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Home My WebLink About185-198MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3C-13 KUPARUK RIV UNIT 3C-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3C-13 50-029-21424-00-00 185-198-0 W SPT 6342 1851980 1586 2925 2925 2925 2925 450 450 450 450 4YRTST P Austin McLeod 8/2/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3C-13 Inspection Date: Tubing OA Packer Depth 820 2000 1955 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250803181150 BBL Pumped:1.2 BBL Returned:1 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 99 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:09:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3C-13 KUPARUK RIV UNIT 3C-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 3C-13 50-029-21424-00-00 185-198-0 W SPT 6342 1851980 1586 2800 2800 2800 2800 130 130 130 130 INITAL P Brian Bixby 7/16/2023 Post conversion from producer as per SUNDRY 323-194 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3C-13 Inspection Date: Tubing OA Packer Depth 910 2175 2140 2140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230718164939 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, September 12, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 Post conversion from producer James B. Regg Digitally signed by James B. Regg Date: 2023.09.12 11:23:49 -08'00' 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: Convert PROD to INJ 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 9594'feet None feet true vertical 6865'feet 9427' x 3 feet Effective Depth measured 9323'feet 8914'feet true vertical 6649'feet 6342'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9070' MD Packers and SSSV (type, measured and true vertical depth) 8914' MD N/A 6342' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4791' 3698' Burst Collapse Production Liner 9541' Casing 6849'9574' 4756' 112'Conductor Surface Intermediate 16" 9-5/8" 76' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-198 50-029-21424-00-00 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: ADL0025634 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3C-13 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) INJECTOR Gas-Mcf MD ~ Size 112' ~ ~~ Well Remained Shut-In ~~ ~ 323-194 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FB-1 Packer SSSV: None Kaylie Plunkett kaylie.b.plunkett@conocophillips.com (907) 265-6450Surveillance Reservoir Engineer 9016-9036', 9199-9243', 9264-9276', 9312-9319' 6416-6431', 6553-6587', 6603-6612', 6640-6646' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov DTTMSTART JOBTYP SUMMARYOPS 6/3/2021 MISC - RES SURV BRUSH n' FLUSH GLM'S & D-NIPPLE @ 8935' RKB; SET 2.75" CA-2 PLUG W/ SINGLE SPARTEK GAUGE @ 8935' RKB. IN PROGRESS. 6/4/2021 MISC - RES SURV PULLED GLV & SET DUMMY @ 8033' RKB, PULLED GLV @ 6628' RKB, ATTEMPTED TO SET DUMMY VALVE ( POSSIBLY DROPPED VALVE ) , IN PROGRESS. 6/5/2021 MISC - RES SURV RECOVERED DROPPED DV FROM CATCHER @ 8935' RKB; SET DV @ 6628' RKB; PULLED GLV & SET DV @ 3813' RKB; PULLED OV @ 8859' RKB; LRS ON LOCATION PERFORMING CIRC OUT OF 295 BBLS CISW FOLLOWED BY 77 BBLS OF DIESEL (U-TUBE FP). IN PROGRESS. 6/5/2021 MISC - RES SURV PUMPED 5 BBL METH PILL, FOLLOWED BY 290 BBLS OF SEAWATER, FOLLOWED BY 77 BBLS OF DIESEL, U-TUBE TO FREEZE PROTECT, JOB COMPLETE. 6/6/2021 MISC - RES SURV SET DV @ 8859' RKB; MITT & MITIA TO 2500 PSI (BOTH PASSED); PULLED CATCHER & 2.75" CA-2 PLUG W/ GAUGE @ 8935' RKB. JOB COMPLETE. 6/7/2021 ANNCOMM (MISC) IC POT PASSED , IA & OA DDT IN PROGRESS 6/8/2021 ANNCOMM (MISC) : DDT-IA PASSED, DDT-OA PASSED, R&R IC-PO ALEMITE (COMPLETE), PPPOT-IC PASSED. 12/13/2022 ACQUIRE DATA (MISC) RE-ENERGIZE IC-PO (IN-PROGRESS) 12/14/2022 ACQUIRE DATA (MISC) IC PO RE-ENERGIZER (IN PROGRESS) 12/15/2022 ACQUIRE DATA (MISC) IC PO RE-ENERGIZER (COMPLETE) IC-POT (PASSED) IC-PPPOT (PASSED) 4/14/2023 PUMPING TRACKING ONLY PUMP 12 BBLS DSL OUT OF 25 DWN FL FOR FLUID PACK & PT, LEAK DETECTED DSO SHUT DWN JOB, WILL RETURN ONCE DSM HAVE ADDRESSED ISSUE 4/15/2023 PUMPING TRACKING ONLY PUMPED 8 BBLS DSL DOWN FL TO FLUID PACK. PT'D FL TO 3000 PSI. PT GOOD. DSO TO BLEED FLOWLINE DOWN. JOB COMPLETE 4/18/2023 ACQUIRE DATA (PRE-SW) MITIA PASSED TO 2500 PSI. 7/1/2023 WELL CONVERTED TO PRODUCED WATER INJECTOR 7/16/2023 ACQUIRE DATA (SW) 3C-13 (BRIAN BIXBY) MIT-IA TO 2175 PSI (PASSED) Initial T/I/O = 2800/910/130, IA FL @ SF LRS pressured the IA to 2175 psi w/1.4 bbls Starting T/I/O = 2800/2175/130 15 min T/I/O = 2800/2140/130 (-35) 30 min T/I/O = 2800/2140/130 (0) LRS bled the IA to 910 psi (1.4 bbls back) Final T/I/O = 2800/910/130 3C-13 Convert to Injector Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 9,323.0 3C-13 8/16/2019 jhansen8 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled GLV's & Set DV's for Injection Conversion 3C-13 6/6/2021 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/11/2010 ninam 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 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.3 4,791.3 3,698.2 36.00 J-55 BTC PRODUCTION 7 6.28 33.1 9,573.7 6,848.7 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.0 Set Depth 9,069.9 Set Depth 6,456.4 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.00 HANGER 8.000 CIW GEN IV TUBING HANGER 3.500 509.3 509.3 1.18 NIPPLE 3.800 CAMCO DS LANDING NIPPLE w/ NO GO PROFILE 2.812 3,813.9 3,110.7 48.25 GAS LIFT 6.018 CAMCO MMM 2.920 6,628.4 4,808.1 50.38 GAS LIFT 6.018 CAMCO MMM 2.920 8,033.0 5,737.6 47.49 GAS LIFT 6.018 CAMCO MMM 2.920 8,525.5 6,069.6 46.66 GAS LIFT 6.018 CAMCO MMM 2.920 8,859.9 6,302.6 44.05 GAS LIFT 6.018 CAMCO MMM 2.920 8,905.6 6,335.7 43.39 NIPPLE 3.980 CAMCO W SELECTIVE LANDING NIPPLE 2.812 8,912.9 6,340.9 43.33 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 8,913.9 6,341.7 43.32 PACKER 5.875 BAKER FB-1 PACKER 4.000 8,917.2 6,344.1 43.29 SBE 5.000 BAKER 80-40 SEAL BORE EXTENSION 4.000 8,935.3 6,357.3 43.14 NIPPLE 4.500 CAMCO D NIPPLE NO GO 2.750 9,069.0 6,455.7 41.98 SOS 4.500 BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Found empty pocket 9/9/1989 9/9/1989 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Valve Lost in Hole 6/17/1993 6/17/1993 9,427.0 6,731.1 37.07 FISH 1 1/2" OV Found Empty Pocket 6/20/1993 6/20/1993 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) 3,813.9 3,110.7 48.25 1 GAS LIFT DMY RK 1 1/2 0.0 6/5/2021 0.000 6,628.4 4,808.1 50.38 2 GAS LIFT DMY RK 1 1/2 0.0 6/5/2021 0.000 8,033.0 5,737.6 47.49 3 GAS LIFT DMY RK 1 1/2 0.0 6/4/2021 0.000 8,525.5 6,069.6 46.66 4 GAS LIFT DMY RK 1 1/2 0.0 12/12/1995 0.000 8,859.9 6,302.6 44.05 5 GAS LIFT DMY RK 1 1/2 0.0 6/6/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,016.0 9,036.0 6,416.5 6,431.3 C-1, UNIT B, 3C- 13 11/5/1985 12.0 IPERF 120 deg. ph; SOS 5" Csg Gun 9,199.0 9,243.0 6,553.5 6,587.1 A-4, A-3, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,264.0 9,276.0 6,603.2 6,612.5 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,312.0 9,319.0 6,640.3 6,645.8 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 3C-13, 8/30/2023 3:54:41 PM Vertical schematic (actual) PRODUCTION; 33.1-9,573.7 FISH; 9,427.0 FISH; 9,427.0 FISH; 9,427.0 IPERF; 9,312.0-9,319.0 IPERF; 9,264.0-9,276.0 IPERF; 9,199.0-9,243.0 IPERF; 9,016.0-9,036.0 PACKER; 8,913.9 GAS LIFT; 8,859.9 GAS LIFT; 8,525.5 GAS LIFT; 8,033.0 GAS LIFT; 6,628.4 SURFACE; 35.3-4,791.3 GAS LIFT; 3,813.9 NIPPLE; 509.3 CONDUCTOR; 36.0-112.0 KUP INJ KB-Grd (ft) 37.49 RR Date 10/29/198 5 Other Elev 3C-13 ... TD Act Btm (ftKB) 9,594.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292142400 Wellbore Status INJ Max Angle & MD Incl (°) 55.12 MD (ftKB) 5,500.00 WELLNAME WELLBORE3C-13 Annotation Last WO: End Date 12/12/1995 H2S (ppm) 100 Date 12/9/2014 Comment SSSV: NIPPLE X SFD 6/14/2023 DSR-3/31/23 X 10-404 VTL 6/22/2023GCW 06/22/2023 06/23/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 09:00:07 -08'00' RBDMS JSB 062723 Proposal ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3C-13 (PTD #185-198) from Oil Production service to Water Injection service. Area of Review: Kuparuk well 3C-13 was completed as a producer in October 1985. It has been shut in since Apr-2020 for low productivity. Within a quartmile of the completed zone is 1Q-01 (PTD #210-026) and 3C-11 (PTD #212- 188). The top of the Kuparuk C Sand is at 8949' MD / 6367' TVD The base of the Kuparuk C Sand is 9028' MD / 6425' TVD The top of the Kuparuk A Sand is at 9188' MD / 6544' TVD The base of the Kuparuk A Sand is 9338' MD / 6660' TVD Area Map with ¼ mile radius around target injection zone (see attached): The attached map shows that neighboring wells, 3C-11A and 1Q-03A are located within a 1/4 mile radius of the 3C-13 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3C-13 is good. It will be utilized for water injection only because there is no gas injection infrastructure at 3C pad. The injection tubing/casing annulus is isolated with a Baker FB-1 packer and Baker 80-40 seal bore extension located at 8914' MD (6342' TVD). Well 3C-13 passed a MITT & MITIA to 2500 psi on 6/6/21 and passed a DDT-IA, DDT-OA, PPPOT-IC on 6/7/21. A State-witnessed MIT-IA will be performed once well 3C-13 is converted to water injection, online, and stabilized. CET and interpretation of the cement quality: The production casing CBL found top of cement at 7700' MD (5512' TVD). The log indicates sufficient cement bond above and through the Kuparuk interval to ensure injection zone containment. The 9-5/8" Surface casing was cemented with 1300 sx PF "E" & 330 sx Class "G" The 7" Intermediate casing was cemented with 575 sx of Class "G" & 200 sx of PF "C" Conditions for approval (if applicable): convert Kuparuk River Unit Well 3C-13 (PTD #185-198) from Oil Production service to Water Injection service. A State-witnessed MIT-IA will be performed once well 3C-13 is converted to water injection, online, and stabilized. PTD API WELL NAME STATUSTop of C-Sand Oil Pool (MD)Top of C-Sand Oil Pool (TVD)Top of Cement (MD)Top of Cement (TVD)Top of Cement Determined ByReservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity210-026 50029212490100 1Q-03A Producing 10,048 6,425 10,136 6,478 CBLslotted liner open for productionBaker FHL packer at 10008' MD / 6399' TVD and Baker FB-2 packer 10348' MD and 6598' TVD.9-5/8" Inter-casing 1300 sx CS III, 550 sx CS 1, 89 sx CS1 7" production casing - 470 Class G, 250 sc CS 1 No known mechanical integrity issues. Passed TIFL 3/11/11. 212-188 50029213570100 3C-11AOffline producer8,319 6,374 7,790 6,024 CBLSlotted liner open for productionBaker FHL packer at 8128' RKB / 6246' TVD and Baker DB packer at 8487' RKB / 6484' TVD.9-5/8" inter-Casing 1360 sx AS III, 320 sx class G 7" Production casing, 325 sx Class GWaivered for IAxOA communication. Secured with a PX Plug W/ Gauge at 8,139' MD. Passed CMIT-TxIA to 2500 psi on 6/7/2021. T12NR9ET12NR10E1Q-221Q-02B1Q-04L1-013C-16 1Q-02BL11Q-151Q-013C-14A1Q-033C-17 3C-09L1PB13C-12 1Q-15L1-02PB13C-14BPB11Q-211Q-15L1-021 Q -0 3 A 3 C -1 4 3C-14B1Q-03AL1 3C-11 3C-10APB13C-11A3C-11AL13C-10A3C-13 ADL025629ADL025628ADL025629 ADL025634 ADL025635ADL0256343C PCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 1:59,310,894-10APB13C--3C3C33C-11A3C3C13CADL025629ADL0256283C-13 10-403 Sundry 6/14/2021 1Q-151Q-151Q11Q-151QP+A Well Active Well ADNR Township CPAI Lease 3C-13 Well Trajectory 3C-13 Open Interval 3C-13 OI Quartermile Buffer 0 0.25 0.5 Miles Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 9,323.0 8/16/2019 3C-13 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled GLV's & Set DV's for Injection Conversion 6/6/2021 3C-13 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.3 Set Depth (ftKB) 4,791.3 Set Depth (TVD) … 3,698.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.1 Set Depth (ftKB) 9,573.7 Set Depth (TVD) … 6,848.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.0 Set Depth (ft… 9,069.9 Set Depth (TVD) (… 6,456.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.0 32.0 0.00 HANGER CIW GEN IV TUBING HANGER 3.500 509.3 509.3 1.18 NIPPLE CAMCO DS LANDING NIPPLE w/ NO GO PROFILE 2.812 8,905.6 6,335.7 43.39 NIPPLE CAMCO W SELECTIVE LANDING NIPPLE 2.812 8,912.9 6,340.9 43.33 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 8,913.9 6,341.7 43.32 PACKER BAKER FB-1 PACKER 4.000 8,917.2 6,344.1 43.29 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,935.3 6,357.3 43.14 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,069.0 6,455.7 41.98 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Found empty pocket 9/9/1989 9/9/1989 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Valve Lost in Hole 6/17/1993 6/17/1993 9,427.0 6,731.1 37.07 FISH 1 1/2" OV Found Empty Pocket 6/20/1993 6/20/1993 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,016.0 9,036.0 6,416.5 6,431.3 C-1, UNIT B, 3C -13 11/5/1985 12.0 IPERF 120 deg. ph; SOS 5" Csg Gun 9,199.0 9,243.0 6,553.5 6,587.1 A-4, A-3, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,264.0 9,276.0 6,603.2 6,612.5 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,312.0 9,319.0 6,640.3 6,645.8 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,813.9 3,110.7 48.25 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/5/2021 2 6,628.4 4,808.1 50.38 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/5/2021 3 8,033.0 5,737.6 47.49 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/4/2021 4 8,525.5 6,069.6 46.66 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/1995 5 8,859.9 6,302.6 44.05 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/6/2021 Notes: General & Safety End Date Annotation 11/11/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3C-13, 6/7/2021 8:25:22 AM Vertical schematic (actual) PRODUCTION; 33.1-9,573.7 FISH; 9,427.0 FISH; 9,427.0 FISH; 9,427.0 IPERF; 9,312.0-9,319.0 IPERF; 9,264.0-9,276.0 IPERF; 9,199.0-9,243.0 SOS; 9,069.0 IPERF; 9,016.0-9,036.0 NIPPLE; 8,935.3 SBE; 8,917.2 PACKER; 8,913.9 SEAL ASSY; 8,912.9 NIPPLE; 8,905.6 GAS LIFT; 8,859.9 GAS LIFT; 8,525.5 GAS LIFT; 8,033.0 GAS LIFT; 6,628.4 SURFACE; 35.3-4,791.3 GAS LIFT; 3,813.9 NIPPLE; 509.3 CONDUCTOR; 36.0-112.0 HANGER; 32.0 KUP PROD KB-Grd (ft) 37.49 Rig Release Date 10/29/1985 3C-13 ... TD Act Btm (ftKB) 9,594.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292142400 Wellbore Status PROD Max Angle & MD Incl (°) 55.12 MD (ftKB) 5,500.00 WELLNAME WELLBORE3C-13 Annotation Last WO: End Date 12/12/1995 H2S (ppm) 100 Date 12/9/2014 Comment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Plunkett, Kaylie B To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3C-13(PTD 185-198, Sundry 323-194) Conversion to WI AOR Date:Tuesday, June 20, 2023 3:37:47 PM Attachments:image001.png You don't often get email from kaylie.b.plunkett@conocophillips.com. Learn why this is important Hi Victoria, Just following up on this. I am more than happy to submit a corrected sundry for this and include the drilling report that indicates the additional cement squeeze. Kindest regards, Kaylie Plunkett Reservoir Surveillance Engineer|Alaska Scale Lead 3ROCKQNJ |ConocoPhillips Alaska |O: 907.265.6450 |C: 918.857.5323 From: Plunkett, Kaylie B Sent: Tuesday, May 9, 2023 8:38 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3C-13(PTD 185-198, Sundry 323-194) Conversion to WI AOR Hi Victoria, For your consideration, The previous TOC value reported for 1Q-03 is the TOC from the CBL ran on 04/17/85. Subsequent drilling reports from 4/27-4/30/85 show a cement squeeze of 50 sx class G followed by 50 sx cement spotted at the squeeze perfs in the Area of Concern. The cement squeeze is the equivalent of 453’ of cement behind pipe, bringing the adjusted TOC to 9,683’ MD. As an additional consideration, this portion of the wellbore is also outside of the ¼ mile radius indicated on the map. Please let me know if you have any other questions or concerns. Kaylie Plunkett Reservoir Surveillance Engineer|Alaska Scale Lead 3ROCKQNJ |ConocoPhillips Alaska |O: 907.265.6450 |C: 918.857.5323 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, April 24, 2023 11:30 AM To: Plunkett, Kaylie B <Kaylie.B.Plunkett@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 3C-13(PTD 185-198, Sundry 323-194) Conversion to WI AOR CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Kaylie, In reviewing the area of review, for Well KRU 1Q-03A, the TOC is below the top of the C Sand oil pool(10,136’ MD TOC vs 10-048’ MD top of oil pool). How will injected fluids in 3C-13 be confined in offset well KRU 1Q-03A? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov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y Samantha Carlisle at 3:39 pm, Jul 08, 2021 321-342 Devin Kozak Digitally signed by Devin Kozak Date: 2021.07.08 12:36:26 -08'00' DSR-7/9/21 X -00 DLB DLB 07/08/2021 X 10-404 VTL 7/12/21 X dts 7/12/2021 JLC 7/12/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.12 12:09:47 -08'00' RBDMS HEW 7/14/2021 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99505-3448 www.conocophillips.com July 2, 2021 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 ConocoPhillips Alaska, Inc. requests approval to convert long-term shut-in Kuparuk River Unit Well 3C-13 from production service to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approval regarding KRU 3C-13, (PTD# 185-198). If you have any questions regarding this matter, please contact me at 907-265-4121. Regards, Devin Kozak Associate Surveillance Reservoir Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Application Devin Kozak Digitally signed by Devin Kozak Date: 2021.07.08 12:35:57 -08'00' Proposal ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3C-13 (PTD #185-198) from Oil Production service to Water Injection service. Area of Review: Kuparuk well 3C-13 was completed as a producer in October 1985. It has been shut in since Apr-2020 for low productivity. Within a quartmile of the completed zone is 1Q-01 (PTD #210-026) and 3C-11 (PTD #212- 188). The top of the Kuparuk C Sand is at 8949' MD / 6367' TVD The base of the Kuparuk C Sand is 9028' MD / 6425' TVD The top of the Kuparuk A Sand is at 9188' MD / 6544' TVD The base of the Kuparuk A Sand is 9338' MD / 6660' TVD Area Map with ¼ mile radius around target injection zone (see attached): The attached map shows that neighboring wells, 3C-11A and 1Q-03A are located within a 1/4 mile radius of the 3C-13 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3C-13 is good. It will be utilized for water injection only because there is no gas injection infrastructure at 3C pad. The injection tubing/casing annulus is isolated with a Baker FB-1 packer and Baker 80-40 seal bore extension located at 8914' MD (6342' TVD). Well 3C-13 passed a MITT & MITIA to 2500 psi on 6/6/21 and passed a DDT-IA, DDT-OA, PPPOT-IC on 6/7/21. A State-witnessed MIT-IA will be performed once well 3C-13 is converted to water injection, online, and stabilized. CET and interpretation of the cement quality: The production casing CBL found top of cement at 7700' MD (5512' TVD). The log indicates sufficient cement bond above and through the Kuparuk interval to ensure injection zone containment. The 9-5/8" Surface casing was cemented with 1300 sx PF "E" & 330 sx Class "G" The 7" Intermediate casing was cemented with 575 sx of Class "G" & 200 sx of PF "C" Conditions for approval (if applicable): convert Kuparuk River Unit Well 3C-13 (PTD #185-198) from Oil Production service to Water Injection service. A State-witnessed MIT-IA will be performed once well 3C-13 is converted to water injection, online, and stabilized. PTD API WELL NAME STATUSTop of C-Sand Oil Pool (MD)Top of C-Sand Oil Pool (TVD)Top of Cement (MD)Top of Cement (TVD)Top of Cement Determined ByReservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity210-026 50029212490100 1Q-03A Producing 10,048 6,425 10,136 6,478 CBLslotted liner open for productionBaker FHL packer at 10008' MD / 6399' TVD and Baker FB-2 packer 10348' MD and 6598' TVD.9-5/8" Inter-casing 1300 sx CS III, 550 sx CS 1, 89 sx CS1 7" production casing - 470 Class G, 250 sc CS 1 No known mechanical integrity issues. Passed TIFL 3/11/11. 212-188 50029213570100 3C-11AOffline producer8,319 6,374 7,790 6,024 CBLSlotted liner open for productionBaker FHL packer at 8128' RKB / 6246' TVD and Baker DB packer at 8487' RKB / 6484' TVD.9-5/8" inter-Casing 1360 sx AS III, 320 sx class G 7" Production casing, 325 sx Class GWaivered for IAxOA communication. Secured with a PX Plug W/ Gauge at 8,139' MD. Passed CMIT-TxIA to 2500 psi on 6/7/2021. T12NR9ET12NR10E1Q-221Q-02B1Q-04L1-013C-16 1Q-02BL11Q-151Q-013C-14A1Q-033C- 1 7 3C-09L1PB13C-12 1Q-15L1-02PB13C-14BPB11Q-211Q-15L1-021Q-03A 3 C - 1 4 3C-14B1Q-0 3 A L 1 3C-11 3C-10APB13C-11A3C-11AL13C-10A3C- 1 3 ADL025629ADL025628ADL025629 ADL025634 ADL025635ADL0256343C PCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet 1:59,310,894-10APB13C---3C3C33C-11A3C3C 13C3CADL025629ADL0256283C-13 10-403 Sundry 6/14/2021 1Q-151Q-151Q 11Q-151QP+A Well Active Well ADNR Township CPAI Lease 3C-13 Well Trajectory 3C-13 Open Interval 3C-13 OI Quartermile Buffer 0 0.25 0.5 Miles Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 9,323.0 8/16/2019 3C-13 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled GLV's & Set DV's for Injection Conversion 6/6/2021 3C-13 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.3 Set Depth (ftKB) 4,791.3 Set Depth (TVD) … 3,698.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.1 Set Depth (ftKB) 9,573.7 Set Depth (TVD) … 6,848.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.0 Set Depth (ft… 9,069.9 Set Depth (TVD) (… 6,456.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.0 32.0 0.00 HANGER CIW GEN IV TUBING HANGER 3.500 509.3 509.3 1.18 NIPPLE CAMCO DS LANDING NIPPLE w/ NO GO PROFILE 2.812 8,905.6 6,335.7 43.39 NIPPLE CAMCO W SELECTIVE LANDING NIPPLE 2.812 8,912.9 6,340.9 43.33 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 8,913.9 6,341.7 43.32 PACKER BAKER FB-1 PACKER 4.000 8,917.2 6,344.1 43.29 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,935.3 6,357.3 43.14 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,069.0 6,455.7 41.98 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Found empty pocket 9/9/1989 9/9/1989 9,427.0 6,731.1 37.07 FISH 1 1/2" GLV Valve Lost in Hole 6/17/1993 6/17/1993 9,427.0 6,731.1 37.07 FISH 1 1/2" OV Found Empty Pocket 6/20/1993 6/20/1993 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,016.0 9,036.0 6,416.5 6,431.3 C-1, UNIT B, 3C -13 11/5/1985 12.0 IPERF 120 deg. ph; SOS 5" Csg Gun 9,199.0 9,243.0 6,553.5 6,587.1 A-4, A-3, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,264.0 9,276.0 6,603.2 6,612.5 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun 9,312.0 9,319.0 6,640.3 6,645.8 A-2, 3C-13 11/5/1985 4.0 IPERF 90 deg. ph; SOS 4" Csg Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,813.9 3,110.7 48.25 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/5/2021 2 6,628.4 4,808.1 50.38 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/5/2021 3 8,033.0 5,737.6 47.49 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/4/2021 4 8,525.5 6,069.6 46.66 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/1995 5 8,859.9 6,302.6 44.05 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/6/2021 Notes: General & Safety End Date Annotation 11/11/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3C-13, 6/7/2021 8:25:22 AM Vertical schematic (actual) PRODUCTION; 33.1-9,573.7 FISH; 9,427.0 FISH; 9,427.0 FISH; 9,427.0 IPERF; 9,312.0-9,319.0 IPERF; 9,264.0-9,276.0 IPERF; 9,199.0-9,243.0 SOS; 9,069.0 IPERF; 9,016.0-9,036.0 NIPPLE; 8,935.3 SBE; 8,917.2 PACKER; 8,913.9 SEAL ASSY; 8,912.9 NIPPLE; 8,905.6 GAS LIFT; 8,859.9 GAS LIFT; 8,525.5 GAS LIFT; 8,033.0 GAS LIFT; 6,628.4 SURFACE; 35.3-4,791.3 GAS LIFT; 3,813.9 NIPPLE; 509.3 CONDUCTOR; 36.0-112.0 HANGER; 32.0 KUP PROD KB-Grd (ft) 37.49 Rig Release Date 10/29/1985 3C-13 ... TD Act Btm (ftKB) 9,594.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292142400 Wellbore Status PROD Max Angle & MD Incl (°) 55.12 MD (ftKB) 5,500.00 WELLNAME WELLBORE3C-13 Annotation Last WO: End Date 12/12/1995 H2S (ppm) 100 Date 12/9/2014 Comment SSSV: NIPPLE Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (do.e) RESCAN Color items: Orayscale items: Poor Quality Origin~als: Other: DIGITAL DATA Diskettes, No. Other, No/Type TOTAL PAGES: ORGANIZED BY: ~"'~ ~ NOTES: BEVERLY BREN VINCENT SNERYL MARIA LOWELL DATE: OVERSIZED (Scannable) o Maps: n Other items scannable by large scanner OVERSIZED (Non-Scannable) n Logs of various kinds n Other ISl Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl SCANNED BY: BEVERLY BREN VINCF.~~ MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file:/ Quality Checked RevlNOTScanned.v4xJ i . j . • . • . . . . : . . ; ~ . ~~~~~ ~f ~~ COr1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 20Q9 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite lU0 Anchorage, AK 99501 ~waJ`"R.~~l~~~` ..~ U ~. ; ` ~ `~ ~ ~ Dear Mr. Maunder: JUL (l ~ 20fl9 ~la~ka ~i! ~ G~s ~,~~,. ~o~missian A ~ .r.te~r~p~ ~, ~~ ~ ~~ ~ G, --13~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. 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 June 16~' & 26~', 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30~`, 2009. The attached spreadsheet presents the well naxne, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~f~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operatfons (10-404) Kuparuk Field Date T/3/09 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2QU9 3C-02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6/30l2009 3C-03 500292141500 1851890 5' 1.0 21 " 6/26/2009 5.1 6/30/2009 3C-04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" n/a 24" n/a 4.25 6/23/2009 3C-06 500292109600 1840420 6" n/a 6" n/a 7.65 6/23/2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6/23/2009 3C-08 500292139000 1851550 12' 2.00 22" 6/16/2009 3.4 6/23/2009 3C-09 500292135500 1851000 20" n/a 20" n/a 2.55 6/23/2009 3C-10 500292135600 1851010 30' 4.10 24" 6/16/2009 4.25 6/23/2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3G13 500292142400 1851980 20" n/a 20" n/a 2.12 6/23/2009 3C-14A 500292142501 2071750 3' n/a 3' n/a 8.07 6/23/2009 3G15A 500292142601 2080810 31' 4.40 26" 6/16/2009 2.75 6/23/2009 3C-16 500292142700 1852010 20" n/a 20" Na 2.12 6/23/2009 3C-17 500292338900 2080590 2'6" n/a 2'6" n/a 8.92 6/23/2009 \ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 8, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 3C-13(Permit No. 85-198) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 3C- 13. The original 2-7/8" selective single completion was pulled and the wellbore was cleaned out. A 3-1/2" single completion was re-run. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Petroleum Engineering WSI/skad FEB 0 9 Naska Oil A Gas Cons. Commission STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMIS,.,,ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r~ GAS [~] SUSPENDED [~ ABANDONED [--'] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 85-198 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21424 4 Location of well at surface 9 Unit or Lease Name 1310' FNL, 1217' FEL, Sec. 14, T12N, ROE, UM :,' Kuparuk River Unit AtTop Producing Interval .!,~ ~~' ~-J 10 Well3c_lNumber3 At Total Depth ;[~ 1~ '~ ~'J,~!~~ 11 Field and Pool 1203' FSL, 951' FEL, Sec 13, T12N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 85' ADL 25634 ALK 2567 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore MSL 16 No. of Completions October 17, 1985 October 27, 1985 12-Dec-95 (recompleted) NA feet 2 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thlckness of permafrost 9594' MD & 6865' TVD 9491'MD & 678lq'VD YES L_.J NO x~JI NA feet MD] = 1380' ss APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CE]VIENTRECORD 16" 62.5# H-40 SURF. 112' 24" 188 sx CS II 9.625" 36.0# J-55 SURF. 4791' 12.25" 1300 sx PF "E" & 330 sx Class G 7" 26# J-55 SURF. 9574' 8.5" 575 sx Class G & 200 sx PFC 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9070' 8914' 9016'-9036' MD 12 spf 9199'-9243' MD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, FTC 9264'-9276' MD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9312'-9319' MD 4 spf A' & 'C' sands 14,000# of 20/40, 80740# of 16/20, 94260# of 12/18, 11163# of 10/14, 197,000# of proppant behind pipe, 3163# of proppant left in wellbore 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUE[DON REVERSE SIDE ;~9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8950' 6368' Bottom Kuparuk C 9029' 6426' Top Kuparuk A 9183' 6541' Bottom Kuparuk A 9320' 6647' 31. LIST OF ATTACHMENTS Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~.~'~ I~, ~J,~..-~....~_ Title 0~[LI.T~C ~{~l~r~;, 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. L; I V Item 28: If no cores taken, indicate "none". ~ j'? L~ Form 10-407 FEB 0 9 1996 Alask~ Oil & Gas Cons. Commission Date: 2/6/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:3C-13 RIG:NORDIC WELL ID: 998483 AFC: 998483 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD' START COMP: BLOCK: FINAL: Page: 1 C ivED FEB 0 9 1995 Alas~ ~ & Gas Con~, Commission ~'~o: ~ SECURITY : 0 AFC EST/UL:$ OM/ OM API NUMBER: 50-029-21424-00 12/05/95 (1) TD: 9594' PB: 9491' SUPV:DEB DAILY: 12/06/95 (2) TD: 9594' PB: 9491' SUPV: DLW DAILY: 12/07/95 (3) TD: 9594' PB: 9491' SUPV:DLW DAILY: 12/08/95 (4) TD: 9594' PB: 0' SUPV:DLW DAILY: 12/09/95 (5) TD: 9594' PB: 0' SUPV:DLW DAILY: 12/10/95 ( 6) TD: 9594' PB: 0' SUPV: DLW DAILY: C&C 10.5+ PPG MUD - WELL MW:10.5 LSND Move rig from 3C-06 to 3C-13. Accept rig @ 0930, 12/4/95. Prep to kill well. Load well with seawater. Kill well. Well dead. $39,250 CUM: $78,500 ETD: $0 EFC: $78,500 PULL 2-7/8" TBG & JEWELRY MW:10.5 LSND Continue circulating and conditioning mud. Test BOP's. Pull and lay down 2-7/8" tubing and jewelry. $37,828 CUM: $154,156 ETD: $0 EFC' $154,156 RIH OVERSHOT FOR SLICK ST MW:10.5 LSND Continue to pull tubing and jewelry. Fish @ 8824'. POOH w/fish. $31,872 CUM: $217,900 ETD: $0 EFC: $217,900 POOH W/FISH BLAST RING JT MW:10.4 LSND Continue to RIH 8840' w/fishing BHA run %2 dressed w/3.25" grapple. Work over Slick Stick @ 8848', pull 60K over string weight jarred free, move PKR up and down, let PKR set 10 min. POOH slowly with packer assy. L/D recover 143.41' of fish. Change grapple to 2-7/8" & RIH to 8972'. Work over fish @ 8993'. $31,700 CUM: $281,300 ETD: $0 EFC: $281,300 CBU @ 9090' W/ FISH 6' AB MW: 0.0 Continue to POOH (no fish). Rerun same BHA w/2-7/8" grapple run %4 fishing for blast ring jt @ 8995' TOP. Work over fish @ 8995' cut off above blast ring. POOH. L/D blast ring jt w/ cut off's of (15.32' & 5.25'). Change grapple and RIH to 9094'. P/U kelly work over top of fish @ 9100' Pull free w/ 10K over string weight. $13,761 CUM: $308,822 ETD: $0 EFC: $308,822 RIH W/SPEAR FOR WD PKR MW:10.7 LSND Continue to circulate and condition mud. POOH w/fish. L/D 2-7/8" cut off 9.85', 1 jt., 1 2-7/8" GLM and Camco seal assembly. L/D 5-3/4" overshot, P/U 6-1/8" PKR milling BHA %2, RIH to 9096' P/U kelly. Mill up 7" x 2-7/8" Otis WD pkr from 9096'-9099' @ 65 spm 1250 psi. L/D PKR mill, P/U BHA %3, spear to fish "WD" PKR, RIH. $34,906 CUM: $378,634 ETD: $0 EFC: $378,634 Date: 2/6/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 12/11/95 ( 7) TD: 9594' ?B: 0' SUPV:DLW DAILY: POOH TO RUN 3-1/2" COMPLE MW:10.7 LSND Continue RIH w/ BHA ~3, 3-1/4" spear to 9374'. P/U kelly and latch on to 7" Otis packer assy. Pull tool joint to rig floor. POOH w/Otis 7" "WD" Pkr assy. L/D "WD" Pkr Assy. 2 2-7/8" pups, Camco "D" nipple and WLEG. P/U rerun 6-1/8" bit, w/7" scraper spaced out to stop @ 8900'. RIH to 9396' Run in to wireline junk. Unable to pass. R/U and POOH L/D 76 jts DP. $32,714 CUM: $444,062 ETD: $0 EFC: $444,062 12/12/95 (8) TD: 9594' PB: 0' SUPV:DLW DAILY: RUN 3-1/2" COMPLETION MW: 8.5 LSND RIH w/ 5.95" Gauge ring junk basket to 9200'. Flag line to set FB-1 Assy. Tight spot at 3180'. RIH w/Baker FB-1 permanent Pkr assy total of 156.02', set Pkr top @ 8900' to 9056'. Run new 3-1/2" production tubing with jewelry. $70,532 CUM: $585,126 ETD: $0 EFC: $585,126 12/13/95 (9) TD: 9594' PB: 0' SUPV:DLW DAILY: RIG RELEASED MW: 8.5 DOILSW Run 3-1/2" single completion assembly. Run tubing. Test tubing to 2500 psi for 15 minutes, OK. Test annulus to 2500 psi for 15 minutes, OK. Test packoff to 5000 psi. Test tree to 250 psi and 5000 psi. Freeze protect tubing. Secure well. Release rig @ 2400 hrs. 12/12/95. $28,413 CUM: $641,952 ETD: $0 EFC: $641,952 End of WellSummary for We11:998483 STATE Of ALASKA ALA~/.,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet feet feet feet ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1310' FNL, 1217' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1441' FSL, 1283' FEL, Sec. 13, T12N, R9E, UM At effective depth 1244' FSL, 1009' FEL, Sec. 13, T12N, R9E, UM At total depth 1203' FSL, 951' FEL, Sec. 13, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 9594' true vertical 6864' Effective depth: measured 9491 ' true vertical 6781 ' Casing Length Size Structural 80' 1 6" Conductor Surface 4759' 9 5/8" 6. Datum elevation (DF or KB) RKB ~4' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3C-13 9. Permit numb/er ° 10. APl number 5o-02~)-21 424 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Junk (measured) None Cemented 188 Sx CS II Measured depth True vertical depth 112' 112' 1300 Sx PF "E" 4791' 3697' 330 Sx Class "C" 88 Sx PF "C" 575 Sx Class "G" 9574' 6844' sx RECEIVED & C~as Cons. Commissio Anchorage 9542' 7" 13. measured 9016'-9319' true vertical 6415'-6645' 14. Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth 2 7/8", J-55 , 9122' Packers and SSSV (type and measured depth) Packer: Camco HRP @ 8867' & Otis WD @ 9096', SSSV: Camco TRDP-1A-SSA @ 1819' Tubing 1200 90 1100 90 Stimulation or cement squeeze summary Refrac A Sands Intervals treated (measured) 9312'-9243' MD -RKB Treatment description including volumes used and final pressure Attached Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Service Pressure Prior to well operation Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X SUB IN 200 1 00 - 0 - 250 1 25 - 0 - Status of well classification as: Water Injector___ Oil ~t. Gas Suspended 16. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~nedForm 1'0-~404~R~v/~05/17/-89~(//'P'/4'2 Title Srl Operations Engineer t. ~ ARCO Alaska, Ine---~ ..... Sutmicllary of Atlantic Rlchfielcl Compal J:_ r=__ WELL ' IPBDT I F~ELD- DISTRICT- STATE · ~ . ~,'-~ I ~,_ <-,'_<,-~ I ~-~J C,~NTRACToR"- IOPERAT~ON AT REPORT TIME R=MARKS WELL SERVICE REPORT IDAYS I DATE t I ~,1~11~ E~- t~: ~---.. -~L~( ~7 / 1'~ ~ -4:~z? ?8 414- G~#. to* 15).8 · [-'-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I Signed/,'1 knot.I KUPARUK STIMULATION SUMMARY WELL: TUO ~) PERF$: MD · PERFS: HOLE ANGLE ~-PERFS: DATE: CONTRACTOR: COMPANY TYPE DENS ITY P HAS I N I~ EFF. PAD: 752. WHTPR: $9¥z- / ISlP: ..3j~,o / LEAK OFF: NOTES: ACTUAL VOLUME RATE PRESSURE STG/CUM MID ~ PROP. PROP. ANN. pI£SH ~ .J~ PR;SS. - -~.W..~ · OESIGN UOLUME STG/CUM : o.1.~_! ., ____1 ..__/ too / 700 ., '~? / 7't° ~o f'7~o zo //~z.c ~,-///~ ?~.. /___ /, , EFF. SLURRY: Zo'-/ EFF. PROP: FRRC 6RRO: ,%~f / TBG.FRIC: z.~ ~3 PERF FRIC: ~lCt / pOST LOS INTERVAL: FLUID TEMP: FLUID vise: 5 MIN. ~-q ~' · 15 MIN. Z%~'"/ _ ARCO Alaska, Inc. Date: September 20, 1989 Transmittal #: 7560 RETURN TO: ARCO Alaska, Inc. Attn: Madeline N. Rivera Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Q- 03 Kuparuk Fluid Level Report 9 - 7 - 8 9 Tubing 2 B-1 I Kuparuk Fluid Level Report 9-6-8 9 Tubing 2 B - 1 2 Kuparuk Fluid Level Report 9 - 8 - 8 9 Tubing 2 H - 1 6 Kuparuk Fluid Level Report 9 - 8 - 8 9 Tubing 3 C- 1 3 Kuparuk Fluid Level Report 9 - 5 - 8 9 Casing 3 H - 01 Kuparuk Fluid Level Report 9 - 5 - 8 9 Tubing Receipt Acknowledged' asa 0il & CoL C0¢[Q[t ..... Ah orage DISTRIBUTION' BP Chevron Unocal Mobil State of Alaska D&M STATE OF AI_ASKA 0 J~ ALASK~ OIL AND ~ CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska,, In(;;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1310' FNL, 1217' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1441' FSL, 1283' FEL, Sec. 13, T12N, R9E, UM At effective depth 1244' FSL, 1009' FEL, Sec. 13, T12N, R9E, UM At total depth 1203' FSL, 951' FEL, Sec. 13, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9594' feet Plugs (measured) 6864' feet None 6. Datum elevation (DF or KB) RKB 84' 7. Unit or Property name Kuparuk River Unit 8. Well number 3C-13 9. Permit number 85-198 10. APl number 50-029-21424 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured true vertical 9491' feet Junk (measured) 6781' feet None Casing Length Structural 8 0' Conductor Surface 4 75 9' Size Cemented 16" 188 Sx CS II 9 5/8" Intermediate Production Liner Perforation depth: 9542' measured 9016'-9319' true vertical 6415'-6645' ,1 Measured depth True vertical depth 112' 112' Tubing (size, grade, and measured depth 2 7/8", J-55 , 9122' Packers and SSSV (type and measured depth) Packer: Camco HRP @ 8867' & Otis WD @ 9096', SSSV: Cat~~P-1A-SSA ~ 1819' 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch 1300 Sx PF "E" 4791' 3697' 330 Sx Class "C" 88 Sx PF "C" 575 Sx Clas,,s, ',',G" 9574' 6~44' sx o _ RECEIVE ; R!CEIVE . ._ b,/ikY 2 6 19_.8 as cons C0mmissi0rl Alaska Oil & Gas Cons. Commissio~ Anchorage 14. Estimated date for commencing operation June 30, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned (~-.,~f //~ r/rd//~"~-~('~"~'~ Title ' ' F~ ~MI~N~ Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 0RIGIN~I -.qtqNED BY LONNIE C SMITH -,pp;oved Copy Returned Commissioner JApproval No. SUBMIT IN TRIPLICATE Well 3C-13 Permission to refracture Well 3C-13 in the A Sand is requested. This well was originally fractured in November, 1985, with 13,000 pounds of sand. The proposed refracture treatment calls for 70,000 pounds of sand and is designed to more effectively stimulate this interval. BHP is estimated to be 2400 psi. No workover fluids or BOP equipment will be needed during this job. Anchorage ARCO Alaska, In' Posl Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one sigqed copy of this transmittal. xx'J lB-2 ~ 1C-4 "~ 1H-4 "~ 1H-4- '"'J 1H-3 ----0 2F-5 "'--3 2C-9 -'"-J 2F-6 -"J3C-13 ~'-J3A-13 '"'~- 1L-2 "--o 1L-5 ~ IL-7. ~ 1L-1 ~ 1L-16 ~ 1E-4 ~ 1F-16 ~iF-10 ~ 1F-9 ~-lF-4 ~ lQ-9 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis)- KOE Buildup Analysis. KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Anaiysis KOE Falloff Analysis Kuparuk Well Pressure Report 6-10-87 6-~3-87 6-14-87 6-17-87 6-18-87 6-14-87 6-11-87 6-10-87 6-17-87 6-12-87 6-9-87 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS- 70043 7-14/17-87 100591H 7-15/19-87 6-10-87 Static 7-28-87 Static 'C' Sand 'C' Sand Both Sands Both Sands Both Sands Both Sands 'C' Sand Both Sands Both Sands 'C' Sand Both Sands 11-3-87 Static 'A' Sand Receipt Acknowledged: DISTRIBUTION: ,~la\~-'/ Al~U~<a 01;t & Gas cons. Commission Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlleldCompany ARCO Alaska. Post Office Box 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 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE 09-15-86 TRANSMITTAL # 5761 Please acknowledge receipt and Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-85 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85- Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04'85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 #1 3F-6 11-13-85 Run 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: S~e- 'o~ AK*~ Vault*films ~ NSK Files*bi AR~ All,kl. Inc. ~!, a Subaidiarv of AlllnticRichfleldComDlflY STATE OF ALASKA ' ALASKA talL AND GAS CONSERVATION CU~V~MISSION¢_"."U WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIt [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator " 7. Permit Number ARCO Alaska, Inc. ' 85-198 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21424 4. Location of well at surface 9. Unit or Lease Name 1310' FNL, 1217' FEL, Sec.14, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1441' FSL, 1283' FEL, Sec.13, T12N, R9E, UM 3C-13 At Total Depth 11. Field and Pool 1203' FSL, 951' FEL, Sec.1;3, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 85' RKBI ADL 25634 ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/17/85 10/27/85 10/29/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9594'MD,6864'TVD 9491 'MD,6781 'TVD YES E~X NO []I 1819 feet MD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR, RFT, CET, 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" 188 sx CS II 9-5/8" 36.0# J-55 Surf 4791' 12-1/4" 1300 sx PF "E" & 330 sx Class "G" Top job performed w/88 tx PF "C" 7" 26.0# J-55 Surf 9574' 8-1/2" 575 sx Class G & 200 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9199' - 9243' 2-7/8" 9122' 8867' & 9096' 9264' - 9276' w/4 spf, 90' phasing 9312' - 9319' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9016' - 9036' w/12 spf, 120° phasing N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Tubing was run and the well perforated 11/6/85. DAM/WC55 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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 8949' 6367' DEPTH HYDRO.PRESS. SHUT-IN PRESS. Base Kuparuk C 9028' 6425' 9204.6' 3404 psi -- Top Kuparuk A 9188' 6544' 9025.4' 3400 psi 3177 psi Base Kuparuk A 9338' 6660' 9201.6' 3488 psi -- 9201.6' 3483 psi 9202.5' 3479 psi 3237 psi 9212.5' 3479 psi -- 9212.3' 3463 psi -- 9219.1' 3463 psi 3250 psi 9222' 3468 psi 3031 psi 9223' 3468 psi 3031 psi 9236' 3475 psi -- 9234.1' 3469 psi 3079 psi 9267.9 3491 psi 3298 psi 9314' 3518 psi 9315' 3514 psi 3591 psi 9315' 3510 psi 3540 psi 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~~)~/ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Bo,, ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-13 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for 3C-13. If you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU13/L65 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '"--' STATE OF ALASKA ~--, ~ ALASKAC ,AND GAS CONSERVATION CO, ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL J-)(Ix GAS I--J SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-198 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21424 4. Location of well at surface 9. Unit or Lease Name 1310' FNL, 1217' FEL, Sec.14, T12N, R9E, UM -[~f-~;AI'IONS Kuparuk River Unit At Top Producing Interval ~ -V[i~'lFl~\ / 10. Well Number 1441' FSL, 1283' FEL, Sec.13, T12N, R9E, UM J,$uri.~ 3C-13 At Total Depth JB. H.~ 11. Field and Pool 1203' FSL~ 951' FEL~ Sec.13~ T12N~ R9E~ UM~ Kuparuk R~ver Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk R~ver 011 Pool 85~ RKB ADL 2563~ ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 16. No. of Completions 10/17/85 10/27/85 10/29/85* N/A feet MSLJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19. Directional Survey 20. Depth where SSSV set J 21. Thickness of Permafrost 9594 'MD ,6864 'TVD 9491 'MD,6781 'TVD YES ~ NO ~ 1819 feet MDJ 1700' (approx) 22. Type Electric or Other Logs Run DIL/CR/SP/SFL~ FDC/CNL~ Ca]~ GR~ RFT~ CET~ 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" 188 sx CS II 9-5/8" 36.0~ J-55 Surf 4791' 12-1/4" 1300 sx PF "E" & 330 sx Class "G" Top job performed w/88 ~x PF "C" 7" 26.0~ J-55 Surf 9574' 8-1/2" 575 sx Class G & 200 sx PF "C" : 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9199' - 92~3~ 2-7/8" 9122' 8867' & 9096' 926~' - 9276' w/fi spf, 90' phasing 9312' - 9319~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED 9016' - 9036' w/12 spf, 120° phasing 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 CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITy-APl (corr} Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~'? ;' ~ ~. ; .~.... , , ~;.;.' .. -~,.,..~ Form 10407 * NOTE: Tubing was run and the well perforated 11/6/85. GRU13/WC01 Submit in duplicate Rev. 7-1430 CONTINUED ON REVERSE SIDE 29. I~ 30. ~ ' . · GEOLOGIC MARKERS -. FORMATi(~N TESTS. , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. RFT to be submitted when received. Top Kuparuk C 8949' 6367' Base Kuparuk C 9028' 6425' Top Kuparuk A 9188' 6544' Base Kuparuk A 9338' 6660' 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 (~~ .~,L~w~,~ Title Associate Engineer Date ]%'~/'~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc..r~-~'. Post Office B .~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 3, 1986 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Al< 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells: 1R-8 2D-12 3C-13 3C-14 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L01 Enclosures RECEIVED J/'-'~["',.I 0 7 19~S 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlanflcRIchlieldCompany STATE OF ALASKA ---- ALASKA O,,- AND GAS CONSERVATION CO~ .,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 ~lumber ARCO A1 aska, I nc. 85-198 3. Address 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510 50- 029-21424 ,, , 4. Location of well at surface 9. Unit or Lease Name 1310' FNL, 1217' FEL, Sec.14, T12N, R9E, UM (approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 3C-1~ At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKBI ADL 25634 ALK 2567 · 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 10/17/85 10/27/85 10/29/85*I N/A feet MSLI 1 17. Total DePth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9594'MD 9491 'MD YES [~X NO []I 1819 feet MD 1700' (approx) , -- 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Ca1, GR, RFT, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112' 24" 188 sx CS I I 9-5/8" 36.0~' J-55 Surf 4791' 12-1/4" 1300 sx PF "E" & 330 sx;Class "G" Top job performed w/88 ~x PF "C" 7" 26.0# J-55 Surf 9574' 8-1/2" 575 sx Class G & 200 sx PF "C" , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) · 9199' - 9243' 2-7/8" 9122' 8867' & 9096' 9264' - 9276' w/4 spf, 90' phasing 9312' - 9319' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9016' - 9036' w/12 spf, 120° phasing See attached Addendum, dated 12/11/85, for frac data. 27. N/~, PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cRoKESIZE IGAS-OILRATIO TEST PERIOD ~ I Fl°w Tubing Casing Pressure CALCULATED oIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.i 24-HOUR RATE I~ 28. COP E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . , , . Form 10~07 * NOTE: Tubing was run and the well perforated 11/6/85. GRU12/WC16 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .30. . GEOLOGIC MARKERS ' FORMATI'ON'TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS; DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted w~ ;n gyro is received. 'RFT to be submitted when received. . 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Associate Engi neet Date /~'~'~/"~--~' ///- - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If n° cores taken, indicate "none". ADDENDUM WELL: 10/30/85 10/31/85 lt/27/85 3C-13 Arctic Pak w/200 sx PF "C". Rn CET log f/9474'-7075'. Rn GCT gyro f/9423'-surf. Frac well w/total of 350 bbls diesel, 1000# 100 mesh & 11,718# 20/40 sand @ avg rate of 17 BPM, 5300 psi. Drill~ntendent Date · , ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date; 12-19-85 Transmittal No: 5481 A RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. BOX 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Final Prints/ Schl/ One * of each 2A-8~5'' DIL/SFL-GR ~'-%~2" DIL/SFL-GR ~5" Den/Neu %~2" Den/Neu ~5" Den/Neu '~2" Den/Neu ~.Cyberlook 1G-29-85 Run #1 10-29-85 Run #1 (poro) 10-29-85 Run #1 (poro) 10- 29-85 Run #1 (raw) 10-29-85 Run #1 (raw) 10-29-85 Run #1 10-29-85 Run #1 3407-8492 3407~8492 3407-8466 3407-8466 3407-8466 3407-8466 7850-8443 2~-12v~'%5'' DIL/SFL-GR '~-~2" DIL/SFL-GR 5" /N Den eu 2" Den/Neu -~5" Den/Neu ~2" Den/Neu ~ ~Cyberlook 11-07-85 Run #1 11-07-85 Run #1 (poro) 11-07-85 ~un #1 (poro) 11-07-85 Run #1 (raw) 11-07-85 Run #1 (raw) 11-07-85 Run #1 11-07-85 Run #1 3c-1~ ~5" DIL/SFL-GR 10-26-85 Run #1 ~2" DIL/SFL-~R 10-26-85 Run #1 ~5" Den/Neu (poro) 10-26-85 Run #1 ~2" Den/Neu (poro) 10-26-85 Run #1 ~5" Den/Neu (raw) 18-26-85 Run #1 ~ 2" Den/Ne.u (raw) 10-26-85 Run #1 '~ Cyberlook 10-2-7-85 Run #1 2743-6829 2743-6829 5500-6803 5500-~803 ~500-6803 5500-6803 6300-6780 2698-9420 2698-9420 8750-9394 8750-9394 8750-9394 ~ 9024-9315 ...... ~'~A~- ?3/;~ska Oil & Cas ~,,~. Receipt Acknowledged: State of AK *bl/se Rathmell *bl NSK Clerk *bl Drilling *bl Vault *Films DeGloyer & MacNaughton *bl Date: ~,Rt"C~ alaska Inc ~s a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ? Post Office Be,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-13 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 3C-13. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is run. If you have any questions, please call me at 263-4944. Si ncerely, . Gruber Associate Engineer JG/tw GRU12/L116 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , "-' STATE OF ALASKA --~ ALASKA ~.. .AND GAS CONSERVATION CO. .,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. 85-198 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21/+2/+ 4. Location of well at surface 9. Unit or Lease Name 1310' FNL, 1217' FEL, Sec.14, T12N, RgE, UI4 (approx.) Kuparuk River Unit At Top ProduCing Interval 10. Well Number To be submitted when gyro is received. 3C-13 At Total Depth 11 Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25634 ALK 2567 12. Date SPudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/17/85 10/27/85 10/29/85* N/A feet MS LI 1 17. Total Depth (M D+TV D) 9594 ' MD 18. Plug Back Depth (MD+TVD)9491 'MD YEsl 9. Directional SurveYD~ NO [] I20' Depth where sssv set1819 feet MD [ 21. Thickness of Permafrost1700, (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR, RFT, CET, 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" 188 sx CS II 9-5/8" 36.0# J-55 Surf 4791' 12-1/4" 1300 sx PF "E" & 330 sx Class "G" Top job performed w/88 ,, x PF "C" 7" 26.0# J-55 Surf 9574' 8-1/2" 575 sx Class G & 200 sx PF "C" ,_ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9199' - 9243' 2-7/8" 9122' 8867' & 90~)~' 926/+' - 9276' w/4 spf, 90' phasing 9312' - 9319' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9016' - 9036' w/12 spf, 120° phasing N/A --, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested !PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 124-HOUR RATE ~1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10~07 * NOTE: Tubing was run and the well perforated 11/6/85. TEMP3/iVC05 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. '~ GEOLOGIC MARKERS -' ' FORMATION TESTS' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wh.~n gyro is recei ~ed. RFT to be submitted when received. 31. LIST OF ATTACHMENTS Well History (drilling & completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge t~ ~. '~~.__ Title ASsoci ate Engi neeF Date /Z-/~-8~' Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water in- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oil and Gas Company Well History- Initial Report - Daily Inatrtlction·: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operation· are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska_ Field Huparuk River Auth. or W,O. no. AFE 604925 ~abor8 26E.~ Operator ARCO Alaska, Spudded or W.O. begun Spudded Date and depth aa of 8:00 a.m. lo/19/85 thru 10/21/85 The above is correct 10/22/85 10/23/85 10/24/85 For form preparation and distribu~n, see Procedures Manual, Section 1~, Drilling, Pages 86 and 87. [Count~. parish or borough North Slope Borough Leaes or Unit ADL 25634 JTitle Drill AMI 50-029-21425 IDle 10/17/85 ]Hour IState Complete record for each day reported 2230 hrs. IARCO W.I. Prior status if a W.O. i6" ~ 112' 850', (738'), Navi-Drl Wt. 8.8, PV 13, YP 30, PH 10, WL 14.6, Sol 4 Accept rig @ 1630 hfs, 10/17/85. NU diverter sys. 2230 hfs, 10/17/85 Drl to 500' Navi-Drl to 850' · · · Spud well @ 16" @ 112' 4811', (3961'), Cmt'g 9-5/8" Wt. 9.5· PV 27, YP 27, PH 10, WL 8.4, $ol 10 ND to 2047', POOH f/washout, ND f/2047'-4881', wiper trip, circ, POOH. RU & rn 121 its, 9-5/8", 36#, HF/ERW, J-55, BTC csg w/FC @ 4710', FS @ 4791'. Circ & start to cmt. 604', 3.2°, S62.8E, 6039 TVD, 3.6 VS, S6.0, El.2 1145', 18.8°, S71.8E, 1133.1TVD, 107.3 VS, S41.6, E99.0 1519', 26.0", S62.8E, 1479.7 TVD, 246.9 VS, S97.6, E227.0 2184', 47.1°, S59.8E, 2015.2 TVD, 634.4 VS, S280.2, E569.2 2719', 49.6", S62.8E, 2353.8 TVD, 1048.2 VS, S469.1, E937.7 3035', 46.3", S59.8E, 2565.4 TVD, 1282.4 VS, S581.7, El143.4 3887', 50.8", S61.8E, 3151.1TVD, 1899.2 VS, S883.8, E1682.9 4300' 53.6° S63.SE, 3399.6 TBD, 2228.8 VS, S1032.1, E1977 4 4731' 54.4* S63.8E, 3652.4 'r~, 2577 8 vs, s1186.2, E2290 6 · · · · 9-5/8" @ 4791' 4944', (133'), Navi-Drl Wt. 8.9, PV 4, YP 3, PH 10.5· WL 18.6, Sol 4 Cmt 9-5/8" w/100 sx PF "E" w/10#/sx Gilsonite & 1200 sx PF "E" w/5#/sx Gilsomite & 330 sx C1 "G" w/2% salt & .75% CFR-2. FS @ 4791', FC @ 4710'. Displ using rig pmps, bump plug. CIP @ 1130 hrs, 10/21/85. NU BOPE &tst. TIE, tst csg to 2000 psi. Drl to 4821'. Conduct formation tst to 12.5 ppg EMW. Navi-Drl to 4944'. Alaska Well no. 3C-13 56.24% 9-5/8" @ 4791' 7244', (2300'), Navi-Drl Wt. 9.3, PV 12, YP 9, PH 10.5· WL 10, Sol 6 Navi-Drl 8½" hole to.7244'. 4924', 53.5", S63.8E, 3766 TVD, 2733.8 VS, 1255.1S, 2430.6E 5708'· 51.3", S64.8E, 4233 TVD, 3363.4 VS, 1530.2S, 2997E 6305', 51.3°, S65.8E, 4601.7 TVD, 3832.9 VS, 1729.3S, 3422.1E 6906', 49.6°, 565.8E, 4983.3 CVD, 4297.2 VS, 1919.7S, 3845.7E 9-5/8" @ 4791' 8398', (1154'), Nevi Drl'g Wt. 9.3, PV 14, YP 10, PH 10.0, WL 5.6 Sol 5 Nevi drl f/7244'-7313', POOH, LD Nevi drl. PU new Nevi drl & dmp vlv. Orient Navi Dril w/MWD. TIH, drl f/7313'-8398'. 7228' 49~ S65.SE, 5193.3 TVD, 4541.2 VS, S2019.7 E4068.3 , · 7626' 47.8° S64.8E, 5457 5 TVD, 4838 VS S2144.0, E4338 7 · · · · · 8126', 48.2°, S64.8E, 5792.1TVD, 5210.4 VS, S2302.3, E4674.9~i~/./~ · / ~ - 4 -~ Drilling Superintenden~'!~ ' .... '.,.:..?$ , ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska Field ~bease or Unit Kuparuk River I ADL 25634 Auth. or W.O. no. ~Title AFE 604925 I Drill Nabors 26E API 50-029-21425 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Oate Spudded I 10/17/85 lO/25/85 10/26/85 thru 1o128185 Date and depth as of 8:00 a.m. Complete record for each day reported Accounting cost center code Stale North Slope Borough Alaska Iotal number of wells (active or inactive) on this i cst center prior to plugging and ~ bandonment of this well 1 our I Prior status if a W.O. I 2230 hrs. 9-5/8" @ 4791' 8967', (569'), Navi Drl'g Wt. 10.0, PV 12, YP 9, PH 10.0, WL 5.0, Sol 6 Drl to 8713', Navi-Drl to 8967'. 8549', 46.5°, S63.8E, 6078.6 TVD, 5521.5 VS, 2437.2S, 4955.3E 9-5/8" @ 4791' 9594' TD, (627'), Rn'g 7" csg Wt. 10.1, PV 11, YP 6, PH 10.0, WL 5.0, Sol 7 Navi-Drl to 9440', 25 std short trip, CBU, POOH. RU Schl, rn DIL/GR/SP/SFL f/9428'-4793', GR F/4793-2000'. Log FDC/CNL f/9428'-8750'. Rn CAL f/9428'-7400'. TIH to 4791', C&C, POOH. Rn RFT w/9 out of 16 RFT's good. RD Schl. TIH, rm 9318'-9440', drl to 9574', C&C, POOH, LD DP. Chg top rams to 7", tst to 3000 psi. RU GBR & begin rn'g 223 its, 7", 26#, J-55 BTC csg. FS @ 9574', FC @ 9491'. 9159', 41°, S56.8E, 6519.1TVD, 5941.6 VS, 2646.0S, 5321.3E 9355', 38.2°, S51.8E, 6670.1TVD, 6064.4 VS, 2718.8S, 5422.7E 10/29/85 7" @ 9574' 10.0 ppg NaBr/NaC1 Fin rn'g 7" csg. Cmt~sx Class "G" cmt & 500 sx tail "G" cmt. Displ w/10.0j~g brine, bump plug. CIP @ 1700 hrs, 10/28/85. Good-~s & recip thru entire j~-~. N~~~U & tst tree to 3000 psi. RR @ 0400 hrs, 10/29/85. Old TD I New TD PB Depth I 9594' TD (10/27/85) 9491' PBTD Released rig I Date K nd of r g 0400 hrs. I 10/29/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected i The above is correct Well no. 3C-13 Signature Date ITitle Ze2zf ~ For form preparation and distril:~tion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the '.'Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an 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 available. I Accounting District I(~ounty or Parish ] Slate Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25634 Auth. or W.O. no. ~Title AFE 604925- I Completion Nordic 1 API 50-029-21425 cOSt center code Alaska Well no. 3C-13 Operator [ A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Complete I 11/4/85 I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our I Prlor status If a W.O, I 0600 hrs. Date and depth as of 8:00 a.m. 11/05/85 11/06/85 11/07/85 Complete record for each day reported 7" @ 9574' 9491' PBTD, TOH to perf 10.1 ppg NaC1/NaBr Accept rig @ 0600 hfs, 11/4/85. ND tree, NU & tst BOPE. TIH w/6-1/8" bit & 7" csg scrprs to 9489', rev circ hole & filter brine, TOH. 7" @ 9574' 10.1 ppg NaCl/NaBr Fin TOH. RU Schl, perf w/5" guns, 12 SPF, 120° phasing f/9016'-9036'. Perf w/4" gun, 4 SPF, 90° phasing f/9199'-9243', 9264'-9276' & 9312'-9319'. Rn gauge ring & JB to 9175'. RIH, set 7" WD pkr @ 9096'. Rn 292 jts, 2-7/8", 6.5#, J-55 8RD EUE, IPC tbg & ind. Tst SSSV; OK. Set BPV. BOPE, NU tree & tst to 300/5000 psi. (Note: WD pkr @ 9096' @ 9114', TT @ 9122', SSSV @ 1819' ~ HRP pkr @ 8867'.) 7" @ 9574' 9480' WLM PBTD, RR Diesel Tst tree to 5000 psi. 0930 hrs, 11/6/85. Displ well to diesel. Set BPV. RR @ ND , "D" Nipple Old TO Released rig 0930 hrs. New TD Date 11/6/85 IPB Depth Kind of rig 9491' PBTD Rotary Classifications {oil, gas, etc.) Oii Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test? ~ ~ Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ;~.. =. ,E?ective date corrected ,~ % Oil ~I ..... The above is correct ~,. ~ ' Signature ' ' ' ': ~: d //-~0-~ Drilling Superintendent For form preparation and distribu~n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. SUB. SURFACE DIRECTIONAL SURVEY L-'~ UIDANCE ~ONTINUOU5 ~OOL Coml~any' Well Name Fleld/l.~¢atlon ARCO ALASKA INCORPORATED 3C-13 (1310' FNL, 1217' FEL, S14, T12N, R9E) KUPARUK, NORTH SLOPE, ALASKA [6-JAN-86 CUDNEY ~ SCHLUMbERgER ~ GCT DIRECTI2NAL SURVEY CUSTOMER LISTINS FOR ARC] &L&SKA, INC. 3C-13 KUP~RUK NCRTH SLOPE,ALASKA SURCEY SATE: 30-0CT-85 ~ETHODS OF CDMPUT&TiO'~ TgOL L2C~TI]N: T2NSENTZ~L- I'~T~PO~ATI]N: LINEAR V:~TIC~L SECTZgq: qO~IZ. DIST. ENGINEER: P:PPEL AVERAGE] PROJECTED DEVIATION ~NO ,2NTO ~ T~RGET ~ZIMUTH AZIMUTH OF SO U T'.i .,S~ DES 44 MIN EAST cg~PUT4TIDN DARE: 16-J~N-85 INTE~POL~TED VALJES FOR EVEN 100 FEET OF TRUE SUB-SEA E~SURED VERTICAL VERTICAL 3EPTH DEPTH OEPFH 0.00 0.00 -85.00 100.00 100.00 15.00 ZO0.O0 ZO0.O0 115.00 300.00 300.00 215.00 ~OO.O0 ~00.00 315.00 500.00 499.99 414.99 500.00 599.34 51~.94 700.00, 699.58 '51~.68 800.00 798.91 713.91 900.00 897.18 812.18 1000.39 99~.60 909.60 llO0.O0 1090.69 1005.69 1200.00 1135.61 110~.61 1300.00 1279.84 1194.84 1~00.00 1372.75 1287.75 1500.00 1463.89 1378.89 1500.00 1553.25 1468.25 1700.00 1640.30 1553.30 1300.00 1724.55 1539.65 1900.00 1806.06 1721.06 20~0.00 1883.81 1798.81 2100.00 1958.79 1873.49 2200.00 2028.02 1943.02 2300.00 Z0~3.04 2008.04 2~D0.92 Z154.11 206~.11 2300.00 2214.37 Z129.37 2600.00 Z274.51 2189.61 2700.00 2337.33 2252.03 2~00.03 2402.31 2317.31 2~30.00 2~59.58 2384.68 COJRS= VERTICAL DOGLEG DE¥IATION AZIMUTH SECTION SEVERITY O'EG:MIN DEG MI~ FEET OEG/IO0 0 ,0 N 3 ~ E 0.00 0.00 0 5 S 21 22 W 0.02 0.23 0 6 S 22 8 E 0.08 0.05 0 12 S 31 4~ ~ 0.30 0.13 0 26 S 41 4~ E 0.77 0.32 0 59 S 54 43 ~ 1.84 0.81 2 58 S 63 1T E 4.76 3.30 5 11 S 63 33 E 11.83 2.73 9 3 S 70 13 E 24.02 3.97 11 ~6 S 71 ~+ E 42.38 2.54 14 28 S 71 19 E 64.79 3.53 17 20 S 71 50 E 92.23 2.72 18 52 S 71 1 E 123.45 1.12 20 34 S 67 33 E 156.79 2.42 23 2 S 64 52 E 193.72 3.06 25 19 S 6.3 30 E 23~.85 2.2~ 28 3 S 63 35 5 279.70 30 54 S ~4 20 E 328.87 3.12 33 .~7 S 62 34 E 382.55 3.1~ 37 10 5 60 30 E 440.47 3.69 40 22 S 60 30 E 503.12 2.31 43 '46 S 51 28 E 569.46 47 37 S 50 35 E 641.16 2.9~ 51 16 S 62 9 E 716.93 3.87 52 ~5 S 53 '~4 E 796.09 0.34 53 3 S 63 Zi F_ 875.88 0.79 52 2(3 S 52 15 E 955.65 1.73 50 5 S 52 57 E ~033.69 2.31 48 29 S 52 58 ~ 1109,41 1.78 47 3 S 52 2 5 1183.25 0.76 46 20 S 51 25 E 1255.94 0.73 ~5 35 S 50 59 E 1327.72 0.85 44 59 S 60 23 E 1398.57 0.64 44 ~3 S 60 5 E 1468.88 0.52 44 10 S 60 34 E 1538.69 0.49 44 31 S 60 45 5 1608.26 0.67 4~ 53 S $0 32 c 1678.35 1.57 46 30 S 52 6 ~ 1749.94 1.19 47 53 S 62 1~ E 1822.96 Z.96 50 30 S ~2 13 ~ 1~9~.75 1.35 3000.00 2538.23 2453.23 3100.00 Z607.72 2522.72 32~0.00 2678.12 2593.12 3300.00 2749.01 265~.01 3500.00 2820.&0 2735.40 3500.0'] 2892.07 2507.07 3500.00 2963.22 2378.22 3790.33 3032.~1 2947.91 3BOO.OO 3101.17 3015.17 3900.00 3166.2~ 3081.28 PAGE D&TE DF SJRVEY: 33-0CT-85 KELLY BUSHING ELEVATIQN: ENGINEER: PEPPEL 85.00 MEASURED DEPTH RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FEET FEET H3R DI FEE DEPARTURE ~ZI~UTH G MIN O.O0 N 0.00 ~ 0.00 S 0.02 E 0.08 S 0.05 E 0.33 S 0.18 E 0.72 S 0.51 E 1.46 S 1.34 E 2.99 S 3.85 E 5.70 S 10.40 E 10,00 S 21.84 E 16.07 S 39.28 E 23.42 S 60.59 E 32.14 S 86.81 E 42.02 S 116.58 E 53.69 S 148.03 E 68.55 S 181.86 E 86.55 S 218.84 E 106.71 S 258.92 E 128.13 S 303.19 E 151.94 S 351.31 E 179.72 S 402.25 E 64.96 S 68 51 E 92.57 S 69 41 E 124.01 S 70 11 E 157.47 S 70 3 E 194.35 S 69 20 E 235.34 S 58 25 E 280.05 S 57 36 E 329.15 S 67 5 E 382.75 S 66 36 E ~40.57 S 65 55 E 210.98 S 456.77 E 503.14 243.07 S 514.98 E 569.46 277.77 S 577.88 E 541.17 314.50 S 644.29 E 716.99 350.16 S 715.04 E 795.18 385.56 S' 786.56 E 875.97 ~22.07 S 857.5~ E 955.78 ~58.30 S 925.73 E 1033.86 492.46 S 994,34 E 1109.61 526.51 S 1059.9l E 1183.49 S 65 lZ E S 64 43 E S 6~ 19 E S 63 58 E S 63 54 E S 63 53 c S 63 47 ) s 63 41 S 63 39 E S 63 35 E 561.02 S 1124.01 E 1256.24 595.58 S 1167.03 E 1328.10 530.38 S 1248.99 E 139'9.06 665.~2 S 1310.20 E 1469.49 700.15 S 1371.01 E 1539.43 734.27 S 1431.83 E 1509.12 768.60 S 1493.13 E 1679.34 802.84 S 1556.14 E 1751.03 836.70 S 1520.90 E 1824.11 872.12 S 1687.99 E 1899.97 S 63 S 63 S 63 S 63 S 62 S 62 S 62 S 62 S 62 S 62 28 21 13 4 56 51 45 42 41 4O O, 0 0 E 0'0 15 59 E 0*09, ,,'S' 35 31 E 0-38 :S 28 35 E 0.88 S. 35 30 E 1.99 .S 42 34 4.87 S 52 11 11.85 2~.02 S AqC3 ALASKA, INC. 3~-1.3 N3RTH SL3PE,AL&SKA COMPUTATION DATE: 16-J~N-85 PAGE DATE DF SURCEY: 30-0'T-85 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 85.00 FT D-_- 400 410 420 450 450 470 4)0 593 510 520 530 5%0 550 550 5?3 530 590 500 610 oZO 630 5%3 650 650 570 5~0 730 710 720 730 7%9 753 750 7.30 793 INTERPOLATED VALUES FOR EVEN 100 TRUE SUB-SEA ' U2E3 VERTZC~L VE~TI"AL. DE¥IATION PTH DEPTrt DEPTH 'D~G: MIN 0.00 3228.91 3143.91 52 15 0.00 3288.78 3203.78 53 33 0.00 3348.36 3263.36 53 13 0.33 3408.19 3323.19 53 21 0.00 3~67.75 3382.75 53 33 O.OO 3527.02 3442.02 53 47 0.33 3535.83 3500.~3 54 7 0.00 3644.21 3559.21 54 23 0.03 3702.53 3517.53 54 0 0.03 3761.83 3676.83 53 28 3.03 3821.%2 3735.~2 53 27 0.00 3883.51 3795.81 53 ~9 O.OO 3939.39 3854.39 54 25 0.00 3997.20 3912.20 54 ~9 0.~3 ~054.74 3969.74 54 57 O.OO ~112.35 ~027.05 55 7 3.00 4169.24 ~084,24 54 59 0.00 ~228.01 4143.01 52 18 0.00 ~290.39 ~205.39 51 23 O.DO ~352.58 ~267.58 51 39 FEET OF MEASURED DEPTH COURSE VERTICAL DOGLEG RECTAN AZIMUTq SECTION SEVERITY NORTH/ DEG MIN FEET DE~/IO0 FEE S 62 55 E 1976.65 S 63 25 E Z056.72 S 63 27 E 2137.01 S 63 39 E 2217.12 S 64 2 E 2297.44 S 64 10 E 2377.98 S 64 19 E 2~5B.85 S 54 36 5 15~0,04 S 5~ %1 E 2521.27 S 6~ 33 E 2701,79 3.03 4414.44 432~.44 51 56 0.00 %475.89 4390.89 52 13 0.00 4537.11 4452.11 52 16 0.~9 ~598.58 %513.58 51 35 0.00 ~551.25 ~575,25 50 ~4 O.OO 4725.31 4540.31 4~ 56 3.00 ~789.%4 470~.44 50 16 O.O0 ~53.03 4768.03 50 38 O.O0 4917.08 4832.08 49 27 0.33 498Z.30 %897.30 49 25 O.OO 5047.18 ~952.15 49 37 0.03 5112.40 5027.40 48 55 0.00 5178.18 5093.1~ 48 52 0.00 5243.~5 5158.95 48 56 0.03 5309.52 521~.62 48 34 0.93 5376.37 5291.37 47 58 0.00 5443.~8 5358.45 47 %0 0.00 5510.)4 5425.34 47 2~ 0.33 557B.63 5493.63 47 17 O.O0 5546.55 5561.65 47 1 S 64 45 E S 65 2 E S 65 5 E S 65 25 S 55 2 E S 64 58 E S $4 53 E S 65 9 = S 55 13 E S 55 15 E S 55 15 E S 65 11 E S 55 15 E S 65 42 E S 65 10 E S 66 32 E S 66 22 E S 66 1Z E S 66 Z~ E S 55 17 E 2782.10 2862,55 !943.60 3025.19 3'106.97 3188,92 3273.95 3351.83 3429.99 3508.29 3535.86 3665.76 3744.82 3823.59 3901.5~ 3978.34 ~055.04 ~132.19 ~208.94 %284.72 2.76 908, 0.43 944. 0.55 980. 0,3~ 1015. 0.41 1051. 0.48 1086. 0.39 1121. 0.51 1156. 1.22 1191. 0.22 1225. S 55 13 E S 65 39 E S 65 23 E S 65 17 E S 55 2 E S 65 2.5 E S 55 i3 E S 55 5 = S 64 5~+ E S 64 42 E 0.24 1260. O.TB 1294. 0.55 1328. 0.16 1362. 0.18 1397. 0.18 1431. 0.41 1~66. 3.49 1500. 0.30 1533. 0.25 1566. 0.29 1599. 0.36 1632. 0.15 1565. 1,2~ 1598, 1.45 1730. 0.44 1760. 0.48' 1791. 0.17 1~22. 1.03 1853. 0.39 1883. ~350.79 0.24 1914. ~436.55 0.47 1944. ~511.84 0.16 1974. ~587.14 0.32 2004. ~562.52 1.39 2035. %736.98 0.23 2065. ~81!.10 0.34 2396. ~884.92 0.26 2127. %958.53 .0.42 2158. 5031.83 0,26 2190. GULAR CDDRDINATES H3R'[ IEPARTURE SOUTri EAST/WEST DIS tZ, I M'UT H T FEET FEE, G MIN 18 S 1757.10 E 1977. 2 40 E 16 S 1828 66 E 2058 O/ 2 41 E O1 S 1900.53 E 2138.3,2 ' 2 43 E 75 S 1972.25 E 2218.451' :S'62 45 E 15 S 2044.35 E 2298.76 $" 62 47 E 28 S 2116.83 E 2379.28 S 62 50 F 42 S 2189.6'7 E 2~,60.13 S 62 52 L ) 4~, S 2262.92 E 2541.29 S 62 55 E 12 S 2336.38 E 2522.49 S 62 59 E ?0 S 2409.09 E 2702.9? S 63 2 E 10 S 2481.67 E 2783.26 S 63 4 E 21 S 2554.53 E 2863.,67 S 63 7 E 35 S 2628.03 E 2944.67 S 63 11 E 76 S 2702.01 E 3026.21 S 63 14 E 26 S 2776.17 E 3107.96 S 63 17 E 86 S 2850.45 E 3189.88 S 63 19 E 66 S 2924.74 E 3271.88 S 63 22 E 82 S 2998.05 E 3352.73 S 53 24 E 60 S 3069.01 E 3~,30.85 S 63 26 E %0 S 3140.11 E 3509.12 S 63 29 E 26 S 3211.68 E 3587.55 S 63 31 E 32 S 3283.12 E 3566.51 S 63 33 E ~8 S 3354.89 ~ 3745.55 S 63 35 ; 25 S 342b.54 E 3~24.38 S 63 38 E 04 S 3497.78 E 3902.24 S 63 40 E 73 S 3568.16 E 3978.94 S 63 44 F 36 S 3638.52 E 4055.59 S 63 47 L 41 S 3709.17 E 4132.69 S 63 50 E 27 S 3779.48 E 4209.41 S 63 52 E 65 S 3848.9~ E 4285,14 S 63 55 E 34 S 3918.57 E 4361.18 S 63 57 E 59 S 3988.07 E 4~36.91 S 64 0 E 59 S 4057.17 E 4512.16 S 64 2 E 82 S 4126.16 E 4587.43 S 64 5 E 18 S 4195.19 E 4562.78 S 64 7 E 85 S 4263,04 E 4?37.22 S 64 8 E 80 S 4330.40 E 4811.34 S 64 9 E 81 S 439?.39 E 4885,14 S 54 10 E 91 S 4464,11 E 4958.?5 S 64 11 E 13 S 4530.43 E 5032.04 S 6~ 11 E kRCO A~.ASKA, INC. ~C-13 ~3RTH SLOPE~AL&SKA COMPUT.~TION D&TE: 16-J~N-86 DATE DF SURVEY: '30-g=T-B5 KELLY BUSHING ELEVATI2N: ENGINEER: PEPPEL 85.00 FT ., iNTERPOLATEg VALUES ~gR EVEN 100 FEET OF TRUE S3B-SEA :&SURED VERTICAL V~RTICAL DEPTH DEPT4 DEPTH 3000.30 5714.75 5~29.78 ~100.90 5782.16 5597.16 ~300.00 5849.13 576~.13 ~300,00 ~916.11 5831,11 ~40~.90 5'983.43 589~.43 3590.00 6051.~ 5955.48 ~500.00 5120.32 5035.32 3700.00 5189.39 5104,39 ~O0.OO 5239~05 517~.05 ~900.03 6330.74 52~5,74 9330.93 5404.00 5319.00 9100.00 5478.00 5393.00 9200.00 6553.39 5~68.39' 9300.00 6630.14 5545.14 ~00.00 6708.33 5623.53 9500.00 57~8.5~ 5703.68 9594.03 5364.13 5779.13 MEASURED DEPTH CDJRSE VERTICAL DOGLEG RECTANSULAR DEVI~TIDN ~ZIMJTH SECTION SEVERITY NDRTH/SOUTH DEG MIN DEG MI~ FEET DE3/IO0 FEET 47 19 S 54 35 E 5105.04 0.75 47 ~9 S 54 33 ~ 517~.92 0.35 47 58 S 54 25 E 5253.19 0.31 47 5~ S 5~ 12 E 5327.44 0.40 47 2.~ S 64 1 E 5401.38 0.50 ~6 ~5 S 6~ 1 E 5474.64 0.87 46 21 S 6~ 8 E 5547.17 g.31 46 i8 S 64 lO E 5619.48 0,61 44 58 S 62 1~ E 5691.21 2.99 43 26 S 59 5 E 5'760.71 2.08 42 34 S 57 57 E 5828.35 0.52 41 ~2 S 57 27 E 5895.12 1.50 40 25 S 56 17 E 5960.21 1.7~ 39 14 S 5~ 55 ~ 5023.51 1.94 37 14 S 51 3 E 5084.39 5.37 36 37 $ 49 2~ E 514~.13 0.00 36 37 ~ 49 24 E 5195.21 0.00 2221.~1 S 2253.21 S 22B5.12 S 2317,28 S 2349.59 S 2581.57 S 2413.42 S 2~44.85 S 2~76,78 S 2511.06 S COORDINATES EAST/WEST FEET 2546.75 2552.69 2618.~4 2554,68 2591,51 2730.19 2766,57 · 45 46 47 47 48 49 49 50 51 51 96.62 E 63.31 E 30.37 E 97.30 E 63. B1 E 29.69 E 94.89 E 60.02 E 24.27 E 84.9~ E H3R.i DEPARTURE DI ~UTH FE~ G MIN 5105. 12 E 5253,~.0 '":":,.S 6¢ 12 E 5327,65 S' 64 13 ~ 5~01.59 $ 6~ 12 E 5~74,B7 $ 6~ 12 E $5~7.39 ~ 6~ 12 E ! 5519.71 S 64 12 E 5591,45 S 64 12 E 5760,99 S 66 9 E S 5242.89 E 5828.71 S 5299.76 E 5895.57 S 5354.87 E 5960.78 S 5407.76 E 6024.21 S 5457.69 E 6085.28 S 5503,28 E 6143.29 S 5545.86 E 6197.67 S 6~ 5 E S 64 1 E S 63 56 E' S 63 51 E S 63 44 E S 63 36 E S 63 29 E SO ALASKA, INC. -13 RTH SLOPE,AL&SKA TRUE ,SURED VERTIC&L ~EPTH DEPTH 0.00 O.O0 O0.OO 994,50 O0.OO 1883.81 00.09 2538.23 00.00 3228.91 00.03 3821.42 00.00 4414.~4 00.00 5047.18 O0.OO 5714.78 00.00 5404.00 ;94,00 6864,1.3 COMPUTATION DATE: 1,5-J~N-$6 INTERPOL&TED VALUES FOR EVEN 1000 FEET DF 3 JB-S EA CSUPSE VERTI"AL DEVIATION AZIMUTH DEPTH D,EG,,~IN OEG MI'~ VERTICAL DOGLEG SECTION .SEVERITY FEET DEGFIOD 0.00 D,O0 64.79 3.58 503.12 2.31 1255.94 0.73 1976,65 2,76 2782.10 0.24 3586.~6 0.29 4360.?9 0,24 5105.04 0.76 5828.35 0.52 -85.00 0 0 N 0 0 9o~.6o 14 'ZB s 71 19 179~.81 40 ',22 S 60 33 2453.23 46 20 S 51 25 3143.91 52 15 $ 62 55 3736.42 53 27 S 64 45 4329.44 51 56 S 65 15 4962.18 49 37 S 6~ ~ 5629.78 47 19 S 64 35 5319.00 42 34 S 57 57 5779.13 35 37 S 49 24 E MEASUR PAGE DATE DF SURVEY: 30-02T-85 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL BS.00 FT ED DEPT RECTANGULAR COORO NORTH/SOUTH EAST/ FEET FEET 0.00 N 0.0 23,42 S 60.5 210.98 S 456,7 561.02 S llZ4.0 908.18 S 1757.1 lZ60.10 S ~481.6 1599.26 S 3211.4 .1914.34 S 3918.5 2221.41 S 4596,6 2545.?5 S 5242.8 5196.21 0.00 2766. INATES' 0.00'. ,' ,.N '.;;~;~,~ 0 E 503.14 .S,~',6,:5 12 E 1256.24 S"~'63:28 E 1977.93 S'6~ ~0 E 2?83,26 $ 63 ~ E 3587.65 S 63 31 E 4361,18 S 63 57 E 5105.25 S 6~ 12 E 5828,71 S 67 S 5545.85 E 6197,57 S 63 29 E ,'.- 1 ~ UPARJK 3RTH SLOPE~AL~SKA COMPUTATION OATE: 16-JAN-86 INTERPOLATED VALUES FOR EVEN 100 FEET OF TRUE SJB-SEA &SURE9 VERTICAL VERTISAL DEPTH DEPTH DEPTH 0.00 0.00 -85.00 35.09 85.00 0.00 135.00 185.00 100.00 285.00 2~5.00 200.00 335.00 385.00 300.00 435.01 4~5.00 400.00 $~5.0~ 5~5.00 500.00 555.25 585.00 600.00 795.92 785.00 700.00 ~7.56 885.00 800.00 ~90.09 985.00 900.00 394.03 1085.00 1000.00 199.35 1185.00 1100.00 305.50 1285.00 1ZO0.O0 413.38 1385.00 1300.00 523.~2 1~85.00 1~00.00 535.11 1585.00 1500.00 752.57 1655.00 1800.00 ~73.6% 1785.00 1700.00 001.55 18~5.00 1800.00 :137.41 1985.00 1900.00 :187.26 2085.00 2000.00 !&51,15 2185,00 2100,00 :517.14 2265.00 2200.00 !773.7~ 2385.00 2300.00 !922.45 2~5.00 2400.00 ~367.~5 25~5.00 2530.00 ;209.72 2685.00 2500.00 ~350.55 2785.00 2700.00 ~90.10 2865.00 2803.00 ~530.8~ 2935.00 2900.00 ~T76.08 3085.00 3000.00 ~929.60 3185.00 3100.00 ~093.62 3285.00 3200.00 ~251.18 33~5.00 3300.00 ~29.08 3435.00 3~03.00 ;59~.58 3535.00 3500.00 ~759.98 3635.00 3600.00 ,~33.87 3735.00 3700.00 ~107.0~ 3835.00 3800.00 CDORSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MI~ FEET DES/lO0 0 2 4 8 11 0 0 N 0 0 E 0.00 ~.00 0 6 S lB 15 E 0.02 0.97 0 6 S 29 52 E 0.06 0.15 0 11 S 29 45 E 0.26 0.13 0 25 S 44 38 E 0.66 0.20 51 S 53 22 E 1.60 1.25 27 S 61 45 E ~.05 3.46 ¢8 S 68 32 E 10.55 2.41 29 S 70 D E 21.88 3.99 28 S 71 ~ E 39.89 2.28 14 17 18 ZO 23 25 29 32 36 40 7 S 71 13 E 62.37 3.50 11 S 71 50 E 90.44 2.86 52 S 71 2 E 123.24 1.11 ~1 S 57 %1 E 158.68 2.40 22 S 54 38 E 199.11 2.78 55 S 53 22 E 245.01 2.69 3 S 6~ 2 E 2~6.89 2.85 33 S 63 39 E 356.53 3.30 14 S 60 52 E 424.68 3.40 24 S 60 31 E 504.13 2.26 45 27 50 50 52 56 52 i2 48 53 46 54 45 51 44 55 44 26 44 ZB S 51 14 E 595.81 4.30 S 61 50 E 707.07 %.12 S 63 40 E 836.86 0.~9 S 62 9 f 9§9.27 2.22 S 63 8 E 1069.67 1.50 S 61 53 ~ 1199.65 0.87 S 61 6 5 1304.46 0,91 S 60 24 E 1405.41 0,53 S 60 16 f 1504.26 0.85 S 60 ~5 5 1501.35 0.68 45 28 47 15 50 56 53 34 53 17 53 36 :4 6 54 13 53 25 53 51 S 61 11 E 1700.15 2.21 S 62 24 E 1805.35 1.79 S 52 ZO E 1921.66 1.39 S 53 26 f 2051.58 0.42 S 53 31 E 2185.99 0.33 S 64 5 E 2320.85 0.19 S 6~ 19 E 2457.71 0.39 S 54 44 £ 2596.91 0.45 S 54 35 E 2733.01 0.15 S 65 3 E 2858.26 0.83 PAGE DATE OF SURVEY: 30-0CT-85 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 35.00 FT SUB-SEA DEPTH RECTANGULAR COORDINATES HOR NORTH/SOUTH EAST/WEST DI FEET FEET FEE 0.00 N 0.00 E 0.03 N 0.0,3 E 0.05 S 0.04 E 0.28 S 0.15 E 0.64 S 0.43 E 1.32 S 1.14 E 2.66 S 3.22 E 5.23 S 9.20 E 9.27 S 19.82 E 15.26 S 35.90 E 22.64 S 58.28 E 31.58 S 85.10 E 41.95 S 116.46 E 54.39 S 149.80 E 70.88 S 185.72 E 91.12 S 227,92 E 114.32 S 274.35 E 140.18 S 326.08 E 171.91 S 388.46 E 211.~,8 S 457.65 E ARTURE MUTH MIN O. 0'0' 0 E 0.06, 11 E 0.07~ ~;'.40 24 E 0.3Z '~il 328 Z7 E 0,77 ~ ¢ 12 E 1.75 S 40 48 E 4.18 S 50 24 E 10.58 S 60 23 E 21.88 S 64 56 E 39.93 S 67 31 E 62.52 S 68 46 f 90.77 S 69 38 E 123.80 S 70 11 E 159.37 S 70 2 E 199.72 S 6~ 12 E 245.46 S 68 12 E 297.21 S 67 22 E 356.78 S 66 51 E 424.80 .S 65 7 E 504.15 S 65 11 E 255.65 S 538.17 f 595.81 309.93 S 635.59 E 707.13 368.19 S 751.61 E 636.95 428.44 S 869.59 E 969.40 483.51 S 976.74 E 1089.86 534.25 S 1074.40 E 1199.90 584.39 S 1166.63 E 1304.82 633.77 S 1254.96 E 1405.91 583.12 S 1340.98 E 1504.95 730.88 S 1425.78 E 1602.2.0 S 54 35 E S 6~ 0 E S 53 54 E S 63 46 E S 63 39 E S 53 33 E S 63 23 E ) S 63 12 E S 63 0 E S 62 51 f S 62 44 E S 62 41 E S 62 40 E S 62 41 E S 62 44 E S 62 48 E S 62 52 E S 62 58 E S 63 3 E S 53 8 E 779.24 S 1512.21 E 1701.18 828.54 S 1605.27 E 1806.48 882,79 S 1708.28 E 1922,90 941.87 S 1824.06 E 2052.88 1001.90 S 1944.36 E 2187.31 1061.37 S 2065.41 E 2322.16 1120.92 S 2188.6~ E 2458.99 1180.74 S 2314.33 E 2598.13 1239.11 S 2437.29 E 2734.18 1296.61 S 2559.70 E 2869.37 CC~PUTATZ3~ ~CD ~L~SK~.~ !NC, '-13 JP6RUK ]RTH SLOPE,ALASKA ZNTERPoL&TED VALJES FOR ~SURE'3 )EPTH TRUE SUB-SEA V:RTIC~L VERTICAL DEPTt DEPTH OATE: 16-J6N-85 S27 [14 .32 3985,00 3900.00 .7~ 4085.00 4000.00 .53 4185.00 4103.00 .37 4235.00 ~200.00 .31 ~385.00 %300.00 .93 4~5.00 ~400.00 .15 ~5~5.00 ~500,00 .33 ~685.00 ~500.00 .05 4785.00 6700.00 .~1 ~885.00 %800.00 =YEN 100 ]58 !10 362 512 551 3O9 ~56 104 253 · 15 4955,00 %900,00 · 2~ 5085.00 5000.00 .37 5185.00 5100,00 .61 52~5.00 5200.00 · ~0 5385.00 5300.00 .58 5435.00 5403.00 .3~ 5555.00 5500.00 .20 5635.00 5600.00 .2~ 5?85.00 5700.00 .54 5855.00 5800.00 FEET D= SUB-SEA ~02 593 10 '9 241 370 594 .3Z 5935.00 5900.00 · 75 5085.00 5003.00 · 53 61~5.00 ~100.00 .50 5295.00 5200.00 · 20 6385,00 5300,00 .35 6435.00 5400.00 · 33 5585.00 5500.00 .27 66~$.00 6600.00 · ~1 57~5.00 5700,00 .00 5854.13 5779.13 COJRSE VERTICAL DOGLEG RECTAN DEVIATION AZIMUTH SECTION SEVERITY NORTH/ DEG MIN DEG MI'~ FEET DEG/IO0 FEE 54 ~6 S 55 2 E 55 2 S 65 1 E 54 %0 S 64 57 E 51 Z1 S 55 13 E 51 47 S 65 15 E 52 15 S 65 11 E 51 48 S 65 36 E 50 16 S 66 23 E 50 15 S 66 2~ E 50 11 S 66 18 E 49 26 S 65 17 E 49 13 S 66 31 E 48 51 S 66 22 E 48 54 S ,'55 1~ 5 47 57 S 65 2~ E 4,7 33 S 55 8 E 47 15 S 6~ 53 E 47 3 S 64 42 E 47 50 S 64 33 E 47 56 S 6~, 20 E 3007.87 3150.17 3Z93.49 3423.25 3549.35 3677.54 3805.57 3930.38 ~049.71 ~171.14 G287.87 ~405.06 4519.65 ~634.40 ~7~6.55 %855.58 &9~5.41 5072.91 5182.05 ~92.93 5403.09 5510.05 5514.85 5716.82 5811.02 5901.27 5~86.60 5066.66 5139.49 5196.21 0.26 1355. 0.20 1415. 1.78 1476. 0.32 1530. 0.31 1583. 0.21 1537. 1.57 1591. 1.33 1741. 0.41 1789. 2.0¢ 1838, 0.35 1884. 1.22 1932. 0.13 1977. 0.77 2023. 0.25 2069. 9.29 2115. 0.40 2161, 0.58 2207. 0.35 2254. 0.22 2302. 0.62 2350. 0.3~ 2397. 0.48 2~42. 2.90 2488. 0.93 2537. 1.39 2586. 1.12 2533. 3.45 2580. 0.00 2728. 0.00 2766. PAGE DATE DF SURVEY: 30-0CT-85 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 85.00 FT' DEPTH 3UL4R COORDINATES SOUTH EAST/WEST T FEET 46 S 2686.31 ¢9 S ,"815.33 22 S 2945.15 77 S 3062.89 57 S 3177.41 26 S 3293.82 21 S 3411.03 50 S 3524.16 23 S 3633.63 13 S 3744.83 92 S 385 11 S 395 71 S 406 83 S 416 83 S 427 89 S 437 83 S 447 58 S 456 56 S 466 30 S 476 H3R!Z, P~RTURE OIS T '~,, U~l: ;MUTH FEET' MIN E 3008.91 ~ ;3 13 E 3151.14,,,??,., 18 E 3294.~1" ~ 63 22 E E 3424.12S 63 26 E E 3550.16 S 63 30 E S 63 34 E S 63 37 E S 63 42 E S 63 4'7 E S 63 51 E E 3578.29 E 3807.27 E 3931.01 E 4050.26 E 4171.63 1.83 E 42.88.30 9.14 E 4605.43 4.32 E 4519.96 9.44 E 4634.67 1.75 E 4746.80 1.69 E 4856.81 0.35 E 4965.53 7.58 E 5073.13 6.14 E 5182.27 6.21 E 5293.15 S 63 55 E S 63 59 E S 64 3 E S 64 6 E S 64 8 E S 6~ 10 E S 6~ 11 E S 64 12 E S 64 12 E S 64 13 E 34 S 486 18 S 496 85 S 505 99 S 514 51 S 522 03 S 530 41 S 537 36 S 544 41 S 550 67 S 554 5.35 1.51 5.87 6.83 8.09 4.99 5.98 3.35 1.20 5.86 E 5403.30 E 5510.27 E 5615.09 E 5717.07 E 5811.36 E 5901.74 E 5987.22 E 6067.48 E 6140.64 E 6197.67 S 64 12 E S 64 12 E S 64 12 E S 64 11 E S 64 6 E S 64 0 E S 63 54 E S 63 47 E S 63 37 E S 63 29 E 3C-13 KUPARU< NORTH SLOPE,AL~SK~ TOP TgP PBTD TO MA RKER KUP a, RUK C KLJPARUK ~,_ KUP6RUK ~ KUPARUK 6 COMPUTATION DATE: 16-J6N-86 INTERPOLATED VALUES FOR CHOSEN HJRIZDNS ' ;,~ " ORIGIN: .: ~EASUREO DE~TH T~D BELOW KB FROM KB PAGE DATE DF SJR~EY: 3D-OCT-85 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL SURF 85,00 1310' FNL,121?' FEL, SUB-SEA 8g~'g. O0 6366,51 5281,51 g028.00 5424,64 5)39.,54 9188,00 5544.28 5459.28 9338.00 5659.58 6574,68 9491.00 5781.46 6596,~6 9594.00 ~864.13 6779,1~ RECTANG NORTH/ 2528, 2556, 2614, 2668, 2726, 2756. FT ,~L~SKA, INC. ~RUK SLOPE ~ ALA3,~ ~ DP .~ SE OP ~S~ STD D MA.~KER ~UP~RU~ S KU'PA~UK C KUP&RUK ~ KUPARUK A COMOUT&TION DATE: ~IEASUR ED DEPTH BELOW K2 8969.00 9.028.00 9188.00 9338.00 9~91.00 9594.00 15-J~N-85 PAGE DATE DF SURVEY: 30-0CT-85 KELLY 5USHING ELEVATION: ENGINEER: PEPPEL 8 85,00 ORIGIN: 1310' FROM K~ SUB-SEA 5~66.51 5281.51 6424.64 5339.54 6544.28 5459.28 6659.68 5574.68 5781.46 5595.46 5864.13 6~79,13 SUR FNL,121?' FEL RECTAN NORTH FACE ,SEC GULAR /SDUT~ 2528,51 S 2556.83 S 2614.14 S 2558.51 S 2726.70 S 2756.67 S LOCAT :" C ;'ES EAS EST ,~. 5213.53 E 5258' 92 E 53¢8.36 E 5427.23 E 5499.21 E 55¢5,85 E FT ,UM :INAL WELL LOCATION AT TO: TRUE SdB-SEA EASJRED VERTICAL VERTICAL DEDTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 51~7.57 S 63 29 E '3] b SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY WELL FIELD COUNTRY ARCO ALASKA INC 3C-13 KUPARUK USA RUN DATE LOOOED ONE REFERENCE 000071]58 WELL NAME- 3C-13 SURFACE LOCATION' 1310' FNL, 1217' FEL, S14, T12N, RgE HORIZONTAL PROJECTION N~I~rH ~ ~F I:~)O0~] ]~ ~E = ]/1000 IN/FT 2OOO ]ODD - ! 000 -2000 -9O0O -4000 SOUTH -SO00 NEST i, i i,,, ii,! :+ii i .... :: i :: ! !! : ~ i J i.~ ~ :'- -?'-~"T"-T-T'T"r"C?.'T'TT- !iii i i!i i ii;.- :iii i -' L- 7. -T'T';-T-'~"?..-FT-:"m?- -.?~.:-?... -?-?. ,.m?- ."-~.'t'~..:~. ~ ~ ~ =: ! ! -" ! ~ ~ i ': ~ ~ ; ~ ': i " ~ [ ~ -~ ~ ~ ~ .: -: ~ 4-.--.4--.i-.4,--4-.-..~.,~..;--,i---.~--4.,4, ...... ,;-4.-...~....;. ....... ,;...4...4...;- -~; ~ ~ ~ ~ ~ ii i -i !! :: ! ! ! ! !!!4~ ~ i~ -: J-4-4-~ :. ~ !-~.--4-~---~4-.: ...... ~--4~i~ -.:.-.-4-~---4--P4-.~ .... 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S~:PLEO IN VER'[ICPIL DEPTI-I~ HORIZ SCALE : 1/2000 IN/FT Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by:"/[--'~ '-~"~f,~-~-~ Date ,_ Required Date Received Remarks Complet ion Report _ Well History Samples Core Chips W ~ , , Regis tered Survey Platx~ : ~ e~ ~' .~.~c~.f~ : "~.~c' ~ f~ ~~, Inclen>at ~on.~:~vey Production Test Reports Log Run x. / L. FJ. 04 ARCO Alaska, Inc./- Post Office Box 100360 'Anchorage, Alaska 99510-0360 Telephone 907 276 1215 --'- _u.-~ ~:': KUPA~K OP~TIONS ~NGINEE~G ~CO~S CLE~ AT~lllS~ P.O. ~OX 100360 ANCHO~GE, AK 99510 DATE: 11-19 -85 TRANSMITTAL NO: 5453 TRANSMITTED HEREWITH AR~ THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE REC~:IPT AND RETURN ONE ~IGN~D COPY OF THIS TRANS~ITTAL. OPEN HOLE LIS TAPES PLUS LI~%'ING/ $CHL/ ON~ COPY OF EACH 3F-7 11-03-85 RUN #1 3F-6 . 10-27-~.5 RUN 3C-13 10-26-85 RUN 3A-8 10-30-85 RUN 3A-1 09-30-85 t{UN #1 2A-8 10-29-85 R~N 3456.0-8045. 3384.0-7689 3134 3392.5-8527. RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DRILLING L. JOHNBTON MOBIL NSK CL E I~K DISTRIBUTION: W. PASHER EXXON PHILLIPS 0IL J. RAThMELL ~-'/SOHIO UNION VAULT/ANO ARCO Alasl;a. Inc. is a Subs,Oiary ol AtlanticRichfiel~Compan¥ ARCO Alaska, Inc. Post Office B~. .,0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures RECEIVED Alaska Oil & Gas Cons. Comm!ssJon Anchorao~ ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany - ~--. STATE OF ALASKA ALASKA O,._ AND GAS CONSERVATION COk..,ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-198 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21424 4. Location of Well at surface 1310' FNL, 1217' FEL, Sec.14, T12N, R9E, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 85 ' RKB 6. Lease Designation and Serial No. ADL 25634 ALK 2567 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3C-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. October ,19. 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2230 hfs, 10/17/85. Drld 12-1/4" ho]e to 4811'. Ran, cmtd, & tstd 9-5/8" csg. Performed top job. Drld 8-1/2" hole to 9440'. Ran logs. Continued drilling 8-1/2" hole to 9594'TD (10/27/85). Ran, cmtd, & tstd 7" csg. PBTD = 9491'. Secured well & RR @ 0400 hfs, 10/29/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 112'. Cmtd w/188 sx CS I1. 9-5/8", 36.0#/ft, J-55 BTC csg w/shoe ~ 4791'. Cmtd w/1300 sx PF "E" & 330 sx Class "G". Performed top job w/88 sx PF "C". 7", 26.0#/ft, J-55, HF-ERW BTC csg w/shoe ~ 9574'. Cmtd w/575 sx Class "G", 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/9428' - 4793' FDC/CNL f/9428' - 8750' Cal f/9428' - 7400' GR f/4793' - 2000' RFT f/9316' - 9025' CET f/9474' - 7075' GCT f/9423' - surface 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas C0r~;. 60mrr.,!ssi0r~ SIGNED (~~ ~_, TITLE Associate Engineer DATE ,4r NOTE--Report f~/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 Con~servation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRH/MR52 Submit in duplicate August 28, 1985 Mr. J. B. Kewin Area Drilling Engineer AP, CO Alaska, Inc. P, O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3C- 13 ARCO Alaska, Inc. Permit No. 85-198 Sur. Loc. 1310'FNL, 1217'FEL, Sec. 14, T12N, R9E, UM. Btmhole Loc. 1305'FSL, 851'FEL, Sec.13, T12N, RgE, I~R. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~zaing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to com~encing operations you may be contacted by a representative of the Department of Environmental Conservation. !~fr. Je~_~rey B. Kuparuk River Unit 3C-!3 -Z- 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 ~urface casing shoe is drilled. ~_ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very .tru!v yo?rs, i C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE CO~IISSiON 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 B, ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3C-13 Dear Mr. Chatterton- Enclosed are: An application for Permit to Drill Kuparuk 3C-13, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot Diagram and description of the surface hole diverter system o Diagram and description of the BOP equipment We estimate spudding this well on October 20, 1985. If you have any questions, please call me at 263-4970. cerely, ~~gineer JBK/JFB/tw PD/L147 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany la. Type of work. STATE OF ALASKA "-' ALASKA ~lL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 SERVICE [] SINGLE ZONE MULTIPLE ZON E)~] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Irc, 3. Address P, 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1310' FNL, 1217' FEL, Sec.14, T12N, R9E, UM At top of proposed producing interval 1514' FSL, 1294' FEL, Sec.13, T12N, R9E, UN At total depth 1305' FSL, 851' FEI', Sec.13, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease ¢e'~ignation and serial no. RKB 85', PAD 48' 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3C-13 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13, Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 3C-14well 60' ~ surface feet 16. Proposed depth(MD & TVD) 9492' MD, 6730' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 0' ~ 2532'TVD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 49 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 10/20/85 2831 psig@. 80*F Surface 3271 _psig@ 6/~18 ft. TD (TVD) SIZE . Hole Casing i24" 16" i 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 Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH MD TOP TVD 80' 37' I 37' 4829' 37' I 37' I MD BOTTOM TVD 117~ 117' i 4866'I 3720' I QUANTITY OF CEMENT (include stage data) ± 200 cf 1190 sx CS III & ~ 400 sx CS II 9456' 36' I 36' 9492'1 6730' 300 Sx Class G I ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9492' MD (6730' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The-13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2831 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 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-13 will be 60' away from 3C-14 at the 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 certi/f4~that the foregoing is true and correct to the best of my knowledge / //..~'/~ ( TITLE The spac f sion u Samples required [~]YES ,~NO Permit number APPROVED BY(; ~/~ Form 10-401 [O1'1:1)~ ' PD'~' Regional Drilling Engr. CONDITIONS OF APPROVAL Mud log required i-]YES ~NO Approval date -'") ..~ 08,/28,,/S5 /'/ Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE At~gt!St 28~ 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3C-13 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 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 ~t~.~ Oit & Gas Cons. Commission Anchorage ~: ~,I : i':' HORIZONTAL PROJEC~ ON .......... i;' -~""' !"',"'"" ~'i.' ~ ~i !, i ', SCALEi ' ' ' I ' '! ~1 ' I. ' .t. , . , ~ ,, ....... , ....................... , ................ ,,, ~ ........... ARCO~ ALASKA,, '. [NC'''. PAD 3C, HELL. N0.'13' PROPOSED'i KUPARUK:FIELD,'NORTHiSLOPE, ALA, SKA ] '. ~' ' ' ~ HAN' 'WHIPSTOCK,,' . . · '1" ' ' ],,NC,~' ' ' '" ' ' EAS,. '. , . . .!, , 1 000 ..... 1 000 ..'_J z c) ~ .... 1 000:.._ '0 '--,t I ; 0 11000 2000 i ~000 i i SURCACE LOcA'r[ ON, 1;310' FNL,' 1217" FEL .. 2000. _ ' i 3000 ~' --, TARGET LOCATION, 1460'. FSL. 1180' FEL SEC, 13. T I2N. RgE S ,64'..DEG 44 MIN' 58,80," (TO TARGET) . . ~.. TARGET CENTER TVD-6418 TMD-901 2 DEP-5$80 I .......... , .............. ~ ........ . ............ ! , , SOUTH 2510 . EAST . 5,.31Z : t t : [, ] TD LOCAT [ ON" 1305' FSL, 851' FEL SEC, 13,-TI2N, RgE )0 1500 ':" i1400 1300 )0 NORTH IARCO :ALASKA :INC., ~PAD""~C,',"'WELL' NO.,' 1~-:14-15~16 :KUPARUK'FIELD, NORTH: SLOPE 1100 i PROPOSED 1000 I 900 I 800 700 6o0 5 ,i' ' 3O DO 00 ALASKA NOTE, WELL:PATHS EXTEND BEYOND THIS VIEWIqO WINDOW H .... ~.. . . . , ~ ' 3191 : 1277 I " 2855 455 I $40 3369 1623 2940 I , 1702 I 3454 .... ~ ' ' 3023 I Z?8 O2 1850 1919 KUPARUK RIVER UNIT 20" -DI VERTER SCHEMAT I C i DE S CR I P T I ON i. I G' COt,,EXJCTOR. 2. TAI',,IKOSTARTER HEAD. ;5. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CC)t,,I'~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. '7. I0' HCR BALL VALVES W/lO' DIVERTER LINES° VALVES OPEN AUTOMATICALLY UPON CLOSURE AhI',,I.~AR PREVENTER. 8. 20" 20(~ PSI AI',X~LAR PREVENTER. 7 6 7 5 4 ._ '~ 1 L ECEIVED IviAl NTENANCE & OPERATI ON I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES ' HAVE OPE~D PROPERLY. 2. CLOSE ANNULAR PREVENTER AhD BLOW AIR THROUC~ DIVERTER LIliES EVERY 12 HOURS. 3, CLOSE AhlNULAR PREVENTER IN THE EVENT 'THAT AN IhFLUX OF ~LL~. · FLUIDS OR GAS IS DETECTED. IF . NECESSARY, IV~AI~JALLY OVERRIDE Ahl) CLOSE APPROPRIATE VALVE TO ACHIEVE DO~NWlN[) DIVERSION, i§85 DO NOT SHUT IN ~LL ~UGi Gas coo~. co~:,m~ss,o~ UNDER ANY CIRCUMSTANCES. Anchorage . . ii ii i i J 13-5/8- P~ RSRRA BOP STACK I. 16' - 2000 PS! TAAK~ STARTING HEAD 2. I1' - 3000 PSI CASING 3. i1' - 3000 PSI X 13-5/8' - 5000 PSI SPACE~ SPOOL 4. 13-5/8" - 5000 PSI PIPE 5. I~r-5/8' - 5000 PSI DRILLING SPOOL W/~ AND KILL LIAF_S 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RN~ ON TOP, 7. 13-5/8' - 5000 PSI ArvN. EAR ACCt.lV~ATOR CAPACITY TEST 1. C~CX AhD FILL ACC~TC~ RE.S~OIR TO F~ LEVEL WlTN NYDRALLIC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I I~ ~I ~T~ ~ ~ ~~T~. 3. ~ TI~, T~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ 12~ ~I ~INI~ 5 F-J 13-5/8" BOP STACK TEST /I ~ 1. FILL BOP STAEX A~ C]40KE MANIFOLD WITH ARCTIC DIESEL. 2. O-ECX THAT ALL LOCK D~ S~ IN WEI. U.F. AD ARE FLLLY RETRACTED. SEAT TEST PLUG IN ~Ei. LPEAD WITN ~,JANING JT ~ RUN IN LO~ SO~. LI~E VALVES A~ TO BOP STACY~ ALL VALVES At~D CHOKES SHOL~ BE OPEN. __ 4. PRES,.~ UP TO 2_50 PSI AI~ HOLD FOR I0 MIN. IN- C~ P~S~ TO 3000 PSI AJ~ HOLD FOR I0 MIN. BLEED PEE~ TO 0 PSI. S. OPEN AI~ PREVENTER AJ~D MANJAL KILL A~D LIAE VALVES. CLOSE TOP PIPE RAMS AAD HeR VALVES ON KILL AND CHOKE LIAES. -6. TEST TO 250 PSI A~ 3000 PSI AS IN STEP ?. CCt4TI~JE TESTING ALL VALVES, LIAE. S, At~ (~ES WITN A 2_50 PSI LO~ AI~ 3000 PSI NIGH. TEST AS IN STEP 4. DO NOT Pf~E~ TEST ANY CHOKE THAT TS ~) NOT A FULL CLOSING POSITIVE SEAL Q46KE. OI~Y FU~ICt~ TEST (~$ THAT DO NO'[ FULLY CLOSE. ' 8. OPEN TOP PIPE RAI~ AAD CLOSE BOTTO~ PIPE RAMS. TEST BOTTCt~ PIPE RAMS TO 2_50 PSI AAD 34X30 PSI. D. OPEN BOTTCt,4 PIPE RAIDS, BACK OUT RUffING JT AAD .' PULL OUT OF HOLE. ~ . . I0. CLOSE BLIhD P,~ AAD TEST TO 250 PSI AI~ I1. OPEN BLIAD RAMS ANO RETRIEVE TEST PLUG. MAKE SURE / FLUID, SET ALL VALVES ZN DRILLING POSITICt4. ;12~ TEST STANDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, Ah/:) INSIB6 BOP TO 250 PSI ANO 3000 PSI. Ai~s~a~G[ ~.~ ~ 14. PERFORM COVPLETE BOPE TEST AFTER NIPPLIN6 UP AAD WEEKLY THEREAFTER FL~IONALLY OPERATE BOPE DAILY. & Gas Cons: 6ommissio~ Anchorage ARCO Alaska, Inc.~'' Post Office b~.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3C Pad Wel 1 s 1-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer J G/tw GRU6/L113 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~.~ ~1~ i i i ~ i i i i · Y = 5~995,83§.15 Lot. : 70°23'58.955'' SEC.~ WELL I x= 528,205.68 Lo,g.= ~49o46'~3.62z" ~ SEC. 14 596"FNL 1366'FEL N O R T H ~ - - Y: 5,995,89~.7~ L~t. : 70°2~'59.5~2" WELL 2 x: 528,193.14 ~n~,= 149°46'13.983" 537' FNL~ 1378'FEL Y = 5,995~952,43 L~t. = 70°24'~. II0" WELL 3 x= 528,180.60 Lon~= 149°46'14.343" 478'FHL ~ 1390'FEL Y = 5~9967 011.07 Lot. = 70°Z4'00.687" ~ ~ WELL 4 x= 5~8,~8.~ Lo,~.: 420' FNL~ 1402'FEL ~ ~'~ ~ ~ ' ~ WELL 5 X= 528,520.16 Long.= 149°46'04.3~' 346' FNL ~ 1050'FEL Y = 5~996,0~7.76 LQt. = 70°24'00.837~ WELL 6' x= 5ze,5~z.8~ Lo,g.= ~49o~'~.0~5' , 404' FNL ~ 10~' FEL Y= 5~995~969.11 LOt. = 70°24'00.260'' WELL 7 x= 52e,~5.24 Long.= 149°46'03.658'' 463'FNL ~ 1025' FEL ~ Y= 5~995~910.44 'Lol. = 70°23'59.683" .~ WELL 8 x= 528,557.71 Long,= 149°46'03.~99" 5~FNL ~ 1013' FEL ~ '~' " WELL 9 x, 5~8,s?e.~ Lo,t= . ,,~ ~ ~,~ ~ ~0'FNL, 901' FEL WELL 10 x= szs,6as.04 Lo,~=~9°~5'~9.s~s 1119~FNL ~ 889' FEL Y = 5,995~255.2Z Lat. WELL '11 x= ~,s97.~ ~,~.= ~s°~'59. z~" 1177'FNL~ 876'FEL Y = 5~995, 196.51 Let. = 70°2~'52.6~'' pRILL SITE 3'C .~:,.=.oo, ,.~,~.~, AS-BUILT CONDUCTOR LOCATIONS ' ~= 5,~95,,~.~3 L,~. WELL I~ x= sza,~.~o ~,~.= ~4s°~'o~.z~' WITHIN SECTION 14~ TI2N~ 'RgE~ U.M.~ ALASKA 1310'FNL~ 1217'FEL NOTE: ~ = s,995,~eo.o~ t,t. = 70°~'5~.5m" WELL 14 x= ~zs,~.s~ Lo,~.=~so4s'o9.5s4" COORDINATES ARE ALASKA STATE PLANE ZONE 4. 1251'~L, 1229' F~ SECTION LINE DISTANCES ARE TRUE. Y = ~995,238.66 L,t. = 7~2~'5~'.084" ,ORIZONTAL POSITION PER L,D E ASS~. MONU~S 19-1 E 19-2. WELL 15 x= ~,~.o7 Lo,~.= ~49o~6'0~.95s" VERTICAL POSITION PER LHD 6 ASSOC. TBM 0PI6~ 6 DOC. 125. 1193~FNL~ IZ41'FEL eWELL NO. 6 INFORMATION PER DWG. NO. NSK 9.05.~0~dl. Y= 5,~5~297.32 L~I. = 70°23'53.661" WELL 16 x= 5ze,3zo.~5 Lo,t=~4~o4~'~o.~s" 11~4' FNL~ 1253'FEL i i i i i II CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~D THAT ~ OF MADE BY ME OR UNDER MY SUPERVISlON~ AND ~eee ~. THAT ALL DIMENSIONS AND OTHER DETAILS ~ ~- ~e ~ I~[ ~ ' DATE MAY 14~ 1985 .... "." , , . ~ ~ 3 = ROBEO~ ...... . .. · - a~Hfi, ~,~ ~. 8,0, I SERVICES ~-,.-~'...._ ................. ' , d ....... ] ~o~;; ...... - IICHECKED d. HEHMAN I ~ ~_ ~t-.SI0[{~c 3340 Arctic Boulevard, Suite 201. Anchorage, Alaska 99503 Il' , .... I _ ll~Oa· ~. oou~ I , i ~ LIST FOR NEW WELL PERMITS Lease & Well No. ~ P/-.~ ~ ~.~-/3 ITEM APPROVE DATE YES NO REMARKS (1) Fee ~' ~-/9-~-g' (2) Loc f- e- g (2 thru 8) (3) Admin X ,'~-'f'i',"~,~ 9. (9 thru 12) 10. (10 and 12) 12. ( (13 thru 21) (22 thru 26) 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 .......................... 22. 23. 24. 25. 26. '27. 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 ............................ Is diverter system required Are neCessary diagrams of diverter and BOP equipment attached ....... ,~ ' Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements' ' · ®® ~® ~·. ·® ~ e. ~ ~.. e ~... m. ~,·..·.·... ·.1..·· $ ®... Additional Remarks: Geology: HWK WVA ~-- JAL Engitkeering: LCS ........ rev: 03/13/85 6.011 INITIAL GEO. uNIT. ON/OFF . , ., POOL CLASS STATUS AREA NO. 'SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS TAPE VERi~IC,~TiON LISTING LV° 01O,.HOZ VERIFICATION LISTING PAGE i " .... R:EL HEADER SERVICE NAME :EDIT DATE :85/11/ T ORIGIN : REEL NAME :149,247 CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS :Li,SRARY T~PE ** T~PE HEADER ~, SERVICE NAME :EDIT OATE ':85/11/ 7 ORIGIN :0000 TAPE NAME :0917 CONTINUATION ~. :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE X:~ FILE HEAOER *~ FILE NAME :EDIT SERVICE NAME : VERSION ~ : DATE : ~AXIMUM LENGTH : FILE TYPE : PREVIOUS FILE : · 001 1024 INFORMATION RECOROS ~:* MNEM CONTENTS CN : ARCO ALASKA INC WN : 3C-13 FN : KUPARUK RANG: TOWN: 12N SECT: 14 COUN: N. SLOPE STAT: AK CT~Y: USA MNEM CONT:NTS PRES: E ..... COMM~-NTS ...... UNIT UNIT TYPE 000 000 000 000 000 000 000 000 000 TYPE 000 CATE 000 000 000 000 000 000 O00 000 000 CATE 000 SIZE 016 OO6 OOB 002 00~ 002 012 OO6 003 SIZr- 001 CODE O65 065 065 065 C, 55 065 065 065 065 COD; mIII 065 LVP OIO.H02 VERIFICATi0N LISTING PAGE "'-,- SCHLUMB:RGER~ -,- ~',-' ALASKA COMPUTING CENTER ;:-' COMPANY : ARCO ALASKA iNC WELL = 3C-13 ,mi ELD : KUP &'RUK COUNTY : NORTH SLOPE BOROUGH ST.~T~ = ALASKA JOB NUMBER AT ACC: 7091'7 RUN m2, DATE LOGGED: ZG-OCT-$5 LDP: MoOGDEN CASING : 9.823" @ ~791.0' - BIT SIZE : 8.3" TO 9440.0' 'TYPE F'LUIO : 'LSNO DENSITY = 10.00 LB/G RM : 3.120 @ 67.0 DF 'VZSCOSZ'TY = 39.0 S RMF = 3.330 @ 65.0 DF PH = 10.0 RMC : 2.650 @ 87..0 DF FLUID LOSS = 5.0 C3 RM AT BHT : 1.490 @ 145. OF M~TRIX S~NDSTON~ ~:~ THIS DATA HAS N~T ~EEN DEPTH SHIFTED - ~VERLAYS FIELD PRINTS ~*~:~ LVP OlO.H02 VERIFICATION LISTING PAGE 3 SCHLUMBERGER LOGS INCLUDED WI'TH THIS MAGNETIC T~PE'. '.:: DUAL INDUCTION SPHERICALLY FOCUSECt LOG (DIL) · ~:.' DATA AVAILABLE: 9,420o0' TO 4793.0' ~: FORMATION DENSITY COMPENSATED LOG (F~N) ~:: C~MPENSATED NEUTRON LOG (FBN) ~',~ ~:~ D~T~ AVAILABLE: 9394.0' TO 8750.0' ~ GAMMA RAY !N CASING (GR.CNL) ~',~ D~TA ~&VAILABLE: 4830.0' TO 2696.5' NOTE: FIELD TAPE DATA (OIL) IS 12 =T. LESS THAN THE BLUELINE DEPICTS. (SHALLOW END) $::= OATA FORMAT RECORD ~ ENTRY BLOCKS TYD5 SIZE REPR CODE ENTRY 2 1 68 0 4 1 66 LVO 010.H02 VERIFICATION LISTING PAGE OATUM SPECIFICATION MNEM SERVI'CE SERVICE ID ORDER ~ OEPT SFLU OIL !LO OIL ILM OIL SP OIL GR OIL GR ~DN CALI FDN RHOB FON ORHO FDN NRAT RN'RA FDN NPHI FDN N C N L F 0 N FCNL FDN 8 a 73 60 9 4 65 .lin 16 1 66 1 0 1 66 0 BLOCKS UNIT API ADZ LOG TYPE FT O0 000 OHMM O0 220 DHMM O0 1.20 OHMM O0 120 MV O0 010 GAPI OO 310 GAPi O0 310 IN O0 280 G/C3 O0 350 G/C3 O0 356 O0 420 O0 000 PU O0 890 CPS O0 330 CPS O0 330 AP1 APi CLASS MOD O0 O 01 0 45 0 44 0 O1 0 01 0 O1 0 O1 0 02 0 Ol 0 O1 0 0,0 0 O0 0 31 0 3O FILE NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SI 25 SPL 4 1 4 1 4 4 4 1 4 1 i REPR CODE 68 ,,68 68 68 68 68 68 68 68 68 6,5 PROCESS (OCTAL) 00000000000000 00000000000000 O000OO00000000 00000000000000 O000OOOO000000 000000000'00000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 OEPT SP RHOB NPHI DEPT SP NPHI OEPT SP NPHI SP NPHI OEPT SP NOHI DEPT SP 9449.0000 SFLU -41.8320 GR 2.0842 DRHO 46.9727 NCNL 9400.0000 SFLU -44.~.:B20 GR 2.1174 DRHO 43.5547 NCNL 9300.0000 SFLU -67.3477 GR 2.4163 DRHO 34.4727 NCNL 9200.0000 SFLU -45.0195 GR 2.4084 ORHO 3Z.0313 NCNL 9100.0000 SFLU -39,4255 GR 2.4005 ORH3 31.6~95 NCNL 9000.0000 SFLU -21.1982 GR 2.5002 ORHD 2.8225 iLO 112,6523 GR 0.2119 NRAT 2033.5875 FCNL 2.4573 ILD 112.6523 GR 0.2245 NRAT 1959.6575 FCNL 7.3835 iLD 82.6523 GR 0.0366 NRAT 2429.5000 FCNL 6.1804 iLO 71.1523 GR 0.0527 NR~T 2569,5000 ~CNL 6,8601 ILO 79.2148 GR 0.0088 NRAT 2717.5000 FCNL 2.56B2 94.4648 GR 0.0430 NR~T 2.5940 112.6523 3.7073 519,312'5 2.353~ 112.6523 3.5764 540.8125 5.8328 82.6523 3.1252 766.8125 5.8210 71.1523 2.9570 ~29.8125 6.2976 79.2145 2.9631 897.~125 3.0323 94.464B 2.9436 ILM CALI RNR4 ILM CALI RNR~ ILM CALl RNR4 ILM C4LI RNR~ ILM CALl RNR4 ILM C~LI RNRA 2.7639 8,5020 3.9202 2.4065 9.1895 3.5233 5.9539 9.7520 3.1663 8.4785 9.6270 3.0959 6.4773 9.8223 3.0256 3.1721 10.3535 3.1652 LVP OlO.H02 VERIFICATION LISTING PAGE 5 NPHI DEPT SP RH06 NPHI OEPT SP RHOB NPHI OEPT SP RHDB NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI OEPT SP RHOB NPHi OEPT SP NPHI OEPT SP RHOB NPHI DEPT SP 30,7617 NCNL 8900,0000 SFLU -33,9258 GR 2,4709 DRHO 35,0586 NCNL 8800.0000 SFLU ,-26.1826 GR 2.2756 DRHO 49.5605 NCNL 8700,0000 SFLU -25,7754 GR -999,2500 DRH8 -999,2500 NCNL 8600,0000 SFLU -33,4883 GR -999,2500 DRHO -999,2500 NCNL 8500,0000 SFLU -31,0576 GR -999,2500 DRHO -999,2500 NCNL 8400,0000 SFLU -39.4883 GR -999,250'0 DRHO -999.2500 NCNL 8300,0000 SFLU -39,0508 GR -999.2500 ORHO -999,2500 NCNL 8200,0000 SFLU 15,9004 GR -999,2500 DRHO -999,2500 NCNL 8100,0000 SFLU -65,8477 GR -999,2500 DRHO -999,2500 NCNL 8000,0000 SFLU -$1,7227 GR -999,2500 DRHO -999,2500 NCNL 7900.0000 SFLU -41.6758 GR Z 529. 5000 FCNL 3,3323 ILO 123,652.3 GR 0,0352 NR4T 2315,5000 FCNL t,7706 ILD 123,0273 GR 0,0127 NRAT 1841,68'75 FCNL 2,0002 ILD 125,8398 GR -999,2500 NR~T -999,2500 FCNL 3,1213 ILO 148,9375 GR -999,2500 NRAT -999,2500 FCNL 1,9131 ILD 350,6406 GR -999,2500 NRA'T -999,2500 FCNL 3,6409 ILO 157.1875 GR -999.2500 NRAT -999,2500 FCNL 2,9299 ILO 114,5898 GR -999,2500 NR~T -999,2500 FCNL 2,.4026 ILO 106,2148 GR -999,2500 NRAT -999,2500 FCNL 2,0940 ILD 105,0273 GR -999,2500 NR~T -999,2500 FCNL 2,2'991 ILO 95,6523 GR -999,2500 NRAT -999,2500 FCNL 4,4539 ILO 73.7148 GR 7'97.8125 3,4807 ILM 123,65.23 CALI 3,2.385 RNR4 69.4.8125 1.6348! ILM 123.0273 CALI 3.951,4 RNRA ~08..3906 2.0393 ILM -999.2500 CALl -999.2500 RNRA -999-2500 3,00:22 ILM -999.2500 CALI -999'2500 RNRA -999.2500 .1,8682 ILM -999.2500 CALl -999,2500 RNRA -999,2500 3,3870 ILM -999,2500 CALI -999,2500 RNRA -999,2500 3,4749 ILM -999,2500 CALI -999,2500 RNRA -999,2500 2.53,54 !LM -999.2500 CALI -999.2500 RNR4 -999.2500 2.4651 ILM -999.2500 CALI -999.2500 RNRA -999.2500 2,7600 ILM -999.2500 CALI -999,2300 RNR4 -999.2500 4,~031 iLM -999,2500 CALi 3,381i 10'7832 3.3303 1,7022 9.7598 4-5085 2.1526 -999,2500 -999,2500 3,0413 -999,2.500 - 999.2500 1.8624 -999.2500 -999.2500 3,3401 -999.2500 -999.2500 3,5901 -999,2500 -999.2500 2.5920 -999.2500 -999.2500 2.4573 -999,2500 -999.2500 2,7170 -999.2500 -999.2500 4.6218 -999,2500 LV,,° 010.H02 VERIPICATION LISTING PA,GE 6 RHO6 NPHI SD RHOB NPHI OEPT SP RHOB NPHI O EPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT RHOB NPHi DEPT SP RHOB NPHI DEDT SP RMOB NOHT 9EPT RHOB NPHI OEPT ~HOB NPHI DSPT SP NPHI -999.2500 DRHO -999.2500 NCNL 7800.0000 SFLU -35,89~5 GR -999°2500 -999.2500 NCNL 7700.0000 SFLU -41.1133 GR -999.2500 DRH~ -999,2500 N-CNL 7500,0000 SFLU -38,9883 GR --999.2500 ORHO · -999..2~00 NCNL 7500,0000 SFLU -39.8008 GR -999.2500 DRMO -999,2500 NCNL 7400.0000 SFLU -44.6445 GR -999.2500 DRHO -999.2500 NCNL 7300.0000 SFLU -50.2070 GR -999.2500 ORHO -999.2500 NCNL 7200.0000 SFLU -59.5820 GR -999.2500 ORHO -999.2500 NCNL 7100.0000 S=LU -62.3008 GR -999.2500 DRHO -999.2500 NCNL 7000.0000 SFLU -66.3477 GR -999.2500 DRH~ -999.2500 NCNL 6900,0000 SFLU -63.9727 OR -999.2500 -999.2500 NCNL 8800.0000 SFLU -999.2500 NRAT -999.. 2500 FCNL 3.0530 ILD 73.339'8 GR -999.2500 NRAT -999.2500 FCNL 2.9885 ILD 74.4648 GR -999.2500 NR~T -999.2.500 FCNL .3.2190 ILO 101.4023 GR -999.2500 NRAT -999.2500 FCNL 2.0120 ILD 110.1523 GR -999,2500 NR&T -999.2500 FCNL 2.7639 ILD 103.8398 GR -999.2500 NRAT -999,2500 FCNL 2.7483 ILD 119.1523 GR -999.2500 NR~T -99'9.2500 FCNL 2.3,440 ILD 91.9023 GR -999.2500 NRAT -999.2500 FCNL 2.6584 ILD 101,0273 GR -999.2500 NR&T -999.2500 FCNL 2.4749 ILO 100.0273 GR -999.2500 NRAT -999.2500 FCNL 3.3088 iLD 94.2148 GR -999.2500 NR~T -999.2500 mCNL 3.5823 ILD -999.2500 -999.2500 2.9612 -999.2500 -999.2500 -999.2500 3.4377 -999,2500 -999.2500 -999.2500 3.6135 -999.2500 -999.2500 -999.2500 1.9659 -999.2500 -999,2500 -999,2500 3.1057 -999.2.500 -999.2500 -999.2500 2.9456 -999.2500 -999,2500 -999.2500 2.6877 -999.2500 -999.2500 -999.2500 2.8635 -999.2500 -999.2500 -999.2500 2,7756 -999.2500 -999.2500 -999.2500 3.5193 -999.2500 -999.2500 -999.2500 RNRA ILM CALl RNRA ILM C AL 'I RNRA ILM CALI RNR.& !LM CALI RNRA ILM C~LI RNRA ILM CALI RNRA ILM CALi RNR~ ILM CALI RNRA ILM CALI RNRA ILM C~LI RNRA iLM -999.2500 3,0100 -999.2500 -999,2500 3,4856 -999,2500 -999.2500 3.6663 -999. 2500 -999.2500 1.9864 -999.2500 -999.2500 3,0999 -999.2500 -999,.2500 2.9124 -999.2500 -999.2500 2.6838 -999.2500 -999.2500 2,8733 -999.2500 -999.2500 2.7815 -999.2500 -999.2500 3.~983 -999.2500 -999.2500 4.6257 ~'l'~ i~ LI I mil ,Iq ~[! [;11 LVP OlO.HO2 VERIFICATION LISTING PAGE SP RHOB NPHI DE PT SP NPHI OEPT SP RHOB NPHI DEPT SP NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT Se RHOB NPHi DEPT SP RHOB NPHI DEPT SP RHOB NPHI D2PT SP RH05 NPHI DEPT S? RHOB -61,9570 GR -999,2500 ORHO -999,2500 NCNL 6700,0000 SFLU -62,2695 GR -999,2500 DRHO -999,2500 NCNL 6600,0000 SFLU -76,5.352 GR -999,2500 DRHO -999.2500 NCNL 6500,0000 SFLU -63.3633 GR -999,2500 DRHO -999,.2500 NCNL 6400,0000 SFLU -75,0977 GR -999,2500 DRHD -999,2500 NCNL 6300,0000 SFLU -67,9102 GR -999,2500 DRHO -999,2500 NCNL 6200,0000 S~LU -65,7852 GR -999,2500 DRHO -999,2500 NCNL 6100.0000 SFLU -52.9883 GR -'999.2500 DRHO -999.Z500 NCNL 6000.0000 SFLU -50.4258 GR -999,2500 ORHO -999,2500 NCNL 5900,0000 SFLU -48,8633 GR '-999,2500 ORHO -999,2500 NCNL SBO0,O000 SFLU -50.3633 GR -999,2500 DRH8 -999.2500 NCNL 92,8.398 GR -999,2500 NRAT -999,2500 FCNL 2.9026 ILD 94,6523 GR -999,2500 NRAT -999,2500 FCNL 3,8889 !LO 120.9023 GR -999,2500 NRAT .-99'9,2500 FCNL 2.5530 ILO 96,0898 GR -999.2500 NRAT · -999,2500 FCNL 2,8.362 ILO 104,7148 GR -999.2500 NRAT -999.2500 FCNL 2.7034 ILD 102,4023 GR -999,2500 NRAT -999,2500 FCNL 3,4827 ILD 101,4648 GR -999,2500 NRAT -999,2500 FCNL .2,7151 105,7?73 GR -999,2500 -999,2500 FCNL 2,5627 ILD 95,9648 GR -999,2500 NR~T -999,2500 FCNL 2,2463 ILO 104,6523 GR -999,2500 NR.&T -999,2500 FCNL 2,2834 ILO 9?,7148 GR -999,2500 NR~T -999.2500 FCNL -999,2500 -999,2500 -9'99,2500 3.3108 -999.2500 -999.2500 -999.2500 4,3328 -999,2500 -999,2500 -999.2500 2,9260 -999.2500 -999,2500 -999,2500 3.2542 -999.2500 -999.2500 -999.2500 3.0745 -999,2500 -999,2500 -999,2500 3.6233 -999.25~0 -999.2500 -999.2500 3.0510 -999.2500 -999.2500 -999.2500 3.0198 -999.2500 -999.2500 -999.2500 2.6350 -999.2500 -99'9.25!]0 -999.2500 2.6252 -999,2500 -999,2500 -999.2500 C~LI RNRA ILM CALI RNR~, ILM C AL I R NR~ iLM CALI RNRA ILM C&LI RNRA ILM CALl RNRA !LM CALI RNRA ILM CALI RNR,& iLM C&LI RNR& ILM CALi RNR~ ILM CALl RNRA -999.2500 -9'99.2500 3.2639 -999.2500 -999.2500 4.2859 ,-999.2500 -999.2500 2.8811 -999.2500 -999.2500 3.2249 -999.2500 -999.2500 3.0198 -999,2500 -999.2500 3.8401 -999.2500 -999.2500 3,0217 -999,2500 -999,2500 2.9749 -999.2500 -999.2500 2.5823 -999.2500 -999.2500 2.58a2 -999.2500 -999.2500 LV? 010.H02 VERIFICATION LISTING P6GE 8 OEPT SP RHOB NPHi OEPT RHOB NPHI SP RHOB N,PHI DEPT NPHI SP RHOB NPH! DEPT SP RHOB NPHI DEPT SP RHO~ NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI OEPT SP RHOB NPHI DEPT SP NPHI 5700,0000 SFLU -51,7595 GR -999,2500 DRHO -999,2500 NCNL 5600,0000 SFLU -51,2070 GR -999,2500 ORHO -999,2500 NCNL .5500,0000 SFLU -,45,2695' GR -999,2500 DRHO '-9'99,2500 NCNL 5400,0000 SFLU -48.7383 GR -999-2500 DRHO -999,2500 NCNL 5300.0000 S~LU -30.1758 GR -999.2500 ORHO -999.2500 NCNL 5200.0000 SFLU -51.8945 GR -999,2.500 DRHO -999.2500 NCNL 5100.0000 SFLU -54.3945 GR -999.2500 DRHO -999,2500 NCNL 5000,0000 SFLU -51.5523 GR -999.2500 ORHO -999,2500 NCNL 4900.0000 SFLU -55,4570 GR -999.2500 DRHS -999,2300 NCNL 4800,0000 SFLU -55.4258 GR -999,2300 ORHO -999.2500 NCNL 4780,0000 SFLU -42.6445 GR -999.2500 ORH~ -999.2500 NCNL 2.5393 ltd 110,0273 GR '-999,.2500 NRAT 999.2500 Fr - .N'L 2.2795 I:LD 104.4023 'GR -999,2'500 NRAT -999,2500 FCNL 0,5078 ILO 86.0898 GR -9'99,2500 NRAT -999,2500 FCNL 3.1487 iLO 96.2148 GR -999.2500 NRAT -999.2500 FCNL 2,6389 iLD 100,2148 GR -999.2500 NRAT -999,2500 FCNL 2,5920 ILD 90.6523 GR -999.2500 NRA'T -9'99,2500 FCNL 2.6272 ILO 97,839'8 GR -999.2500 NRAT -999,2590 FCNL 2.7092 ILO 83.0896 GR -999.2500 NR&I -999.2500 FCNL ~.473& ILD 82.2773 GR -9~9.2500 NRAT -999.2500 ~CNL 4.4929 ILO 86.2148 GR -999.2500 NRAT -999.2500 FCNL 2000.6875 iLC' 68.$398 GR -99'9.2500 NR4T -999.2300 FCNL 2,8010 -999'2500 -999.2500 -999.21500 1'8682 -999.2500 -999.2500 -999.2500 0.6489 -9'99.2500 -999,2500 -999.2500 3.5331 -999.2500 -999,2500 .-999.2500 3.1643 -999.2500 -999.2500 -999,2500 3,1995 -999.2500 -999.2500 -999.2500 2.6077 -999.2500 ,-999,2500 -999.2500 3.3225 -999.2500 -999.2500 -999,2500 5.0867 -999.2500 -999.2500 -999.2500 5.5007 -99~.2500 -999.2500 -999.2500 1!.1~,95 -999.2500 -999.2500 -999,2500 I L M C ALI RNRA ILM CALl RNRA I LM C ALI RNRA I L M C AL i RNRA ILM CALI RNR4 I LM CALl RNRA C ,AL I RNRA ILM C~LI RNR~ ILM CALl RNR~, ZLM CALl RNR~ ILH CALI RNR~ 2.7893 -999.2500 -999.2500 1.9278 -999.2500 '-999.2500 0,6660 -999.2500 -999.2500 3,5608 -999.2500 -999.2500 3-0608 -999,2500 -999.2500 3.0471 -999.2500 -999.2500 2.6741 -999.2500 -9 99 . Z 500 3.1272 -999.2500 -999,2500 ~.7703 -999.2500 -99'9.2590 4.5984 -999.2500 -99~.2500 2000.6875 -999.2500 -999.250~ LVP OlO.N02 VERIFICATION LISTING PAGE 9 ~ FILE TRAIcER *~ FiLE NAME :EDI'T .001 SERVICE NAME : VERSION ~ : DATE : M~X!NUM LENGTH : 1024 =IL~ TYPE : NEXT FILE NAME : ...... -,--,, FiLE HEADER FILE N4ME :EDIT SERVICE NAME : VERSION ~ O&TE : MAXIMUM LENGTH : FILE TYPE PREVIOUS FILE : .002 1024 '~:-';:~ DAT.~ FORMAT ENTRY BLOCKS 'DATUM SPECIFICATION MNEM SERVICE SERVICE ID ORDER ~ 9EPT GR CNL 0 ;:" TYP2 2 16 0 BLOC KS UN I'T F T G4Pl OEPT 4886.0000 OEPT 4800.0000 DEPT 4700.0000 OEPT 4600.0000 DEPT 4500.0000 OEPT 4400.000g GR GR GR GR GR GR ~PI LOG O0 O0 SIZE 1 1 4 1 i REPR CDD~ 6,5 66 73 65 66 66 ENTRY 0 1 60 .lin ! 0 API API API FILE SIZE TY~: CLASS MOO 000 O0 0 0 4 310 Ol 0 0 4 106.0273 87.3398 58.1680 52.9492 54.6367 5!.9~92 SPL REPR CODE 1 68 1 68 PROCESS (OCT.&L) 00000000000000 OOOOOO00000000 LVP 010.H02 VERIFICATION LISTING PAGE OEPT 4300.0000 GR OEPT b,ZO0.O000 GR DEPT 4100.0000 GR OEPT ,~O00.O000 GR OE~T 3900.0000 GR OEPT 3800.0000 G~ OEPT 3700.0000 GR DEPT 3600.0000 G~ DEPT 3500.0000 GR OEPT 3400.0000 GR OEPT 3300.0000 GR O~PT 3200.0000 GR OEPT 3100.0000 GR OEPT 3000.0000 GR DEPT 2900.0000 GR OEPT 2800.0000 GR DEPT 2700.0000 GR 9~T 2695.5000 GR 55.5242 46.4492 52.7'930 48.8242 62.7930 ,47.6367 52.8242 44.~492 37.7305 ~5.9180 53.5742 48.0742 32.6367 39.5117 55.6680 36.7305 30.8174 44.0742 ~* FiLE TRAILER ,~ Cite NAME :EOIT .002 SERVICE NAME : VERSION ~ : gATE : MAXIMUM LENGTH : 102~ FILE TYPE : NEXT FILE NAME : ~;~ T~PE TRAILER *~ SERVICE NAME :EDIT DATE :85/11/ 7 ORIGIN :0000 TAPE NAME :0917 LVP OiOoH02 VERIFICATIDN LISTING CONTINUATION ~ :01 NEXT TAPE N~ME : COMMENTS :]LIBRARY TAPE ~:~ REEL TRAILER SERVi:CE N~ME :EDICT DATE :85/111/ T ORIGIN : REEL N~ME :1~9247 CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :LiER~RY TAPE