocophillips.com> Subject: 2D-02 (AIO 2B.052, PTD 184-1 2D-04(AIO 26.037, PTD 184-151) and 2E-10(PTD 184-230) update 3-18-17 Chris, 2D-02 (AIO 2B.052, PTD 184-152),2D-04(AIO 2B.037, PTI :4-151)and 2E-10(PTD 184-230) were all identified with TxIA communication earlier this winter after their pads were s • sed to colder seawater injection for the first time in years. (Please see the attached latest email communication regardin: -ach well.) We believe that the wells only display communication when on cold fluid injection due to shrinkage of the metal, sing the tubing to pull out of the PBR. Two of the wells (2D-04 and 2E-10) had this theory corroborated when LDL ere run while on seawater and discovered that the PBR's were in fact the leak sources. 2D-04's acoustic LDL was run . 12/07/17 and 2E-10's acoustic LDL was run on 02/15/17. 2D and 2E pads will be swapped back to the warmer produced water injection (PWI) later this spring, cur stly anticipated to occur mid-April. To confirm that the leaks are indeed only present when on cold water,when t •ads resume PWI,CPAI intends to return the 3 wells to produced water injection and be put on a 30 day diagnostic 1 RECEIVED • 2c6k-67 MAY 10 2017 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. April 11, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100DATA LOGGED Anchorage, Alaska 99501 5 /14/201/ RENDER RE: Leak Detect Log with ACX: 2E-10 Run Date: 2/15/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2E-10 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21246-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-029-21246-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. �� MA) 2 6 L it r Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Aiza-rttiv • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,January 29, 2017 2:17 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 2E-10 (PTD 184-230) Report of IA pressure anomaly update 1-29-17 Attachments: 2E-10 90 day TIO plot.PNG Chris, The tubing plug for 2E-10 was set on 11/23/16. Although the initial attempts at MIT failed on 11/25/16,we did obtain a passing MITIA on 12/1/16. There was Opsi loss on the IA with minimal tbg build up during the MITIA. But that minimal buildup is suspected to be due to the plug leaking based on the follow-up drawdown tests where the tubing failed and IA passed. Since early December,the IA has also maintained 150psi while the well has been shut in. TxIA communication is suspected to only be present while the well is online. Therefore we intend to pull the plug and return the well to water injection. If communication resumes,we will perform a leak detect log using Eline. In this case, if communication does resume, it is expected that the IA pressure may rise above the DNE of 2000psi, rising as high as injection pressure, (recent history has been maxing out at "2700psi). The well is completed with 7"J-55 production casing which has a burst rating of 4980psi. Therefore 2700psi represents 54%of burst. Attempts will be made to limit the injection pressure so as to limit the IA pressure and amount of bleeding needed prior to the logging. The well will only be allowed to be online for a maximum of 7 days in this scenario. However, if signs of communication do not return,the well will be monitored for 30 days. A follow-up email will be provided at the conclusion of the monitor/logging and appropriate paperwork filed when a path forward is established. Please let us know if you disagree or if you have any questions. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 scAMR FEB 1 0 2017 Mobile Phone(907)943-0170 From: NSK Problem Well Supv • a , November 22,2016 10:40 AM To:Wallace,Chns A)<chris.wallace@alaska.gov> Cc: NSK Problem Well Supv<n 6i7.@conocophillips.com> Subject:2E-10(PTD 184-230) Report of IA pres ure anomaly Chris, Kuparuk injector 2E-10(PTD 184-230)was reported with a rapid increase in .ressure. Attempts to bleed it down have been unsuccessful and the well has been SI. The well will be secured with a down . plug set by Slickline and initial diagnostics will be performed by DHD including tubing packoff testing and an MITIA. If t' = MITIA passes,an IA drawdown test will be performed. Additional diagnostics will be scheduled as needed. Once •'=:nostics are complete • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, November 22, 2016 10:40 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv Subject: 2E-10 PTD 184-230) Report of IA pressure anomaly Attachments: 2E-10 90 day TIO p of jpg;2E-10 schematic.pdf Chris, Kuparuk injector 2E-10(PTD 184-230)was reported with a rapid increase in IA pressure. Attempts to bleed it down have been unsuccessful and the well has been SI. The well will be secured with a downhole plug set by Slickline and initial diagnostics will be performed by DHD including tubing packoff testing and an MITIA. If the MITIA passes, an IA drawdown test will be performed. Additional diagnostics will be scheduled as needed. Once diagnostics are complete and a plan forward is developed,the appropriate paperwork will be submitted at that time. Please let me know if you disagree with this plan. Attached is a wellbore schematic and a 90 day TIO plot for reference. Please let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 AWEDS TEAM SCANNED NOV 2 2 2016 • diiielleMOLIO • CD 0 0 0 0 ILO C Lep CD C\J , • 1 t, I .1 1 11 I .1 : !: i i I I. II I I II II I I I. i 111 1 1 1 • • • • . • • . • • • 1 • • : _ . I ( : • • : ------ -: • • • C,S3 . . • • —1 ••• . • • . " • . • -- 0 1 • • • • : ,' ' • Z . • . • . •• / • - '1\ -:: • • • • • • . ' • CD • • • • ::: (...o . . - : • . - •.,- • . . --- . . . - : • • • 0 • • • : 1, _ . - 1\. • • • . . • . . • • • . - . : c....o . . . 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I :• _ • • • I • • .. 1 - • . • . 11 • • L : (.0 I • • 1 • -- • — 1.— . . . . . • • • 1 : i cr) I pi ,1 1. i 1 .1 1. 1 . 1 .1 1 1 . 1 1 i. 1 i D Y < 0 i_ 1-3._ 0 c_-3 (:-.) c_-_-) cts i i_ < C (-_D CC c_-) 0 u_ 0 Lo c) up c c Lo CD C\I (NI (N.I ‘— ISd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg --i DATE: Friday,July 22,2016 P.I.Supervisor I` �� 7'ZiI/Se SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-10 FROM: Lou Grimaldi KUPARUK RIV UNIT 2E-10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2E-10 API Well Number 50-029-21246-00-00 Inspector Name: Lou Grimaldi Permit Number: 184-230-0 Inspection Date: 7/21/2016 Insp Num: mitLG160721153923 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2E-10 - Type Inj W' TVD 5903 • Tubing 2565 , 2565 2565 - 2565 - PTD 1842300 - Type Test SPT Test psi 1500 - IA 980 2000 1970- 1970- Interval 4YRTST P/F P OA 660 700- 700 - 700 - Notes: .6 Gallons Diesel pumped.5 returned.Good solid test.All pertinent paperwork supplied prior to test. .— eat : GLOTei - i st,te_& ps SCANNED MAY I92017 Friday,July 22,2016 Page 1 of 1 • I dwaljaloyo o ► a o I 1. 1 .1 . h .1 .1 . 1, 11 . . ► .1 i 1. ► 4 1, 1 .1 , 1, • . CO , - : : . • 0 •• - co C • • : : • — 't • . : • N • • • CD - O • - I C • W el :: • I N• • • . Y— • • O : .a. — p • 1- ; • •: N • : : CO• , • ._ cQ : : . - ch • . T • .• (D I : • 03 LL Q • • V - M o • • 1 - co L YI 1 'I 1' 1' 1 y P 1 ' 1 1 1' 4111 r 1 `1 t 111 '1 1 1' 14 Q F— 0 0 n. 0 0 0 0 0I~LO N N o o N � I ISd I - . ! • ' KUP PROD 2E-10 ConocoPhillips g 'Weil ANBb;Ann Tex Angle&MO T) Ala6kit 1110. V llbora APUJVA HAM name yMHbais8l8.o eel Cl MDIeXHI AdBln 111118) c-0,..,,,erLl.+yw 1500297174600 1 KUPARUK RIVER UNIT PROD it 67 3,400.00 8,861.0 --• 'CommentS!ppm) loth. AM116 6W1 End hate 1116-add len 10911010.110 001,1 1o.ZAT/D151014D;AM SSSV:LOCKED OUT l RM ...-_ �La51WO: I 117,1 12(2941984 :Annotation -Depth MKS) IEnd Data Samna oa ... Les:Mall. End Data ... .- 'Last Tap:SLM i 6,324.0 11!152015 Rev Reason"TAB.OLV C10 I hipshki I 2117/2015 ": Casing Strings _ HANGER 331- - .1 F Carina ll Duelip4ea _._. 0041n) ID Oar Top 01101) Sat Depth VniD) 1 Set Depth(IVO)...1/4/Len 0.. Grade Top Thread Ti CONDUCTOR 16 16062 38._2 1 t:, 1l ,;.bl I T TO WELDED • CMhq Oem+lp0tr 001110 ID Imo) Top(SA Sal Depth MKBJ 6:1 Depth(7110)„1600an(1...Grade . Tep Thread SURFACE 95n1 8.971 37.8 3308.7 6247.6 76.0:1.1 sr. c Castes DeeedpDpn-_.__._._0041n) at 104 Top;NIG!) Selfeptn(MB) 'Set Depth(N0),.Wet.en ll...Grade Top Peered PRODUCTION 7 6.276 31 9 6,610.0 6,356.0 24.0)r5; a,.,.1 Tubing Strings Tuhlns not edp11on r.s ..I op Sat I;Loiset Daplh(7110)1 T1Vt Pr 10rad.- Top Co.nectioe -- TUe1NG 7710. 2.441 �r.t 6,tDO. 6,532, rL55 1EUE8RD a. ...y Omptetlun betails Nominal D • Top(11103) .a_P_IN IND)UMW Top anal'1 sem Des c':n, -1 CONDJCTOR.360-11006401-",""a. 1"+ 'Y', 3 1 33 I 0.07 HANti0`FI MCEVOY TUBING HANGER 2875' 1,869.3 1,868.1 2.11 SAFETYVLV CAMCO TRDP-1A SAFETY Y+'1VE;LOCKED OUT 2312 921AN) D6,144.6 601.7 178 �- 11ROWN1'YBR 2600 SAFETY WV,,19603 l- --r ( u BROWN H9 PACKER 3.000 8,172.7 5,9 io.6 376 MIl': CAOlC` DNIPPLE 22110 6,;84.3 !'.831.3 3.76 S0.5 DATERTfiggraUTIab 1 Perforations&Slots 8Md GAS I 1FT:19111 - 111 0/1.0Tap DVD) aha 1140) 1.8et.11 MP 18884 Bbn(aK8( Ink.) 8* Tale Ode 0 i FI7(7 7 6,322.0' ..'111,3 - 4.61EtRF-:..4'7w-bolo (;.:344 n 8,3520 800.6 _ /.985 40 101/78 4'Jumbo Jet 6,381.0 6,380.0 6,127.6 .-I F.+-1 4-.11 61711685 4 iI 1."111 4'Jumha Jet , Stimulations&Treatments 600 lap Hen We ..- Depth Depth lop 41301 11to 0 W) n.evAcr N 0.3.3ot r- ;nun; 1116111 /hen) (3r484 Mx Dian coo 6,332.0 6.389.0 6.048.7 6.135.5 5.95411 FHAC 11)42008 A sand(realm lreaLmeri usirp 500 Winked pd a;15 Spm.Pump Ictal of 234:900W of 18420 ceramic GAS LIFT.eAelea .I j piappa t,placing 10 ppa an pale and 234,8000 e behind pipe. Mandrel Inserts 01 DASOIh 4.4080 1 cn 1 Top(TVD) Wlo latchPan 81a iN::laan Top(11034 ;':36:, Make Mehl OD pie few Teee Type OM awl Rue Dab Car 1,:3!I I 3510 CALICO KANO I GAS LIFT HT1' BK 0.000 410 114540.015 3,376.3 3,2523 CALICO KONG1-GASL1iT OW t3k. 0.000 0.0 tri SrN15 GAsuR,s]a33. 1 3 4,488.7 4.2967 t M1O '1(0580 4 .rAS-LffT Oaf' 017 - 600FJ 40 171672015 4 5,293.3 6017.3 CALICO 1031161 (14.4 LET MAY BK 0.000 001/1 /5315 ICI 6,6430.4 4446.2 CALICO KONG GAS LIFT 0611' .--0140.033 0.0 1U1/11006 009111r:5E10.4, 8,103-1 6,8543 GANG'S KONG1 GAS L(TT WY 0k O.00t1 0u5 1R1FNtb Notes:General ill Satety 2nd Dale e -._.... A _ Anmldlml 8A0uFr.slass 0601010 _NOTE: Schamatk w)Alaska Shcemalic9.0 -__ t_ P811 6.1446 ) PACNi:8,41863frri NOPE.41111.- 906.5110-).... i IPERF.430280.3040 ' . A4i9ND TRA(?1,307.0 ar1AF.6348/1.83626 .f- 11ERF,0,30106.3090 1- i PRODUCTION 3473/,5100 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,July 14,2015 Jim Regg P.I.Supervisor of C (6(1�/C SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-10 FROM: Chuck ScheveKUPARUK RIV UNIT 2E-10 Petroleum Inspector SCOW 1 i 1 i 0 1,2 C.;j ih Src: Inspector Reviewed By: P.I.Suprv3 e- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2E-10 API Well Number 50-029-21246-00-00 Inspector Name: Chuck Scheve Permit Number: 184-230-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713093316 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2E-10 Type Inj W•TVD 5903 • Tubing l 1360 H 1360 1360 1360 ' PTD 1842300 - Type Test SPT Test psi 1500 j IA 1600 1. 2500. 2480 - 2480 - Interval INITAL P/F� P OA 580 - 580 -1 580 - 580 . Notes: Initial test post conversion from producer to injector. Packer TVD taken from operator report. Tuesday,July 14,2015 Page 1 of 1 STATE OF ALASKA AL ,CA OIL AND GAS CONSERVATION CON .3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair well r Plug Perforations r Perforate r Other r PROD to WINJ Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name. 4 Well Class Before Work: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 184-230 3 Address: 6 API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21246-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025658 KRU 2E-10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071). 10 Field/Pool(s)• Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary Total Depth measured 6661 feet Plugs(measured) None true vertical 6407 feet Junk(measured) None Effective Depth measured 6526 feet Packer(measured) 6156 true vertical 6272 feet (true vertical) 5903 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 3271 12 3309 3248 0 0 PRODUCTION 6575 7 6610 6356 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6302-6322, 6344-6352,6381-6389 True Vertical Depth• 6048-6069, 60914-6099,6128-6136 9ECEWED JUL 14 201) Tubing(size,grade, MD,and TVD) 2.875, J-55,6184 MD, 5931 TVD ��'`++ .AOGCC Packers&SSSV(type,MD, and TVD) PACKER- BROWN HB PACKER @ 6156 MD and 5903 TVD SAFETY VLV-CAMCO TRDP-1A SAFETY VALVE(LOCKED OUT 9/21/04)@ 1869 MD and 1869 TVD 12.Stimulation or cement squeeze summary. Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 81 153 100 795 150 _Subsequent to operation 0 0 1000 1560 1393 14.Attachments 15.Well Class after work. Copies of Logs and Surveys run Exploratory r Development r Service F.; Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-659 Contact Bob Christensen/Darrell Humphrey Email n1139@conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone 659-7535 Date yr q/z/l S %/, RBDMO-V .I„r 1 7 2015 1=nrm 1n_nnn Pint/lend 1(1/')(11) CIihmif(lrininol (lnly 2E-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/10/15 STATE WITNESSED (CHUCK SCHEVE) MIT-IA PASSED TO 2500 PSI. 07/01/15 WELL CONVERTED TO WATER INJECTION SERVICE , . KUP PROD 2E-10 ConocoPhil ips 4 `i' Well Attributes Max Angle&MD TD Alaska,Inc a Wellbore API/UWI Field Name Wellbore Status ncl p) MD(ftKB) Act Btm(ftKB) rr,r ,A IIp F 500292124600 KUPARUK RIVER UNIT PROD 28.07 3,400.00 6,661.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2E-10,2/17/2015 10:14.03 AM - SSSV:LOCKED OUT Last WO: 41.90 12/29/1984 Pert cel schematic(actual) AnnotationDepth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLIT'6,324.0 1/15/2015 Rev Reason:TAG,GLV C/O hipshkf 2/17/2015 i II IP' Casing Strings HANGER 33.1 i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I...Grade Top Thread 1"I CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED 8- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.8 3,308.7 3,247.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 PRODUCTION 7 6276 348 6610.0 6,356.0 26.00 3-55 BUTT Tubing Strings Tubing Description String Ma...ID On) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt)Ib/ft) Grade Top Connection TUBING 27/8 2441 331 61850 5,932.0 6.50 3-55 E0E8RD Completion Details unw Nominal ID 1 Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Corn (in) .A.A../CONDUCTOR;38.0-110.0• I k✓.n-n...". 33.1 33.1 0.07 HANGER MCEVOY TUBING HANGER 2.875 1,869.3 1,869.1 2.11 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE(LOCKED OUT 2.312 9/21/04) 6,144.6 5,891.7 3.78 PBR BROWN 10'PBR 2.500 SAFETY VLV',1,8693 r III 6,156.3 5,903.4 3.78 PACKER BROWN HB PACKER 3.000 r X 6,172.7 5,919.8' 3.78 NIPPLE CAMCO D NIPPLE 2.250 6,184.3 5,931.3 3.78 SOS BAKER SHEAR OUT SUB 2.441 Perforations&Slots Shot GAS LIFT.1,911.1 Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 1 6,302.0 6,322.0 6,048.7 6,068.7 A-5,2E-10 6/7/1985 4.0 IPERF 4"Jumbo Jet 6,344.0 6,352.0 6,090.6 6,098.6 A-4,2E-10 6/7/1985 4.0 IPERF 4"Jumbo Jet 6,381.0 6,389.0 6,127.6 6,135.5 A-4,2E-10 6/7/1985 4.0 (PERF 4"Jumbo Jet 1 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) SURFACE;37.83,3087^a . (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 6,302.0 6,389.0 6,048.7 6,135.5 A-SAND FRAC 11/4/2006 A sand fracture treatment using 508 X-linked gel at 15 bpm.Pump total of 234,9008 of 16/20 ceramic GAS LIFT;3.325.3 Y '. proppant,placing 10 ppa on perfs and 234,800# behind pipe. Mandrel Inserts St GAS LIFT;4,488.8lk all on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 1,911.1 1,910.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/15/2015 2 3,3253 3,262.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/15/2015 GAS LIFT,5,293.3 3 4,488.7 4,299.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2015 4 5,293.3- 5,047.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2015 5 5,697.4 5,446.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/10/2006 GAS LIFT;5,697.4 6 6,103.1 5,850.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/21/2015 Notes:General&Safety End Date Annotation GAS LIFT,6,103.1 10/6/2010 NOTE:View Schematic w/Alaska Schematic9.0 I PER;6,144.6 PACKER;6,1563 GF. NIPPLE;6,1727 SOS;6,184.3 i IPERF;6,302.0-6,322.0 _ A-SAND FRAC;6,302.0 -- IPERF;6,344.0-6,352.0 IPERF;6,381.0-6,389.0 -- -- PRODUCTION;34.7-6,610.0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, August 10, 2010 3:20 PM To: DOA AOGCC Prudhoe Bay Subject: FW: KRU 2E-05 MIT Exceptions follow-up inspection would be warranted Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 y ( ~ ^Jr From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, August 07, 2010 2:34 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: KRU 2E-05 MIT Exceptions Jim, Page 1~ ~,2i;t Zc- I i ~i--- Z3 Q Initial action taken was to have corrosion inspections done on the well lines. All three well lines were inspected and all three have a pipe strength substantially above the strength required by the design pressure of the system Further actions are being taken to address the wellheads and fasteners. Those actions can or will include the following items as per well specific requirements: 1. Secure the well. 2. Abrasively clean the wellhead and associated piping to remove the current external corrosion. 3. Visual inspection by the Mechanical Engineer. If further evaluation needs to be done, it will be done at this time as well. 4. Paint the wellhead and valuing with a corrosion resistant type paint. 5. Replace any or all of the tree valves, casing head studs and nuts. This step will also repair insufficient bolt/nut engagement as well. 6. Evaluate on a case by case basis the replacement of any lockdown screws. Further mitigation ideas are being discussed in order to prevent this from reoccurring. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@al .gov] Sent: Tuesday, July 27, 2010 12:25 PM To: NSK Well Integrity Proj; NSK Proble ell Supv Cc: DOA AOGCC Prudhoe Bay Subject: KRU 2E-05 MIT Excep ' s Inspector's report attache or witnessed MIT 7-5-10. Please provide status of response to noted exceptions on wells 2 8, 2E-10, and 2E-15 8/10/2010 Cc~nocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: it f~~t~f ~ , ~r L J ~~~'~,~~ APR 2 ~ 2010 . ,~ask~ C7il ~ C~as Cons. Gommissior Anct-oraae ,, ~3 d 1$~' ~~d C~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/77/2010 2B_ 2E_ 2G_ 2H_ 2K_ 2M_ 2V_ 21N_ 2X_ 2Z S< 3S PAG's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 2B-08 50029210790000.. 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na Na Na 5.9 .4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" n/a 2.1 4/15/2010 2H-09 50103200500000 1852590 SF n/a 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" n/a 2.1 4/15/2010 2M-20 50103201690000 1920480 SF Na 17" Na 2.5 4/152010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/152010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF n/a 19" Na 7.6 4/16/2010 2V-1o 50029213100000 1850480 SF Na 19" Na 2.5 4!16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-o3 50029212740000 1850110 SF n/a 3T' n/a 4.2 4/16/2010 2X-11 50029211880000 1841640 SF n/a 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF Na 19" n/a 2.5 4/152010 2Z-12A 50029213800100 1951480 SF Na 19" n/a 2.5 4/152010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" n/a 2.1 4/152010 3S-09 50103204320000 2022050 SF n/a 45" Na 23 4/17/2010 REceIVED NOV 2 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska 0'1 & REPORT OF SUNDRY WELL OPERATIONS ' Gas Cons. Commission . . STATE OF ALASKA JI, .L 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 . Other U ...' Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 184-230 1 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21246-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 142' 2E-10 . 8. Property Designati.on: 10. Field/Pool(s): ADL 25658, ALK 2584 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6661' feet true vertical 6407' feet Plugs (measured) Effective Depth measured 6407' feet Junk (measured) true vertical 6154' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3167' 9-5/8" 3309' 3248' PROD. CASING 6468' 7" 6610' 6356' Perforation depth: Measured depth: 6302'-6322',6344'-6352',6381'-6389' "t;.;ti!!-Nr'·17 "0 , (3.~.,i,:' i, ~'-I!;f1 · t' ""..\ . ,"! .;<'i t·" ...:.:.... ¿- true vertical depth: 6049'-6069',6091'-6099',6128'-6136' Tubing (size, grade, and measured depth) 2-7/8", J-55, 6185' MD. Packers & SSSV (type & measured depth) pkr- BROWN 'HB' pkr- 6156' CamcoTRDP-1A-SSA SSSV= 1869' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6302'-6389' Treatment descriptions including volumes used and final pressure: pumped 234900# of 16/20 ceramic proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 105 640 45 -- 175 Subsequent to operation 223 885 193 - 190 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0' Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasO WAG 0 GlNJ 0 WINJO WDSPL 0 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: Contact Guy Schwartz @ 265-6958 Printed Name Guy sry._ Title Wells Group Engineer Signature éh 0- .~~ Phone Date II-J.. 7 -0<'- pfPMred bv .<:h"rnn AII~"n-Drake 263-4612 -L - "---...J R80MS 8Ft DEe 1 :1 2DD6k-\'ã ~ /(. f) .0(... Form 10-40Ç/ev:: 04/2004 \ Submit Original 0 Iy ORIGIr~/~L 1\> ~. f2/Í1~ . ConocoPhUlips Alaska,lnc. ~ sssv ~ (1869-1870, L 00:2.875) Gas Lift .. MandreWaM! 1 (1911-1912, 00:4.750) Gas Lift .. MandreWaM! 2 (3325-3326, 00:4.750) Gas Lift .. MandreWaM! 3 (4489-4490, 00:4.750) Gas Lift .. MandreWaM! 4 (5293-5294, 00:4.750) Gas Lift .. landreVOummy YaM! 5 (5697-5698, 00:4.750) Gas Lift .. MandreWaM! 6 (6103-6104, 00:4.750) P8R (6145-6146, 00:2.875) D PKR (6156-6157, 00:6.151) NIP II (6173-6174, 00:2.875) TUBING (0-6185, OD:2.875, 10:2.441) Perf ~ ~ (6302-6322) ~ A-SANO ~ FRAC i 1 (6302-6389) Perf (6381-6389) ~ 2E-10 API: 500292124600 SSSV Type: LOCKED OUT Annular Fluid: Reference Loa: Last Taa: 6407 LastOOate: 11/9/2006 I DescriDtion I CONDUCTOR I SUR. CASING I P~G Si~ Top 2.875 I 0 Interval 6302 - 6322 6344 - 6352 6381 - 6389 TVD 6049 - 6069 6091 - 6099 6128 - 6136 . Interval 6302 - 6389 Date 11/4/2006 St MD TVD Man Mfr 1 1911 1911 Camco 2 3325 3262 Camco 3 4489 4300 Camco 4 5293 5047 Camco 5 5697 5446 Camco 6 6103 5850 Camco lurner DIUQSêêiÛib~¡"· Depth TVD Type 1869 1869 SSSV 6145 5892 PBR 6156 5903 PKR 6173 5920 NIP 6184 5931 SOS 6185 5932 TTL I wt I Grade I 6.50 J-55 Date Type Comment 6/7/1985 ¡PERF 4" Jumbo Jet 6/7/1985 IPERF 4" Jumbo Jet 6/7/1985 IPERF 4" Jumbo Jet Comment A sand fracture treatment using 50# X-linked gel at 15 bpm. Pump total of 234,900# of 16/20 ceramic proppant, placing 10 ppa on perfs and 234 800# behind ~ ~ V Type V OD Latch Port TRO Date Run Vlv Cmnt Well Type: PROD Oria Completion: 12/29/1984 Last W/O: Ref Loa Date: TD: 6661 IIKB Max Hole Anale: 28~ I TOD I Bottom o 110 o I 3309 o I 6610 I Size I 16.000 I 9.625 I 7.000 I I I Bottom I 6185 Zone Status A-5 A-4 A-4 TVD 5932 Ft SPF 20 4 8 4 8 4 Type A-SAND FRAC Man Type VMfr . KRU 2E-10 Angle @ TS: 4 dea /!j) 6263 Anale /!j) TD: 4 dea /!j) 6661 Rev Reason: FRAC TAG GLVC/O Last Update: 11/14/2006 TVD 110 3248 6356 wt Grade Thread 62.50 H-40 36.00 J-55 26.00 J-55 Thread 8rd I KBMG KBMG KBMG KBMG KBMG KBMG \ GLV 1.0 BK 0.125 1410 11/10/2006 GLV 1.0 BK 0.125 1365 11/10/2006 GLV 1.0 BK 0.156 1367 11/10/2006 GLV 1.0 BK 0.188 1374 11/10/2006 DMY 1.0 BK 0.000 0 11/10/2006 OV 1.0 BK 0.188 0 11/11/2006 Description Camco TRDP-1A-SSA (LOCKED OUT FLAPPER & HYDRAULICS 9/21/2004 Brown 10' Brown 'HB' Camco 'D' Nipple NO GO Brown ID 2.312 2.500 3.000 2.250 2.441 2.441 . . 2E-10 Well Events Summary DATE Summary 10/25/06 TAGGED FILL @ 6354' RKB, EST. 35' OF FILL ABOVE BOTTOM PERF., SET 2.25" SV @ 6173' RKB, PULLED 1" GL V'S FROM ST A'S 1,2,3,4, & 1 "OV FROM ST A# 6, LDFN, IN PROGRESS. 10/26/06 SET 1" DV'S IN STA'S 4,3,2,1. LOADED WELL WITH 150 BBLS SW AND 90 BBLS DIESEL. SET 1" DV IN STA# 6. IN PROGRESS. 10/27/06 PULLED 2.25" CAT SV @ 6173' RKB AND SET 2.25" CA-2 BLANKING PLUG. APPEAR TO HAVE SLOW LEAK PAST PLUG AND ONE WAY LEAK FROM IA TO TUBING, LDFN, IN PROGRESS. 10/28/06 PULLED DV'S FROM ST A'S # 6,4, INPECTED, RESET, TESTED TUBING AND fA, MIT- IA TO 3000 PSI, PASSED. PULLED 2.25" CA-2 PLUG @6173' RKB, SET FRAC SLEEVE @1869' RKB,( 97" OAL) RDMO, COMPLETE. 11/4/06 Pump A sand fracture treatment using 50# X-linked gel at 15 bpm. Pump total of 234,900# of 16/20 ceramic proppant, placing 10 ppa on perfs and 234,800# behind pipe. Flush job to completion, with 20 bbls of diesel down tubing for freeze protection. 11/5/06 ATTEMPT TO FISH TREE SAVER RUBBER.NO SUCCESS. PULLED FRAC SLEEVE FROM TRSSSV @ 1869' RKB. 11/6/06 FCO to 6,494.2' RKB with slimhole BHA JTSWRL NZL. 1 3/4" coiled tubing @ 1 BPM. 290 BBLS slick diesel w/1 00 BBLS diesel gel used as power fluid. Well ready for wireline GLV C/O pre-production. 11/9/06 TAGGED @ 6407' RKB, EST. 18' RATHOLE. IN PROGRESS. 11/10/06 PULLED DVs @ 1911', 3325',4489',5293' & 6103'. SET SV @ 6173'. SET GLVs @ 1911',3325',4489' & 5293', IN PROGRESS. 11/11/06 SET OV @ 6103'. TESTED TBG 2000 PSI, PASS. PULLED SV FROM 6173'. MEMORANDUM TO: THRU: FROM: Julie Heusser, Commissioner TOm Maunder, P. I. Supervisor ChuCk. Scheve; Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, JanuarY 28,,, 2001: I traveled t© the Kuparuk River Field and witnessed the Semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCC Safety Valve syStem Test Report indicates I witnessed the testing of 9 wells and 18 components with one failure on 2D Pad and 5 wells and 10 compOnents with one failure on 2E Pad. The SurfaCe Safety Valve on Well 2E-16 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing' valve. This valve will be tested as soon as the wing valVe is repaired. Earnie Barndt conducted the testing tOday he demOnstrated good test procedure and was a pleasure to' work with _ AlI the wellhouses entered at these locations were clean and all related equipment appeared to be in good condition. .SummarY: I Witnessed the semi annual SVS testing at 2D & 2E Pads in the Kuparuk River Field. KRU 2D Pad, 9wells,~ 18 components' 1 failure 5.56% failure rate KRU 2E Pad, 5 wellS, t0 components, 1 failure 10% failure rate 24 wellhouse inspections AttaChment: SVs KRU 2D & 2E Pads 1-28-01 CS -X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2D & 2E Pads 1-28-01 CS. doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: P, ril~,'ps Submitted By: ~hu~k Scheve Date: 1/28/01 Operator Rep: Earnie Barndt Field/Unit/Pad: Kuparuk / ICRU / 2D Pad AOGCC'Rep: Chuck Scheve Separator psi: 'LPS 99 HPS Well Permit Separ Set L/P Test Test Test Date ~ WAG, Ol~J, Number Number psi . psi .T. riP .Code Code Code Passed GAS or CYCLE, 2D-01 1841710 '99 70 65 P 'P ' OIL 2D-02 1841520 2D'03 1841530 2D-05 1841260 3750 2000 1750 P 7' wAG 2D,06B 1981760 99 70 55 P P 'OIL '~D-67 '184i430 3750 2000 .18~0 P P ' ' 'WAG 2D-08 1841270 99- 70 60 P P OIL 2D,09 1841030 9~}1- 70 '" 55 P P ....... OIL 5b-10 1841010 ................ , , , , 2D-11 1840990 2D-12 1840940 : ~9! 70 60' P P ' OIL 2D'13 - 1840120 , 99 79 ,, 60, p p, OIL 2D- 14 1841590 2D-15 184'1600 99. 70 ' 60 'P P ' OIL , , , 2D-16 1841610 , , ,, , , , , · , , , , Wells: _ .9 Components: 18 Failures:.., 1 Failure Rate: 5.56% [] 90 Day Remarks: Suffac~..safety on 2D-05 not tested due a slow leaking ~ valve Grove valve could be closed due to snow dfiKs. tLIF 1/16/01 Page 1 of 1 SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas Conservation Commission Safety. Valve System Test Report Operator: ,Phillips Operator Rep: Eamie Brandt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 2E Pad Separator psi: LPS 99 HPS 1/28/01 Well Pemit Separ Set L/P Test Test Test Date Oil, WAG, GI~IJ, Number Number PSI PSI . Trip Code Code Code Passed GAS or CYCLE '2E-07 '1931040 2E-08 1931890 99 70 60 P P 2E-09 1842400 2E-10 -1842300 99 70 60! P P 2E-l! 1842260 99 70 50 P P 2E-15 1841890 99 70~ 50 P P 2E-16 1841900! 99 70 50 P 4 ! , , Wells: 5 Components: 10 Failures: 1 Failure Rate: 10.00°/13 9o my Remarks: Surface safety on 2E-16 had slow leak when pressure tested. Valve will be serviced a retested by operator. RJF 1/16/01 Page I ofl SVS KRU 2E Pad 1-28-01 CS.xls STATE OF ALASKA ALASK,. ,.)IL AND GAS CONSERVATION COMb,. ~$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska.. Inc. 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 780' FSL, 160' FWL, Sec. 36, T11N, RgE, UM 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2E-10 Producer' At top of productive interval 1346' FSL, 1301' FWL, Sec. 36, T11N, R9E At effective depth 1354' FSL, 1320' FWL, Sec. 36, T11N, R9E At total depth 1356' FSL~ 1326' FWL, Sec. 36~ T11N~ R9E 11. Present well condition summary 6660' Total depth: measured true vertical 6406' feet feet Effective depth: measured 6526' feet true vertical 6272' feet , UM , UM , UM Plugs (measured) Junk(measured) 8. Approval number 8-102 9. APl number 50-- 029-2124600 Feet 10. Pool Kupar'uk River' 0il Pool Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 115' 16" 1250 lbs Poleset 115' 115' Surface 3309' 9-5/8" 1370 Sx PF 3309' 3248' Intermediate Production 6610' 7" 610 Sx Class "6" 6610' 6635' Liner Perforation depth: measured 6302'-6322', 6344'-6352', 6381'-6389' MD true vertical 6049'-6069', 6091'-6099, 6128'-6185' TVD[.,., 2 7/8", 6.5 lb/ft, J-55, 6185' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) B~o~n HB, 6156', Camco TRDP,_ 1869 Alaska 12. Stimulation or cement squeeze summaryRefractur'e ^ and C Sand ~1th gelled dlesel Intervals treated (measured) 6263 ' -6389' Treatment description including volumes used and final pressure 344 bbl gelled dJesel, 32,000 lbs 20/40 car'bolite~2400 ps 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 124 224 0 1200 135 Prior to well operation Subsequent to operation 529 1154 0 1200 460 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,~¢_¢.,/M~ ~ ,/¢~.44._~¢-~,~¢._.~ Form lO-404-Rev. /~-1-85 Submit in Duplicate ARCO Alaska, Inc~~ Subsidiary of Atlantic Richfield Company REMARKS ' -/ - IOPERAflON A,T REISOTRT. TIME I C~,~'/~ WELL SERVICE REPORT E] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. .'-":. Post Office B(~ .~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 17, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Dear Mr. Chatterton' Attached in triplicate are multiple.Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Well Action Anticipated Start Date 2G-9 Fracture February, 1988 2D-16 Perforate & Stimulate March 4, 1988 ~ Perforate & Stimulate March, 1988 3M-21 Perforate & Stimulate February, 1988 2E-11 Stimulate February, 1988 2H-15 Perforate February, 1988 2H-13 Perforate February, 1988 3M-1 Perforate & 3M-2 Conversion 3M-10 Conversion 3M-15 Conversion 3M-16 Conversion Stimulate February, 1988 February, 1988 February, 1988 February, 1988 February, 1988 3J-4 Perforate 3J-9 Perforate 3J-13 Perforate March, 1988 March, 1988 March, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS-pg-0154 Attachments cc' File KOE1.4-9 AtaSka 0il & Gas Cons. c0mmiss[~)~ Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany ;--' STATE OF ALASKA ~-' ALASK, OIL AND GAS CONSERVATION COMM. .JON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate J~L Pull tubing [] Amend order [] Perforate ~A Other [] 2. Name of Operator ARCO Alaska, Inc,' 3. Address P.O. Box 100360, Anchora(je, Alaska 99510 4. Location of well at surface 780' FSL, 160' FWL, Sec. 36, T11N, RgE, UH At top of productive interval 1346' FSL, 1301' FWL, Sec. 36, T11N, R9E, UM "-"- '-'--'-"-~3e~e~;t~§l~,eP~%20' FWL, Sec. 36, T11N, RgE, UM At total depth 1356' FSL, 1326' FWL, Sec. 36, T11N~ RgE~ UM 11. Present well condition summary 6660' Total depth: measured 6406' feet true vertical feet Plugs (measured) 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2E-10 f,e ~ 8. Permit number 84-230 feet 50-- 10. Pool Kuparuk River 0il Pool Effective depth: measured 6526' feet Junk (measured) true vertical 6272' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 115' 16" 1250 lbs Poleset 115' 115' Surface 3309' 9-5/8" 1370 Sx PF 3309' 3248' Intermediate Production 6610' 7" 610 Sx Class "G" 6610' 6635' Liner 6302' -6322', 6344' -6352', 6381' -6389' MD Perforation depth: measured true vertical 6049'-6069' 6091'-6099' 6128'-6136' TVD RECEIVED Tubing (size, grade and measured depth) 2 7/8" 6 5 lb/ft J-55 6185' Packers and SSSV (type and measured depth) GaS CONS. c0mmiSSi0~ Brown HB, 6156' Camco TRDP 1869' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP ~n~]~ Perforate C Sand through tubing 6263'-6270'. Stimulate with acid or sand fracture 13. Estimated date for commencing operation 03/15/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true_and correct to th_~ best of my knowledge Signed /'~,,~.,.~ /2 .~.~~~ Title _2<~/~,~ //,~_...~,.~....~.'/~x,~ ~/' Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ORIGINAL S!r--NF~ B' LONNIE P, m.'""~-: Approved C.opy Returnee Commissioner }Approval No.2 _/~/I ~... by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ~'" STATE OF ALASKA ~'--" ALASK,. OIL AND GAS CONSERVATION COMb .... .31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator _ ARCO Alaska. Inc,- . 3. Address P.0. Box 100360, A. nchorage, Alaska 99510 4. Location of well at surface 780' FSL, 160' FWL, Sec. 36, T11N, R9E, UM At top of productive interval 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2E-lO f£o~ ~A 8. Permit number feet 1346' FSL, 1301' At total depth 1356' FSL, 1326' FWL, Sec. 36, T11N, R9E, UM FWL, Sec. 36, T11N, R9E, UM FWL, Sec. 36, T11N~ R9E~ UM 11. Present well condition summary 6660' Total depth: measured 6406' feet true vertical feet Plugs (measured) 84-230 50-- 10. Pool Kuparuk River 0il Pool Effective depth: measured 6526' feet true vertical 6272' feet Junk (measured) Casing Length Size Structural Conductor 115 ' 16" Surface 3309' 9-5/8" Intermediate Production 6610' 7" Liner 6302 '-6322' Perforation depth: measured Cemented 1250 lbs Poleset 1370 5x PF 610 Sx Class "Gm' , 6344' -6352' Measured depth 115' 3309' 6610' , 6381 '-6389' MD True Vertical depth 115' 3248' 6635' true vertical 6049' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 2 7/8", 6.5 lb/ft, J-55, 6185.~::::']; ~' '.-' ;''' "m (~OlifflllS L'.[~-.,~ (lOllS` ' - ,e~ Brown HB, 6156' Camco TRDP, 1869' , , , , ~!~sk~ 0il & '~` -' ,.' 12.Attachments Description summa~ of proposal ~ Detailed operations p}Jgram Q ~r~tch ~ Perforate C Sand through tubin9 6263'-6270'. Stimulate with acid or sand fracture 13. Estimated date for commencing operation 03/15/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to t~l~, best of my knowledge Signed ///~7'~.~ ~ .,~.~,~L/-~ Title ~ ~),~/~~~ Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test. ,QL..[.ocation clearance I Approvea t.,upy Returned , ~ Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 1. Status of Well Classification of Service Well REVISION #2 OIL [~ GAS [] SUSPENDED [] . ABANDONED [] SERVICE [] · . . 2. Name of Operator 7. Permit Number ARCO A1 aska, Inc. ~ 84-230 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21246 4. Location of well at surface 9. Unit or Lease Name 780' FSL, 160' FWL, Sec.36, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1346' FSL, 1301' FWL, Sec.36, T11N, RgE, UM 2E-10 At Total Depth 11. Field and Pool 1356' FSL, 1326' FWL, Sec.36, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc~) I 6. 'Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 142'I ADL 25658 ALK 2584 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/18/84 12/28/84 12/29/84* N/A feet MSL 1 I 17. Total DePth iMD+tVD} liS.Piug Back Depth {MD+'I'VDI 10. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6660'MD, 6406'TVD 6526'MD, 6272'TVD YES [~ NO [] 1869' feet MD . 1470' (approx) 22. TYpe Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/Cal , Gyro (GCT), CBL/CCL/GR 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" 1250# Pol eset 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 710 sx PF E & 660 sx PF C . 7" 26.0# J-55 Surf 6610' 8-1/2" 360 sx Class G & 250 s~ PFC , , . 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) 2-7/8" 6185 ' 6156 ' 6302 ' -6322 ' 6344'-6352' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6381 '-6389' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addel~dum for fracture ~lata. . . _ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MGF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ , . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core Description was previously submitted. ~ I~'~ i!4 ~- '""-:; '¢'":~ S~.:,-~ n ~; !:'~':: ~, ..,.. ,~. ,~o,,.. Oil & O. aS *Note: Tubing was run and the well perforated 6/7/85. F,,~ .... ,..~ ~'" STATE OF ALASKA ~-" ~ ALASKA OIL AND GAS CONSERVATION L, OMMISSION ELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Rev. 7-1-80 WC:~/6O :DAN I CONTINUED ON REVERSE SIDE Submit in duplicate · _,GE'OILOGICLMAR~:~RS:'-~ ~':) ~:,'~ ,~ ,.-:--, ~'i~, ¥:t :%,,¢;; .-': ;F, j-.:~. ~ ', ',,'". ' ' NAME ........................ Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ?. ~.~.~.; ~ .... :.-.. , . . , . , . . Top Upper Sand :,-L_ 6263' 6009~ N/A . Base Upper Sand 6269.~ 6015~ Top Lower Sand :~;~t'r~ --;~2 6287~ 6033~ ~--~:'.-'.,~'-~' · '~'-~ ..... ' ' Base Lower -Sand ~ ':"' t6397, 61 ~3-i ,~. J -;a,~ ..:_'~[:'~. :.., :~.-..' . . ; ;;-'...~..,. -. ; .. . . L; i - ': . ............ ' .... I ' 31. LIST OF ATTACHMENTS .. Addendum 32. I hereby certify that the fo~goin~ i~:t~'U~'ah~ correct to t~best of'my knowledge ' :'" ' "" ~: .: ~ ~. .. ~ ~ ~ : .~: :.~ . ::?~. .:', . ..,.. _,'. .. Signed )~~ .~/~__) TitleASsoc'a~e Eng 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 :6'~ ~;-bfVi~' 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 producti°n 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 detai'ls 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 ADDENDUM WELL: 8~26~85 2E-10 Frac well in 3 stages w/139 bbls gelled diesel. Pmp 2100# of 20/40 sand. Rn CCL/Temp tl to PBTD. Martin entry @ 6326'-6390'. POOH, RD. Drilling ~perintendent Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA DATE: APRIL 30, 1986 AK, OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR. ANCHORAGE, AK 99510 ATTN: JOHN BOYLE OPERATOR: ARCO SAMPLE TYPE: CORE CHIPS NAME: KUP 2E-10 NUMBER OF BOXES: 12 SEE ATTACHED: SHIPPED BY I ~-~'~-~ PEG WEISSER, TECH AIDE FOR T.A. GORUP UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: PALEO LAB, ABV-100 RECEIVED BY: DATE: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /- ARCO Alaskal Inc. Post Office B~-'~00360 · - Anchorage, A ..... ~(a 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL. SHIPPED TO: STATE OF ALASKA DATE: APRIL 30, 1986 AK, OIL & GAS CONSERVATION COMMISSION . 3001 PORCUPINE DR. ANCHORAGE, AK 99510 · ATTN: JOHN BOYLE OPERATOR: ARCO SAMPLE TYPE: · SEE ATTACHED: CORE CHIPS NAME: KUP 2E-10 NUMBER OF BOXES: 12 .. · · .. SHIPPED BY I ~,~&~ PEG WEISSER, TECH AIDE FOR T.A. GORUP UPON. RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ' ARCO ALASKA, INC. P.O. BOX 100360 .... ANCHORAGE, ALASKA 99510 ATTN: PALEO LAB, ABV-100 RECEIVED BY: DATE: ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfieldCompany Date: April 17,. 198~ ~ Subject: Documentation Request-Core Chips For The State Of Alaska From Kuparuk 2E-10 From/Location: Peg Weisser, ABV-100 For T.A. Gorup To/Location: Dan Fortier, ATO-1026 @ 1' Intervals DEPTHS COMMENTS DEPTHS COMMENTS 6250-6284 6287-6385 6398-6446 THIS LIST EXCEPT AS NOTED IN COMMENTS AND CORRECTIONS COLUMN, IS A COMPLETE LIST OF SAMPLES DUE THE STATE OF ALASKA.- PLEASE SIGN AND RETURN THIS FORM TO: PEG WEISSER, ABV-100 FOR T.A. GORUP .~. NAME DATE ARCO Alaska, Inc. is a Subsidiary of AtlanllcRIchfleldCompany AR3B-6001 ARCO Alaska, Inc. Date: April 17, 1986 Internal Correspond a Subject: Documentation Request-Core Chips For The State Of Alaska From Kuparuk 2E-10 From/Lecation: Peg Weisser, ABV-100 To/Lecation: Dan Fortier, ATO-1026 For T.A. Gorup @ 1' Intervals DEPTHS COMMENTS DEPTHS COMMENTS -6250-6284 ~ 6287-6385 6398-6446 THIS LIST EXCEPT AS NOTED IN COMMENTS AND CORRECTIONS COLUMN, IS A COMPLETE LIST OF SAMPLES DUE THE STATE OF ALASKA. PLEASE SIGN AND RETURN THIS FORM TO: PEG WEISSER, ABV-100 FOR T.A. GORUP NAME DATE ARCO AlasKa. Inc Post Office uox 100360 Anchorage. AlasKa 99510-0360 Tetel~one 907 276 1215 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. return one signed copy of this transmittal. DATE 04-03-86 TRANSMITTAL # 5622 Please acknowledge receipt and Final Prints: Schl: CET's or CBL's: One * of each ~iA-14 12-03-85 Run #2 7050-7732 '~1E-24 02-21-85 Run #1 6390-6964 ~1E-24 02-23-85 Run #2 6400-7000 ~'"~ lQ-1 04-16-85 Run #1 0695-4476 ~iQ- 10 01-28-85 Run #1 5346-7359 '~2E- 10 01-14-85 Run #1 4710-6500 '~2E-11 01-13-85 Run o#! 6050-8250 ~2E-12 01-13-85 Run #1 5390-7522 '~2H-9 12-06-85 Run #1 6000-8016 ~2W-15 02-11-85 Run #2 6488-8062 ~3A-5 11-03-85 Run #1 6771-8518 ~3A-6 11-03-85 R~ #1 6086-7545 '~3A-8 11-04-85 Run #1 5186-7006 ~3F-8 11-14-85 Run #1 5410-6885 Receipt Ack~nowiedged: Vault*films AIqCO AlasKa. Inc. ,s · Sul)l~O~af'y Of Altallt~clal~cl~flei~Col~lO&fly Date: NSK C!erk*b! & Gms Cans. Oomm,ssio- ARCO Alaska, Inc. Post Office r=,.._ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 PorcuPine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED S E P o O~ ~ G~s Cons. Commission Anchore..:l.e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~-'"L AND GAS CONSERVATION C('-"-,MISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address . P.O. Box 100360, Anchorage; Alaska 99510 COMPLETED WELL OTHER [] 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 7. Permit No. see attached 8. APl Number s0- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Poo see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [~ Repairs Made Pull Tubing [] Other X~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list o~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. sEP 2 o AlasKa Oil & Gas Cons. commiss'~on Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :~,/~'~ ~.~-~'~'~--~ Tit~e. Kuparuk Operations Coordinator Date. 9/18/85 The space below for Commission use Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy .... By Order of ¢_--~. ~_~:;~'~ COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:009 100 96 95 84-152 151 126 143 101 99 159 161~ 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 8'3-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 " 2580 12/15/85 20970 " " 10/15/85 20974 " " 12/15/85 029-21177 25653 2579 12/15/85 '21176 " " 10/15/85 21157 " " 10/15/85 21169 " " 12/15/85 21135 25658 2584 10/15/85 21134 " " 12/15/85 21183 " " 12/15/85 21185 " " 10/15/85 029-21246 25658 2584 12/15/85 21227 " " 12/15/85 21213 " " 12/15/85 21214 " " 12/15/85 029-21058 25657 2583 12/15/85 21063 " " 12/15/85 21062 " " 10/15/85 21065 " " 10/15/85 21032 " " 12/15/85 21035 " " 12/15/85 21048 " " 10/15/85 21052 " " 10/15/85 029-21150 21165 21119 21124 21140 21159 21163 25656 2582 12/15/85 " " 10/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 029-21269 25644 2575 10/15/85 21270 " " 12/15/85 21283 " " 10/15/85 21303 25643 2574 10/15/85 21262 " " 10/15/85 21264 " " 12/15/85 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25655 2581 10/15/85 25644 2575 10/15/85 " " 10/15/85 " " 12/15/85 25655 2581 10/15/85 " " 12/15/85 25642 2573 10/15/85 " " 12/15/85 " " 12/15/85 ,," .,,~, ~,~2/i5/85 ECEIV Aiask~ {')i! & Ga.~ ¢;or~s_ comm!ssiort ARCO Alaska, Post Offk. :ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/30/85 TRANSMITTAL NO: 5305 RETU~ TO: ARCO ALASKA, INC. KUPARUK OPE~a?IONb ENGINEERING RECORDS CLLKK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND RETURN ONE SIGNED COPY OF bE~ULNCE OF EVENTS PRESSURE DATA "-2X-10~PBU -"-lQ-9 -- PDU C SAND ~2A-2-~PBU A SAND "'~2AC4'' PBU PRE bTRESS FRAC A SAND 2A-4 PBU PRE STREbS F~c~C a bAND HEReWITh ARE THE FOLLO~ING I?~v]$. PLEASE ACKNO~LEDGE THIS TRANSMITTAL. ! . ~2E-9"- PRESSURE REPORT ~2L-10-'PRE~SURE REPORT '~2~REbS UR~ REPORT ~~ PRESSU~ REPORT ~2U-10 PRESSURE ~LPORT ~2U-1t PkESSU~ REPOKT ~2U- 16--PRESSURE REPORT ~ 2U-16 ~BOTTOM-HOLE-S~PLE ~2U-16-PBU C SAND ~2U-14-PBU A SAND ~2U-16~PBU A S~D ~2U-14'PBU C SAND ~2W-13 PBU C SAND ~2U-16 PRESSU~ REPORT / /'~ f- .~, RECEIPT ACKNO%~LEDGED: DISTKIsUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLE~ J. RATHMELL* BPAE* B. CURRIER CHEVRON* D & M* 4~25/85 2~22/85 5/12/85 1124/85 12/6/84 12128/84 6/13/85 6/13/85 6/13/85 6/ 7/85 61 6~85 5/27/85 5/27/85 5/29/85 6/13/85 61 6~85 6/30/85 6/16/85 6/17/85 6/17/85 5/29/85 STATE OF ALASKA* SO,riO* UNION* K. TULI~/VAUL? ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska. Post Offic Cox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/30/85 TRANSMITTAL NO: 5305 RETURN TO: ARCO ALASKA, INC. KUPARUK OPE~ATIONb ENGINEERING RECOkDS CLL~d< · ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 9951U TkANSt4ITTED MERL%~ITh ARE THE FOLLOWING RECEIPT AND RET0}~N ONE SIGNED COPY OF THIS TRANSMITTAL. bE~ULNCE OF EVENTS PkCSbURE DATA ~2X-10~PBU ~vbW-1 'ShBhP ~1~-9--PDU C SAND ~2A-2-~ PBU A ~2A-4- PBU P~ bT~SS F~C A 2A-4 PBU PRE STI{Eb~ F~C a bAND 2E-9~ PRESSU~ REPORT 2~-1 ~PRESSU RE REPORT ~bSU~ ~EPORT ~'2~J~6'' PRESSURE REPORT "-2U-10 PRESSURE F, LPORT -"'~2U-1t PR~.'bSUKE REPO~{T "~ 2U- 16"PRESSURE REPORT 20-16 ~BOTTOM-HOLE-S~3PLE ~2U-16'PBU C SAND ~2U-14'PBU A SAND ~2U-16~PBU A ~2U-14'PBU C SAND ~2W-13 PBU C SAND ~2U-16 PRESSU~ REPORT / RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DIST~iDUTION: DRILLING W. PASHER L. JOHNSTON LXXON ~OB!L* PHILLIPS OIL* NSK CLE~( J. RATHMELL* PLEASE ACKNOWLEDGE 4/25/85 2/22/85 5/12/85 1/24/85 12/6/84 12/28/84 6/13/~5 6/13/85 6/13/85 6/ 7/85 6/ 6/85 5/27/85 5/27/85 5/29/85 6/13/85 6/ 6/85 6/30/85 6/16/85 6/17/85 6/17/85 5/29/85 DATE: STATE OF SO~IO* UNION* ALASKA* K. TULIr~/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanhcRichf~etdCompany ARCO Alaska, Inc. Post Office Bo^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2E-10 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, , ^ssociate Engineer JG/tw GRU10/L113 Enclosure If RECEIVED AUG 1 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALASK'A',~ _ AND GAS CONSERVATION CO .~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i · , . 1. Status of Well Classification of Service Well REV I S I ON OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Nam~ of Oper~t0r 7. Permit Number ARCO Alaska, Inc. 84-230 .. 3. Address ........ 8. Apl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21246 ,, , . 4. Location of well at surface 9. Unit or Lease Name 780' FSL, 160' FWL, Sec.36, T11N, PgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1346' FSL, 1301' FWL, Sec,36, T11N, PgE, UN 2E-10 · At Total Depth 11. Field and I~ooi 1356' FSL, 1326' F~fL, Sec,36, T11N, PgE, UM Kuparuk River Field ,, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 142' RKB ADL 25658 ALK 2584 . 12'.'" Date Sp'uddedl 2/18/84 13. Date Ti~). Reached12/28/84 14' Date C°mp'"~usp' °r Aband' ! 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 2/29/84*, N/A feet MSL 1 '17. Total Depth {MD+T'VD) 18.Plug Back DePth (MD+'I~D) 19. Dire'ctional Survey I 20. Depth ~here SSSV'set ] 21. ~'hickness of permafrost 6660'MD,6406'TVD 6526'MD,6272'TVD YES [~X NO []J 1869 feet MD~ 1470'...(.Approx) _ 22. Typ~'Electric or Other Logs Run DIL/SFL/CR/SP, FDC/CNL/Cal, Gyro (GCT} · , 23. ' ...... cASING, LINE'F~ AND cEMENT. I_NG RECORD . . . , . SETTING DEPTH MD CASINGSlZE WT. pER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTINGRECOFI. D AM.OU. NTPULLED 16" 62.5# ' ' H';40 Surf 115' 24" 1250# Poleset 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 710 sx Permafrost E & (;60 sx Permafrost C ,, 7" 26.0# J-55 Surf 6610' 8-1/2" 360 sx Class C & 25.0 s; PF "C" ., , ,. J 24. Perforations open to'Production (MD+TVD o~ ~rop and BOttom and 25. TUBING RE"OR6 interval, size and number) SIZE ' DEPTH SET {MD). PAC. KER 'SET (MD) 6302' - 6322' 2-7/8" 6185' 6156' ,,, 6344' - 6352' w/4 spf, 120° phasing 6381' - 6389' ~_6. ACID, FRACTURE, CEMENT SQUEEZE, ETc. DEPTH iNTERVaL (MD') AMouNT& KINDbF MATERIALUS~D N/~ ,,, · .. _ ..... 27. N/A PRODUCTION TEST · ,, Date First Production I Method of operation (Flowing, gas lift, etc.) I Date of Test Hours Tested I~RODU~TIC~N FORt Gl L-BBL ' GAS-MCF WATER-BBL CHOKE SIZE GAS-OI~ RATIO TEST PERIOD ~. .. Flow Tubing Casing PressUre cALcuLATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~j 28. ' ........... CORE DATA ....... Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or wale r. Submit core chips. Core Description was previously submitted. R E C E IV E D 4 Alaska 0il & Gas Cons. Commission Anchorage ...... Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and the well perforated 6/7/85. TEMP/WC78 CONTINUED ON REVERSE SIDE Submit in duplicate :-.' -, ,.-- '.;: ? ':: G~O'~'i'C'I~'/~i~-~I~ ;-~i;:';:i _~ i~ -:/ ~',:_': .::. ";'i'-: ;:'- !.'--~" .-f",::'"' -kLt-': ~:"'~-~ ~...P ;':;,TFORMAT'iON':T'Es~:' "..."~,. '; .*.;:! .. ':' :;:'"'": '": . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 626~?' 6009~ N/A :"' '. Base Upper Sand . 6269, - 6015' . . Top Lower Sand !:'--6287' 6033' " ~ "' "' ' " Base Lower Sand 6397' 6143' . . ·. ~..' - - .. : · .. .. . , 31. LIST OF ATTACHMENTS We!! H~story (¢omp!et~o_n det~_J!s) 32. I hereby certify that the foregoing is true and correct to the best of my knowle~lge . :. ,'~~",; - c~-~ Signed~'k~f;/'1/~1.~//f]?( ~'; i/"C, ~ Title Associ ate Engineer Date /I 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". Fnrm 1 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 test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District I County or Parish I State Alaska North Slope Borough Field ILease or Unil Kuparuk River I ADL 25658 Auth. or W.O. no. ITM AFE 203947 I Completion cOSt center code Alaska IWell no. 2E-10 Nordic # 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Comp let e 6/06/85 A.R.Co. Date 6/07/85 Date and depth as of 8:00 a.m. 6/08/85 thru 6/10/85 Complete record for each day reported API 50-029-21246 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well IHour I Prior status if a W.O, 6/05/85 ! 1215 hrs. 7" @ 6610' 6526' PBTD, WO fsh'g tls 10.1 ppg NaC1/NaBr Accept rig @ 1215 hrs, 6/05/85. NU & tst BOPE. RU & perf 6381'-6389', 6344'-6352', 6302'-6322' w/4" guns, 4°SPF. RIH w/2-7/8" compl string. Drop ball, lnd tbg. Pull up to shear PBR. Pkr not set. POOH w/PBR. 7" @ 6610' 6526' PBTD, TT @ 6185', Displ to crude 10.1 ppg NaC1/NaBr RIH w/OS, POH w/pkr. RIH w/2-7/8" tbg. BOPE, NU & tst tree. Displ w/crude. Set pkr, shear PBR, ND 7" @ 6610' 6526' PBTD, TT @ 6185', RR Kuparuk crude Displ well to crude. Set BPV. RR @ 0930 hrs, 6/8/85. (Note: Rn 252 jts, 2-7/8", J-55, 6.5# EUE 8RD, IPC tbg w/SSSV @ ~9~3', I~1~'~' Pkr @ 7~B8~', "D" Nipple @ $~C~', Tailpipe @.~'.) blS ' r'/5 ' Old TD Released rig 0930 hrs. New TD Date 6/8/85 PB Depth Kind of rig 6526' PBTD Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single tCF' Producing method I Official ..... oi ..... (s) '",~, ] V~..~ Flowing J Kuparuk Sands Potential test data · Well no. Date Reservoir Producing Interval Oil or gas Test time Production'-' ,~4 ~,, A/ask P~Gt/t~f ~,~ Gas por-~ay - ~a~ Oqns. Commission Anchora~o Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date I Title For form prep-aration and dis~ri4tion, -- see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ALASKA OIL AND gAS gONSERYATION.GOMMI$SION Bill Sheffield, Governor 3001 PORC'UPINE DRIVE ANCHORAGE,ALASKA g95014-3~02 TELEPHONE(907) 279,-1433 RE: Well · · - J We wish to bring to your attention that the Commission has no~ yet received the following required items on the subject well which our records indicated was completed ../_~.~-_~?-t~>~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. C. V. Chatterton/ Chairman lc:C.024 35 36 0 I~, 015 014 0 I~ 012 011 0 I0 0 · ~ :LO WELL ',,E:LL WELL 16 V m y m X- FSI. y imm X- PAD FSL y m V m X- IAD FSL X- PAD i:'SL 5,9~,aZ2.~9 529,971.!9 E::~ · 1D5.7 7~0 5,9,~,Z.,47.~ LAT. 70°~,' 529,971.~ ~. 14~4~'27. 89~' ~. 105.6 O.G. ~. 1~.2 5,9~4,&72.31 LAT. 7(f~15' 33.6926'' 529,971.00 LOI, C. 14gO&5'27. 893" ~. 10S.& O.G. ~. 1~.1 8~ ~ 1~ ~. 36 5, o~4,497.&1 LA:T. 70015, 33.9395" 529,970.8A t.13t~. 14~4~'27. 8~" ~. 1~.7 0.~. ~. 1~.0 8~5 ~ 1~ S~. ~ 5,96,~, 547.Z,0 LA.T. 70015, 34.4312" 529,970.59 LOt~. lZ~9045'.27. 8~" ~. 105.9 O.G. ~. ~.6 Y = 5,9/a4.572._'10 LAT. 70°15'34.6781" X = 529,97G. 51 LDbr,. 149°45'27. 895" PAD ~. 105.9 O.G. EI---'V. 99.5 FSL 930 ~ 160 SFAC. 36 2 I . NC) SC, A L~E LOCATED IN PROTRACTED SECTIONS 35 NOTE: BASIS OF POSITION IS MONUMENTATION l~~~i~'~/ i "B k k ~ "~ i %" I "I , .~.=s~ c~..,.. 'HAT ' AM PROPERLY REGISTERED AND ) ~ ,, , %~- ~ ~ . ~ _ ~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~ ~ ~ ~ ~ I ALASKA AND %HAT THIS PLAT REPRESENTS A SURVEY MADE _-5{ ,. sx,, I ~{ I I I k { I i ~ll / [~~ Ku.or.' PrOjeCt North Slope Drilling ,, I ~ ) I I . / I~ i ~'~ ' " DRILL SITE 2E I 'V fl~g.ffi CONDUCTOR AS-BUILT THISSIEVEY~~ / I~ UU$ ;~ LOCATIONS .,o. .' ,. ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-08-85 TRANSMITTAL NO: 5242 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. / pL/EASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS FLUID AND ACID DATA lQ-5 'C' SAND ACID 06-23-85 lQ-6 'C' SAND ACID 06-24-85 2D-7 'C' SAND ACID STIMULATION 06-21-85 2D-8 'C' SAND ACID STIMULATION 06-21-85 2H-3 'A' SAND ACID STIMULATION 06-23-85 2H-3 'A' SAND ACID STIMULATION 06-21-85 2H-3 'A' SAND ACID STIMULATION 06-22-85 3B-3 FLUID I. D. 06-23-85 3B-3 FLUID I. D. 06-20-85 PRESSURE DATA 1E-25 BHP WORKOVER lQ-13 STATIC AND MISCELLANEOUS lQ-14 STATIC AND MISCELLANEOUS lQ-15 STATIC AND MISCELLANEOUS lQ-16 STATIC AND MISCELLANEOUS 2E-9 BHP STATIC SURVEY 2E-10 .BHP STATIC SURVEY 2E-11 BHP STATIC SURVEY 2E-12 BHP STATIC SURVEY' 2F-10 FLOWING BHP AND MISC. !U-14 'C' SAND PBU--START 2U-14 'C' SAND PBU--FINISH 2U-16 'A' SAND PBU--START 2U-16 'A' SAND PBU--FINISH !V-5 'A' SAND PBU--START 2V-5 'A' SAND PBU--FINISH 2V-13 INITIAL BHP & MISC. 2V-13 INITIAL BHP & MISC. !V-14 INITIAL BHP & MISC. ~V-15 STATIC BHP lV-16 STATIC BHP lX-2 2X-2 lX-5 ~B-2 'B-3 B-5 B-6 .ECEIPT ACKNOWLEDGED: ~PAE* MOBIL* -HEVRON* ~ & M* E-LINE BHP E-LINE BHP BHP FOR WORKOVER STATIC PRESSURE & MISC. STATIC PRESSURE & MISC. STATIC BHP PRIOR TO FRAC STATIC BHP PRIOR TO FRAC 06-12-85 06-24-85 06-23-85 06-21-85 06-21-85 06-13-85 06-13-85 06-13-85 06-13-85 06-14-85 06-18-85 06-18-85 06-17-85 06-17-85 06-26-85 06-26-85 06-22-85 06-21-85 06-22-85 06-19-85 06-19-85 06-16-85 06-14-85 06-12-85 06-14-85 06-15-85- 06-26-85 06-26-85 SOHIO* NOWSCO/HALLIBURTON NOWSCO/HALLIB URTON B.J.HUGHES B.J.HUGHES CAMCO/HOT OIL DOWELL N OWS CO OTIS OTIS OTIS CAMCO CAMCO CAMCO CAMCO OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO/OTIS OTIS ~ OTIS OTIS CAMCO A, laska 0il & G~s Oons. oomm\ss~on CAMCO kn~,hsra93 CAMCO CAMCO DATE: K. TULIN/VAULT L. JOHNSTON WELL FILES ALASKA OIL AND ~AS gONSEIII/ATION.COMMISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA ggS01~-3fg~ TELEPHONE(g07) 21g,.-1433 DATE: ~- -- "' ~oc, ~ We wish to bring to your attention that the Co~ission has yet received the following required items on the subject well ~n~n our r~oras ~a~atea was completed _/~-~ ~-2~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing m. aterial. Chairman lc:C.024 ARCO Alaska, Inc .... Post Office Be J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Revised Well Completion Reports Dear Mr. Chatterton' Enclosed are revised Well Completion Reports wells' 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the when each well was Arctic Packed. If you please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures for the following cement quantity used have any questions, RECEIVED APR 2 2 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchlieldCompany STATE OF ALASKA ALASKA,~.L AND GAS CONSERVATION CC._..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV 151 ON OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-230 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21246 4. Location of well at surface 9. Unit or Lease Name-' 780' FSL, 160' FWL, Sec.36, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1346' FSL, 1301' FWL, See.36, TllN, RgE, UM 2E-10 At Total Depth 11. Field and Pool 1356' FSL, 1326' FWL, Sec.36, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool .142' RKB ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/18/84 1 2/28/84 1 2/29/84 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6660'MD,6406'TVD 6526'MD,6272'TVD YES I~X NO [] N/A feet MD 1470' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/Cal, Gyro (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" 62.5t/ H-40 Surf 115' 24" 1250# Pol eset 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 710 sx Permafrost E & ;60 sx Permafrost C 7" 26.0# J-55 Surf 6610' 8-1/2" 360 sx Class G & 250 s 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) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST ~ERIOD I~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core Description was previously submitted. RECEIVED APR 2 '2 Alasi<a Oil & Gas Cons. Commission A,qchor&o~ Form 10-407 JNH2/WC10 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " GEQLOGI'C MARKERS .... ~. - ' NAME Include interval tested, pressure data, all fluidS"r~0vered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time 0f each phase~ Top Upper Sand 626~~ 6009~ N/A Base Upper Sand 6269~ 6015~ Top Lower Sand ,' -.6287~ 60~~ Base Lower Sand 6397' 6143' .. ,- ~ ,~ . -' . :, .' : .'-. .. ,, - ;~ ~ .: . :~,'~ .... : . .-;.. . , - _ . ;. ..[-. . t · · ' . . , . . . . . ~ ~ · . . . 31. LIST OF ATTACHMENTS .... ,--. .: - None., - ~ - .... ', ' 32. I hereby certify that the foregoing is true and correct to the best of my kn0wledge Signed ~~ ~~ Title Ass°ciate Engi neet Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from mo,re than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.); Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Bo.,( 360 Anchorage,, ka 99510 Telephone 907 277 5637 P~ETUP~N TO: Date:03/06/85 Transmittal No'5077 **Page 2 of 2*** ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 /~chorage, AK 99510 ' . ~ansmitted herewith are the following items. ~/and return one signed copy of this transmittal. FINAL PRINTS OPEN HOLE (One Sepia of each) Blueline Schlumberger Please acknowledge 2C-15-LCONTIN~ED from previous page. 2" Density/Neutron-GR 12/30/84 5" Density/Neutron-GR 12/30/84 5" Cyberlook 12/30/84 Run #1 Run #1' Run #1 6545-7129 (Porosity) 6545-7129 (Porosity) 6545-7114 2C-16 2" DIL/SFL-GR 12/22/84 5" DIL/SFL-GR 12/22/84 2" Density/Neutron-GR 12/22/84 5" Density/Neutrmn-GR 12/22/84 2" Density/Neutron-GR 12/22/84 5" Density/Neutron-GR 12/22/84 5" Cyberlook 12/22/84 Run #I Run #1 Run #1 Run #1 Run ~1 Run #1 Run #1 3853-8392 3853-8392 3853-8392 3853-8392 7650-8392 7650-8392 7850-8320 (Raw Data) (Raw Data) (Porosity) (Porosity) AE-IO 5" Cyberlook 12/28/84 Run #1 2" DIL/SFL-GR 12/28/84 -Run #1 5" DIL/SFL-GR 12/28/84 'Run #1 2" Density/Neutron 12/28/84 Run #1 5" Density/Neutron 12/28/84 Run #1 2" Density/Neutron 12/28/84 Run #1 5" Density/Neutron 12/28/84 Run #1 6090-6605 3306-6652 3306-6652 6100-6623 6100-6623 6090-6623 6090-6623 (Raw Data) (Raw Data) (Porosity) (Porosity) receipt Receipt Acknowledged: DISTRIBUTION B. Currier Drilling BPAE Geolog~L.Johnston Chevron Mobil D NSK Drill Clerk Pasher F_2cx o n Sohio Phillips Oil Union J. Rathmell K. Tulin/Vault ARCO Alaskl, loc. iS a lubsidiar¥ of AllanhcRIchfieldCompany ARCO Alaska, Inc. Post Office B 360 Anchorage, A.,...~ka 99510 Telephone 907 277 5637 RETUP~N TO: Date:03/06/85 Transmittal No: **Page i of 2** 5077 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P./~. Box 100360 chorage, AK ~9510 ' ' /~ansmitted herewith are the following items. Wand return one signed copy of this transmittal. ¢ FINAL PRINTS OPEN HOLE (Onesepia of each) Blueline Schlumberger Please acknowledge receipt 1Q-12 5!, 2,I 5,! 11 5II 211 2W- 12 11 5t~ 2" 5I! 2" 5'1 51' DIL/SFL-GR 12/25/84 Run #1 DIL/SFL-GR 12/25/84 Run #1 Density/Neutron 12/23/84 Run #1 (Porosity) Density/Neutron 12/25/84 Run #1 (Porosity) Density/Neutron 12/25/84 'Run #1 (Raw Data) Density/Neutron 12/25/84 Run #1 (Raw Data) Cyberlook 12/25/84 Run #1 · .. DIL/SFL-OR DIL/SFL-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-GR Density/Neutron-Gr Cyberlook 12/29/84 Ru~ #1 12/29/84 ~un #1 12/29/84 Run #1 12/29/84 Run #1 12/29/84 Run #1 12/29/84 Run #1 12/29/84 Run #1 3570-6992 3570-6992 5570-6966 5570-6966 5570-6966 5570-6966 6450-6950 '2717-8038 2717-8038 2717-8012 (Raw Data) 2717-8012 (Raw Data) 2717-8012 (porosity) 2717-8012 (Porosity) 7450-7950 2C-15 2" DIL/SFL 5" DIL/SFL 2" Density/Neutron-GR 5" Density/Neutron-GR Receipt Acknowledged: B. Currier BPAE 12/30/84 Run #1 12/30/~', Run #1 12/30/84 Run #1 12/30/84 Run #1 **CONTINUED** DISTRIBUTION Drilling Geolog~L.Johnston 3154-7154 3154-7154 .... W. Pasher Exxon Sohio Chevron Mobil Phillips Oil Union D &M NSK Drill Clerk J. Rathmell K. Tulin/Vault ARCO Alaska. Inc. i$ a ~ubsidiar¥ of AllanticRichlieldCompany ARCO Alaska, Inc. Post Office B~,.~'00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 15, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2E-10 Dear Mr. Chatterton' Enclosed is a copy of the 2E-10 Well History to include with the Well Completion Report, dated 02/05/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L155 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B0"X-'f00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2E-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2E-10. I have not yet received the Well History, but when I do, I will forward a copy to you. Also, the tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L98 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ~ o ALASK/~';~..~ AND GAS CONSERVATION CO...,_/~I. ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well I OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-230 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21246 4. Location of well at surface 9. Unit or Lease Name - ~ 780' FSL, 160' FWL, Sec.36, TllN, RgE, UM ~kCC.,~ll¢:,h!Si Kuparuk River Unit At Top Producing Interval ~ ¥~[qi.Fi~-~ I 10. Well Number 1346' FSL, 1301' FWL, Sec.36, TllN, R9E, UM iSurf. ~,.~I 2E-10 At Total Depth i ~'' id... ~: _ j 1 1. Field and Pool 1356' FSL, 1326' FWL, Sec.36, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 142' RKBI ADL 25658 ALI( 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 1 2/18/84 1 2/28/84 1 2/29/84I N/A feet MSLI N/A 17. Total Depth (M D+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6660'MD,6406'TVD 6526'MD,6272'TVD YES ~X NO []I N/A feet MD 1470' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL/Cal, Gyro (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" 1250# Pol ese1; 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 710 sx Permafrost E & 60 ~x Permafrost c 7" 26.0# J-55 Surf 6610' 8-1/2" 360 Sx Class G 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) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT~& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Description. REcEiVED FEB 0 $1985 Alaska 0il & Bas Cons. commission Anchorage- Form 10-407 GRU3/WC69 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate . : NAME Include interval tested, pressure data, all fluids recovered and gravil~, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6263' 6009' N/A · Base Upper Sand 6269' 6015' Top Lower Sand 6287' 6033' , Base Lower Sand 6397.' 6143' : 31. LIST OF ATTACHMENTS ~nr~ 19e.~ri?-~nn~ Oyrn_~r. nrir..q,,rv~y (? r~n,n~_~) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~0_ 0~ ~~ Tide Associate Engineer Date ~'s' ~' 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 s~ch 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 2E-lO CORE DESCRIPTION Core #1 6250 - 6263 Cut 13', Rec. 12.7' Shale and sandstone. Core #2 6263 - 6272 . Cut 9', Rec. 8.7' Sandstone and interbedded siltStone and claystone. Core #3 6272 - 6287 . Cut 15', Rec. 11.5' Interbedded siltstone and claystone. Core #4 6287 - 6346 . Cut 59', Rec. 60.3' Sandstone with interbedded siltstone. Core #5 6346 - 6398 . Cut 52', Rec. 40' Sandstone and interbedded siltstone. Core #6 6398 - 6447 Cut 49' Rec. 49 2' Interbedded siltstone and mudstone. GRU3/CDOI'tw RECEIVED FEB 0 8 I B5 Alaska Oil & Gas Cons. commission Anchorage r~ ARCO Oil and Gas Company Well History- Initial Report- Daily Inst~u¢tiofls: Prepare and submit the "lnlt~i RN~rt" on the first Wednesday after a well is spudded or workover operations are started. Dally wor~ prior to sp<~ddlng ~hould be summarized on the form giving inclusive dates only. DlatHct Alaska Field Kuparuk River AuIh. or W.O. no. AFE 203947 ICounty, parish or borough North Slope Borough Lea~e or Unit Tm, ADL 25658 Drill, C0mp]ete & Perforate JState Alaska IWell no. 2E-10 Doyon 9 API 50-029-21246 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 12/19/84 12/20/84 12/21/84 12/22/84 thru 12/26/84 12/18/84 I"°ur Complete record for each day reported 1200 hrs ARCO W.I. Prior status if a W.O. 56.24% 16" @ 115' 2425', (2310'), DD Wt. 9.4, PV 23, YP 29, PH 8, Sol 6 Accept rig @ 0830 hrs, 12/18/84. NU 20" diverter sys. Spud well @ 1200 hrs.~ Drl 12¼" hole to 2200' CBU, POH. RIH, DD to 2425'. IZltgl/~- ' 481', .2°, N27.9E, 481TVD, .67 VS, .74, .39 991' .8°, S29.1E, 990.98 TVD, 4.73 VS, .79, 4.84 1522:, 1.2°, S13.2E, 1521.90 TVD, 4.14 VS, - 4.84, + 8.18 1986', 2.1°, N82.2E, 1985.71TVD, 10.43 VS, -15.42, +19.19 2281', 4.4°, N67.9E, 2280.24 TVD, 26.90 VS, -11.23, +35.38 16" @ 115' 3330', (905'), Prep to rn 9-5/8" Wt. 9.8, PV 28, YP 41, PH 8, WL --, Sol 12 DD, drl & surv to 3330', short trip to 1300', C&C, POH. RU to rn 9-5/8" csg. 2404', 8.3°, N60.2E, 2402.49 TVD, 40.50 VS, - 5.37, + 47.66 2819', 21°. N62.5E, 2804.06 TVD, 142.39 VS, + 44.48, +136.85 3105'' 25.8°, N60.2E, 3066.68 TVD, 254.31VS, + 98.13, +236.44 3290', 28°, N61.5E, 3231.66 TVD, 337.78 VS, +138.90, +309.54 9-5/8" @ 3309' 3825', (495'), Drlg Wt. 8.7, PV 4, YP 6, PH 9, WL 22, Sol 2 Rn 82 jts, 9-5/8", 36#, J-55 HF-ERW csg w/FS @ 3309', FC @ 3226'. Cmt w/710 sx PF "E" @ 12.9 ppg, followed by 660 sx PF "C" @ 15.6 ppg. Bump plug. CIP @ 1345 hrs, 12/20/84. Circ 220 sx cmt to surf w/good rtns thruout.- ND diverter sys, MU & tst BOPE; OK. PU BHA, RIH to 3221', tst csg to 1500 psi; OK. DO plugs, FC, FS + 10' new formation to 3340'. Conduct leak-off tst; did not leak off in 10 mins. Drl to 3825'. 3578', 27.8°, N63.7E, 3486.18 TVD, 472.41VS, +201.78, +427.21 - 9-5/8" @ 3309' 6395', (2490'), Coring #5 Wt. 10.1, PV 14, YP 16, PH 9, WL 5.6, Sol 13 Drl, Navi-Drl & surv to 6250', 10 std short trip, circ, POH. PU core bbl, core 6250'-6263', rec'd 12.7'. Core #2, 6263'-6271', rec'd 8'. Core #3, 6272'-6287', rec'd 11.5'. Core #4, 6287'-6315', rec'd 60'. Cutting core #5. 4338', 25.4°, N67.5E, 4181TVD, 825 VS, 350N, 747E 4943', 22.5°, N67E, 4715 TVD, 1067 VS, 442N, 968E 5319', 10.7°, N59.9E, 5074 TVD, 1177 VS, 490N, 1067E 6004', 4.4°, N54E, 5755 TVD, 1259 VS, 590N, 1134E 6220', 3.9°, N72E, 5971TVD, 1275 VS, 547N, 1148E Signature For form-preparation andj~l'latrlbutlo~ see Proceduree Manual, gectlon 10, Drilling, Pages 88 and 87. Date I Title 1/09/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wail is Plugged, Abandoned. or Sold. "Final Report" should be submilted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operalion if space is available. District Alaska North Slope Borough Fie~d Kuparuk River ADL 25658 JAccounting cost center code State Alaska IWell no. 2E-10 I County or Parish I Lease or Unit Auth. or W.O. no. ITitle AFE 203947 I Dril]~ Complete & Perforate Doyon #9 AP1 50-029-21246 Operator I A.R.Co. W.I. ARCO Alaska, Inc. J 56.24% IDate 12/18/84 Complete record for each day reported Spudded or W,O. begun Spudded Date and deplh as of 8:00 a.m. 12/27/84 12/28/84 12/31/84 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. 1200 hrs 9-5/8" @ 3309' 6423', (28'), Coring #6 Wt. 10.1, PV 15, YP 16, PH 9, WL 6.2, Sol 12 Co~#5, 6346'-6398', rec'd 40'. Ten hrs dn time f/rig repairs. Cut core #6, 6398'-6423'. 9-5/8" @ 3309' 6660', (237'), Logging Wt. 10.2, PV 13, YP 13, PH 9.5, WL 5.6, Sol 12 Cut core #6 to 6447', rec'd 49'. Tst BOPE; OK. to 6270', rm to 6447', drl to 6660', CBU, POH. logging operations. 6620', 4°, N62.5E Chg BHA, RIH RU Schl, begin 7" @ 6610' 6526' PBTD, RR 10.1 Brine Rn DIL/SFL/GR/SP f/6652'-3306', rn FDC/CNL/CAL f/6623'-6100", RD Schl. RIH to 6510', rm to 6660', C&C f/csg, POH. Chg rams to 7", tst doors. Rn 165 its, 7", 26#, J-55 HF ERW butt csg w/FSi@ 6610', FC @ 652~. M&P 360 sx C1 "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ~/249 bbls, 10.2 ppg brine. Bump plug. CIP @ 5:30 a.m., 12/29/84. Tst csg to 3000 psi. ND BOPE, instl pack-off &tst same. RR @ 1030 hrs, 12/29/84. Old TO New TD Released rig Date 1030 hrs Classifications (oil, gas, etc.) Oil PB Depth 12/29/84 IK nd of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 6526' PBTD Rotary 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. W~.~a~tef~'~'~[~t~F ~- Gravity Allowable Effective date ~ ~''-'~'~ ~'~D .... acted The above is correct Signature [Date ~-~,~f~, (~/~0 ITM lvZ ', lac, ,.... Drilling Superintendent For ~is. , form preparation an distribution see Procedures Manual, Sec.on 10. Drilling, Pages 86 and 87. $ UB-$ URFA CE DIRECTIONAL SURVEY F-~ UIDANCE [~ONTINUOUS I-fi COl Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2E-10 (780"FSU~ 160' FWL~ S36~ TllN~ R9E~ UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 70016 Logged By: PEPPEL RECEIVED FEB 0 8 I~t85 Aiaslm Oil & Gas Cons. Commission Anchorage Date 30-JAN-1985 Computed By: STEVE.NS GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. 2E-lO ". KUPARUK NORTH SLOPEs ALASKA ~NGINEER: ,PEPPEL METHODS OF COMPUTATION TOOL .LOCATION: TANG2NTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLAT:ON: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 65 DEG g MIN £.AST ARCO ALASKA~ INC. 2E-10 KUPARUK NORTH SLOPEr ALASKA COMPUTATION DATE: £9-JAN-85 DATE OF SURVEY: 15-JAN-85 KELLY 5USHING ELEVATION: 1~2.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN ZOO FEET DF MEASURED DEPT~ TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DE¥zATION AZIMUTH DEPTH DEPTH OEPT.:.~ ,DE6,,:,:HIN D~G H[N 0.00 0.00-142 O'L,~"O,' 0 N 0 0 E 100.00 100.00 -42:00'".~?'0', [2 N 69 1½ W ZO0.O0 200.00 58.00:* 0 ,11 N 20 la ~ 300.00 300.00 158.00;'! O' 6 N 13 19 E 4oo. oo 400.00 258.00:". 0. 8 s 86 43 E 500.00 500.00 358.00' .'0"':'[2 S 6~ 48 E 600.00 600.00 458.00 0 17 S 56 47 ~ 700.00 700.00 $58.00 '; 0 [9 S 55 3 E 800.00 799.99 657.99 0 23 S 51 45 E 900.00 899.99 757.99 0 28 S e5 13 E 1000.00 9'99.98 857.98 1100,.00 109,9.97 957.97 1200.00 1199.9~ 1057.94 1300.00 1299.92 1157.92 1~00.00 1399.89 I257.89 1500.00 1~99.87 1357.87 1600.00 1599.86 1457.86 1700.00 1699.83 1557.83 1800.00 1799.76 1657.76 1900.00 1899.70 1757.70 ZO00.O0 1999.68 lS57.64 1 2100.00 2099.59 1957.59 2200.0'0 2199.52 2057.52 2 6 2300.0.0 2299.36 2157.36 2400.00 23'98.77 2156.77 7 35 2500.00 24'37.42 2355.42 10 53 2600.00 2595.31 2453.31 13 2700.00 2691.95 2549.95 16 2800.00 Z786.81 264¢.81 20 17 2900.00 2879.43 2737.¢3 23 33 S 85 2~ E N ab 43 E N 88 7 E N 68 13 E N 57 25 E N 62 27 E N 59 I E N 60 43 E N 50 5t E N 61 45 E 3000.00 29'70.8& 28Z8.84 24 1[ 3100o00. 3061.49 2919.~9 25 47 3200.00 3151.07 3009.07 27 20 3300.00 3,239.73 3097.73 27 27 3400.00 3328.19 3186.19 28 ~ 3500.00 3416.38 377~.38 27 57 3600°00 3504.73 3362.73 27 54 3'700.00 3593.11 3~51.11 27 52 3800'00 3681.67 3539.67 2*7 ~2 3900.00 37'70.40 3628.40 27 1~, N 60 N 59 t E N 60 55 E N 62 11 E N 62. 1:9 E hi 6£ 36 E N 62 42 E N 62 5,~ E N 63 21 E 'N 63 ~ E VERTICAL DOGLEG RECTANGULAR C90ROtNATES hORZZ.-OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET O.O0 0.00 0.00 N 0.00 -0.12 0.4/, 0.0~ S 0.11 -0.21 0.16 0.18 N 0.32 -0.1'7 0.2.2 0.45, N 0.41 -0.01 0.12 0.53 N 0.25 0.21 0.08 0.4/* N O.OZ 0./.6 0.10 0.22 N 0.4I 0.71 0.21 0.07 S 0.81 1.00 0.13 0./.3 S 1.30 1.30 0.30 0.91 S 1.86 1.,66 0.43 1.8~ S 2.87 1.29 0.31 3.42 S 3.02 0.77 0.08 5.57 S 3./*/* 0.16 0.2.5 7.83 S 3.8l -0.08 0.18 9.93 S ~.5/, -0.09 O.~b 11.83 S 5.~1 0.29 0.55 13.35 S 6.53 1.~7 0.61 1~.77 ~ ~.50 ~.80 0.32 15.95 S ~1.62 6.65 0.13 16.83 S 15.18 9.60 0,60 , 17.3it 12.. 63 0.15 17.33 S 22.00 15.72. 1.27 17.25'5 25..57 21.22. 3.10 15.83 S 30.7~ 31.86 48.10 1.90 2.8t~ S ~4.40 68./,$ 9~.00 3.38 10.19 N 94.29 11~.½6 3.80 163.05 103.50 1.59 245.49 1.03, i89.75 2.15 335.92 0 382.51 0.40 /,29.59 0.76 475.~1 0.51 523.15 0.7'7 569.57 615.67 ,', 3.08 S 53 ll E 4.56 S 41 26 E 6.5.5 S 31 ~,1 E 8.,71 S 26 0 E 10.92 S 2~ 32 ,E 13.01 S 2.~ 34 E lz, o86 S 26 ' ~ E 17.0e S £9 54 E' 19.73 S 3.5 4 E 12.67 S 42 2 E 35.70 N 121.77 E 126.,:,89 N 73 3'9 53.72 N 154.8,~ E ,1~:3.,.90 N TO 51 E 25.52 S 47 4' E 28.01 S 5I. 45 E 30.62 S 55 ,~7 E 34.61 S 67. 4,6 E 41.5'9 S 7,~" 58 E 54.,',8 S 86 ~8 'E 72.50 N 8'~ 15 ~ 96. ~Z N 77 5~ 73.13 N 190.,I. 1 E 203.98 N 68 59' E 94.76 N lZ6.67 E 245.6.8 N 67 18 El 116.98 N 155.15 E 289.81 N 66 II 138.97 N 305.8~ E 33'5.93 N 65 33 E' 160.61 N 3~7.16 E 382.5I N 65 182.40 N 388.9~ E' 429.59 ,N 6~ 5l' E. 20~.92 N ~30.58 E ~76.,~2 N 6~ 39 E 225,.25 ~ .~'7Z.20 E 523.17 N 6¢ 29: E Z~6.Z7 N 513.62 E 569.60 N Z~6.79 N 55¢.9Z E 615.72 N 6e 19 E ARCO ALASKA, INC. 2E-10 KUPARUK N~RTH SLOPE, ALASRA CgMPUTATI2N DATE: Zg-JAN-85 P AG,.. DATE OF SURVEY: 15-JAN-85 KELLY 5USHING ELEVATION: ENGINEER: PEPPEL INTERPDLATED VALUES FDR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL. VERTICAL DEVIATION ALIMUTH DEPTH DEPTH DEPTH DEG'MIN DEG MiN 4000.00 3859.45 3717 4~?:'~26 4100.00 3948.98 3806~98'.,126 12 4Z00.00 ~038.89 3896.89. 25 53 4300000 ~129.01 3987.01 15 35 4400°00 ~219.30 4077.30 25 21. 4500.00 6309.77 4167.77 25 19 4600.00 ~400.13 4258.13 ZS 7 4700.00 ½491.02 4349.02 23 53 4800.00 ~583.12 4641.12 22 7 ~900.00 ~675.66 4533.66 22 37 5000.00 ½767.99 4625.'99 ZZ 5100.00 ~861.22 4719.22 19 25 520'0.00 ~956.~3 4814.43 15 50 S300.00 5053.35 4911.35 12 52 5~00.00 5151.36 5009°36 10 0 5500.00 5250.oa 5108.08 8 5600.00 53~9.11 5207.11 7 5700.00 5~48.39 5306.39 6 5800°00 5587.82 5405.82 5 ~6 5900.00 5647.39 5505.39 ~ 53 2.3 47 2 $5 5O 50 50 6000.00 5767.05 5605.05 6100.00 5846.80 5704.80 6200.00 5946.58 580~.58 6300°00 60~6.3.4 5~0~.34 6400.00 6146.10 6006.10 6500.00 6245.88 6103.88 6600.00 5345.65 6103.65 6660.00 6405.51 6263.51 142.00 VERT:CAL DOGLEG RECTANGULAR C~ORDINATES HOR~Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST., J~ZIMUTH F~.ET DE$/100 N 63 37 E 661.16 0.59 N 63 58 E 705° 71 0.5o N 6~, 31 E 749.~6 0.53 N 65 7 E 79Z.80 0.53 N 55 ~3 E ;:335.79 0.26 N 66 25 E 878.37 0.65 N 66 25 E 921.20 0.97 N 66 $ E 962.89 2.08 N 65 53 E 1001.64 0.8t N 66 19 E 1039.72 0.73 N 66 51 E 1078oll N 65 18 E 111~,.21 N 63 13 ~. 114.6.,7~ N 58 11 E 1169.29 N ~9 21 E 1188.66 N 46 5I E 1203.91 N ~5 49 E 1117.05 N ~6 37 E 1228.42 N 49 3 E 1238.60 N 52 I ~ 1247.60 N 53 26 E 1255.53 N 57 ~ E 1262.48 hi 65 21 E 1262.07 N 69 10 E 1275.96 N 69 30 E 1182.90 N 68 ,39 E 1289.61 N 68 39 E 1296.31 N 68 39 E 1300.33 0.81 2.83 3.85 2.33 2.02 ! .31 1.0~ 0.7~ O. 75 1.20 · 0.31 0.86 0.70 0.98 0.00 0.00 0. O0 FE~ T FEET F E E 1', ',:-i,,.,..iJj,& 315.6l N 675.11 E 749~$3~:;':,~ 6~~' 15 E 361.93 N 753.~3 E 835.8~'~. ~ 6~ gO E 379.17 N 792.3~ E 878.~2 N 6~ 25 E 396.25 ~ 831.6~ E 921.28 N ~6'& 31 E ~Iz.ga ~ 869.86 E 962.92 N 6~ 36 · 28.79 N 905.~7 E 1001.86 N 6~ 39 4~&.16 N 9~0.09 E 1039.73 N 6~ ~59.~1 N 975.33 ~ 1078.12 N 6~ ~73.87 N 100~.~3 E 111~.22 N 6~ ~9 E' ~aT.0a N 1035.97 E 1I~.75 N 6~ ~9 E · 9&.g& N 1057.51 E 1Ib9.30 N 510.~3 N 1073.53 E 1188.70 N 6~ 3~ E 521.1~ N 1085.35 E 120~.00 N 6~ ZO E 530.7~ N 1095.39 E 1217.20 N 6~ 8 E 539.0~ N 110~.06 E 1228.62 N 63 58 E 5~6.17 N 11~1.97 E 1238.86 N 63 50 E 552.09 N 1119.I5 E 12~7.92 N 63 ~a E ',, ~57.03,N 11Z5.60 E 1255.,85 N 63 ~0 E 5b1.12 N 1131.35 .E 12~2.86 N 63 5&a.~2 N 1137.09 g 1269.47 N 63 36 E 566.90 N 11~3.53 E 12'16.3~ N 63 37 E 569.Za* N 1150.08 E 1283.27 N 63 571.77 N 1156.33 E 1289.97 N 63 ~I E 576.21 N 115'2.5~ E 1296.65 N 63 575.68 N 1166.33 ~ 1300.67 N 63 43 . COMPUTATION DATE: 29-JAN-85 PAGE ARCO ALASKAt INC. 2E-10 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 15-J~N-85 KELLY ~USH[N~ ELEVATION: ENGINEER: P EPP E/,.. 1~2.0~ FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF HEASURED OEPT TRUE SU~-SEA CgURSE, EASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG'~ZN D~G 0.00 0.00 -14Z.00 0 0 1000.00 999.98 857.98 '. 0 46 2000.00 1999.64 1857.66 1 54 3000.00 zg70.8~ 2828.a* 2* 11 4000.00 3859.45 3717.,5 26 *S 5000.00 ~767.99 ~625o9g, 22 22 6000°00 5747.05 5605.05 4 23 6660°00 6405.51 6263.51 3 50 VERTICAL DO:$LEG RECTANGULAR C30RDINATES HORIZ.. DEPARTURE SECT.T. QN SEVERITY NORTH/SOUTH EAST/~EST DISTo. AZIMUTH FEET DEG.' 10~ FEET FEET FEET,. D. EG HIN 0.4.3 0.60 1.59 0.59 0.82. 1 0.00 73.13 N 190.4Z e 203.98 N 68 ~9' E 286.93 ~ 595.71 E 661~2Z N 6~ 16 E 459.~1 N 975.33 E I078~12 N 6~ ~6 E 557.03 N 1125.60 E 1255.89 57S.68 N 1166.33 E 1300.67 ARCO ALASKAt INC. ZE-iO KUPARUK NORTH SLOPE, ALASKA CDHPUTATIQN DATE.: 29-JAN-85 PAGE DATE OF SURVEY: 15-jAN-85 KELLY ~USH~NG E.L~VATION: 162,00 ENGINE.ER: PEPPEL INTERPOLATED VALUgS FOR EVEN 100 FEFT OF SUS-SEA DEPTH TRUE SUB-SEA COURSE: IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HZN DEG H:N 0.00 0.00 -162.00.~:':!?0 ~.0 hi 0 0 E 42.00 42.00 -100.00'-'-~,0-5 S 22 47 E · 162o00 162.00 0.00: ' 0 10 N 66 19 W 242.00 2~2.00 100.00 .. 0 11 N 22 2~ ~ 342.00 362.00 200.00. 0, 5 N 52 59 e · 42.00 662.00 300.00 09 S 70 2~ E 562.00 562.00 400.00 .... 0'16 $ 60 5~ E 642.00 6~2.00 500.00 ' 0 16 $ 53 18 6 742.00 7~2.00 600.00 0 20 $ 53 3a E &42..01 842.00 700.00 0 24 S 49 3~ E 942.01 962.00 SO0.O0 1042.02 1042.00 900.00 I142.06 1162.00 1000.00 1262.07 1262.00 1100.00 1342.09 1362.00 1200.00 1~62.12 1662.00 1300.00 1~42.13 15~2.00 1600.00 1662.15 1662.00 1500.00 1:742.19 1762.00 1600.00 1862o26 18~2.00 1700.00 0 37 S 33 5~ E 0 55 S 20 69 E I 15 S 12 16 E I la S 8 '7 E I 16 $ 18 13 E I 16 S 23 59 E I ,~ S 35 15 E i 19 $ ~0 35 ~ I 53 S 68 6?.. i 2. 6 S '75 18 E 2 4 i 5.3 1962.33 1962.00 1800.00 2042.38 2062.00 1900.00 2142.6~ 2162.00 2000.00. 1 56 2242.51 22~2.00 2100.00 2 57 2342.83 2362.00 2200.00 5 5'7 2663.69 2462.00 2300.00 9 12 2565.65 2562.00 2~00.00 11 37 2668.11 26~2.00 2500.00 2752.~9 2762.00 2600.00 18 27 2859.28 2862.00 2700.00 22 32 VERTICAL DOGLE:G RECTANGULAR COORDiNATeS HORiZo DEPARTURE , SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FE:ET DEG/ZO0 FEET F:E6T 0.00 0.00 0.00 N 0.00 E 0 ~':' :'~.,:~:~*.iI~,', 0 0 E 0.00 0.37 0.00 hi 0.00 E O";~O,,,::~':,::'N','i'go 0 E -0.20 0.3~ 0.33 hi 0.38 ,, 0..50'"N 4~ ~7 W -0.12. 0.22. 0.52 N 0.37 W 0o63~ N .35 2,.6 W 0.07 0.11 0.51 N 0.16 W 0.S) hi 16 56 W 0.31 0.10 0.36 N 0.17 0.57 0.12. 0.11 N O.Sa E 0.59' N 79 16 f 0.83 0.20 0.21 S 1.01 E 1.03 S 75 20.E. 1.13 0.06 0o62 S 1.56 E 1.66 S 68 I E 2968,.61 2962.00 2800.00 24 0 3078.36 3062.00 2900.00 25 30 3189.80 3162.00 3000.00 27 7 33:02.55 3242.00 3100.00 27 27 3615.66 3342.00 3200.00 28 5 3528.97 36~2.00 3300.00 27 56 3642.15 3542.00 3400.00 27 49 3755°22 3662.00 3500.00 27 36 3868.06 37~Z.00 3600.00 27 19 3980..~6 38~2.00 3700.00 26 5~ 1.,~0 0.5,:~ 1.21 S 2.11 ~ 1.~.6 0.63 2.~1 S 2.72 E 1.12 0.36 6.27 S 3.22 E 0.~,7 0.31 6.56 S 3.57 E 0.02 0.11 8.73 S 4.09 E -0.12 0.54 .L0.79 S 4.89 E -0.01 0.57 12.49 S 5.82 E 0.63 0.71 13.96 S 7.19 E 2.36 0.69 15.31 $ 9.7~. E ~.96 ,0.25 16.36 S /3.09 i~' S 80 11 E 7.94 0.67 N 89 20 E 10.86 0.2,.9 N 88 2~, E 13.93 0.27 N 77 50 E 17.14 3.25 N 63 25 E 25.20 2.,82 N 60 63 ,E 3f3.19 4.38 N 60 10 ~ 56.96 N 59 29 6 80.01 3.58 NOO 22 ~ 10'9.73 3.86 N ~1 28 ~ 1~7.05 3.73 N 61 ~ ~ 190.&6 1.06 N 58 52 E 235.15 1.72 N ~0 65 E ~85.11 2.28 N 62 la E 337-09 0.69 N 62 22 E 389.85 0.56 N 62 40 E 663.11 0.57 N 62 52 ~ e96o08 0.29 N 63 7 ~ 5~8.80 0.26 N 63 37 ~ 601.03 0.39 N 63 39 E 652.33 0.77 2..46 S 60 7 E. 3.,63 S 46 2& 5.35 S 37 2 E 7.½5 S 28 36 E 9.66 S 25 6 E 11.8~ S g~ 23 E 13.78 ,S 2~ 59 E' 15.,,70 S 2Z 16 E' ~8.,15 S 32 27 E Z0.95 S 3~ 17.12. S 16.73 E 23.9~, S ~.,~ 20 E 17.42 S ].0.09 E 26.59 S 4.J 6 E' 17.27 S 23.61 ~ 2E,.O~ .S 53 35 E 17.0~ S 27.17 E 32.07 S 57 1~.21 S ,3~.42 E 37.23 S 67 53 E 7.~9 S 45.61 E ~6.22 S 80 ~0 E 1.37 N 62.19 E 62.21 N 88 ~4 E 13.23 N 82.10 E 83.16 N 80 50 27.92 N 108.0~ E 111.5'9 N 75 66.83 N 179.1'7 E 19.1.23 N ~":~ 32 E 89.91 N 218.63 E 236.60 N 67 38 E' 116.7.I N 2:~.1.09 E 285.18' N 66' 16 E 139.52 N 306.~ a 337.1'1 N 65, 33 E' 164.03 N 353.66 E 389.85 N 65 7 E 188.61 N 400.97 E '~3.11 N 64 ~8 E 212.92 N ~48.08 a 496.,0~ N 6~ 35 E 236.90 ~ 495.01 E 548.83 N 6~ 2~' E 260.30 N 5~1.7'~ E 601.07 .N 6~ 20' E' 283.01 N 587.80 ~ 652.39 N 6~ I7 E COMPUTATION DATE: 29-JAN-85 PA~E 5 ARCO ALASKA, INC. ZE-IO KUPARUK NORTH SLOPE, ALASKA TRUE SUa-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG'MIN DEG MIN 4092.Z2 39½2.00 3aoo.o0- 4Z03.~5 ~0~2.0o 4314o~0 4142.0o 44ZS.1Z ~Z42.00 4100.00 25 15 4535.67 ~34Z.00 4ZOO.O0 25 25 4646.17 ~4*Z.O0 4300.00 24 4.3 4755.5Z ~5,g.O0 4¢00.00 22 50 4563.57 ½64Z.00 4500.00 22 19 4971.87 ~742.00 4600.00 2g 30 5079.58 ~842.00 4700.00 ZO 8 518¢.96 494Z.00 4800°00 16 27 5288.35 5O~Z.O0 4900.00 13 15 5390.69 51~2.00 5491.83 5242.00 5100.00 5592.83 5342.00 5200.00 5693.57 5442.00 5300.00 5794.15 5542.00 5894.60 56~2.00 5500°00 5994.94 5742.00 5600.00 6095.19 58~2.00 5700.00 6195.~! 5942.00 5800.00 6295..65 &042.00 5900.00 6395.89 6142.00 6000.00 6496.12 6242.00 6/00.00 '6596o34 &3~2.00 6ZO0.O0 6660.00 6405.51 6263.51 DAT~ OF ~URVEY: 15-JAN-85 KELLY 6USH[NG ELeVATiON: .14Z.O0 FT, ENGINEER: PEPPEC INTERPOLATED VALUES FOR EVEN 10~ FEET OF SUS-SEA DEPTH VERTICAL ~GLEG RECTANGULAR C~RDINATES HORIZ. O'EPARTUR~ SECTION SEVgRITY NORTH/SOUTH EAST/~EST DISTo..;~ AZIMUTH FEET DEG/IO0 N 63 55 E 702.27 N 64 31 E 750.97 N 65 13 E 799.03 N 65 53 E a46.54 N 66 29 ~ aS3.Ea N 66 27 ~- 940.66 N 66 3 E 98~.a7 N 66 3 E 1025.79 N 66 45 ~ 106'7.35 N 65 49 E 1107.31 N 63 36 E 1140.,~9 N 59 0 E 1166.66 N 50 11 E 1187.05 N 46 50 E 1202.74 N 45 46 E 1216.18 N .~6 39 E 1227.71 N 49 5 E 1238.03 N 51 49 E 12~1.15 N 56 ~ E 1262.16 8 43 7 2'7 5 48 4 26 3 47 3 47 ,~ 3 3 57 3 50 3 50 3 5O N .6~ 3~ E 1268.77 N 69 ~ E 1275.6.5 N 69 46 E 1282.62 N 68 39 E 1289.35 N 68 39 E 1296.07 N 08 3-3 E 1300.33 0.46 0.68 0.74 0.30 0.8Z 1.6. 0.77 0.37 3.96 3.98 3.50 3.20 1.90 1.19 0.44 0.98 1.06 0.42 1.0~, 0.76 0.93 0.00 0.00 0.00 FEET FEET FEET' ','"',"" 'DE G ~IN ,:~ -'~:~, ,~i' .- .~ . ~..-~'-. '.~,~,.,;' ,.~ 305.1]. hi 632.62 E 702.,~-':-"#~'6~ ].5 E 32.6.27 N 676.47 '.., ~,. ... 366.34 N 7~3.Z3 E 846.,6~:':~'!-',:N'64 2't E 385.29 N 806.41 E 893..7.Z'""~'N:'64 Z7 E 404.04 N a~9.50 E 940.69..N 6~ 33 E 421.86 N a~9.97 E 984..~9 438. Sa, 47~.0Z N 1002.1~ E 1107.3Z N 64 /,9 E 485.16 N 1032.~7 E 11,:,,0.50 N 64 a9 E 497.57 N 1055.25 E 1.166.67 N 6~* ~5 E' 509.35 N 107:~.25 E 11~7.,09 N 6~ 35 E 520.3,~ N 108~.,~ E ~Z02-83 N 6'~ Z2 E 530.0~ N ~09~.73 E 1Z~6.3Z N 6'~ 9 E 538.5g N ~03.52 E 1ZZ7.9[ N 63 ~9 E 5~5.78 N [~1[.53 E ~23a.29 N ~3 50 E 551.81 556.79 N 1125..2~ e ~Z~5.50 N 63 aO E 550.95 N 115~.09 E ~26Z.,5~ N 63 37 E 5 ha.29', 5~6.79 N 569.19 571.67 N 1I~6.09 E 1289.71 N 63 ~1 E 57~.12 N 1152.35 E 1296.~1 N 63 ~2 E 575.68 N 1166.33 E 1300.67 · N 63 43 E ARCO ALASKA, [NC. 2E-10 KUPARUK NORTH SLOPEr ALASKA NARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND PBTO TOTAC DEPTH COMPUTATION DAT~: £~-JAN-~5 INTERPOLATED VALUES FOR CHOSEN !',~", :':~,' MEASURE'3 DEPTH "",.. :':'~:]:' BELQ~ KB FROM KB 6263.00 6009.~3 6269.00 6015.~2 6287.00 6033.37 6397.00 61~3.1! 6526.00 6271o82 6660.00 6~0~o$1 ORIGIN= TVD PAGE 5' DATE DF SURVEY: 15-JAN-,8J KELLY 8USHING ELEVATiCN:' 1~2o0D FT , ENGINEER: P~PPEL SURFACE LCICAT]: ON CTA~ SUB-SEA NORT SO UTJ~.~'~ 6263.51 575.68 COMPUTATI3N DATE: 29-JAN-35 PAGE 7 ARCO ALASKAt INC. 2E-lO KUPARUK NORTH SLOPEr ALASKA DATE OF SURVEY: 15-JAN-85 KELLY &USHING ELEVATION: ENG[N&ER: P~PPEL 14,2.00 F! - MARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND PBTD TOTAL DEPTH NEASURED DEPTH SELOW KB FROM KB 6263.00 6009.~3 6269.00 6015o4,Z 6287.00 6033°57 6397.00 6143.1! 6526.00 6271.B2 6660.00 6405.51 SURFACE LOCATION ORIGIN=' 780" FSL, 160' FWL, SEC 36,'.'TllN~ RgE, UM TVD RECTANGULAR '~.I~IiATES $ U B- S E A NO R T H/S O U T ~':'.."~::."~ ~"'~'E'~'$T~ ~ E ~ T 5857.4,3 5873.4,2. 5891.3'? 6001.11 ~12go82 6263.51 FINAL WELL LOCATION AT TO: TRUE SU6-SEA MEASURED VERTICAL VERTICAL DEPTH DEP[H DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 6660. O0 64,05.51 6263.51 1300.67 N 63 43 ~ SCHLUMBERGER ARCO ALASKA, INC. 2E- 10 KUPARUK NORTH SLOPE, ALASKA JANUARY 1S, !98S TVW PLOT FROM OCT DATA ,JOB REFERENCE 210 WELL: 2E21g '- SURFACE LOCATION' 7BO' FSL, 160' FWL, S3ra, Tl1~!, RgE, tim VERTICAL PROJECTION -~RO0 -~000 - ! RO0 - 1000 -~00 0 0 SO0 ! O00 : : : : ~ -' ~'~ ~ : i i ~ i / -:, ii ~ .:, i i i i i ~ ~ ~ ! i ~ !iii i i :, ~ i ~ i :, i ~ i i i ,~ i . --~~-'-W.' i i iii ii-?" i!~:, Ii i~: ~i i'i ii i .-'~'~-- -"~-'-r~.'~-r-.-'?--?-r-?"-~',q--:'-T"T-~"-'r"r"~"?~"'.:'"'..'"'T"? ....... ~"/"?'",'"}'":'"r"T'"7't -T'.. i ~. i [ i i fi ii i iT~ i i ii i:}i ii ii T i 'i:~.:.'-' ."T-.] ..~{'-i-l'-~'-_ "'i"Tei~i~T-?'?'f"i ...... ??-~"T"r'r".?-'".r"-'.:'"~'"~'~"T"?i"T"~'" --F~. !,~ ! ! ! ~ ! ! ! ! ! ! ! ! ! ! ! !4-.~ ! } ~:! ii: ~ ~ ~-~:-4-?':--4.-.~--~4'-;44-..P-~-;-.-;--4-.-;.--;--.;--~--;-~--.~-4.-.!..4..4.-.~..,; ...... ;...;_.i...;...[..:...;.....Z..L. 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'--','-,-',","'-,"',","',"','",'",'",'"'" ~]" 7"~ '~", '~"'~'"~'"~'"? 7"? T' '~'"~-'7~'"7'?'"?"'7"~" T" T' 't "~" 7'T': "i'"~'",' 'Z'T [ I~OD NE PROJECTION ON VERTICRL PLANE OF RZIMUTH 6S SCALEO IN VERTICAL DEPTHS HORIZ SCRLE = I/S00 [N/FT ~TH lO00 WbL, L: ~i--llJ SURFACE LOCATION' 780' FSL, 160' REF 2i0 SCRLE = i/BDD [N/FT FWL, S36, T11N, RgE, UM HORIZONTAL PROJECTION SO0 :::::::::::::::::::::::::::::::: H--.H...i.-i.-i--!.-F ~...:..4...~...~,..~,..¢ ..... ~.--~.,.~...~.4...~...~...~...~ .... ~'"~"-~-'-~"'!--'+-"-F-'~-"~"' : : g.~._L.~...~_j~ : ~ ~ ~ ~ : ~ L ' ..... ::::::::i:::...i...~...~._i...,.i...i...L;.__..~...F~...~...!...,.t...~...~ .... -=:TI T ITT'..' ~ ........ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:~ _ ~: .._~...~__~: ...~...~._..=...:_~... '"r"?"T'T '~'"?"' ? "~ ~'~' ..................... '"'"':'" f"f":.-:"i"!'"f"~'"! i ......... ' : : : : , : ....... ; : : : "'?'"T'".:'"?'"T"T'"T'"?'"? '-'?..ff--.~ '--r'-~.---~'"-.'"~--'~'- -I~00 ......... ~-~ ~ ~4. .......................... "'":: '~ ~ ~ -.-~---~...~.---L.l---~.-.~---?-..-i ....... ~...~..:..L.~...!....;. i-~ ...... :.--.~ ...... ?-.~ ....... ~.-+.+. i~ffflf': . ................. -2000 .4.-~-...L-4..J,..--:.-.-L..~.-.L- ~ ~ ~ [ ! ~ ~ ~ ~ ........ - ........ ......... : , : : : : : : : ~ ~ -.' ~ I :' ! .: ~ ......... · -i-FH-'-FH--!--i-- : S~TH -~000 -2500 -2000 - 1 ~OO - 1000 NEST Suggeste.:~form to be insertcd in each "Ac..~re" well folder to d:eck for timely cc~liance wi~] our' regulations. · operator, Wel~l N~ne and Number Reports and Materials to be received by: Required Date Received Remarks · · Ccmpletion Report Yes ~ '~68 '-~~'' ~c~ ~----- _.. -~. Well Hi ~ .." Yes · Core Chips '-:->" (./~,. Inclina~on S~ey j/~ Dire~ional ~ey ~ := ~/ ~ _ Drill 8t~ ~es~ Re~s ~~ ,/ ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 14, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - December, 1984 Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' DS 6-11 (Workover) 2C-15 1Q-12 DS 11-12 2C-16 2W-9 DS 11-15 2D-13 2W-10 DS 15-16 (Workover) 2E-10 2W-11 DS 15-17 (Workover) 2E-11 2W-12 DS 17-13 2E-12 CPF-1A DS 17-14 2E-13 WSP-3 2X-9 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L68 Enclosures RECEIVED JAN'I~]~ (~as Cons. Commlsslea Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA O"~AN D GAS CONSERVATION corv..~lSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~J × Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-230 3. Address 8. APl Number P. O. Box 100360, Anchorage, Al( 99510 50- 029-21246 780' UM 4. Location of Well atsurface FSL, 160' FWL, Sec.36, T11N, RgE, 5. Elevation in feet (indicate KB, DF, etc.) 142' RKB 6. Lease Designation and Serial No. ADL 25658 For the Month of December 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2E-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 1200 hfs, 12/18/84. Drld 12-1/4" hole to 3330'. Ran 8-1/2" hole to 6250'. Cored f/6250' - 6447'. Continued drlg 8-1/2" (12/28/84). Ran OH logs. Ran 7" csg. PBTD = 6526'. Secured well 12/29/84. 9-5/8" csg. Drld hole to 6660'TD, & RR @ 1030 hrs, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set (~ 115'. Installed w/1250# of Poleset. 9-5/8", 36.0#/ft, J-55, HF-ERW BTC csg w/FS @ 3309'. Cmtd w/490 sx PF "E" cmt & 660 sx PF "C" cmt. 7", 26.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 6610'. Cmtd w/360 sxs "G" cmt. 14. Coring resume and brief description Core #1 f/6250' - 6263'. Rec. 12.7' Core #2 f/6263' - 6271'. Rec. 8' Core #3 f/6271' - 6287'. Rec. 11-1/2' Core #4 f/6287' - 6346'. Rec. 60' Core #5 f/6346' - 6398'. Rec. 40' Core #6 f/6398.' - 6447'. Rec. 49' A detailed core description will be sub- mitted with the Well Completion Report. 15. Logs run and depth where run DIL/SFL/GR/SP f/6652' - 3306'. FDC/CNL/Cal f/6623' - 6100'. 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN 1 5 198,5 Alaska 0il & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Con this form's q INOTE--Repoeach calendar month, regardless of the status of o ations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/HERR Submit in duplicate I ARCO Alaska, Inc. Post Office "-~ 360 Anchorage, aska 99510 Telephone 907 277 5637 RETURN TO: ARCO ALASKA, INC. Date: 1/08/85 Transmittal No: ATTN: Records Cl~rl l15B Box 100360 ~horage, AK 99510 ///Transmitted herewith are the following items. f/ and return one signed copy of this transmittal. 4961 Please acknowledge receipt OH LIS TAPES Schlumberger - _ #69829 2E-13 12/03/84 Run 1 3685.5 - 8072.5 (Computed 1/03/85) #69924 2E-10 12/28/84 Run 1 3270.5 - 6665 (Computed 1/05/85) ~69853 2X-10 12/05/84 Run 1 3212.5 - 7111 (Computed 1/0~'/-~5) /cat Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Geology G. Phillips Chevron Mobil D&M Date: Sohio Phillips Oil Union NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AllanllcR~chfieldCornpany MEMORANDUM Stat6of Alaska TO: ALAS¥~& OIL AI,~ GAS CONSERVATION CObR4ISSION Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector FROM: DATE: December 28, 1984 ~'i. :/ /~., __../ FILE NO: D 1I 45 ,~/~,]~TE LE P H O N E N O: SUBaECT: W±t~es~ ~OPE Tests Sec, 36, ~11N,Agg,~, Wednesday, December 19, 1984: I departed my home at 1:50 pm for a -2j20 pm shOwup and-3~20 pm departure via Alaska Airlines, Flt. ¢57 for Deadhorse, arriving at 5:40 pm. Weather: -34°F, clear, ice fog. Th~rpday, December 20, 1984: BOPE tests on 2E-10 began at 7:45 pm and were completed at 9:0~m. BOPE inspection report is attached. Friday, December 21, 1984: Standing by on Kuparuk iQ-12o Saturday, December 22, 1984: BOPE tests on Kuparuk IQ-12 were compieted,L the subject ~-f' a separate report. Bottom plug tagged on Conoco's C-5. . . Sunday, December 23, 1984: . . . and top plug pumped, the subject of a separate report. I departed Deadhorse at 10:00 am via Alaska Airlines, Flt ¢54 arriving in Anchorage at 11:40 am and at my home at 12:10 pm. in summary, I witnessed successful BOPE tests on ARCO's Kuparuk 2E-10. Attachment 02-00IA(Rev. ~0179) O&G tt4 5/S4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~ Operator /~~,~ Location: Sec c~ T//~/R~-- M Drillin~ Contractor Location, General ~/~ Well Sign ~ General Housekeeping~Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams ~ Test Pressure Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Representative .7~,'~ ~~,~,~ -- Permit # ~~&%sing Set 8 ~S~ ft. Representative ~~ ACC~ATOR SYST~ Full Charge Pressure ~O~ psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master Remote ~/~Blinds switch cover~/~ Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure No. flanges min .-~ sec. min ~sec .' Test Results: Failures ~ Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: 7~._~'_r-_.~-' ,~~ ,,~-~ ~.'~W'~ ~~ Adjustable Chokes / Hydrauically operated choke Test Time /y~ hrs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector December 14, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2E-10 ARCO Alaska, Inc. Permit No. 84-230 Sur. Loc. 780' FSL, 160' FWL, Sec. 36, TllN, RgE, Btmhole Loc. 1320' FSL, 1320' F~, Sec. 36, 'TI1N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of-well cuttings and a mud log are not required. A continuous directional survey .is required as per 20 AAC 25. 050(b) (5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing opeorations ~7~ou may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ,truly 3-o~urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI~{ISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery ARCO Alaska, Inc. ~-'-~ Post Office b..x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 12, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2E-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2E-10, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on December 17, 1984. If you have any questions, please call me at 263-4970. Sincerely, A~~ea~ ~~~n .~g Engi ne~r JBK/HRE/tw PD/L09 Attachments / £C£1VED ARCO Alaska, Inc. is a Subs[diary of AtlanticRichfieldCompany /--'. STATE OF ALASKA ~', ALASKA ~IL AND GAS CONSERVATION CL,,vIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I-X]X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-I SINGLE ZONE [] MULTIPLE ZONE~L 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 780' FSL, 160' FWL, Sec.36, T11N, R9E, UM At top of proposed producing interval 1320' FSL, 1320' FWL, Sec.36, TllN, RgE, UM At total depth 1320' FSL, 1320' FWL, Sec.36, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 142', PAD 106' ADL 25658 ALK 2584 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 6656' ND, 6372' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2229 feet. 21 14. Distance to nearest property or lease line miles 780' (~ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 33 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program SIZE i Hole Casing i24" 16" il 2-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36.0# 26. O# CASING AND LINER Grade CouplingI Length H-40 Welc~ 80' J-55 BTC/ 3285' HF-ERW / J-55 BTC/ 6622 ' HF-ERW / SETTING DEPTH MD TOP TVD 35' 135' 35' 135' 1 I 34' I ~ 34' 10. Well number "'Cno£c~oe-' bOtTllTl]S$,ioFi 2E-10 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed E-11 well 25' (~ s..urface feet 18. Approximate spud date 12/17/84 MD BOTTOM TVD 115' I 115' 3320' 3262' 6656' I 6372' I I 2771 psig@ 80°F Surface 3181 psig@ C~172 ft. TD (TVD) QUANTITY OF CEMENT (include stage data) + 200 cf Poleset 710 sx Permafrost "E" 710 sx Permafrost "C" 220 sx Class G neat 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6656'MD (6372'TVD). The Kuparuk interval is expected to be cored in this well. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3320'MD (3262'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2771 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6.5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereb cerJ~f4~ that the foregoing is true and correct to the best of my knowledge SIGNED/ /~~~./c-~-~,~ TITLE Area Drilling Engi neet The space/~v~ ~-~1,'~ i ss i o ~use - CONDITIONS OF APPROVAL DATE Directional Survey required I APl number I~,.Y E S E~]NO 50- 0 SEE COVER LETTER FOR OTHER REQUIREMENTS Samples required ! Mud log required I~YES j~qO I-lYES ,,~N O i Permit number ~-~"~'~ ~ .I Approv~q.L~te APPROVED BY/ Z}/'[~/~~~ ~o~m~O~O~ PD/PD09 ~' / '~'~ ,C'OMMISSIONER DATE December 14, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2E-!O installed and tested upon completion of the job. 2E-10 will be the seventh well drilled on the pad. It is 25' away from 2E-11 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 5285'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. RECE i'","- ;Alaska Oil 8, t~as ~, Anc','t.: · . __, ....... ~ -.~-----L~ ....... L-- ; ;--L-.--. ...... · ....... 4- ....... J ....... ~---{ ...... : .............. -{ ......... 4-- ...... ~ ....... .... DE- ::i4'4 ~ ~ , .. ! .... , ~ ' { , ~ { , ) , { , ~ _ ,i ...... , , , , .~ .... } ! ..... : ':sO_nay-: ...... ~-- ,.. DEP 1 62{ - - - _ _ .~ -._~ ~ - . .... ............ ~ ........ ~ ...................... ~ ......... ~ ...... ~ .... ~ ._~ .._ ~_~ . ~ ...... :_ _ . ! . . ~ . , . _-__,_ ===================================================================== ~S~S~:.:.T.V-D~ t72--~D=~ D~P=.~ ~BO: ::: ::-:.::: :::-:::-~:-:-: ======================== :::~..: :_: :__:__:_._::~~~~-~-~~7~~~-'~E~~~: :..: :~ :_: .: ::::;. .................... ~ ........................... -~ ................ ~ ..................... ~ .......... ~ ........: .......... ~ ......... : ................. I ................... ~ . ........ ~4 ........ .... ~ -[: ........ i~ .................. l~ ....... 1~ , , .... ~ ............... ~ 1; ' ' ' il - · :~ .... ~)' ...... ~ ~ I I I ~ ~I ....... ~ ...... ~ _ :.:::::?' ::::;:::: ..... :b::::~::::~:ooo :::::::::::::::::::::::::::::::::::::L::-':.:f::: ::-: ::::::::::::::::::::: ~:: :': :.._~_~.:: ::-::.~ ~ ~ ' [ '~ ~3-~LUt' - I ~- ~ I I I ' ~ ' ' ] '~ --'1 : ....... ~ ..... ~ ........... ~ ........ : -~ T ..... T ......... : ............ -t ........ : ........... ~ ........ ~ ......... { ....... '~,::',--' 2'-.] ....... ~ ' ' ' + ........ ..... ~ .......... ! ......... , .... . __~ ...... i.. _: ___{ .... ~- . ; I ! ! 7 6 5 i i DIAGRA/~ #1 I~578"~"-'Y'JO PS~ F~RA E~ STACK, A~ATOR CAPACITY TEST I. O-ECK ~ FILL lEVEL ~.TH HYD~IC FLUID, 2. ~ 'THAT ACC~ATC)~ Pt~ IS ZOO0 F'~I I~I'TH > 15. t4. RECEIVED DEC I gB& 1. FILL BC:P STACK ~ O-ID<E Ivla/~FCI_D W'[TN AECT]C DIESEL.. 2. O-ECl< THAT /~_L LOC:K DONN SCI~ FLLLY ~-TRACTED. SEAT TEST PLUG W3TH EL.N~I~ JT AhD EL~ IN L~ 3. Q_CS~ ANN.L~ Pf~-VENTi~ AN) ~ K:[LL LI~ V~ ~~ TO ~ ST~ 4. ~~ ~ TO ~ ~ ~ ~D F~ I0 ~ ~~ TO ~ ~] ~ ~D F~ I0 ~D ~_~ TO 0 ~. L3~ V~ ~ T~ PI~ ~ ~ ~ V~ 7. ~I~ ~l~ ~L V~ LI~ F~li~ i~l ~S T~i ~ ~ F~Y ~. ~N ~TT~ P]~ ~ BA~ ~ ID. ~ ~I~ ~ ~ T~T TO ~ F~UI~ ~T ~ V~ ~N ~Z~]~ ~ITI~ 12. ~ST ~~I~ V~ ~Y, ~Y ~ ~I. F~ S]~ ~ ~ TO ~ILLI~ ~RVI~. 510084C~ ! , ,) PS; RSRRA BOP STAEK i, )E" - 2000 ~sl Tankcc s~arcinc neac 2. i!" - 2000 psi casinc i]" - 3000 FSi x !3-5/8' - 5000 DSi spacer 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi spool 5. 13-5/8" - 5DDD psi pipe rams 6. i3-5/8" - 5000 psi OriilinG spool w/choKe anC kill lines 7. 13-5/8" - 5DOD psi pipe rams ~3-5/8" - 5000 psi blin~ rams 1~-5/~" - 5ODD psi annular BLI~] - ~ ~'~ spook -,,, ] 5 I mil m RECEIVED Alaska Oil & f~as Cons. Commissio, Anchorage ACCUMULATOR~.'~'t"'~'~,, TEST ~ CHECK AND FiLL ,~ruu,,,,~n= ... .. ~ ...... ~,~ RESERVOIR TO PROPr; LEVEL w!~ HYDrAULiC D. UID, 2. ~SSURE THAT ACCUMULATOR PRESSURE ~S 3DO0 PS] WiT~ 15Do PS] DDWNSTREA)q, OF T~E REGULATOR. ~ D~SERVE T~ME, TI~,EN CLOSE .... UN~TS SiHULTANEOUS[" AND RECORD THE TIHE AND PRESSURE REM$,!NING A~E~ ~LL ,,~,~t ARE CLOS.-~ Wii"P, r., 'NG PUMP ..... ~KAR6, OFF. 4. RECD~D O~ N~C REPORT. THE ..... ~rrr~-~ABL_~ LOWE~ LiMiT IS 45 SECONDS CLOSING TI~E A~ 1200 PSI ~iK]NG PRESSURE. '.,3-5/8" BOP STACK TEST ,r~l)... SOP STACK AND ~%N." FOLD WiTH ARC~,TM. ~r~r:u I ~ 2. CHECK THAT ALL HO~ DOWN SC~F~S ARE FULLY ~. PRUDiSH]NE DEFTH THAT TEST PLUG ~iLL AND S~T IN WELLHE~. RUN IN LDCK DDVN SCR~S H~. MINUTES, 5.]NCRE~E P~ESSU~E TO iBOD PSi AND NDLE FOR !D HINUTES. BLEED TD ZERO PSi. 6.OPEN ANNU~R PREVENTER AND C~O$E TOP SET DF R~HS. 7. iNCR~SE PRESSURE TO 3000 ~S] AND NOLO FOR TE~T R[~.]~]NG UNTt~7[h ....... ~N]FOY~.'''~',m~:~, iF ANY, W]TX 3COO PSi 'JPSTR[~. OF VALVE AND ZE~O DOWNSTRE~v,. ~LEED SYSTE~ TD ZERO OPEN TOP S~ OF PiPE ~S AND CLOSE EC~DF. S~ OF P l PE lO. ~CRE~E PRESSURE TO.~'~" ~S'J AND HOLD FOR HI "'-' ~ ' . N~,:_ B~E[D TO ZERO PS~ O~EN BO~DK S~ OF ~IPE ~S. BACK OFF RUNN]N6 ' "' OF . ..OSE TM ~'~ RAHS JOINT AND PU~ OUT HOLE r~ ~r~T TO ~OO0 PSi FOR !0 ~ ,',-r~ TC ZERO' PS~. !2 DPEN ~L~N[' ~S ' '~ RECDVE; TEST P' UE. MAKE SL;F,E ~N~FOLD AND LINES ARE FULL OF ARCTIC D:ESEL AND ALL ....,~L,~.urt ARE .,.~ ]N ~'~'ur,,~NG' POSiTiON. 12. TEST STANDPIPE VALVES TO 3DOD )~ TEST '~'. ;N. iDE BO~ TO 3OOO Pi; .. K~_~v CDC~ AND KOOM? PUMP. ~ RECDKD T~T INFORMATION OK" ..... :K~"~'-~: -'~- FORK S:GN AND SEND TO DR]LZ~N6 ~ ....... . Oh~. A ~EEK ANt ruh'c 16 FK~FO~'~ COMPL~E BOFE TE~T .~s TiDNALLY DPE~TE ~DPE DAILY. Surface Diverter System 1. 2. 3. 4. 5. 6. ?. ii 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Operation 1. Upon 'initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" COnductor RECEIVED Alaska Oil 8, Gas Cons, C,,ommisslon Anchorage CHECK LIST FOR NEW WELL PERMITS Lease & Well Company ITEM APPROVE DATE (1) Fee_ .~'~ ~,--C.< ~ %." ~. .:t'c~' (2) Loc (.i_./~:~.~._~'t,-~;,,,-.,~'~ (2 thru 8% i. Is the permit fee attached ........................................ me 3. 4. 5. 6. 7. 8. (3) .A..dmin ?.,,--.~,<" ) ~- ~2"~ 9. ('9" thru 12) 10. (10 and 12) 12. (13 thru 21) (5) S/Y// (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is well to be located in a defined pool ........................... Is well located proper distance from property line . Is well located proper distance from other wells .................. Is sufficient undedicated acreage available in this pool .......... Is well to be deviated and is wellbore plat included .............. Is operator the only affected party ............................... Can permit be approved before ten-day wait ........................ YES NO REMARKS Does operator have a bond in force .................................. . Is a conservation order needed ..... Is administrative approval needed ............................... .... <i~ ......... 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, tension and burst.[ Is this well to be kicked off from an existing wellbore ............. , .... Is old wellbore abandonment procedUre included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required. ........................ .... .......... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating -Test to ~/~'~'~ p~ . Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. _ 0 ~-~ o Geology:/ Engineering:, JAhi:,?,:..,.,!? .................. MTM ~' / rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF 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 APPENDIX. , No special effort has been made to chronologically organize this category of information. 2 ,3 7 c, 7 ,.r, 65 9 {) ,'.~: ;", :~ '] , , ,,[ I !) 6. 3. 92. 3. 5 3 -'~ '?4 3 .'"' t 5 -:, 2 b .t, i z.! :.,: 6 3 "-~ "b, (, ;', f') .: 4 3 '7:1." 9.0 e:,2 5 3,21.97 1 · 48 0 t, 9.03.1..3 '.~,. 9 ~ (') 9 5 ('., 5~ 8 ~.~ (} ':',.., 677'! ":' 3..>' _? r', 3.1.54,3 8.8,.I, 25 i.. 3 0 r~ h 4,64 ~ 4 :1.0,578i 9,7 42 2 4.475 t 0,2 42 2 4.. 3 8 2'~.~ 9, T bob 3,3bi i'. 1.9 ? :27 ,i <) o 3 t 3 ¢ . . 3,5 4 3 3.9102 10.1.$53 3.3652 3.3457 l 0. '1 i:~ 91 2. '7559 4,75 (:' O -tO ,, r, 1 ~ ,, . ~ . I 12. J, q 7 7 '! 0,0 ,")0(} 5 2 8. II ,.)0 i,.~ "~, 3 ",t 5 3.267 C 9..36 72 2, ? 9 30 2. 7168 9. 3 9 ;a 4 · ,,~ ti 3.7 ! 4 3,4 .i. 2 .? 9,5 9 '3 t~ 3.61 ! 3 2.69 7 3 it, (), 132 t: '.t. 2910 2.5391 9.04t, 9 '2..6582 o q 359 3,3i. 2h 2.53~ 3 g, B 5 .' 6 10. 8 4 3 '/ 0 . C,,, 4 2, ~: ~'. ~,: q 4 ,. fl 9 3 '3 9 :!. 0 5 2 5 3.32a2 ,,. ~, ~ 3 4 ('::. '7 5 0 {:~ 3. ? <:', 17: ? 'o 5. '2 .h !": I (), {5.8 7 5 ],l Il ,~ 9 / 6 6 4.3 4, ? 7 3.5 o :! 2.1 1 7 Z ,~. 7 '7 ~' ~ . ,. 4.7 3 ~:t ,3 8. % 9 3 S '2, t) () (). 0 0 (,),'.~