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Home My WebLink About185-024 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. 7 th 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 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 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 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: BiSN Repair 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 6796'feet 6227'feet true vertical 6485'feet None feet Effective Depth measured 6227'feet 6195', 6384', 6402', 6410' feet true vertical 5920'feet 5888', 6075', 6093', 6101' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/J-55 6433' MD 6124' TVD Packers and SSSV (type, measured and true vertical depth) 6195' MD 6384' MD 6402' MD 6410' MD N/A 5888' TVD 6075' TVD 6093' TVD 6101' 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: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3312' 3263' Burst Collapse Production Liner 6749' Casing 6469'6779' 3282' 117'Conductor Surface Intermediate 16" 9-5/8" 81' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-024 50-029-21287-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025633 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3B-14 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 117' ~ ~~ Well Remains Shut In ~~ ~ 323-131 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: Baker FHL Retrvbl Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Otis WD Perm Packer SSSV: None Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 6294-6350', 6374-6380', 6470-6502', 6514-6530' 5986-6042', 6066-6071', 6161-6193', 6205-6220' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.10.18 11:46:48-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn By Grace Christianson at 3:01 pm, Oct 19, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 18, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the BiSN plug repair performed above the known tubing and production casing leak in the inner annulus of KRU 3B- 14 (PTD #185-024). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN= Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.10.18 11:46:10-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 5/3/2022 REPAIR WELL LOGGED BASE LINE PASS WITH ARCHER VIVID ACOUSTIC LEAK DETECT TOOL DOWN TO TOP OF PLUG @ 6213' RKB. PRESSURE UP ON IA x TBG TO ACTIVATE LEAK. SWAB VALVE BEGAN TO LEAK OUT OF STEM @ 2400' PSI. PULLED OOH & HAD SWAB VALVE SERVICED. RBIH TO TOP OF PLUG @ 6213' RKB. UNABLE TO BUILD PRESSURE ABOVE 750 PSI & TOOL IS READING NOISE AT PLUG, INDICATING PLUG IS NOT HOLDING. JOB SUSPENDED UNTIL NEW PLUG IS SET. IN PROGRESS 5/6/2022 REPAIR WELL PULLED 3 1/2" D&D PLUG ASSEMBLY @ 6237' RKB. READY FOR PLAN FORWARD. 5/9/2022 REPAIR WELL SET QUADCO 3.5" RBP (S/N:CPP35113 & CPEQ35043) @ 6230' RKB MID-ELEMENT. T/I/O WHEN SET = 600/600/50 RAN ARCHER VIVID ACOUSTIC LDL. MAKE DYNAMIC PASS f/ SURFACE TO TOP OF RBP @ 6228' RKB. ACTIVATE LEAK w/ LRS CONSTANTLY PRESSURING UP ON THE IA TO 3000 psi. LOG f/ TOP OF RBP TO SURFACE. WHILE LOGGING SEE NOISE SIGNATURE @ ~6123' RKB & ~6118' RKB. ALSO SAW A SMALL AMOUNT OF NOISE @ ~4960' RKB. DATA SENT OFF FOR PROCESSING. JOB COMPLETE 6/16/2022 REPAIR WELL DRIFT TBG W/24'X 2.625'',SET 2.77''AVA CATCHER(OAL34''),PULLED 1.5''GLV FROM ST#4 @5614'RKB,SET 1.5''DMY VLV W/RK LATCH IN ST#4 @5614'RKB,ATTEMPTED TO PULL 1.5''GLV FROM ST#3 @ 4960'RKB IN PROGRESS 6/17/2022 REPAIR WELL PULLED 1.5'' GLVS & SET 1.5''DMY VLVS IN STATIONS #1 @2495' RKB,#2 @3930'RKB & #3 @ 4960'RKB. TURN OVER TO LRS FOR CIRC OUT. IN PROGRESS 6/17/2022 REPAIR WELL CIRC OUT PUMPED 3 BBLS DSL. PUMPED 180 BBLS SEA WATER W/CRW FOLLOWED BY 70 BBLS DSL DOWN TUBUING TAKING RETURNS UP IA AND THROUGH FLOWLINE OF 3B-13. U-TUBE TBG AND IA FOR FEEZE PROTECT. 6/18/2022 REPAIR WELL SET 1.5''OV (1/4''PORT)W/RK LATCH @ 6113' RKB,PULLED CATCHER @ 6228'RKB. BiSN PREP COMPLETE. 6/23/2022 REPAIR WELL LOG BASELINE CBL FOR PRE-BISN TREATMENT FROM TOP OF RBP AT 6228' RKB TO SURFACE. FREE PIPE OBSERVED IN IA. JOB COMPLETE READY FOR BISN TREATMENT. 6/3/2023 REPAIR WELL SET SS CATCHER @ 6145' SLM, PULL OV @ 6112' RKB, PULL CATCHER. READY FOR BISN SHOT DEPLOYMENT. 8/22/2023 REPAIR WELL SET CATCHER W/ RBP STINGER ON RBP @ 6227' RKB, SET 1.5" DMY VALVE IN ST#5 @ 6113' RKB, PULL DMY VALVE FROM ST#4 @ 5614' RKB. READY FOR BiSN SHOT DEPLOYMENT 8/28/2023 REPAIR WELL PUMPED 3,969 LBS OF BISN BASE SHOT & 529 LBS OF BISN SEAL SHOT DOWN THE IA WITH ~12 BBL OF DIESEL (COMPLETE) 3B-14 BiSN Repair Summary of Operations 8/29/2023 REPAIR WELL TAGGED TOP OF PLUG AT 6223', PERFORM REPEAT PASS FROM 6218' - 5950', PERFORM MAIN PASS FROM 6218' - SURFACE. BiSN ALLOY OVER INTERVAL: 6068' - 6084' 9/1/2023 REPAIR WELL MELT BiSN BEADS W/ TOP AT 6068' RKB, CCL TO PRT = 14.4' , CCL STOP = 6053.6', CORRELATED TO AKE GR/CCL LOG DATED 8/29/23, JOB IS READY FOR DDT OF IA. 9/3/2023 REPAIR WELL BLEED IA DOWN TO 0 PSI AND PERFORM DDT (JOB COMPLETE) SEE LOG FOR DETAILS 9/15/2023 REPAIR WELL (AC-EVAL) LOAD T FOR UPCOMING CMIT-T X IA (COMPLETE) 9/23/2023 REPAIR WELL SET CATCHER ON TOP OF RBP @ 6227' RKB, SET DMY IN STA #4 @ 5614' RKB, CONDUCT PASSING MIT-IA, CONDUCT FAILING MIT-T... IN PROGRESS 9/24/2023 REPAIR WELL ATTEMPT MITT, ESTABLISH A LLR OF 4.2 GAL/MIN DOWN THE TUBING, RUN DD HOLE FINDER TEST RIGHT ABOVE RBP, SAME TEST RESULTS, TEST ABOVE MANDREL @ 6114' RKB TO 2500 PSI & HOLD FOR 5 MINS, PULL CATCHER FROM 6227' RKB. READY FOR DHD 9/27/2023 ACQUIRE DATA (AC EVAL) IA DDT TO 50 PSI (COMPLETE) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est 21' of Rathole) 6,551.0 3B-14 6/27/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added BiSN "packer" at 6068' RKB 3B-14 9/29/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: T x IA COMMUNICATION, ESP WELL 12/30/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 117.0 117.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 3,312.2 3,262.9 36.00 J-55 BTC PRODUCTION 7 6.28 30.0 6,779.5 6,468.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.7 Set Depth 6,415.2 Set Depth 6,106.5 String Max No 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection 8 rd EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.7 23.7 0.07 HANGER 6.250 FMC TUBING HANGER 3.500 514.3 514.3 0.12 NIPPLE 4.520 CAMCO 'DS' NIPPLE 2.875 2,495.1 2,494.7 5.97 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 3,930.6 3,802.4 29.10 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 4,959.7 4,706.4 27.21 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 5,614.4 5,316.9 13.98 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 6,112.5 5,806.2 7.76 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 6,162.8 5,856.0 7.50 LOCATOR 5.880 BAKER LOCATOR w/ pup Spaced out 7' off 3.010 6,176.2 5,869.3 7.43 PBR 5.880 BAKER 80-40 PBR 3.000 6,195.0 5,887.9 7.33 PACKER 5.940 BAKER 'FHL' RETRIEVABLE PACKER 2.920 6,245.7 5,938.3 7.15 GAS LIFT 5.968 Camco 3.5"x1.5" 'MMG' GLM CAMCO MMG 2.920 6,367.1 6,058.7 6.87 BLAST RING 4.500 CARBIDE BLAST RING (1) 2.867 6,395.1 6,086.6 6.83 SLEEVE-O 4.500 CMU SLIDING SLEEVE w/2.813" (CLOSED 6/27/2020) 2.812 6,409.2 6,100.5 6.80 SEAL ASSY 4.450 HES STRAIGHT SLOT LOCATOR SUB & SEAL ASSEMBLY w/MULE SHOE GUIDE - STABBED INTO ORIGINAL COMPLETION PACKER @ 6410' 2.970 Top (ftKB) 6,410.0 Set Depth 6,433.0 Set Depth 6,124.2 String Max No 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,410.0 6,101.3 6.80 PACKER 5.875 OTIS 7" WD PERMANENT PACKER 4.000 6,413.4 6,104.7 6.79 SBE 5.000 OTIS SEAL BORE EXTENSION 4.000 6,425.0 6,116.2 6.76 NIPPLE 4.500 CAMCO NO GO 'D' NIPPLE 2.750 6,432.5 6,123.7 6.74 WLEG 4.000 OTIS BALL CATCHER w/WIRELINE ENTRY GUIDE 3.000 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) 6,068.0 5,762.1 8.17 OTHER BiSN BEADS MELTED FROM 6068' TO APPROX 6078' RKB (ANNULUS OF 7" X 3.5") 9/1/2023 3.500 6,113.0 5,806.7 7.76 LEAK TUBING LEAK AT GLM, 0.3 BPM, 2400 PSI 9/19/2020 2.990 6,123.0 5,816.6 7.71 LEAK - CASING 7" CASING LEAK 5/3/2022 0.000 6,227.5 5,920.2 7.21 PLUG 3.5" QUADCO RBP. OAL=7.98, 3.99' f/ TOP OF PACKER TO EQ PISTON CPP3 5113 / CPEQ 35043 5/9/2022 0.000 6,384.0 6,075.5 6.85 PATCH - PACKER 2.72" P2P, SPACER, ANCHOR LATCH, OAL 18.86' CPP3 5280 9/18/2020 1.625 6,388.0 6,079.5 6.84 SPACER PIPE 2-1/16", P110 SPACER PIPE CPAL 35172 9/18/2020 1.590 6,398.0 6,089.4 6.82 LEAK TUBING LEAK AT CMU 9/18/2020 2.500 6,402.0 6,093.4 6.82 PATCH - PACKER 2.72" P2P, OAL 4.01' CPP3 5286 9/18/2020 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,495.1 2,494.7 5.97 1 GAS LIFT DMY RK 1 1/2 0.0 6/17/2022 0.000 3,930.6 3,802.4 29.10 2 GAS LIFT DMY RK 1 1/2 0.0 6/17/2022 0.000 4,959.7 4,706.4 27.21 3 GAS LIFT DMY RK 1 1/2 0.0 6/17/2022 0.000 5,614.4 5,316.9 13.98 4 GAS LIFT DMY RK 1 1/2 9/23/2023 6,112.5 5,806.2 7.76 5 GAS LIFT DMY RK 1 1/2 6/3/2023 3B-14, 10/16/2023 4:09:33 PM Vertical schematic (actual) PRODUCTION; 30.0-6,779.5 IPERF; 6,514.0-6,530.0 IPERF; 6,470.0-6,502.0 PACKER; 6,410.0 PATCH - PACKER; 6,402.0 LEAK; 6,398.0 SPACER PIPE; 6,388.0 PATCH - PACKER; 6,384.0 IPERF; 6,374.0-6,380.0 IPERF; 6,294.0-6,350.0 GAS LIFT; 6,245.7 PLUG; 6,227.5 PACKER; 6,195.0 LEAK - CASING; 6,123.0 GAS LIFT; 6,112.5 LEAK; 6,113.0 OTHER; 6,068.0 GAS LIFT; 5,614.4 GAS LIFT; 4,959.7 GAS LIFT; 3,930.6 SURFACE; 30.6-3,312.2 GAS LIFT; 2,495.1 NIPPLE; 514.3 CONDUCTOR; 36.0-117.0 KUP PROD KB-Grd (ft) 35.98 RR Date 3/23/1985 Other Elev 3B-14 ... TD Act Btm (ftKB) 6,796.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128700 Wellbore Status PROD Max Angle & MD Incl (°) 29.55 MD (ftKB) 3,400.00 WELLNAME WELLBORE3B-14 Annotation Last WO: End Date 7/2/2010 H2S (ppm) 125 Date 10/8/2018 Comment SSSV: NIPPLE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,245.7 5,938.3 7.15 6 PROD DMY RK 1 1/2 0.0 7/7/2010 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,294.0 6,350.0 5,986.2 6,041.8 C-4, C-3, C-1, 3B-14 5/21/1985 12.0 IPERF 120° ph; 5" Scalloped Csg Gun 6,374.0 6,380.0 6,065.6 6,071.5 UNIT B, 3B-14 5/21/1985 12.0 IPERF 120° ph; 5" Scalloped Csg Gun 6,470.0 6,502.0 6,160.9 6,192.7 A-4, A-3, 3B-14 5/21/1985 4.0 IPERF 120° ph; 4" Carrier Csg Gun 6,514.0 6,530.0 6,204.6 6,220.5 A-2, 3B-14 5/21/1985 4.0 IPERF 120° ph; 4" Carrier Csg Gun 3B-14, 10/16/2023 4:09:34 PM Vertical schematic (actual) PRODUCTION; 30.0-6,779.5 IPERF; 6,514.0-6,530.0 IPERF; 6,470.0-6,502.0 PACKER; 6,410.0 PATCH - PACKER; 6,402.0 LEAK; 6,398.0 SPACER PIPE; 6,388.0 PATCH - PACKER; 6,384.0 IPERF; 6,374.0-6,380.0 IPERF; 6,294.0-6,350.0 GAS LIFT; 6,245.7 PLUG; 6,227.5 PACKER; 6,195.0 LEAK - CASING; 6,123.0 GAS LIFT; 6,112.5 LEAK; 6,113.0 OTHER; 6,068.0 GAS LIFT; 5,614.4 GAS LIFT; 4,959.7 GAS LIFT; 3,930.6 SURFACE; 30.6-3,312.2 GAS LIFT; 2,495.1 NIPPLE; 514.3 CONDUCTOR; 36.0-117.0 KUP PROD 3B-14 ... WELLNAME WELLBORE3B-14 JLC 3/15/2023 RBDMS JSB 031523 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-03_21067_KRU_3B-14_VIVIDCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21067 21067 3B-14 50-029-21287-00 VIVID Camera 03-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:185-024 T36607 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.16 14:37:09 -08'00' Originated:Delivered to:3-Dec-20 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 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 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: PTD: 1850240 E-Set: 34344 Received by the AOGCC 12/04/2020 12/08/2020 Abby Bell Originated:Delivered to:3-Dec-20 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 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 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: Received by the AOGCC 12/04/2020 PTD: 1850240 E-Set: 34343 12/08/2020 Abby Bell Originated:Delivered to:3-Dec-20 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 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 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: Received by the AOGCC 12/04/2020 PTD: 1850240 E-Set: 34341 12/08/2020 Abby Bell Originated:Delivered to:3-Dec-20 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 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 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: Received by the AOGCC 12/04/2020 PTD: 1850240 E-Set: 34340 12/08/2020 Abby Bell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y Samantha Carlisle at 9:44 am, Oct 20, 2020 ADL 025633 VTL 11/03/20 SFD 10/20/2020 RBDMS HEW 11/13/2020 X DSR-10/20/2020 SFD 10/20/2020 ! " #$$% & ' () *( +,,* -) ./ #012+,3-4& %+,5 ") "(" + ( ) / - 3$56+*7 78 / ! 7 94 ! & - '" -) ./ Alexander J Trower Digitally signed by Alexander J Trower Date: 2020.10.18 18:29:01 -08'00' !" #$ % " !$ " &'( % """ % )*+,-!&" &'( ". " /0#! ! !" # ! ! $ # !!% $&% '## !( ) * !$ ! 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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est 21' of Rathole) 6,551.0 6/27/2020 3B-14 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TUBING LEAK AT CMU, SET PATCH, CHANGE OV, TUBING LEAK AT GLM 5 9/19/2020 3B-14 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 30.6 Set Depth (ftKB) 3,312.2 Set Depth (TVD) … 3,262.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.0 Set Depth (ftKB) 6,779.5 Set Depth (TVD) … 6,468.6 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.7 Set Depth (ft… 6,415.2 Set Depth (TVD) (… 6,106.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8 rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.7 23.7 0.07 HANGER FMC TUBING HANGER 3.500 514.3 514.3 0.12 NIPPLE CAMCO 'DS' NIPPLE 2.875 6,162.8 5,856.0 7.50 LOCATOR BAKER LOCATOR w/ pup Spaced out 7' off 3.010 6,176.2 5,869.3 7.43 PBR BAKER 80-40 PBR 3.000 6,195.0 5,887.9 7.33 PACKER BAKER 'FHL' RETRIEVABLE PACKER 2.920 6,367.1 6,058.7 6.87 BLAST RING CARBIDE BLAST RING (1) 2.867 6,395.1 6,086.6 6.83 SLEEVE-O CMU SLIDING SLEEVE w/2.813" (CLOSED 6/27/2020) 2.812 6,409.2 6,100.5 6.80 SEAL ASSY HES STRAIGHT SLOT LOCATOR SUB & SEAL ASSEMBLY w/MULE SHOE GUIDE - STABBED INTO ORIGINAL COMPLETION PACKER @ 6410' 2.970 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 6,410.0 Set Depth (ft… 6,433.0 Set Depth (TVD) (… 6,124.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,410.0 6,101.3 6.80 PACKER OTIS 7" WD PERMANENT PACKER 4.000 6,413.4 6,104.7 6.79 SBE OTIS SEAL BORE EXTENSION 4.000 6,425.0 6,116.2 6.76 NIPPLE CAMCO NO GO 'D' NIPPLE 2.750 6,432.5 6,123.7 6.74 WLEG OTIS BALL CATCHER w/WIRELINE ENTRY GUIDE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,113.0 5,806.7 7.76 LEAK TUBING LEAK AT GLM, 0.3 BPM, 2400 PSI 9/19/2020 2.990 6,384.0 6,075.5 6.85 PATCH - PACKER 2.72" P2P, SPACER, ANCHOR LATCH, OAL 18.86' 9/18/2020 1.625 CPP35280 6,388.0 6,079.5 6.84 SPACER PIPE 2-1/16", P110 SPACER PIPE 9/18/2020 1.590 CPAL35172 6,398.0 6,089.4 6.82 LEAK TUBING LEAK AT CMU 9/18/2020 2.500 6,402.0 6,093.4 6.82 PATCH - PACKER 2.72" P2P, OAL 4.01' 9/18/2020 1.625 CPP35286 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,294.0 6,350.0 5,986.2 6,041.8 C-4, C-3, C-1, 3B-14 5/21/1985 12.0 IPERF 120° ph; 5" Scalloped Csg Gun 6,374.0 6,380.0 6,065.6 6,071.5 UNIT B, 3B-14 5/21/1985 12.0 IPERF 120° ph; 5" Scalloped Csg Gun 6,470.0 6,502.0 6,160.9 6,192.7 A-4, A-3, 3B-14 5/21/1985 4.0 IPERF 120° ph; 4" Carrier Csg Gun 6,514.0 6,530.0 6,204.6 6,220.5 A-2, 3B-14 5/21/1985 4.0 IPERF 120° ph; 4" Carrier Csg Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,495.1 2,494.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,174.0 7/8/2010 2 3,930.6 3,802.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,183.0 7/8/2010 3 4,959.7 4,706.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,184.0 7/8/2010 4 5,614.4 5,316.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,180.0 7/8/2010 5 6,112.5 5,806.2 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 9/19/2020 6 6,245.7 5,938.3 CAMCO MMG 1 1/2 PROD DMY RK 0.000 0.0 7/7/2010 Notes: General & Safety End Date Annotation 12/30/2003 NOTE: WAIVERED WELL: T x IA COMMUNICATION, ESP WELL 3B-14, 9/20/2020 5:38:43 AM Vertical schematic (actual) PRODUCTION; 30.0-6,779.5 IPERF; 6,514.0-6,530.0 IPERF; 6,470.0-6,502.0 PACKER; 6,410.0 PATCH - PACKER; 6,402.0 LEAK; 6,398.0 SPACER PIPE; 6,388.0 PATCH - PACKER; 6,384.0 IPERF; 6,374.0-6,380.0 IPERF; 6,294.0-6,350.0 GAS LIFT; 6,245.7 PACKER; 6,195.0 GAS LIFT; 6,112.5 LEAK; 6,113.0 GAS LIFT; 5,614.4 GAS LIFT; 4,959.7 GAS LIFT; 3,930.6 SURFACE; 30.6-3,312.2 GAS LIFT; 2,495.1 NIPPLE; 514.3 CONDUCTOR; 36.0-117.0 KUP PROD KB-Grd (ft) 35.98 Rig Release Date 3/23/1985 3B-14 ... TD Act Btm (ftKB) 6,796.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292128700 Wellbore Status PROD Max Angle & MD Incl (°) 29.55 MD (ftKB) 3,400.00 WELLNAME WELLBORE3B-14 Annotation Last WO: End Date 7/2/2010 H2S (ppm) 125 Date 10/8/2018 Comment SSSV: NIPPLE .� • • 0 e9 (0 UJ"0 In 170 0 CC cu ~ > 3 O X a @ n U O N W 4 > LP jc-N1 Q v � � ° 4, h o I- Y On 4-' o - O _ M 4- -0 CO 0 ` N co a c O a a) 0 0 c a) E - rt .", (1} +, -a ..,,.. O a a -7_,-- 1▪3 Q L , C Q s m CI W m c0 co CO (C (0 (0 (0 c0 (0 L v o J Q O ti-, fZ E }, L -0 O cn J d a) u 0 U U U U U U _c , g; 0 0 0 0 0 0 O O O O c L C y.., W C cz U U C '. 1n t0 N M V t0 t� c0 O Q O +"' C Q N N U -6 M O N D > u i v > -6 [1 �L7 H- N ° @ +cam r▪d -O N OU V 0 0 0 0 0 0 0 0 0 0 C a1 L W J J J J J J J J J J O° C i= O y W W W W W W W W W W U F- LL LL LL LL LL LL LL LL LL LL N a) N a) -f_ Q J J J J J J J J J J CD a > N >" � I- < < < < < < < < < < a1 v, C , It- �O+ m O Z Z Z Z Z 2 Z Z Z Z N t N O '- a) O W LL LL LL Li Ll. LL LL LL LL LL a. .p C > C 03 1.4 EC cow' CO U Yr O 0 vi FH oi. c~ > u a) + p 0 v .„, — d coaOO teu 3 < aJ a a c a •V vl CD W LL d LL LL 7 0 CD it E 0 0 0_ O ccx LE O s a g) c Y may .Z I- 0 W to• U B W L rMi > ,,1 m0 ca i � II acZ0 , M ▪ x W °”' CZ' ? ns '73 ' fd C`' 0 W > > > > > 3 > 3 3 3 zap U � Li) W # Ilf .,,1O / a a z z z z W W 0 0 D O W W;W W W > > W W W W > >i> > a Y Y E E E E Y YiY Y 0 0 0 0 0'0 0 Y Y Y Y W 0 0 0 0 0 0 Q Q Q QI a) +; Lu ac 0LL a a Ce CC CL CC a 0_ a. a. 0 YY YY Y Y c> 0 CC ? j ? ? no O aMISSl 1-4 0 rn rnN 0.3 Tt 0 0 0 , X n 0 0 0 0 0> 0> > ooO/ ro U WV It V U — oo ao 3 > Lu 5go' rn rn rn rn _ O w A::; 0 O 0 W W D 0 0 0 O' Q C ora EY 0 0 0 0 0 0 0 0 0 0 4.4u 0 0 0 0 0 0 0 0 0 0 @ m 0 co V C) ,- 0 0 N N N- t0 4.4N N CO Cr 0 N- CO N = a r111�� - 0 CO 0 M O N O — N N N N • N N N N N N N E ; t r o6 A6 A o6 C) C) C) C) C) C p a 001 N 0 N O N O N N N N O 0 0 0 0 r6 u 0 O O 0 0 0 0 0 0 O O O O +, i+ O O 04 J. NIII N U) U) U) LO ') LO a 'O 0 C Lfl CID W rc 1A E E Ti MI cu ry 01 er . a z b ao � Z E N ._ 1- ,_ N 7 N O a en cl aN Eco 0d v (I)▪ daO m el M M rQ 7 N Z OO N M L ,..1 W H C E E oem a3 ¢ I _ it as H H • -46 0244 • 2h 2.02. WELL LOG TRANSMITTAL DATA LOGGED 4/3/zo1 K.BEND To: Alaska Oil and Gas Conservation Comm. August 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVE° P 01 L1 RE: Production Profile: 3B-14 Run Date: 8/15/2015 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 3B-14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21287-00 Production Profile Log %o e j') 1 Color Log 50-029-21287-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 18, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 stoma) MAR 0 9 L O l f RE: Production Profile: 3B -14 Run Date: 1/31/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3B -14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21287 -00 Production Profile Log 1 Color Log 50- 029 - 21287 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 1 �5 09 L f rafael.barre ' ..liburton com Date: 9011 Signed: C 2�eq STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell Plug Perforations ""` Stimulate " Other "" Aker Casing WII Tubing ~' Perforate New Pool Waiver Time Extension Change Approved Program Operat. Shutdow n Perforate '°" Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebpment Exploratory '"" 185-024 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21287-00 7. Property Designation: 8. Well Name and Nu er. ADL 25633~ 3B-14 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6796 feet Plugs (measured) None true vertical 6485 feet Junk (measured) None Effective Depth measured 6688 feet Packer (measured) 6195, 6410 true vertical 6377 feet (true verucal) 5888, 6101 Casing Length Size MD ND Burst Collapse CONDUCTOR 81 16 117 117 SURFACE 3282 9-5/8" 3312 3263' PRODUCTION 6750 7 6771 6460' ~ ~~~~ V ~D r ~ t1i1 "- ~ ~ ~~ ;. ~ ,~ a U' ~.. L ~~y ~ ~'.,i3_ ~ ~01C! Perforation depth: Measured depth: 6294'-6350', 6374'-6380', 6470'-6502', 6514'-6530' ~Iaska ~ ~t Gsa CMil. Cfllt#TIISSiOn True Vertical Depth: 5986'-6042', 6066'-6072', 6161'-6193', 6205'-6221' ~i'1C}1a~f~~J!! Tubing (size, grade, MD, and TVD) 3.5, L-80, 6415 MD, 6107 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER'FHL' RETRIEVABLE PACKER @ 6195 MD and 5888 TVD PACKER - OTIS 7" WD PERMANENT PACKER @ 6410 MD and 6101 TVD NIPPLE - 3.5" x 2.875" Camco "DS" Nipple 8rd EUE @ 514 MD and 514 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Developme t ~` Service 15. Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR ~ WAG ~ GASINJ ~" WINJ SPLUG 16. 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: none Contact J. Brett Packer Cad 265-6845 Printed Name J. Brett Packer Title Wells Engineer Signature •7~ .Phone: 265-6845 Date ~/2 7~.-/lam v~/~il~ / RBDNlS JUL 2 $ ~,~i7-z~-~~ Form 10-404 Revised 7/2009 Submit Original Only ConatoPhiliips KUP -- _ attributes '~ -- APIIU WI 11 Field Name ~ Well 51 225 3B-14 3/23/1985 Casing Description String 0... ,String ID ._ Top (ftK8) Sel Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 117.0 117.0 6250 H-40 WELDED C ing De p[ n ~jStrmg 0... String ID .. Top (ftK8) Se[ Depth (f .. Set Depth (ND) Str ng Wt... Str g String Top Thrd SURFACE ~ 9 5/8 8 765 30.6 3,3122 3,262.9 36.00 J 55 BTC '.C sing Da pt on ~ Str ng 0... Str ng ID .. Top (ftK8) Set Depth (f .. Set Depth (ND) Str ng Wt... Str g String Top Thrd PRODUCTION BTC 7 6.151 21.0 67705 6459.6 26.00 J55 __ _ ITub(n Stnn s 9 Tubin De g iption String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) .. String Wt... Str g String Top Thrd String O._ I TUBING I I 3 1/2 2.992 23.7 6,415.2 6,106.5 9.30 L 80 8 rd EUE Coin letion De tails Top Deptn (ND) Top Incl. Nomi... Top1ftK6) (ftK6) (°) Item Description GommeM _ 1 ID (in) 23.7 237 0.38 HANGER FMC Tubing Hanger w/pupjt 1 3.500 514.3 514.3 0.121 NIPPLE 3.5" x 2.875" Camco "DS" Nipple Srd EUE 2.8121 6,162.8 5,856.0 7.50'~ILOCATOR Baker Seal Assembly locator w! pup Spacetl out T off 3.010 6,176.2 5,869.3 7 43~PBR Baker'80-00' PBR w/40K N shear 3.000 6,195.01 5,887.9 7.33 PACKER Baker'FHL'Retrievable Packer 2.9201, 6,367.11 6,058.7 ~1 6.87~BLAST JT 4 1/2" OD Brown Oil Tool Blast Jt 2.86711 6,395.1! 6,0866' 6.83 SLEEVE-O CMU Sliding Sleeve w/2 S13" (OPENED 7111/2010) 2.812~~1 6,4092, 6,100.5: 6.88 SEAL ASSY HES Straight Slot Locator Sub & Seal Assy w/Mule Shoe Guide - 2.970 ' I STABBED INTO ORIGINAL COMPLEHON PACKER @ 6410' cription 9 String O... IString lD ... T op (ftK8) Set Depth (f.,. Se[Depth (NDi ...IString Wt... String ._ String TOp Thrd TUBING G riginal 1 31/2 ~i 2.992 I 6,410.0 I 6,433.0 ~ 6,124.2 11 9.30 ~_ J-SS EUEB - rtl.__ 11 Completoon~ De T tails (ND) 1 17op Incl Nomi... `iftKBi Top (ftKB) ~) Item Description Comment ID (in) 6,410.0 _ 6,101 4 6.88 PACKER OTIS 7" WD PERMANENT PACKER 2.992 6,413.4 6,104.7 6.87 SBE OTIS SEAL BORE EXTENSION 2 995 16,425.0 6,116.2 6.83 NIPPLE CAMCO NO GO 'D'NIPPLE 2.750 'I 6,432.5 6,123.7 6.80 WLEG __. _. OTIS BALL CATCHER w/WIRELINE ENTRY GUIDE ___ 2.992 rForations & Pe Slots _ snot Top (ftK8) Btrn (ftK8) Top (TVD) (ftK6) Btm (TVD) (ftK6) Zone Date Dens (sh-~ Type I CommaM 6,294 6,350 5,986.2 6,041.8 C-0, C-3, C-1, 5/21/1985 12.0 IPERF ~ 120 deg. ph; S" Scalloped Csg Gun 36-14 i 6,374 6.380 6,065 6 6 071.5 UNIT B, 36-14 5/21/1985 12.0 IPERF 120 tleg. ph; 5" Scalloped Csg Gun 6,470 6,502 6,160.9 6,192.1 A-0, A-3, 36-14 5/21/1985 4.0 IPERF 120 tleg. ph; 4" Carrier Csg Gun 6,514' 6,530 6,204.6 6,220.5 A-2, 36-14 5/21/1985 ~ 4.OI IPERF 120 deg_ ph; 4" Carrier Csg Gun Notes: General 8 Safet y End Date Annota tion - ---- -- 11/5/1998 ',NO TE Run Standing valve or valve catcher in CAMCO D Nipple BEFORE wireline work. 12130/2003 'NOTE WAIVERED WELL T x IA COMMUNICATION, ESP WELL 12/12/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1 etail Mandrel D s - __ __ - I.TopDepth Top port ~ (TVD) Incl I OD Valve ~' Latch ~ Size TRO Run Sln Top (ftK6) (ftK6) (°) I Make Model (in) Serv i TYPe TYPe ', (in) (psi) Run Date Cam... 1 2,495.1 2494.7 5.96'CAMCO MMG 11/2 GAS LIFT 1GLV R-20 0.188 1,1740 7/8/2010 2 3,930.6 3,802.4 29.t0~CAMCO MMG 1 1!2 GAS LIFT GLV R-20 0.188 1,183.0 7/812010 3 4 959.7 4 706.5 27.21 CAMCO MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,184.0 7/8/2010 4 5,614.4 5,317.0 13.49 CAMCO MMG 1 1!2 GAS LIFT GLV R-20 0.188 1,180.0 7/8/2010 5 6,1125 5,806.2 7.76 CAMCO MMG 1 1/2 GAS LIFT OV rtlo20 0.250 0.0 7(//2010 3B-14 Well Events Summary DATE SUMMARY 5/25/10 (PRE RWO) T-POT (PASSED, T-P OT (PASSED), IC-POT (PASSED), IC-PP~T (PASSED), FUNCTION TEST LDS'S 6/7/10 PULL DMY VLV FROM 5989' RKB (OPEN POCKET), REPLACE OV @ 89' W/ DMY VLV. PERFORM SBHPS @ 6075' RKB=2998 PSI. 15 MIN GRADIENT STOP MADE @ 5974'= 2962 PSI. READY FOR BPV. 6/29/10 TAG @ 6566' SLM. SET 2.75" CA-2 @ 6425' RKB. SET CATCHER ON PLUG @ 6425' RKB. RAN PDS CALIPER IN 7" CASING f/ 6410' RKB TO SURFACE. DATA OBTAINED. COMPLETE. SPOT UNIT ON 1C- 170 FORAM JOB. 7/7/10 SET CATCHER @ 6425' RKB,. REPLACE SOV @ 6112' RKB W/ OV, PULL DMY VLV @ 5614' RKB. IN PROGRESS. 7/8/10 PULL DMY VLV'S @ 4959', 3930', 2495' RKB. SET GLV'S @ 5614', 4959', 3930', 2495' RKB. PULL CATCHER @ 6245' RKB. IN PROGRESS. 7/9/10 PULL DMY FROM 6246' RKB, MEASURE BHP @ 6322' RKB (C only 3093 psi), SET DMY @ 6246' RKB, PULL CATCHER FROM TOP OF PLUG @ 6425' RKB, ATTEMPT TO PULL PLUG @ 6425' RKB. IN PROGRESS. 7/10/10 PULL 2.75" CA-2 PLUG @ 6425' RKB, TAG @ 6558' SLM, OBTAINED SAMPLE. IN PROGRESS. 7/11/10 MEASURE A SAND BHP @ 6500' RKB=3240 psi, OPEN CMU @ 6395' RKB. COMPLETE • • ConocoPhitlips Time Log & Summary WelNiew Web Reporting Report Well Name: 3B-14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/24/2010 3:00:00 PM Rig Release: 7/2/2010 4:30:00 PM Time Lo s Date From To Dur 5. De th E. De th Phase Code Subcode T Comment 6/23/2010 u hr Summary Started moving Rig from 1C-Pad to 3B-14. 18:00 18:30 0.50 MIRU MOVE MOB P Move Rig To Opposite side of 1C-170. Movin 18:30 23:00 4.50 MIRU MOVE MOB P Move Rig Mats on 1C Access Road. Standb 23:00 00:00 1.00 MIRU MOVE MOB P Move Rig F/ 1C- KIC Y Intersection. Movin 6/24/2010 Completed Rig Move. MIRU Rig. Spotted Equipment.Pull BPV. Circulated Heated SW around. Started Well Kill. 00:00 01:30 1.50 MIRU MOVE MOB P Rig Between KIC Access Rd & KCC. Movin 01:30 03:30 2.00 MIRU MOVE MOB P Rig In Front of Fire Station @ KOC. Move Rig Mats around Rig. Standb 03:30 04:30 1.00 MIRU MOVE MOB P Mats in Place. Start Moving Rig Again from KOC to Access Road @ 1 R-Pad/1 G-Pad Y Intersection. Movin 04:30 07:00 2.50 MIRU MOVE MOB P Stop Rig @ 1 R-Pad Access Road For Field Wide Crew Change Out. Standb 07:00 14:00 7.00 MIRU MOVE MOB P Continue moving from 1 R access road to 36 ad. 14:00 15:00 1.00 MIRU MOVE MOB P Move over well. Spot & level rig. Accept Nordic 3 rig @ 1500 hrs 6-24-2010. 15:00 16:30 1.50 MIRU MOVE RURD P Rig up Handy-Berm for containment around cellar. Load pits with 10.2 ppg NaCI/NaBr. Spot kill tank and RU hardline. 16:30 18:00 1.50 MIRU WHDBO MPSP P PU lubricator, Pull BPV. Tubing pressure = 1300 psi IA pressure = 1200 si. 18:00 20:00 2.00 COMPZ WHDBO KLWL P Heat Seawater to 180 deg. Weight U KWF to 10.2 20:00 22:30 2.50 COMPZ WHDBO CIRC P Circulated 300 bbls of 180 deg Seawater down IA & Up Tubing @ 3 bpm. ICP=1180 / IAP=890 psi. FCP=510 si / FIAP=460 si. 22:30 00:00 1.50 COMPZ WHDBO CIRC P Start Circulating 10.2 ppg NaCI/NaBr KWF down tb 3 b m, 670 si. 6/25/2010 Circulated 10.2 KWF down tbg & IA. N/D Tree and N/U BOPE. Function & PT BOPE, annular and choke manifold.Pull & Landed Han er. Started Pull 3-1/2" ESP Com letion. Page 1 of 9 • ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ WELCTL KLWL P Finished pum in 10.2 KWF volume. Unable to get 10.2 KWF up IA. Formation started taking fluid. Total Pum ed down Tb 250 bbls 01:00 01:45 0.75 COMPZ WELCTL KLWL P Shut in to Tubing and Circulated 160 bbls down IA 3 b mat 150 si. 01:45 02:15 0.50 COMPZ FLOWT OPNW P Monitor Well For Flow. 02:15 02:30 0.25 COMPZ WHDBO MPSP P No Flow From Tbg Or IA. Set BPV.. 02:30 04:00 1.50 COMPZ WHDBO NUND P N/D Tree. 04:00 06:00 2.00 COMPZ WHDBO NUND T Waiting On the proper Blanking Plug For Tree. 06:00 11:30 5.50 COMPZ WHDBO NUND T Install blanking plug. N/U 11"BOP wNBRs in bottom & 3 1/2" rams in upper cavity. Pre test and could not get blanking plug to hold pressure. PU retrieving tool and pull blanking plug. Teflon taped threads and reinstalled. Pre test and held ood. 11:30 15:00 3.50 COMPZ WELCTL ROPE P Function & pressure test rams, annular, and choke manifold to 250/3500 psi. Testing waived by Lou Gramaldi @ 0600 hrs 6-25-2010. Pull blankin lu . 15:00 16:00 1.00 COMPZ RPCOM PULL P Pull BPV. MU landing jt and hoses. BOLDS. PU to 125K but could not unseat hanger. Wrapped tubing spool with steam blanket and heat up. PU and unseat hanger w/130k including block wt. Pull hanger to rig floor. Well taking fluid, Filled hole. FL dro ed 6' in less than 1 min. 16:00 17:30 1.50 COMPZ RPCOM PULL P Break out cable from penetrators. Break out and LD tubing hanger. Breakout hoses and valves. 17:30 00:00 6.50 6,210 2,850 COMPZ RPCOM PULL P POOH W/ 3-1/2" ESP Completion 6/26/2010 Pulled & Lay down 3-1 /2" ESP Completion. MU & RIH w/ Washover BHA Down to top GLM @ 6259'. POOH S/B Drill Pi e & Collars to surface. UD BHA # 1 & Start Makin U BHA #2. 00:00 05:00 5.00 2,850 0 COMPZ RPCOM PULL P Continue POOH, UD 3-1 /2" ESP Com letion. 05:00 08:30 3.50 COMPZ RPCOM PULD P At Surface With ESP. Break Apart ESP Section and LD same. 08:30 09:30 1.00 COMPZ RPCOM OTHR P Clean and clear rig floor. Finish tieing u cable on s ool. 09:30 10:30 1.00 COMPZ RPCOM OTHR P Load out ESP equipment. Load Baker fishin tools for clean out run. 10:30 11:00 0.50 COMPZ RPCOM OTHR P Install wear ring. 11:00 12:30 1.50 COMPZ FISH PULD P PU BHA #1 for clean out run (wash over fish) consisting of Washover shoe, 2 jts Wash pipe, Boot basket, BS, Oil Jars, 9 drill collars. 12:30 13:00 0.50 COMPZ FISH CIRC P Stopped MU head pin, circulated 00 bbls 10.0 # brine to et oil ca off. Page 2 of 9 l 1 J • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 17:00 4.00 0 6,209 COMPZ FISH TRIP P Continue RIH picking up 3 1/2" drill pipe. On bottom and tagged up @ 6209' 17:00 17:30 0.50 6,209 6,256 COMPZ FISH WASH P Up wt 130K, Dwn wt 105K, Rot wt 115. Pump @ 6 BPM w/1000 psi. Washed down to 6256', to ed GLM. 17:30 18:30 1.00 6,256 6,202 COMPZ FISH CIRC P PU above fish to 6202' Circulate hole clean. Pump Hi-Vis sweep and followed with filtered 110 bbls 10.0# brine. Seen Hi-Vis Shakers. 18:30 20:00 1.50 6,202 6,202 COMPZ FISH CIRC P Pump 210 bbls of Filter 10.0 KWF around @ 3 bpm @ 270 psi. Blow down TD. 20:00 00:00 4.00 6,202 86 COMPZ FISH TRIP P POOH w/ 3-1/2" Dp and BHA #1 F/ 6202'. 6/27/2010 RIH with Rattler fishing Assembly down to top of stub @ 6209' and Engage fish and started jarring and runnin the Rattler at different rates until fish worked free. Started POOH S/B Drill i e. 00:00 00:30 0.50 86 0 COMPZ RPCOM PULD P Finish Laying down BHA #1. Pick-up Fishin ass u to floor. 00:30 01:30 1.00 0 51 COMPZ RPCOM PULD P PJSM w/Baker.MU Fishing BHA #2. 01:30 02:00 0.50 360 360 COMPZ RPCOM CIRC P Stop & Circulate thru RATTLER to make sure tool is working before oin an dee er. 02:00 06:00 4.00 360 0 COMPZ RPCOM CIRC T Unable to get the RATTLER tool To Rattle. Dispatch Warehouse support to Baker Fishing shop for another Rattler tool. Try several more times pumping and reversing to get tool to function. 06:00 07:00 1.00 0 COMPZ RPCOM PRTS T Unload second rattler tool. MU and ran just below surface. Pumped down Rattler tool 1/2 BPM, Tool pressured up to 1850 psi no action in tool. Bled down tool, reverse circulated through tool, starting pressure was 380 psi, pumped 5 bbls through tool. Pressure came down to 250 psi. Pumped down tool again, pressured up to 2000 psi. Shut down pump pressure bled off slowly. Bled down tool, reverse circulated through tool again pressureed up to 250 psi. Pumped 10 bbls through tool lost 60 bbls to formation. Attempted to pump again down Rattler tool, pressured to 2000 si, tool bled to 1430. 07:00 08:30 1.50 COMPZ RPCOM TRIP T Broke off tool, broke out top sub and valve assembly. Very little debris found in screen, 1 small piece of scale. Cleaned up and re-assembled tool. 08:30 09:30 1.00 COMPZ RPCOM TRIP T Run tool just below surface again. Tried pumping through Rattler tool again with same results 2000 psi. Bled off ressure. LD tool. Page 3 of'9 l Time Lo s ..Date From To Dur S. De th E. De th_Phase Code Subcode T Comment 09:30 11:30 2.00 0 6,083 COMPZ RPCOM TRIP P MU BHA # 3 consisting of Overshot, safety jt., ported sub, original Rattler tool, BS, Oil jars, 9 drill collars, Intensifier and pump out sub. RIH on 3 1/2"drill i e to 6083' 11:30 13:00 1.50 6,083 6,083 COMPZ RPCOM SLPC P Slip and cut drill line 13:00 16:30 3.50 6,209 6,209 COMPZ RPCOM FISH P Up wt 130K, Dwn wt 105K. RIH and latched onto fish with overshot Cc~ 6209'. PU 50 over wt and set jars off twice with no movement. Start pump @ 2BPM w/1560 psi. Pulled 50 over wt and set jars off and Rattler Tool started working. Continued rattling and jarring for 1 1/2 hrs, fish came loose and dragged up hole 17' and stopped. Continued rattling and jarring and fish came free. Pulled up hole with string wt only for 40'. Lowered back down and tagged at same spot 6209'. Pulled up to next connection, shut off pump. Dropped ballrod and sheared out pump out sub. 16:30 17:30 1.00 6,209 6,209 COMPZ RPCOM CIRC P Monitored well and had small flow tappered off to 0. Circulated bottoms up. Shut pump down, monitored well. Ve small flow but to ered to 0. 17:30 18:00 0.50 5,660 5,660 COMPZ RPCOM TRIP P Pulled 5 stands. Monitored hole fill and well swabbin . 18:00 19:00 1.00 5,660 5,660 COMPZ RPCOM OWFF P Shut in well for 30 mins. Watch for psi increase. Seen 10 psi in 30 mins. Open well and bleed down to trip tank. Getting 2 bbls every 10 mins, Well still trying to flow. Batch up 30 bbls of 10.2 KWF. 19:00 21:00 2.00 5,660 5,660 COMPZ RPCOM CIRC P Circulated 30 bbl of 10.2 ppg follow by 20 bbls of 10.0 ppg KWF. Pump 10 bbls of 10.2 ppg out pump & sub into annular. Shut in & bullheaded 10.2 ppg down to formation, leaving 20 bbl left in Drill Pipe. Open well and check for flow. No pressure or flow surface. 21:00 21:30 0.50 5,660 5,180 COMPZ RPCOM TRIP P Pulled 5 stands. Monitor well for flow. Still no flow, Lost 2.6 bbls from trip tank after 5 stands. 21:30 00:00 2.50 5,180 2,082 COMPZ RPCOM TRIP P Continue w/ tripping operation, checkin for flow eve 5 stands. 6/28/2010 Recover Upper cut section of 3-1/2" Completion from 6,335'. RIH w/ washover assembly and wash down from 6209' to to of GLM 6386'. MU & RIH w/ Fishin Assembl . 00:00 01:30 1.50 2,082 146 COMPZ RPCOM TRIP P Continue to POOH With Fish. 01:30 02:30 1.00 146 0 COMPZ RPCOM PULD P OOH.Was able to Retrieve Cut Section from 6,355'. UD Fishing BHA. Page 4 of 9. • r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 04:30 2.00 0 0 COMPZ RPCOM PULD P Lay Down Fish & Blast Joint Section. Clean Rig Floor. Gas Lift Mandrel Pulled @ 6,255' was wash out in two places inside the pocket. Several of Blast 'oint was broken. 04:30 05:30 1.00 0 0 COMPZ RPCOM PULD P Pick-Up Clean Out Assembly to Rig Floor. 05:30 07:00 1.50 0 0 COMPZ RPCOM PULD P MU Washover Shoe Assembly, to washover tubing stub. RIH on drillpipe to top of 31/2" tubing stub. Runnin over as we run in. 07:00 08:30 1.50 0 0 COMPZ FISH CIRC P Stop and circulate crude off top of hole to minimize the mess. Change out ESP spool and install) empty s ool while circulatin . 08:30 10:30 2.00 0 6,209 COMPZ FISH TRIP P Continue RIH w/washover assy. to 6209'. Up wt = 125K, Dwn wt = 105K, Rot wt = 115K 40 T = 3K. 10:30 11:00 0.50 6,209 6,386 COMPZ FISH WASH P Wash down F/6209' to 6386' Tag top of GLM @ 6386' pumping @ 4 BPM, 470 si, 40 RPMs. 11:00 15:30 4.50 6,336 6,386 COMPZ FISH CIRC P CBU 6 BPM 780 psi Pumped sweep @ 6 BPM. SD monitor well, small flow. Weight up from 10.0 ppg to 10.2 and circulate around. 15:30 19:00 3.50 6,386 717 COMPZ FISH TRIP P PJSM. POOH standing back drill i e and LD Washover BHA #4. 19:00 19:30 0.50 717 717 COMPZ FISH CIRC P Circulate 20 bbls down & out to Kill Tank, clean crude top off of good fluid.6/D Lines 19:30 20:00 0.50 717 0 COMPZ FISH TRIP P Continue to POOH from 717' 20:00 21:00 1.00 0 0 COMPZ FISH PULD P R/B Drill Collars. UD BHA #4. MT Boot basket, clean floor and load tools. Had 3 gallons of sand and scale inside basket. 21:00 22:30 1.50 0 339 COMPZ FISH PULD P PJSM. MU "Rattler" BHA #5 22:30 00:00 1.50 339 5,179 COMPZ FISH TRIP P RIH w/ DP & BHA #5 6/29/2010 Fish lower section of Completion. Monitor Well and observe a slight flow. Weight up to 10.2 ppg. Circulate Well. Monitor Well static. POOH. LD BHA and Fish. RIH with 7" Casing Scraper and Mule Shoe Joint. Wash down to Packer at 6,410-ft. Continue down to D-Nipple at 6,425-ft. Circulate Well. POOH and LD Casin Scra er and Mule Shoe Joint. Pre for S-Llne O s. 00:00 01:00 1.00 5,179 6,314 COMPZ FISH TRIP P Cont in hole from 5179' to 6314'. Up Wt=125k / Dn Wt=110k. 01:00 03:00 2.00 6,314 6,269 COMPZ FISH FISH P Engage top of fish @ 6,361' & stack out on fish to 6,365' with 10k down. Rattled & Jarred @ 2bpm , 1500 psi and worked fish up & down from 110k, 150k,175k and up to 190k . Able to move fish 6' while working the Rattler and Fish came free. Had a total of 11 'ar hits. Page 5 of 9 ~~ • Time Lo s Date From To Dur S. De th E. De th Phase Code 5ubcode T Comment 03:00 04:00 1.00 6,269 6,269 COMPZ FISH CIRC P Drop Dart and shear Pump out sub. Build Hi-Vis sweep.Monitored well and seeing small flow .weight up KWF to 10.2 ppg. Inspect Derrick & Top Drive, while building sweep & Monitorin well. 04:00 06:30 2.50 6,269 6,269 COMPZ FISH CIRC P Start Circulating 30 bbl Hi-Vis @ 3 bpm, 750 psi. Let sweep turn the corner and increase pump rate to 5 b m with 960 si. 06:30 12:30 6.00 6,269 0 COMPZ FISH TRIP P Monitor well, static. Start POOH S/B Drill Pipe & Drill Collars. Hole fill for 5 stands calculated = 2.7 bbls Well taking 6.7 bbls. LD Rattle tool and fish. Recovered all of anticipated fish, 5' cut off 3 1/2" tbg. Blast jt, 3 1/2" pup jt, GLM, 31/2" pup jt and Otis Strai ht Slot Locator w/Mule Shoe. 12:30 15:00 2.50 0 6,425 COMPZ FISH FCO P MU and RIH w/BHA # 6. 16' x 2 7!8" mule shoe jt, 7" casing scraper, BS, Oil 'ars and 9 drill collars. 15:00 15:30 0.50 6,425 6,425 COMPZ FISH FCO P Up wt = 127K Dwn wt = 107K,Rot wt 118K 40 RPM Rot Torque 3K. Pumping 4 BPM @ 370 psi. Wash down from 6320' went into packer @' 6410' Tagged fill in packer @6418'. Washed down to'D' Nipple @ 6425'. Reciprocated through packer to clean out. LD sin le. 15:30 17:00 1.50 6,425 6,425 COMPZ FISH FCO P Pumped Hi-Visc sweep around to clean up at 4.0 bpm/400 psi. MOnitor Well. 17:00 21:30 4.50 6,425 0 COMPZ FISH FCO P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Stand back Drill Collars. Lay down 7" Casing Scraper and Mule Shoe Joint. Clear and clean floor. 21:30 00:00 2.50 0 0 COMPZ EVALWE SLKL P PJSM. Prep for S-Line operations. Nipple down Flow Nipple. Nipple up 7" OTIS Thread Shooting Flange. Spot S-Line Unit. Make-up 7" x 15-ft Riser. 6/30/2010 Rig up S-line and tag fill at 6,566' slmd. Set CA-2 Plug in "D" Nipple. Set Catcher Sub. Record PDS Caliper Log data. RIH with Test Packer and verify integrity of the OTIS WD Packer. Good. Pick up 3 1/2" Lower Com letion and be in RIH on 3 1/2" Drill Pi e. 00:00 02:30 2.50 0 0 COMPZ EVALWE SLKL P PJSM. Make-up Lubricator. Make up S-Line Tools. Rig up complete. Pressure test at 250/1000 psi. Good. Page 6 of 9 • ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 03:30 1.00 0 6,566 COMPZ EVALWE SLKL P RIH with a 2.60" Swedge and Brush. Entered top of the OTIS Packer at 6,410.-ft with no problems . Found the "D" Nipple at 6,430-ft slmd (6,425-ft rkb). Brush the Nipple profile several times. Continue RIH. Found top of fill at 6,566-ft slmd (-6,561-ft rkb). Bottom Perforation is at 6,530-ft. Should have ~31-ft of Sum .POOH. 03:30 04:30 1.00 0 6,425 COMPZ EVALWE SLKL P Pick-up a 2.75" CA-2 Plug. RIH and set in the "D" Nipple at 6,425-ft. with no roblems. POOH. 04:30 05:30 1.00 0 6,418 COMPZ EVALWE SLKL P Pick up Catcher Sub. RIH and set with the to at 6,418-ft slmd. POOH. 05:30 09:30 4.00 0 6,410 COMPZ EVALWE SLKL P RIH w/ PDS Memory Caliper, CCL & Gamma Ray and log from 6410' to surface.. RDMO slickline. 09:30 12:00 2.50 6,410 0 COMPZ RPCOM NUND P ND shooting flange. NU riser. 12:00 15:30 3.50 0 6,395 COMPZ EVALWE TRIP P MU Baker Retrievamatic test packer and RIH on drill i e 15:30 17:30 2.00 6,395 6,395 COMPZ EVALWE PRTS P Set Baker Retrievamatic test packer @ 6395' (center of element). MU head pin and chart recorder. Pressure test to 2500 psi for 10 min. (good test). Release packer. Move test packer up hole and reset @ 6280'. Pressure test IA (backside) to 1250 psi and pumped into ?hole @ 2 BPM, 5.5 bbls. Shut down. Pressure bled off to 1050 in two min. OA pressure 50 psi. Released test packer and move up hole to 6250'. Pressured up to 2500 psi. Held for 30 min. OA ressure 50 si. 17:30 21:30 4.00 6,395 0 COMPZ EVALWE PRTS P Release Packer. Trip out from 6,395-ft, standing back 3 1/2" Drill Pipe in Derrick. Lay down 4 3/4" Drill Collars in Pi a Shed. 21:30 23:00 1.50 0 0 COMPZ RPCOM PULD P Clear and clean floor. Organize and perform final inspections of the 3 1/2" Lower Com letion Jewel 23:00 00:00 1.00 0 48 COMPZ RPCOM PULD P PJSM. Begin to pick ug the 3 1/2"_ Lower Com letion as_follQV~Halco Straight Slot Locator Seal Assembly, 3 1/2" x 2.813" Sliding Sleeve Assembly (SS in closed position), 4 1/2" Blast Joint. 7/01 /2010 Sting into OTIS WD Pkr. Set Baker FHL Pkr. Test Tbg and FHL Pkr. Shear PBR. LD Drill Pipe. Run Upper 31/2" Gas Lift Completion on 3 1/2" Tbg. Locate PBR and space out Upper Completion. Land Tubing Han er. Dis Well w/Cory Inhib Sea Water. Page T of 9 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 48 459 COMPZ RPCOM PULD P Continuing to pick up the 3 1/2" Lower Completion as follows: XO Pup Joint, 3 Joints of 3 1/2" 9.3 Ib/ft L-80 IBTM SCC Tbg w/Blast Rings spaced out to cover perforations, XO Pup Joint, 3 1/2" x 1 1/2" GLM Assembly w/Dummy Valve., 1 Joint of 3 1/2" 9.3 Ib/ft L-8- 8rd EUE Tbg, Baker 7" x 3 1!2" FHL Packer, Baker PBR, Baker Seal Assembly Locator w/ Pu Joint. 01:30 04:30 3.00 459 6 COMPZ RPCOM TRIP P Run the 3 1/2" Lower Completion section on 3 1/2" Drill Pipe from Derrick. UP weight = 115K. Down Weight = 107K. Enter the OTIS WD Packer with Seal Assembly at 6,410-ft . No problems. Set down 5K to confirm locate. Pick up to neutral weight. End of Seal Assembly/Mule Shoe inside Packer Bore at 6,414-ft). Center of element on FHL Packer set @ 6196'. Top of PBR 6176'. 04:30 06:00 1.50 6,414 6,414 COMPZ RPCOM PACK P Pressure up on Drill Pipe and saw Packer set at 1,800 psi. Increase pressure to 2,500 psi and test x 5 minutes. Bleed pressure to "0" psi. Pressure up on Casing/Packer to 2,500 psi x 10 minutes. Both test good and recorded on chart. Bleed pressure from IA. Pressure back up on Drill Pipe to 1,500 psi. and shear PBR at 130K. Good. Prep to POOH and la down Drill Pi e. 06:00 12:30 6.50 6,414 0 COMPZ RPCOM PULD P POOH Laying down drill pipe and kicking out of pipe shed. LD seal assembl . 12:30 14:30 2.00 0 COMPZ RIGMN? SLPC P Slip and cut drill line. 14:30 15:00 0.50 COMPZ RPCOM OTHR P Pull wear ring. 15:00 15:30 0.50 COMPZ RPCOM OTHR P Service Top Drive, Grease Crown and Blocks 15:30 16:00 0.50 COMPZ RPCOM RURD P Rig up floor to handle 3 1/2" Tubing 16:00 22:00 6.00 COMPZ RPCOM PUTB P Pickup 3 1/2" Gas Lift Completion as follows: Pick up Baker Seal Assembly Locator. Single in with 3 1/2" 9.3 Ib/ft L-80 EUE 8rd-M Tubing. Add Camco 3 1/2" x 1 1/2" MMG GLMs and a 3 1/2" x 2.875" DS Ni le er ro ram desi n. Page 8 of 9 • Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 22:00 23:00 1.00 COMPZ RPCOM PUTB P Up Weight = 82K. Down weight = 79K. Bring charge Pump on line at 70 psi x 0.5 bpm. Ease in hole. Enter top of PBR at 6,175-ft. Pressure increased to 250 psi. Shut down Charge Pump. Swallow the length of the Seal assembly and set down on Locator Sub (5K). Pick up to string weight plus 7-ft and mark Tubing. Figure out space out. Lay down the required amount of Tubing. Make up 18 -ft of Pup Joints. Pick up Jt #195 and the Tubing Han er/Pu Joint Assembl . 23:00 00:00 1.00 COMPZ Displace the 10.2 Ib/gal Brine in wellbore with Corrosion Inhibited Sea Water at 4.0 b m/520 si. 7/02/2010 Test Upper Completion. ND BOP Stack. 00:00 01:30 1.50 COMPZ RPCOM PRTS P Drain BOP Stack. Land Tubing Hanger. RILDS. Rig up test e ui ment. 01:30 03:00 1.50 COMPZ RPCOM PRTS P PJSM. Test Tubing at 2,500 psi x 15 minutes. Good. Bleed Tubing down to 1,500 psi. Pressure test Casing at 2,500 psi x 30 minutes. Good. Bleed Casing pressure down to "0" psi. Bleed Tubing pressure down to "0" psi. Pressure back upon the Casing and saw the SOV shear at 2,250 psi. Pump through SOV to confirm communications. 03:00 06:00 3.00 COMPZ RPCOM NUND P Set BPV. Rig down lines. Remove 3 1/2" Pipe Rams and install 4 1/2" __ Pipe Rams. Nipple down BOP Stack and set back on stum . 06:00 08:30 2.50 COMPZ RPCOM NUND P NU tree. Change configuration of valves. 08:30 09:00 0.50 COMPZ RPCOM PRTS P Test tubing hanger void 250/5000 psi. Held for 10 min. Good 09:00 11:00 2.00 COMPZ RPCOM NUND P Pull BPV, setTWC. re- configure tree as per Pad Operator. Test tree 250/5000 si. 11:00 14:00 3.00 COMPZ RPCOM FRZP P RD test equip. RU circulating hoses and LRS. Press test lines to 2500 psi. Freeze protect well with 82 bbls diesel down IA and up tubing. ICP 400 @ 2 BM. STP 400 @ 2 BPM. Let U-tube for 1 hr. 14:00 16:30 2.50 COMPZ RPCOM NUND P Blow down circulataing lines and lines to Kill tank. Break down hard lines and Handy-Berm. Set BPV secure well. RDMO. Clean cellar with Super Sucker. Release Nordic 3 ri 16:30 hrs 7-2-2010 Page 9 of 9 ' ~ ~ S !HELL !OG TRAIVSMlTTAL ~--•, PrtoAcrivE Dinynosric SeRVicFS, INC. To: Aorcc Christine ,-$(~.cs,r{z2~ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 30-Jun-10 3B-14 1 Report/ EDE 50-029-21287-00 2j (~5-_~~ I ~ n Signed : ~~ Print Name: ~~w ~ ... ~9 . ~UL 2 ~ 2010 Date I~sioi~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAX: (907)245-88952 E-MAIL : pdsanclt©rage(a~memorvlog.cam WEBSITE : www.rnemorylog.c®m C:\Documents and Settings\Diane Williams\Desktop\Tcansmit_Conoco.doc2c • i Memory f1~ult~Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 36-14 Log Date: June 30, 2010 Field: Kuparuk Log No.: 7422 State: Alaska Run No.: 1 API No.: 50-029-21287-00 Pipet Desc.: 7" 26 Ib. HF-ERW BTC Top Log Intvl1.: Surface Pipet Use: Production Casing Bot. Log Intvll.: 6,402 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into a Schlumberger Cement Bond Log (10-April-85). This log was run to assess the condition of the 7" production casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 7" production casing logged is in good to poor condition with respect to corrosive and mechanical damage. A hole is recorded in joint 158 (6,265'), the joint immediately above the upper perforation interval. Cross-sectional wall loss of 26% is recorded in the area of erosion opposite the hole in joint 158. Wall penetrations from 20% to 47% are recorded throughout the remainder of the casing logged. Recorded damage appears isolated pitting, with intermittent lines of corrosion and general corrosion. Although the caliper recordings indicate scattered deposits throughout the log interval, particularly in the vicinity of the pertoration intervals, no significant I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS Hole (100%} Jt. 158 @ 6,265 Ft. (MD} Isolated Pitting (47%) Jt. 10 @ 394 Ft. (MD} Isolated Pitting (47%) Jt. 153 @ 6,108 Ft. (MD) Isolated Pitting (40%) Jt. 4 @ 141 Ft. (MD) Isolated Pitting (36%) Jt. 147 @ 5,850 Ft. (MD} MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Erosion across hole ( 26%) Jt. 158 @ 6,265 Ft. (MD) No other significant areas of cross-sectional wall loss (> 10%) are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the production casing logged. Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: R. Overstreet/L. Hinkle ProActive Diagnostic Services, Inc. f P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS`~?memorylog.com Prudhoe bay Field Jffice Phone: (907j 659-2307 Fax: (907j 659-2314 i~~-aay i9~~~- • Correlation of Recorded Damag Pipe 1 7. in (22.6' - 6362.6') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 3B-14 Kuparuk Con~mPhillips Alaska, Inc. USA June 30, 2010 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 23 20 ~ I 80'I 40 1591 60 2381 O a~ ~ 80 3177 ,i ~ .~ z i= ~ Q- a o p 100 3980 120 4782 1411 5565 1611 6321 161 6363 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 161 • • PDS Report Overview ~,. ~~, Body Region Analysis Well: 3B-14 Survey Date: June 30, 2010 Field: Kuparuk Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade &Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f HF-ERW BTC 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 150 100 50 ~ 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 160 pone. 0 102 28 25 2 3 loss 109 49 1 1 0 0 Damage Configuration (body ) 80 60 4J I I 20~ i p - - =' `- isolated general line ring hole /puss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 70 63 1 5 0 1 Damage Profile (% wall) ~ penetration body __,;, metal loss body 0 50 1 51 Bottom of Survey = 161 100 10 `I 151 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf HF-ERW BTC Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 3B-14 Kuparuk Conoco Phillips Alaska, Inc USA June 30, 2010 Joint No. Jt. Depth (Ft.) I'r~n. Upset (Ins.'} Pen. Body (Ins.) Pen. °~~ ~~tcLrl Ie»s °-~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 23 i' 0.02 7 ~' 6.29 2 60 U 0.04 10 ? 6.27 Shallow ittin . 3 99 f! 0.10 2f3 ~' 6.25 Isolated _ ittin . 4 139 ti 0.14 4i1 6.28 Isolated ittin . 5 176 ?i 0.10 27 6.28 Isolated ittin . 6 215 i? 0.09 23 6.28 Isolated ittin . 7 256 i? 0.13 ~5 6.27 Line corrosion. 8 297 i~_i)`i 0.13 3`~i 6.26 Line corrosion. Lt. Deposits. 9 334 0.13 i5 6.25 Isolated ittin Lt De osits. 10 373 i' 0.17 4i 5 6.25 Line corrosion. 11 414 i!.i?-a 0.13 i7 6.24 Line corrosion. Lt. De osits. 12 455 ,? 0.04 12 6.26 Shallow ittin . 13 498 a 0.03 8 2 6.25 14 542 i ~ 0.02 7 ? 6.25 15 585 t? 0.02 6 I 6.28 16 627 !? 0.02 t, 6.27 17 670 U 0.03 ~~ _' 6.29 Shallow ittin ~ 18 714 U 0.03 ~~ I 6.27 Shallow ittin . 19 758 t! 0.03 8 . 6.27 ~ 20 801 0.02 (, 6.27 21 844 i? 0.05 I i 1 6.25 Shallow ittin . 22 888 i? 0.11 3(1 Z 6.29 Isolated ittin . 23 925 t? 0.08 2~' ? 6.27 Isolated ittin . 24 967 i? 0.04 1~ ~' 6.29 Shallow ittin . 25 1004 !! 0.05 13 I 6.27 Shallow ittin . 26 1042 '? 0.09 25 1 6.28 Isolated ittin . 27 1083 i! 0.09 24 ? 6.27 Isolated ittin . 28 1124 !! 0.04 It) _' 6.29 Shallow ittin . 29 1165 i? 0.05 i t _' 6.29 Shallow ittin . 30 1201 ~. ~ 0.03 7 1 6.27 31 1238 ~! 0.05 14 1 6.28 Shallow ittin . 32 1278 i! 0.05 I a I 6.28 Shallow ittin . 33 1315 !? 0.02 6 I 6.28 34 1356 U 0.03 9 i 6.28 Shallow ittin . 35 1397 i? 0.04 11 I 6.29 Shallow ittin . 36 1438 ~! 0.03 7 I 6.28 37 1476 0.03 8 i 6.28 ~ 38 1512 ~ ! 0.01 ~ I 6.29 39 1551 0.01 ~ I 6.29 40 1591 +! 0.04 i I I 6.29 Shallow ittin . 41 1632 U 0.01 ~ I 6.28 42 1671 i? 0.02 6 1 6.28 43 1712 U 0.02 6 2 6.27 44 1751 i? 0.02 6 I 6.27 45 1791 i? 0.01 3 1 6.30 46 1832 `! 0.04 1 U i 6.29 Shallow ittin . 47 1869 i? 0.02 b I 6.29 48 1907 ~? 0.02 6 I 6.29 49 1948 !? 0.02 c, 6.29 ~ 50 1989 i? 0.02 (~ I 6.26 _ Penetration Body Metal Loss Body Page 'I • PDS REPORT JOINT TABI Pipe: 7. in 26.0 ppf HF-ERW BTC Well: Body Wall: 0.362 in Field: Upsct Wall: 0.362 in Company: Nominal LD.: 6.276 in Country: Survey Date • !CATION SHEET 3B-14 Kuparuk ConocoPhillips Alaska, Inc USA June 30, 2010 Joint No. Jt. Depth (Ft) !'~~n. C ~i»ct (li~~.) Pen. Body (Ins.) Pen. % :Vlc(~I I o5s °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2028 U 0.02 (~ I 6.27 52 2065 ~! 0.02 G 1 6.28 53 2106 !+ 0.02 t~ 1 6.28 54 2147 t! 0.03 f'.• I 6.27 55 2187 +~ 0.03 ~! 6.26 Shallow ittin ' 56 2224 !! 0.03 ~! I 6.27 Shallow ittin . 57 2265 ! ~ 0.03 ~) ,_' 6.28 Shallow ittin ~ 58 2305 i+ Q03 i 1 6.26 59 2342 :' 0.02 1 6.27 ~ 60 2381 ~! 0.02 6 1 6.28 61 2420 ~ i 0.02 G 1 6.27 62 2459 +1 0.03 7 I 6.28 63 2500 U 0.03 7 I 6.28 64 2541 ~! 0.02 (~ 6.28 65 2582 +? 0.04 1 1 6.28 Line shallow corrosion. 6b 2622 +! 0.02 E, I 6.28 67 2664 !) 0.02 (~ I 6.28 68 2704 +) 0.02 ~ I 6.27 69 2743 +) 0.01 4 1 6.28 70 2783 !! 0.01 1 6.27 71 2821 +! 0.01 4 I 6.28 72 2859 0.02 0 i 6.28 73 2900 ~:; 0.03 - I 6.27 74 2941 !! 0.01 ~~ ~ 6.24 75 2981 ! ~ 0.02 r, i 6.28 76 3022 ~! 0.01 ~t i 6.29 77 3059 U 0.02 ~ I 6.27 78 3099 !! 0.01 I 6.27 ` 79 3136 ~! 0.01 I 6.28 80 3177 ~! 0.01 3 i 6.29 81 3218 +! 0.02 ti I 6.29 82 3258 ! ~ 0.01 4 I 6.29 83 3297 t1 0.01 4 I 6.27 84 3334 i ~ 0.01 ~ 1 6.29 85 3375 : ~ 0.02 6 1 6.26 86 3412 !! 0.01 4 t 6.27 87 3453 i! 0.01 I 6.27 a 88 3491 t! 0.02 G I 6.28 ~ 89 3530 +! 0.01 3 . 6.2G 90 3571 i! 0.02 6 i 6.25 91 3612 0.02 6 6.27 ~ 92 3655 i 0.02 i> I 6.27 93 3699 t! 0.02 E~ I 6.27 94 3739 +! 0.01 4 I 6.26 95 3781 i) 0.02 6 1 6.26 96 3819 t) 0.03 - 1 6.27 97 3860 t! 0.04 1 U I 6.26 Shallow ittin . 98 3900 + i 0.02 6 1 6.2 7 99 3939 +! 0.03 '~ 1 6.25 Shallow ittin . 100 3980 c! 0.02 (, I 6.26 Penetration Body ~~letal Loss Body Page 2 • • PDS REPORT JOINT TABUL ATION SHEET Pipe: 7. in 26.0 ppf HF-ERW BTC Well: 3B-14 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc.. Nominal LD.: 6.276 in Country: USA Survey Date: June 30, 2010 Joint No. Jt. Depth (Ft.) !'~~n. (liriE~t iins.) Pen. Body (Ins.) Penn. % ~~1ctai I os~ ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4020 U 0.02 6 1 6.26 102 4061 U 0.02 ~ i 6.27 ~ 103 4102 ~! 0.02 ~~ 1 6.28 104 4142 ! ~ 0.03 ~ I 6.25 105 4179 !? 0.02 t, I 6.27 106 4220 U 0.03 I 6.26 107 4258 tr 0.04 It) I 6.27 Shallow ittin . 108 4299 s) 0.02 E> I 6.24 109 4339 i? 0.04 1 < I 6.27 Shallow ittin . 110 4377 c1 0.03 ti 1 6.27 1 1 1 4418 + r 0.01 .3 I 6.23 112 4459 ! ~ 0.02 ! 6.22 113 4500 i) 0.01 /ii I 6.24 114 4537 t) 0.01 i i 6.24 115 4578 s7 0.04 12 i 6.27 Shallow ittin . 116 4619 i1 0.01 4 1 6.26 117 4659 U 0.01 ~ 1 6.27 118 4700 U 0.01 a I 6.25 119 4741 (1 0.01 4 1 6.26 120 4782 it 0.05 Li I 6.26 Shallow ittin 121 4823 a 0.01 3 ~ 6.27 122 4864 (~ 0.04 1 ' + 6.25 Shallow ittin . 123 4902 t) 0.02 ~ 6.24 124 4939 (_~ 0.03 ~ 4 6.23 ~ 125 4980 ~? U.U3 - 6.24 126 5019 tr 0.04 12 6.23 Shallow ittin . 127 5060 ) 0.05 i ~1 6.25 Shallow ittin . 128 5101 +~ 0.04 i+) 6.24 Shallow ittin . 129 5141 +~ 0.04 1 ~ I 6.25 Shallow ittin . 130 5179 t) 0.04 10 1 6.24 Shallow ittin . 131 5220 !) 0.07 18 _' 6.25 Shallow ittin . 132 5258 U 0.06 1' I 6.25 Shallow ittin . 133 5296 a 0.06 16 i 6.24 Shallow ittin . 134 5332 t ~ 0.02 6 I 6.24 135 5369 t) 0.03 6.24 136 5407 n 0.06 16 I 6.24 Shallow ~ittin 137 5444 +r 0.09 ~'b I 6.24 Isolated ~ittin . 138 5485 ++ 0.10 Z9 6.23 Isolated ittin . 139 5524 t! 0.07 I ~1 ! 6.24 Shallow ittin . 140 5565 (1 0.10 ~H 6.23 Isolated ittin . 141 5606 i; 0.10 ~' 6.23 Isolated ittin . 142 5647 i i 0.06 1 (, I 6.24 Shallow ittin . 143 5689 +i 0.08 ~ 6.24 Isolated ittin . 144 5728 tr 0.11 3O 1 6.23 Isolated ittin . 145 5769 t) 0.10 <f5 ? 6.21 Isolated ittin . 146 5806 ;? 0.07 19 ? 6.22 Shallow ittin . 147 5845 t~ 0.13 36 6.24 Isolated ~~ittin . 148 5885 i! 0.09 Z5 ! 6.24 Isolated ittin . 149 5926 ~? 0.12 1 , _' 6.23 Isolated ittin . 150 5967 t~ 0.08 ~' 1 1 6.24 Isolated ittin . Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI Pipe: 7. in 26.0 ppf I-IF-LRW BTC Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: iti'ominal LD.: 6.276 in Country: Survey Date. • CATION SHEET 3 B-14 Kuparuk ConocoPhillips Alaska, Inc USA June 30, 2010 Joint No. Jt. Depth (Ft.) I'c~n. tlpsc>i (Ins.) Pen. Body (Ins.) Pcn. % ,Metal loss ,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 6004 !) 0.11 3U ! 6.23 Isolated ittin . 152 6045 U.(?7 0.10 26 I 6.24 Isolated ittin . 153 6085 t) 0.17 47 2 6.19 Corrosion. Lt. De osits. 1 S4 6126 a 0.06 1 ? 6.20 Shallow ittin . 155 6163 t) 0.07 I ~> s 6.24 Marker oint. Shallow ittina. 156 6181 ~? 0.04 1 I 1 6.19 Marker oint. Shallow ittin . 157 6199 i? 0.06 18 1 b.19 Shallow ittin . 158 6240 rl 0.37 1(10 2ii 6.03 Hole! _- 159 6281 0.42 t!?t? !!~ 6.00 Perforations. 15(l 6321 0.51 6.03 Perforatigns. - - - - ~ 161 G 3F>> I ~ (? --~ ____i i ~ O,(?1 1 r I I ~: ~! I i Penetration Body Metal Loss Body Page 4 • • ~ PDS Report Cross Sections 1 - Well: 38-14 Survey Date: June 30, 2010 Field: Kuparuk Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 26p f HF-ERW BTC Anal st: M. Lawrence Cross Section for Joint 158 at depth 6264.51 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 82 °% Tool deviation = 9 " Finger 16 Penetration = 0.37 ins Hole 0.362 iris = 100% Wall Penetration i SIDE = UP Cross Sections page 1 PDS Report Cross Sections Well: 38-14 Survey Date: June 30, 2010 Field: Kuparuk Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 2b f HF-ERW BTC Anal st: M. Lawrence Cross Section for Joint 10 at depth 394.13 ft Tool speed = 43 Norninal ID = 6? 76 Norninal OD = 7.000 Remaining wall area = 97 °% Tool deviation = 1 Finger 2 Penetration = 0.171 ins Line Corrosion 0.17 ins = 47% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ConocoPhillips i~~~~:, I. ,.: HPNGER. ESP MPNDREL, 69 CONDUCTOR, sti117 ESP MANDREL. ESP MPNDREL, 3.900 ESP MANDREL. KUP .~ 3B-14 KUPARUK RIVER UNIT PRODUCING 29.55 3.400.00 6.796.0 H251ppm) Date AnnMatian F11d Dale KB-lYd pt) Rig Release Dal 225 1/12009 Last WO. 921!1998 35.98 323/1985 rp(h ptlC) Entl Dale Annotation Last Mod By End Date 6,796.0 921/1998 Rev Reason: FISH CORRECTION TRIPLWJ 3/112009 CONDUCTOR wa„yvrnn,yu.n, SURFACE w,,,ryv... 95/8 w.nry... 8.765 ... ...y 1......r 0.0 ...,.....r....~ .... 3,312.0 .........~....~....~.. 3,262.7 .......y ...... 36.00 ~.....~... J-55 ~....a .T ....~ Casing Description S[dng 0... Bring ID ... Top IRKBI Set DepM (f... Set Depth (ND) .. . Bring ViL.. Stdrg ... S[dng lop 7hrd PRODUCTION 7 6.151 0.0 6.770.0 6,459.1 2fi.00 J-55 Tubin Strin s Tubing Desaiptlon TUBING S[dng 0... Stang ID 312 2.992 ... Top pD(B) 23.7 Set Depth (f... Set Depth (ND).. 6.170.4 5,863.6 . Stdng yh.. Stdng ... Sldng Top Thrtl 9.30 J-55 EUEBrdMOD 2,992... 6AUOE, ti,03E NIPPLE, 6,06E ESP PUMP 5 O6? Gas Separator 6,11E GEOL. B, 12? ESP MOTOR MANDREL CUT, 6,355 IPERF. PACKER,6410 SBE.6413 NIPPLE, WLEG, Comment IStn TOR dIKBI 1~8) Ill°G I Make I Model I (~ I Sero I VT~e I Type I M) rn(Ps4~ Run Dale ICOmm._I IPERF, 6 5146,530 PRODUCTION, 46,770 TD. 6.196 SI ESP Producer 3B-14 (PTD 185-024) SCP report Page 1 of 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, December 20, 2008 5:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: SI ESP Producer 3B-14 (PTD 185-024) SCP report Attachments: 36-14.pdf; 36-14 T10.jpg f Jim, ~.~~ f Z ~ Zq-~ zesz;~ ~~~ J~~ :~ 20D9 ,/ Packerless Kuparuk ESP producer 3B-14 (PTD 185-024) was reported on 7/29/08 as having experienced an ESP failure. It has been shut in and freeze protected since the ESP failure. It currently on the Nordic 3 workover schedule for the first week of April 2009. Since the well has been SI and it has no packer the IA pressure has slowly increased with time. The IA pressure has recently exceeded 2000psi which under CO 494 requires notification to the AOGCC. The T/I/O pressures are currently 2100/2100/30 (see the attached TIO plot). Our current plans are to continue to leave the well SI. monitor it closely. and pump a full kill lust before the workover in April. The well will also be added to our internal Weekly SCP report and already resided on the Quarterly SCP report submitted to the AOGCC each quarter. Please advise if this plan is not acceptable. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «3B-14.pdf» «3B-14 TIO.jpg» 12/24/2008 ,~- COCIUtO~~tl~~ijJS wee c fia_ _ HANGER, ESP OREL, 2,683 ESP )REL, 3,900 ESP JREL, 4.214 ESP GAUGE, ESP PU 6, Gas Sepan fi, ESP MOTs IPERF, • 6,294-6,350 IPERF, 6,3]4-6,380 IPERF, . 6,4]0-6,502 IPERF, 6,514b,530 MANDREL, _ 6,522 GUT, 6,622 MANDREL, 6,656 68E, 6,660 NIPPLE, 6,692 I I~ WLEG, 6,]00 PRODUCTION, °I o s,]]o rD. 6,no -- KUP ~ 3B-14 WeII Attributes Max Angle 8 MD STD .. ._. _., - ~ W IIb re APUUWI Flaltl Name We1 15tat PFON InI Type Inel t') MUINn61 Act tf[m (NKB) ,. 500292128700 KUPARUK RIVER UNIT PR OD 29.5 5 3,400.00 6,7700 Ani C mment H2S (ppm) SSSV. NONE 225 Date 7/1/2008 An Cation End Date Last WO: 9/21/1998 KB.Grd (N) 35.98 Rig Releau Date 3/23/1985 Annotation Depth (ftKB) End Date Last Tag: 6,796.0 9/2111998 Casing Strings Annotaion Rev Reason: Comment No te changed for WV 8.1 End Date 1/25/2007 Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Sat Depth (ND) ... String Wt... String ••• Sbing Top Thrd CONDUCTOR 16 15.062 0.0 117.0 117.0 62.50 H-40 Casing Deaeription String 0... String ID ... Top (ftK8) Sat Depth (f... Sal Depth (ND) ... String Wt... String ... String Top Thrd , SURFACE 95/8 8.765 0.0 3 312.0 3 262.7 36.00 J-55 Casing Description String 0... Slring ID ... Top (ftK8) , Set Depth (/... , Set Depth (TVD) ... String WL.. String ... String Top Thrd PRODUCTION 7 6.151 0.0 6,770.0 6459.1 26.00 J-55 Tubin Strin s _ _ cubing Deauiplion ~) Sfri g ID ... TUBING ~ 2_I 2992 ~ Top (ftKB) ; 23.7 ~ Set Depth (f... 6.170.4 ~ Sat D pth (ND) 58.63.6, ,ig W~String .. 'd.30 _ I J-55 _ Str g Top Thrd EU_ E8rdMOD Com letion Details _ Top Depth (ND) Top Inel Top tftKB) (NKB) (°) Item Descriptio n Commsnt ID (inl ..e.... ..e ..... ..... e... .. ...r r..,..,r .... ,..r,... t.... .,. ...r ...... .a .. ....e ...r ...... TUBING FISH 3 1!2 2.992 6,461.0 6,700.0 6 389.5 9 20 J-55 Com letion Details ~~~yyy T p Depth I I (ND) ~~Top lncll F ~~ ~. t F .~„ y `i ~` ~I _ i .~ I ~~ Ih 6 ~I i ~. i Pe_r_F_o_ratio_n_s_ _ Top (ND) Btm (ND) Top tftKB)~Btm tNKBI ~(ftKB) (NKB) I Zone & Safety __ - -- Shot Dens Date (sh... 11/5/1998 NOTE: Run Standing valve or valve catcher in CAMCO D Nipple BEFORE wireline work. 12/30/2003 NOTE: WAIVERED WELL: T x IA COMMUNICATfON, ESP WELL NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Top Depth Top (ND) Inel OD Stn Top (ftKB) (NKB) (') Maka Motlel tin) Serv Valve Type Latch Type Port Size (in) i TRO Run (psi) Run Dgte Comm... 1 89.1 89.1 0.31 CAMCO KBMM 1 ESP OV BKP 13/16 0.0 9/28/1998 2 2,662.9 2,660.5 11.53 CAMCO KBMM 1 ESP DMV BK 0 0.0 9/21/1998 3 3,900.0 3,775.6 29.08 CAMCO KBMM 1 ESP DMY BK 0 0.0 9/21/1998 4 4,214.2 4,050.7 30.00 CAMCO KBMM 1 ESP DMY BK 0 0.0 9/21/2008 5 5,988.9 5,683.9 9.07 CAMCO KBMM 1 ESP DMY BK 0 0.0 9/28/1998 .~ ti/' I ~. KRU 3B-14 PTD 185-024 12/20/2008 SI ESP Producer Tn~~ Pi~~ - sg•~~ ~ooo goo 1500 ~ 1000 500 0 - ++ 20-Sep-08 03-Oct-08 16-Oct-08 29-Oct-08 11-Nov-08 24-Nov-08 07-Dec-08 Date 150 ~. a~ 100 ~ 0 50 0 KRU 3B-14 (PTD 185-024) ESP Failure Notification Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, July 29, 2008 4:25 PM 70: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: KRU 3B-14 (PTD 185-024) ESP Failure Notification Attachments: 3B-14 Wellbore Schematic.pdf Jim/Tom, Kuparuk ESP lifted producer 3B-14 (PTD 185-024) experienced an ESP failure on 7/24J08 at 20:50 hours. Diagnostics indicate the ESP has shorted to ground after 9 years and 10 months of service life. The pump was installed in the well on 09/19/1998 and put on production on 10/0111998, The well is currently shut-in and we are evaluating options to return to production. 3B-14 was not permitted with gaslift as a backup so should we decide to convert to gaslift we will request permission by submitting a 10-403. Attached is the most recent wellbore schematic. «3B-14 Wellbore Schematic.pdf» Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office 907-659-7224 Cell 907-943-1720 Pager 907-G59-7000 #909 7!30/2008 . ConocJPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED !4UG 1 3 200í ¡Alaska Oil & Gas Cons Cnn. . . . . "",mISSion Anchorage August 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tÌ1 Avenue, Suite 100 Anchorage, AK 99501 5CANNED AU\) 1 4: 20{)7 \<35-Dd--4' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of20". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, 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 ofform 10-404, Report of Sundry Operations. The cement top-fill operation was completed on July 27,2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner August 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ;¡;¡U~ M~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/7/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement Dumped cement date inhibitor sealant date ft bbls ft na gal 38-02 185-057 32" .4 bbls 20" 7/27/2007 4.2 8/5/2007 38-03 185-060 29' 5.2 bbls 20" 7/27/2007 4.2 8/5/2007 38-04 185-061 14' 2.5 bbls 20" 7/27/2007 4.2 8/5/2007 38-05 185-075 SF N/A SF 7/27/2007 1.7 8/5/2007 38-07 185-077 45' 6.1 bbls 20" 7/27/2007 6.8 8/5/2007 38-08 185-087 14' .5 bbls 20" 7/27/2007 2.5 8/5/2007 38-09 185-113 SF N/A SF 7/27/2007 1.7 8/5/2007 38-11 185-115 20' 2.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-12 185-116 43' 7 bbls 20" 7/27/2007 3.4 8/5/2007 38-13 185-023 43' 5.9 bbls 20" 7/27/2007 11.9 8/5/2007 38-14 185-024 11' 8.9 bbls 20" 7/27/2007 5.1 8/5/2007 38-15 185-025 57' 9 bbls 20" 7/27/2007 7.6 8/5/2007 38-16 185-026 43' 6.8 bbls 20" 7/27/2007 7.6 8/5/2007 RE: 3B-14 (PTD 185-024) ESP producer expired sundry . . Tom, Thanks for the response. A 10-403 renewal wíH not be submitted at this time for continued operation with the ESP 'as run' as it doesn't appear to be necessary. There are letters in our files documenting AOGCC approval to install the packerless ESPs by both Blair and Commissioner David Johnston. I think Jerry submitted the 10-403 for 3B-14 in 2003 to update the documentation paper trail since he was completing sundries for all the other ESPs that were being gas lifted at the time. I'll check with Jerry when he returns next month in case I've overlooked an issue that requires the additional paperwork to be submitted. 3B-14's ESP has been running continuously since installed in Sept 1998 except for the typical occasional well shutdowns. It is the last Kuparuk ESP that is still running. Marie McConnell Problem Well Supervisor 659-7224 SCANNED S EP 1 4 2005 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, September 14, 20067:59 AM To: NSK Problem Well Supv Subject: Re: 3B-14 (PTD 185-024) ESP producer expired sundry Marie, As I remember my review regarding the sundry requests, employing ESPs was approved by the Commission via a letter from Blair or the actual sundrys. You might look at the original letter from back then. Since 3B-14 continues to operate "as run", I do not see the need for a new sundry. I agree that if the pump were to fail and CAPI would desire to produce the well on gas lift that a sundry should be secured. How long has the ESP been running? I suppose there have been shut downs, but that it has apparently restarted each time. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 9/13/20065:38 PM: Tom, Reviewing data in our office, I just discovered that 3B-14 ESP producer has been operating under an expired sundry variance. Sundry variance 303-278 to document production of the well with a packerless ESP completion expired on 10/1/05. Due to an administrative oversight in our office, the sundry was not renewed last fall. This variance was missed as it was thought that only the failed ESPs on gas lift were operating under 2 year sundry variances. 3B-14's ESP is still operational. Permission to continue production with the expired sundry is requested. lof2 9/14/2006 1 :07 PM RE: 3B-14 (PTD 185-024) ESP producer ex. sundry . Is it permissible to continue production with the ESP indefinitely, or is a sundry application required to request a renewal to the original variance? If renewal is required, a sundry application will be submitted as soon as possible. Marie McConnell Problem Well Supervisor 659-7224 20f2 9/14/2006 1:07 PM Re: Failed ESP sundries Subject: Re: Failed ESP sundries Date: Mon, 10 Nov 2003 11:29:27 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jerry C Dethlefs <Jerry. C.Dethlefs@conocophillips.com> CC: NSK Problem Well Supv <N1617@conocophillips.com> Jerry, MJ and Nina: Sorry about the confusion on those wells. I went back and checked your applications as well and you are correct. I also noted in the letter that 3H-16 is mentioned at point 1 in the text, but not in the well list. I have made an edit of the original letter and can fax that to you for your files. The plans as stated in the sundry applications are appropriate for the wells. I think this is the easiest way to fix this. Thanks for reading closely. I need to improve. Tom Maunder, PE AOGCC Jerry C Dethlefs wrote: Tom: I reviewed the cover letter again as compared to the submitted Sundry Notices. As MJ mentioned below, we could re-submit the Sundry's for 3B-14 and~?.j~r correction. Alternatively, you could just correct the details on your cover letter and send that to us. We are going to attach the cover letter to each Sundry for our files and there is more detail in that than on the 10-403. Your choice, just let us know how we can help fix the discrepancy. This is just to prevent confusion in the future-- Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska ..... Forwarded by Jerry C Dethlefs/PPCO on 10/26/2003 02:40 PM ..... NSK Problem Well Supv 10/24/2003 08:40 AM To: tom_maunder@admin.state, ak. us cc: n1617@conocophillips, com@Phlllips, Jerry C Dethlefs/PPCO@Phillips Subject: Re: Failed ESP sundries Tom: While reviewing the signed 10-403's on 3B-14 (Sundry # 303-278) and 3M-14 (Sundry # 603-282), we noticed that the Commissioners comments and attached documentation appear to be miss matched. 3M-14 has a failed ESP and is currently gas lifted and 3B-14 currently has a functioning ESP, while the Commissioners comments on the 10-403's and accompanied documentation have them vise versa. Please review your copy of the Sundries and let us know how you would prefer we fix the discrepancy. We can re submitted the 10-403's if you would like. Thanks MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. 1 of 3 11/10/2003 11:29 AM ALASKA OIL AND GAS CONSERVATION CO~$SION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 \\l ~0 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 KRU 2C 16 184-202 303-275 KRU 3B 13 185-023 303-276 KRU 3A 01 185-186 303-277 KRU 3B 14 185-024 303-278 KRU 3H 04 187-076 303-279 KRU 3J 10 185-250 303-280 KRU 3M 13 187-040 303-281 ~ KRU 3M 14 187-051 303-282 Dear Mr. Dethlefs: ESP failed flowing well ESP failed flowing well ESP failed gas lifted well ESP failed ~ 12 qrv gas lifted well ESP operating ESP failed gas lifted well ESP failed gas lifted well You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3J4'~ should be allowed to continue production with no restrictions. "~- ~,~ ~%~ 2. The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configui%~t.' ' 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C-16 should be changed to be similar to the other failed ESP wells with the fluid entry Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, RandS? Ruedrich Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon r-~ Alter casing Change approved program Suspend [~ Operation Shutdown [~ Repair well [~ Plug Perforations r~ Pull Tubing [] Perforate New Pool r~ Perforate [] Variance Stimulate [~] Time Extension Re-enter Suspended Well Annular Disp. F-~ Other E~] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ [] Exploratory Stratigraphic [~ Service 5. Permit to Drill Number: 185-024 6. APl Number: 50-029-21287-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 85' 3B-14 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6796' 6485' 6688' 6377' 6207' (old packer) Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 16" 117' 117' SUR. CASING 3227' 9-5/8" 3312' 3263' PROD. CASING 6685' 7" 6770' 6459' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6294'-6350', 6374'-6380', 647o'-65o2', 6514'-653o' 5986'-6042', 6066'-6072', 6161'-6193', 6205'-6221' 3-1/2" J-55 6170' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal F~ 13. Well Class after proposed work: Detailed Operations Program [] BOP Sketch BI Exploratory r-~ Development [~] Service r-~ 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil ~-~ Gas [] Plugged [] Abandoned [] WAS CI G NJ I--I WINJ CI WDSP, I--I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name _Jerry Dethlefs Signature ~.~.~~___~ / Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date Conditions of approval: Notify Commission so that a representative may witness ISundry Number: Plug Integrity BI BOP Test ~ Other: ~,~,~.~ ~i~ h C~. ~,~"1~ '-.> Subsequent Form Required: ~0 ~ : ~'~ ' ' ....... Mechanical Integrity Test E] Location Clearance BY ORDER OF THE COMMISSION Approved by: ~"'~ ~~"~-'~~ COMMISSIONER Form 10-403 Rev,~2~,~.~,.: OOT ~ ~ ~.0[}3 :i,...~ !~ I GIN A L SEP1 6 2003 0il & Gas Co~s. Commissi0p Anchorage Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3B-14 (PTD 1850230) September 11, 2003 This application for Sundry approval for well 3B-14 (PTD 1850230) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3B-14 was originally completed in March 198~5 as a gas lifted producer. The well was re- completed with an ESP in Se~ber !998. The well continues to be produced via ESP; the p~ump is_fully o..pera.~tional. Should a workover take place in the future, a casing inspection log ~wilIbe run. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Produced fluids flow into the pump intake, up the tubing and out the wellhead to production facilities. Gas that breaks out near the pump flows up the annulus (IA) and is recombined with produced fluids via a gaslift mandrel at 89' measured depth. The well is equipped with a wellhead Safety Valve System as per regulations. Recent well test data shows the following results: WELL TEST SUMMARY REPORT f '~TOTAL FORM TOTAL PUMP DS WL LENGTH CHK FTP FTT OIL WATERI%WC (FLUID GAS GOR GLR HERTZ 3B 14 18:00 100 125 139 404 1213 ~. 75 ~1617 366 906 226 51 3B 14 18:00 100 118 139 348 1178 / 77 11526 340 976 223 51 3B 14 14:00 100 119 139 345 1189 )78 )1534 334 969 218 51 3B 14 14:00 100 108 140 350 1198 177 11548 342 978 221 51 3B 14 15:00 100 122 140 343 1207 I 78/ 1550 333 970 215 51 As per this request, ConocoPhillips intends to produce 3B-14 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ARCO Alaska, Inc. A TUBING -- (0-6170, OD:3.500, ID:2.992) GAUGE (6O38-6O39, OD:3.500) NIPPLE (6066`6069, OD:3.500) PROD. CASING (0-677O, OD:7.000, Wt:26.00) PUMP (6083-6084, OD:6.151) GAS SEPARATOR (6118-6120, OD:3.500) SEAL (6123-6124, OD:6.151) MOTOR (6136-6137, OD:6.151) JUNK (6207-6209, 0D:3.500) KRU 3B-14 3B-14 APl: 1500292128700 Well Type:I PROD PBTD: t 6796 ftKB SSSV Type: None C°mpleti°n:lOrig13/23/85 TD: 6796 ftKB Annular Fluid: Last W/O:19/21/98 Max Hole 30 deg @ 3400 I Angle:I Last Tag: 6796 Last Tag Date: 9/21/98 Angle ~. TS:I7 deg ~,, 6291 Rev Reason: COMMENTS BY VG Last Update: 11/5/98 Angle ~ TD:I6 deg ~ 6796 CONDUCTOR Size Top I Bottom TVD Wt Grade Thread 16.000 0 I 117 117 62.50 H-40 SURFACE Size Top I Bottom , TVD Wt Grade Thread 9.625 0 I I 3312 3263 36.00 J-55 PRODUCTION Size Top I Bottom I TVD Wt Grade Thread 7.000 0 I [ 6770 6459 26.00 J-55 - TUBING Size Top Bottom TVD Wt 'Grade Thread 3.500 0 6170 5863 9.30 J-55 8 RND-MOD Perforations Interval TVD I Zone Feet SPF Date Type Comment 6294- 6350 5986- 60421 C-4,C-3~C-1 56 12 5/21/85 5" Scalloped Csg Gun 120 deg. phasing 6374- 6380 6066- 60721 UNIT B 6 12 5/21/85 5" Scalloped Csg Gun 120 deg. phasing 6470 - 6502. 6161 - 6193 A-4~A-3 32 4 5/21/85 4" Carrier Cs,(] Gun 120 deg. phasing 6514 - 6530 6205 - 6221 A-2 16 4 5/21/85 4 Carrier Csg Gun 120 deg. phasing Gas Lift;MandrelsNalves:: : ; :: : :: Date Run KBMM OV 9 28 '98 ....................................... 2 2663 2661 CAMCO KB:;:M DMY 1.0 , BK 0.000 C 9 21 98 .................... 3 3900 3776 CAMCO KBMM DMY 1 0 BK 0.000 C 9 21 98 4 42!4 4050 CAM$O K~,/.lt.,1 DMY 1.0 BK 0.000 0 9 21 98 5 5989 568,; CAMCO KBMM DMY 1.0 BK 0 000 0 9 28 9.8 .eq_uip., .etc.) - JEWEL~' ............. ~D Depth TVD Type Description 6038 5732 GAUGE Baker Sentry suction gauge 6068 5762 NIPPLE CAMCO 'D' nipplew/NoGo 6083 5777 PUMP Centrilift 513Tandem Pump 6118 5812 GAS SEPARATOR Centrilift Tandem rotarygas separator 6123 5817 SEAL Centrilifttandem seal section 6136 5829 MOTOR Centrilift 562 tandem motor 418 HP Other (plugs, eq_~p., etc.) - FISH 2.867 2.750 0.000 0.000 0.000 0.000 Other {plugs, Depth I TVD Type Description I ID 6207 5900 JUNK SBE,GLM' Dtubing'n pp e,l°cat°rot s baSUbcatcher & seal assy, Otis WD pkr, Otis 0.000 General Notes Date Note 9/28/98 OV at 89' is CAMCO SBK-DF 3/8" x 7/16" OV 11/5/98 I Standing valve or valve catcher should be run in CAMCO D Nipple prior to any wireline work. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __Stimulate_ Plugging __ Pull tubing X Alter casing __ Repair well __ Perforate _ Other X Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service _ 4. Location of well at surface 109' FSL, 792' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1233' FNL, 1168' FEL, Sec. 21, T12N, R9E, UM At effective depth At total depth 1266' FNL, 1212' FEL, Sec. 21, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 6796' true vertical 6484' Effective depth: measured 6208' true vertical 5900' Casing Length Size Structural Conductor 94' 16" Surface 3289' 9.625" Intermediate Production 6747' 7" Liner feet feet feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 85' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-14 9. Permit number/approval number 85-24/398-230 10. APl number 50-029-21287 11. Field/Pool Kuparuk River fish @ 6207' (refer to note below) Cemented Measured depth True vertical depth 200 SX PFC 1 17' 117' 830 sx AS III & 3312' 3262' 450 sx Class G 500 sx Class G 6770' 6458' Perforation depth: measured 6294'-6350', 6374'-6380', 6470'-6502', 6514'-6530' true vertical 5985'-6041 ', 6065'-6071 ', 6160'-6192', 6204'-6220' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6170' Packers and SSSV (type and measured depth Otis WD perm Pkr @ 6410' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Alaska Oil & Gas Cons. Commissio, Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4~'4 Rev 05/17/89 Title Kuparuk Drilling Team Leader SUBMIT IN DUPLICATE NOTE: Old completion equipment left in hole, top of fish @ 6207'. Cut off jt (chemical cut)l GLM, 1 it. J-55 tubing, 1 jt FL4S, pup it., 4.5" blast it, pup it. GLM, pup it., Iocator sub & seal assy., Otis WD perm. Pkr, Otis SBE, pup it, D nipple, pup it. Otis ball catcher. ~ Date: 10/15/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3B-14 WELL_ID: 999268 TYPE: AFC: 999268 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/13/98 START COMP:09/13/98 RIG:NORDIC ~ 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21287-00 09/13/98 (C1) TD: 6796' PB: 6688' 09/14/98 (C2) TD: 6796' PB: 6688' 09/15/98 (C3) TD: 6796' PB: 6688' 09/16/98 (C4) TD: 6796' PB: 6688' 09/17/98 (C5) TD: 6796' PB: 6688' 09/18/98 (C6) TD: 6796' PB: 6688' 09/19/98 (C7) TD: 6796' PB: 6688' TESTING BOPE MW:10.2 BRINE SUPV:RICK OVERSTREET Circulate well to seawater. Spot LCM pill and bullhead. Displace well with Thicksal brine. ND tree and NU BOPE. POH W/3-1/2" TBG. MW:10.2 BRINE SUPV:RICK OVERSTREET NU BOPE and function test. RIH w/wireline, cut 3.5" tubing ~ 6120'. POH w/3.5" tubing. SERVICE RIG SUPV:FRED HERBERT Spot LCM pill ~ 6100'. POOH w/tubing. MW:10.0 BRINE CIRC BTTMS UP, WELL NOT T MW:10.1 BRINE SUPV:FRED HERBERT TIH w/fishing assy #1 and latch onto fish. Work packer free. POOH w/fish. RIH with fishing assy #2. ATTEMPT TO SET STORM PACK MW:10.1 BRINE SUPV:FRED HERBERT POOH, packer hanging up. POOH slow due to drag and swabbing, well not taking fluid for fill. Continue to try to work fish, will not come free. RIH with scraper. CIRC & RAISE WEIGHT TO 10 MW:10.1 BRINE SUPV:FRED HERBERT Set storm packer @ 35'. ND BOPE, install tubing spool for ESP completion. NU BOPE and function test to 350/3500 psi. Pull storm packer. Rig up to run ESP equipment. Monitor well flowing. RIH w/3.5" tubing. Monitor flow while RIH. NIPPLE UP TREE MW:10.3 BRINE SUPV:FRED HERBERT Circ out oil & gas thru choke, weight cut to 9.4 ppg. CBU (no gas). Monitor well (flowing slightly). Circ and raise weight to 10.3 ppg. RIH with ESP completion. Date: 10/15/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/20/98 (C8) TD: 6796' PB: 6688' RIG RELEASED FROM 3B-14 @ MW:10.3 BRINE SUPV:FRED HERBERT ND BOPE, test tree to 250/5000 psi. Freeze protect well. Release rig @ 1600 hrs. 9/20/98. Gas Cons. commiSs'mn Anchm'8~e ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 16, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3B-14 (Permit No. 85-24/398-230) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 3B-14. If there are any questions, please call 265-6120. Sincerely, Graham L. Alvord Kupamk Drilling Team Leader GLA/skad RECEIVED OCT 2 1 Alaska 0il & Gas Cons. commis~io[~ Anchorage ~,--~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 11. Type of Request: Abandon_ Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate_ Pull tubing _ Variance_ Perforate _ Other X . .Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 109' FSL, 792' FEL, Sec. 16,'T12N, R9E, UM At top of productive interval 1233' FNL, 1168' FEL, Sec. 21, T12N, R9E, UM At effective depth At total depth 1266' FNL, 1212' FEL, Sec. 21, T12N, R9E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-14 9. Permit number 85-24 10. APl number 50-029-21287 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 6796' (approx) true vertical 6484' Effective depth: measured 6688' (approx) true vertical 6377' Casing Length Size Structural Conductor 94' 16" Surface 3289' 9.625" Intermediate Production 6747' 7" Liner feet feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 200 sx PFC 104' 104' 830 sx AS III 3312' 3262' & 450 sx Class G 500ax Class G 6770' 6458' Perforation depth: measured 6294'-6350', 6374'-6380', 6470'-6502', 6514'-6530' true vertical 5985'-6041', 6065'-6071', 6160'-6192', 6204'-6220' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6433' Packers and SSSV (type and measured depth) Otis WD Perm Pkr @ 6410' and Otis 'RRH' Pkr @ 6151', Camco TRDP-1A SSSV @ 1871' 13. Attachments Description summary of proposal X Detailed operation program __ Contact Mark Chambers at 265-1319 with any questions_. RECEIVED 28 Naska 0il & Gas Cons. C0mmis Annhnrage BOP sketch _X 14. Estimated date for commencing operation Au.qust 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~--~ ~' Title Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test .~ Location clearance Mechanical Integrity Test _ Subsequent form require 10- ~ 0 ~ Approved by the order of the Commission ~'~ginal 5 gneo 0avid W. Johnston Form 10-403 Rev 06/15/88 IApproval No.,~%~---. SUBMIT IN TRIPLICATE KRU 3B-14 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w/wireline. Dummy off all GLM's. 2. RU CTU and cleanout down to PBTD. 3. RIH w/wireline and pull DV from GLM g9 @ 6097', GLM #10 @ 6186' and GLM #12 @ 6391' leaving open pockets. 4. RU E-line unit. Chemical cut tubing 4' down into 10' pup joint below bottom FL4S Blast Ring Joint @ 6361' In middle of first full joint above GLM #11 @ 6242'. 5. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 11.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/3-1/2" tubing changing out couplings to modified thread. Stand back tubing and lay down all jewelry. 5. PU DP and RIH with overshot. Latch onto slick stick and pull retrievable packer free. POOH with packer, GLM and tubing down to cut above GLM #11 and blast joints. RIH w/overshot. Wash over tubing stub and fish GLM and blast ring joints. POOH and lay down fish. RIH w/ overshot and fish remaining completion equipment down to bottom production packer. POOH and lay down fish. 7. RIH and mill permanent packer. POOH. RIH with spear and fish permanent packer. POOH w/fish. 8. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. 9. Set storm packer and change out tubing head for ESP completion compatibility. Pull storm packer and verify well is dead. POOH laying down DP. 10. RIH w/Electric Submersible Pump completion on 3-1/2" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 11. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 9.0 days Expected Case: 10.0 days Upper Limit: 12.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion MAC 8/20/98 i 3B-14 Proposed Completion L. 3-1/2" 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. 3-1/2" L-80 EUE 8rd tubing pup below hanger. Flat #1 power cable with tech wire in double armor wrap K. Rerun 3-1/2" J-55 EUE 8rd Mod tbg to surface. Space-out 3-1/2" x 1" Camco 'KBMM' mandrels (box x bm w/DV's as follows: GLM# TVD 2 TBD 3 TBD 4 TBD 5 100' NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 10' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as per procedure ~ Cable splice from motor lead to flat #1 power cable adjacent to 1 O' pup above pump LaSalle /~ Protectolizers at each flange of ESP assembl, J. 3-1/2" X 1" Camco 'KBMM' mandrel (box x box) with STS-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 3-1/2" x 10' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 10' pup and full it. H. 1 jt Rerun 3-1/2" J-55 EUE 8rd Mod tubing with LaSalle cable protector on cplg below joint. G. I jt of Rerun 3-1/2" J-55 EUE 8rd Mod tubing with annulus sensing Baker 'Sentry' gauge clamped to OD of tubing. Conductor Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. F. 3-1/2" Camco 'D' landing nipple with 2.75" No-Go profile. Standing Valve to be set as nipple is made-up. E. Pup jt, 3-1/2" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. D. Centrilift '144GC4100' Series 513 Tandem Pump with bolt-on intake and bolt on discharge head. 3-1/2" x 10' L-80 handling pup on top. C. Centrilift 'GRSXBCTH6' Tandem Rotary Gas Separator. B. Centrilift 'GSB3 DB FER HLB PFS H6 UT/LT' Tandem Seal Section. A. Centrilift '418 HP KMH 2610/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/- 6239' MD. 6294'-6350' C Sand Perfs 6374'-6380' 6470' - 65O2' A Sand Perfs 6514 - 6530' 7" 26# J-55 @ 6770' OBSTRUCTION @ 6581' PBTD @ 6688" MAC 8/19/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 109' FSL, 792' FEL, Sec. 16, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 85 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-14 At top of productive interval 1233' FNL, 1168' FEL, Sec. 21, T12N, At effective depth 1259' FNL, 1203' FEL, Sec. 21, T12N, At total depth 1266' FNL, 1212' FEL, Sec. 21, T12N, 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 3 2 81 ' Intermediate Production 6747' Liner Perforation depth: measured 6294'-6350', true vertical 5985'-6041 ', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6433' Packers and SSSV (type and measured depth) R9E, UM R9E, UM R9E, UM 6796 feet 6484 feet 6688 feet 6377 feet Size 16" 9-5/8" 7" 9. Permit number/approval number 85-24 10. APl number 50-029-21287-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None ORIGINAL Cemented Measured depth True vertical depth 200 Sx PFC 104' 104' 830 Sx AS III & 331 2' 3262' 450 Sx Class G 500 Sx Class G 6770' 6458' 6374'-6380', 6470'-6502', 6514'-6530' 6065'-6070', 6160'-6192', 6203'-6220' Pkr's: Otis RRH @ 6151' & Otis WD @ 6410'; SSSV: TRDP-1A SSA @ 1895' (Locked out) 13. Stimulation or cement squeeze summary Fracture stimulate "C" sand on 4/13/97. Intervals treated (measured) 6294'-6350', 6374'-6380' Treatment description including volumes used and final pressure Pumped 39.4 M lbs of 20/40 ceramic proppant into formation, fp was 6200 psi. O0r~s. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~uu~ng Pressure Prior to well operation 201 213 168 1056 182 Subsequent to operation 698 441 1327 1076 162 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,,..¢g ~ii~~~,~ Title Wells Superintendent Form ~/~64 ~//06~1~81~,~ Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ~' WELL SERVICE REPORT ~ K1(3B-14(W4-6)) WELL JOB SCOPE JOB NUMBER 3B-14 FRAC, FRAC SUPPORT 0408970759.1 DATE DAILY WORK UNIT NUMBER 04/13/97 "C" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI ® Yes O No DS-YOAKUM CH/~I,'EY/ FIELD AFC# CC_,~ DALLY COST ACCUM COST ESTIMATE KD1697 230DS36BL $60,827 $64,231 Initial Tb~ Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Out 1750 PSI 2000 PSI 650 PSI 500 PSI 100 PSI I 2 I DALLY SUMMARY "C" SAND FRAC COMPLETED THRU FLUSH. INJECTED 39443 LBS OF PROP, W/5# PPA OF #20/40 @ PERF'S. MAX PRESSURE 6200 PSI AND F.G. (.86). FREEZE PROTECTED W/DIESEL DOWN TO 4600'. TIME 06:30 08:30 09:00 10:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRUCK, AND LRS HOT OIL UNIT. HELD SAFETY MEETING (16 ON LOCATION. PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 8900 PSI. PUMP BREAKDOWN W/J-313 SLICK WATER, 50# DELAYED XL GW, AND STRAIGHT WATER @ 20 TO 15 BPM. VOLUME PUMPED 489 BBLS. MAXIMUM PRESSURE 6200 PSI AND ENDING PRESSURE 3600 PSI. S/D AND OBTAINED ISIP OF 2480 PSI AND F.G. @ (.86). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 15 TO 10 BPM. COMPETED THRU FLUSH. VOLUME PUMPED 518 BBLS. MAXIMUM PRESSURE 5000 PSI AND ENDING PRESSURE 4265 PSI. S/D AND MONITORED WHTP FOR 10 MINS. INJECTED 39443 LBS OF #20/40 PROP, W! 5# PPA @ PERF'S. NO PROP LEFT IN THE WELLBORE. FREEZE PROTECTED W/DIESEL DOWN TO 4600'. 11 '15 STARTED R/D. DEPRESSURED THE 7" CSG TO 500 PSI AND R/D LRS HOT OIL UNIT. 11:30 12:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,100.00 $5,100.00 DIESEL $400.00 $400.00 DOWELL $54,007.00 $54,007.00 HALLIBURTON $0.00 $3,104.00 Ln-FLE RED $1,320.00 $1 ;620.00 TOTAL FIELD ESTIMATE $60,827.00 $64,231.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl.. OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 109' FSL, 792' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1233' FNL, 1168' FEL, Sec. 21, T12N, R9E, UM At effective depth 1259' FNL, 1203' FEL, Sec. 21, T12N, R9E, UM At total depth 1266' FNL, 1212' FEL, Sec. 21, T12N, R9E, 'UM 12. Present well condition summary Total Depth: measured true vertical 6796 6484 feet feet 6. Datum elevation (DF or KB) RKB 85 7. unit or Property name Kuparuk River Unit feet 8. Well number 3B-14 9. Permit number/approval number 85-24 10. APl number 50-029-21287-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 6 6 8 8 true vertical 6377 feet feet Junk (measured) None Casing Length Structural Conductor 8 0' Surface 3 2 8 1 ' Intermediate Production 6747' Liner Perforation depth: measured 6294'-6350', true vertical 5985'-6041', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6433' Packers and SSSV (type and measured depth) Size Cemented 1 6" 200 Sx PFC 9-5/8" 830SxASlII& 450 Sx Class G 7" 500 Sx Class G 6374'-6380', 6470'-6502', 6065'-6070', 6160'-6192', Measured depth True vertical depth 104' 104' 3312' 3262' 6770' 6~45 8' ~, 6514'-6530' 6203,.6220,4, .. · ¢0 1997 Pkr's: Otis RRH @ 6151' & Otis WD @ 6410'; SSSV: TRDP-1A SSA @ 1895' (Locked out) 13. Stimulation or cement squeeze summary Refracture "A" sands on 7/12/96 Intervals treated (measured) ORIGINAL 6470'-6502', 6514'-6530' Treatment description including volumes used and final pressure Pumped 168.4 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 3846 psi. 14. Representative Daily Average Production or Injection D~ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 501 270 133 943 130 Subsequent to operation 370 174 297 977 177 15. Attachments Copie. s-of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ 4,~ ,3'~ Form 10-404(-~ev 06/15~88 Title Wells Superintendent Date 4- 9- (:;)"'/ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '-- WELL SERVICE REPORT ~' K1(3B-14(W4-6)) WELL JOB SCOPE JOB NUMBER 3B-14 FRAC, FRAC SUPPORT 0721961555.2 DATE DAILY WORK UNIT NUMBER 07/24/96 REFRAC A SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes (-.) NoI (~) Yes O No DS-GALLEGOS PALISCH FIELD AFC# CO# DALLY COST ACCUM COST Signed ,~ . d C', ~ ESTIMATE KM1329 230DS36BL $121,025 $132,018 J"'i~(.15¢l,J ~ ~ Initial Tbcl Press Final Tb.cl Press Initial Inner Ann Final InNer Ann I Initial Outer Ann I Final Outer A~n 0 PSI 1000 PSI 500 PSI 1 000 PSII 250 PSII 300 PSI DAILY SUMMARY I P UMPED 3B-14 "A" SANDS REFRAC TO COMPLETION. 13,617# 20/40,131400# 12/18, AND 23,426# 10/14. PUMP 1088 BBLS SLURRY. MAX TREATING PRESSURE 3846 PSI. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIPMENT. RU ARC BACKSIDE PUMP AND VAC TRUCK. 08:30 TGSM. 13 TOTAL ON LOCATION (9 DOWELL, 3 ARC & 1 ARCO). WATCH OUT FOR TRAFFIC BEING REROUTED WITH RIG CAMP. 08:45 PRIME PUMPS. PT BACKSIDE TO 3700 PSI. OPEN WELL; ON VACUUM; PUMP 65 BBLS INTO WELL TO SET TREESAVER. PT HARD LINES TO 8000 PSI. 09:15 START BM. PUMPED 15 BPM FOR FIRST 17 BBLS AT200 PSI! WHTP GRADUALLY INCREASED TO 3400 PSI AT END OF 125 BBL STAGE. PUMP 1 PPA AND 2 PPA CONDITION STAGES, 4396~ TOTAL 20/40 PROP. 09:35 SD FOR ISIP. ISIP = 1700 PSI; 0.72 PSI/FT FG. PERFORM 3 PULSES. 10:30 START DF. SD FOR ISIP. ISIP - 1700 PSI; 0.72 PSI/FT. 11:55 START PUMPING PAD 170 BBLS 5 TO 15 BPM , 3470 PSI 12:12 PUMPED PROPPANT STAGES AT 15 BPM , 2 PPA TO 10 PPA, 13617# 20/40 , 131,400# 12/18 AND 23,426# 10/14. MAX PRESSURE 3846 PSI. 12:56 FLUSHED FRAC TO COMPLETION , DIESEL LEFT IN TOP OF WELL BORE. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $3,634.00 APC $3,400.00 $3,400.00 APC-PUMPING $0.00 $2,850.00 ARCO $175.00 $175.Q0 DOWELL $117,450.00 $117,450.00 HALLI BURTON $0.00 $4,509.00 TOTAL FIELD ESTIMATE $121,025.00 $132,018.00 . STATE Of ALASKA .,~ ~ OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate . ~( Plugging ...... Perforate _ Pull tubing Alter casing Repair well Other__ '2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, lnc. Exploratory _ 85 RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 109' FSL, 792' FEL, Sec. 16, T12N, R9E, UM 3B-1 4 At top of productive interval 9. Permit number/approval number 1233' FNL, 1168' FEL, Sec. 21, T12N, R9E, UM 85-24 At effective depth 10. APl number 1259' FSL, 1203' FEL, Sec. 21, T12N, R9E, UM 5(~029-21 287 At total depth 11. Field/Pool 1266' FNL, 1212' FELr Sec. 21, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6 796' feet Plugs (measured) true vertical 6484' feet Effective depth: measured 6 688' feet Junk (measured) true vertical 6378' feet Casing Length Size Cemented Measured depth True vertical depth Structural 1 04' 1 6" 200 Sx AS I 1 0 4' 1 0 4' Conductor 3288' 9 5/8" 830 Sx AS III & 3312' 3263' Surface 450 Sx Class G Intermediate Production 6746' 7" 500 Sx Class G 6770' 6459' Liner Perforation depth' measured 6294'-6350', 6374'-6380', 6470'-6502', 6514'-6530' true vertical 5986'-6042', 6065'-6081', 6160'-61 93', 6205'-6221' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55 set @ 6433' Packers and SSSV (type and measured depth) SSSV: Camco WRDP @ 1871', Packers: Otis RRH @ 6151' & Otis WD @ 641~' ,., ~ r' ! t ~ t- I'~ 13. Stimulation or cement squeeze summaryr.L E. IV r.. Refracture A Sands Intervals treated (measured) 6470'-6502', 6514'-6530" JAN 17 Treatment description including volumes used and final pressure ~' ' .0ii & 6as Cons. Pumped 57MIb of 16/20 proppant. Final Pressure: 4700#'""-~:~. , 14. Reoresentative Daily Average Production or In!ectiQrl Data ......... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 8 0 0 9 0 0 2 5 0 I 2 0 0 1 0 0 Subsequent to operation 2 3 0 0 1 5 0 0 2 5 0 1 2 0 0 1 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ Water Injector ~ Daily Report of Well Operations X Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'"~P~ '~-~ Title ~---~~(~~~ ~'~' Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL -/.,/ ..,ON TRA. CTO,R , REMARKS WELL SERVICE REPORT tDATE 0~0o /030 !zo ~ ? . ' - - ' . , .. - / ~ 0 '. / ~ j, - Weather I Tema. I Chill Factor I ~sibilitv I Wl~el. ' ISig~ ~ )- ~ ~ OILAND GAS CONSERVATION CO,,.,AIL )N APPL,CATION FOR SUNDRY APPROVAL ti:: 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 109' FSL, 792' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1233' FNL, 1168' FEL, Sec. 21, T12N, R9E, UM At effective depth 1259' FNL, 1203' FEL, $ec.21, T12N, R9E, UM At total depth 1266' FNL, 1212' FEL, Sec. 21, T12N, R9E~ UM 12. Present well condition summary Total Depth: measured 6 7 9 6' true vertical 6 4 8 4' feet Plugs (measured) feet Cement: RKB 85 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3B-14 9. Permit number 85-24 10. APl number 50-029-21 287 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 6688'-6796' Effective depth: measured true vertical 6688' feet Junk (measured) 6378' feet Fill @ 6570' Casing Length Structural Conductor 1 04' Surface 3 2 8 8' Intermediate Production 6 7 4 6' Liner Perforation depth: measured 6294'-6350', 6374'-6380', 6470'-6502' true vertical Size Cemented Measured depth 1 6" 200 Sx AS I 1 0 4' 9-5/8" 830SxASIII & 3312' 450 Sx Class G 7" 500 Sx Class G 6 7 7 0' 6514'-6530' 6205'-6221' True ve~ical depth 104' 3263' 6459' 5986'-6042', 6065'-6081', 6160'-61 93', Tubing (size, grade, and measured depth 3-1/2" J-55 set at 6433' Packers and SSSV (type and measured depth) Otis RRH @ 6151' and Otis WD @ 6410', Camco WRDP @ 1871' 13. Attachments Description summary of proposal _ Detailed operation program X Refracture stimulate the A sands. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: August, 1990 Oil X Gas ~ 16. If proposal was verbally approved Name of approver Date approved Service _oil BOP sketch production Suspended 17. I he,~~ .Si~lned that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require 10- Approved b~/the order of the Commission Form 10-403 Rev 05/03/89 ORIGINAL SIGNED BY ! nNNIE (;, SMITH Commissioner Approv~.d C~r~v IApproval N o~' I Date SUBMIT IN~RII~LI(~ATE Kuparuk Well 3B-14 A Sand Refrac Procedure Cost Tracking AFE: # K81298 1. Pull WRDP. Isolate the C sand by pulling the CV's from 6186', 6257', and 6391' MD- RKB and setting DV's at same depths. If a Petredat gauge is available, pull a DV from 6186' MD-RKB (top C sand GLM) and replace it with the pressure gauge for the C sand pressure measurement during the stimulation treatment. Estimate the time of the refrac as accurately as possible and Set the data sampling frequency to collect the pressure data in an one minute interval during the stimulation period (a 24 hour period bracketing the estimated stimulation time and in a five minute interval outside of the period). 2. Pull GLV's from 1923', 4456', and 6097' MD-RKB and run DV's @ same depths (leave the bottom GLM open while displacing the 7" annulus with diesel). 3. Displace annulus with diesel. 4. Pressure test tubing. Fracture Tr{~atment (using non-delayed gelled water) JLIL Quality Control: 1. Oheck all tanks for cleanliness and check ~rop~ant for fines. InsUr~ water is uncontaminated. 2. Insure adequate amounts of proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job: 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. 2. Pressure up 3-1/2" x 7" annulus to 3000 psi. Do not allow this pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressures are shown below as a function of annulus pressure. annulus oressure (DSi) *maximum WHTP (DSi~ 2500 5500 3000 6000 3500 6500 * Well 3B-14 has 3-1/2", 9.3 #~ft., L-55 tubing. Maximum WHTP's above are based 100% of the MYS of 3-1/2" L-55 tubing. . Pump 150 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Cut the crosslink chemical towards the end of the breakdown stage (with the tubing volume remaining). Check tank straps against flow meter and correct flush volume as necessary. . Pump fracture treatment per attached schedule starting with a 450 barrel gelled water pad. The following three gelled water systems are acceptable for the refracture treatment: Halliburton: BoraGel Dowell: YF240D B.J. Titan: RXL 5. The expected treating pressure is 3600 psi based on the following: Fracture gradient = 0.74 psi/ft (6196' TVD) Tubing friction = 0.263 psi/ft (6433' MD) Fluid gradient = 0.435 psi/ft (6196' TVD) Estimated perf friction = 0 psi based on initial frac 6. If necessary, cut rate in 1 BPM increments down to 16 BPM during job to reduce WHTP. 7. Obtain representative fluid samples from the pad, slurry, and flush stages during the fracture treatment. 8. Bleed down annulus to 500 psi. Rig down fracturing equipment. Post-Frac Flowback , Establish baselines for comparisons by visually inspecting choke and performing NDT of erosion prone areas, immediately downstream of choke, the drain line, all elbows, and all tees that will be exposed to flowback fluids. Document these inspections on a Flowback Log. . Based on the NDT results on the choke and piping, replace as necessary after reviewing with Corrosion Engineering. At the foreman's discretion, Steps 3 through 5 may be skipped. . Inspect S-Riser and modify as recommended in Cowan/Jackson letter "Modified S-Riser Design Criteria for Post-Frac Flowbacks" dated February 6, 1990 if expected flowrate as determined by KOE, KFE, and Corrosion warrant, or if existing riser has eroded based on UT tests. 4. Install one thread-o-let on the riser (KFE to design proper location and size) to allow hook up of an erosion probe connected to the wellhead safety system. . Install an erosion probe that is tied into the wellhead safety system. If Well 3B-14 has a 3" x 3" choke, it should be replaced with a 4" x 3" choke if possible in order to avoid the increased frequency of monitoring flowback required on a well with a 3" x 3" choke. . Operations Engineer: Place samples taken during the fracture treatment in hot water bath at 150F to observe break time. After the design break time and after verifying that the gel has broken in the water bath, the Operations Engineer will contact the Production Foreman to initiate flowback. , Open well to tanks at a Iow flow rate, not to exceed 300 BLPD. On bottoms up, verify that the gel has broken. If excessive proppant or unbroken gel is present, SI well and contact A. Ramirez/G. Limb (x7525). Do not exceed 300 BLPD for the first 12 hours. After several bottoms up and as soon as clean returns are present with no noticeable gel or significant amounts of proppant, turn well into test separator. Set Iow flowrate alarm for 50 BLPD. Set high flowrate alarm on test separator for 600 BLPD for a 3" choke or 1100 BLPD for a 4" choke. SI After the first 24 hours of flowback, decrease wellhead pressure in 50 psi increments at regular time intervals (minimum two hours) until the well is producing at header pressure. Limit the flowrate increase to no more than 750 BLPD every 24 hours. . Reset the high flowrate alarm to stay below erosional velocity as predicted by the table provided by Corrosion Engineering shown in Step 10. Alarm settings should be based on the maximum flowrate for the average GLR from the first 24 hours of flow. If the GLR changes by more than 250 SCF/BBL, change the high flowrate as appropriate. Record rates, choke setting, and WHP's during the flowback period on the flowback log. 10. Inspect the choke internals visually and the erosion prone areas, downstream of the choke and the S-riser, twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those specified in the following table: Gas 4" Choke 3" Choke Liquid Maximum Maximum Ratio Flowrate Flowrate 300 3500 2000 500 2800 1600 1000 2000 1100 1500 1500 8OO 2000 1300 700 3000 1000 500 5000 700 400 11. Increase the flowrates outlined in the previous table only after a non-erosive condition is verified through inspection and confirmed by Corrosion Engineering. If erosion in the piping or choke body is identified, the well will be choked back to the previous non- erosive rate until some indication is obtained that the solids production has decreased and an assessment of the damage has been made. 12. Once the FTP has returned to normal line pressure, send all flowback logs and other pertinent information to A. Ramirez/G. Limb. Post-Frac Wirelirle 1. If a Petredat gauge was installed, replace it with a DV. Tag fill. This step may be done later with a CV while opening the C sand to production (Step 5). 2. Install a gas lift design. Check with the drill site engineer if a new design is necessary. 3. Install WRDP. 4. Perform' 12 hour A sand only tests with gas lift (1000 to 1100 MSCFD) until at least two consistent results are obtained. 5. Open the C sand to production by replacing the C sand DV's with CV's. 6. Perform A/C combined well testing. WELL 3B-14 GW FRAC DATA TABLE STAGE I PUMP RATE I CLEAN VOLUMEI PROPPANT I CUMULATIVE I DIRTYVOLUIVlF-I CUMULATIVE I STAGEHITS I I (BPM) I (BBL) I {POUNDS) IPROPPANT (LBS)I (BBL) IDIRTY VOL (BBL)I PERES @ (BBL) J BREAKIX)WN 20 150 0 0 150 150 57 SD FOR ISIP, PROVE FLOWMETER PAD 20 450 0 0 450 600 207 SLURRY 2 PPG 20 1 8 1544 1544 20 620 657 4 PPG 20 34 5713 7257 40 660 677 6 PPG 20 47 11957 19214 60 720 717 8 PPG 20 59 19872 39086 80 800 777 10 PPG 20 35 14575 53661 50 850 857 12 PPG 20 20 9889 63550 30 880 907 FLUSH 20 55 0 63550 55 TOTAL 868 63550 935 935 VOLUME TO PERES (BBL) = 57.0 PROPPANT: 16/20M CARBOUTE or LWP THROUGH 10 PPG STAGE 12/18M CARBOLITE in 12 PPG STAGE PUMP RATE = 20 BPM (Drop to 16 BPM if necessary) Estimated Surface Treating Pressure = 3600 psi for non-delayed (surface crosslinked) GW, including zero perf friction based on initial frac. BREAKDOWN = GW + 40 LB/lO00 GAL Silica Flour + 8 Hour Breaker Cut XL during last part (flush) of BD stage PAD = GW + 40 PPT Silica Flour + 8 Hour Breaker SLURRY = GW + 8 Hour Breaker (no Silica Flour) CYC 7/6/90 KUPARUK WELL 3B-14 APl #: SPUD DATE: ORIGINAL RKB: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 104 9.625' 36~ J-55 3312 7' 26# J-55 6770 3.5" 9.3~ J-55 6433 500292128700 ADL LEASE: 25633 PERMIT #: 03/11/85 COMPLETION DATE: 05/22/85 WORKOVER SURFACE LOCATION: 109'FSL,7921 FEL,SECl 6,T12N,R9E TOP OF KUPARUK: 1233'FNL,1168'FEI, SEC21 ,T12N,R9E TD LOCATION: 1266'FNL, 1212'FELMSEC21 ,T12N,R9E Ail del~h~ am MI~RKB t~ I~p of equirmem unlees other,~e noted 85 TUBING SPOOL: 23.68 WELLTYPE: PRODUCER STN LINER DETAILS SIZE WEIGHT GRADE TOP TUBING JEWELRY 8TM ITEM TYPE ID DEPTH SSSV CACMO TRDP-1A 2.81 ' 1871 WRDP WRDP 1.56' SBR OTIS SBR 2.81' 6142 PKR OTIS RRH 6151 PKR OTIS WD 6410 NOGO CAMCO 'D' 2.75' 6425 SHROUT OTIS 64.33 deg MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 30 HOLE ANGLE THRU KUP: 7 LAST TAG DATE: 03/15/90 RATHOLE: 40 FISH/OBSTRUCTION: PBTD: ' PBTDSS: NONE DEPTH 2700 6570 6292 1 2 3 4 5 6 7 8 9 10 11 12 INTERVAL 6294-6350 6374-6380 647~65o2 6514~6530 DATE: 85-24 PAD ELEVATION: 55 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 1923 MERLA TMPD 1.0' 3183 MERLA TMPO 1.0" 4175 MERLA TMPO 1.0' 4456 MERLA TMPO 1.0' 4779 MERLA TMPO 1.0' 5133 MERLA TMPO 1.0' 5425 MERLA 'IMPO 1,0' 5779 MERLA TMPD 1.0" 6097 MERLA TPDX 1.5' 6186 MERLATPDX 1.5' 6257 MERLA TPDX 1.5' 6391 MERLA TPDX 1.5' PERFORATION DATA ZONE FT SPF PHASE C1,3 56 12 120 B 6 12 120 A3,4 32 4 12O A2 16 4 120 REVISION DATE: REASON: PORT SIZE 0.188' DV DV 0.188' DV DV DV DV 0.25" CV CV CV COMMENTS DA 5" SCALLOPED DA 5' SCALLOPED DA 4' JUMBO JET2 DA 4" JUMBO JET2 03/22/90 Tag Fill/CV Check 2 1. ~)000 PS1 ?" WE:LLHr..AD CONN[CTOR FLANGE: 2. 5000 PS1 WIRE:LIN[ RAMS (VAR:IABL[ SIZE:) 3. ~)000 PS1 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW.TUB[: PACK-Orr ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7470 Anc~hor~ge Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 . ~3A-03 ~'3A-08 ~"30-11 ~"30-1 3 *'"30-17 -08 ~0 ~'3H-1 0 ~3 2 0-1 '~ 3BO:18 2 14 ~1 ~-02 ~ 3F-16 ~1 R-02 ~1Y-06 ~2T-07 ~'"~1 E-25 Please acknowledge receipt and return Sub-Surface Pressure Survey 2- 1 5- 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 3 0 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 5-03-89 Kuparuk Fluid Level Report 5 - 0 4 - 8 9 Kuparuk Fluid Level Report 5 - 0 3 - 8 9 Kuparuk Fluid Level Report 5- 0 8 - 8 9 Kuparuk Fluid Level Report 5 - 0 7- 8 9 Kuparuk Well Presure Report 1 1 - 0 7- 8 #64613 Casing Casing Casing Casing Casing Casing CasIng Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M '~ SAPC Chevron Mobil Unocal ARCO Alaska, Inc. Date: September 30, 1988 Transmittal #: 7303 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3B-14 3B-14 3B-14 3B-09 3B-09 3B-09 3B-08 Kuparuk Well Pressure Re Kuparuk Well Pressure Re Kuparuk Well Pressure Re Kuparuk Well Pressure Re Kuparuk Well Pressure Re Kuparuk Well Pressure Re Kuparuk Well Pressure Re )ort '4 - 1 3 - 88 Both Sands 3ort 4 - 1 6 - 88 Sand 'C' 3ort 4 - 1 3 - 88 Sand 'A' 3ort 4 - 1 0 - 88 Sand 'A' 3ort 4 - 1 5 - 88 Sand 'C' 3ort 4 - 1 2 - 88 Sand 'A' 3ort 3 - 1 3 - 88 Amerada Receipt Acknowledg, : DISTRIBUTION: D&M Mobil State of Alaska Unocal SAPC Peter Hogg Chevron ARCO Alaska, inc. Date' August 26, 1988 Transmittal #: 7'280 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 - P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the folloWing items. Please acknowledge' receipt and return one signed copy of this transmittal. 3 H - 2 2 Kuparuk Well. Pressure Report 6 - 2 9 - 8 8 Amerada 3 H - 2 2 Kuparuk Well Pressure Report 8 - 1 0 ~ 8 8 Sand 'A' 3H-1 8 Bottom-Hole Pressure Survey 8-22-88 PBU 3 K- 1 7 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 4 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B- 1 3. Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing Receipt Acknowledged' DISTRIBUTION' D&M State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Post Office r 100360 Anchorage, A,aska 99510-0360 Telephone 907 276 1215 hand carried S,'kMP LE TRJiNSbIITTAL SHIPPED TO' State of Alaska -. DATE- 3/30/87 Oil & Gas Conservation Commission · 3001 Porcupine Dr. Anchorage, Ak. 99501 OPERATOR' Arco SAMPLE TYPE' core chips SAMPLES SENT: 6290 - 6327 6332 - 6354 6396 - 6452 6459 - 6493 6494 - 6540 6543 - 6583 at one foot intervals NfuME' :Knpar~k qR-!4 NUMBER OF BOXES'~ SHIPPED BY: .. _ UPON RECEIPT OF THESE .SkMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FO~M TO: RECEIVED BY: ARCO ALASIC~, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN' Paleo Lab ARCO Alaska, Inc, is a Subsidiary of AllanticRichfieidCompany ARCO Alaska, Inc. -.~ Post Office Bc ~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal ~5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy. of this transmittal. Final Prints' --~-~IR- 14 CET/CEL ~1R-14 CET/CEL 2A-14 CET/CEL -:3A-1 CET/CEL f3A-2 CET/CEL _J-3A-3 CET/CEL 3A-15 CET/CEL ~-~3A-16 CET/CEL -~--~3C- 15 CET/CEL '-a- --~3C-16 CET/CEL '~ J3F-1 CET/CEL _.~ 3F-10 .CET/CEL ~-J --3F~11 CET/CEL ~3J-4 CET/CEL ~3J-6 CET/CEL --3J-9 CET/CEL 10-12-85 Run ~2 10-13-85 Run ~,3 10-02-85 Run ~,1 10-01-85 Run ~,1 10-01-85 Run ~1 10-01-85 Run #1 12-30-85 Run #2 12-30-85 Run ~2 10-!5-85 Run ~1 t0-15-85 Run ~1 10-!7-85 Run ~1 12-19-85 Run ~1 12-19-85 Run #1 10-05-85 Run =1 10-19-85 Run ~1 12-18-85 Run ~. 1 8600' - 9120 85.50' - 8894 6795' - 7763 7550' - 9467 6680' - 8570 6080' - 8256 6400' - 8038' 7300' - 9030 5887 3995 7000 5166 6950 6860 7000 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 36 - 6678 · . · REC IV . Receipt Acknowledged: .~.~-~./ ~ "i~'¢D~tSe.~sa~/ ' _.'~ · . . /" K Drilling Vault(1 film) ARCO Alask,3. Inc. is e Subsidiary o! AlianticRichfi~idCom~any Telecopy No. (907) 276-7542 October 10, 1986 Teresa Gorup - ABV 100. ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Ms. Gorup: In an effort to make our data current, it has been found that the following materials have not been submitted to the Commission as required by 20 AAC 25.071(b) of our regulations. Please submit the following materials: (. 2 ) SAMPLES Well Name Hemi Springs Unit ~3 Winter Trails ~1 Completion Date Permit Number 4/6/85 85-22 3/7/86 86-8 (.3) CORE CHIPS PBU DS 3-32 4/12/86 84-107 PBU DS 16-21 9/2/86 85-312 PBU L1-9 11/19/86 85-1 PBU L2-29 4/12/86 85-297 PBU L3-23 2/28/86 85-306 PBU L-~I-12 5/2/86 86-54 KRU lQ-16 6/10/85 85-47 KRU 3B-14 5/22/85 85-24 Teresa Gorup October 9, 1986 Page 2 (.3) LITHOLOGIC DESCRIPTION Well Name Co.mp!et ion Date PBU DS 3-32 PBU DS 16-21 PBU L1-9 PBU LGI-12 Hemi Springs Unit f3 4/12/86 9/2/86 1/19/86 5/2/86 4/6/85 We appreciate your attention to this matter. /~ grfncere!~, ~ / John~F. Boyle ~'~--'J o - ~ Petroleum Engineer Assistant jo/A.JFB. 4 'Permit Number 84-107 85-312 85-1 86-54 85-22 STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COIv,,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-24 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21287 4. Location of well at surface 9. Unit or Lease Name 109' FSL, 792' FEL, Sec.16, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1233' FNL, 1168' FEL, Sec.21, T12N, R9E, UM 3B-14 At Total Depth 11. Field and Pool 1266' FNL, 1212' FEL, Sec.21, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25633 ALK 2566 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 03/11/85 03/20/85 03/23/85*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6796 'MD ,6484 'TVD 6688 'MD ,6377 'TVD YES [~(X NO []I 1871 feet MDI 1600' (approx) 22. Type Electric or Other Logs Run DIL/LSS/CR/SP/Cal, LDT/CNL/GR/EPT, DIL/GR, WSP, Hicrolog/LSS/Cal, Dipmeter, Gyro 23. CASING, LINER AND CEMENTING RECORD ! SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 200 sx PF "C" 9-5/8" 36.0# J-55 Surf 3312' 12-1/4" 830 sx AS Ill & 450 s~ Class G 7" 26.0# J-55 Surf 6770' 8-1/2" 500 sx Class G & 420 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6514' - 6530' 3-1/2" 6433' 6410' & 6151' 6470' - 6502' W/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6294' - 6350' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6374' - 6380' w/12 spf, 120° phasing 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 II~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OILGRAVITY~API (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Description attached to Well Completion Report, dated 4/8/85. Form 10-407 * NOTE: Tubing was run and the wel 1 perforated 5/22/85. DAM/WCS0 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ~ , ~j ~__ ~ ,r: ~''' 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 6293' 6351' 6411~ 6585' 5984' 6042' 6102' 6274' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer 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 injectionf salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, It~c. Post Of?ice b.... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-11-85 TkANSt~ITTaL NO: 5346 RLTUliN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUitN ONE SIGNED COPY OF THIb TRANS~ITTAL. lQ-12 2z-2 3B-14 WSW-5 iR-Ii 1R-12 1H-07 SEQUENCE OF EVENTS SBHP 9/3-4/85 SEQUENCE OF EVENTS FRACTURE STIMULATION 9/2/E5 SEQUENCE OF EVENTS PBU 'A' SAND 9/2/85 SEQUENCE OF EVENTS TEMPERATURE LOG 8/15/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE tLEPORT 8/20/85 RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNbTON MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* UNZ ON* K.~ULIN/VAULT ARCO Aia'ska. Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 00-30-85 TRANS[~IITTAL ~O: 5315 RETUR[4 TO: AP, CO ALASKA, INC. KUPARUK OPERATION;3 ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AI~CHORAGE, AK 99510 TRAN$[qlTTED HEKEWITtt ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RE'i'Ut~i~ ONE SIGNED COPY OF THIS TRAi~SMITTAL. CL~L FINAL PRINTS/SCHL/ONE * OF EACH .... -~ 3B- 14 04-10-85 RUN #1 4695-6672 ~3B-16 04-12-135 I{UN #1 5860-7758 '"°3 B- 4 05-07-85 I{UN ~1 57~2-775~ ~ 3i~-15 04-12-05 RUN #1 6693-8357 ~3b-2 05-07-85 RUN i%1 48~15-8158 ""~ 3B- 3 05-07-85 RUt4 #1 4770-6495 ~-20-12 05-04-85 IiUN #1 6100-7409 ~.3 B- 13 04-10-05 RUN #1 5689-7921 RECEIPT ~'~CKht)%~LED~LD: DISTRiBUTiON: BPAll btlI i,L ING '~1~ ~1_.~ W. PAS~iUR ~. CURRIER h. JO~l~b'~'oN LXXON Ci~LVK~N ~IOBIL PtlILLIPS OIL D & i~t N5K CLERK*BL J~-~~ DATE: .... '.~:',' ~i;n ~. ,-,~ - ~a~ Co.s. Commission STATE SOHIO /SE U N I ON K .TUhI ARCO Alaska, Inc.,-"'"'- Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/30/85 TRANSMITTAL NO: 5305 RETUBi~ TO: ARCO ALASKA, INC. KUPARUK OPE~aTIONb ENGINEEkING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, ~K 9951U TRANSMITTED HERL%~ITii ARE THE FOLLO%{ING ITL/viS. PLEASE ACKNO%{LEDGE RECEIPT AND RETg~,N ONE SIGNED COPY OF THIS TRANS~ITTAL. bE~ULNCE OF EVENTS PRESbURE DATA ~-~ 2X-10~PBU ~lU-9- PBU C SAND ~2A-2-~ PBU A ~2AJ4'- PBU P~ bT~SS F~C A SAND 2A-4 PBU PRE STI<ESS F~C A bAND ~2E-9" PRESSU~ REPORT ~2L-i~PREbSURE REPORT ~2~~~REbSU~~/ . . REPORT _ ~2~6- PRESSURE REPORT ~2U-10 PRESSURE ~{LPORT ~"~2U-1t PREbSUKE REPORT ~'2U- 16-'PRESSURE REPORT ~' 2U-16 ~BOTTOM-HOLE-SAMPLE ~'~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 / RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTKISUTION: W. PASHER EXXON PHILLIPS OIL* J. RATMMELL* 4/25/85 2~22/85 5/12/85 1/24/85 12/6/84 12/28/84 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 6/ 6/85 6/30/85 6/16/85 6/17/85 6/17/85 5/29/85 DATE: STATE OF ALASKA* SO,riO* UNION* K. TULI~/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieidCompany ARCO Alaska, Inc Post Office . ~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TP, ANSMITTAL NU: 5292 R~TURN TO: ARCO aLASKA, INC. KUPARU K OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED kECEIPT AND KUPARUK ~ lB-1 r ' 05-30-~5 CAMCO lB- 2 · 05- 3 0- 85 CAMCO ~iB- 4~ ' 05 - 16- 85 CAMCO ~ lC- 4 07- 2 4- 8 5 CAMCO --lC-6~' 07-25-85 CAMCO - iD- 8 -~ U 7- 3 0- 8 5 CAMCO --iH- 3 · 07- 30- 85 CAMCO ~ lQ-13f' 06-24-85 CAMCO ~ lQ- 14-~ 06-23-85 CAMCO . "IQ- 15 ..... 06- 21- 85 CAMCO "lQ-16'" 06-21-85 CAMCO ~ 1R- 5~- 07- 05- 85 CAHCO ~ 1R-6 ~" 07-06-85 CAMCO '~ 1R- 7/' 07- 06- 8 5 CAMCO "1R- 8 / 07- 08- 85 CAMCO "2A-2 .... 07-04-85 OTIS ~2W-7 ..... 07-26-85 DRESSE~< "2V-3 07-11-85 OTIS "2W- 15" 08-04-85 OTIS 3B-t~ 06-14-~5 ???? ~ 3B-27~ 06-14-85 CAMCO . 3B-3''~ 06-28-~5 OTIS ~3B-3~ 06-15-85 CAMCO ~3B-4~' 06-15-85 CA~CO ~3B-5 ~'; 06-26-85 CAMCO ~3B-6~' 06-26-85 CA~CO '~3B-7~' 06-28-85 CAMCO ~ 3B-7 -~ 06-27-85 CAHCO - 3B- 8~- 06-28-85 OTIS --3B-9~ 07-18-85 CA~CO ~3B-10~ 07-20-85 CAMCO ~3B-11 -- 07-20-85 CAMCO ~3B-12-~ 07-21-85 CAHCO ~ 3B-13. 05-29-85 OTIS ~'3B-14 05-29-85 OTIS RECEIPT ACKNO~LEDGED: BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* ~,~3B I L* D & H* NSK CLERK HEREWITH ARE THE RETURN ONE SIGNED COPY WELL PRESSURE REPORT--ENVELOPE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE DISTRIBUTION: W. PAShER EXXON PHILLIPS OIL* J. RATHMELL* OF THIS TRANSMITTAL. FACE DATA '~3B-15 · 05-28-85 OTIS 3B-16-" 05-28-85 OTIS ~'~3C-11-~' 07-29-85 CAMCO STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc, ~s a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO, MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Sta,~e ~,{ AJaska Alaska 0!t and Cas Conservation Commission SO01 Porcupine Drive Anc}:oru~e, Alaska ~x:=,~ Receipt of the following material which was transmitted via /~/~// is hereby acknowledged: _QUANTITY _/5" ~..,/~.. ~ ~ ,~" DESCRIPTION !~._ ~_ I~ - DATED: Copy sent to sender YES .. NO STATE OF ALASKA ALASKA vIL AND GAS CONSERVATION CO~MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which was transmitted via ~i/ is hereby acknowledged: ,q,UANTITY Copy sent to sender YES NO ~_ ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TRANSHITTAL NO: 5285 RETURN TO: ARCO ALASKA, INC. KUPAkUK OPERATIONS ENGINEERING ~ECO~d3~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 £RANSMITTED HERE~4ITH ARE THE FOLLOWING ITemS. ~ECEIPT AND RETURN ONE SIGNED iN BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS LISYINGS (ONE 1 4427.5-8881 3C-11 06-23.-85 RUN i 3C-10" 07-02-85 RUN ~1 3C-9 ~' 07-10-85 }{UN tl ]C-7~ 07-31-85 RUN #1 3B-14- 03-20-85 RUN #2 3B-12-- 07-03-~5 RUN tl 3B-11~ 06-26-85 RUN tl 3B-10~ 06-17-85 RUN ~1 3B-9---- 06-10-85 RUN 91 2Z-15" 06-19-85 RUN tl 2Z-14-' 06-28-85 RUN #1 /Z-13" 07-05-85 RUN #1 2Z-12~ 07-20-85 RUN #1 !Z-11,~ 07-27-85 }{UN #1 ~ ACKNO~LEDGE COPY OF THIS TRANSMITTAL. 1785.0-8987 3920.0-8332 4617.5-8747 3280.0-6803 4021.5-8261 2190.5-9257 3273.0-7270 2092.0-8415 2658.0-6620 3876.0-8334 4180.0-8538 4409.0-9412 3531.5-7534 COPY OF EACH) .5 REF #70597 .5 t~EF #70620 .5 REF 970642 · 5 REF 970706 .5 RSF #70229 .5 REF #70641 .0 REF #70598 .5 REF #70555 .0 REF #70634 .0 REF #70562 .0 REF #70600 .5 REF #70639 · 5 REF #70661 .0 t~EF 970704 _N BOX 2 OF 2: ~P~N~HOLE LIS TAPES PLUS LISTINGS (ONE COPY OF 'W-16-~/ 01-28-85 RUN il 3116.0-7038.5 kEF ?,V-14~/ 05-16-85 ~V- 12 ~f~ 04-22-85 ~U-10~ 04-11-85 U-7~'-~ 03-1.9-85 A- 13,Z~ 07-16-85 R-13'/ 07-27-85 R-12 ~ 07-20-85 -R-11'~'' 07-13-85 -R-10~'/ 07-06-~5 R-9~/ 06-28-85 -R-7// 06-04-8b RUN Il aUN #1 RUN il RUN ~1 RUN tl RUN tl RUN .# 1 }{UN tl RUN #1 RUN #1&3 3047.0-7086.5 I{EF 3960.0-9265.0 REF 2972.0-7063.0 kEF 3594. b-8179 . 5 REF 7649.5-8160.0 R~F 3940.0-8578.0 REF 3935.0-8277.5 KEF 3810.0-7213.5 RI~F 2991.0-8738.0 KEF 3991.5-8131.0 REF 0045.5-7103.0 kEF EACH) ~ 70436---REVISED # 7 U 614---REVI # 70613---REVISED # 70612---REVI SED # 70505---i{EVI SED 970645 #70702 #70660 ~70643 #70640 #70601 #70509 ECEIPT ACKNO;~LEDGED: PAE · CURRIER ~EVRON & ~4 DRILLING L. JOHNSTON MOBIL NSK CLERK DISTI{IBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: ~-~?~'~ ~il '~~-~ Cons. Commission, STATE OF ALASKA*~' ~ SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL ~ND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: A]as~ka 0~] amc] Cas Conservation Commission 3001 Porc.p~e Drive Receipt of the following material which was transmitted via /~_/'/ is hereby acknowledged: QUANTITY DESCRIPTION DATED: Copy sent YES ,, to sender NO STATE OF ALASKA · ALASKA oIL AND GAS CONSERVATION CO~..,ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Sta~e o~ Alask~ Alaska Oil and G~s Conservation Commission ~.~.~ i-et 3001 Po,~p.,.e Drive Anehorage, ,&laska §9501 Receipt of the following material whiCh was transmitted via is hereby acknowledged: ~UANT ITY DE S CRI PTI ON · ,_~, ~~. ~$- ~-~,:e~, - +~ -?/:_~ . ' ~VIS~-- ,~ / RECEIVED: DATED: Copy sent to sender YES NO ,]>( ALASKA OIL AND 8A$ CONSEIII/ATION.COMMI$SION · We wish to bring to your attention that the Commission has nor- yet received the following required items on the subject well which our records indicated was completed Bill Sheffield, C~overnor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 995014'3l 9:! TELEPHONE (1107) 279~1433 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. Chatterdon/ Chairman lc i.C. 024 ARCO Alaska, In' Post Office .,,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE:07-16-85 TRANSMITTAL NO:5252 RETURN TO: TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE FINAL PRINTS/SCHL (ONE * OF EACH.) 3B-13 ~.~'5" DIL/SFL-GR · 03-09-85 RUN #1 3657-8014 2" DIL/SFL-GR 03-09-85 RUN 91 3657-8014 5" DEN/NEU PORO 03-09-85 RUN #1 5900-7989 2" DEN/NEU PORO 03-09-85 RUN #1 5900-7989 5" DEN/NEU RAW 03-09-85 RUN #1 5900-7989 2" DEN/NEU RAW 03-09-85 RUN #1 5900-7989 CYBERLOOK 03-09-85 RUN #1 3657-8014 3B-14 2" 5" 2" 5" 2" 5" 2" 5" DIL/SFL-GR 03-20-85 RUN #2 3311-6770 DIL/SFL-GR 03-20-85 RUN #2 3311-6770 LITHO DEN/NEU PORO 03-21-85 RUN #2 6100-6774 LITHO DEN/NEU PORO 03-21-85 RUN #2 6100-6774 LITHO DEN/NEU RAW 03-21-85 RUN #2 6100-6774 LITHO DEN/NEU RAW 03-21-85 RUN #2 6100-6774 LONG SPACING SONIC 03-20-85 RUN #2 3311-6731 LONG SPACING SONIC 03-20-85 RUN #2 3311-6731 (AND 25") MICROLOG 03-21-85 RUN #2 6100-6735 MICROLOG 03-21-85 RUN #2 6100-6735 CYBERLOOK 03-22-85 RUN #2 6111-6727 DUAL DIPMETER-GR 03-21-85 RUN 92 3311-6774 3B-16 5" DIL/SFL-GR 04-06-85 RUN #1 3412-7828 2" DIL/SFL-GR 04-06-85 RUN #1 3412-7828 5" DEN/NEU PORO 04-06-85 RUN 91 4300-7805 2" DEN/NEU PORO 04-06-85 RUN #1 4300-7805 5" DEN/NEU RAW 04'06-85 RUN #1 4300-7805 2" DEN/NEU RAW 04-06-85 RUN #1 4300-7805 CYBERLOOK 04-06-85 RUN 91 7150-7890 RECEIPT ACKNOWLEDGED:. BPAE B. CURRIER CHEVRON D & M*BL DISTRIBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL*BL SOHIO ~,nch/er~ UNION K. TULIN/VAULT*FILMS ARCO Alaska, tnc is a Subsidiary of AtlanticRichheldCompany ARCO Alaska, Inc. Post Office Bo~ .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 3, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 3B-14 3B-15 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L47 Encl osures RECEIVED JUL 0 8 {m & Gas Cons. Commissio~ '~.t}r, hor~ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ...,~-'~ STATE Of ALASKA ALASKA ~. _ AND GAS CONSERVATION CC ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-24 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21287 4. Location of well at surface 9. Unit or Lease Name 109' FSL, 792' FEL, Sec.16, T12N, RgE, UM Kuparuk River Unit , At Top Producing Interval 10~ Weil Number 1233' FNL, 1168' FEL, Sec.21, T12N, R9E, UM 3B-14 At Total Depth 11. Field and P°ol 1266' FNL, 1212' FEL, Sec.21, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25633 ALK 2566 12. Date Spudded 03/11/85 13. Date T.D. Reached 03/20/85 14' Date C°mp" Susp' °r Aband'03/23/85* I15''water Depth' if °ffsh°re N/A feet MS L 116' N°i °f C°mpleti°ns 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6796'MD,G484'TVD 6688'MD,6377'TVD YES I~X NO [] 1871 feet MDI 1600' (approx) 22. Type Electric or Other Logs Run PI L/LSS/GR/SP/Cal, LDT/CNL/GR/EPT, D I L/GR, WSP, Hicrolog/LSS/Cal, Di pmeter, Gyro 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ......16,, 62.5# H-40 Surf 1041i 24" 200 sx PF "C" 9-5/8" 36.0# J-55 Surf 3312' 12-1/4" 830 sx AS Ill & 450 sx Class G 7" 26.0# J-55 Surf 6770' 8-1/2" 500 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) ,_ 6514' - 6530' 3-1/2" 645:~' 6410' & 6151' 6470' - 6502' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT sQuEEzE, ETC. 6294' - 6350' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6374' - 6380' w/12 spf, 120° phasing N/A .,, 27. N/A PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Description attached to Well Completion Report, dated 4/8/85. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ...... Form 10-407 * NOTE: Tubing was run and the well perforated 5/22/85. GRU9/WCS0 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTI- GOR, and time of each phase. Top Upper Sand 629:~~ 598z~' N/A Base Upper Sand 6351f 60z~2, Top Lower Sand 6#11 f 6102~ Base Lower Sand 65857 627z~ 31. LIST OF ATTACHMENTS We]] History (completion de'cai]s) - 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~0~~ ~,L~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. Accounting District ICounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25633 Auth. or W.O. no, ~Title AFE 604445 I Completion Roll'N 4 API 50-029-21287 Operator A.R.Co. W.I. ~Total number of wells (active or inactive) on this, ARCO Alaska, Inc. 56.24% [cost center prior to plugging and Jabandonment of this well Spudded orW.O. begun Date ~Hour I Prior status if aW,O. Complete 5/21/85 / 0700 hrs. I cost center code Alaska JWell no. 3B-14 Date and depth as of 8:00 a.m. Comptete record for each day reported 5/22/85 5/23/85 7" @ 6770' 6688' PBTD, 6796' TD, Rn'g 3½" compl 10.1 ppg NaCl/NaBr Accept rig @ 0700 hrs, 5/21/85. ND tree, NU & tst BOPE. RU WL. RIH w/4" csg guns, 4 SPF, 120° phasing. Perf f/6530'-6514', 6502'-6470'. RIH w/5" csg guns, 12 SPF, 120° phasing. ?erf f/6380'-6374', 6350'-6294'. RIH w/WL pkr & tailpipe assy. Set pkr @ 6410'. 7" @ 6770' 6688' PBTD, 6796' TD, RR Crude oil Rn 195 its, 3½", J-55, 8RD EUE, IPC tbg w/SSSV @ 1871' to 6770', space out & lnd tbg. Drop ball, set pkr. ND BOPE, NU & tst tree to 300/5000 psi. Displ well w/35 bbls diesel, followed by crude. Set BPV. RR @ 2230 hrs, 5/22/85. Moving rig to 3B-2. Old TD JJ New TD J PBDepth 6796' 6688' PBTD Released rig J Date Kind of rig · 2230 hrs. 5/22/85 Rotary. Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil . .J Single Produ.cing method . . ] Official reservoir name(s) . . Flowing Kuparuk Sands Potential test data . .. Well no. Date Reservoir Producing interval Oil or gas Test time r~ P~;~lu~er~ I~°E°~et I V E~' da~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity ~1~ C) ~ctive date corrected ~,laska U & Gas Corm. Commission Anchorage The above is correct Signature For form preparation and dis~ution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate JTitle 6/07/85 Drilling Superintendent NEW PROJECTS ENGINEERING TRANSKITTAL f }-P~gM: L. K. SPIITH/P. S. BI~_'TIER TRANSEIT~ EER~-W'!TH' A1LE TiLE FOLLOW. lNG: PLEASE NOTE: BL - BLUIiLINE, S - SEPIA, F - F~, T - TAPE, PC - PROTOCO-:~f RECEIPT ACKNOWLKDGED: PLEASE RETURN RECEIPT TO: AllC0 ALASKA, INC. A.TTN: PATSY S. P. 0. BOX 100360 ~_NCRORAGE, AK 99=!0 ATO/507 ARCO Alaska, inc. Post Office B~",,!00360 Anchorage, A ,ka 99510-0360 TelePhone 907 276 1215 Date: 6/12/85 Transmittal No.: 5212 Return To: ARCO Alaska, Inc. Attn: Records Clerk ATO-1115-B P.O. Box 100360 Anchorage, AK 99510 ,Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Otis Static Gradient Final Report- ''2A-2 5/27/85 --.2H-1 5/27/85 ~--3B-14 5/29/85 ~3B-!5 5/28/85 j'3B-16 5/28/85 Receipt Acknowledged: BPAE B. CURRIER CHEVRON D&M DRILLING L. JOHNSTON MOBIL NSK CLERK' DISTRIBUTION W. PASHER EXXON SOHIO PHILLIPS 0IL' UNION J. RATttMELL K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlenticRichlietdCompeny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alaska Alaska Oil and Gas Conservation CommisSion 3001 Porcupine Drive Anchorage, Alaska 99501 Receipt of the following material RE: which was transmitted via is hereby acknowledged: ,Q,UANTITY DESCRIPTION ~ iV-Il :tY6~ z./9~-.~- aflcn - ~/~ -~oz~ RECEIVED: DATED: 6;-/,o-.P& Copy YES sent to sender . N0 _~ ARCO Alaska, Inc. Post Office B~,.. f00360 Anchorage, A~aska 99510-0360 Telephone 907 276 1215 June 4, 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: 3B-14 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. The tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU9/L35 Enclosures RECEIVED Alaska Oil & .Gas Cons. Conlrniss/on Ancho,.~ge ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO~,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] ..... , 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 85-24 ":~. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21287 ,, 4. Location of well at surface . 9. Unit or Lease Name 109' FSL, 792' FEL, Sec.16, T12N, RgE, UN i LL_;?~,.i"~i.i-ilj~ii¥ Kuparuk River Unit At Top Producing Interval ~;~-~i~D j 10. Well Number 1233' FNL, 1168' FEL, Sec.21, T12N, RgE, UN ISur~'~ -a - ~ ~ I 3B-14 At Total Depth !~.H~.~i! ll. FieldandPool 1266' FNL, 1212' FEL, Sec,21, T12N, RgE, UM ..... Kuparuk River Field ,, 5. Elevation in feet (indicate KB, DF, etd.) [ 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKBj ADL 25633 ALK 2566 .,, 12. Date Spudded03/11/85 13. Date T.D. Reached03/20/85 14' Date c°mP" Susp' °r Aband' I 15' Water Depth' if °fish°re 116' N°' °f C°mpleti°ns03/23/85 N/A feet_ MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6796'ND,6484~TVD 6688'ND,6377'TVD YES F~X NO [] N/A feet MDI 1600' (approx) 22. Type Electric or Other Logs Run D I L/LSS/GR/SP/Cal, LDT/CNL/GR/EPT, D I L/GE, WSP, Microl og/LSS/Cal, Di pmeter, Gyro "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 200 sx PF "C" 9-5/8" 36.0# J-55 Surf 3'312' 12-1/4" 830 sx AS III & ~50 sx Class G 7" 26.0# J-55 Surf 6770' 8-1/2" 500 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) N/A 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.) 1 Date of Test Ho'ursTested 'PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL cHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I FloWmubi.ng. Ca~ing Pressure . CALCULATED OIL-BBL ,GAS-MCF WATER-BBL OIL GRAvITY-APl (~'~rr) ' '. " Press. ,24-HOUR RATE Jl~ 28. CORE DATA Brief description of lithology, porositY, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Description attached to Well Completion Report, dated 4/8/85, Alaska Oit & G~, Co~s.~ t,,.~,.,~. ....... Form 10-407 TEMP/WC23 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VEtRT. DEPTH GOR, and time of each phase. Top Upper Sand 6293' 5984' i N/A Base Upper Sand 6351' 6042' Top Lower Sand 6411 ' 6102' Base Lower Sand 6585' 6274' . 31. LIST OF ATTACHMENTS Well History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~ Title Associate Erlgineer' Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item.24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' 'Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple' stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 · ARCO Oil and Gas Company Well History - Initial Report - Daily I,natructione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. ~' Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O, no. AFE 604445 ICounty, parish or borough North Slope Borough Lease or Unit Title ADL 25633 Drill IState Alaska Welt no. 3B-14 Parker 141 API 50-029-21287 Operator ARCO Alaska~ Inc. Spudded or W.O. begun ]Date IHour Spudded 3/11/85 Date and depth as of 8:00 a.m. 3/12/85 3/13/85 3/15/85 3/16/85 thru 3/18/85 Complete record for each day reported IARCO W.I, 56.24% 1245 hrs. IPrior status if a W.O. 16" @ 104', 2300', (2196'), DD Wt. 9.3, PV 13, YP 19, PH 9.5· WL 16.2, Sol 5 Accept rig @ 0800 hrs, 3/11/85. NU 20" Hydrl. 1245 hfs, 3/11/85. Drl surf hole to 2300'. Spud well @ 16" @ 104', 3320', (1020'), Logging Wt. 9.4, PV 13, YP 18, PH 9.5, WL 13.8, Sol 7 Drl & surv 12¼" hole to 3320', 18 std short trip, C&C f/logs. RU Schl & log. 2455', 4.9°, S12.6W, 2454.82 TVD, 8.25 VS, 8.02S, 1.94W 2985', 21.2°, S18W, 2969.83 TVD, 126.07 VS, 120.04S, 37.86W 3140', 25.9°, S14.7W, 3111.92 TVD, 187.97 VS, 179.83S, 55.29W 3265', 29.5°, S16.4W, 3222.59 TVD, 246.07 VS, 235.81S, 70.87W 9-5/8" @ 3312', 3320', (0'), Tat BOPE Wt. 9.0, PV 10, YP 13, PH 9.0· WL [8!,1, Sol 6/~ Log DIL/LSS/GR/SP/CAL, LDT/CNL/G~i~/332~~f~ TIH & cond f/csg. TOH, LD BHA. RU & rn 76-~i~,. 9~5/8,,~.6~, j_55 BTC csg w/FS @ 3312'· FC @ 3222'. Cmt w/830 sx AS III & 450 Displ & bump plug. ND diverter & instl Tankco head. NU &tst BOPE. 9-5/8" @ 3312' 4900'· (1580'), Turbo Drlg Wt. 9.0· PV 10, YP 10, PH 10.5· WL 16.5· Sol 6 RIH, tst csg to 1500 psi. DO cmt & flt equip. Perform leak-off tst to 12.28 ppg. TOH, PU turbine· TIH, drl & surv 8½" hole to f/3340'-4900' . 3591'· 29.2°, S16W, 3506.75 TVD, 405.79 VS, 389.25S, 115.45W 4090'· 29.2°, S12.3W, 3942.34 TVD, 649.22 VS, 625.31S, 174.96~ 4373', 27.3°, S13.6W, 4191 63 TVD, 783.11 VS, 755.85S, 204.98W~ 4684', 28.3°, S10.3W, 4466 73 TVD, 928.03 VS, 897.62S, 235.63W 9-5/8" @ 3312' Wt. 10, PV 13, YP 12, PH 9.5· WL 8.0· Sol 12 Drl & surv to 6290'' circ, TOH. PU core bbl, TIH, cut core 6290'-6332', jammed, TOH, rec'd 38'. Core #2, 6330'-6396', TOH, POH & LD. 4965', 26.7°, S12.2W, 4715.98 TVD, 1057.59· 1024.77S, 261.50W 5538', 15.6° S16 2W, 5248.35 TVD, 1267 64, 1229 27S, 309 75W 5820', 11.3°, S38.9W, 5522.62 TVD, 1331.56, 1287.42S, 340.09W 6200', 7°, S55.3W, 5397.78 TVD, 1382.52, 1328.55S, 384.36W The above is correct Signature For form preparatl~n'-a-~d dietd-butl~or~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 4/19/85 ITM Drilling Superintendent ARCO, Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. K+Jmber all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District County or Parish IState Alaska North Slope Borough I Alaska Field Lease or Unit IWell no. Kuparuk River ADL 25633 I 3B-14 Date and depth as of 8:00 a.m. 3/19/85 3/20/85 3/21/85 3/22/85 The above is correct Complete record for each day while drilling or workover in progress 9-5/8" @ 3312' 6485', (89'), Core #/~ Wt. 10, PV 11, YP 10, PH 9.5, WL 6.4, Sol 11.9 Rec'd 22' f/core #2. Core #3, 6396'-6455', rec'd 55'. Core #4, 6455'-6459',bbl jammed,TOH, no rec'y. Core #5, 6459'-6485'. 9-5/8" @ 3312' 6596', (111'), LD core bbl Wt. 10.1, PV 12, YP 10, PH 9.5, WL 6.4, Sol 12 Fin core #5, 6459'-6493', POOH, rec'd 34'. Core #6, 6493'-6543', bbl jammed, TOH, rec'd 48'. Core #7, 6543'-6596', rec'y not available at rapt time. 9-5/8" @ 3312', 6796', (200'), Logging Wt. 10.1, PV 13, YP 11, PH 9.5, WL 5.8, Sol 12 RIH, drl to 6796', CBU, POOH. RU Schl to rn logs. 6746', 1°, S55W, 6442.12 TVD, 1407.33 VS, t350.11S, 415.49W 9-5/8" @ 3312', 6796', (0'), LD DP Wt. 10.1, PV 10, YP 10, PH 9.0, WL 5.8, Sol 13.2 Rn DIL/SFL/GR f/6770'-3311', rn VSP @ selected intervals, rn Microlog/L$S/CAL f/6735'-6100', rn Dipmeter f/6774'-3311', RD Schl. TIH, C&C hole f/7". Signature For form preparation-a~'d d~stribution /~ - - ' ""- see Procedures Manual Section 10, v Drilling, Pages 86 and 87 JDate 4/30/85 [Title 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 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. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River ADL 25633 Auth. or W.O. no. T t e AFE 604445 Drill Parker 141 API 50-029-21287 Operator 1A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Spudded I 3 / 11/85 Complete record for each day reported Date and depth as of 8:00 a.m. ~!23!~5 7" @ 6770' Accounting cost center code State North Slope Borough Alaska I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1245 hrs. IWell no. 3B-14 6770' PBTD, RR Wt. 10.1, PV 7, YP 6, PH 9.0, WL 6.8, Sol 11 Chg rams to 7" & tst. RU & rn 168 jts, 36@, J-55 BTC HF-ERW csg w/FS @ 6770.50', FC @ 6687.85'. Cmt w/500 sx Cl "G" w/3% KC1, .8% D-60 & .2% D-46. Displ using rig pmp, bump plug. Good rtns thruout job CIP @ ~hrs, 3/22/85. ND BOPE, set slips, cut off csg & ~U wellhead.~Tst pack-off to 3000 psi; OK. RR @ 0100 hrs, 3/23/85. I~-k~ R CEiVED Old TD New TD PB Depth 6796' (3/20/85) 6770' ?BTD Released rig Date Kind of rig 3/23/85 0100 hrs. Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sigr~ature For form preparati-on-;nd-dis~ribu~i~ see Procedures Manual, Section Drilling, Pages 86 and 87. Drilling Superintendent TRANSMITTED HEREWITH ARE TEE FOLLOWING: FROM: L. K. SMITE/?. S. BAXTER WELL NAME: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: PATSY S. BAXTER P. O. BOX 100360 . ANCHORAGE, AK 99510 ATO / 507 ARCO Alaska, Inc~-''~ Post Office .~ .)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 t~ay 3, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3B Pad Wells 1-4, 13-16, Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU6/LI01 Enclosures If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 2l t5 22 SCALE. N T S LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12N., WELL I Y = 5,991,896.45 X= 518,178.72 O.G. Elev. 49.6 776' FSL WELL 2 Y= 5,991,956.26 X= 518,172.79 O.G. Elev. 49.5 856' FSL WELL 5 Y= 5,998:,015.79 X= 518,167.27 O.G. Elev 49.2 896' FSL WELL 4 Y =5,992,07S. 65 X= 518,161.64 O.G. Elev. 49.0 955' FSL WELL t$ Y=5,991, 169.71 X = 518,247.90 O.G. Etev. 48.5 49' FSL WELL t4 Y-- 5,991,229.62 X= 518,242.16 QG. Elev. 49.0 t09' FSL WELL t5 ¥ 5,99;,z89.13 X= 518,256.44 O.G ~:Le v. 4 9.0 169*FSL WELL t6 Y=5,991~34~.67 X= 518,250.79. 0 G. E lev. 49.0 228' FSL 8 20 RANGE 9 E., UMIAT MERIDIAN. COORDINATES ARE A.S.P.~ ZONE 4. SECTION LINE DISTANCES ARE TRUE. HORIZONTAL POSITION PER LHD'S ON PAD PILING CONTROL PK'S. N 26 +45 N E 8*50 E 8+50 VERTICAL POSITION PER LHD'S ALCAP TBtM'S 3B-I1&3B-12. O.G ELEVATIONS INTERPOLATED FROM S/C DWG CED-gBo0-3001 CPF_ [ /I 16 ~ 0 15 14 Lat. 70o23' 20.5210" Long 149°51'07. 675" Pod Elev. 54.6 852' FEL Lat. 70° 25'21.1094'' Long. 149o5 I' 07.. 84:~" Pod Elev. 54,8: 858' FEL Lat 70°25'21.6951'' Long 149o51' 08.000" Pad Elev 54.6 863' FEL Lat. 70° 23'22.Z840' Long. 149° 51'08,161" Pod Elev. 55.9 l~68' FEL Lot. 70° 23' 13.3712" Long. 149° 51' 05.69cJ" Md Elev. 55.4 786' FE L Lat. 70° 23' 13.9607" Long. 149°51' 05.863" Pad Elev. 55.4 792' FEL Lat. 70°25' 14.5461" Long. 149o51'06.026'' 1~3d. Elev. 55.7 797' F E L Lat. 70° 25' 15. I$;59" Lom~. 149° 51'06. Pod Elev 55.4 802' FEL ARCO Alaska, Inc. Kuparuk Project North Slope Drilling DRILL SITE 3B CONDUCTOR AS-BUILT LOCATIONS Oote:Morcht~t985 J Scale' AS SHOWN Drawn By' DJ.W. J Dwg. No. NSK 9.05.302d2 i I HEREBY CERTIFY ~'HAT' I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE' UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF MARCH 3,19~5 FOR WELLS !-4~13-16. ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 121.5 April 12, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the March monthly reports for the following wells' 1Q-3 2U-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/Li06 Enclosures RECEIVED APR 1 6 1985 Alaska 0tl & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany '~'--" STATE OF ALASKA '~-~" ALASKA O,,_ AND GAS CONSERVATION COl, .... iSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-24 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21287 109' 4. Location of Well at surface, FSL, 792' FEL, Sec.16, T12N, R9E, UM I6. LeaseDesignationandSerialNo. ADL 25633 ALK 2566 For the Month of. Hatch , 19 85 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3B-14 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1245 hfs, 03/11/85. Drld 12-1/4" hole to 3320', Ran and tstd 9-5/8" csg. Drld 8-1/2" hole' to 6290'. Cored f/6290' 6796'TD(3/20/85). Ran logs. Ran, cmtd, & tst. d 7" csg. PBTD = 6688'. ~ 0100 hfs, 03/23/85. logs. Ran, cmtd, 6596'. Drld to Secured well & RR 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 104'. Cement record not available at this time. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS @ 3312'. Cmtd w/830 sx AS Ill & 450 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/FS @ 6770'. Cmtd w/500 sx Class "G". 14. Coring resume and brief description Core #1 f/6290' - 6332'; cut 42', recovered 38' Core #2 f/6332' - 6396'; cut 64', recovered 22' Core #3 f/6396' - 6455'; cut 59', recovered 55' Core #4 f/6455' - 6459'; cut 4', no recovery Core #5 f/6459' - 6493'; cut 34', recovered 34' Core #6 f/6493' - 6543'; recovered 48'. Core #7 f/6543' - 6596'; cut 50', cut 53' 15. Logs run and depth where run DIL/LSS/GR/SP/Cal f/3280' - surface LDT/CNL/GR/EPT f/3280' - surface DIL/GR WSP Microlog/LSS/Cal Dipmeter 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED Oil & Gas Cons. Comm~sslon Anci~orage SIGNED ' ;~/%/~" "~J~ 2:-~)L--, TITLE A$$0¢i ~_~ Fng i nee_r' DATE 4 NOTE--Repo/,¢t on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TI'MD /MD1 /~ Submit in duplicate TO' DATE: TRANSMITTED EEiLE%'ITE A_RZ TEE FLF~.S E NOTE: Fi{OH: L. K. ~/P. $. BAXTER BL - BLIT~INE, ATOISO7 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 8, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-14 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 3B-14. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the tubing details, intervals perforated, bottomhole location, and TVDs will be submitted when the gyroscopic survey has been run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L97 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ..... ' ALASKA ,.,IL AND GAS CONSERVATION CC,..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL i--I GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 109' FSL, 792' FEL, 5ec.16, T12N, RgE, UN At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 7. Permit Number 85-24 8. APl Number 50-- 029-21287 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3B-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 85' RKB ADL 25633, ALK 2566 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 03/11/85 I 03/20/85 03/23/85 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 6796'MD J 6688'MD YES [] NO E~X I N/A feet MD 22. Type Electric or Other Logs Run D IL/LSS/CR/SP/Cal, LDT/CNL/GR/EPT~ Mi cro]og/LSS/Cal ~ Di pmeter~ D I L/GR~ WSP 23. CASING, LINER AND CEMENTING RECORD 15. Water Depth, if offshore 16, No. of Completions N/A feet MSL N/A I21. Thickness of Permafrost 1600' (approx) SETTIN( DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf ~' 9-5/8" 36.0# J-55 Surf 7" 26.0# J-55 Surf 104' 3312' 6770' 24" 12-1/4" 8-1/2" 230 sx CS Il (Approx) 830 sx AS ill & 450 sx 500 sx Class G 24. Perforation! open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) None C1 ass G SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/^ 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Flow Tubing Press. Hours Tested Casing Pressure IPRODUCTION FOR iOIL-BBL TEsT PER,OD CAlCuLAteD .io, . BL 24-HOUR RATE -~ GAS-MCF GAS-MCF WATER-BBL WATER-BBL I CHOKESIZE {GAS-OILRATIO OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Description. RECE V' APR l 1 85 Alaska 0il & Gas C0r~s, ,,;,,. ...... Anch0ra0-~ Form 10-407 GRU5/WC43 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUEVERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed i~ ~ ~'~"/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Date: Subject: March 26, 1985 DS 3B-14 Core Internal Correspond/ File code: From/Location: To/Location: D. W. Brizzolara ~ ATO 1092 J. Gruber - ATO 1478 The following represents the cored intervals Interval Cut Recovered Core #1 6290' -6332' 42' 38' Core #2 6332'-6396' 64' 22'2" Core #3 6396'-6456' 60' 55'6" Core #4 6456'-6459' 3' 0 Core #5 6459'-6493' 34' 34' Core #6 6493'-6543' 50' Core #7 6543'-6596' 53' Senior Geologist DWB:dvh File: GO 12 48' 41 '4" and lithologies from 3B-14' Lithology Glauconitic sandstone, siltstone and shale. Glauconitic sandstone, siltstone and shale. Interbedded siltstone, shale and subordinate very fine to fine grained sandstone. II II II Interbedded very fine to fine grained sandstone, siltstone and shale. II II II II II II ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany RECEiVFr AJaska 0il & Gas Cons, Anchor'a.g~:~ S UB-S URFA CE DIRECTIONAL SURVEY [-~'IUIDANCE r~] ONTINUOUS r~OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 3B-14', (109' FSL. 79g' F~.T,: gl6, T12N. R9E. UM) KUPARIIK~ NORTH SLOPE~ ALASKA Job Reference No. 70315 Locj~3ed By: T .WEST GCT DIRECTZONAL SURVEY FOR ARCO ALASKA° ]B-14 KUPARUK NORTH SbOpE,AbASKA SURVEY DATE: 11 APR 85 ENGINEERS T. WEST METHODS OF CDMPU?ATION TOOL bOCATZON~ ?ANGENTIAb- averaoed deviation and azimuth [NTERPOLAT~O~I LINEAR VERTICAL SECT{O.I HORIZ, DfST, PROJECTED ONTO A TARGET AZ{MUTH OF SOUTH 14 DEG {6 MZN WEST ARCO AbASKA, TNC, 3R'14 KUPRRUK NOR?H SbOPE,ALASKA TRUE SUB-SEA COURSB :gASUR£D V£R?XCAL VERTICAb D£V~A?ION AZIMUTH DEPTH DEPTH DEPTH DEG MIN D£G M~'N 0.00 100,00 200.00 300 O0 400.00 ~00,00 600,00 700,00 800,00 900.00 0 O0 100,00 2O0 On 3O0 O0 400 O0 500 '00 600 O0 7O0 O0 799 99 809 99 COMPUTATION DATE: 24-RPR-85 PAGE 1 DATE OF SURVE¥I t~ APR_SS KEbb¥ BUSHING EbEVATIONI ENGIN£ERI T, WEST XIITERPOLATED VALUEG FOR EVEII tO0 FEET OF MEASURED DEPTH VERTTCRL DOGLEG RECTANGULRR COORDXNATE& HORZZ,:: DEPARTURE SE~TXON SEVERITY NORTH/SOUTH ERST/WEST DXST.: RZIMUTH FRET FEET FEET FEET DEG MXN 0 0 N 0 0 g O.O0 0 18 N 76 50 £ -0,20 01~ ~ 55 59 E =0.43 0 11 N 55 22 E -0,68 0 ~ N ~4 30 E -0.83 0 6 S 77 9 E -0,90 0 15 $ 65 44 E -0,88 0 17 S 59 30 E -0.77 0 23 S 67 59 ~ -0,64 0 21 S 76 40 £ -0,6! '85,00 5 O0 1~5 O0 oo O0 41~ O0 :1~.00 ,II.°° .°09 814.99 ~000 O0 999 90 9~.99 !O0'.O0 1009 99 lO .99 121a,99 99 1]1a.99 98 t414.98 98 1514,98 9~ 1614.98 9~ 1714,98 97 1814,97 0 19 $ 84 14 ~ '0.65 0 12 ~ '8 23 F '0. 0 12 $ 32 0 E -0.65 0 12 S 13 24 g -0.32 0 14 $ ~5 31 E 0,00 0 ? $ 33 12 E 0,22 0 33 Ii ~9 51 W 0,02 0 51 ~ ~6 3~. ~ -0,97 0 40 ~ 18 21 W -2o00 ~00.00 1~99 ~300.nO ~ 99 1400.00 1399 1500.00 1499 1600.00 1599 1700,00 1699 190 O0 1899 N 0 4~ E -~.05 ~ 11 25 g -3 64 N 22 28 E -4'43 $ 16 23 E -4.64 $ 1 58 W -1.28 S ~4 ~ W 7,04 5 16 32 W 20.94 S ~5 55 w 38.94 g 16 ~ W 63.56 $ ~4 2O W 93.27 2000.00 1999 96 1914.q6 0 27 2100.00 2099 96 2014.96 0 26 2200,00 2199 95 2i14,q5 0 24 2300.00 2299 95 2214.95 0 2400,00 2399 80 2314,88 3 32 2500 O0 ~409 5~ 2414.52 6 6 2600:00 25O8 63 2513,63 9 2700.00 26¢6 85 261~,05 12 39 2800.00 9793 76 270~,76 15 40 2900.00 2889 23 2004.~3 ~8 45 2897,q8 21 57 2989.67 25 7 9 3079.19 27 36 3 3166.'3 ~9 20 93 3253.93 ~9 3) 04 3341,04 29 17 2a 3428,~9 ~9 17 59 3~5,59 29 9 90 3602,90 ~9 6 32 3690.32 29 5 S 14 41 w S 14 47 W S i6 40 w 5 ~7 3t W S t6 14 w S ~4 58 W ,~ 14 2 w S 13 16 w ooo OD 3100 O0 3~00 O0 3164 3~00 O0 3251 3400 O0 3338 3500 O0 3426 3600 O0 3513 3700 O0 3600 3900.00 ~6~7 3900,00 3775 128,00 167.88 212.40 260.48 309 53 358 61 407 45 456 22 504 97 553 52 DE~/IO0 000 0 5~ 0 08 0 O9 0 20 0 17 0 10 0 4J 0 22 0 O4 0 34 0 O9 0 10 0 1! O65 0 46 0 10 0 1~ 0 09 0 38 2 16 2 51 3 05 4,21 2,89 2,83 2 93 2 89 3 O3 0 34 0 34 0 62 0 ~8 0 SO 0 S3 0 4O 0 O0 N ):15 N :27 N 0 47 n 056N 0 57 ~ 0 47 N 0 2~$ 0 O0 E 0 24 E 0 64 E 0 90 E ~ 14 g 1 67 E 3 30E 85,00 FT i8 N: 59 5 E 9 N 66 37 E O, N 62 35 E N 64 4 E 8 N 67 t 4 $ 89 14 E 31 S 86 0 g 0 34 S 0 34 S 037,5 0615 0988 1348 I 60 $ 1358 0205 1 .04 N 3,89 4,31 4.65 4,90 5,04 5,15 5.27 5,:1t 3 90 $ 85 3 E 4 33 15 85 28 E 67 $ 85 26 g 94 $ 82' 56 E 13 $ 78 57 E 33 $ 75 23 E 51 $ 73 4 g 29 $ 75 t0 E 61 $ 87 34 g 10 N 75 21 £ 8 20 38 62 97 N 75 n 5! N 67 N 17 n 76 $ 43 $ 3 78E 388£ 4 05 E 4 34 E 4:42 g 0 9 W 5 70 W 12 48 w 20 17 W E 4 26 N 62 32 4 76 N 54 37 538 N 49 18 E 5 4 8 20 39 63 93 6 8 N 49 46 E 42 N 87 48 E 7 S 7 W 18 S 8 22 W 66 S 11 18 W 33 S 12 28 W 124,76 S 163.39 S 38 206'25 S 50 252I1 S 65 298 87 S 80 345 86 5 04 S 120 487 13 S 133 534 33 $ 144 29 85 W 128 05 $ 13 1 W 98 W 167 91 S 13 25 W 80 W 212 49 W 260 56 W 309 88 W 358 W 456 16 W 505 60 W 553 42 S 13 50 W 48 S 1433 W 54 S 15 5 W 64 S 15 20 W 49 S 15 23 W 26 S 15 22 W O0 S 15 t7 W 55 S 15 8 W 0 O0 N 0 0 E ARCO ALASKA, INC, 3B-14 KUPARIIK NORTH SLOPE, ALASKA COMPUTATION DATE~'24-APR-85 TRUE SUB-SEA COURSE IEASURED V£RTICAb VERTICAL DEVIATION AZIMUTH ~EPTH DEPTH DEPTH DEG NIH DEG ,, PAGE 2 DATE OF SURVEYl 11 APR 85 KELLY BUSH[NO ELEVATION{ 85,00 FT 99 29 9 S 11 57 W 25 29 16' S ii 3] W 50 29 0 8 11 1.8 W 55 27 50 S 11 49 W 88 28 9 $ 11 44 W 96 28 19 $ 11 24 W 95 28 3! S 11 ~ W ~1 ~8 17 S 11 11 w 5000,00 4741 5100.00 4831 5900.00 4922 m015 530o.00 5400.00 ~110 5500.00 5205 5600,00 5302 5700.00 5399 5800.00 5497 5900,00. 5595 4656 86 26 44 4746 95 95 22 28 18 5025,t8 18 21 68 5i20,68 16 30 5412,30 11 27 47 5510,47 lO 27 S 13 20 w S 13 10 w 1127.87 107 ~,43 ~ !1 53 W' 1]62,53 8 Il 52 W 1199,23 8 12 56 W 1232.65 S 14 45 W 1262,28 S 15 28 W 128~,50 S 23 21 w 1311.34 ~ 3537 W 133!,56 S 46 46 ~ 1348,48 6nO0.O0 5694 04 5600 04 6100.00 5792 6200.'00 5892 13- 3 15 6300,00 5991 6400.00 6090 6500.n0 6189 6600.00 6289 6700,00 6388 6,96.O0 6484 98 5707 98 5807 35 5906 63 6005 63 93 6104 93 30 6~04 30 7~ 6303,73 18 6399,18 8 54 7 50 7 18 6 59 6 49 6 35 6 15 6 6 6 6 S 49 52 W 1362 37 51 23 W 1374 15 S 55 33 W 1384 32 $ 56 12 w 1393 67 ~ 56 4 w 1402 73 8 56 3 W 1411,~7 S 55 33 W 1419.92 S 53 3 W 1428,26 S 53 3 W 1436.27 4000 O0 3862 67 3777 67 29 9 4100 O0 3949 99 3864 4200 O0 4037 2~ 3952 4300 O0 4124 50 4039 4400 O0 4212 55 412, 4500 O0 4300 88 4215 4600.00 4388 96 4303 4700.00 4476 95 439, 4800.00 4564 81 4479 49 00,00 4652 S 12 32 W 602 19 650 86 699 65 748 43 795 77 842 60 889 88 931-31 98 98 82 4567 82 27 56 S 11 56 W 1037 37 0 49 0 0 42 114 0 38 0 28 0 49 0 9 2 57 0,69 3.99 1.42 1,7~ 74 1 22 0 95 0 47 0 49 0 36 0 76 0 99 0 O0 0 O0 581 78 S 155'49 W 602'20 $ 14 57 W 629 39 S 165 81W 650,87 $ 14 45 W 677 21S 175 77 W 699,65: S14 32 W 725 11S 185 40 W 748,43 $ 14 20 W 817 45 S 204 48 W 842;64 $ 14 2 W 8 63 84 $213 98 W 889,94 S 13 54 "' 910 43 S 223 30 ~ 937.4! S' 13 46 957 30 S 232 44 W 985,.11 $ 13 38 W 1003 84 S 241 77 W 1032.55 8 13 32 ~ 104 ! , 1~07 1342. 1349 1356 1362 1368 1374 20 $ 251 ~ 271 278 :39 8m .28 18 S 9 S 299 0 S 3O6 47 S 316 65 S 329 W 29 W 69 W 1288;77 S 13 26 W ~1 W 1311,5, S 11 31W 45 w ;70 W 134~ S 49 ,53 $ 14 8 W 7. S 353.2 W 1 ~9 S 363.66 W 1184 76 8 373,97 W 1393 54 S 383.87 w 1403 4 8 393~60 W 1412 34 S 402.94 W 1420 72 S 411,55 W 1.429 86 S 419,73 W 1437 37 S 1432 7 S 14 53 0 S 15 13 67 $ 15 33 O8 $ 15 52 11 S 16 11 68 S 16 28 25 S i6 44 50 $ 16 58 ENGINEER: T,: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTTCAL DOGLEG RECTANGULAR COORDINATES HORIZ' DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,:. AZIMUTH FEET DE~/100 FEET PEET FEET DEG MIN KUPARUK NORTH COMPUTATION DATE: 24-APR'g5 PAGE DATE OF SURVEY1 11 APR 85 KELLY BUSHING EbEVATIONI ENGINEERI T. WEST XNTERPOLAT£D VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG: MIN D£G MIN 0 O0 0.00 -85.00 0 0 1000'00 9q9.99 914,99 0 2000:O0 1999,96 1e14,96 0 27 3000.O0 2992,9~ 2897,98 21 57 400~ 00 3862.,67 ~777,67 29 5000~00 4741.86 4656.86 ~6 6000.00 5694.04 5609.04 8 54 6796.00 6484.18 6399,18 6 6 VERTICAL DOGLEG S£CTI~N SEVERITY FEET DEG/IO0 N 0 0 £ ~o00 S 84 14 E '0.65 N 0 41 ~ S 14 4] W 128,00 32 1 60~ ~ 077, 49 52 W 136~.37 S 53 3 W 1436.27 0.00 ,9~ ,49 0.69 1.22 0.00 3 85,00 FT RECTANGULAR COORDtNATES' HORIZ' DEPARTUR£ NORTH/SOUTH EAST/WEST DXST,~ AZIMUTH FEET FEET FEET DEG 0.00 N 0,.34 1,97 124,76 S 581,78 S' 048'20 13~8,71 S 1374.86 $ 0 00 E 0 3 89 Z 3 3 78 E 4 28 8~ W 128 155 49 W 602 251 98 W t078 342 13 w i362 419 73 W 1437 00 N 0 0 g 90 S 85 332 E 26 N 62 $ 14 50 $ 16 58 ARCO 3R-14 KUPARIIK NORTH SLOPE,ALASKA COMPUTATION DATE~ 24-APR-~5 TRUE ;UB-SEA COURSE IEASURED VERTICAL VERTZCAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0 O0 85 O0 185 O0 285 O0 385OO 485 O0 595 O0 685 O0 795 O0 885 O0 DATE OF' SURVEY{ 11 APR ii5 KELLY BUSHING EL, EVATION{ ENGINEERI T, WEST 0.00 85,00 185.00 ~8~,00 485 O0 505 O0 685 oO 785 O1 88~,01 PAGE 4 85,oo 1t88 Ol 1185 1285,01 i285 1385,01 1395 1485,02 1485 1585.02 i585 1685,02 1685 178~,02 1785 188~,03 1885 O0 1100 O0 O0 l~O0 O0 O0 1300 O0 O0 1400 O0 O0 l~O0 O0 O0 1600 O0 O0 1700 O0 O0 IRO0 O0 0 12 ~ 87 9 E '0,74 0 11 ~ 75 7 ~ -0.82 0 1~ S 36 44 E -0,68 0 1] S 15 3 £ -0.37 0 14 ~ 23 14 E 0,05 0 ? ~ 24 17 E 0,20 0 2? ~ 31 2~ ~ 0,1i 0 49 ~ 22 2~ W -0.80 0 4~ ~ ~2 31W '1.85 1085,04 !98~ O0 2089,04 2185,04 ~185 2~85.05 22m5 2385.!0 2385 248~ 41 2485 258~:~0 2585 2687'87 26~5 2790,91 2785 2895,54 2885 lOOO,O0 0 27 O0 2000,00 0 26 O0 2100,00 0 27 O0 2~00,00 0 18 O0 2300,00 3 9 O0 2400,00 5 4~ O0 2~00.00 8 37 O0 2600.00 12 1! O0 2700.00 15 25 O0 2800.00 18 38 w 2 ] w -2.74 N 10 17 E -~ 53 S 44 45 E '4' S 0 30 W -2'12 ~ 12 38 W 5.54 $ 17 ! W 18 ~ 15 54 V 36,]5 $ 16 14 W 61,14 S 14 22 W 91.83 3n02,!7 2985,00 2000,00 22 3111,45 3095,0o 3000,00 25 27 223 52 ]185,00 3100.00 78 13 338"03 3285,00 3200,00 29 21 452'92 33R5 O0 3~00,00 29 24 ~67~57 3485 O0 3400,00 29 14 3682,16 3585 O0 3~00,00 ~9 3796,68 3685 O0 3600,00 29 6 3911,08 ]785 O0 3700,00 79 6 402~,57 3885 O0 3800,00 ~9 10 S 14 41W 128.81 $ 14 48 W 172.81 S 17 27 W 223.37 S 17 57 W 279,05 S 16 54 W 335.56 $ 15 4~ W 391,59 S 15 0 W 447.53 S 14 4 W S 13 11W 558.91 $ 12 21W 614.63 985,01 1088.01 0 0 N 0 0 E 0.00 0 17 N 62 26 E -0.16 0 12 N 57 4 ~ -0,39 0 11 N 54 26 ~ -0.64 0 ~ ~ 75 47 ~ "0,81 0 5 S 79 40 ~ -0.90 0 1] S 67 44 E -0,89 0 18 8 60 40 ~ -0'79 0 22 S 65 47 ~ -0.65 0 21 S 75 50 E -0,61 '85,00 0 O0 100 O0 200 O0 3O0 O0 4OO O0 500 O0 600 O0 700 O0 800 O0 985 O0 900.00 i085 O0 1000.00 0 O0 0 47 0 08 Ooi o6 16 0 ! 9 O, 25 0 3~ 0 o 0 04 0.03 0 2~ 0 O8 0 3 0 71 0 78 0 23 0 '10 0 {4 2 O2 2 77 2 86 2 9.5 3 5? 2 4~ 2 74 2 85 2 84 2 85 0 92 0 86 0 49 0 36 0 53 0 43 0 31 0,00 N 0,00 0,12 N O,l? 0.24" 0,59 O~ 44 N 0,86 55 N 1,11 0:58, N 1,34 50 N 1,61 0.28 ~ 2.0~ o..oo . O, 21S 3,2i 0328 0348 0 36 S 0578 0938 1298 I 59 S 0 87 N .64 3 ,40 .77 1.04 N 6,64 S 18,71 8 36,26 8 60,~0 S 89, 3 S 0 E 4 61 E 4 7 E 5 082 r. 5 13 ~ 526 E 4 ~0 ~ 4 02 E 3 78 ~ 3 86 E 4 04 E 4 30 E 4 44 E 3 51 E 0 02 F. 4 99 W 11 80 W 19 81 W 125154 S 29 06 W 269 593 · 128 10 S 40,23 w 172 74 S 54,05 w 223 79 8 71,30 w 279 75 $ 88,30 W 335 60 $ 103,91 W 391 56 8 !32,78 W 503 5? S i45,84 W 558 94 S i~8,17 W 6t4 0:00 N 0 0 E 4 4 4 5 5 5 5 4 4 8 85 8 E S 85 22 g 62 $ 85 35 E 90 8 83 22 E 1! S 79 30 E 29 S 75 55 E 49 S 73 17 E 39 S 74 10 E 72 S 85 8 E 12 N 77 SO E 4 21 N 63 58 E 4 5 5 4 7 18 36 61 91 67 N 55 36 E 29 N 49 54 E 72 N 48 46 E 56 N 76 48 E 51 S 27 5 73 S 0 3 60 so 25 S ll 6 W 8q S 12 27 W 86 S 13I W 84 S 13 27 W 38 8 14 0 W 05 8 14 48 W 58 $ 15 15 W 63 S 15 23 W 59 S 15 22 W 39 S 15 17 W 93 $ 15 7 W 64 S 14 5~ W INTERPOLATED VALUES FOR EVEN 100 FEET Or SUB-SEA DEPTH VERTTCRb DO~LEG RECTANGUbAR COORDINATES HORXZ;,!. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIS?, AZIMUTH FRET DEG/IO0 FEET FEET FEET DEC MIN ARCO ALASKA, ZNC. KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE IEASURED V£R?ICAL VERTICAL DEVIATION AZ[MU?H DEPTH DEPTH DEPTH DEG MIN DEG MIN COMPUTATION DATEI 24-APR-85 PAGE 5 DATE OF SURVE¥t 11 APR 85 KELLY BUSHING EbEVATZON{ ENGTNEERI T. NEST iNTERPOLATED VALUES rob EVEN 100 fEET OF SUB-SEA DEPTH VERTTCAb DOGLEG RECTANGULAR cOORDINATES HORIZ., DEPARTURE SEC?ION SEVERITY NORTH/SOUTH EAST/WEST D[ST.~ AZINUTH r£gT DE~/IO0 fEET fEET FEET DEG. MZN 4K95.50 4385 470q.16 4485 4829.91 4595 4935,~9 4685 5049,34 4785 5158.80 4885 4140.10 3985 O0 3900 O0 29 15 4~54 74 40~5 O0 4000 O0 29 14 4368"~4 4185 448~:q9 4285 O0 4200 O0 28 4 O0 4100 O0 28 O0 4300 O0 28 20 O0 4400,00 O0 4~00.00 28 19 O0 4600,00 ~7 9 O0 4700,00 ~6 O0 4800.00 23 19 5266.q0 49~5 O0 4000.00 5373 42 5085 O0 5000.00 5478:44 5185 O0 5100.00 16 36 5200.00 5]00.00 O0 14 3~ O0 12 41 O0 5400,00 11 36 O0 5500,00 10 35 O0 5600,00 9 O0 5700.00 7 54 O0 5800.00 7 558~ ~6 52~5 5685 14 5385 5781 45 54~5 5889 ~5 5585 5990 85 5685 6091 q4 ~7~5 619~ 81 5885 7 0 6 49 6 36 6 15 6 6 6 6 S ~1 48 w 670.41 $ 11 20 W 726.39 S 11 42 w 781.23 S 11 46 w 834.11 S 11 24 W 887.74 8 11 3 W 941,68 8 11 1~ W 995.78 S ~2 47 W 1049.13 ~ 12 56 W 1099,66 8 13 0 W 1146,53 S 11 57 W 1187,5! S 12 17 W 1224.'5 S 14 19 W 1~56.21 S 15 21W 1284.05 S ~1 34 ~ 130~.16 8 33 52 W 1329.20 R 45 5q W 1346.83 $ 49 57 W 1361.~2 S 51 14 W 1373.~6 S 55 2e W 1383.63 S 56 13 W 1393,09 S 55 54 W 1402.22 S 56 ~ W 1411.15 S 55 55 W 1419.56 S 53 3 W 1427.95 S ~3 3 W 1436,~7 6293 60 5985.00 5900.00 6394 33 6085.00 6000.00 6495 03 6185.00 6100.00 6~95 67 6285.00 6~00.00 6696 ~5 63~5.00 6300.00 6796.00 6484.18 6399.18 0 '20 0 24 I 28 0 68 0 43 0 38 0 94 1 86 1 21 2 8] 2 41 312 2 25 1 66 '2 86 3 12 2 04 I 21 [ 48 0.54 0.33 0,77 1,16 0,00 0,00 648 54 S 57 8O9 861 914 967 1020 1069 1115 169 83W 670 46 S 181 07 W 726 31 S 191 92 W 781 13 S 202 75 W 834 7 4 S 213 56 W 887 72 S 224 14 W 941 91 S 234 55 W 995 23 S 245 36 W 1049 43 S 256 91 W 1099 09 S 267 60 W 1146 85.00 FT 1155 1191 1222 1249 1272 1291 1306 1335 · 21S 276,16 W 1187,76 S 13 26 W 10 S 283,71W 1224 4~ S 13 23 W 31 $ 291.08 W 1256 49 8 13 23 W 20 S 298 31 w 1284 32 S 13 25 W 25 8 305 45 W 1308 40 S 13 .30 W 40 8 315 41 w 1329 36 S 13 43 W 32 S 32807 W 1346 89 8 14 5 W 81 S 341 05 W 13~1 22 S 14 30 W i342 1349 1355 1362 1368 1374 33 S 373 83 8 3 O7 S 4O2 48 8 411 86 S 419 32 W 1393,28 $ 1~ ;2 W 31W 1402.56 $ 1 I W 13 W 1411.68 S 16 10 W 23 W 1428.93 $ 16 43 W 73 W 1437,50 8 16 58 W 41 $ 14 40 W 39 S 14 26 W 25 S 14 13 W 4 $ 14 4 W I S 13 55 W 92 S 13 " 88 S 1330 75 S 13 29 W ARCO AbASKA, ~NC, 3B-14 KUPARI.IK NORTH SLOPE,ALASKA MARKER TOP UPPER SAND BASE UPPER SAND TOP bOWER SAND BASE tOWER SAND PBT~ TD COMPUTATION DATE~ 24-APR-85 INTERPOLATED VALU£S FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 6293,00 6351 O0 ~411 O0 65R5 O0 6688 O0 6796 O0 PAGE 6 DATE OF SURVEYI 11 APR 85 ' KELLY BUSH]lNG ELEVATION~ 85,00 FT ENGINEER~ T, WEST OR~GIN= 109' FSL,792' TVD FROM KB SUB-SEA 5984.41 ~899'41 6041.~ 5956.98 .39 6199.39 6~76.~0 6291,80 6484.18 6399,18 SURFACE LOCATION AT 1342 29 8 1346 24 S 1350 27 8 1161 42 S ! 5 $ 1374 86 'S 401 41 O6 W 05 W 53 W '73 W ARCO ALASKA, tNC. KUPARUK NORTH sLOPE,ALASKA MARKER TOP. UPPER SAND BASE TIPPER SAND TOP. LOW~R SAND BASF LOWER SAND PBTD TD COMPUTATION DATEI' 24-APR-85 MEASURED DEPTH BELOW KB 6293 On 6351 O0 641i O0 65R5 O0 6688 O0 6796 O0 PAGE DATE Op SURVEY1 11 APR 85 KELLY BUSHING ELEVATIONI 85,00 ENGINEERI T...: WEST SURFACE LOCATXON ORIGINm 109~ FSL,?92" FEL~SEC 16,T12N'RgE.uM RECTANGULARCOORDINATES TVD SUB.SEA NORTH/SOUTH EAST/WEST FROM KB 5984 41 6041!98 6101 56 6~74,]9 6376,80 6484,18 5899 41 5956 98 6016 56 6 8O 6399 19 1346,~ 1350, ~ S 136~'425 136~.95 1374,86 S 1ti.o6 . ,95 W 410,53 " 419,73 W ?INAL WELL LOCATION AT TD~ TRU~ SUB-SEA MEASURED VERTICAL VERTTCAL DEPTH DEPTH DEPTH 6796.00 6484.i8 6399,18 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MEN 1437.50 S 16 58 W SCHLUMBEROER O I REC T [ ONAL SURV E Y COMPANY ARCO ALASKA I NC WELL 3B- 14 FIELD KUPARUK RI VER COUNTRY USA RUN ONE DATE LOOOEO i1 APR 85 REFERENCE 00007031S WELL NAME: 3B- 14 SURFACE LOCATION: 109' FSL, 792' FEL, S1-6, T12N, R9E, UM V~RTICAL PROJECTION 14. - ] SO0 - ! 000 -SOO 0 0 ~00 ] 000 ] E~O0 ~000 '"~'"~'"~"~ '~7'~'"~ ....... ~'"~'"T"~ ....... ~'"F'T"'~ ...... 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'-'~'"~'"'~--~ ....... t ...... ¢ ........... ?-r"~ ....... ~-"~'--t-? ....... t'"t"'~-'"~ ...... ~-"~-'-~'"'~ ........ ~-'-~'"~-'~ ...... ~"T'T"~ .... ~'-?"~ ........ ['-~ ........ ~-~ ...... ;'-?'"'~-"r'"I'"'?~"'~ '? ...... ~'"r'"~"'~'i' 'F'~'-r"'~ ....... '"?"?"'r:'"~"?":'"~ ...... ,'"~'"?'"?~"'?'"'~"~'-~ ...... ~""r~"'?"f"?"~'"?'"~ ........ ~mnn~:~'"?"~ ....... r~'"~'"~'"'r'"~"'~'"?'": ...... ~"'~""?"~"'r'":'"~'"'~""~'"{'"~'-~'"'r""r"r'"r'"?"~'"'~ ....... r"?"T"r"~'"'~'-":'"~'-'~'" PROJECTION ON VERTICAL PLANE lg4. - 14. ~I:II. ED IN VEI~TICI=I. DEPTHS HORIZ SCRLE = I/SO0 IN/FT form ro be inserted in each "Active" well folder to d~.eck fo~ timely ccmpliance with our regulations. ' Operat6r, W~i 1 ~ame ~d Numar ' Reports and Materials to be received by: Required Date Received Remarks · ~ ._ Ccmpletion Report ' Yes · _ / '-.'- Core ~scr~p~cn ' . Inclina~on S.~ey . Drill St~ ~Re~s, , ~~~. .. ~~n T~t Re~rts ~~~ R~ > Yes "' ~: . . Digitiz~ ~ta y~ FROM: L. K. SMITH/P. S. BAXTER WELL NAME: TRANSMITTED HEREWITH ARE THE FOLLOWING: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, ~T - TAPE, PC - PHOTOCOPY RECEIPT ACKNO%~LEDGED: PLEASE RETURN RECEIPT ~: ~.--'%RC0 ALASKA, 'INC. ~/ ATTN: PATSY S. BAXTER P. O. BOX 100360 ANCHORAGE, AK 99510 ATO/507 DATE: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COP~.!ISSION TO: C. V/~~terton DATE: }'[arch 19, 1985 Cha~a~- THRU. Lonn£e C... Smith . - i ~'-~{ Commissioner FROM: F,LE NO: D. EWS. 15 TELEPHONE NO: Edgar W. $ipple, Jr~ Petroleum Inspector SUBJECT: Witness BOPE Test on ARCO' s Kuparuk 3B-14, Sec. 16, T12N,R9E,UM, Permit No. 85-24, Parker Rig 141. Wednesday, ~iarch 13, 1985: I traveled this date from ARCO's lQ-4, T~-e-C-~the~'report) to ARCO's 3B-14, Parker Rig 141, to witness a BOPE test. The drilling contractor was in the process of nippling up. Thursday, l~arch 14, 1985: The BOPE test commenced at 2:45 am and Was ~'°nclUded-~t~5': 3:0 ~. There was one failures. ~ne check valve leaked, the rubber seal on the flapper was changed out and the check valve tested to 3000 pounds satisfactorily I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 3B-14, Parker, Rig 141. Attachment 02~001A(Rev. 10/79) O&G #4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator A~'- Well Location: Sec IL T;~ R~'~A M Drilling Contractor Location. General ~ Well SignO~ General Housekeeping 0 ~ Rig Reserve Pit ~ ~ Mud S~stems Visual Audio Trip Tank Pit Gauge Flow Monitor ~/~ Gas Detectors ~ ~A~ BOPE Stack Test Pressure ~r Preventer ~ Pip,Rams O~ ~D~ Blind Rams '0~ ~ Chok"e Line Valves Choke Manifold No. Valves ~ No. flanges ~ Adjustable Chokes HI~.R. Valve ~. ..~0~, ~ Kill Line Valves ~)~lt C~e~c~ ~lve ~, ,, ~.~ HMdrauicall~ operated choke Test Results: Failures --~ ~ Test Time ~ ,hrs. Repair or Replacement of failed equipment to be made within ~/A days and Inspector/ Co, lesion office notified. Well £-'/'/ Representative O~. ~55~ 7~ Permit # ~-z~ ~ Casing Set 8 ~ ft. ~ # ~ q/ Representative ~, ~L~ ~ ACC~LATOR SYST~ Full Charge Pressure ~ psig ~ Pressure After Closure f~ psig f2~4 Pump incr. clos. pres. 200 psig. ~ min OOsec. Full~ Charg~ Pressure Attained:~ ~ mind,sec. N Controls: Master.. ~ ~ ~ ~ Kell~ and Floor Safet~ Valves Upper Kelly ~ ~ ~ Test Pressure ~ Lower Kelly ~ ~Test Pressure ~ Ball Type ~ ~est Pressure ~ Inside BOP ~ Test Pressure ~ m~ OK Test Pressure ~e~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector~ March 5, 1985 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Uni~ 3B-14 ARCO Alaska, Inc. Permit No. 85-24 Sur. Loc. 109' FSL, 791' FEL, Sec. 16, T12N, R9E, UM. Btmhole Loc. 1108' FNL, 1108' FEL, Sec. 21, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated February 19, 1985, accompanying the original approved permit are in effect for this revision. Very___t~ly yours, . C. V. Chattertpn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION lc Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc.~--x Post Office .~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 26, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3B-14 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 3B-14 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 March 14, 1985. questions, please call me at 263-4970. Si n~c~rely, A~ea D~lling Engineer JBK/HRE/tw PD/L48 Attachments If you have any RECEIVED 2 7 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK,, .)IL AND GAS CONSERVATION G,~MMISSION PEltMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~x DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE~ 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface D 109' FSL, 791' FEL, Sec.16, T12N, R9E, UM (App~,~ At top of proposed producing interval 0ii (~ ~ CO/;,~ 1108' FNL, 1108' FEL, Sec.21, T12N, R9E, UM A.,'TCllOt.age' CO~il;$ At total depth 1108' FNL, 1108' FEL, Sec.21, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 85', PAD 55' ADL 25633 ALK 2566 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 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles 109' ¢ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6709' MD, 6432' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2205 feet. MAXIMUM HOLE ANGLE 33 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name Kuparuk River Unit 10. Well number 3B-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 3B-13weII 60' ~ surface feet 18. Approximate spud date 03/14/85 2810 psig@ RO°F Surface 321F; _psig@ 6_?30 ft. mD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Casing Weight ~16" 62.5# 9-5/8" 36.0# 7" 26.0# CASING AND LINER Grade Coupling H-40 We1 d J-55 BTC HF-ERW J-55 BTC HF-ERW Hole 24" 12-1/4" 8-1/2" 22. Describe proposed program: SE I T'ING DEPTH Length MD TOP 80' 29' I 29' 3265' 29' I 29' 28' I 28' 6681' TVD MD BOTTOM TVD 1091 109' 3294~ 3236' I 6709'1 6432' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 830 sx AS Ill & 450 sx Class G 245 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6709' MD (6432' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3294' MD(3236' 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. Expected maximum surface pressure is 2810 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. The Kuparuk Sand will be cored. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I herebT~r~'l~ that the foregoing is true and correct to the best of my knowledge The spa~ f¢ '~ o~se? ~ CONDITIONS OF APPROVAL Samples required I Mud log required []YES J~NO I [-]YES [~NO Permit number Directional Survey required APl number /[~YES []NO 50- 0 2. ~ - Z i 7_ ~ 7 Form 10~401 ] Approval date . 8 5 APPROVEDBY //,~~ ~~,COMMISSIONER DATE (,~.... ' ", ~:~-~~~ by order of the Commission (HRE) PD/PD48 ~ / / / SEE COVER LETTER FOR OTHER REQUIREMENTS March 5, 1985 Submit in triplicate PERMIT TO DRILL 3B-14 installed and tested upon completion of the job. 3B-14 will be 60' away from 3B-13 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5223'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 workover rig has moved off location this well will be fracture stimulated. 1 000 2000 3000_ 4000_ 5000_ 6000_ 7O0O BASE PERMAFROST TVD=1616 MAX ]: HUH AN GL E 32 DEG 39 - TOP UGNU SNDS TVD=2036 KOP TVD=2205 TMD=2205 DEP=O 3 BUILD 3 DEO 9 PER 1 O0 FT 15 TOP W SAK SNDS TVD=2731 TMD=2738 DEP=74 ~2! K-12 TVD=3036 T~D=3065 DEP=190 x~ EOC (CSO PT) TVD=3236 TMD=3294 DEP=30227 ~, BEGIN ANGLE DROP 30 X TVD=3785 T~D=3946 DEP=654 24 ' DROP I 1/2 DEG ~;8 ~ PER 100 FT 11~$~ K-5 TVD=5206 T~D=5480 DEP=1204 3 END ANGLE DROP TVD=5846 TMD=6123 DEP=1258 ~ ~ TOP UPPR SNDS TVD=5946 THD=6223 DEP=1258 , ; TARGET CNTR TVD=6066 THD=6343 DEP=1258 ' - TOP LOWR SNDS TVD=6104 THD=6381DEP=1258 BASE KUP SNDS TVD=6232 THD=6509 DEP=1258 TD (LOG PT) TVD=6432 THD=6709 DEP=1258 I I 1000 2000 VER!T t CAL SECT I ON PAD..~B, I~'LL NO~ 14 REVISED PROPOSAL KUPARUK FI.ELD. NORTH SLOPE. ALASKA _ EASTMAN WHIPSTOOK. z 1000 I 1000 _ 2000 _ 3000 _ 2OOO WEST-EAST 1000 0 I I CE 1000 I SURFACE LOCATtO# t 1~' FSL. 7,91' FEL SEC. 16, T12N. RgE TARGET LOCATION ~ 1108' FNL, 1108' FEL SEC. 21. T I2N, RgE TARGET CENTER TVD-6066 TMD-6343 DEP- 1258 SOUTH 1217' WEST 317, S 14 DEG 36 HI N W 1 258' (TO TARGET) 200 _ 100 _ m 1,00 200 _ 500 NORTH 400 1 300 1 200 11 O0 1000 900 800 I I I I I I ?00 ~ ARCO ALASKA. INC. PAD 3B. WELL NOt 13-14-15-16 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. NOTE, WELL PATHS EXTEND BEYOND I,' Surfece Diverter System i6"-2000 psi 7~nkco s~.ertin.c he~c. l~nkco ~uick connec'. ~-ssy. 16" X 20': 2000 psi Coubie s~.ucoec a~a~.er. 20" 2000 psi trilling spool w/id" side ouziezs. lC" bell velves~ hvoreu';icaliv ecsu~sed, w/lC" lines closure of ennuler proven%er. 20" 2000 psi ~nnuler preve~ser. 20'~ Dell ~ippie. verify ~he% ,b~ii veives hove o.~enec properi~ 2. Close 8nnuier prevenser eno' ~i~ ei r %brough. divester lines every ]2 hours. Close annulet preventer in she evens tr, a~ ~es or fiuiC flo- So surfe~e is deSecSec. ~f necessary, m~nueii>' override anc close Deli vsive %c uDwlnC Civet%er line. De no% sbu% ir, ~e!i under ~nv circums%~nces. i 6" C~nouc'cor ¢¢..,,,,.. 6 i' > > DIAGI~AA4 #I 1~-5/8' 5C~ PSI R~EA BOP STACK 2. ira' - ~ ~I ~I~~ K~LL LI~S ACOJMJI,.ATC~ CAPACITY TEST I, ~CX ~ FILL ._~Z:I3JIvU. ATC);~ ~L ~TH ~IC 2. ~ T~T ~AT~ I~ ~I ~~ ~ T~ ~T~, ~ ~ ~ ~T, T~ A~~ L~ LI~T IS 45 ~~ ~I~ TI~ ~ l~ ~I ~I~ 5 4 3 13-5/8" ~ STACK TEST 1. FILL BCP STA~CX AN:) ~ NIINNFIF~ WITH AI~CTIC DIESEL, F~LY ~~, ~T TEST ~TH ~I~ JT ~ ~ IN 3. ~ ~ ~~ ~ ~I~ ~t~ ~L~~ LI~ 2 WiTH A ~ ~S1 LOW ~ 3000 ~'8I MION, TEST A~ IN STEP 4, ~ NI~T ~3~;;~-_~j;~ T~"F ANY ~ A FULL O,.O'$INS ~iTiv~ SEAL FLINI~TICIN llr. Sl ~--_..--I[~F5 THAT CO NOT FULLY 8. ClaN TCP PI~ RAMS Ah~D ~T ~ PI~ R~ TO ~ ~I ~ ~ ~I. 9. ~N ~TT~ PI~ ~ I0. ~ ~I~ ~ ~ T~T TO ~I. il, ~N~I~ ~ ~ I Z. ~ST ~I~ v~ ~y, ~y ~ ~I~ ~ ~I. ~ECC~ 1EST IN'rCI~TION ON 84,0~ ~'VEhq'~ TEST SIGN,, ~ ~ TO C)~!LLIINI3 Sk, P~RVI~. W~CEKLY ~AFTE~ FLINL"TI~Y (3:F. RATE I)OPE 13AILY. February 19, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3B-14 ARCO Alaska, Inc. Permit No. 85-24 Sur. Loc. 109'FSL, 791'FEL, Sec. 16, T12N, RgE, Btmhole Loc. 1320'FNL, 1320'FEL, Sec. 21, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 A~C 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 operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kew, zn Kuparuk River Unit 3B- ! 4 -2- February 19, 1985 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 o,~zzce adequate advance notification so that we may have a witness present. Very truly vours, C. V. Chatterto~ / Cha±rman of Alask~ Oil ~nd Gas Con~e:~,~ation Commission BY ORDER OF ~E CO~ISSION be Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~,.. 100360 Anchorage, Alaska 99510 Telephone 907 276 '~215 February 11, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3B-14 Dear Mr. Chatterton' Enclosed are: We estimate spudding this well on March 14, 1985. questions, please call me at 263-4970. An application for Permit to Drill Kuparuk 3B-14, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment If you have any JBK/TEM/tw PD/L33 Attachments RECEIVED FEB I 1985 Alaska 0il & Gas Cons. ~m,qissJon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,..,L AND GAS CONSERVATION Ct..,~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL 13qX REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE j~ 2. Name of operator A_de_ssARC0 Alaska, Inc. 3. p'dro-- Box 100360, Anchorage, Alaska 99510 109' FSL, 791' FEL, Sec.16, T12N, RgE, UM At top of proposed producing interval 1320' FNL, 1320' FEL, Sec.21, T12N, R9E, UM At total depth 1320' FNL, 1320' FEL, Sec.21, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) ! 6. Lease designation and serial no. RKB 85', PAD 55' [ ADL 25633 ALK 2566 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 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 109' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6818' MD, 6432' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1955 feet. MAXIMUM HOLE ANGLE 42 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name Kuparuk River Unit 10. Well number 33-14 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 3B-13well 60' ~ surface feet 18. Approximate spud date 03/14/85 2810 . psig@ RO°F Surface 3216 psig@... 6?30 ft. TD (TVD) SIZE Hole Casing Weight 24" 16" 62.5# 12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length MD TOP 80' 29' I 3330' 29' 6790' 28' SETTING DEPTH TVD 29' 1091t 29' 28' M D BOTTOM TV D 109' 3359'I 3236' 6818'1 6432' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 830 sx AS III & 450 sx Class G 245 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6818' MD (6432' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3359' MD(3236' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be insta]led on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2810 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. The Kuparuk Sand will be cored. Selected intervals will be logged. The we]l will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downho]e safety valve will be (see attached sheet) · 23. I here~ify that the foregoing is true and correct to the best of my knowledge l SIGNE~0 ~¢n ~ TITLE Area Drilling Engineer The spa (N ~ is~ion use-V CONDITIONS OF APPROVAL DATE Samples required Mud Icg required Directional Survey required APl number I--lYES [~,NO [~YES ,j]~,,o .~,YES E]NO 50- i~ 't,"~ - )--'1 '-i'_ ~ ~? Permit number Approval date ' '"'-- ~" ),~/(~//~/,~___.... SEE COVER LETTER FOR OTHER REQUIREMENTS (TEM) PD/PD35 APPROVED BY Form 10-401 ,COMMISSIONER DATE February 1 9, 1 985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3B-14 installed and tested upon completion of the job. 3B-14 will be 60' away from 3B-13 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5332'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 workover rig has moved off location, this well will be fracture stimulated. · ) : - ..t ' - ' z ' ~ . . .. : ~ .: ' . ~ :__~__-,._l. , ;-- ..t_.. _:~ .... : ._~_.j...~ . ' ..... ;--.i-.~,- ~ --.~.-: ........ ,9~- '. . ?- ..... -~ :-.:: :-: -'·; ":-::: .... ::-:~:. ,SCALE~- 1 ~._IN- ~ 1000 :FEE ::: ..... ~--~.~--i ·, .~--.-:--- ....... :--: -.~-L.__._._._~_~ .... _.~.-:_: ....:_~_,._~. :.~-:--:~__~-- r--'--,t-+-:--'-~-,'-7-;-: .... i'--"'-7-T."!,-.'--~..-":~T:.-T ,'i-:T-T-:: j ; : ~ '-'-]. : ' i :-~. ..... ; ; ..L.-.: ..... ~ i ' '----i'.' ~-"--; :..~..:_. '4' : ...... -__' .... _:._'_ ~-..4-..'--.:.4-----:-.-:--~--4--x-~ - ~ ~ ~ ~ ":--!'-'-~ --'-r--~ ..... T-~r-~----r----- 'T---"-T--*---'--T-T-T'-:-'-I-~ ; ..... : . I ' ~ ~ i · . , . . ' i ~ . . . ' _ '.'- · .... LT.,-_._..._: ....... .4- '.- ..'- ..... ...... --.:-:-?-.,: ;', ............ .... .... --'T. ~---,-----$ .... T "'~---:-- .i ~ ' - 1 · ,-: ' ~ ...... I ..... 1. . J. m _-; .1 ....... L ;--'-' ..... J ' ' , ' ' ' .} -.: .... z----'l:' ....... ~ ~ , · ! - .. ~., : .: ~.-.~-.. :::['_~_!_ ;_.:._L_.;_,._~~-: . .'-: -': ~-.:--t ....... u--.~.' , ~----~.-- i --~-~---'-'.-~-~ ~ ~ =': ......... .... :x.-~ .......... r- ?-'~'- ........ ---'";-'"~'--'-"I,-'~'-', · ' TI' .--r ;- T [~ ~. . ' i ~ : , ~ , . · . ~ . . ~ ~ : '. ' . ,,. . : - ' ' '-i, . . ' : . i 1,- ,;:. ~..;_ .... s_, ,I' J ' ~-' '~;--.~-, :' ':-J ;;-';, " ~ '~---~--~'-:---~-' ~ ...... ~ ~, ....- ....- ~ : ~.. ~ ! .... r-'T...' '-.~ ; ~ ...... ~__~ ! .. ' ' t ..... ' .... ;-4 ~-: ...... ~-F-:~::-'--~ .... ¢-' ARCO' ALASKA,--' INC'-'-.--:.-:-T .... ----:-~-. T.-'-,. ' '. ,..':/1['%:'::':-:_:.:..'i.-;-: "'; ':::: -;":: ~:-'.-~-T "-'-;-: ~ ~j ':'-' ":" P AD "3B ' .... WELL~ NO '-':i 4-: 'i REV I SED::P. ROPOSAL~,/:--:: [I--.--~'N,,---'-5:-L;-~-: :-::.-~--~-':~::-Y:-[:-:-~::--:-'.!:'-::::::--':-KUPARUK..FIELD. NORTH iSLOPE.--.ALASKA ---~ ,~_:.~/~.- .... '~:i--: .':"-...~_ ~ : ' ~ ~-..."i .- .' ......... ...... -- .... " .. ~ ': ' - .... :~--T- -: · : !'. ...., .- ', .... , -.__:.~ -- :.-' ..... :-i-:~-:-:---.-~- :. ,;_.,L:': .............. -~.-,.~..:.-. ....... !:. i' "---Ti-- .....:. ..... ......... ............ ........ ...... ......... ...... .= .... '-'- ...... : i-,--'.--.---:-'--'-, ..... '. EASTMAN-WHIPSTOCK.-- INC -:- ..... --,----}---- -:~I-:_~:: ,?-:-.i ':. '?.':.-:'-~--' ~- ' ----'---:----';' ...... -"L'~:-'-I--'~----;-:';--;--F' ; ~' ! t-'''- .......... J ' i - I --:- ....... ~ ...... '-'~- , '. .l ' , ,. , · ~ .. . ) ; ,.,. ! ~ · , ~.~ : - - ' ~ - ' --,~L~ ' , . 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' ..... : -. _ ' ' -~ '- - ~ ~:-~ ............. ~ .... ~----:---i ............ -TOP .LOVR SNDS-LLLTVD=6104 TI'ID=6490 DEP=1S24 ;-i ';'i;."Y; .:_.~ . --~ :....... !' I ................ ' ' -- ' ~ BASE KUP'SNDS---~TVD=6232 TMD=6618 DEP=1524- : ............ :- ' ..... ~ ...... ~ ...... : ......... : .......... ~ ......... .'.__.- ...... ~_.~_ TD]'-(LOG:~PT) ..... i_TVD~6432 TMD=681 8 DEP=I 524 .~ ..... - ..... . , ..... ......... ........... , ...... .................... ,..~ .... : .....z_..:. ~_:_ :.--:.--4 ~-':--'-~::-~ ~ ......... --.-' ----- -- ' ............ ~ ...... -- -- .'i ........ ' ............. "- -~ ......... "- ' . ..... i .- · ; ~ · "' ............ . }-r-~----;-x--:----: ..... ~ ~ ,,. ',. .... ~ ..... : ......... : ..... :..-.-.:.--~ ,' q -. ', --i.: ..... ~ .....~ . ~ .........' .... ~ ....... ~ ._L_2.;_ --~_ __' ~-- .~'.._;_~_~ ~ ...... ~ ............. , .... : ............ ........... ..... ,__ . .... ...... .... .... _: :_ .... ..... ..._... - . --!---:. ': ~ }-.'~-'- :- .'i : j. -i--.'- .... i ..~ :_::: _i.:-'.-._ ':" :FEe'1. ~ 1~§ 'i '-.: -.: [ .~.'-. ;' :' ':__-/--fYZ_ D_-../_';;_"L'~.'-~ ~ 000 ~000 ~ - .ii-.. ........ i ......... : .... ~o~_,~,~...,_~,~---~ · - - - .--: ............................ ~ ............ - __.~.~:-]L~/._'_'-.~.~!~_~-.../-'-J:_:.~-..': ~.-~:-_.'~-__/_.-'..i .i.~.i'-~'.ii.~_"/ .... .: ..... : ..... J-.-'--:=--~-:.:-'-:. --j-: .... · --~.. -. -,, Alaska Oil &-~as 8ohs. Comml~sjori . · -- , · : ! ' i . · I , . t ............... : ...................................... i ................... .~ ............. ; .... ~ ...... .. _ .'~...~. ......... .... ~'; ........ ~ ..... ~ .... :- - ' ..... i '" --~ .... ~ ....... , ._ __- . . _ .: ..---. .......... .. . ......... ~. :_~'_ . iPROPO~ : i NOTE~ t i Surface Diverter System 1. 16"-2000 psi Tankco starting head~ 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets.' 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & 0Deration 1. Upon initial instalJation' close annular preventer and verify Ehat 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 ~low to surface is detected. If necessar¥~ manually override and close ball valve to upwind diverter line.. Do not shut in well under any circumstances. 16" Conductor ! 7 6 -~-DI AGRAM #1 13--5/8' 5, _3 PSI RSRRA BOP STACK i. 16- - 2000 PSI T/~i<~ STARTII~ kEN) 2. II * - 3000 PSI CASING HEAD 3, II * - 3000 PSI X 13-5/8'-- 50(30 PSI SPACER SPOCL 4. 13-5/8" - 5030 PSI PIPE 5. 13-5/8" - 5000 PSI DRILLING SPOCI. W/Q-IOKE KILL LIltS 6, 13-5/8" - 5C00 PSI DCM~E RAM W/PIPE RAMS ON TCP, ?, 13-5/87 - 5000 PSI AI~L.IAR ACO. MJLATOR CAPACITY TEST I, (3-ECl< ~ FILL ACO, MJ.A'rOR RESERVOIR TO PRCPER LEVEL WITH HYDRNJ_IC FLUID. 2. ASSI.RE THAT ACO. MJLATDR ~ IS 3000 PSI WITH 1500 PSI DCI~ISTREAM OF THE RE(iJL.ATOR. 3. OBSERVE TIldE, TFEN CL_OSE ALL UNITS SIMJLT~~Y AN3 RECORD TIE TINE A~) ~ REMAINING AFTER ALL UI~TS ARE CLC~:~D WITH CHARGI~ ~ OFF. 4. RECORD ON N~i)C RI~>ORT, TIE ~ABLE LO~SR LIMIT IS 45 SE~ Cl. OSING TII~ ~ 1200 PSI REJOINING 5 4 ,I 13-5/8" BOP STACK TEST I. FILL BQ0 STACK AN3 Q-O<E IvlN~FO_D WITH ARCTIC DIESEL, 2. Q-ECK THAT ALL LOO( DOV~ SCREt~$ IN I~ELL~ ARE FLLLY RETRACTED. SEAT TEST PLUG IN ~E. LL~r_AD WITH RUNNING JT AhD ~ IN LOCKDOV~ SCRE~ 5. CLOSE ~ PREVENTER ~ MANJAL KILL ~ Q-O<E LI~E VALVES ADJ~ TO BCP STACK. ALL OTI-ER VALVES AM) ~ SHOJ_D BE OPEN, 4. PRESSLRE UP TO 250 PSI ~ HOLD FOR I0 MIN, IN-- CREASE PRESSURE TO 3K:XIO PSI AM~ HOLD FOR I0 MIN, BLEED PRESSLRE TO 0 PSI. 5, CPEN ~AR PREVENTER AhD ~ KILL AI~ O-O<E LIhE VALVES. CLOSE TCP PIPE ~ AI~ HC~ VALVES CN KILL /tho CHCKE LIliES, 6, TEST TO 250 PSI AhD 5030 PSI AS IN STEP 4. 7. CO~IN.E TESTING ALL VALVES. LIliES- ~ Q-IOKES WITH A 250 PSI LOW AM) 3000 PS! HIGH. 'rEST AS IN STEP 4, DO I~IT PRE~ TEST ANY CHO~ THAT ~S NOT A FULL CLOSING POSITIVE SEAL CH(~, CN.Y FLJ~TI~ TES[ CHCKE~ -[HA]' DO NO-[ FULLY CLOSE. 8. CPEN TCP PIPE RAMS AhO CLC~E BOTTOM PIPE RAMS. TEST BOTTOM PIPE RN~ TO 250 PSI AI~ 3000 PSI, 9. CPEN BOTTOM PIPE RAlv~ BACK OUT RLN~NG Jr. AM:) PLLL OJT OF HOLE, I0. CLOSE BL]NO ~ AhD TEST TO 250 PSI AI~ 3000 II. CPEN BLIP:) ~ ~ RE'rR[EVE TEST PLL~ lvlN<E SURE I~NIF~D ~ LIliES N;E FLLL OF ~EZING FLUZD, SET ALL VALVES IN DRILL[NG POSITZ~ 12. TEST STAhI~IPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AI~ INSIDE BOP TO 250 PSI ~ 13. RECOR3 TEST II~,FCRM~TION ON BLOVOJT PREVENTER TEST FORM, SIGN, AhD SENO TO DRILLING St~ERVISOR. PERFCRM ~TE B(3~ TEST AFTER NIPPLING UP ~ VEEKLY THEREAFTER FI.N:TIQNALLY OPE~TE B(~IE DRILY. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Loc ~ thru 8~ 3. (3) Admin/ (13 thru 21) thru 12) 10. o ai d' 12) (5) BOPE ~~.~--~. - ~'~~' (22 tl~k'u 26) Company ~ Lease & Well No. YES NO Is the permit fee attached .......................................... Is well to be located in a defined pdol ........ · .................... Is well located proper distance from property line ........... . ~'.. 4. Is well located proper distance from other wells .............. 5. Is sufficient undedicated acreage available in this pool .....' 6. Is well to be deviated and is wetlbore plat included. ........ 7. Is operator the only affected party .......................... __ 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~_~ Is administrative approval needed ................................... Is the lease'number appropriate ..................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones .. ' .............. 18. Will all casing give adequate safety in collapse, tension and burst.. 19. Is this well to be kicked off from an existing wellbore ............. 20. Is old wellbore abandonment procedure included on 10-403 ............ 21. Is adequate wellbore separation proposed ............................ 22. IS a diverter system required ....................................... 4~F 23. Are necessary diagrams of diverter and BOP equipment attached ....... 4~ 24. Does BOPE have sufficient pressure rating - Test to ~,~_~ psig .. 4~ 25, Does the choke manifold comply w/API RP-53 (Feb.78) .................. 26. Is the presence of H2S gas probable ................................. (6) Add o22~-~ 27. Additional requirements Additional Remarks: ~z Ho I--I Geo~logy:~Engineering: HWK .~"'-LCS yd~ BEW .....--2 rev: 10/29/86 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. J SHORE CMECK LIST FOR NEW WELL PERMITS Lease & Well No. ~ ~ ~-~J ~ ITEM APPROVE DATE (2) Loc ~ thru 8) (3) (13 thru ~1) (22' thr~ Company YES NO REMARKS Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ................. 4. Is well located proper distance from other wells ..' i. i'... ' 5. Is sufficient undedicated acreage available in this pool .... 6. Is well to be deviated and is wellbore plat included .............. 7. Is operator the only affected party ........... ...... [ ..... ' 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force ................. 10. Is a conservation order needed . ....... .....' ................ . . . 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cement cover all known productive horizons ...... 17. Will surface casing protect fresh water zones ..[[.--t ...... ...... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Is this well to be kicked off from an existing wellbore ............. 20. Is old wellbore abandonment procedure included on 10-403 ............ 21. Is adequate wellbore separation proposed ............................ 22. Is a diverter system required .................................... ,~ 23. Are necessary diagrams of diverter and BOP equipment attached'....[.[ 24. Does BOPE have sufficient pressure rating - Test to ~-~ psig . 25. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 26. Is the presence of H2S gas probable ................................. 27. Additional requirements ............................................. Geology: .Engineering.: Lcs WVA i t HJH# V rev: 10/29/84 ~'~ 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LVP 010~HOZ VERIFICATIDN LISTING ** REEL HE~DER SERVICE NAME :EDIT DATE :~5/03/Z4 ORIGIN : REEL NAM:.. : CONTiN[JATI3N # :01 PREV[O~S R~EL COMMENTS : e~:TAPE HEADER SERVICE NAME : DATE :85/03/24 ORIGIN TAPE ~. NAME : 01 95 CONTZNUATI3N ~ :01 PREVIOUS T~PE COMMEN~S : ~r4t "F IL E HEADER FZLE NAME :EDIT SEEV[CE NARE : VERSZO~t ~ : DATE : MAXZMUM LE,~GTH : FILE: T~PE ' PREVi02S F[[E ~ INFORMATION RECgRDS ~ ##EM CONTENTS .,,m, ,,,m, CN : ARCO ALASKA [NC lilN'~:' ; 38'14 FN : WEST SAK F:'IRMATION RI~NG$ ~ ~:' ::'?: ·::9 E' TOWN: 12M SEC T ~ ?~:,~:~ 6 COUN: N. SLOPE CT~Y: US COMTENTS PA~E RECEIVED JUNo ? ,1985 Alaska Oil & Gas Cons. Cor~lmJssion Anchorage TYPE CATE S[Z,E COOE 000 000 015 065 000 000 OOS 065 000 000 018 000 000 002 06S 000 000 003 ODS 000 OOO 002 065 000 000 007 055 000 000 006 065 000 000 003 TYPE CATE SIZE CODE UNIT OOO 000 001 065 I LVR 010'oHOZ VERI,I::I~AI'II3N LISTING PA~E Z SCHLUMBERGER : ALASKA 2IVISIDN CQMPUTING CENTE~ : COMPANY = ~RCO ALA$~ YELL = 3~-1~ FIELD = WESt SAK FO2MATION ~COUNT¥ = N.SLOPE STATE = ALASK :~"$ECT[gM = 16 TOWNSH:P = 12N RAMGE = 9E TAPE DENSITY = 800 BPI '~O'B t 70195 BASE LDG: OIL , RUN ~ ! OATE LOGGED 13 MAR 85 'BOTTOM LOG INTERVAL = JZSO FT. TOP LOG INTERVAL = 209 FT. CA$~MG~LgGGER = 16.000 IN. ~ BIT SiZE = 12.250 IN. TYPE .HOLE FLUID = GELEX {.09 FT. ~I LVP 010oHOZ VERIFICATION LISTING , , DENSITY VISCOSITY PH FLUID LOSS RM @ MEAS. TEMP. RMF @ ME~S. TEMP. RMC ~ MEAS. TEMP. RM @ LOP: T ~LSTEAD 9.30 47.00 9.50 16.20 5.640 @ 66 F 4.700 @ 66 F Z. 360 @ 56 F 0.000 ,~ 0 F PA~E DATA FORMAT REC3RO ENTRY 5LUCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 8 4 73 60 0 I 66 0 O~,TUM SPF. CIFICa, TION BLOCKS ~ MNEM SERVICE S~=RVICE dNiT AP1 APl AP1 ~Pi FILE SIZE SPL REPR ID ORDER $ LOG TYPE CLASS qOD NO. DEPT FT O0 000 O0 0 0 SFLU OIL OHHM O0 Z20 ~ ILD OIL DHMM O0 120 46 0 0 [LM OZL ~HMM O0 120 SP OIL MV ~0 010 gl 0 0 GR OIL GAPI O0 310 01 0 0 ~ GR LOT 6&PI O0 }10 CALI LOT IN O0 280 RH2B LOT G/C3 00 350 DRMO LOT G/C3 O0 355 ~ NRAT LOT DO 620 RNRA LOT O0 000 O0 0 0 6 NPHI LOT PU O0 890 OD 0 PEF LOT O0 358 O1 0 0 ~1~ NCNL LOT CPS ~0 .330 31 FC'NL LOT CPS O0 3~0 30 0 0 OR LSS ~API O0 310 DT LSS US/F OD 520 80 0 0 ~ DTL LSS ,. US/F O0 520 80 0 0 PROCESS CODE COCTAL) 68 O000000000000O 68 00000000000000 68 00000000000000 68 00000000000000 ~8 00000000000000 68 0000000000000~ 68 00000000000000 68 0000000000000~ ~8 00000000000000 68 00000000000000 68 00000000000003 68 00000000000000 68 00000000000000 68 00000000000000 b3 0000000000000~ 68 00000000000000 68 O00OO000000000 58 00000000000003 6E 00000000000003 i LVP 010.HOZ VERIFICATION LISTING S TPL EATT ' FVB CALl GR EPE NS/M O0 131 O! 0 EPT 3B/M O0 130 01 0 EPT ¥ O0 000 O0 0 EPT V O0 000 O0 0 EPT ZN O0 280 Ol 0 EPT GAPI O0 310 O1 0 .... ,~* DATA DF. PT SP RHOB E'ATT GR DEPT .... RHOB ~R ' E~TT ' ,,,,~ ~ ~R . .~ ~ ,-.. 3198.5000 SFLU -999.2500 GE -131.7500 ORHO 1.1719 PEF -399.1500 DT 323.5000 FVD 8~64,.0000 3200.0000 SFLU -3Z. 7500' GR 2.2676 ORHO 43-4570 PEF 77.1875 gT 314- ~166 FVO 111.~375 3100.0000 SFLU -31-375'0GR Z.1777 ORHO GR 7~.1875 DT EA~TT~ ' ]74-4166 FVD GE 93.0615 DEPT 3000.0000 SFLU SP~ -29~2187~ GR RHO6 2.15~3 DRHD NP~Z 45.3125 PEF :~,,: GR 53.Z813 OT ~;~[ ?,::"EATT';'~:: ?:. 8333 FV O '*~.~,~ GR, . 68.312.5 ~:~ RHOB ,2,2012 DRHO 7~.1500 DT ?FVD SFLU ,,~,,,~, :~,,~:,,~,~?~,~:...,58- .,063 ~ G :,,. ~'~ RHOB Z.1211 DRHO -999.2500 IL3 -99g. ZSO0 &R -231.5000 NRAT 2.3574 NC~L -999.1500 OTL 3.5742 FVU 8.8125 [L~ 77,1875 aR 0.0098 NR&T Z'6641 NC~L 113.0000 OTL 2.04~3 FV~ 5.0078 ILD 74.1875 GR -0.0015 NRAT 2o&855 NC~L 121.0000 DTL 1.6670 FVU 5.8789 [Lg 53,.,2813 gR 0.0127 NRAT 2.4121 NC~L 10~.5000 DTL 1.6943 FVJ 5.2539 7~.2500 GR -0.0005 NRAT 2.~629 NCNL 12~.7500 DTL 2.1758 FVU 9.6563 ~?~' ~, 9375 0.0928 NR~T 2.-1328' NC~L 0 0 0 0 0 -999.2500 8~,64.0000 0.9551 32752.0000 -999.2500 3.5215 9.~688 111.~375 3.7402 1757-0000 L1Z.?500 2.3464 5.5731 93.0625 ~.0078 1826o~000 122.~000 1.8268 7.3789 68.3125 3.8457 1805.000'0 105.0000 2.0609 5.3789 75.4375 3.3066 1738.0000 126.0000 2.2311 9.7188 51.7500 3.'7~61 1718o0000 PAGE I 08 0000000000000~ I 68 0000000000000~ L ~8 00000000000000 I 68 O0000000000OO0 I 68 OOO00000000000 I 68 0000000000000~ ILM -999.2500 CALI 11. Z500 RNRA /.0000 FCNL 32752.000'0 TPL 1~.~531 CAL! 1g. z500 ILM RNRA 3.96&8 FCNL 4~.3o0000 TPL 1~.22~0 CALl I2o4453 ILM 5.6055 CALl 12.~609 RNRA 4.1992 FCNL 434.75'00 TPL 15.1927 CALl 12-9609 ILM 7.3810 CALl 12o5703 RNRA 4.066~ FC~L 443.5000 IPL 1~.7161 CALl 12.5703 [LM 5. 5672 CALI 1Z.7188 RNRA 3.96,~8 FCNL TPL 1.5.2.057 CALl 11.7188 ILM 9.80½7 CALl 12.3750 RNRA ~.0508 FCNL ¢23.7500 LI'~ i"J 1111 i I e[:.] te: t:.t j ~! LV'P 010oHOZ VERZFZ~ATIDN LISTING PAGE' 5 48.93'75 DT EATT 252. 4583 FVO &R 52.7500 DE RHO '~ 2700.0000 &FLU -42.5625 Z. 232,.4 DRHO 4Z.2852 PEF 74.3750 DT 253.6667 FVO 80.1250 Z$O0.O000 &FLU '50.7500 aR 2.2344 DRHO 42.5293 PEF 59.5313 OT Z21,~ 3333 FVD 61.7.500 2500.0000 SFLU -¢7,,6250 OR 2.19~Z DRHO ' 4:8~$352~ PEF , GR 59.0625 DT "GW,~I?i~'~':'~EJtTT':~:: ' :: ~'.:' '~:~.:'::::3~ 3, 2'500 FY D- , GR 64.4375 '4'~:':';,r:::~,; "."?;~:~':',.' : ~: ' ': ;,,. ~F~'~:~' ; ', ' T~ ' ?(,;,;' ,~ 3~;,~;~?.¢E-~ · .. , .,. ~:~:.: r~,: .. ,.., :~,: ~ OE~T 2~00. 0000 SFLU RHOB Z. Z383 ORHO GR 60.0313 DT 135.0000 DTL 2.~668 FVU 9.0547 74.3750 GR 0.0352. NRAT 2.5391 NC~L 124.7500 OTL 2.7507 FVLI 8.55~7 IL3 5g.5313 ~R 0.10~0 NR~T 2.5098 NC ~28.~000 2'6934 T.O898 59.0625 GR 0.0327 ~6513 NCNL 1,881:5 FV~ 9.8~03 60-0313 GR 0.0483 NR~T 12605000 DTL 39158~ FYg 70.3750 [13 31.3750 GR 0.0103 NRAT 1'8447 NC~L 136.7500 DTL. 2'~ 9128 FV"~ ~e~ OEPT ,¢~ .2ZO0.OOO0 SFLU 10.Z344 R~'OB 2.1367 DRHG 0.0122 NR~T ~s~ ~" ' ~,,~!;~':~:~'~:q~:?'.~ ,~' ~',' : : ¢' ~, ' ~' : ~~ 6;6&:?:;:r'F'YD:'";~: ~ .... 2~:2201 ' F'V Y 69. SO00 134.Z500 TPL 3.3978 CAL[ ~.6953 ZLM 80.1250 CALI 3.6836 RNRA 1670.0000 FCNL 124.7500 TPL 2°9557 CALX 9.3828 61'7500 CAL! 3°6934 RNRA l&gSoOOOO FCNL 1Z8.SO00 TPL Z,66Z8 CAL! 7.~213 64.4315 CAL! ~.0234 RNRA 1665.0000 FCNL 134o0000 TPL 1'6325 CAL! 9.3984 ILM 67o06Z5 'C&L~ 3.9414 RNRA 1657°0000 FCNL 127.0000 TPL 3.2721 CALl 63.7813 ILM 30.1719 CALZ 3.~301 RNRA 1851.0000 FCNL 140.7500 TPL 3.3997 CAL! 20.7031 ILM 6g, 5'000 CAL! 6.1211 RNRA 15TO°OO00 FCNL 147.Z500 TPL 2.351& CAL! 35,,, 7813 CALI 16.Z161 12.3750 8.6047. 12.757'8 3.7598 444.0000 15.6958 12. 751r8 9.1656 1Z.5859 3.~684 4'I5. 0000 1~.0685 12o5859 7.6328 1Z.&4O& 4.1852 388,..,.~0 O0 1'7. $406 IZ,..64~06 9.2518 13 '2169 3.8398 431.5000- 16.5875 13, 2109 6T.$000 12.3'1'50 4.0000 k6ZoT500 12, 37 SO 10.12.50 1Z,.~,406 4,3672 359' 2500 14.d620 12.- 6,406 12'2813 ! LYP 010~HO~' VERIFICATZON LISTING PAGE $ ~ RHOB NP#Z GR E'I[TT --., GR 2.05~6 OReO 37.3125 DT 19B.9166 FVD 3~.7813 2000.0000 SFLU -4.7.2500 GR 2.0215 DRHO 4,0.9688 PEF I27.2083 FVD 4.5.4063 1900.0000 SFLU -2&,; 984,4 GR 2.0684 DRHG 56,,054? PEF 66.9375 DT 31.~0000 FVD 81.5625 1BO0.O000 SFLU 2.0254 DRHO ;:41~ 1680" '~ P E F 4.7.2813 DT 4.8.2187 ~ :2'~'~2187 O R -0.0088 NR~T Z.1816 NC~L 141.5000 DTL 1.6702 FV~ 25.1562 I. LD 41.6563 GR 0.0103 NR'~T 2.2617 NChlL 133.5000 OTL 3.2598 FV~I 8.2891 IL:~ 66.937S GR 0.0283 NR~T 3~0645 NC'iL 147.5000 DTL 2.2513 FV~ 31..'5250 ZLD 4,7"2813 GR -0.0151 NRa, T 2'~375 NCIIIL'= 134.5000 DTL. 46.5938 IL3 41. 0625 GR 0.0762 NRAT 2~ 32'03 NCIilL 152.2500 DTL 2. ~276 FV LI 39.3438 41.0000 -0.0088 NRAT ~,5430 NC~iL 142.0000 DTL 3,2'04.A ' :FV~ 3.$523 RNRA 1855.0000 FCNL 141°7500 TPL 2.1100 CAL! 29.5625 ILM 45o6063 CAL! 3.59~6 RNRA 1S03.0000 FCNL 132.7500 TPL 3.~193 C~L! 9.7969 XLH 81.5625 CALZ 4.½3?5 RNRA l&Ol~O00O FCNL 2.7233 CAL~ 33.6563 48.2187 CALX 3.9414 RNRA 1879o0000 FCNL [33.7500 TPL Z.9603 CaL! 40.1562'! CALl 3.6367 RNRA 177S°OOOO'~FCNL .151.5000 TPL 2o1617 CAL! 48.3125 tLM 48oa688 CAL! 3.a730 RNRA 1802.0000 FCNL 14.1o0000 TPL 3-1224. CAL~ 59.2813 59.8125 CALt 4°179'7 RNRA 1552' OO~ FCNL 177.75 TPL 3°3255 CAL! 3.9648 467.~500 12.2813 28.9531 12.2813 3.8868 4.12.5000 12.2813 9.2656 12.7578 4.~766 357o5000 16.4010 12.7578 3,~. 78~3 12.,3TS0 ,~. 1562 452.0000 15.2266 12,3750 53.5875 IZo3750 3.7207 13.7682 12.3750 12,.5703 3. 647'7 468. ZSO0 16.1094 12. 5703 4~.0313 15.6844 4.3164 366°2500 17.~740 15o~844 B,,,,-.r~J ;1 il I Iii ~I~li[~ [:-I ,m I'L'YP O~O,It~Z'-VER%FICATIDN LISTING '~ DEPT SP~ 1~00.0000 SFLU -29.9062 GR L.91~9 DRH~ 52.8809 PEF 40.1562 CT 399.7500 FVD 41.6250 1300.0000 SFLU -19o8906 GR 1. 9453 ORHG 60.9863 PEF 29.7813 OT 202.7500 FVD 31.9531 1200.0000 SFLU -35.8125 aR 1.6152 DRHO &6'6016 PEF 49.1875 DT ZSx~?gIT FVD 55.0938 ?. ~ ?' -~ , ~.:. ~,~i DEPT 1100.0000 SFLU RHOB . 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ILM CALl RNRA FCNL TPL CALI ILM CALl RNRA FCNL TPL 'CALZ CALZ RNRA FC~L TPL CALI ZLM ALZ FCNL PAG, E 30.5313 13.3281 3.9570 380. 5000, 15.8177 13.3261 27.0000 13. ~,219 331.5'000 Z0.5729 13o~219 5'9.9687 3.5352 ,i~ ~iF 6 ,~,r 00 O~ 0 20.$016 1~.0391 66.5625 ~6.03t3 2~2.8750 20.9062 16.0313 36.~688 14.1875 ½.2656 336.7500 19.69~8 14.1875 25./~06 14.5156 4.$016 39'5.0000 14.5156 0.9697 15-5156 5,..766 202'6250 ~1 LVP 010.HOZ VERIFICATION LISTING PA~E 9 GR £i. 7656 OT fATT ZB9.7500 FVD GR 15.2959 OEPT 97.0000 SFLU SP 5?°2500 ~R NPH~ -~99.2500 PEF ~TT -999.~500 FVD GR -~99.2500 57.~750 ~TL 3. ]'259 Z.OO20 21.2656 -~999.2500 NRAT -999.2500 NCNL 57.5000 DT~ · e,FILE TRAILER *~ FILE NAME :2DIT .001 SERVICE NAME : VERSIO~ # : DATE : MAXIMUM LE~G'TH : 102~ FILE TYPE : NEXT FILE ~AME : EOF ~**~*~*~** · $ FILE ME~DER FILE NAME :EDIT SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : FILE TYPE PREVIOUS FILE : .001 102~ ** INFDRMATION REC2ROS ~ ~)l MNEM C O"~ITENT S C~ : ARCO ALASKJt .[NC ~'i~'~ "#'N :~:?::': :'i','~ :?3 $" 14 FN [~ WEST SAK FORMATION ~ TOMN: 12M ,' COdN: ~.SLOPE CTRY: USA MNE~ CO~TENTS 5B.1250 4.0534 2000.0000 -999.2500 -999.2500 -999.2500 57.Z500 -999.2500 TPL CALl ILM CALl RNRA FCNL TPL CALl 22.9531 15.5156 -999.2500 -99g.2500 -999.Z500 ' -ggg. ZSO0 -ggg. ZSO0 UNIT TYPE CATE SIZE CODE 000 000 015 065 000 000 005 065 000 000 018 065 000 000 002 065 000 000 003 065 000 000 OO2 065 000 000 007 0~5 000 000 086 065' 000 000 003 CATE SIZE CODE TYPE ~JN I T 000 000 00'1 0.65: I LVP. 010;HO~'::~'VERIFICATION LISTING $ -~.-~ O, COMMIENT S : SCHLUMBERGER · : ALASKA ~IVISION CgMPUTING CENTER Pa~E 10 ~CO#P&NY = ARCO .a. LASKA INC WELL = 35-1/, ":"~"~'~ELD ~ WEST- SAK FORMATION COUNTY = N.SLOPE SECT[ON = 16 TOIdNSHZP "" 1ZN RANGE = 9 E TAPE DENSITY = 800 BP,T. ,JOB ~ 70195 BASE LOG: OIL ~ RUN # L DATE LOG~E~ 13 MAR 85 BOTTOM L:}G ,INTERVAL -- ,~280 FT = 109 FT ,~ C;ASZ~G.L:]GGER = 16,,000 IN. @ tO9 FT. ~1 LVP 010.,HOZ 'VERIFICAT.[ON LISTTNG Ti'PE tHOLE FLUIO DENSITY VXSCOS*rTY PH FLU*r I) LOSS RPI ~ ,qEAS. TEMP. IPlF':*~ NEAS, TEHP. RMC a HEAS. TE~4Po = GELEX = 9,,,,_-10 = 47.00 = = 16.,Z0 = 5.640 -:~ 66 F = ~,.700 a 66 F = 2.3~0 @ 66 F = 01000 @ 0 F '~:::"::~1'i4X$ FI~LE CONTAINS HIGH RESOLUTION EPT DATA ONLY'¢i,,,Z" SAMPLE RATE)· T NALSTEAD ENTRY 8LOGICS TYPE 8 0 SIZE REPR CODE ENTRY 65 0 '66 1 ¢ 73 12 · 65 .lIN I 6~ 1 1 66 0 d~,.,~:i ~EN~SERVI~E SERVICE UNIT AP! API AP1 ~Pl FILE SIZE SPL REPR ~'~!/?~'~:J~:~i?:':!:,.'~:~r.*rD-":::'/:~:" ORDER # LOG TYPE CLASS ROD NO. CODE DEPT ': :~4~Y" ?~' N ' :': :~*::':~' ~;: ' ~, EATT SAM FT O0 000 O0 0 0 NS/N O0 1,t2 01 38/M O0 130 01 0 0 V O0 'O00 v OO 000 O0 0 0 INi :': OO: 280 01 0 0 ~API O0 310 01 0 0 PAgE I1 PROCESS (OCTAL) ~8 00000000000000 8000000000O'O00, I 68 00000000000003 I 68 00000000000000 1 68 0000000000000~ I 68 0000000000'000~ I 68 0000000000000~ ~'~! LVP 01~,HOZ VERIFZCATION LISTZNG $ ~.q OEPT 3Z97.7998 TPL FVtJ :~ 3. 3477 CALI DEPT:/ 3 ZOO. Z998 TP L .-,*,,FVU ;P. 4554 CALI DEPT 3100.29'58 TPL !' FVEI' 1. 5013 CALI I~T '~' 3900. 2998 TPL FVU 2.1966 CALI OEPT 2300.2998 TPL 'J ~:' F¥'U 1.9167 CAL! ) '~"' DElfT 2600.2998 TPL :,~,, FVU 2.7939 CALl ., OEPT 2700.2998 TPL .~ ..... · :~':::~T'~:' ' ~' 2$6~'5000 TPL FVU Z. 9219 CALI ~ FILE NAME :EDIT .001 ~ VERS ZOM ~ : NAXZNUN LEMGTH : lOZ~ 13.3359 EATT 12.2500 GR 14.2891 EATT 12.3750 GR 1~.9818 ~ATT 12o9844 &R' 14.8333 EATT ZZ. 6563 GR 15.1641 EAI'T 12.7578 ~R 1'4' 859~ EA'TT - 1Z.3750 F_,R 15.6698 ~ATT 12o8750' GR 15 ~,167" E A T T 13.0938 ~R EOF 288.0000 97.31Z5 290.4166 LIZ.IZSO 373.1666 85.5000 337.2500 6~.Z500 310.Z500 78.7500 263.1666 51.1562 252.7oa3 76. Z875 Z66'7500 76,9375 FVD FVD FVD FVD FV'D FVD FVO PAgE 3.189'5 2.6866 1.5768 1.6396 2.0833 2.2832 2o~'970 ,·. m.-'i"~ 11 pi,i] ~z;~l_*. L:~ J ' COMMENTS : ~ .... SC HLIJ t~lP., E RS.E R .... ~ L:IS T~PE VE~I,F:ICATIO ~ LISTING :~: 'TAPE HEADER ;ER¥ICE NAME :EDIT ~ATE :55/05/30 'APE NAME :0229 ;ONT ~NL~ATi2N ~ ~R.EVIO~S T~P:E : ~OMM~NTS : FILE HE~DER *~ :ILE N~ME :EDIT ;E~VICE NAME : ~ER.S ION ~ : JA'TE : :ICE TYPE : 'R2VIO~S FILE :~- INFORMATION .001 : 102~+ : REC 3RDS ~ ~NEM C. gNT~NTS : AR : :N : KU ~ANG: gE FOWN: ~ECT: 16 :DUN: N. ~TAT: ~T2Y: ALASKA iNC PARUK SLOPE SKA qNEM Cg~TENTS >RES: E ~.v, COMMENTS JNiT iNIT TYPE 0 g 0 OOO ODO 000 000 0~0 OgO OgO TYPE 000 000 000 000 000 000 000 000 000 000 SiZE 0t5 005 0 ~ ? 002 003 O02 007 006 003 SI?E: 001 0:55 O65 ~.m~ VP 0!O.HO'z VE~.IFi~A'TIDN LISTING - ALASKA DIVISION COMPUTING C~NTE~ COMPANY CgUNTY ST~T~ SECT'IDN TOWNSHIP ~ANG~ = ARCO &LASKA INC : 35-1A : K UPARUK : N. SLO'DE = ALASK = 16 : = gE JO5 ~ 70Z29 ~ASE LOG: OIL , RUN .i~ ~2 DATE LOGGED 20 MAR 85 ~OTTGM LOG INTERVAL TOiP LOG IN'TE~VAL CASING-L DGGE~ ~IT SiT~. TYPE HOLE FLUID DENSITY VISCOSITY = 6770 FTo = 3311 FT. = 9.52 5 tN. = 3.5.00 IN. = G6LEX = 10.10 = 3 t'.00 ~ 3~%1~ FT. VP OiO.HOZ VERIFICATION LISTING ?~E 3 FLUIO LOSS = '6.00 RM ~- ME~S. TEMP. = 4.510 RMF ~ ME.A$. 'TEMP. = 4.ZO.O RMC ~ ME~S. TEMP. : 2.700 RM ~ ~HT = Z.255 LOP: T 9ALSTEAD *~*~-' NDT.~ ~**-~ NOTE ~*'~.~ N~T~ ~~ NOTE ~~ NDT~ ~~ NCNL~FCNL~ND ~N~A ARE ONLY VALID UNTIL TH~ DEPTH ~F 6iti. O TH,~S i5 DU~ TO .~ ~NCO~R~CTA~ ERROR ~ FIELD ENGINEER TH. DATA F~RMAT REC:2RO NTRY 5L!2C (S TYPE SIZE REPR C'2DE ENTRY 2 I 6~, ~, 1 65 1 8 4 7~ 60 0 I 65 0 ,ATUM SPEC[F!CATXON i~LOC~S IN~ $~R¥ICE S~R¥i~E ~NiT APl -~Pi ADZ ~P.I FIL~ SiZE SPL RE.PR IO ORDER ~ LOG TYP~ CLASS MO~ NO. 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