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185-261
Originated: Delivered to:9-Dec-24 Alaska Oil & Gas Conservation Commiss 09Dec24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1R-03A 50-029-21406-01-00 200-021 Kuparuk River WL IPROF FINAL FIELD 8-Nov-24 3S-718 50-103-20884-00-00 224-034 Kuparuk River WL TTiX PPROF FINAL FIELD 20-Nov-24 2B-11 50-029-21089-00-00 184-035 Kuparuk River WL IPROF FINAL FIELD 22-Nov-24 3S-617 50-103-20864-00-00 223-085 Kuparuk River WL IPROF FINAL FIELD 30-Nov-24 3M-22 50-029-21740-00-00 187-067 Kuparuk River WL LDL FINAL FIELD 2-Dec-24 1J-156 50-029-23311-00-00 206-067 Kuparuk River WL IPROF FINAL FIELD 2-Dec-24 2H-11 50-103-20052-00-00 185-261 Kuparuk River WL IPROF FINAL FIELD 4-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39843 T39844 T39845 T39846 T39847 T39848 T398492H-11 50-103-20052-00-00 185-261 Kuparuk River WL IPROF FINAL FIELD 4-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.10 08:20:31 -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 Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6765'feet None feet true vertical 6344'feet 6613'feet Effective Depth measured 6512'feet 6247', 6433'feet true vertical 6132'feet 5907', 6066'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" J-55 6450' MD 6080' TVD Packers and SSSV (type, measured and true vertical depth) 6247' MD 6433' MD N/A 5907' TVD 6066' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-334 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 107 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Brown HB Retrvbl Packer Packer: Brown 1-B Packer SSSV: Baker FVL Sfty Vlv Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-6718Well Interventions Engineer 6400-6409', 6466-6486', 6513-6539' 6038-6045', 6093-6110', 6133-6152' 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) 137 Gas-Mcf MD 1145 Size 112' 752 126137 72 210400 193 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-261 50-103-20052-00-00 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: ADL0025587 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2H-11 Plugs Junk measured Length Production Liner 6714' Casing 6328'6746' 2707' 112'Conductor Surface Intermediate 16" 9-5/8" 76' 2743' 2742' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:05 pm, Oct 12, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.10.12 09:09:22-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 5/10/2023 ACQUIRE DATA (AC EVAL) BLEED IA & OA AS LOW AS POSSIBLE (COMPLETE) 5/17/2023 ACQUIRE DATA DRFT TBG W/ 1.9" CENT, 1.75" SAMPLE BAILER TAG BTM @ 6512' RKB. MEASURED SBHP @ 6500' RKB (3381 psi)JOB COMPLETE. 7/27/2023 ACQUIRE DATA LOG PRE-BISN TREATMENT CEMENT BOND LOG TO EVALUATE THE BASELINE IA CONDITIONS. DISCOVERED TBG FULL OF GAS WHILE RIH. CALL FOR LRS TO LOAD TUBING W/ DIESEL. MAIN PASS LOGGED FROM 6320' TO 200' AT 30 FPM. LRS PUMPED AT MIN RATE DURING LOGGING OPERATIONS TO KEEP HOLE FULL. NO OBSTRUCTIONS DISCOVERED IN IA. JOB COMPLETE. 8/18/2023 ACQUIRE DATA SET SS CATCHER @ 6253' RKB, PULLED DV & SET 1/4" OV @ 6191' RKB, PULLED GLVs & SET DVs @ 5563' & 4874' RKB. IN PROGRESS. 8/19/2023 ACQUIRE DATA PULLED GLVs & REPLACED W/ DVs @ 2244' RKB & 3786' RKB, PULLED EMPTY SS CATCHER @ 6253' RKB. READY FOR BISN 8/20/2023 REPAIR WELL BULLHEAD 200 BBLS DIESEL DOWN IA FOR BISN PREP JOB COMPLETE 8/21/2023 REPAIR WELL PUMP DOWN IA WITH DIESEL FOR BISN JOB. PUMPED 8 BATCHES OF BEADS DOWN IA AT .35 BPM AND 1400 PSI. PUMPED 4.5 BBLS TOTAL TOTAL BEADS PUMPED 265 LB BASE SHOT, 551 LB SEAL SHOT 8/22/2023 ACQUIRE DATA LOG POST-BISN TREATMENT CEMENT BOND LOG TO EVALUATE THE BEAD SETTLING DEPTH IN IA. MAIN PASS LOGGED FROM 6350' TO 200' AT 30 FPM. PRE AND POST GR OVERLAY SHOWS NOTIBLE GR SHIFT OVER 6223'-6233', JOB COMPLETE. 8/26/2023 ACQUIRE DATA PUMPED 70 BBLS SW DWN TBG, FOLLOWED BY 20 BBLS DSL FOR FREEZE PROTECT 8/27/2023 ACQUIRE DATA RIH W/ 2-1/8" BISN (PRT) HEATER TOOL FOR PACKER REPAIR/BEAD MELT. SIT DOWN AT 5000', ABLE TO WORK TOOLS DEEPER TO 5600' (JUST PAST GLM #4) AND UNABLE TO GET ANY DEEPER. ATTEMPT RIH AT VARIOUS SPEEDS WITH NO SUCCESS. DECISION MADE TO POOH BEFORE TIMED HEATER INITIATES. JOB COMPLETE, READY FOR SL TO CLEAN UP TUBING 8/28/2023 ACQUIRE DATA B&F TUBING TO 6400' RKB, PUMPED DISPLACEMENT OF 36 BBLS DSL , UNABLE TO DRIFT BELOW 5100' RKB W/ 2.25'' X 20' DRIFT, CLEAN DRIFT W/ 2.125'' X 20' SLICKLINE TOOL STRING DRIFT, 900 LB WEIGHT SWINGS BETWEEN 4200'-6300' RKB WHILE POOH...COMPLETE 8/29/2023 ACQUIRE DATA LOAD/DISPLACE TBG WITH 70 BBLS SW & 15 BBLS DSL FOR UPCOMING ELINE BISN JOB JOB COMPLETE READY FOR ELINE 8/30/2023 ACQUIRE DATA RIH W/ BiSN HEATERS, SET DOWN AT 5100'. HAD TO GET PUMPED DOWN AT 1 BPM TO 6300' (5 BBL TOTAL). PLACE UPPER HEATER AT 6223' AND FIRE, WAIT 25 MIN AND PLACE LOWER HEATER AT 6223' AND WAIT FOR TIMER. AFTER 30 MINS. POOH. TOOLS STARTING MOVING 2300 OVER NORMAL TENSION (PUMPED ADDITIONAL 8 BBL DIESEL POST PRT FIRING). AT SURFACE CONFIRM LOWER HEATER DID NOT FIRE. CONFER W/ TOWN, DECISION MADE TO PERFORM CMIT-IA TO TEST BiSN PLUG. JOB IS READY FOR SL. 9/1/2023 REPAIR WELL PULL OV FROM STATION 6 @ 6191' RKB. REPLACE W/ 1.5" DMY VALVE. PERFORM PASSING MIT-IA TO 2500 PSI JOB COMPLETE 9/8/2023 REPAIR WELL SET 2.3" AVA CATCHER IN D-NIPPLE @ 6443' RKB. PULLED DMY VALVE FROM STA # 4 @ 5562'RKB. SWAB LEAKING, UNABLE TO GET OFF WELL, VALVE CREW SERVICES SWAB, UNABLE TO GET SWAB TO HOLD, DECISION WAS MADE BY CWG TO RDMO UNTIL SWAB IS REPLACED. IN PROGRESS 9/12/2023 REPAIR WELL SET OV IN STA # 4 @ 5562' RKB, PULLED DV & SET GLV IN STA # 3 @ 4874' RKB, PULLED DV IN STA #2 @ 3786' RKB. IN PROGRESS 2H-11 BiSN Repair Summary of Operations 9/13/2023 REPAIR WELL SET GLV IN STA #2 @ 3786' RKB, PULLED DV & REPLACED W/ GLV IN STA #1 @ 2244' RKB, PULLED EMPTY AVA CATCHER FROM D-NIPPLE @ 6443' RKB, PERFORMED A DDT ON IA (FAILED), SET COLLAR STOP HOLEFINDER (M.E. @ 6223' RKB) PERFORMED A PASSING MITT TO 1750 PSI. JOB COMPLETE. 9/17/2023 ACQUIRE DATA (AC EVAL) TIFL (PASS) 9/23/2023 ACQUIRE DATA (WC) MIT-OA (PASSED TO 1800 PSI) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,512.0 2H-11 5/17/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added BiSN "packer" with top at 6222' RKB 2H-11 9/26/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: *** TUBING SET DEPTH/COMPONENT DEPTHS ARE WLM *** 7/12/2012 osborl NOTE: WAIVERED WELL: IA x OA COMMUNICATION 5/11/2003 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 36.0 112.0 112.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.5 2,742.6 2,742.5 36.00 J-55 BTC PRODUCTION 7 6.28 31.7 6,746.2 6,328.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.5 Set Depth 6,449.7 Set Depth 6,079.7 String Max No 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.5 31.5 0.09 HANGER 6.000 FMC GEN III TUBING HANGER 2.875 1,775.5 1,775.4 0.43 SAFETY VLV 4.760 BAKER FVL SAFETY VALVE BAKER FVL 2.313 2,243.7 2,243.7 0.38 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 3,786.4 3,785.6 8.33 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 4,873.8 4,771.5 34.77 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,562.8 5,334.7 36.03 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 5,876.7 5,589.8 33.19 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,191.0 5,859.3 30.50 GAS LIFT 5.500 MMH FMHO MMH FMHO 2.347 6,234.9 5,897.0 30.90 PBR 3.500 BROWN PBR BROWN 2.500 6,247.0 5,907.4 31.03 PACKER 6.151 HB RETRIEVABLE PACKER BROWN HB 3.000 6,284.6 5,939.6 31.44 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,351.2 5,996.2 31.84 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,387.8 6,027.3 32.01 BLAST RING 3.500 CARBIDE BLAST RING (1) 2.441 6,421.0 6,055.4 32.20 GAS LIFT 4.750 CAMCO KBMG CAMCO KBMG 2.347 6,431.6 6,064.4 32.26 LOCATOR 3.500 BROWN LOCATOR SUB w/ 5' SEALS BROWN 2.440 6,433.1 6,065.7 32.27 PACKER 5.660 BROWN 1-B PACKER BROWN 1-B 3.250 6,443.3 6,074.3 32.33 NIPPLE 3.668 CAMCO D NIPPLE CAMCO D 2.250 6,448.8 6,079.0 32.36 SOS 3.750 BROWN SHEAR OUT SUB, ELMD w/ PPROF 1/4/2007 6445' BROWN 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,222.0 5,886.0 30.77 OTHER BiSN BEADS MELTED FROM 6222' TO APPROX 6232' RKB (ANNULUS OF 7" X 2-7/8") 8/30/2023 4.000 6,247.0 5,907.4 31.03 LEAK - TUBING Brown HB Packer potential TxIA, Tx Form, IAxForm leaks 10/20/2020 0.000 6,421.0 6,055.5 32.20 LEAK - TUBING Identified significant C sand leak in/near CSM @ 6421. 2/3/2012 6,613.0 6,217.0 33.15 FISH Wobble Ring LOST 6/17/1998 6/17/1998 1.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,243.7 2,243.7 0.38 1 GAS LIFT GLV BK 1 1,273.0 9/13/2023 0.156 3,786.4 3,785.6 8.33 2 GAS LIFT GLV BK 1 1,272.0 9/13/2023 0.156 4,873.8 4,771.5 34.77 3 GAS LIFT GLV BK 1 1,303.0 9/12/2023 0.188 5,562.8 5,334.7 36.03 4 GAS LIFT OV BK 1 9/12/2023 0.188 5,876.7 5,589.8 33.19 5 GAS LIFT DMY BK 1 7/25/1992 0.000 6,191.0 5,859.3 30.50 6 GAS LIFT DMY RK 1 1/2 0.0 9/1/2023 0.000 6,284.6 5,939.6 31.44 7 PROD HFCV BEK 1 0.0 8/12/2014 0.000 6,351.2 5,996.2 31.84 8 PROD HFCV NO Latch 1 0.0 2/23/2012 8/11/1 4 0.000 6,421.0 6,055.4 32.20 9 PROD HFCV BEK 1 0.0 8/10/2014 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,400.0 6,409.0 6,037.7 6,045.3 C-4, UNIT B, 2H- 11 12/14/1985 12.0 IPERF 5" HyperJet II; 120° Phasing 6,466.0 6,486.0 6,093.5 6,110.3 A-4, 2H-11 3/18/1986 4.0 APERF 2 1/8" Tornado Link; 0° Phasing 6,513.0 6,536.0 6,133.1 6,152.4 A-3, 2H-11 12/14/1985 4.0 IPERF 4" HyperJet II; 90° Phasing 2H-11, 10/10/2023 1:10:29 PM Vertical schematic (actual) PRODUCTION; 31.7-6,746.2 FISH; 6,613.0 IPERF; 6,513.0-6,536.0 APERF; 6,466.0-6,486.0 PACKER; 6,433.1 GAS LIFT; 6,421.0 LEAK - TUBING; 6,421.0 IPERF; 6,400.0-6,409.0 GAS LIFT; 6,351.2 GAS LIFT; 6,284.6 PACKER; 6,247.0 LEAK - TUBING; 6,247.0 OTHER; 6,222.0 GAS LIFT; 6,191.0 GAS LIFT; 5,876.7 GAS LIFT; 5,562.8 GAS LIFT; 4,873.8 GAS LIFT; 3,786.4 SURFACE; 35.5-2,742.6 GAS LIFT; 2,243.7 SAFETY VLV; 1,775.5 CONDUCTOR; 36.0-112.0 KUP PROD KB-Grd (ft) 39.51 RR Date 11/17/198 5 Other Elev 2H-11 ... TD Act Btm (ftKB) 6,765.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005200 Wellbore Status PROD Max Angle & MD Incl (°) 36.12 MD (ftKB) 5,600.00 WELLNAME WELLBORE2H-11 Annotation Last WO: End DateH2S (ppm) 80 Date 12/15/2019 Comment SSSV: TRDP 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 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 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 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: BiSN Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6765'6613' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Interventions Engineer Tubing Grade: Tubing MD (ft): 6247' MD and 5907' TVD 6433' MD and 6066' TVD 1775' MD and 1775' TVD Perforation Depth TVD (ft): Tubing Size: J-55 6450' 7/6/2023 Packer: Brown HB Rtvbl Packer Packer: Brown 1-B Packer SSSV: Baker FVL Safety Valve STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025587 185-261 P.O. Box 100360, Anchorage, AK 99510 50-103-20052-00 ConocoPhillips Alaska, Inc. KRU 2H-11 Kuparuk River Oil PoolKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6344' 6512' 6132' None MD 112' 2742' 112' 2743' 6328'6746' 16" 9-5/8" 76' 2707' Perforation Depth MD (ft): 6400-6409', 6466-6486', 6513-6539' 6714' 6038-6045', 6093-6110', 6133-6152'2-7/8" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:42 am, Jun 09, 2023 323-334 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C= US Reason: I am the author of this document Location: Date: 2023.06.09 08:11:15-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor X DSR-6/12/23VTL 6/27/2023 10-404 MDG 6/12/2023JLC 6/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.27 14:21:39 -05'00'06/27/23 RBDMS JSB 062823 Well: 2H-11 Date: 6/8/23 Proposed Start Date: 7/6/23 Written By: Katherine O’Connor Well History & Objective 2H-11 is a gas lifted producer with a two packer leaks at 6248’ and 6251’ RKB. Setting a patch to repair these leaks was not successful. A BISN plug will be set in the IA to repair the packer and return this well to production. This well is waivered for IAxOA communication. Procedure: Eline 1. Run baseline CBL survey 2. Pump bismuth beads down the IA (aim is to get 5’ worth of beads above uppermost leak) 3. Run CBL to survey bead settling depth 4. Pump down IA if needed to push beads to depth 5. Run heater to melt beads into solid patch 6. Run CBL to survey BISN bismuth packer top (expected about 6243’ RKB) Slickline 7. Set tubing plug and perform MIT-T and CMIT-TxIA to confirm well integrity barriers 8. If passing pressure tests, RDMO and hand well over to operations to bring online Expected top ~6243’ RKB Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2E-10 50-029-21246-00 907100157 Kuparuk River Packer Setting Record Field- Final 19-Apr-21 0 1 2 2H-11 50-029-20052-00 n/a Kuparuk River Packer Setting Record Field- Final 18-May-21 0 1 3 2M-07 50-103-20178-00 907126248 Kuparuk River Plug Setting Record Field- Final 30-Apr-21 0 1 4 3K-03 50-029-21602-00 907097693 Kuparuk River Leak Detect Log Field- Final 16-Apr-21 0 1 5 3K-03 50-029-21602-00 907132626 Kuparuk River Packer Setting Record Field- Final 5-May-21 0 1 6 3K-30 50-029-22777-00 907098723 Kuparuk River Multi Finger Caliper Field & Processed 16-Apr-21 0 1 7 3K-30 50-029-22777-00 907098126 Kuparuk River Packer Setting Record Field- Final 6-May-21 0 1 8 3Q-06 50-029-21674-00 907089173 Kuparuk River Multi Finger Caliper Field & Processed 13-Apr-21 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 06/01/2021 PTD: 1852610 E-Set: 35188 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2H-11 50-029-20052-00 906834022 Kuparuk River Leak Detect Log with ACX Processed 2-Dec-20 0 1 2 2H-11 50-029-20052-00 906834022 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-20 0 1 3 2N-333 50-103-20525-00 906859420 Tarn Participating Area Plug Setting Record Field- Final 11-Dec-20 0 1 4 2N-333 50-103-20525-00 906869831 Tarn Participating Area Leak Detect Log Field- Final 17-Dec-20 0 1 5 2W-13 50-029-21252-00 906808475 Kuparuk River Leak Detect Log Field- Final 13-Nov-20 0 1 6 2W-13 50-029-21252-00 906808475 Kuparuk River Packer Setting Record Field- Final 14-Nov-20 0 1 7 2W-13 50-029-21252-00 906813971 Kuparuk River Multi Finger Caliper Field & Processed 11-Nov-20 0 1 8 2Z-08 50-029-20924-00 906803595 Kuparuk River Plug Setting Record Field- Final 8-Nov-20 0 1 9 3H-01 50-103-20084-00 906826894 Kuparuk River String Shot Record Field- Final 19-Nov-20 0 1 10 3H-26 50-103-20208-00 906832308 Kuparuk River Leak Detect Log Field- Final 24-Nov-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 01/08/2021 01/11/2021 Abby Bell PTD: 1852610 E-Set: 34548 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2H-11 50-029-20052-00 906834022 Kuparuk River Leak Detect Log with ACX Processed 2-Dec-20 0 1 2 2H-11 50-029-20052-00 906834022 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-20 0 1 3 2N-333 50-103-20525-00 906859420 Tarn Participating Area Plug Setting Record Field- Final 11-Dec-20 0 1 4 2N-333 50-103-20525-00 906869831 Tarn Participating Area Leak Detect Log Field- Final 17-Dec-20 0 1 5 2W-13 50-029-21252-00 906808475 Kuparuk River Leak Detect Log Field- Final 13-Nov-20 0 1 6 2W-13 50-029-21252-00 906808475 Kuparuk River Packer Setting Record Field- Final 14-Nov-20 0 1 7 2W-13 50-029-21252-00 906813971 Kuparuk River Multi Finger Caliper Field & Processed 11-Nov-20 0 1 8 2Z-08 50-029-20924-00 906803595 Kuparuk River Plug Setting Record Field- Final 8-Nov-20 0 1 9 3H-01 50-103-20084-00 906826894 Kuparuk River String Shot Record Field- Final 19-Nov-20 0 1 10 3H-26 50-103-20208-00 906832308 Kuparuk River Leak Detect Log Field- Final 24-Nov-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 01/08/2021 01/11/2021 Abby Bell PTD: 1852610 E-Set: 34547 Originated:Delivered to:15-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 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1 2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1 3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1 4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1 5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1 6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1 7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1 8 2N-315 50-103-20270-00 906731635 Tarn Participating Area Leak Detect Log with TMD3D Field & Processed 28-Sep-20 0 1 9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1 10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-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 12/16/2020 12/16/2020 Abby Bell PTD: 1852610 E-Set: 34413 • 110 2E WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 4, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 swim frt RE: Production Profile: 2H-11 Run Date: 3/28/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2H-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 =20052-00 3� Production Profile Log 1 Color Log 50-929=20052-00 kOS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: f0/!2 Signed: / ~~ ;! i % ~' _. __. ., (~, NO.4775 ,r~ , ~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 „ ATTN: Beth , ~ ~~~~ ~U~ ~ ~ ~~uU Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE j 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE (TCj ~ 06/26/08 1 1 1 G-05 12080389 LDL fp 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE -r _ t / 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ ~ ~- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY G 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY cf- 5 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE V r' ( /(~j 07/05/08 1 1 2H-05 12080396 SBHP SURVEY =` --- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY b~ 06/30/08 1 1 2H-1 f 12080394 SBHP SURVEY "- - ( 06/30/08 1 1 1 D-07 12080398 SBHP SURVEY -, j 07/02/08 1 1 2N-341 12061720 SBHP SURVEY p 06/30/08 1 1 3C-15 11982441 USIT - / (~ 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE $ - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE ~ p -(~ 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,~ 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • 4 1 ~ ~~ =,~ ~~ . ConocoPhillips ~ ~ { Alaska ;E ' ~ !: P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 MAY 0 Z~o~ ~ " ~ ~ t Anchorage, AK 99501 S~~N 2 ~ C~ ~J 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. These voids. were filled•with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped Apri13 2008 and the corrosion inhibitor/sealant was pumped on April 20th and 30~' of 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ a Perry Kle ConocoPhillips Well Integrity Projects Supervisor ~~L-~ ConocoPhillips Alaska-Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 5/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-01 -184-115 25' S" 3.25 23" 4/3/2008 1.7 .4/20/2008 26-02 184-122 30' S" 0.5 20" 4/3/2008 4.3 4/20!2008 2B-03A .203-009 4' 0.5 33" 4/3!2008 10.2. 4/20/2008 2B-04 184-120 30' 4 28:' 4/3/2008 6.4 4/20/2008 26-06 184-022 26' 5 19" 4/3/2008 8.5 4/20/2008 26-09 184-027 74' , 10.5 32" 4/3/2008 11.1 4/20/2008 2B-10 184-029- 74' - 10.5 33" 4/3/2008 17 4/20/2008 2B-11 184-035 50' 7.5 29" 4/3/2008 6 4/20/2008 26-12 184-038 6' 1 29" 4/3/2008 6 4/20!2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2 4/30/2008 2H-03 184-070 SF n/a SF n/a 4 4/30/2008 2H-04 184-055 SF n!a SF n/a 2 4/30/2008 2H-OS 185-171 2' 6" n/a 2' 6" n/a 25 4/30/2008 2H-10 185-260 SF n/a SF n/a 2 4/30/2008 2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a ~ 2.5 4/30/2008 2H-13 184-096 2" n/a 2" n/a 2 4/30!2008 2H-14 184-095 SF n!a SF n/a 2 4/30/2008 Sehtullbel'gel' ~ Jþ.~ 3 í) 'l.1}t!I 01/24/07 NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~I/\~\ "I. 9 ZOO7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk {~~-d(ç( Well Date CD BL Color Job# Log Description 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y-22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ) ~~~~'~ :'1 ~~~~~~~ AI~ASKA. OIL AND GAS CONSERVATION COltDlISSION FRANK H. MURKOWSKI, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 26,2004 \ Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 10, 2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, .'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 100/0 failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, cf~3~~c; James B. Regg -ll Petroleum Inspection Supervisor Attachment SCANNED J AN 1 1 2,GO~ì ') ') Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P :: f:~,~~S\~;',: :~~$;T1: t~itl!<~l~~tl~Jtttq1~ 1Wl!JIIl!IŸR' Test Test Test Date Tested and or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, Sf WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG '~'æèllrl)'litðj ..¡,. ,;':~" .:>... ...;-:t~ '$ ':... -~, ; ,,~:~,,; .:'~ :~,' ;~} '. . Well Permit Separ Number Number PSI 2H-Ol 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H~09 1852590 96 2H-10 1852600 96 2H-l1 1852610' 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-15 1840860 2H-16 1840870 2H-17 2000190 Set LIP PSI Trip 96 Wells: 9 Components: 18 F ai/ures: 2 Fai/ure Rate: 11.11010 90 Day Remarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls MEMORANDUM State of Alaska Alaska. Oil and. Gas ConserVation CommisSion TO' Julie Huesser, ~ DATE: Commissioner THRU: Tom Maunder, P. I. Supervisor December 2, 2000 FROM' Chuck Scheve; SUBJECT: Safety.Valve Tests Petroleum Inspector · Kuparuk River Unit 2H Pad Saturday, December 2,-2000: I traveled to the KuparUk River Field and witnessed. the semi annual safety valve system testing' on 12H Pad. . As the attached AOGCC Safety Valve System Test Report indicates I witnesSed the testing of 9 wells and 18 components with four failures obServed. The Iow pressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required set point and the surface safety valve on well 2H-12 failed to pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valVe will be repaired and retested by the operator. The 22.2% failure rate.will require a retest of this Pads safety valve SYStem in 90 days rather than the normal~,~day cycle. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with · Summary: I witnessed the semi annual SVS testing at 2H Pad in the Kuparuk River Field. .. KRU 2H Pad, 9 wells, 18 components, 4 failures 22% failure'rate . Attachment: SVS KRU 2H Pad 12-2-00 cS .- .- X Unclassified ~ Confidential (Unclassified if doc. RemOved) SVS KRU 2H Pad 12-2-00 CS.doc Alas~"~Oil and Gas Conservation COmmiSsion Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 12/2/00 Operator Rep: Emie Bamdt Field/Unit/Pad: Kuparuk / KRU / 2H Pad . AOGCC Rep: Chuck Scheve .~ Separator psi: LPS 96 HPS Well Permit SepaL Set L/P Test Test Test Date: Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed CAS or CYCLE 2H-01 1840770 2H-02 1840730 . · 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 70 20 3 P 12/2/00 OIL 2H-06 1851690 961 70 10 3 P 12/2/00 'OIL 2H-07 1851700 961 70 60 P P OIL 2H-08 1851710 96 '70 60 P P OIL 2H-09 1852590 96 70 50 P P ' OiLi 2H-10 1852600 96 70 50 P P . OIL 2H-11 1852610 96 70 50 P P OIL 2H-12 1852620! 96~ 70 10 3 4 remarks 2H-13 1840960 '1 2H- 14 1840950 96 70 60 P P 6IL · · 2H-15 1840860! 2H- 16 1840870 · 2H- 17 2000190 Wells: Remarks: Components: 18 FailUres: 4 Failure Rate: 22.0% I~]90 var three failed pilots repaired and retested, failed SSV to be repaired and retested by op Pad on 90 day teSt cYcle · 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls . STATE OF ALASKA AU~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ,5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 130' RKE 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 170' FNL, 654' FEL, Sec 35, T11N, R8E, UM 2H-11 At top of productive interval: 9. Permit number/approval number: 1336' FNL, 1247' FEL, Sec 35, T11N, RSE, UM 85.261 At effective depth: 10. APl number: 1380' FNL, 1279' FEL, Sec 35, T11N, R8E, UM 50-103-20052-00 At total depth: i 1. Field/Pool: 1496' FNL, 1364' FEL, Sec 35, T11N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 6765 feet Plugs (measured) None true vertical 6344 feet Effective Deptt measured 6655 feet Junk(measured) None true vertical 6122 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 224 Sx AS I 112' 112' Surface 2704' 9-5/8" 620 Sx CS III & 2743' 2743' 300 Sx CS II Production 6744' 7" 400 Sx Class G & 6746' 6328' 175 Sx CS I Liner measured 6400'-6409';6466'-6486';6513'-6536' true vertical 6038'-6045';6094'-6110';6133'-6152' ~ ,' '..:~i:-- Tubing (size, grade, and measured depth) 2.875", 6.5 Ib/ft, J-55 @ 6450' Packers and SSSV (type and measured depth) Packer: Brown HB @ 6247' & Brown 1-B @ 6433'; SSSV: Baker FVL @ 1775' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/7/98. Intervals treated (measured) 6466'_6486' Treatment description including volumes used and final pressure Pumped 145,259 lbs of 16/20 & 12/18 ceramic proppant into formation, fp was 7990 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 286 202 262 643 198 Subsequent to operation 377 311 827 1303 223 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil _X Gas _ Suspended _ Service _ 17. I hereby .certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title: Production Engineering Supervisor Date ~/Z~../~ Form 10-404 Rev~ 6/15/88 SUBMIT IN DUPUCA:I"B ~ .ARCG Alaska, Inc... '~UPARUK RIVER UNIT '~,-~'LL SERVICE REPORT 2H-11(4-1)) WELL JOB SCOPE JOB NUMBER 2H-11 FRAC, FRAC SUPPORT 0505980650.1 UNIT NUMBER DATE 06/07/98 DAY 4 FIELD ESTIMATE DALLY WORK A SAND REFRAC OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ~'~ Yes ~ No ('~ Yes ~'~ No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2127 230DS28H L $109,275 $134,294 750PSll 500PSll 484 PSI 500 PSI 400 PSI 400PSll 0.000 " SUPERVISOR JORDAN Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY A SAND REFRAC SCREENED OUT EARLY WITH 10 PPA PROPPANT AT PERFS. 145,245 LBS PROP PLACED IN FORMATION WITH 12,638 LBS PROP LEFT IN PIPE. MAX TREATING PRESSURE 7990 PSI. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - YOAKUM; LRS; APC. TGSM. PT EQUIP TO 9700 PSI OK. 10:00 PUMP CONDITIONING/BREAKDOWN STAGE ACCORDING TO PROCEDURE. MAX PRESS 7990 PSI AT 25 BPM. 10:19 STEPDOWN TEST AT SD AND PULSE TESTS. OBTAIN ISIP 2005 PSI. 11:38 BEGIN DATA FRAC. MAX PRESS 5928 PSI AT 15 BPM. ISIP 2060 PSI. 12:44 PUMP FRAC ACCORDING TO PROCEDURE TO 10 PPA FLAT STAGE, CUT GEL FROM 50# TO 40#, CUT ACTIVATOR AND RATE AS REQUIRED. 13:50 WELL SCREENED OUT EARLY WITH 10 PPA AT PERFS, 6200 PSI MAX. 145,259 LBS PROP PLACED IN FORMATION WITH 12,638 LBS LEFT IN PIPE. 16:00 RDMO DS FRAC UNIT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $965.00 APC $5,000.00 $7,600.00 DOW ELL $100,775.00 $105,775.00 HALLIBURTON $0.00 $9,739.00 LITTLE RED $3,500.00 $10,215.00 TOTAL FIELD ESTIMATE $109,275.00 $134,294.00 STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~STON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well _ Pull tubing Other X 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 170' FNL, 654' FEL, Sec. 35, T11N, R8E, UM At top of productive interval 1336' FNL, 1247' FEL, Sec. 35, Tll At effective depth 1380' FNL, 1279' FEL, Sec. 35, Tll At total depth . 1496' FNL~ 1364' FEL~ Sec. 35, Tll 12. Present well condition summary Total Depth: measured 6 7 6 5' true vertical 6344' N, R8E, UM N, R8E, UM N, R8E, UM feet feet Plugs (measured) 6. Datum elevation (DF or KB) 130' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-11 9. Permit number/approval number 85-261 10. APl number 5o-103-20052 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6 6 5 5' feet true vertical 6122' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 8 0' 1 6" 224 Sx 11 2' 1 1 2' 2704' 9 5/8" 1600 Sx 2743' 2743' 6744' 7" 575 Sx 6746' 6328' measured 6400'- 6409' (C Sand), 6466'- 6486', 6513'- 6536' (A Sand) true vertical 6038' - 6045' (C Sand), 6093' - 6110', 6133' - 6152' (A Sand) Tubing (size, grade, and measured depth) 2 7/8", 6.5 lbs/fi, J-55 EUE, set @ 6447' MD Packers and SSSV (type and measured depth) Packers: Brown HB 6244', Brown lB 6430', SSSV: Baker FVL 1772' 13. Stimulation or cement squeeze summary Refrac A Sand Intervals treated (measured) 6466' - 6536' A Sand Treatment description including volumes used and final pressure Pumped 34,200 lbs of light weight prop[ 14. Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations RE£EIVED ant (LWP) in I to 8.7 ppa stages. Last WHTP=7150 psi. Re_~reserltative Daily Average Production gr In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Press Tubing Press 323 314 57 1 0 0 0 208 1244 1792 138 1200 219 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 C.{~, ~ T'~e PETROLEUM ENGINEER Form 10-404 Rev 06/15/88 Date ~/~--'-4/~ ~--, SUBMIT IN DUPLICATE 'ARCO Alaska, Inc Subsicllary of Atlantic Ricl~field CompanY"--' WELL tTRACTOR REMARKS IPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME 4-.,,~/e WELL SERVICE REPORT I DAYS/ RECEIVED S E P 2 8 1997. I-"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W'ath' I Temp' I Chill Factor I Visibility }Wind Vel'Report OF OF miles Alaska, 0il .& Gas Cons. Commisslo9 Anchorage 1. Type of Request: STATE OF ALASKA ~ A~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARQO Alaska, In{;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Other feet 4. Location of well at surface 170' FNL, 654' FEL, Sec. 35, T11N, R8E. UM Service 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit 8. Well number 2H-11 At top of productive interval 1336' FNL, 1247' FEL, Sec. 35, T11N, R8E, UM At effective depth 1380' FNL, 1279' FEL, Sec.35, T11N, R8E, UM At total depth 1496' FNL, 1364' FEL, Sec. 35, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 6765' feet Plugs (measured) true vertical 6 3 4 4' feet Effective depth: measured 6501 ' feet Junk (measured) true vertical 6122' feet None Casing Length Size Cemented Structural Conductor 80' 1 6" 200 Sx AS II Surface 2704' 9 5/8" 620 Sx CS III & Intermediate 300 Sx CS II Production 6 74 4' 7" 400 Sx Class G & 175 Sx CS I Liner Perforation depth: measured 6400'-6409' (C Sand), true vertical 6038'-6045' (C Sand), Tubing (size, grade, and measured depth 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 6447' Packers and SSSV (type and measured depth) Packers: BROWN HB 6244', BROWN lB 6430', Baker FVL @ 1772' 85-261 ,/ 10. APl number 5o-1 03-20052 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 112' 112' 2743' 2743' 6746' 6328' 6466'-6486', 6513'-6536' (A Sand) 6093'-6110', 6133'-6152' RECEIVED 13. Stimulation or cement squeeze summary ~JUL ~1, 0 ]990 Intervals treated (measured) 6466'-6536' (A Sand) Treatment description including volumes used and final pressure Screened out refracture stimulation, pumped 310 bbls gelled water and 10,200 lbs of 16/20 Carbo-Lite (5,500 lbs in formation), final pressure 5090 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 7 6 2 3 3 0 8 0 0 1 3 3 Subsequent to operation 4 5 0 3 2 7 0 1 3 0 0 1 7 5 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 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. Si,ned ~~1~ ~/~o p~-~ Title SR. OPERATIONS ENGINEER Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WE~L ARCOAlaska, Inc ~ S'~bsidiary of Atlantic Richfield Comp; .../ IPBDT _ ~ )NTRACTOR REMARKS ,,,~. ~,s~,,c~. s~.~ OPERATION AT REPORT TIME WELL SERVICE REPORT DATE 06oo i,?/o R~,,,, 3~/ ] ! / ] ~ 1555- iqOO ? 16-2o 2,3° D52.~ HL [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp' I Chill Fact°r I Visibility IWind Vel'Report "F "F miles knots I Signed 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ STATE OF ALASKA AE,_~, OIL AND GAS CONSERVATION COMMI'I~ION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 650 1 ' feet Junk (measured) 61 2 2' feet None 6. Datum elevation (DF or KB) RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-11 9. Permit number 85-261 10. APl number 50-1 03-20052 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 170' FNL, 654' FEL, Sec. 35, T11N, RSE. UM At top of productive interval 1336' FNL, 1247' FEL, Sec. 35, T11N, R8E, UM At effective depth 1380' FNL, 1279' FEL, Sec.35, T11N, R8E, UM At total depth 1496' FNL, 1364' FEL~ Sec. 35, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 6 7 6 5' feet true vertical 6 3 4 4' feet Effective depth: measured true vertical Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 200 Sx AS II I 1 2' I 1 2' Surface 2 7 0 4' 9 5/8" 620 Sx CS III & 2 7 4 3' 2 74 3' Intermediate 300 Sx CS II Production 6 7 4 4' 7" 400 Sx Class G & 6 7 4 6' 6 3 2 8' 175 Sx CS I (C Sand), 6466'-6486', 6513'-6536' (A i~n"d_~) V ~.-~ (C Sand), 6093'-6110', 6133'-6152' ~- .... '-.~'l.~:~ii:/:! Liner Perforation depth: measured 64O0'-6409' true vertical 6O38'-6045' Tubing (size, grade, and measured depth 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 6447' Packers and SSSV (type and measured depth) Packers: BROWN HB 6244'~ BROWN lB 6430'~ Baker FVL ~ 1772' 13. Attachments Description summary of proposal _ Refrac A Sand with 29,400 lbs of 16/20 mesh carbolite. Detailed operation program X BOP sketch _ (Procedure and Wellbore schematic attached). Status of well classification as: Oil _X Gas __ Suspended 14. Estimated date for commencing operation I 15. December. 1989 I 16. If proposal was verbally approved I Name of approver Date approvedI Service 7. I hereby certify that the f,~regoing is true and correct to the best of my knowledge. Signed ~'~~-~/ Z~ _~~~~) FoRTitle COMMISSIoNSr' OperatiOnSuSEEngineerONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance ~ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY LONNIE [7,. SMITH IApproval No ~...,/,~~ I ~,pproved CoPY Returned Commissioner Date Approved by the order of the Commission Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE , . . g . . Kuparuk Well 2H-11 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80658 MIRU Slickline unit. Tag bottom. Pull CV's at 6282', 6348', and 6418'. Run DV's at 6282', 6348', and 6418'. Pull GLV's at 2241', 3783', 5560' and 6188'. Run DV's at 2241', 3783' and 5560'. Circulate 2 7/8" tubing and 7" annulus with 9.8 ppg brine with a diesel cap. Set DV in GLM at 6188'. Note that DV's are set in GLM's at 4871' and 5874'. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. Perform A Sand only production test. Set standing valve in Camco 'D' nipple at 6440' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO Slickline unit. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 100 Bbl pre-pad at 18 BPM. Shut down and determine the ISIP. The A Sand was perforated with 172 shots, 4 spf, at 90 degree phasing with an SOS 4" Casing Gun. Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISlP. Expected wellhead treating pressure: WHTPE = 4380 psig Fracture Gradient = 0.73 psi/ft (6100' TVD) Frac Fluid Gradient -- 0.35 psi/ft Tubing Friction = 320 psi/1000 ft @ 18 BPM (6447' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. With brine on the backside, the maximum recommended treating pressure is 6500 psi based on analysis of tubing strength and PBR type. Maximum pressure during the initial fracture treatment was 6800 psi. Rig down fracture stimulation equipment. Follow attached flowback schedule. Obtain a fluid sample from flowback to determine if a water cut is present which will indicate if the refrac propagated into the C Sand. KUPARUK WELL 21t-ll A SAND FRACTURE PUMP SCHEDULE 1117189 STAGE FLUID CLEAN VOLUME PUMP RATE PI::IOP. CONC. PI::IOPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CU M BBLS I GD PRE-PAD 100.0 18 0 - - 0 1001 100 39 ............................................. SHUT DOWN FOR ISIP, FLOW METER CALIBRATION ................................................ 2 GDPAD 170.0 18 0 - - 0 170 I 270 139 3 GD w/2 PPG 4.6 18 2 16/20 M CARBO-LITE 386 5 / 275 309 4 GD wi4 PPG 8.5 1 8 4 16/20 M CARBO-LITE 1428 1 0 I 285 314 5 GD wi6 PPG 11.9 18 6 16/20 M CARBO-LITE 2989 1 5 / 300 324 · 6 GD w/7 PPG 15.3 18 7 16/20 M CARBO-LITE 4494 20 I 320 339 7 GD wi8 PPG 18.5 18 8 16/20 M CARBO-LITE 6210 25 / 345 359 8 GD wi10 PPG 17.4 18 1 0 16/20 M CARBO-LITE 7288 25 / 370 384 9 GD w/12 PPG 13.1 1 8 1 2 16/20 M CARBO-LITE 6593 20 I 390 409 1 0 SLICK DIESEL FLUSH 36.0 +SV 18 0 - - TOTAL SLICK DIESEL = 36.0 +SV 29,389 LBS TOTAL GELLED DIESEL = 359.2 BBLS TOTAL FLUID = 395.2 The table above represents total job volume. Stages 1 and 2 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. Stages 3 through 9 are Gelled Diesel with enough breaker for an 8 hour break and WITHOUT silica flour. Stage 10 should include, a volume adjustment for Surface equipment between the wellhead and the densitometer and an 8 hour breaker. ,Stages 3 through 10 are scheduled to pump at 18 BPM to limit height growth. However, an increase in treating pressure may warrent a decrease in rate or early flush, The job is Intentionally underflushed by 2 Bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 degrees F on the sudace. The A Sand was perforated with approximately 172 shots (4 spf). KUPARUK WELL 2H-11 APl #: SPUD DATE: 501032005200 11/10/85 ADL LEASE: 25587 COMPLETION DATE: 12/15/85 PERMIT #: WORKOVER DATE: SURFACE LOCATION: 170'FNL,654'FEL,SEC35,T11N,R8E TOP OF KUPARUK: 1336'FNL, 1247'FEL, SEC35,T11N,R8E TD LOCATION: 1496'FNL, 1364'FEI~SEC35,T11N,R8E All depths am MD-RKB to top of equipment unless otherwise noted ORIGINAL RKB: 130 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5# H-40 112 9.625" 36# J-55 2743 7" 26# J-55 6746 2.875 6.5 J-55 EUE 6447 LINER DETAILS SIZE WEIGHT GRADE TOP TUBING SPOOL: 31.5 WELLTYPE: PRODUCER BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.313 1772 SBR BROWN PBR 2.5 6232 PKR BROWN HB 6244 PKR BROWN lB 643O NOGO CAMCO 'D' NIPPLE 2.25 6440 SHROUT BROWN 6446 L PAD ELEVATION: 95 STN 1 2 3 4 5 6 7 8 9 INTERVAL 64oo-64o9 6466-6486 651 ~6536 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2241 CAMCO KBMG 1.0" 3783 CAMCO KBMG 1.0" 4871 CAMCO KBMG 1.0" 5560 CAMCO KBMG 1.0" 5874 CAMCO KBMG 1.0" 6188 MCMURRY HUGHES 1.5" 6282 CAMCO KBMG 1.0" 6348 CAMCO KBMG 1.0" 6418 CAMCO KBMG 1.0" PERFORATION DATA ZONE FT SPF PHASE C 9 12 120 A 20 4 A 23 4 90 85-261 PORT SIZE .1875 .2500 DV .3125 DV .3750 FO FO FO COMMENTS SOS 5' CSG GUN SOS 4" CSG GUN MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 36 HOLE ANGLE THRU KUP: 32 LAST TAG DATE: 10/28/86 RATHOLE: ~'S¢~ FISH/OBSTRUCTION: PBTD: PBTDSS: dog deg DEPTH 6655 6121 REVISION DATE: 10/06/88 REASON: OPEN C SAND SUNDRY NOTICE - WELL 21-1-11 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) = 3230 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. STATE OF ALASKA ALA-~,%,,~OIL AND GAS CONSERVATION COI~,,,.,,,,r..,.,CSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 170' FNL, 654' FEL, Sec.35, T11N, R8E, UM At top of productive interval 1336' FNL, 1247' FEL, Sec.35, T11N, R8E, UM At effective depth 1448' FNL, 1329' FEL, Sec.35, T11N, R8E, UM A~./~jtg~d~t~, 1364' FEL, Sec.35, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name KiJnarlJk Riving' lin'ii- 7. ~ell number 2H-11 8. Approval number 9. APl number 50-- 103-20052 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured 6765 true vertical 6344 feet feet Plugs (measured) None Effective depth: measured 6655 feet true vertical 6251 feet Junk (measured) None Casing Structural Conductor Surface x x Production XXXL>~i~xxxxx Perforation depth: Length Size Cemented Measured depth 81' 16" 125SX CS-II 112' MD 2711' 9-5/8" 620SX CS-III 2743' MD & 300SX CS-II 6714' 7" measured 400SX Class G 6746' MD & 175SX CS-1 6513'-6536' MD, 6400'-6409' MD, 6466'-6486' MD True Vertical depth 112' TVD 2743' TVD 6328' TVD true vertical 6133'-6152' TVD, 6038'-6046' TVD, 6100'-6119' TVD 12. Tubing (size, grade and measured depth) 2-7/8", J-55 EVE @ 6447' MD Packers and SSSV (type and measured depth) Baker FVL SSSV @ 1772'/Brown HB pkr @ 6244'/Brown lB pkr. @ 6430' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 1746 7758 0 500 355 2917 5754 0 500 500 14. Attachments Daily Report of Well Operations 1~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~r.~' '.~ -¢ ~ '- ~ Signed ¢ ~ ~I.,~,,,/. ~ //~ ,t~'"k.~ ~-,¢~'r/"f'q Form 10-404 Rev. 1/2-1-85 Title Sr. Operations Engineer Date ;~ (/ 0-~ ~ ~ Submit in Duplicate ARCO Alaska, Subsidiary of Atlantic Richfield Company · ' ,.;ONTRACTOR REMARKS ......__.__.. WELL SERVICE REPORT IFIELD- DISTRICT.- STATE OPERATION ATREPORT TIME i DAYS I DATE ~Sqo 1"tl5 Z~. + S~r~ ~- ~/(,(, - ~ "IRE& '~_~f~ ~,~11 I C53~~ CoB sh~,~ AS~ Po / [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Post Office b,~,~_. '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1990 Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: As per your request, included in this package is a copy of the open hole LIS formatted tape for well 2H-11, API number 501032005200, a copy of the verification listing, and a scan of the tape. I compared the statistics of the data on this tape, and the data on file in our database, and this does appear to be the same data. Please return a copy of the transmittal. If I can be of further assistance, please let me know. Sincerely, Lynn Goettinger Associate Explorafionist LG/dlw T.L. Hudson - ANO 946 C.G. Suchland - ANO 848 CONCUR' TRAVIS L. HUDSON RECEIVED MAY - 8 1990 Alaska 01t & Gas Cons. Commisslen Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AR3B-6003-C Transmittal Arco Alaska Inc. Re: ~H-II Well Name : ,P, ~4 -! I Well API : ~o I o ~ ~o o ~S 2.c~ Tape#: D~ is ~ c.p~ Please return a copy of this transmittal when you have received the tape. Thank you. - STATE OF ALASKA ALAS~OTE AND GAS CONSERVATION COI~,MISSION WF. LL COMPLF. TION OR RECOMPLF. TION RF.I ORT &ND Leo 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-261 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20052 4. Location of well at surface 9. Unit or Lease Name 170' FNL, 654' FEL, Sec.35, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1336' FNL, 1247' FEL, Sec.35, T11N, R8E, UM 2H-11 At Total Depth 11. Field and Pool 1496' FNL, 1364' FEL, Sec.35, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 130' RKBI ADL 25587 ALK 2673 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore I16- No. of Completions 11/1 0/85 11/15/85 11/17/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+l-VD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 6765'MD,6344'TVD 6655 'MD ,6251'TVD YEs[~X NO [] 1775 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, Gyro(GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112' 24" Conductor report not y~t received. 9-5/8" 36.0# J-55 Surf 2743' 12-1/4" 620 sx CS Ill & 300 sx CS II 7" 26.0# J-55 Surf 6746' 8-1/2" 400 sx Class G & 175 s:~ CS 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) 6513' - 6536' w/4 spf, 90° phasing 2-7/8" 6450' 6247' & 6433' 6400' - 6409' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO AI~ ~1 & uas Cons. Form 10-407 * NOTE: Tubing was run and well perforated 12/15/85. GRU13/WC17 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS · . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Kuparuk C 6400' 6037' N/A Base Kuparuk C 6409' 6045, · Top Kupauruk A 6436' 6067' - . Base Kuparuk A 6604' 6209' -~ ' · : . . · 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · /~ _- Associate Engineer ..~ .~ / ..~/..~ ! Signed ~ N.~~ Title Date__ I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production frOm more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item z3~.~A-tta'cl~e-~ s~JppJemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. &,DO,- ' "' ~'"'~"i", ,..,~.~.~, ~,; ,,; ~ ., Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- je~iE'~.)~ as ~ njection~.S~ut:in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 : ADDENDUM WELL: 11/19/85 12/02/85 1/12/86 2H-11 Arctic Pak well w/175 sx CS I. Log GR/CCL/CET/gage ring f/6648'-4900'. Rn GCT gyro f/6648'-surf. Frac Kuparuk "A" sand perfs 6513'-6536' in 3 stages per 12/27/85 procedure using gelled diesel, Musol & 20/40 sand. Press'd ann to 1500 psi w/diesel. Tst ins to 7000 psi; OK. Pmp'd 20 bbls 5% Inflo 40 Musol, followed by 38 bbls cln diesel on 1/11/86. Stage 1: 22 bbls gelled diesel pad @ 5/6.1BPM, 4070 psi-3480 psi. Stage 2: 22.7 bbls gelled diesel w/6 ppg 20/40 mesh sand @ 12.4 BPM w/max press of 3900 psi. Stage 3: 37.5 bbls gelled diesel flush @ 15.3/19 BPM w/final press of 6900 psi. Pmp'd 3990# 20/40, 6 ppg sand in formation leaving 494# 20/40, 6 ppg sand in 7" csg. Load to recover 77 bbls of diesel. Job complete @ 1534 hrs, 1/12/86. APR0 1986 ~Jaska Oil & Gas Cumin. ~o~i~missi0n Anch~rnge Drilling ~uperintendent / ~ate .ARCO Alaska. h - . Post Office 6'e-g'100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints/ Schl/ CET or CBL's/ One * of each ~lQ-12 01-21-85 Run #1 3536-6934 A-8 11-02-85 Run #1 6986-8362 D-13 12-17-84 Run #1 5425-7488 ~2D-14 17-12-84 Run #1 6288-8136 ~H-11 11-28-85 Run #1 4850-6642 ~2H-12 11-28-85 Run #1 5500-6776 ~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Run #1 6792-8329 ~3F-4 11-12-85 Run #1 4770-6734 ~F-7 11-14-85 Run #1 4950-7876 DATE 03-11-86 TRANSMI?fAL # 5595 Please acknowledge receipt and PLEASE NOTE: These logs were received from the vender today 03-11-86. Receipt Acknowledged: ~.~S~.ate of' AK*bl/se "*~-i~~ Vault*~films NSK Clerk*bl ARCO Al-,lkl. Inc:. ~! · Subs,chlr~ of Alls, nlicRicl~fieldComDany STATE OF ALASKA .._~. . ALAsKA'~AND GAS CONSERVATION CO~/I~rgJlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc 85-261 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 5o- 103-20052 4. Location of Well 9. Unit or Lease Name SURFACE LOCATION: 170' FNL, 656' EL, SEC. 35, KIJPARUK RIVER UNIT T11N, RSE, LlVl lo. well Number 2H-11 11. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KUPARUK RIVER 0IL PCX)L 130' (RI<B) AB_ 25587, ALK 2673 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~_Jrm Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-i Repair Well [] Change Plans [] Repairs Made [--J Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand be perforated for production. Procedures call for the Nell to be perforatec through tubing wJth 4 SPF. Proposed Interval (IVD). 6466 - 6486 AF,rFICIPATED START DATE: ~rch 10, 1986 .. RECEIVED MAR 0. 1986 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The spa~e be,ow 6~?/Co'mm~ssi~on use - T~t,e Sr. 0perat4ons I:ngr. Conditions of Approval, if any: ~turr~d COMMISSIONER the Commission Date Form 10-403 P..~,_. 7-1 -Riq Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company Daily web"History-Final Report Inatructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Ret0ort" should be submitted also when operations are suspended lot an indefinite or appreciable length of time, On workovers when an olficial 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 avadable. District Alaska Field ICounty or Parish Lease or Unit Title North Slope Borough Accounting cost center code State Alaska IWell no. 2H-1I Kuparuk River Auth. or W.O, no. AFE kE0065 Roll'N 4 Operator ARCO Alaska, Inc. ADL 25587 Completion Spudded or W,O, begun AP1 50-103-20052 Complete Date and depth as of 8:00 a.m. 12/13/85 thru 12/16/85 IA.R.Co. W.I. 56.24% IOate - 12/13/85 Complete record for each day reported Iotal number of wells (active or inactive) on this pst center prior to plugging and I bandonment of this well I our J Prior status if a W.O. 2100 hrs. I 7" @ 6746' 6655' PBTD, RI{ 6.8 ppg Diesel Accept ri~ @ 2100 hfs, 12/13/85. ND lower tree, NU & cst BOPE to 250/3000 psi. RU Schl, perf w/4", 4 SPF, 90° phasing f/6513'-6536'. Perf "C" sand w/5", 12 SPF, 120° phasing f/6400'-6409'. Make 6-1/8" gage ring/JB rm co 6500'. RIH, set BOT lB Pkr w/top @ 6430' ELM, RD Schl. Rn 203 its, 2-7/8" 8RD tbg & lnd w/SSSV @ 1775', HB pkr @ 6247', lB Pkr @ 6433', "D" Nipple @ 6443', TT @ 6450'. Set MB pkr, tst tbg. Shear off PBR, re-lnd tbg. Tst ann & pkr; OK. Tst SSSV. Set BPV, ND BOPE, NU &tst tree. Displ well to diesel. RR @ 1500 hrs, 12/15/85. Old TD Released rig 1500 hrs. Classifications (oil, gas, etc.) Oil New TO ] PB Depth 6655 ' PBTD i Date J Kind of rig 12/15/85 ] Rotary Type completion__.~gle, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test dala Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X iength Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ] Title For form preparation aRd distribution, see Precedures Manual, Section 10, Drilling, Pages B6 and 87. Drilling Superintendent STATE Of ALASKA ~- ALASI~..~.~ AND GAS CONSERVATION ~-~-~?IISSION 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. 85-261 3'i Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510-0360 50- 103-20052 4. Location of well at surface ~~ 9. Unit or Lease Name 170' FNL, 654' FEL, 5ec.35, T11N, R8E, UM~ L'-~'""~IVERIFiED ! Kuparuk River Unit At Top Producing Interval [c~..~: ~ [~ ~~ 10. Well Number 1336' FNL, 1247' FEL, Sec.35, T11N, R8E, UM : 2H-11 At Total Depth - - 11. Field and Pool 1496' FNL, 1364' FEL, Sec.35, TllN, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 130' RKB ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/10/85 I 1/15/85 1 1/17/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6765 'MD ,6344 'TVD 6655'MD,6251 'TVD YES ~X NO [] 1775 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring, Gyro(GCT) 23. CASING, LINER AND CEMENTING RECORD -_. SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112' 24" Conductor report not y ;t received. 9-5/8" 36.0# J-55 Surf 2743' 12-1/4" 620 sx CS III & 300 sx!CS II 7" 26.0# J-55 Surf 6746' 8-1/2" 400 sx Class G & 175 s: CS 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) 6513' - 6536' w/4 spf, 90° phasing 2-7/8" 6450' 6247' & 6433' 6400' - 6409' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None A!~sk~ 0il & Gas C0~s. Form 10-407 * NOTE: Tubing was run and wel 1 perforated 12/15/85. TEMP3/WC60 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . GEOLOGIC MARKEF~S ;. ' -; "": ' :-:; :? .: .... ¢:':f;~ (~'~ ~ ~,T;;o N :'¢'I~S'T~:' ' :: .~' : · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6400' 6037' N/A Base Kuparuk C 6409' 6045' . Top Kupauruk A 6436' 6067' Base Kuparuk A 6604' 6209' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~J Title Associ ate Engi neer Date f/ 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 SUB. SURFACE DIRECTIONAl. SURVEY [~]UIDANCE [~ONTINUOU$ ~OOL Company ,A~CO ALASKA INCORPORATED Well Name 2H-11 (170' FNL, 654' FEL, S35, TllN, R8E, UM) II I · i I Field/Location ~~,, NORTH, SLOPE,, ALASKA 71086 Loaaml ~v:. SARBER Oat__.~e 17-DECEMBER- 1985 Computed GCT 3ZRECTi3NAL SU~VF-Y -USTOMEq Li STI~'~S ~RC3 ~L~SK&, iN~. 2H-i1 NORTW SLOPE,&LASK,~ SURVEY 3&T~: Z8 NOV 85 ',IETH33S OF COqP,JT~TIO~i TOSL L3C&TISN: T&NGENTi~L- ZNTERPgL&TI3N: LINE&R V:EqTiC&L SECTIJN: H!']qZZ. DIST. DEVI&TION 'A kl L) ONT3 & T~gET ~ZI~UTm ARCO AL4SKA, INC. OH-11 KJPARUK NORTH SLOPE,ALaSKA COMOUTATION DATE: 17-CEC-85 2,".TE ,3'= .SJeVi:Y': 215 ',~3V '-35 KELLY 3USHiNG ':L=VATIJN: 130.3,2 ENGINeeR: S~R.~£R ,=T INTCRP,.. ~LAT-O- VALOES FOR ~VEN 100 :=:T oF- TRUE SUB-SEA MEASURED VERTICAL V;RTICAL DEPTH DEPTH OE~T~ 0.09 0.00 -130.00 100.00 190.00 -30.00 200.00 200.00 70.00 300.00 300.00 170.00 ~OO.O0 400.00 270.00 500.00 499.99 369.9~ 600.00 599.~9 469.'99 700.00 699.9'3 569.99 900.00 7)9.99 669.99 )00.00 899.99 769.99 lOOO.O0 999.99 889,.99 1100.00 1099.99 969.)) 1ZO0.O0 1199.9~ 1059.98 1300.00 1299.98 1169.98 1~00,00 1399,~ 1269,99 1500.00 1~99.98 1369.98 1600,00 1599,98 1469,98 1700.00 1699.98 1569.98 1800.00 1799.97 1669.97 1900.00 1899.97 1763.97 2000.00 1999.97 1869.97 2100.00 2099.~7 1969.97 2200,00 2199,~6 2069,96 2300.00 2299.96 2169.96 2~00.00 2399.95 2269.96 2500.00 2~99.96 236~.96 2600.00 2599.96 2469.96 2700.00 2699.95 2569.95 2800.00 2799'.95 £669.95 2900.00 2899.95 276'~.95 3000.00 2999.94 1869,94 3100.00 3099.94 290~,9~ 3200.00 3199.93 306~.93 3330.00 3299.93 3169.93 3400.00 33'99.93 3269.93 3500,00 3499,92 3369.92 3600.00 3599.92 3469.92 3700.00 3599.75 3563.76 3~00.00 37~9.03 3669.03 3900.00 3895.95 .3766.98 COURSE V=RT!CAL DOGLEG DEVIATION 4ZIMUT~ SECTION SEV:R~TY DEG MIN DE,3 ~IN ;EET OEG/IO0 0 0 N 0 0 5 0.00 0.00 0 1~ S 44 24 : 0 O0 0 0 19 S aS 33 ~ 0.19 0.12 0 15 S lO 36 : 0.35 0,17 0 12 S 52 15 ~ 0,71 0 13 N 52 31 W 0.9~ 0,2~. 0 9 N 7 34 W ~.73 0.25 0 12 S 55 2 ~ 0.37 0.33 0 16 S 39 10 E 0,70 0.20 O 15 S 20 7 E 0.93 0.2,3 0 22 S 20 la W 1.35 0.23 0 25 S 36 11 W 2,11 0.23 0 25 N 81 53 4 2.75 0..55 0 15 N 68~3 J 2...,~3 0.~ 0 lO S 5 34 5 2.97 0.11 0 17 S 7 20 ,~ 3,37 0.06 0 23 S 27 46 W 3.97 0.05 0 25 S 32 49 W 4.68 0,06 0 26 S, 6,~ 54 W 5.41 0.89 0 17 N 43 32 w 5.43 0.1'~ 0 27 N '37 11 E 4.91 O.l~ 0 23 N 45 17 ~ 4.17 0,44 0 23 S 56 ~ = ~ 72 0,'~8 0 23 S '1~ 21 '= 4,01 0,13 '3 21 S 27 5 E ~.~4 ~,34 0 14 S 49 0 ~ 4,57 0.51 0 25 N 71 32 = 4.28 0.1') 0 24 N 63 23 ~ 3,58 O,a7 0 17 S 29 38 4 3.55 1.57 0 32 S 3~ 15 W ~.,38 0.27 0 13 0 33 S 3& 43 W 5.34 0.0,3 0 35 S 35 11 ~i 5.30 0.29 0 33 S 3:5 25 W 7.2',:) 0.15 0 31 S 35 37 ,~ ~].20 O. 0 28 S 3~ 57 W 8.97 0.13 32 'S'38 5 ~,,,' 9.3~:, ~9 S 13 21 W 10,79 2,25 i'~ S 2 27 ~ 15,26 ~9 S 4 49 W 25,25 5,75 H~aSURE3 eSCT.AN'3 N3RTh/S DEPTH :JLAR CJ3ROIN~T2S 2'JTa Eg'T/NE]T FldT ' O0 N '3.'30 '= O ~3 S 0 ~0 C.55 S 0.7~* ': 0.98 S O. :)9 :_ 1.3~ S 0.90 : 1.35 S 0.56 ~ 1.0=~ S 0.3~ _ ~.27 S G.~i : Z.21 S 1.35 E 2.52 S 0.,57 E 3.20 S S.O~ ,2 2.'9~, S 0.50 :~ 3.05 '5 0.55 W 3.50 S 0.57 ~,~ ~..07 S O. 38 ~ ~.58 S 1.24 W 5 · 27 S i. 70 , 5,04 S 2,14 w 4,48 S 2,05 3,88 S 1.52 3,76 S 0.93 4.32 S 0.E& 4.'~6 ~ 0.29 5.43 S 0.06 5.3~ s o.,s3 5 · 06 S 1 · 39 ~.9~ S !.~5 S · ~c, ~ S 1.06 ,5 · ~ 7 S 0 · 50 7.,:.:~'4 S 0.07 5.'35 S 0.6a 3.50 S 1.17 ').~1 S 1,65 10.14 S 2.20 10 · 92 5 2.67 15,'90 S 2,60 27. S3 S 2.34 47.11 S 7.37 H3RZZ. O~-ST C..~2 1.52 1 !.11 1 .0'~ 1.51 I.~'9 3.20 2.Og 3,13 3.56 4,17 5.54 5.45 '~. ') 3 4.2! 4.35 4. ~ 7 5.34 ~,25 5.15 5.7~ 5.49 7. !4 10.33 1! .25 1,5.12. ~, '7.5 g ]EOARTUR: ALASKA, INC. 2~-11 KUP~RUK NORTH SLOPE,AL~SK~ COMPUT~Ti]N DATE: l?-DEC-95 3AT= G= SU~V' Y: Z'.~ ~lJ'v' $5 AcLLY BjS~tIW..5 =L"V~TiDN: 13).JJ =WSiNEER: SA~D~R '-T iNTETPOL~T:O V~LJES F3~ EVEN TRUE S33-S:A ME&SURED VERTIC&L VERTICAL DEPTH D~PTq DEPTH 4000,00 3993,11 3853,11 4100,00 ~058,70 3958,7J ~200,00 ~1~3,~3 ~053.49 4300,00 4275,57 41~5.57 4400,00 ~367,14 ~237,14 4500,00 ~55,36 ~325,35 4600,00 4541,~1 ~411,81 4700.00 4626.8~ ~496,8~ 4800,00 4710.15 ~5~0.15 4900,00 4792.~3 ~66Z,43 5-000,00 4874,28 47a4,2~ 5100,00 ~956.38 a826,33 5200,00 5035,~9 ~90~,49 5300,00 5120,~5 ~990,~5 5~00,00 5201.96 5071,'~6 5500,00 5283,18 5153,18 5500,00 536~,0~ 523~,02 5700,00 5~44,73 531~,'73 3800,00 5525,84 5395,84 5~00,00 5608,19 5478,19 6000.00 5693.78 5563.78 6100.00 5779.93 55~9.93 6200,03 5866.33 5736.33 6300.00 5952,02 5~22,02 6400,00 6036.88 5906,8~ 6500.0~ 6121,36 599!,36 6600.00 6205.39 5075.39 6700.00 6289.1.1 5159.11 6765.00 6343.53 6213.53 CDJRSE VSRTiC&L 3CGLE'S D:VI~TiON ~ZiMJT~ SECTION S=VEqITY PEG ~iN ]~G MI'J ~E:T C:'3/IOO 16 53 S 22 4~ W 11.70 0.39 17 37 3 23 53 ',q 100.85 2.22 19 36 S 27 37 W 132.~6 1.50 23 21 S 25 39 W 169,35 5,14 26 26 S 2~ 3~ N 211,40 2.71 29 36 S 22 42 W 258.29 3.85 30 34 S gO 44 W 307.~8 1.86 33 1 S 22 55 W ~59 R;q o 55 33 58 S 25 33 W 414.94 2.~6 35 3 S 29 50 N 471.71 1.25 34 58 S 30 15 W 529,16 3,~1 34 ~5 S 30 10 W 595.25 0,16 34 50 S 29 47 .W 54=.3,3 0.31 35 11 S £9 20 W 700,63 O,?O 35 31 S 2& 53 W 755.54 0.3~ 35 53 S 28 11 N 816.~7 0.77 36 7 S 2'7 6 W 875.67 9.54 36 1 S 26 34 W 934.61 0.95 35 44 S 26 13 W 992.98 0,53 32 25 S 28 17 ~ 1049,58 4.89 30 ~5 S 28 59 W 1101.28 0,61 30 11 S 28 23 N 1152,04 0,59 30 32 S 2~ 5~ W 1202.37 1.29 31 36 S 31 58 W 1253.90 2.05 32 4 S 35 22 W 1336,68 1,23 32 40 S 36 1 W 1359,91 3,58 33 9 S 36 12 W 1413.$~ 0.00 33 9 S 36 12 W 1455.21 0.03 33 9 S 36 12 W 1503.55 O.OJ '72.51 'S 17.55 W 74.52 S 13 4~ 4 99~5! S 2~.41 ~ 133.7~ i2S,3'~ S 45.$) N 12.5.51 150.35 S 60.55 W 171.!2 S Z'] 197.30 S ,~1. I~ W 213..~4 c,~ ->_~ ~" 23~.55 5 101. r5 W 2S0.27 S ~3 ~ ~" 2~6.54 S 11~.)7 W .31D.=) S 22 3~ 335.2) S 139.15 W 3 '3.02 5 22 32 3~5.~3 S 151.7~ W ~1'{.36 S g2 ~36.~6, S 185.3! :~ 47~.~8 S 435.57 S 217.2'7 W 5~Z.P6 S 2_~, 5 ,~ 535.31 S 245.,31 ,4 555.~,5 5 2~ 41 ~ 584.43 S 274.56.. W 645.71 5 ~;.., 9 ~ 534.23 S 302.31 ~ ~02.~{5 ~ !5 31 ;g 58~.87 S 331,31 W 78'3.~7 S ,Z5 47 W 736.11 S 35~.~2 Z ~!,J.95 S 25 59 ~ 788.24 S 3~,5.23 W 377.75 S 25 5 W ~40.95 S 41:2.83 W :~35.:51 S 25 ~ W 393,39 S 43~,75 W 9'95,3i S 25 9 4 943,'~3 S 4.54,42 N 1051.99 S 25 11 ,~ 959.11 S 489.57 W I103.64 S 2,5 20 1033.57 S 513.91 W 1154.78 S 25 2~ 1077.99 S 537.$1 W 1.204.7'J S 2,5 30 1122.4~ 5 563,~3 ',~ 125,5.13 5 25 ~J 1166.&6 S 593.20 W 1308.,53 S 2b 5~,i' 1209.77 S 624.63 W 135!.51 S 27 lot 1253,63 S 656.54 'a 1415.12 S 27 38 1297.72 3 688.85 W 1~6~.Z2 3 27 57 1326.40 S 709.85 W 1504.40 S 25 9 w 4RCO ~L4SK~, INC. 2H-11 KUPARUK N]RTH SLOPE,&L6SKA CO~PUTATI]N D~TE: 17-DEC-85 $ a 3 ': 3 DATE O: SORVEY: 23 N]V 95 KELLY '3USHING 5L'fiVATIJN: 13,3.00 iNTERmOL,ATED VALUES FOR EVEN 1000 =EET O: M6ASUREO DEmT TRUE SJB-S:A MEASURED VERTIC&L VERTICAL DEPTH D=PTq DEPTH COURSE DEVIaTiON AZIMUTH DEG MiN DEG MIN VEqTICAL SECTION SEVERITY FEET 0.00 0.00 1.38 0.23 4.91 0.1~ 5.3~ 0.0,9 71.70 0.39 529.16 0.41 1101.28 0.$1 1503.55 9.00 0.00 0.00 -130.00 1000.00 999.99 869.99 2000.00 1999.97 1869.97 3000.00 2999.94 2869.94 4000.00 3993.11 3863.11 5000.00 ~874.Z8 474~.18 6000.00 5693.78 5563.78 6765.00 6343.53 6213.53 R=CTA~ NORTH FE NSOL~R C'3']RDI'IDTES HDqlZ. 3=m&RTURE /SOUTh :&ST/~AxzST.. 3;.ST. &~'"~'UT~:: , . 'r-T r-=ET r~-T '3 5 :.~ qiN 0 Z 4 72 132.-2 .00 N 0.00 ~l 0.O0 q O O E .2! S t.05 E 2.~,5 S 25 39 _ .4'3 S 2.0-5 W ~,.93 S 24 33 ,.,%' .47 S 0.50 .51 S 17.35 .67 S 217.27 W 53Z.05 .11 .S ~.~.37 w i .~3 S '7n~9..35 W 1 ~.,O~.AJ ~q _P~ '9 w =T , ARCO aLASKA, INC. DM-11 KUPARUK NORTH SLOPE,ALASK~ COMPUT4TIDN OATE: 17-D:C-B5 INTERODL~TED V&LgES FOR 5-VEN 100 =CET 3: TRU; SUb-SE& MEASURED VERTICAL VERTICAL DEPTH DEPTH DE~TM 0.00 0.00 -130.00 30.00 30.00 -100.00 130.00 130.00 0.00 230.00 230.00 100.00 330.00 330.00 200.00 430.01 430.00 300.00 530.01 530.00 400.00 630.01 630.00 500.00 730.01 730.00 600.00 830.01 830.00 700.90 930.01 930.00 1030.01 1030.00 900.00 1130.01 1130.00 1000.00 1230.02 1230.00 1100.00 1330.02 1330.00 1200.00 1430.02 1430.00 1300.00 1530.02 1530.D0 1400.00 1630.02 1630.00 1500.00 1730.02 1730.00 1600.00 1830.03 1830.00 1700.00 1930.03 1930.00 1800.00 2030.03 2030.00 190C.00 2130.03 2130.00 2000.00 2230.04 2230.00 2100.00 2330.04 2330.00 2200.00 2430.04 2430.00 2309.00 2530.04 2530.00 2400.00 2530.05 2630.00 2500.00 2730.05 2730.00 2600.00 2830.05 2830.00 2700.00 2930.05 2930.00 2800.00 3030.06 3030.00 2900.00 3130.0~ 3130.00 3000.00 3Z30.OT 3230.00 3100.00 3330.07 3330.00 3200.00 3430.08 3430.00 3300.00 3530.08 3530.00 3400.00 3530.09 3630.00 3500.00 3730.39 3730.00 3~31.~2 3830.00 COORSE V~RTiC~L OOGLEG OEVI~TI~N ~ZIMUTH S~CTi]N SEVERITY DES ~IN DEG MI~'.J FEET ~E5/lO0 0 0 N 0 0 ~ O.OD 0.00 0 16 N 7~ 49 E 0.00 0.2~ 0 20 S 49 35 5 0.05 0.55 0 18 S 37 45 E D.I6 0.13 0 14 S 0 53 W 0.45 '3.19 0 12 S 75 29 W O.~O 0.25 0 13 N ~0 10 W 0.85 0.10 0 $ N 17 59 E 0.65 0.25 0 15 S 43 21 E 0.50 0.13 0 !6 .S ]~ 33 ~ 0.75 0.11 0 17 S 10 46 E 1.04 0.09 0 24 S 30 13 W 1.59 0.34 0 g5 $ 39 1¢ W 2.33 0.34 0 21 N 67 3 W 2.79 0.19 0 9 N ~1 55 ~ 2..B5 0.45 0 14 S 1 37 :~ 3.05 0.39 0 19 S 12 35 W 3.51 0.24 O 24 S £~ 3~ W a.18 0.16 0 25 S 30 20 W 4.90 0 19 N 68 55 W 5.51 0.64 0 19 N 14 39 0 26 N 33 8 0 25 N 71 45 0 25 S a3 33 0 23 S 19 15 0 gO S 33 59 0 13 N 84 0 0 27 N 72 15 0 13 N 21 ~5 0 28 S 24 ~3 5.3'7 0.92 4, 67 O. 24 ~ ")8 O 6~ 3.76 0..56, ;,.1z, 0.20 4. 52 0 · 34 4.64 1.OO 4.10 3.75 0.36 4.68 0.15 5. ,$3 0.33 .5.6 O 0.06 7.57 O,3B 8.45 0.29 ~. 23 0.20 13.17 0.35 11.37 ¢.13 17.62 2.95 30.17 6.64 .0 34 S 33 57 0 32 S 33 25 0 3~ S 35 32 0 29 S 34 5 0 25 S 39 12 0 31 S 36 14 0 32 S 37 34 1 ~ S 0 3'9 6 15 S 2 49 !0 34 S 1i 33 DATE 3: SJRVEY: 23 '~2V 55 KELLY 2USHiNG ELEVaTi2M: liS.JO 5NG!W'zEq: S~qD;e S.JB-SEA FT 5.00 ,"4 3.00 E O.OO '.,~ O 0 ,,: 3.29 S 0.4i E 0.50 " 54 5 "'.57 S 3.,3'-' 1.0~ 1.10 S !.30 f 1.,9 !.39 S 0.$0 _= !.51 1.25 S 0.48 5_ 1.35 S 2,3 0.97 .% 0.37 :. .~ .0. 1.04 S 0.59 ~ 1.!) !.39 S 3.~0 5 1.65 1.33 3 1.O) E 2.13 2.~+0 S 0.'~8 E 2.59 S 22 ~ r_._ 3.00 S :3.54 E 3.j5 S 19 14 E 3.14 S 0.15 ~ 3.14 2.~4 S 0.60 ~ 3.00 S 11 3.16 S 0.Sa W 3.22 S 11 !8 w 3.66 S 0.70 w 3.72 S 4.25 S 0.~,~ ',~ 4.37 4.37 S 1.35 W 5.05 S 5.27 S !.39 W ~.50 S ~.92 S 2.23 W 5.~0 S 24 24 4.2'9 S 1.'91 ~i ,4.69 S 24 0 3.77 S 1.44 W 4.~4 $ 23 5~ 3.)0 S 3.77 W 3.97 S 11 1! 4.51 S 0.48 w 4..54 S ,,.~~o,. 5.11 'S' 0.20 '~ 5. !1 S 2 15~ 5.~6 S 0.17 ~ 5.*6 5 1 4~ 5.23 S 0.85 ~ 5.30 S ') 14 4.96 S 1.:53 E 5.!') S 17 10 3.1. ~ S 1.38 ~_ ~ 5.33 S 1:5 9 5.92 S 0,89 E 5.9'9 S '~ 32 ~.70 S 0.33 ;2 5.71 ~ 2 50 7.69 S 0.25 W 7.~9 S I 53 ~.29 S 0.80 w ~.33 S 5 31 ~,00 3 1.31 J '~.J9 S 8 1'3 '9.53 S 1.80 W 9,30 S 10 3~ 10,38 S 2.37 W 10.54 S 12 ~3 11.33 S 2,70 W 11.99 S 13 7 1;3.94 ~ 2.45 W 19.19 S 7 22 33.05 S 3.12 W 55.2t 5 ~ 22 W ( Il, ( ... ,:- ._ W COMPUTATION ~CO 4LASK4, INC. 2H-il KdP&RdK NORTH SLOPE,~L4SK& DfiTE: 17-DEC-B5 TRUE ME~SUREO VERTIC&L DEPTH DEPTH INTERPOL4TEO V~LUES :OR EVEN lO0 FeET OF 3934.14 3930.00 4038.57 4030.00 4143.46 4130.00 4249.64 ~230.00 4353.70 4330.00 4~70.91 ~430.00 4586.30 4530.00 4703.73 4630.00 4823.95 4730.00 4945.91 4830.00 SU~-SE4 CDURSE V=qTIS&L 2SSuEG VERTICAL DEV!4Ti]N &ZIMUTH S:CTION SEVERITY OSPTH D2G MIN D~G MiN :~iT D:G~IO0 5067.89 51~9.56 5311.70 5434.45 5557.~0 5681.75 5805.13 592'5.64 6042.12 6157.89 3800.00 15 36 S 22 17 W 53.01 5.03 3900.00 16 59 S 23 6 W 4000.00 18 37 S 25 4~ W 114.30 2.95 ~109.00 20 58 S ~200.00 25 30 S 29 0 W 193.33 2.27 ~300.00 28 ~3 S 24 41 W 244.13 ~.~ 4400.00 30 22 S 20 24 W 301.01 1.~3 4500.00 33 6 5 23 0 W 361.92 2.41 4500.00 34 17 4700.00 35 4 S 30 17 W 49~.I0 0.19 62 63 63 65 67 57 91 10 65 .17 .27 .40 .00 4930.00 4800.00 34 ~6 S 30 12 J 567.96 0.12 5030.00 4900.00 34 49 S 29 30 W 537.42 0.31 5130.00 5030.00 35 14 S 29 17 w 707.39 0.61 5230.~0 5100.00 35 38 $ 2'~ 41 W 77~.58 0.63 5330.00 5200.00 3,5 4 S 27 33 W 353.39 0.70 5430.00 5300.00 36 8 S 26 37 ~J 923.85 0.53 5530.00 5400.00 35 ~3 $ 26 10 W 9~5.97 5630.00 5500.00 31 32 S 2~ 54 N 1063.05 Z.99 5730.00 3690.00 30 34 S 2~ 41 '~ 1122.77 0.60 5830.00 5700.00 30 14 S 25 gO ~ 1181.0~ 0.77 3930.00 5800.00 31 17 S 31 5 W 1240.42 2.27 6030.00 5900.00 32 3 S 33 7 W 1302.39 1.47 6130.00 5000.00 32 43 ~ 36 0 W 13,55.44 0.5'3 5230.00 6100.00 33 9 S 36 12 W 1429.32 6330.00 5200.00 33 9 S 36 12 W 1494.77 6343.33 6213.53 33 9 S 36 12 W i.503.55 0.30 PAgE 5 7.,AT= CF SJ?VaY: 25 '43v' :25 K=LLY ~USHiNG -L~-V,~TiCN: 13"J.,]O =T SU3-S:A D-°TM 55.i5 S ~2.B7 S 111.73 1~3.~2 S 13!.~9 S 226.49 S 2~0.03 S ,_ 337.15 S 397.93 S ~5~.~5 S 51 ?. i '9 3 37 9. 30 S SoO. i'~. S 70 ''~ .44 S 7 65.21 ii ~31.31 S 8'9,$ · 0 ,~ S 935.7~ S 1007.'g5 ,S 105'~.27 S 1110.9~ S 1162.93 S 1214.27 $ 1256.57 S 1319.27 S 1326.40 S 10.5~ N 55.15 S 10 49 W 22.!4 W ~,5.;~0 S 15 ! J . 72.4D W !q5.40 S 2i 4~' 3).-)5 ,~ 355.37 { 22 32 J 67.57 'J ~31.7~ S 22 50 J 01.50 W =0!.!'9 S 23 43 N 35.~0 W 570.$4 71.52 W '539.32 05.12. W 74.83 W ~52.93 40.07 99.93 W i125.11 27.56 ~ Ii~3.42 55.77 W 1£42.5~ 90.72 W 27.~9 W 13,57.00 6,5.04 N 1'43!.02 0~.63 W 14~'5.65 09.35 AqCO 4L4$KA, INC. 2H-11 KJP~RUK NDRTH SLDPE,AL&SK~ MARKER TOP KUP&RUK C BASE KUPARUK C TOP KUmARUK 4 BASE KUPARUK A PBTD TO COMPUT4TIg~ INTERP$L~T:D VALUES FOR qEASUREO D~PTH 5ELOW KB 6400.00 $409.00 6436.00 6604.00 6555.00 5765.00 D&TE: 17-DEC-~5 'HOSCN_ HJRI?SNS~ 6036.$~ 604~.51 620~.74 6343.53 ~IGIW: TVO 170 ' SUB-S~& 5906.8? 5914.51 5937.38 5078.7~ 6121.~3 ~213.53 3LTr. D.z StJeV.:_v: 23 N3V S'3 K:LLY 3US-~!NG :L£V~T'3N: !33.02 =T FNL, 65~' F SJR~~,: zDCAT!']N ~T EL, SEC 35, TI1N, R~F_,JM q r_' C T ',1 !'~ uq tJ L ;.!, q CSORSINAT.:_S N,]R T.~/S3UTW 'ZaST/WEST 1165.~,5 '3 5~3.20 ~.~ 125~.36 S 557.~3 1°77 ~ · _, , t _, !'~26.40 S 709.35 w 4~C0 ALASKA, INC. 2H-11 K~PARUK N2RTH SLOPE,ALaSKA M~qKER TOP KUPARUK S SASE KUPARUK C TOp KUPARUK a B~SE KU°ARUK a PBTD TD COMPUT~TIAN DATE: ~AS'JRED DSPTH 5400.30 5~35.00 550~.00 5555.03 6?55.00 17-nFC-85 FT CRIGIN: 17:0' ~NL, TVD 5036.38 6044.51 5~14.51 6067.38 593'F.3S 6Z3,3.74 5075.7~ 5251.43 5121.43 5343.53 6213.53 55~+' F REC ~.~ 3 JR L, SiC ~5, T!IN, SOLAR /SA:JT4 llb6.4g S 1255.36 S 1277.57 S 13Z6.~ $ C3,3R3INAT':S ':~$T/.'~ST FINL~L MEASJRE3 DEPTH 6765.00 WELL L]CATZJN TRUE VERTICAL 63~3.53 ~T TO: SO~-SEa V~RTICAL DEPTH 5213.53 HOR'IZONTAL DISTANCE 1504.40 AZIMUTH DE3 UlN S 28 9 (, SCHLUhlBEROER D I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL 2H-1 1 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 0000?5086 WELL NA~E: 2H- 11 '~--~ SIJRFACE LOCATION: "~'[7c- FNL, 654' FEL, S35, TllN, R8E,, . -,~,....~ VERTICAL PROJECTION - 1000 -~00 0 0 SOO 1000 SOO 2000 2~00 30. 210. PROJECTION ON VERTICAL PLANE 210. - 90. SCALEO IN vERTICAL DEPTHS HORIZ SCIqLE = I/S00 IN/FT WELL NAME: 2H- 11 SURFACE LOCATION: 1~1~' '-'L 654' FEL S35 TiiN R8E If ~ORTH ! SOO 1000 soo REF --~.-.;-.-~...~ ...... ~---~---+4 '-'i--'!'..f--f--I.-.~-.?~--~-- '-!"TT'TTT"?"!'"} :::::::::::::::::::::::::::::::::::: 00007 ! 088 ::::::::::::::::::::::: -'f---f--~'"!"'."-::'"?'?i'" ...Li...L.i..J...LL;...L -+--i--F.!-.-!---F.F-i---::-- --.~--.F.-+.--~--.I---?"---~-~---~--- ?'-~-?---?--t---?-"?-'?'--?'" .... ~...~...g...~...L--x...}...~...g-.. ~...~-.L.;-I.-.L..;-..L..~. ;...L.L.L.J.--i..-L..~.-.L. ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: -SOO ::::::::::::::::::::::::::::::::::::::: :. ;-.-~--.i---!---i---!--.i--.i--- ! ~ ~ ; I : . ! ~ ~ ~ ~ : I ~ ' : ~ : ~ ~ ~ i : ~ ~ : ::::::::::::::::::::::::::::::::::::::: - 1000 .... ! ~--,+-.+.++-~ i i---+..--i---k-+---~-.!. 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' ....... i~ ~ i;; . ;-.-;.--~---k+ ~; ~ ~: ...... ~'"~"~'"+"'~'-f"'~ .; ~ z _: ; L L.L..z. : .......;...L..L.~ .~:~t~:; i : ~'* .... ' ......... ~ ........................................ ; ---??---t--*-?--~---~.---?-;---?--:--~-: :---= ~ ::::::::::::::::::::::::: i..~..L.~ ~ . . : , . . ~-: : : . . : -BOO 0 500 E~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · . 0P~ATbR, WELL NAME ~D ~U~ER - and Materials to be received by: !~- 1~--~'~ Reports D&te- L Required Da~:'e Received ~emarks Completion Report Samples ,., .~ ~ud Log .. ~ ~,~f ..... d/< Core Chips Registered Survey Piat.~ Inclination Survey ~ .... . Directto~~ Drill Stem Tes~ Reports Production Test Reports L,FJ: ' ARCO Alaska, Inc, Post Office '~_.~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-11 Dear Mr. Chatterton: Enclosed is a copy of the 2H-11 Well History (completion details) to include with the Well Completion Report, dated 1/27/86. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L83 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office b,,,-x~"i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2H-11 Dear Mr. Chatterton' Enclosed are the 2H-11 Well Completion Report and gyroscopic survey. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L30 Enclosures 'i ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office I~..~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-31-85 TRANSMITTAL # 5497 Transmitted herewith are the following items. Please acknoWledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each 2H-10~ 5" DIL/SFL-GR ~ 2" DIL/SFL-GR % 5" DEN/NEU % 2" DEN/NEU \5" DEN/NEU ~2" DEN/NEU ~Cyberlook 2H-11 ~5" DIL/SFL-GR (poro) (poro) (raw) (raw) ~2" DIL/SFL-GR %5" DEN/NEU-GR (poro) ~2" DEN/NEU-GR (poro) %" DEN/NEU-GR (raw) EN/NEU-GR (raw) yberlook (poro) (poro) (raw) (raw) (poro) (poro) (raw) (raw) 3A-11 ~" BIL/SFL-GR \2" UIL/SFL-GR ~5" DEN/NEU '2" ~EN/NEU ~5" ~EN/NEU ~2" DEN/NEU \Cyberlook 3A-i2~5'' DIL/SFL ~2" DIL/SFL ~5" DEN/NEU ~2" DEN/NEU 5" DEN/NEU ~ 2" DEN/NEU '--,Cyberlook 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-16-85 Run 01 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run 01 11-16-85 Run 01 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run 01 11-16-85 Run 01 11-16-85 Run 01 11-16-85 Run Mi 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-23-85 Run 01 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-2~-85 Run 01 2856-7960 2856-7960 2856-7934 2856-7934 2856-7934 2856-7934 7500-7900 2744-6752 2744-6752 2744-6727 2744-6727 2744-6727 2744-6727 6190-6705 3208-7330 3208-7330 6600-7303 6600-7303 6600-7303 6600-7303 6600-7250 3797-8006 3797-8006 7200-7981 7200-7981 7200-7981 7200-7981 7300-7700 las,Va Oil & ~as Cons. Commission Receipt Acknowledged: State of Ak*bl/se Rathmell*bl Drilling*bi D&M*bl NSK Clerk*bl Vault*films Date: ARCO Alaska, Inc. Post Office =~,..,~'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-11 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 2H-11. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L158 RECEIVED 0il & Gas Cons. Commission _, Anchorage Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI~_....~ AND GAS CONSERVATION ~~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. 85-261 3. Address 8. APl Number C~-J '~' D~:~ ~" 103-20052 P. O. Box 100360, Anchorage, AK 99510-0360 ~' ~ ?~ r 50- 4. Location of well at surface f'~ ~ ~ ~' 9. Unit or Lease Name 170' FNL, 654' FEL, Sec.35, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval ~i ?"~ !-"~! © '!~ ??~i~ 10. Well Number To be submitted when gyro is received. 2H-11 At Total Depth Alaska 0il & Gas O0~]s~ 00illrnissi0r ~1. Field and Pool To be submitted when gyro is received. Anchorage Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Pool 130' RKB ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 16. No. of Completions 11/10/85 11/15/85 11/17/85* N/A feet MSLJ 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 6765 'MD 6655 'MD YES ~X NO [] 1775 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET/Gauge ring 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER F-T. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112' 24" Conductor report not y~,t received. 9-5/8" 36.0# J-55 Surf 27b, 3' 12-1/4" 620 sx CS Ill & 300 sx CS II 7" 26.0# J-55 Surf 6746' 8-1/2" 400 sx Class G & 175 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) 6513' - 6536' w/4 spf, 90° phasing 2-7/8" 6450' 6247' & 6433' 6400' - 6409' w/12 spf, 120~ phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED,,k. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Tubing was run and well perforated 12/15/85. TEMP3/WC31 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "" GEOLO:GIC MARKERS ' ! :: ' ! '- *~'' Y: ~' "" : .::' ' ;'~ "' 't'-*' -"FoR'MATi'ON:TES'T$--'~', --.~. : .~: .., , ..- NAME Include interval tested, pressure data, all fluids recovered and graviiy, ' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wh,~n gyro is recei/ed. N/A 31. LIST OF ATTACHMENTS Well History (including Addendum dated 12/11/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /,~ ~ Associate Engineer Signed ~ ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached.supplemental records for this well should show the details of any multiple stage cement- 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 Well History - Initial Report - Daily Inslm{=l~na: Prepare and submit the "Initial RaiN, ri" 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 AK0065 ICounty. parish or borough North Slope Borough Lease or Unit 25587 JTItle Drill IState Alaska IWell no. 2H-11 Nabors 26E AP1 50-103-20052 Operator IARCO W.I- ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IOat, IHour IPrior status if a W.O. Spudded 11/10/85 2245 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 11/lO/85 thru 11/12/85 11/13/85 11/t4/85 11/15/85 9-5/8" @ 2743' 2760', (2654'), Top job Wt. 9.1, PV 18, YP 12 Accept ri~ @ 1645 hfs, 11/10/85. NU diverter sys. Spud well @ 2245 hrs, 11/10/85. Drl 12¼" hole to 2760', 14 std short trip, CBU, POOH. RU & rn 69 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 2741', FC @ 2662'. Cmt w/620 sx CS III w/10#/sx Gilsonite, followed by 300 sx CS II. Displ using rig pmps. CIP @ 0245 hfs, 11/12/85. ND diverter sys. Perform 125 sx CS II top job. 9-5/8" @ 2741' 4200', (1440'), Navi-Drl Wt. 9.0, PV 9, YP 8, PH 10, WL 11.6, Sol 4 NU & tst BOPE. RIH, drl FC, cmt, FS + 10' new hole. Conduct formation tst to 12.7 ppg EMW. Navi-Drl to 3600' KOP, drl & build angle to 4200'. 455', .3°, S60.2W, 455 TVD, 1.0 VS, .68, 1.0W 1453', .2°, 838.2W, 1453 TVD, 4.9 VS, 2.6S, 5.2W 2461', .3°, S89.8E, 2461TVD, 3.7 VS, 4.48, .1E 3088', .6°, S54.2W, 3087.9 TVD, 6.2 VS, 8.0S, 1.3E 3944', 16.4°, 822.2E, 3938.9 TVD, 52.7 VS, 63.1S, 3.9E 9-5/8" @ 2741' 5950', (1750'), Navi-Drl Wt. 10.2, PV 14, YP 9, PH 9.5, WL 9.4, Sol 10 Navi-Drl & surv 8½" hole to 5950'. 3944', 16.4°, S22.2W, 3938.9 TVD, 61.8 VS, 63.3S, 14.0W 4699', 33.5°, S24.2W, 4621.8 TVD, 373.3 VS, 347.5S, 144.9W 5736', 36.2°, S26.2W, 5467.0 TVD, 973.7 VS, 874.3S, 433.3W 9-5/8" @ 2741' 6620', (670'), Drlg Wt. 10.8, PV 18, YP 11, PH 9, WL 5.8, Sol 14 Navi-Drl to 6137', rotary drl to 6620'. 6052', 30.9°, S28.2W, 5730.3 TVD, 1148.1VS, 1029.5S, 513.1W RECEIVED Naska Oil & Gas Coils. Commission Anchorage The above is correCt Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 1~..15-,~ ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inatructions: 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. I Accounting District I County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25587 Auth. or W.O. no. ~Title AFE AK0065 I Drill cost center code Alaska Well no. 2H-11 Nabors 26E Operator ARCO Alaska, Inc. Spudded or W.O. begun A.R.Co. Date Spudded Date and depth as of 8:00 a.m. 11/16/85 thru lt/18/85 Complete record for each day reported API 50-103-20052 W.i. rrotal numbe~' of wells (active or inactive) on this 56 24% Icost center prior to plugging and I · labandonment of this well IHour I Prior status if a W.O. 11/10/85 ! 2245 hrs. I 7" @ 6746' 6655' PBTD, 6765' TD, RR 10.9 ppg NaC1/NaBr Drl to 6765', make wiper trip, cond mud to 10.9 ppg, POH. RU Schl, rn DIL/GR/SP/SFL f/6760'-4250' & 3400'-2750', FDC/CNL f/6760'-4250' & 3400'-2750', CAL f/6760'-5300', RD Schl. TIH to 6487'-precautionary rm to 6765', circ, POH, LD DP. RU & rn 155 jts, 7", 26#, J-55 BTC csg & lnd w/FS @ 6746'. Lost all rtns while rn'g csg. Attempt to circ, no measurable rtns. Cmt w/150 sx C1 "G" w/3% KC1, 2.5% D-19, 1% D-31, .25% R-5 & .2% D-6, followed by 250 sx C1 "G" w/l% D-19, .5% D-31 & .3% A-2. Displ w/brine, bump plug. CIP @ 2300 hrs, 11/16/85. ND BOPE. Set pack-of NU tbg spool & lower tree. Tst pack-off to 3000 psi. Arctic Pak w/175 sx CS I. Secure well & RR @ 0800 hrs, 11/17/85. Alaska Oil & Gas Cons. Commission Anchorage Old TO J New TD PB Depth I 6765' TD 6655' PBTD Released rig ~ Date Kind of rig 0800 hrs. J 11/17/85 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I Kuparuk Sands Potential test dala Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 11/19/85 12/02/85 2H-11 Arctic Pak well w/175 sx CS I. Log GR/CCL/CET/gage ring f/6648'-4900'. f/6648'-surf. Rn GCT gyro C V ~D Drilling fSuperintendent Date ARCO Alaska, Inc. Post Office BGr ,}0360 Anchorage, Alas~'~a 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, ~ Gruber Associate Engineer JG/tw GRU12/L129 Enclosures R£C£1VED )EC' 1 31985 ~,laska Oil ~ Gas Cons. Cornrniss[orl Anchorago . - ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany. .. STATE OF ALASKA ALASKA C¥._~AN D GAS CONSERVATION COI~_~tlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellY~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-261 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-103-20052 4. Location of Well atsurface 170' FNL, 654' FEL, $ec.35, T11N, R8E, UN 5. Elevation in feet (indicate KB, DF, etc.) 130~ RKB 6. Lease Designation and Serial No. ADL 25587 ALK 2673 For the Month of November ,19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2H-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2245 hfs, 11/10/85. Drld 12-1/4" hole to 2760'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 6765'TD (11/15/85). Ran logs. Ran, cmtd, & tstd 7" csg. Arctic packed well. PBTD = 6655'. Secured well & RR @ 0800 hrs, 11/17/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 112'. Conductor report not yet received. 9-5/8", $6.0#/ft, J-55, BTC csg w/shoe @ 2743'. Cmtd w/620 sx CS Ill & 300 sx CS II. 7" 26.0#/ft J-55, BTC csg w/shoe ~ 6746' Cmtd w/400 sx Class G & 175 sx CS ! 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/6760' - 4250' & 3400' - 2750' FDC/CNL f/6760' - 4250' & 3400' - 2750' Cal f/6760' - 5300' 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED Alaska Oit & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¢/4~ ~~J~-., TITLE Associate Engineer DATE 12'/.~-~' SIGNED NOTE--Report~n 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 TEMP2/NR76 Submit in duplicate ARCO Alaska, Inc. Post Office "~'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2H Pad Wells 9-12 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. ~ruber Associate Engineer JG/tw GRU12/L65 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · . ' :_:: -~; z < :' . _ . . - . 7" . . · ......-=~ - .. -.., "~'~'",',' :'~','"~:~'~'~- ":-:': '. .... ~: ~ I '~':~- ' -:--'.~'-~?~'~--- y~-=~,g48,693-.X~%.--,~T.-'.-:~ 70 16 I5.7924-. -:,~ .... ~' '~ _. '- :- -:.' ........ : .... :-,- --:----:.-~.-:_ X:~_:,-~-497,864 90~--:--_ LONG _-15Q 1. 2.163 :?.2":'-.-;.-:'--' .~'C. 2 _11 ~' " = " "'OI4"~bq:- ~ ': ::; -~--~ ..... ~:~- '-- .... _ ¢ ?-:Z:-- : --' '. ;':.:,:/.~:.;..~..L:__:;'~:~'..'~-.~? j?: .... : '~. ~ _ _ ~-7~:- __::- (--~-:_:.::7 --~70' F~:;T'=53~'~;Y.-4 ~;7~-9~.8,0G-~. 90;6? ,- ~... ::;~: :..:-:-... · .... - '....-..~'-:' v ~ ' . ~" : . ,~' = ' -:: ~ ..... - "-- '. ' ' -Z~:'Y~: ~.- ' ~-~--~: "' :~? 0 ~- ' ':-~;~ ?';' ::: ,: /.' ,~_ :.: .:',-(~-;F,.:,'...;> _.-' , _.-_:~:,:~::,:,.~:~ ,-:; .: -:~??::: ;_ ~_ X:=?:,?-,~_~:;.~. ~2.~:-~--,(: LO~G,-: 150 i~.~_.~5-, ':~'~,:' :.. ;.'--.- ',,- . '~._;.L~.-.2~'::. ~ ~ ~ ,-~:~:,;~:., '--: ':'-;: ;,:T'?:-c:~ ~ 170'FN~?"654'FE~>~:m EL:--9~ 8;OG --, 90 .,'~-:-..'/- :~'_;::~-~'. '-~ ..... I '%' ":-: ;-~'~.'~,' .'. ~ ~--~ : - -: ' :::~- - :-:-'?- I ..... ~-- ~ ;-. ~,L--i~': :. ~ ,. ~: ...... ~--:'-,- ..' ; :../.~:X~':.? (,r:::.,~..:'-.,: ..;~.- 8 O;. -;- ~ ~ .:: ~_1, :?..:;:¥... '.V:-::: :;:9 ~--' .~ELL-i2':~;-~:::-';:';:7-/~';~--"f'% %(:-?.~ :: ;:- .--.:.' ..... .~ -..__ :... ~ O.~_ -. . . O : .... -. -. :~-_~:-.;~---.-~: 170-. FNL,-. 714_ FEL._:_::-:.-EL:,~,9 .9,OG .... 90,.a. ~. . '.-: ;~.:-" ,,"_. ~:-~¢:" :::-/::;?i:': ~" I '. ¥c'.~::-:i~:::q~ /2:--¥¥% :-? - -~/'--:::':": 7~:??~:'¥'~L/- '--- ~--.,':,: ':--; ,?-,:~ ::~:':~ .-' ~_::~;./'? ' .". - -: '-;-" :' ~ :.. ~.~:. y~ ~.. &'.~g~'~:.- ';-'. Jf ::<;::.:.(;~%:(- ~ff4;'~:.:-4.-~:-::i '~:~2:~>~-Z':~a,;;tCZ-;4;~_;:~%~ ¢~-CLv-~: .~¢~-.':-;,-Z~;:_~; "?i?~~ --~,' "::,-;:'r':'-:;':-:"- ' :& ~ ;'.2Z;2~.F'¥~::' 7:' : , I ',_?-?.~:;~?.~';;:: .~'~?;?.~?~? - .......... . "- . _ ' ........... .:-":: ".¥-- ~. ::::.:. :.-.'::': :.-.:'."-~--? ? ' -b_- '/: :4' - :: --:.-' Anchoraoe ....... :---":'-:~:-':'¥':"'-' :' '----"----'~":': ': :.'-~.::--. '-' ..:-;~ THIS SURV~Y.~:-'.-.;7. l" .-;[- / - I' ; -' X L,k=NS~D 'TO ~RACTtC~--I:AND SURVEYING IN THE sTATE OF. ~*~ .- .- .' . -:___. -~ _ _..~ _ :. -: · .-: -_ -_ ~ .. :~. _. _ - .' -- ..- _ _. AkASKA E~-THAT THIS PLAT.REFRESENTS A SURVEY' MADE_--'_ :- .-uNDE~:'¥y'DtRL"ZC-i: S-i~pE:~,'S,°i~i:- 8~..THAT:':AL[LV~EyAIL:S ARE.;' CORRECT A'S O~-:[":"'.'::'._~;:~:-~::::::..i~,i'.': ::-::-~:--':-:'~'~-~-~j~--:-'"" '-'. -' ::-~':'i'/':~':.' :- ~. ---', ~t~...~ ::':--,;...:::.-.:.:- ARCO'Aleska, I nc.--~. '..: .-', .. ;.'- .:::.: DRILL SiTE" '2_. H T::'-!~' '"KL; :';%," ~c;ec° ::'"':-._:,-:: North.' SLOpe Drillin~ / ~*~ ~-- ':-:-'-': :: .... --:.': LOC AT I 0 N S :- -!..'. .. "~SSO&" D:te:OctoberlS;19$5 Scole: 3r:3~ghtsmon: MC Dwg. no. : N SK 85-28 _. .' i :7'. ¥:.' 'q ~(~.'~ ........ : , .':.:;u 7.' o ::'::'-' s 0'.: : ': : 0 4:.::':/. ,'.~-:':.-..: >:':.L'~ :' .. :'~:: .~ . :! October 30, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2H-11 ARCO Alaska, Inc. Permit No. 85-261 Sur. Loc. 17Q'FNL, 654'FEL, Sec. 35, T!IN, R8E, UM. Btmhole Loc. 1461'FNL, 1402'FEL, Sec. 35, TI1N, R8E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V93~ tr~l~yours, / C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COb~ISSION be 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. Post Office B6"x"100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-11 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2H-11, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot 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 November 10, 1985. any questions, please call me at 263-4970. Si ncerely, Regional Drilling Engineer JBK/lt PD/L97 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OrE AND GAS CONSERVATION COt~vllSSION IIERMIT TO DRILL 20 AAC 25.005 SERVICE [] STRATI ~ R/~P-I::I lC SINGLE Z ~t~, E SUET PLE ~E 9. Unit or lease name la. Type of work. DRILL I~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 170' FNL, 654' FEL, Sec.35, T11N, RSE, UN At top of proposed producing interval 1277' FNL, 1295' FEE, Sec. 35, T11N, R8E, UN At total depth 1461' FNL, 1402' FEL, Sec.35, TllN, R8E, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 130', PAD 95' 6. Lease designation and serial no. ADL 25587 ALK 2673 Federal Insurance ComPany Kuparuk River Unit -. 10. Well number 2H-11 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2H-12well 60' ~ Surface feet 16. Proposed depth (MD & TVD) 6779' MD, 6349' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3600feet. 14. Distance to nearest property or lease line miles 170' ~ Surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 35°1 (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date November 10, 1985 ?,124 ?,B9! psig@ 80°F Surface psig@ 6005 ft. TD (TVD) SIZE . Hole Casing 124" 16" [ 12-1/4" 9-5/8" .8-1/2" 7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade CouplingI Length H-40 Weld I J-55 BTC I 2704' HF-ERW J-55 BTC~ 6744' HF-ERW SETTING DEPTH MD TOP TVD 80' 36' I 36' 36' I 36' I I 35 ' I 35 ' MD BOTTOM TVD 116' Ii 116' 2740' 12740' I QUANTITY OF CEMENT (include stage data) ±200 cf 620 SX CS III + 300 sx Class G 6779' 16349' 300 sx Class G I I ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6779' MD (6349' TV•}. Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 3124 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2H-11 will be 60' away from 2H-12 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cert/i,f,y-~at the foregoing is true and correct to the best of my knowledge SIGNED TITLE Regional Drilling Engineer The space ~J~fw for ~or~mi~ion u~se RATE CONDITIONS OF APPROVAL Samples required Mud log required []YES [~]-N O []YES 15~-NO Permit number Approval date - 2 _ z. o12ol85 Form lOgO1 ~) PDZPD(~i/-- /- - Directional Survey required I APl number [;~¥ES •NO [ 50--] 0-3 --')-OO-,~'2 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 30, I 985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2H-11 Upon completfon of the disposal process~ the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location~ this well will be fracture stimulated. RECEIVED Alasl<a Oil & 6as Cc, ns. Anc?iOF~q9 ];':-' .:_.-::L:PAD. 2H, LWELL: N0, :T1;:::; REV ISED~PROPOSAL: .: : · ~ , ........ ~ ..... ........... ~ .... ¢ ........... ; .........~ ................... / .: ...... ; .................... ~ASE -PERMAFROST ..... -~ T Op-UON U- SN DS~:--T-VD=1550 ........... TOP -~ SAK-SNDS--TVD'21 -- ~p. _--:TVD=-3600.':~=-3600~E~__~0 . ' ~ ' - -2~--K-5 ~ TVD=4460' ~T~D=4492'-DEP=205-::-:/~- :::: ::::- : - :: - :: ::~:-: - .:_-::: -_.. ....... : ................. ~ ..... !~--~ ........ ~ ..... ~ ....... ~ ...... ¢ ...... : ........ ? - .... :- : ....... : -': 2:::~ : _ ~._~: -:~5-~T~rO~~D~O~__T-~~BO__.~E~=__1 2~::::S: '-.::::': :.:: -~ - ~ ....... ~ ................ ;-: ......... ~-~--:~-t.-T/ ~ZONE-~ -TVD 6042-T~D' 6405 DEP 1279 -: ...... .... ; ........ ~ ......................... ~ ...... BASE--KUP- SNDS .... ~VD=61 85-T~D=6579 -DEP=1378 -- - ' "iD ~~)~~-~ 49-~i6~ 9:D~-~ ]:492:: - ~ ] ~ ~ ................... .... ........................... - . . ~ , __ :~ --T ~ .... ........ ~ ........ ~ ............... ...... t ........ 4 .............. ~ ~ ......... + ..... ~ ~ .............. . -- ~ 00~---~--:'-~_~-~---~-~ ~_-.: ~:" ..... ~-~-~-.~--~-~: - ............. : ............... ~ .......... _ .... ..... ; ........ ~ ....... 4.7 ..... ~ ................ : . _ _ ~ ....... ~ ................. ; .......... ...... ...... ~ ........~ ........ ~ ...... [ ..... · ........ ........ ~ ..... - .. _ ~ ~ .... ~ ........ _ ..... : ..... . . . _ ~ .. - i "C:: .-'l SCALE' I iN'.' ~i. lOOI~ .FEtf .... ! 'i"?':-~/'-?T!'-!' TiT 4. : , .... ,. ................. ............ ...... ...... _~_._~_.~ ..... n--~.~ ......... ,..~_~ _ PAD' 2H. WELL N0t'11: ~REV[SED'PROPOS/ KUPARUK FIELD, NORTH~ SL. OPE.~ EASTMAN ~HJPSTOCK., , [~C.~ , ':, ':-:".'";:. :, ,.' ,~ '~--'-:[ .... . ' · ." ~..~.::,, ~' ' ~ ' '~:' "": ~ ...... ~ ........... :"T' ~'"'-'~ ..... : :"': ..... :"-:"-:"-~ ....... :' .... ~ ........... ~000 ~ 2000' , ~ ...... ~ ~ , g:....; ............ '. .................. L._F_ ~..a_;_.~...;_.,_~...~ ..... -~ ........ I- l SURFACE 'LO~ATION,. 'lro' FNL. 654' FEL~ .... ,""'," T'""~ ........... ~ -" t' "T'"t"'-~ ..... ~ *' ~~ ~ .................. 2000 _ TD LOCAT I. ON ' ~, I ~61' ,FNL. 14.02' F£L 3000 i.'SEC"~35' Ti~N.,R ~ ........... · ....... .~.. ,..,! ; .... . ........ J. KUPARUK VER T 20" .DJ: VEF~TER SCHEMAT I C 6 DE S CR I PT I ON t. 16' C~CTO~. 2. TANi,(O STARTER HEAD. 3. TABOO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TAha<O UPPER QUI CK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/!0" OUTLETS. ?. I0" NCR BALL VALVES Vl/lO" DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AI~NL~AR PREVENTER. 8. 20" 2000 PSI Aha'AJLAR Pi::~EVENTERo MA]~ NTENANCE & OPERAT.]: ON 4 I. UP'-C~ INITIAL INSTALLATIOf~ CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY, 2. CLOSE ANtgJLAR PREVENTER AND BLOW AIR THROUGH DIVERTER LIKES EVERY 12 HOURS. 5, CLOSE ANINULAR PREVENTER IN THE EVEN'F 'THAT AN ih~LUX ~ W~LL~ --FLUIDS OR GAS IS DETECTED. IF -- .. NECESSARY, MAhAJALLY OVERRIDE AbED -.CLOSE - APPROPR ! ATE VALVE TO ACHIEVE DO~IND DIVERSION. DO NOT SHUT IN '¢~LL UNDER ANY CIRCUMSTANCES. i '] 7 6 5 4 3 2 ACC..MJ!_ATOR CAPACITY TEST 1. C.-E~ AND FILL ACC~TOR F~OiR TO F~ LEVEL WITH HYDRA~IC FLUID. 2, ASgJRE THAT AC~T~ P~E~ IS 3000 PSI WlT~ 3. CELSE~VE TI~E, TI,-F_N ,¢_~_rCE;E__ ALL UNITS SI~I_TAhECUSLY ALL UNITS AF~ Q_OSE~ WITH ~F~3INO ~ ~. 4. REC::O:~ ON ~ REPCRT, T]-E ACCEPTABLE L~ LIMIT IS 45 SE~ CLOSiNI3 TIIVE ~ 1200 PSI REMAINI~ BOP STACK TEST t. FILL BCP STAO( AND CHOKE MANIFOLD WITH ARCTIC DI F_.S~_. 2. CEO( TN, AT ALL LCX:X ~ ~ IN ~~ ~Y ~RA~. ~T ~T ~ IN 3. ~ ~ ~ ~~~ Ki~ ~ LI~ V~VES ~~ TO B~ STA~ ~ 4. ~~ ~ TO ~ ~I ~ ~ F~ t0 MIN. ~ ~~ TO 3~ PSI ~ ~ F~ I0 MIN. BL~ ~~ TO 0 ~I. LZ~ VALVES. ~ T~ PIPE ~ ~ ~ V~VES ~ KZLL ~ ~E 6. TEST TO 2~ PSI ~ 3~ PSI AS IN ST~ 4. ?. ~I~ TESTi~ ALL V~VES, LI~S, ~ Wi~ A ~ PS! L~ ~ 3~ PSI HI~. TEST AS IN F~i~ TEST ~S ~T ~ ~T ~LY ~E. TEST B~ PIPE R~ TO ~ ~I ~ ~ ~I. 9. ~ ~~ PIPE ~, BA~ ~ ~I~ ~ 10. ~ ~I~ ~ ~ TEST TO 2~ ~I ~ PSI. ' ~uzD. ~ ~l V~LVES ZN ~LL~ P~T~. 3~ PSI. 13. RE~ TEST !~~TI~ ~ ~~ P~ TEST F~, SI~, ~ S~ TO ~I~I~ 14. P~~ ~~E B~E ~ST ~ NI~I~ ~ ~,Y ~R~~ ~!~LY ~~ B~ DALLY. 51oo84oo~ REv.~ . 6 i 5 -1 > '-.-.- DIAGRAM #l 5000 PSI RSRRA BOP STACK I. 16' - 2000 PSI TAN<CO STARTING 2. Ii' - 3030 PS! CASIN~ FF_AD 3. I1' - ~ ~Z X 1~8' - 4. 1~8' - ~ ~I PI~ 5. 1~8' - ~ ~I ~l~I~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ W~I~ 7. i~8' - ~ ~I ACQ, M.LATOR CAPACITY TEST !..C~CK ~ FILL ACO~TOR I~OIR TO P~ LEVEL WITH ~IC ~UID. ~ ~ ~T A~T~ ~ IS ~ ~I WI~ 4. ~~ ~ ~ ~~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ T~ ~ I~ ~I ~I~ 4 3 2 . , ). . 9. .10. il. 13-5/8" BOP STACK TEST I. FILL BO= STACK AN3 Q-E3<E MANIFCLD WITH ARCTIC DIESEL. 2_ Q-ECK THAT ALL LOCK DO~ SCREY~ IN ~ ARE FULLY RETRA~. $F. AT TEST PLUG IN WITH RLt~IN~ J'r ~ ~ IN L(:XD<D3AN SCRENS. LIhE VALVES ADJACENT-TO BOD STAO<. ALL 4. ~ UP TO 250 PSI AND i-K:]LD FOR lO MIN. IN- ~ PEE~ TO 3030 PSI AND HOD FIR I0 MIN. BLEED PRE~ TO 0 PSI. LIllE VALVES. CLOSE TCP PIPE RAMS AhD ~ 'VALVES aN KILL AhD Q-~KE LIt~,S. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CCNTINJE TESTING ALL VALVES, LI~-S, AND CHCKES WITH A 2.50 PSI LOH AAD 3000 PS! HI(~-I. TEST AS IN NOT A F'1JL_L CLOSING POSITIVE SEAL O-K:KE, CN.Y P-'UNCIICI~ TE57 O-E:KES THAI DO NDT FLLLY CLOSE. TEST BOTTOa PIPE ~ TO 250 PSI AJ~ 3000 PSI. CLOSE BLIND RANS AND TEST TO 250 PSI AN3 3000 · '~NIFO.D A~ LZ~S A~ ~ CF FLUID. SET ALL VALVES IN DRILLING POSITICI~L 12_ TEST STANDPIPE VALVES, KE31Yo k'm~Y COCKS, DRILL Pipe ~ vALvE. AND INSIC~ SC~ TO Z.,O PSI 3COO PSI. 13. REO:RD TEST IN=(:RI~TIaN aN BLONOUT PREYFArFER TEST FDRMo SIGN, AND SEND TO DRILLING SLPERVISCR. 14, PERFCI~ ~ BCPE TEST AFTER NIPPLING Lt= AND NSEKLY THEREAFTER ~IO~4.LY CPERATE BO=5 DAILY, ~ I O06400 i REV. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~'""~..,--- :,. (2) Loc ~2 thru (8) . ~ ¥-'~,~- (3) Admin ~' ,~"~ / .... ':-~ -~ 9. (10 and 12) 12. (13 thru 21) Company Lease & Well No. YES NO , , 13. .14. 15. 16. 17. 18. 19. 20. 21. 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ......................... 3. Is well located proper distance from property line ........ 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage available in this pool ........ 6. Is well to be deviated and is wellbore plat included ............ 7. Is operator the only affected party ............................. 8. Can permit be approved before ten-day wait ...................... Does operator have a bond in force .............................. Is a conservation order needed .............. Is administrative approval needed ............................... Is the lease number appropriate ................................. Is conductor string provided .................................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons ...... , ........... Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ eeel~ ieee ieee 22. 23. 24. 25. 26. Is a dtverter system required ...... ~ ................................ ~ Are necessary diagrams of diverter and BOP equipment attached ..... ~ Does BOPE have sufficient pressure rating - Test to ~ pslg i i/A~r Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. 27. Additional requirements ............................................. Additional Remarks: o ~o Geology:;. Engineering: HWK~ LCS ~- BEW WVA~ MTM~-. HJH rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~'(~ ,.~ I o. o ~:~' ,~..,,: / '* I"..2' .... ,,, , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. ********************** L~"~ ~ ! ! I m i ! i ]:-i I_~ [:-] 'i] DA?lC lbD,~"t ',HO lV~tRD ~01gA'lll F'OnHAT i.. DZI, RHO~ PDN ~,,ll~I-.i°~ "PDN 6' 0 B: tl!'HI Ol :PT* "~ ~ ~'~'':~ '~ Rill:iS: . 025 ~t R ' '" ' ,".~ ............ ~: .... ,', '. : rOI ~PH'Z F".'~'''''' d.~~ .... 3~ ~4 9~ 0:~/~ ii ,,,~;+ ,,oo-,,00o ,,~u. ': ,;,~o ,¢': ...i. ,,:'..,ltott~.....~t~,;;~;, ".~,.. ,. ........... ' ,;~:~ ,,titt~.., ?... ~R RHOB 9990 ,.~.-,..:., :., ........ ....... , ~.?: . 2500, , '~9 e 0 A =9' 0 RNRA: ,-999~.2~00 DRHO IRA -9~9 NCNb' 9 , O0 ~CNL , Ell RHO N~H~ 8~RVXC~ NAM VERS.~ON t ' NCNb '~' 1660 DRHO NRA~ .... ;'t ~'~ , 1024 ORXG~N .OOOO~. ~ ?APg'*~NAH£ CONT~NUATZON:.# CO:N#gN?S iLIRRAR! TAPE S~RVZC~ NA~ ,~ NEXT, REEL. NAME TAPE VERIFICATION bISTINO RECEIVE1) ,t'~EC 2 8 1987 ~t~ Oi.~ & Gas Cons. Commissloil · Anchorage O,,tOoH~2 VE~IFICATI~N bISTING ,EEL HEADER 'IC~ NAME :EDIT ::85/11/19 ;IN : ,NAME '?NUATION # {01 '101]$ R~EL : ~APE HEADER ~* rICF NAME ;EDIT =65/11/19 ;IN :0000 NAME :0992 ~INUA?ZON # {01 ,'. NAME :EDIT ,001 ~TCF. NAME :. [MUM LENGTH I 1024 C TYP~ [NFORMATXON RECORDS q CONTENT8 I ARCO AbASKA ZNC B-2 KUPARUK SE NI N. SbDPE AbASKA USA CONT~NT~ COMMEN~$ ~ PAGE UNYT TYPE CATE SIZE CODE 000 000 0i9 O65 000 000 006 065 000 000 0,4 065 000 000 ~ 065 000 000 065 000 000 002 065 000 000 Or2 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 OOt '065 LVP O~O,H02 VEPlFICATION LISTING PAGE 2 * $CHI.,UHBER~ER $ * AbASKA COMPUTING CENTER $.. CONPANY = ARCO AbA&KA INC wEbb = 2H-Il eIEbO = KUPARUK COUNTy = NORTH &hOPE BOROUGH STATE a ALASKA JOB NUHB£R AT ACC: 70982 bOP~HOWARD aObA~ CASING TYPE FLUTD DENSITY VISCOSITY PH ~ATR~X = SAN~ 9.625" P 2743.0' - BIT SIZE m 8.5" TO 6765,0' 6$ND POI, YMER 10.90 6B/G R~ 5eh C3 R~ AT BHT m . -, DF ..olo,Ho2 VERIFICATION bZSTZNG DATA NAS NO? BEEN DEPTH ,SHIFTED - OVERL, A¥$ ?IE6D PRTNT$ ****'* **************************************************************************** SCHbUMBERGER bOGS TNCbUDED NTTH THT$ MAGNETIC INDUCTION SPHERICAbb¥ FOCU~E~ bOG CDI~) DATA AVRIbABbEI 6752,0 0 2744,0 FORMATION DENSITY COMPENSATED bOG CONPENSA?ED NEUTRON bOG DATA AVAIbABbEI 6727,0' TO 2744,0' DATA FO~NAT RECORD *$ R¥ BbOCK~ TYPE SiZE REPR C~DE ENTRY 2 ! 6 6 0 4 1 66 ! 8 4 73 60 9 4 65 ,lIN i LVP OiO,H02 VERIFICA?ZON bI$?ZNG PAGE 4 · 16 1 66 1 0 I 66 0 OA?UM SPECIFICATION BLOCKS MNEH SERVICE &~RVICE UNIT APl AP! APl AP! FII, E SIZE SPb REPR IP ORDER # bOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 SFLU ,IL OHM~ O0 220 Ol 0 0 4 IUD ~IL OHM~ O0 120 46 0 0 4 IbM OIL OHMM O0 120 44 0 0 4 SP DIL MV O0 010 01 0 0 4 OR Plb ~API O0 ~10 01 0 0 4 GR rDN CAPI O0 310 O1 0 0 4 CAb! FDN IN O0 280 01 0 0 4 RHOB FDN C/C3 O0 350 02 0 0 4 ORHO rDN G/C3 O0 356 01 0 0 4 NRAT FDN O0 420 01 0 0 4 RNRA FDN O0 000 O0 0 0 4 ~PHI rDN PU O0 890 O0 0 0 4 NCNb FDN CPS 00 330 31 0 0 4 FCNb rDN CPS O0 330 30 0 0 4 CODE (OCTAL) I 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 000~0000000000 I 68 000 0000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 DATA OEPT 6782,5000 SFLU SP '11.q326 GR RHOB .]440 DAHO NPH! 38.1836 NCNb 2.7620 ~bD 0273 GR I0 . CALl 0288 NRAT 2,4612 8.5020 3.1428 SP RHOB NPHI ~EPT SP NPHZ RHOB MPHI 6700,~ 9170 GR 10 9648 GR 105,9648 CALl 40'~'b273 DRHO :0098 NRAT 3.4182 RNRA NCNb 1930.68~5 FCNb 597o3i25 , GR 8398 GR 9 8398 CALl 2773 CAb! NCNb 2357,5000 FCNb 2,44'75 9.2832 3.2327 3,6448 9,3379 2,9299 5.4500 9,2598 2,9319 D£PT SP RHOB NPH! 6400 0000 SFbU . 48 DRH~ 38.1348 NCN 3.8440 IbD 5.5359 IbM , 3284 RN 3~3401 OEP? SP RHOB 6300.0000 5FLU -37.3945 GR T2:424! I)"I40 4 2168 NCNb ,700 646 3:7561 ICA?XON 67.00,0000 SFLU 42,4570 GE 22:4006 D"HO ' 4 4316 NCNL 6~00.0000 SFLU 3~.2070 C,R ' 3694 DRHO 39:3555 NCNb 6.0.000.0000SFLU 54.1758 CR ~I:~½~o ~,,o 3 NCNb L~$?ING PAGE .0010 2029.68?5 rCN6 57 ,3125 3 22~9 760 ~.9549 ~6~ ~ 0022 186'4395 OR 18 0'0068 NRA? ~. RNRA 3.3635 1869:6875 FCNb 55 .8125 4 ?820 TbD '9773 OR 10~'~3 CAb! 1~.1738 10~'0000 NRAT ~ ~ RNRA 2173.5000 ?CN6 5900.0000 SFLU 3 ?249 ~bD .3 ~ ~ - '5273 OR 11~ 3 2 Ib 3.3928 6~.~ GR 1~'0076 NRAT '~I~ CAb 0801 ' ~ 222 'rCNb 668.3125 ' ~?.oxx? .c ?.sooo . ...[ x~.~ 5800.0000 SFLU 3,T6327 ~bO 3.6917 ]:bl~ 3.911.63 ' '~"?I,~ ~" ,o, ~.~ ~, ,o~ ~ ~, ~.~?,~ e~ 32.4707 NCNb 2213.5000 FCNb 67 ,3 5 ~:'~ 57oo.oooo srt, u 5.?29?6 TLD 3.9807 ~bN 4.1062 -5~.8945 C,R 91 773 ~R 91.7773 CALX 9.455! 45.2776 r)RHO -0~0010 ~RAT 3.6897 RNRA 3. 1643 .2~48 NCNb 1704.6875 FCN6 538,8125 5600.0000 8FLU -56.3945 ~R 2.4690 DRHO 32.1289 NCNb 5500 0000 SFLU 2, 56 DRHO 39,2090 NCNb 3 0725 ~6O 2.9358 IbM 3.0979 ~'9648 ~R 6~.9648 CA~I 9.9004 8 '0161 NRA? .9963 RN 3.0100 2373:5000 ?CN6' 788,3125 11~'4023 OR 115.4023 CALX ~0200 NRA? 3.4651 RNRA 3,53 4 1992.6875 FCN6 563.3125 540,~ 0000 SFLU 4.2899 ThO 3.6,t09 Zb. {0'7581 -2 '9482 GR 102,~3~8 GR 102.8398 CALI 1 4160 2:4436 DRHO 0,0278 NRA? 3.1545 RNRA 3~1233 33.9844 NCNb 2135,5000 ?CN6 683.3125 5300 0000 SFLU i 9280 ~6D 2.9241 TbN 29.996i ,,,2~:3857 GR 8 '6523 GR 84 6523 CALX 947 23.373 DRHO O: ' 0059 NRAT 3. 1995 RNRA 3,0764 35.4980 NCNb 2201.5000 FCNb ?[5.3125 bVP.O'lO.H02 VERIFICATION LI$?ING PAG~ 6 )E:P'I' .~P ~HOB qPH! ~P ~HOB qPHX ~P ~HOB )EPT SP ~HIbB qPH! SP ~P ~HOB qPH! ~P :~HOB ~tPHX ~E:PT SP ~HOB ~IPHX ~P :~HOB )6PT ~P :~HOB '{PHI 3£PT mHOB 5100 0000 SFLU 3 7151 ;3~'6758 GR 118:0273 OR 11 .~i~~ IbM · . CALX 4045 DRHO 0308 NRAT . · , ~AL! 3~,3459 DRHO 0210 .9970 OR 12 8398 OR CALX 43'37333 DRHO '0112 NRAT RNRA .5059 NCNB 1848:6875 FCNb 4700 0000 SFLU 4,2625 '46:2070 CR 1070.9648 OR 2.3967 DRHO .0420 NRAT 42.0420 NCNb 1838,6875 FCNb 4900 3.3538 121.8398 ·6760 510,6406 4~00.0000 SrbU 3.0569 IbD 2.~ M 39.i758 GR 16~.937 1699 NCNb 1763.6875 FCNb 444,8 6 4.1414 IbM 107.964B CALX 3, R R 2,]gog DRHO 0,0444 NRA'I' 39e4531 NCNb 1891.6875 FCNb 34'4727, NCNb 2044'~. FcNR~ 69~.1096 RNRA .3125 4200.0000 SFbU · ~A[,I ]225 DRHO rCNb 54 . 4100.0000 ~F[JU 2.8323 YbO 2,9221 IbM -41 8945 GR 79 0273 CR 9 -99g:2500 DRHO -P99:2500 , RNRA 3.6663 9,8379 3,2288 3.2034 1~,1035 ,3342 3.4553 1~.4551 ,6194 2.5588 9,1504 3.963~ i.2312 .7129 .3381 1.7130 9.3691 3.6155 3,5881 8.5879 3.2209 3.4495 $.6426 2,9534 3,7542 9397 2.3303 8 2.9397 8.3613 -999.2500 ,VP 'gPT P 'PHZ PHI £PT PI'IX ~PT PH! 408 ~PT ~PT F.P~ ? O~O,H02 VgRIFiCA?ION bIS?lNG -999,2500 NCNb -999,2500 FCNb -999.2500 PAGE 4000 0000 SFLU '43'4258 ~A .9~ IbD 2 7795 TbM 2.7600 ' ~R t15'9023 CAI,! 8 8066 -999 2500 NCNb :99 · P¢~b -999.2500 '4 9258 C,R '04 '15~3 GR 10~: 3 CALl 9.1895 -99 2500 DRHO -''999'2500 NeAT -99 2500 RNRA -999. 500 -999.2500 NCNb '999:2500 rCNb -999.2500 3800.0000 SFI~U 12.9729 i D ~.,166 3 .1096 ' ' CAbZ 9 2 -999.2500 ORHO -999. 500 RAT "999.2500 RNRA -999 ~0 3.~00.0000 8FLU ; 42~4 ILD ~:9260 IbM 2 9534 43.7383 GR ' qgq.~.500 DRHO ..q989:3398 ~R 8 3398 2500 N~AT -999.2500 RNRA -999.2500 -999.2500 ~CNb -999.2500 PCNb -999.2500 , oo.oooo -43.9883 GR 97,5898 OR 97. 98 CAbI 2832 -q99.~500 DRHO .,990.2500 NeAT -999.~500 RNRA ,.999.2500 -999.2500 NCNb -999.2500 rCNb -999. 500 3500 0000 RFLU -45'1758 GR -099 2500 DR.O ~.7~I~ IbD 3 0061 IbM . 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