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Home My WebLink About188-060MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-06 KUPARUK RIV UNIT 3O-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 3O-06 50-029-21824-00-00 188-060-0 W SPT 6386 1880600 1596 2375 2375 2375 2375 120 120 120 120 OTHER P Sully Sullivan 6/3/2024 MIT-IA post packer repair per 323-514 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 3O-06 Inspection Date: Tubing OA Packer Depth 860 1820 1790 1780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604104924 BBL Pumped:1.6 BBL Returned:1.5 Monday, July 22, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 999 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.22 15:12:10 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: BiSN Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8172'feet None feet true vertical 6836' feet None feet Effective Depth measured 8172'feet 7620'feet true vertical 6836' feet 6386' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7886' MD 6601' TVD Packers and SSSV (type, measured and true vertical depth) 7620' MD N/A 6386' 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: 4707' 4090' Burst Collapse Production Liner 8113' Casing 6814'8146' 4672' 115'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-060 50-029-21824-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025513 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3O-06 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~ ~~ INJECTOR ~~ ~ 323-514 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 F Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 7849-7859', 7867-7891', 7898-7918' 6571-6579', 6586-6605', 6611-6627' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov ON ONSBy Grace Christianson at 7:38 am, Dec 13, 2023 Digitally signed by Jan Byrne DN: OU=Wells AK, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.12.13 06:56:00-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 8/24/2023 ACQUIRE DATA PERFORM CBL-GR-CCL FOR PRE-BISN TREATMENT 8/25/2023 ACQUIRE DATA ***JOB CONTINUED FROM 8/25/23*** PERFORMED CBL-GR-CCL FOR PRE-BISN TREATMENT FROM TOP OF PLUG AT 7747' TO SURFACE. NO OBSTRUCTIONS DISCOVERED IN IA. JOB COMPLETE 10/6/2023 ACQUIRE DATA DRIFTED TUBING W/ 2.625" X 20' TO 7630' RKB. SET 2.80 X 6' JUNK CATCHER / w RBP STINGER ON TOP OF RBP 7747' RKB. REPLACE DMY W/ 1/4'' PORT OV @ 7556' RKB. READY FOR BiSN BEADS. 10/26/2023 ACQUIRE DATA DEPLOY 750 LBS / 7.70' OF BiSN BEADS IN THE 3.5" X 7" ANNULUS. READY FOR FOR ELINE. 10/29/2023 ACQUIRE DATA RIH W/ GR TO FIND TOP OF BiSN BEADS, LOG FROM ~7640' TO 7300' RKB, CONFER W/ TOWN, DETERMINE BiSN INTERVAL ~7596' TO 7606' (TOP OF BEADS 7596' RKB). POOH, CHANGED TOOL TO THERAMITE HEATER, RIH & MELT BEADS @ 7595' RKB, CCL STOP = 7578.1', CCL TO STOP POINT ON PRT = 17.9', CORRELATE TO TUBING TALLY DATED 10/24/2015, INITIATE THERAMITE HEATER, SET FOR 30 MINS. POOH, RUN IN WITH POST-MELT GR & RE-LOG INTERVAL. JOB IS READY FOR SL 11/15/2023 ACQUIRE DATA PULLED 1-1/2" OV FROM STA # 6, SET 1-1/2 " DMY VLV STA # 6 @ 7755' RKB, OBTAINED PASSING MITIA TO 3000 PSI, TAGGED TOP OF CATCHER @ 7741' RKB, LDFN, JOB IN PROGRESS. 11/16/2023 ACQUIRE DATA PULLED 2.80" X 6' CATCHER W/ RBP STINGER FROM 7741' RKB, EQUALIZED AND PULLED 2.725" 3-1/2" PIIP RBP FROM 7747' RKB. WELL READY FOR DHD. 11/20/2023 ACQUIRE DATA (AC-EVAL) DDT-IA (IN-PROGRESS) 11/21/2023 ACQUIRE DATA (AC EVAL) IA DDT IN PROGRESS. 12/10/2023 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED A TRACE OF DIESEL INTO TBG TBG LOCKED UP AT 3500 PSI PUMPED 7 BBLS METH INTO FL FOR A FREEZE PROTECT. 3O-06 BiSN Bead Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,940.0 3O-06 11/24/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull OV, set DMY. Pull Catcher and RBP 3O-06 11/16/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: DEPLOY 750 LBS / 7.70' OF BiSN PRE MELTED BEADS IN THE 3.5" X 7" ANNULUS 10/26/2023 claytg NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 lehallf NOTE: QTSV (Orbit Valve) at 3496' is NOT a safety valve, it does not fail to closed position. 10/25/2015 condijw 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 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,707.3 4,090.3 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,145.8 6,814.2 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth 7,634.6 Set Depth 6,397.2 String Max No 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 33.0 33.0 0.09 HANGER 7.063 Tubing Hanger Camero n CXS Gen 4 3.500 2,708.6 2,494.7 37.19 GAS LIFT 5.968 Camco MMG 2.915 4,217.3 3,705.9 38.85 GAS LIFT 5.968 Camoc MMG 2.915 5,414.9 4,642.4 39.87 GAS LIFT 5.968 Camco MMG 2.915 6,328.6 5,355.4 36.95 GAS LIFT 5.968 Camco MMG 2.915 7,021.4 5,908.2 37.30 GAS LIFT 5.968 Camco MMG 2.915 7,555.9 6,333.9 36.59 GAS LIFT 5.968 Camco MMG 2.915 7,613.0 6,379.8 36.39 Locator 4.210 Locator Sub Baker 3.000 7,620.5 6,385.8 36.35 SEAL ASSY 3.770 Baker GHB-22 locating seal assembly Baker 80/40 Seal assembl y 3.000 Top (ftKB) 7,620.2 Set Depth 7,886.0 Set Depth 6,601.2 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,620.2 6,385.6 36.36 PACKER 5.850 Baker F packer Baker F 4.000 7,623.5 6,388.2 36.34 PBR 5.040 80-40 PBR Baker 80/40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE 3.940 HES 3.5 X 2.82 X nipple HES X nipple 2.812 7,797.4 6,529.1 35.56 Liner 5.500 5.5 X 14 # J-55 STC Wear sox 5 15/16" OD on Wear rings Wear Sox 5.000 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) 7,596.0 6,366.1 36.46 OTHER BiSN BEADS MELTED FROM 7596' TO APPROX 7601' (ANNULUS OF 7" X 3- 1/2") 10/29/2023 2.992 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5" X 5.5" Whipstock Set 1° ROHS orientation, RA Tags at 7862.35 ft. 12/16/2015 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,708.6 2,494.7 37.19 1 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 4,217.3 3,705.9 38.85 2 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 5,414.9 4,642.4 39.87 3 GAS LIFT DMY RK 1 1/2 0.0 8/14/2016 Schlumb erger Camco MMG 0.000 6,328.6 5,355.4 36.95 4 GAS LIFT DMY RK 1 1/2 0.0 8/14/2016 Schlumb erger Camco MMG 0.000 7,021.4 5,908.2 37.30 5 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 7,555.9 6,333.9 36.59 6 INJ DMY RK 1 1/2 0.0 11/15/2023 Schlumb erger Camco MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing (Strips Kinked @ 35 deg.); 2 1/8" EnerJet 3O-06, 12/12/2023 3:05:47 PM Vertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 NIPPLE; 7,752.7 PACKER; 7,620.2 OTHER; 7,596.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 Tubing - Pup; 4,226.2 GAS LIFT; 4,217.3 Tubing - Pup; 3,502.4 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 KUP INJ KB-Grd (ft) 34.98 RR Date 6/24/1988 Other Elev 3O-06 ... TD Act Btm (ftKB) 8,172.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182400 Wellbore Status INJ Max Angle & MD Incl (°) 40.43 MD (ftKB) 5,500.00 WELLNAME WELLBORE3O-06 Annotation Last WO: End Date 10/25/2015 H2S (ppm) 150 Date 1/21/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,867.0 7,891.0 6,585.7 6,605.3 A-2, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing; 2 1/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1, 3O-06 9/23/1988 8.0 IPERF 45 deg. phasing; 4 1/2" Ultrapak Csg 3O-06, 12/12/2023 3:05:48 PM Vertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 NIPPLE; 7,752.7 PACKER; 7,620.2 OTHER; 7,596.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 Tubing - Pup; 4,226.2 GAS LIFT; 4,217.3 Tubing - Pup; 3,502.4 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 KUP INJ 3O-06 ... WELLNAME WELLBORE3O-06 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: BiSN packer repair 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk River Field 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8172 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Jan Byrne Contact Email: Contact Phone: Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jan.byrne@conocophillips.com 907-265-6471 KRU 3O-06 Kuparuk River Oil Kuparuk River Oil 6836 7747 6488 7747 Length Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7620 TVD/ 6386 MD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025513 188-060 P.O. Box 100360, Anchorage, Alaska 99510 50-029-21824-00-00 ConocoPhillips Alaska, Inc Size Proposed Pools: L-80 TVD Burst 7635 MD 115 4090 115 4707 68147 16 12 79 4672 8146 Perforation Depth MD (ft): 7849 - 7918 8113 6571 - 6627 10/15/2023 3.5 Baker F Packer, No SSSV m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.09.11 10:42:31-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne By Grace Christianson at 1:00 pm, Sep 11, 2023 323-514 10-404 DSR-9/12/23 X VTL 10/04/2023 X SFD 9/19/2023*&:JLC 10/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 13:26:33 -08'00'10/04/23 RBDMS JSB 100523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 11, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3O-06 (PTD 188-060) to install a BiSN plug for packer repair. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Proposal Summary for 3O-06 BiSN Packer Repair History: 3O-06 has been diagnosed as having a one-way packer leak from the Baker F Packer at 7620’ causing the IA pressure to increase while on injecƟon. ObjecƟve: Install BiSN beads into IA and melt into a solid plug to repair the packer leak. Proposal steps: 1. Run baseline CBL survey. 2. Set up well bore for bismuth bead applicaƟon. 3. Pump ~10’ of bismuth beads down the IA onto the packer. 4. Run post bead CBL to determine bead depth. 5. Run heater to melt beads into solid plug. 6. Run post melt CBL to verify bismuth plug top at ~7616’. 7. Replace OV with DV. 8. Perform MITIA and IA-DDT. 9. BOL and perform SW MITIA. 10. 30-day monitor for long term IA-DDT. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,940.0 3O-06 11/24/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced DV @ 7556 3O-06 3/1/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: QTSV (Orbit Valve) at 3496' is NOT a safety valve, it does not fail to closed position. 10/25/2015 condijw NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 lehallf 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 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,707.3 4,090.3 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,145.8 6,814.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.0 Set Depth … 7,634.6 Set Depth … 6,397.2 String Ma… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 33.0 33.0 0.09 HANGER 7.063 Tubing Hanger Camero n CXS Gen 4 3.500 2,708.6 2,494.7 37.19 GAS LIFT 5.968 Camco MMG 2.915 4,217.3 3,705.9 38.85 GAS LIFT 5.968 Camoc MMG 2.915 5,414.9 4,642.4 39.87 GAS LIFT 5.968 Camco MMG 2.915 6,328.6 5,355.4 36.95 GAS LIFT 5.968 Camco MMG 2.915 7,021.4 5,908.2 37.30 GAS LIFT 5.968 Camco MMG 2.915 7,555.9 6,333.9 36.59 GAS LIFT 5.968 Camco MMG 2.915 7,613.0 6,379.8 36.39 Locator 4.210 Locator Sub Baker 3.000 7,620.5 6,385.8 36.35 SEAL ASSY 3.770 Baker GHB-22 locating seal assembly Baker 80/40 Seal assembl y 3.000 Top (ftKB) 7,620.2 Set Depth … 7,886.0 Set Depth … 6,601.2 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd 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) 7,620.2 6,385.6 36.36 PACKER 5.850 Baker F packer Baker F 4.000 7,623.5 6,388.2 36.34 PBR 5.040 80-40 PBR Baker 80/40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE 3.940 HES 3.5 X 2.82 X nipple HES X nipple 2.812 7,797.4 6,529.1 35.56 Liner 5.500 5.5 X 14 # J-55 STC Wear sox 5 15/16" OD on Wear rings Wear Sox 5.000 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) 7,747.0 6,488.1 35.78 RBP 2.725" 3-1/2" PIIP RBP WITH 2.72" EQ. VALVE & 2.84" BULLNOSE. OAL = 4.89' CPP3 5174 11/16/2022 0.000 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5" X 5.5" Whipstock Set 1° ROHS orientation, RA Tags at 7862.35 ft. 12/16/2015 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,708.6 2,494.7 37.19 1 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 4,217.3 3,705.9 38.85 2 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 5,414.9 4,642.4 39.87 3 GAS LIFT DMY RK 1 1/2 0.0 8/14/2016 Schlumb erger Camco MMG 0.000 6,328.6 5,355.4 36.95 4 GAS LIFT DMY RK 1 1/2 0.0 8/14/2016 Schlumb erger Camco MMG 0.000 7,021.4 5,908.2 37.30 5 GAS LIFT DMY RK 1 1/2 0.0 8/15/2016 Schlumb erger Camco MMG 0.000 7,555.9 6,333.9 36.59 6 GAS LIFT DMY RK 1 1/2 0.0 3/1/2023 Schlumb erger Camco MMG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing (Strips Kinked @ 35 deg.); 2 1/8" EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing; 2 1/8" EnerJet 3O-06, 3/2/2023 9:44:05 AM Vertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 Liner; 7,797.4 XO Enlarging (Tubing); 7,796.4 NIPPLE; 7,752.7 RBP; 7,747.0 PBR; 7,623.5 SEAL ASSY; 7,620.5 PACKER; 7,620.2 Locator; 7,613.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 GAS LIFT; 4,217.3 QSTV Tubing Shut Off; 3,495.9 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 KUP INJ KB-Grd (ft) 34.98 RR Date 6/24/1988 Other Elev… 3O-06 ... TD Act Btm (ftKB) 8,172.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182400 Wellbore Status INJ Max Angle & MD Incl (°) 40.43 MD (ftKB) 5,500.00 WELLNAME WELLBORE3O-06 Annotation Last WO: End Date 10/25/2015 H2S (ppm) 150 Date 1/21/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,898.0 7,918.0 6,611.0 6,627.4 A-1, 3O-06 9/23/1988 8.0 IPERF 45 deg. phasing; 4 1/2" Ultrapak Csg 3O-06, 3/2/2023 9:44:06 AM Vertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 Liner; 7,797.4 XO Enlarging (Tubing); 7,796.4 NIPPLE; 7,752.7 RBP; 7,747.0 PBR; 7,623.5 SEAL ASSY; 7,620.5 PACKER; 7,620.2 Locator; 7,613.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 GAS LIFT; 4,217.3 QSTV Tubing Shut Off; 3,495.9 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 KUP INJ 3O-06 ... WELLNAME WELLBORE3O-06 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3O-06 (PTD 188-060) Report of suspect IA pressure Date:Wednesday, October 5, 2022 10:21:47 AM Attachments:AnnComm Surveillance TIO for 3O-06.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, October 4, 2022 8:20 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3O-06 (PTD 188-060) Report of suspect IA pressure Chris, KRU 3O-06 (PTD 188-060) is exhibiting a slow IA pressure increase subsequent IA pressure bleed. The well was recently WAG’d to water and it is believed there may be some residual gas entrained in the IA fluids. The plan is for DHD to perform initial testing to include an MITIA, pack off tests, and then de-gas the IA after which the well will be put on a 30 day monitor period. Any required paperwork for corrective action or continued injection will be submitted upon conclusion of the diagnostics and monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3O-06 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING3O-06 2022-08-19 2400.0 1600 -800.0 IA3O-06 2022-08-19 40.0 80 40.0 OA3O-06 2022-09-03 2400.0 1400 -1000.0 IA3O-06 2022-09-16 2395.0 1700 -695.0 IA3O-06 2022-09-22 1950.0 1200 -750.0 IA 3O-06 2022-09-29 752.0 355 -397.0 IA 3O-06 2022-09-30 420.0 300 -120.0 IA Casing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.062 Top (ftKB)36.0 Set Depth (ftKB)115.0 Set Depth (TVD) …115.0 Wt/Len (l…62.50 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.921 Top (ftKB)35.0 Set Depth (ftKB)4,707.3 Set Depth (TVD) …4,090.3 Wt/Len (l…36.00 GradeJ-55 Top ThreadBTCCasing DescriptionPRODUCTION OD (in)7 ID (in)6.276 Top (ftKB)33.0 Set Depth (ftKB)8,145.8 Set Depth (TVD) …6,814.2 Wt/Len (l…26.00 GradeJ-55 Top ThreadBTCTubing StringsTubing DescriptionTUBING - 2015 WO - UPPER COMPLETION String Ma…3 1/2 ID (in)2.990 Top (ftKB)33.0 Set Depth (ft…7,634.6 Set Depth (TVD) (…6,397.2 Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE 8rdCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.8 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description TUBING - 2015 WO - LOWER COMPLETION String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 7,620.2 Set Depth (ft… 7,886.0 Set Depth (TVD) (… 6,601.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,620.2 6,385.6 36.36 PACKER Baker F packer 4.000 7,623.5 6,388.2 36.34 PBR 80-40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE HES 3.5 X 2.82 X nipple 2.812 7,797.4 6,529.1 35.56 Liner 5.5 X 14 # J-55 STC Wear sox 5 15/16" OD on Wear rings 5.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5" X 5.5" Whipstock Set 1° ROHS orientation, RA Tags at 7862.35 ft. 12/16/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing (Strips Kinked @ 35 deg.); 2 1/8" EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing; 2 1/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1, 3O-06 9/23/1988 8.0 IPERF 45 deg. phasing; 4 1/2" Ultrapak Csg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,708.6 2,494.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 2 4,217.3 3,705.9 Camoc MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 3 5,414.9 4,642.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/14/2016 4 6,328.6 5,355.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/14/2016 5 7,021.4 5,908.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 6 7,555.9 6,333.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 Notes: General & Safety End Date Annotation 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/25/2015 NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE: Orbit Valve is NOT a safety valve, it does not fall to closed position. CommentSSSV: NONE3O-06, 9/2/2016 10:25:23 AMVertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 Liner; 7,797.4 XO Enlarging (Tubing); 7,796.4 NIPPLE; 7,752.7 PBR; 7,623.5 SEAL ASSY; 7,620.5 PACKER; 7,620.2 Locator; 7,613.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 GAS LIFT; 4,217.3 QSTV Tubing Shut Off; 3,495.9 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0HANGER; 33.0CTD L1 Window; 0.0 AnnotationLast Tag: SLM Depth (ftKB)7,940.0 End Date11/24/2015 AnnotationRev Reason: WAIVER CANCELED Last Mod Bypproven End Date9/2/2016KUP INJ KB-Grd (ft)34.98 Rig Release Date6/24/1988AnnotationLast WO:End Date10/25/2015 3O-06H2S (ppm)150 Date1/21/2016...TDAct Btm (ftKB)8,172.0Well AttributesWellbore API/UWI500292182400 Field NameKUPARUK RIVER UNIT Wellbore StatusINJ Max Angle & MDIncl (°)40.43 MD (ftKB)5,500.00 MEMORANDUM TO: Jim Regg P.I.Supervisor ( l FROM: Adam Earl Petroleum laspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 30-06 KUPARUK RIV UNIT 30-06 See: Inspector Reviewed By: P.L Supry Comm Well Name KUPARUK RIV UNIT 30-06 API Well Number 50-029-21824-00-00 Inspector Name: Adam Earl Permit Number: 188-060-0 Inspection Date: 6132021 - Insp Num: mitAGE210607103251 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T 30-06 - Type Inj T w - TVD 6386 Tubing z600 . z600 - z600 z600 ' PTD 1880600 Type Test SPT Test psi 1596 IA 420 2000 1940 - 1930 ' BBL Pumped: 1.4 BBL Returned: 3 OA 40 40 40 40 Interval 4YRTST Notes: MIT 1A Tuesday, June 8, 2021 Pave I of I 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Temporary flowback > 30 days Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8172 feet None feet true vertical 6836 feet None feet Effective Depth measured feet 7620 feet true vertical feet 6386 feet Perforation depth Measured depth 7849 - 7918 feet True Vertical depth 6571 - 6627 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 7796 6528 Packers and SSSV (type, measured and true vertical depth) Baker F Packer No SSSV 7620 6386 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name:Devin Kozak Authorized Title:Petroleum Engineer Contact Email:devin.kozak@conocophillips.com Contact Phone:(907) 263-4121 Senior Engineer: Senior Res. Engineer: Collapse 6,814 Burst 78,146 TVD 115 4,090 Casing Structural 16 12 Authorized Signature with date: Authorized Name: Devin Kozak Liner Length 79 4,672 8,113 5. Permit to Drill Number: 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-082 1400 Size Kuparuk River Field / Kuparuk River Oil Pool measuredPlugs Junk measured Conductor Surface Intermediate Production ADL025513 1369 700 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-060 50-029-21824-00 None P. O. Box 100360, Anchorage, Alaska 99510 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1251015 Casing Pressure Tubing Pressure 4,707 0 Oil-Bbl measured true vertical Packer 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 2. Operator Name Name: ConocoPhillips Alaska, Inc. 8. Well Name and Number:KRU 3O-06 WINJ WAG 47 Water-Bbl MD 115 Development Service GINJ SUSP SPLUG Gas WINJ WAG Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:12 pm, Jun 09, 2020 Devin Kozak Digitally signed by Devin Kozak Date: 2020.06.09 09:58:32 -08'00' DSR-6/9/2020VTL 7/27/20 SFD 6/10/2020 RBDMS HEW 6/10/2020 1 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 June 9th, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 3O-06, 3O-06L1, 3O-06L1-01, 3O-06L1-02, 3O-06L1-03, and 3O-06L1-04 from Oil Production to Water Alternating Gas Injection on 5/31/2020. 3O-06 was operating as an injector and had been injecting until 11/2/2018 when it was shut-in and flow back operations started 2/27/2019 for reservoir pressure management ahead of offset CTD drilling. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 3O-06 (PTD# 188-060), 3O-06L1 (PTD# 215-211), 3O-06L1-01 (PTD# 215-212), 3O-06L1- 02 (PTD# 215-213), 3O-06L1-03 (PTD# 215-214), and 3O-06L1-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application, Well schematic, Well operations report Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 35.0 Set Depth (ftKB) 4,707.3 Set Depth (TVD) … 4,090.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 33.0 Set Depth (ftKB) 8,145.8 Set Depth (TVD) … 6,814.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING - 2015 WO - UPPER COMPLETION String Ma… 3 1/2 ID (in) 2.990 Top (ftKB) 33.0 Set Depth (ft… 7,634.6 Set Depth (TVD) (… 6,397.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.8 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description TUBING - 2015 WO - LOWER COMPLETION String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 7,620.2 Set Depth (ft… 7,886.0 Set Depth (TVD) (… 6,601.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,620.2 6,385.6 36.36 PACKER Baker F packer 4.000 7,623.5 6,388.2 36.34 PBR 80-40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE HES 3.5 X 2.82 X nipple 2.812 7,797.4 6,529.1 35.56 Liner 5.5 X 14 # J-55 STC Wear sox 5 15/16" OD on Wear rings 5.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5" X 5.5" Whipstock Set 1° ROHS orientation, RA Tags at 7862.35 ft. 12/16/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing (Strips Kinked @ 35 deg.); 2 1/8" EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2, 3O-06 6/5/1989 12.0 APERF 60 deg. phasing; 2 1/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1, 3O-06 9/23/1988 8.0 IPERF 45 deg. phasing; 4 1/2" Ultrapak Csg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,708.6 2,494.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 2 4,217.3 3,705.9 Camoc MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 3 5,414.9 4,642.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/14/2016 4 6,328.6 5,355.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/14/2016 5 7,021.4 5,908.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/15/2016 6 7,555.9 6,333.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 Notes: General & Safety End Date Annotation 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/25/2015 NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE: Orbit Valve is NOT a safety valve, it does not fall to closed position. Comment SSSV: NONE3O-06, 9/2/2016 10:25:23 AM Vertical schematic (actual) PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 Liner; 7,797.4 XO Enlarging (Tubing); 7,796.4 NIPPLE; 7,752.7 PBR; 7,623.5 SEAL ASSY; 7,620.5 PACKER; 7,620.2 Locator; 7,613.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 GAS LIFT; 4,217.3 QSTV Tubing Shut Off; 3,495.9 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 Annotation Last Tag: SLM Depth (ftKB) 7,940.0 End Date 11/24/2015 Annotation Rev Reason: WAIVER CANCELED Last Mod By pproven End Date 9/2/2016 KUP INJ KB-Grd (ft) 34.98 Rig Release Date 6/24/1988 Annotation Last WO: End Date 10/25/2015 3O-06 H2S (ppm) 150 Date 1/21/2016 ... TD Act Btm (ftKB) 8,172.0 Well Attributes Wellbore API/UWI 500292182400 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 40.43 MD (ftKB) 5,500.00 3O-06 DAILY REPORT WELL OPERATIONS 5/31/2020: 3O-06 was converted from production to injection to provide injection support at 3O-04. Flow lines have been bolted back to normal injection and a passing MIT-IA to 3050 psi was complete. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon El Plug Perforations Fracture SfimulaLi Pull Tubing LI Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulal❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑-erforate New Pool ❑ Repair WeD Re-enter Susp Well ❑ Other: Temporary ftowback > 30 days 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service 2] 188-060 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21824-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 30-06 ADL025513 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,172 feet Plugs measured None feet true vertical 6,836 feet Junk measured None feet Effective Depth measured feet Packer measured 7620 feet true vertical feet true vertical 6386 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 115 Surface 4,672 12 4,707 4,090 Intermediate Production 8,113 7 8,146 6,814 Liner Perforation depth Measured depth 7849-7918 feet True Vertical depth 6571 -6627 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 7796 6528 Packers and SSSV (type, measured and true vertical depth) Baker F Packer No SSSV 7620 6386 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf I Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation: 0 0 1950 1080 12649 Subsequent to operation: 111 20 12269 11450 1110 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 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 ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Name: Devin Kozak Authorized Name: Davin Kozak Contact Email: devin.kozak@oonocophillips.com Authorized Title: Petroleum Engineer Authorized Signature: Date: 8/16/2019 Contact Phone: (907) 2634121 farm 10-404 Revised 4/2017 % IMMS4" AUG 2 3 2019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 August 161h, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 30-06, 30-0611, 30-0611-01, 30-06L1-02, 30-0611-03, and 30-0611-04 Water Injection Service to Oil Production. 30-06 was operating as an injector and had been injecting until 11/2/2018 when it was shut-in and flow back operations started 2/27/2019 for reservoir pressure management ahead of offset CTD drilling. A second 10-404 will be submitted after completion of the temporary flowback and conversion from production back to injection. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 30-06 (PTD# 188-060), 30-06L1 (PTD# 215-211), 30-061-1-01 (PTD# 215-212), 30-061-1- 02 (PTD# 215-213), 30-061-1-03 (PTD# 215-214), and 30-06L1-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Well Schematic r KUP [NJ 30-06 nocoI Ips ell Attributes Max Angle 8 MD TO Masks, Inc. Wenhore APl/uwI FiYd Nemo wellsorestales nc11°I mG (noel Act BpminKe) 500292182400 KUPARUK RIVER UNIT IN J 4043 5,500.00 8,1720 conheanr H261ppml D. AnnoWlon EnGOale KBGrtl IHI ip RNmse Oete SSSV:NONE 150 1212016 Last Vq: 10252015 34.88 &20/1988 apo5.szmts 1O2523aM ¢e x me v ac Annatanon Depot bah. AnnotationtssIMUOBy End DM cTD a weme,., 0o Haa4G9R a,G Last Tag: SLM ],940.0 lllM4aOl5 Rev Reason: WAMERCANCELED ppeven 9ID2016 asmg Strings - Casing oeecrip0on wfnl lo(Inl Tup IH✓.al SN Depth (nRel fict Depth 177 WVLen B_Grade Top TM1rehl NDUCTOR i6 15.062 36.0 115.0 1150 62.50 H40 WELDED CO11 Casing Oescripaon /Olin Top@KBI 3etOry161HKB1 fiat"Ne"lrvDk..---p.. Grade rop iM1rM lot,(n SURFACE 95/8 8.921 350 4,707.) 4090.3 XDC55 BTC Casing pescopnon Ophn1 10(12 Top1aNR1 Bel OepIM1 IH FR sNDep01Ne, -en,... Grade Top TRraG PROOUOTION 7 6.2]6 330 8.145.8 8,8142 2800 J-55 BTC I Tubing Strings Tueto g Oescriplinn smog ma... TUBING-20151NO- 3112 /olio) 2.990 rop lnl<BI 33.1J sal OepP ln.. ],634.6 6el Depihln01... 6,39].2 wllmnH 9.30 Grade L-80 Top eonnMmn EUE Spot UPPER coNpULiDP. ]e.On 150 COMPLETION Completion Details GAS LIFT. vC8.6 uommau0 Top lHKB1 Top(Teri 10x8/ Top 1201 M) uem Gee Done Is 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 ],6130 6.379.8 36.39 Locator Locator Sub 3.000 ]620.5 (L385,81 35.35 1 SEAL ASSYBaker GHB22IawingsealassendA 3.000 I...no Descrlgbn Shing Ma...1Dllnl Top (flKBI 9H CepiM1 (R. Se[ "'ped I Ivie .WIgEM) GIwN Top Don on 0. T4,q sM14 OH', 9496.9 TUBING 2015M 3112 2.992 7,620.2 ],886.0 6,601.2 9.30480 EUE&tl LOW R COMPLETION _ Gompletipn Details Nominal ID Top lnRel Top(OD)MID Top I.F. l'1 Item Ges Gm Ilnl GASLIF'D4DTTa ],6202 6,305.6 36.36 PACKER BdkerFpacker 4.000 ].UBS 6,308.2 36.36 PBR BOdO PBR 6.000 ],752.] 64928 35.75 NIPPLE HES 35 X 2.82 X mpge 2.512 8529.1 35.56 Liner 5.5X14#J-55 STC R6arso. 515/16"OD on Wear 5.000 Dogs 6VRFACE: 350.4]%3 Other lu Hole ryWreline retrievable plugs, valves, pumps, fish, etc.) TopING Top Incl Top IM1KDI (nK61 I°1 Des Cam gun Gate IDllnl ],855 D 6,5]60 3539 VJr11P3TOCK Sake, an If Cella 3.5"X 5.5" Whipstock Sell' 12/16/2015 GPS LIFT: 5.4149 ROHS onenlalion. RA Tags at ]862.35 R. Perforations & Slots shot Den IF TOM) She/TVG) pet. Top (deal B"IRM) (roof Will Zone Done p Type Com GAS 111.,a.9 78490 ],859.0 6,571.1 6,579.2 A-3,30-06 6/5/1889 12.0 APERF80 deg.phasiog(Ships Opked ® 35 tleg ): 2 1 W' EneNat ].86].0 7,8910 6.585.7 65053 A°2,30-06 6/5/1989 120 APERF 60 tleg. phasing', 21R" Eneolet GAB LIFT', 1 ova 7,898.0 7,918.0 8,6110 6,627.4 A-1,30-06 9/23/1980 8.0 TP -ERF 45 deg.phasing: 4 VT Wrapak Cog Mandrel Inserts s ai GPSLIFT;75559 N Teo DDD) VmW Ierch Polska Na. Red Top (RKB1 (nKB) Make Madel 00 001 Sery Type iypa fol (psi) Run OM Com 1 2,]086 2694.] Cameo MMG 112 GASLIFT DMY RK 0.000 00 &152016 2 4.21].3 37059 Cameo MMG 1112 G.SLIFT DMY RK 001X1 0.0 &152018 3 5,414.9 46624 Cameo MMG 11/2 GAS LIFT DMY RK 0.000 00 &142018 4 8,3286 5.355.4 Cameo MMG 11/2 GASLIFT DMV RK 0.000 00 &1012016 thump. T6ta.0 5 ].021.4 5,9082 Cameo MMG 11/2 GAS LIFT DMY RK 0000 00 8/152016 6 ],5559 6,333.9 Cameo MMG 1112 GAS LIFT DMY RK 0.000 00 1024/2015 PACKER:Ta20.] SEA. May;7ZL5 Notes: General IISafety FWI6Tf.5 Fee! pato Annotapmn 1211/2010 NOTE: View SOhemalicw/Alaska Gchemalic9.0 1025/2015 NOTE: Upon Valve Conlml eneNrystem at Wellhead marked Opep/Cbfie. 10125/2015 NOTEcost Valve is NOT a safety valve, it does not /all to closed ponabon. NIPPLE:7,T337 XOEnte igjeetI :T]98f Lire,: 7.797A APEPF;]8a9671see 0- WHIPSTOLK7.. APERF, 7810- IPERF:Ta9907,9190� PROOUCTION:Ma 146.9 30-06 DAILY REPORT WELL OPERATIONS 2/27/2019: 30-06 was converted from injection to production to reduce the reservoir pressure in the fault block surrounding 30-04. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Devin Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-06 Permit to Drill Number: 188-060 Sundry Number: 319-082 Dear Mr. Kozak: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www.00gcc.alcsko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -ep—�� Daniel T. Seamount, Jr. Commissioner , / DATED this Z 5 -day of February, 2019. RBDMS%UFR % a 2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 `E3 2 2 2019 A( GCk,r 1. Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate Li Repair -Well LJ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Temporary flowback> 30 day4Z 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli sAlaska Inc. Exploratory ❑ Development ❑ Stmtigraphic ❑ Service Q 188-060-0 3. Address: 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-21824-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ciA Will planned perforations require a spang exception? p7 Yes El El 30-06 9. Property Designation (Lease Number): , 3, 10. Field/Pool(s): ADL025513 crlry Kuparuk River Field / Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,172' 6,836' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' Surface 4,672' 12" 4,707' Intermediate Production 8,113' 7" 8,146' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3.500" L-80 7,886' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER F PACKER, no SSSV MD= 7620 TVD= 6386 12. Attachments: Proposal Summary Laj Wellbore schematic 13. Well Class after proposed work: , Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stmtigmphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for . 15. Well Status after proposed work: Commencing Operations: 2/25/2018 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the. foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Devin Kozak Contact Name: Devin Kozak Authorized Title: Petroleum Engineer Contact Email: devin.kozak@conocophillips.com Contact Phone: (907) 263-4121 Authorized Signature: Date: 2/21/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: {✓-,v� I - O Plug Integrity ❑ BOP Test E]Mechanical Integrity Test E] Location Clearance Other. Z 6 2019 Post Initial Injection MIT Req'd? Yes F-1No F-1RBDWAJEB Spacing Exception Required? Yes No D?11 Subsequent Form Required: [� APPROVED BYJ / 7 r I �I Approved by: COMMISSIONER THE COMMISSION Date: CC��I(!/ GG�� l I (�(}`,��(` /�� R I �/1t I'A\I rK&it Z6r'GaR Submit Form and �J` ^`i!8rm 1oa03 Revised 4/2017 Approved appli�oQi�vjllli6r118m{rRh�f the date of approval. Aahment:in Duplicate iUU q ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 February 2151, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to temporarily flow back Kuparuk River Unit Well 30-06, 30-061-1, 30-061-1-01, 30-061-1-02, 30-061-1-03, and 30-0611-04 Water Injection Service to Oil Production. The purpose of the temporary flowback, exceeding 30 days is to reduce the reservoir pressure in aau oc su oun ing uparu -aver Unit Well 30-04 for Coiled Tubing Drilling eve opmen . e ow ac wi e p to re uce t e reservoir pressure in the au oc or lower rilling mud weight for the 30-04 CTD drilling candidate. Initial flowback of 30-06, 30-06L1, 30-061-1-01, 30-061-1-02, 30-0611-03, and 30-0611- 04, upon approval, is targeted on February 25th, 2019. • Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 30-06 (PTD# 188-060), 30-06L1 (PTD# 215-211), 30-061-1-01 (PTD# 215-212), 30-06L1-02 (PTD# 215-213), 30-061-1-03 (PTD# 215-214), and 30-0611-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application KUP INJ WELLNAME 30-06 WELLBORE 30-06 /�( 'r Well Affiibutes Max Angle d MD TD corweoPhllhps FhIEName WellOore APYUW WeIIti e3WWi gIe&) p B flxB) Alaska,Inc. KUPARUKRIVERUNIT 500292182400 INJ 43 550000 8.1720 poae.'I2+npletzmN w4 Last Tag va4tl ecPwrake Wdo Annotation retargets)End Dale Viexbo` teat Mad By ......_........., cro Ll w.w„4;op., .............. --MANGER; Lest Tag: BLMretargets)],9400 ....wu15 JO -O6 lehallt sadLast Rev Reason AnraYWn End pate weleore 111""d6y Rev Reason: WAIVER CANCELED I.UNi 30-06 pprwen Casing strings CaslnO Descrlptlon pD (in) ID pn) Top beat Set proes pike) SN Dept. nVp)... WY Lm p... Grade Top IN.. CONDUCTOR ifi 15.06 36.0 115.0 1150 62.50 H-00 WELDED I .slog Des=nptian oD td,) IDpq Tap ribi semePm Axel se mind, (I.,.- p.. Grade Tap Tnread SURFACE 9510 8.92' 35.0 4,]0].3 4,090.3 38.00 Jb5 BTC Casing DescriptionWpn) mpro TOP IN.).10epM Me) Set Dapm"DI... WIRen p... G2de Tdpi4Rod DmxpuCTOR;33.mitao PRODUCTION 7 6.28 33.0 0,1458 6,814.2 26.00 J-55 eTC Tubing Strings GAS tG[2T®e Tubm.........ion String Ma...ra(io) TUBING -2015 WO- 3112 2.99 aDIME) 'm 330 Joel Depth(&.bN ],634.6 Depm LRAR (... 6,397.2 Wlpbm 9.30 Grade LA0 iap Conn -on' EUE Brd UPPER COMPLETION Completion Details p6NTWY,g 51,NOk. a.49 Top lope) ion p) Top'nel IN. Ceti Com Nord- lppn)1 33.0 33.01 0.09 HANGER Tubing Hanger 3.500 ],813.03fi.J9 Locabr Locator Sub 3.000 GAS uFr; 4,gna ],62.5 6,385.0 36.J5 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tu N"T pewsiption String SL._Iepn) Top lnl(B) PH mepm lM1. Se<pepMpVpj l... WIIIMq Gnda Tpp CmneGun TUBING -2015 WO- JV2 2.99 ],620.2 ],886.0 6,6012 9.30 L-80 EUE Brd LOWER COMPLETION Completion Details SURFACE; S.i,noa Top(TVD) Topl. Nominal Topa) (n..) pl Item Cas cora V(nl 1,629.2 6,385.6 36.38 PACKER BekerFmdker 4.000 GARUFYatl40 7,623.5 8,3882 3834 PBR 8640 PBR 4000 7,7527 8,492.6 35]5 NIPPLE HES 3.5 X 282 X nipple 2812 7,7974 8529.1 35.S6Liner 5.5X144J-55 STC Wearsox 515/16"OD on Wearnngs 5000 GAP UK; am, Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) TOPTo.ln=I Top lflKal mkim I') [N. Com flan Dah I. and ],8550 00IOU 3 Jll WHIPSTOCK Baker Gen It Delb0.0"Whipsleck 1 ROHS 1141WZUI orientation, RA Tags at]8fi2.358- 5 G4sL 7,mta Perforations d Slots shat IDp(rvml BIm ITV.) (,NmPl GA6 GFi; 7.S$a ToplKKa) BlmpinB) (.Kul xl(BI Llnked IDm pale I Type Co. ],8490 7,859.0 6,5]1.1 8,5]9.2 A3, 30-06 &511989 120 APERF 60 deg, phasing(Serps Kinkell @ 35 deg.); 21$ EnerJet ],867.0 7,891 U 6,585.7 6,605.3 A$ 30-06 &91989 12.0 APERF 60 deg. phasing; 2118" man7,B13.p Eroded ],8980 7,9180 8611.0 6,62].4 A-1,30-06 92311988 8.0 IPERF 45 peg. phesing;4 2" PA.T® KFR.a Ultrapak Cap SEAL A86Y:],a E PER. Me Mandrel Inserts 61 ml H ToftKB) WFre Laleb Po(in) TRO Run ToppxB) (2,49 Make Madel rap (in) Tyq IW) Runmale Com K 0.0 1 2,]086 2,494) Camra MMG 112 GAS LIFT DMV RK o.ODD 0.0 &1&2016 LIF xmPta:7.7527 2 4,217.3 3,705.9 Cammc MMG 112 GAS LIFT DMY RK 0.000 0.0 &1512016 3 5,4149 4,642.4 G.R. MMG 118 GAS LIFT DMY RK 0000 0.0 13/1412016 4 6,328.6 5,355.4 Camco MMG 1 112 GAS LIFT DMY RK 0.000 0.0 IV14M16 xo EdapFg (ruboyh T,TP5.4 5 ],021.4 5,900.2 Cameo MMG 1112 GAS LIFT DMY RK 0.000 0.0 131152016 6 7,555.9 6,333.9 Camra MMG 1112 GAS LIFT DMY RK 0.000 0.0 108412015 Notes: General d Safety End pale Annodaon 12/12010 NOTE: View Schematic wl Alaska Schema&9.0 ua7.re 4 10252015 INl Orbit V.11.1SNOTa6a"VaNe,itdoesnottallWoosedposition. 10/262015 NOTE: ONit Valve Control lineslsyskm at Wellhead marked OpenlClose. APEINFJ 4a67.8aalt� VMIP6TOCK 7si APERR AEPLLlraaIA� R FRF:7,Mp7.xap- pRooucnox; aaoe,las.e • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg 2 P.I.Supervisor ' \efl c4zo/t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-06 FROM: Chuck Scheve KUPARUK RIV UNIT 30-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-06 API Well Number 50-029-21824-00-00 Inspector Name: Chuck Scheve Permit Number: 188-060-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605172320 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-06 Type Inj W'TVD 6386 - Tubing 2850 2850 ' 2850 - 2850. PTD 1880600 Type Test SPT Test psi 1596 , IA 1140 2000 - 1960- 1950 - BBL Pumped: I • BBL Returned: 0.9 - OA 280 280 - 280 - 280 - Interval I 4YRTST P/F P ✓' Notes: SCANNED Auf.i 3 0 2017,. Thursday,June 15,2017 Page 1 of I STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG (�/ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-0600 3.Address: 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-21824-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/ Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8172 feet Plugs(measured) None true vertical 6836 feet Junk(measured) None Effective Depth measured 8063 feet Packer(measured) 7620 true vertical 6746 feet (true vertical) 8386 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 115' 115' SURFACE 4672' 9 5/8 4707' 4090' PRODUCTION 8113' 7 8146' 6814' RECEIVED Perforation depth: Measured depth: 7849-7859; 7867-7891; 7898-7918U�a r True Vertical Depth: 6571-6579; 6586-6605; 6611-6627 3I20i6 ,A0GCC Tubing(size,grade,MD,and ND) 3 1/2 ,L-80, 7886 MD, 6528 TVD Packers&SSSV(type,MD,and TVD) SSSV= None PACKER= BAKER F PACKER @ 7620 MD and 6386 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCJAN AN 2 7 2 i? 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 5848 540 1076 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p, Exploratory r Development r Service J Stratigraphic r" Copies of Logs and Surveys Run16.Well Status after work: r Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-389 Contact Darrell Humphrey/Bob Christensen Email: n1139@conocophillips.com Printed Name Rob D. ristens;i Title: NSK Production Engineering Specialist Signaturei) Phone:659-7535 Date VgD// 0 vTG q/z / IC, t Form 10-404 Revised 5/2015 / G RBDMS Submit Original Only UV SEP - 1 2016 • • 30-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/15/16 PULL GLV @ 2708' RKB, PULL OV @ 7021' RKB. SET DV'S @ 7021, 4217 &2708' RKB. CIRC-OUT 165 BBLS INHIBITIED SEAWATER & 90 BBLS DIESEL DOWN TBG UP IA TAKING RETURNS TO PRODUCTION ON 30-08. U-TUBE TO BALANCE FREEZE PROTECT. PERFORM PASSING MIT-IA TO 2500psi, PULL CATCHER @ 7752' RKB, JOB IN PROGRESS 08/16/16 PULLED 2.81"XX PLUG W/GAUGES (2575 PSI) @ 7752' RKB. JOB COMPLETE. 08/18/16 Open well to Injection service 08/28/16 (ISW) INITIAL STATE WITNESSED (Guy Cook) MITIA PASSED TO 3300 PSI • IIv- t KUP INJ 30-06 ConocoPhil/118SI18lips, ( Well Attelautee Men . Ie&MD' ID , a)e ANIttit FIa )erne Weasor•Sinlus note) DA) 'Act atm(IMO L.--,,,,,eh.:,, '1 500292182400 KUPARIN(RIVER UNIT IINJ 40.43 5,500.00 8,172.0 ... Comment RS bpm) Date Annotation End Date Ke-Grd(Al 1 Rb Release Del 00.0r e/12010 MAIDS AM .... SSSV;NONE 150 12112016 last WO. 1012512015 34.98 6/2411988 _ Verner schemes lmeml) . -......... Mnotaltcn Depth pee) End Me Annotation od9y "End6nln CTD virAwio«ao� last Tag;$LM 7,940.0 11/24/2015 Rev Reason:GLV[J0,142S pproven 8!17/2016 Ifid16ER;'1k'i.8" Rapp!'451,411698,, '. yr.. Casing Description , m,. n .....T�^W .Bet U CONDUCTOR (6 15.052 36.0 115.0 1150 62.50(440 WELDED Casl•g D•scdplon OD tint ID DM Top(OCHI Sat Depth 4M(13) Sot Dona(TVD)...WIlL.n)l..Grad. Topthread SURFACE 9 58 8,921 35,0 4,707 3 4,090 3 36.00 J-55 810 CuMg De•cnlp6on D0 tad ID 0.) Top peal Set Depth Oehl Set Depth(IVO).-Man IL..Grade Unthread 1 . PRODUCTION 7 6.276 33.0 8,145 8 6,8142 26.00 J-55 BIC Tubing D•aatpaon Stmq N•._ID tint u Top pea) Sel Mpth(it.DM DepW DVD)(-.Wt Hent) 6b.d.' Top C n.•anon TUBING-2015 WO- 3112 2.990 33.0 7,634.6 6,397 9.30 L-80 EUE 8rd UPPER ,�.. coRolroroR;seatleo UPPER �aT4(ION Nominal ID GAS LIFT;2700.43 ' i Top(IKB( Top(TOD)DIKE) Tooled') nee Des Com 0.) 33T 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0 6,379.8 38.39 Locator t.ocebr bub 3.000 7,620.5 6,385.8 36.35 SEALASSY Baker 0HB-22 locating seal assembly 3.000 Tubky)Dasornp76. Side g Na..0)la roti pea) Mol Oepin(IL.gen Depth(ivW(_wi Hell!' Grade Top Connection Os1vTele COM Oe,3. a I'1 - TUBING-2015W0- 3112 2.992 7,620.2 7,08601 8,601.21 9.30 L-80 EUEBrd IB LOMPL _.. ... 1 hO.xWPE,,T�yyItOy,vNvktft� NOM1M m (1ASUFT;4,17,3 Top(KKB( Top(TVO(plKn) Top Nml)') Nen Des Com (b) i 7,620.2 6,385.6 3636 PACKER Baker Fpacker 4.000 7,623.5 6,3882 3634 PBR 8040 PBA 4.000 7,752.7 6,492.6 35.75 NFPLE HES 3.5 X 2.82 X rtipple 2.612 f,' 7,797.4 6,529.1 3556 Uner 5.5 X 14 a J-55 STC Wear sox 516!16'OD on Wear 5.000 rings ,, 1)010610.1:10, 110; t .1140100104. 61 4311 p,,pailrea,pumps.flsh,@to:) ' >aIRFACE:3s.a4,7o7a Top Top lent io►(NKB) I5KB)IKaI (.) Dos Cpl Run DeM b tin) 7,855.0 6,576.0 35.39 WHPSTOCK Baker Don ti Delta 3.5'8 5.5'Whipstock Set 1' 12/18/2015 - GAS UPC r:6.014 8 ROHS orientation,RA Tags at 7862.35 8. Shot Dens Top lTwl ehln(TVD) (Moe OAS UFT;6,9296 ,111Top polo) Mu 011(6) (IIKB) IIKeI Zone Data II) Type Cpl 7,849.0 7,859.0 6,571.1 6,579.2 A3,30.06 61511989 12.0 APERF 60 deg.phasing(Strips Kinked @ 35 deg.);2 1/8'EnerJet 7,867.0 7,891.0 6,685.7 6,605.3 A-2,3746 61511989 12.0 APERF 60 deg.phasing,2116" EnerJet GAS LITT;7,021.4 1.1 7,8980 7,918.0 6,611.0 6,627.4 A-1,3 .06 9/2311968 8.0 IPERF 45 deg.phasing;412" I Mem*Cs9 Mandrel Inserts st a. IAS LIFT;7.£66.9 1 1 . on Top7Vp( valve Latch P018100 TRO Run N Top DIKE) pM6) Mahe Model 00114 Sen Type Type (h!) (psi) Rin Date Corn 1 2,708.6 2,484.7 Cemco MMG 1 1/2 GAS LFT DMY RK 0.000 0.0 8/152016 2 4,217.3 3,705.9 Cameo MMG .' 1 1/2 GAS LFT DMY RK 0.000 0.0 811552016 • 3 5,414.9 4,642.4 Cemco MMD 1 1/2 GAS LFT DMY RK 0.000 0.0 87142016 Loaner;7,6110 - 4 6,3288 5,355.4 Cemco MMD 112 GAS HET DMY RK 0.000 0.0 8714(2016 ,-t; 5 7,021.4 5,908.2 Camco MMD 11/2 GAS LFT DMY RK 0.000 0.0 8/15120)6 PACKER;7,8202 i ,- 6 7,5559 5,333.9 Cameo MMG 11/2 GAS LFT DMY RK 0000 0.0 18/24/2015 sEn1.PEM?T:, .3 Pr• 1,-- '1 1 9'e9enner@Ih ;Bet! ., .... f End Date Annotation 12712010 NOTE'View$thematic w/Alaska Schema9c9.0 • 717/2015 NOTE'WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. 10125/2015 NOTE 01611 Valve Control lines/system M Wellhead marked Open7Close. KwpLe;7.7s23 - 10/252015 NOTE:Orbit Valve is NOT a safety valve,it does not MI to dosed position. I I XO U*,550(TIrn91:7.055.4 Y11'�., Grom7,797.4 " APERF;7,e1a.67,059D- . I 1 WHIPSTOCK 7,855.0 a I i ' APERF:7.80/.0-T.891A- I WERE.7096.0-7,91a0 - . [ PRODU0Tbtt 93.e4145.1 4 i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e c �q(I DATE: Tuesday,August 30,2016 P.I.Supervisor , l t " SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-06 FROM: Guy Cook KUPARUK RIV UNIT 30-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-06 API Well Number 50-029-21824-00-00 Inspector Name: Guy Cook Permit Number: 188-060-0 Inspection Date: 8/28/2016 Insp Num: mitGDC160828142941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-06 ' Type Inj W TVD6386 • Tubing 1760 1760 - 1760 - 1760 - PTD 1880600 - IType Test SPT Test psi 3000 IA 1080 j 3300 - 3230 - 3230 ' Interval INITAL P/F P ✓ OA 350 380 - 380 - 380 , Notes: 1.8 BBLS used to achieve test pressure.AIO 2C.022 SCANNED JUN 2 3 2017 Tuesday,August 30,2016 Page 1 of 1 OF T4 • /77 THE STATE• Alaska Oil and Gas .S di OfA L JSKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen NSK Production Engineering Specialist SCANNED OCT 3 12016 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-06 Permit to Drill Number: 188-060 Sundry Number: 316-389 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this�i day of August, 2016. RBDMS u- AUG - 2 2016 III DECEIVED • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 7Oi • APPLICATION FOR SUNDRY APPROVALS O7'S �'�+/ /,6 20 AAC 25.280 AOGG 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG W' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development 17. 188-0600. 3.Address: Stratigraphic r-" Service -` 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-21824-00' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No p/ KRU 30-06 4 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025513 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): 'Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8172 ' 6836 • 8063'• ' 6746' 2075 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 115' 115' SURFACE 4672' 9 5/8 4707' 4090' PRODUCTION 8113' 7 8146' 6814' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7849-7859;7867-7891;7898-7918 . 6571-6579;6586-6605;6611-6627 3 1/2 L-80 7886 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NONE PACKER=BAKER F PACKER - MD=7620 TVD=6386 12.Attachments: Proposal Summary r WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P' 14.Estimated Date for 15. Well Status after proposed work: 08/01/16 OIL r WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG P' GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n11390conocophillips.com / / a(L,, 4t,A) Title: NSK Production Engineering Specialist Signature #� `� Date: Z.57/42 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31(40 - 331 Plug Integrity r BOP Test r Mechanical Integrity Test location Clearance r Other: Post Initial Injection MIT Req'd? Yes V No r /t .1C,G Q Spacing Exception Required? Yes r No ,° Subsequent Form Required: / 0 ✓ —"d U`4 �b �/l Ll APPROVED BY Approved by: /i / 'J -�J COMMISSIONER THE COMMISSION Date:25)--2 -l� V T` 7 I � ?'fz7-,� 7276 GGGG`«` !!!( oilz,itOrINALpproval. SubsinFormane Form 10-403 Revised 11/2015 Approved application is valid Attachments in Duplicate RBDMS v1/ AUG - 2 2016 • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhi I I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 July 25,2016 v el) RE.co AOGCC Commissioner JUL 2 1 20.16 State of Alaska, Oil & Gas Conservation Commission C 333 W. 7th Ave. Ste. 100 AO O Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well(s) 30-06, 30- 06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03, and 30-06L1-04 from Production service to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 30-06, 30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03, and 30-06L1-04 (PTD#'s 188-060, 215-211, 215-212, 215-213, 215-214 and 215-215). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, Robert D. Christensen Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • 30-06 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 30-06, 06L1, 06L1-01, 06L1-02, 06L1- 03, and 06L1-04 (PTD's# 188-060, 215-211, 215-212, 215-213, 215-214 and 215-215) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 30-06 was completed as an injector on 7/20/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing offset producers 30-08 and 3R- 26. The top of the Kuparuk A3 sand was found at 7833' and/6558'tvd The top of the Kuparuk A2 sand was found at 7860' and/6580'tvd The top of the Kuparuk Al sand was found at 7876' and/6593'tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers 30-04 & 3R-26, there are no additional production/injection wells located within a 1/4 mile radius of the 30-06, 06L1, 06L1-01, 06L1-02, 06L1-03, 06L1-04 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 30-06 is good and is classified as a"CTD horizontal penta-lateral" well. The injection tubing/casing annulus is isolated via a Baker Packer located at 7620' and (6416' tvd). A State-witnessed MIT-IA will be performed once well 30-06 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 16" Conductor was cemented with 181 sx AS II. The 9-5/8" Surface casing was cemented with 1650 sx AS III &300 sx Class"G". The 7" Production casing was cemented with 300 sx Class"G" & 175 sx AS I. 0 • 82 \ \\\\ \\\\ \\\ - ;§) \ ;§) ( ; ;) ) /,1L4„ /}(2 /\f 2 © >© >© E -2 )c” |( ® !7 |( ; l7 ! E ! : f@f3 .& f\ . ,) ;:f` 3t1 . . !\) 222 ! ) /; ` ( 5] l , :) §G §;\)/ ¥ � = \)( = �)f \ * )i� ) 2±7' j \ \ \ °3 ; a a `0 } t : - }\� \\ /\ Q.12 ) � �/ )/ k( /{ ) ) k / & , w !.1. > |; L1.13 - - o re '� 3 3 3 0 L &! n O . : _. _. W |« 24 24 - Q \� rIf si. II � \ / r \\I- � _/ ,, rl- \ \ / �\ \ } ( \ \\ \\ ' \\� ) $ '4 » § , , , 0 • • ADL355023 • Kuparuk River Unit 3R-26 16 30-06L1-04 .. 30-06L1-03 30-04 30-0644%--...„...,.., i 1- ADLO 3 30-06L1-02 30-06L-1-01 30-06L1 .a 30 0 21 22 1/4 Mi. Radius Well Open Interval I'I 30-06 ❑30-06 30-06L1 30-06L1 y,/ 25Ju116 ❑30-06L1-01 —30-06L1-01 ConocoPhillips Q 30-06L1-02 —30-06L1-02 Alaska, Inc. ❑30-06L1-03 —30-06L1-03 Injection Swap Analysis N ❑30-06L1-04 —30-06L1-04 30-06& Laterals 0 0 08 0 16 0 24 0 32 —Well Within Radius Well Pad . . . . Miles KUP PROD • 30-06 • ConocoPhillips0-2, Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) o++nrc 500292182400 KUPARUK RIVER UNIT PROD 40.43 5,500.00 8,172.0 O ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-06,12720169:42:05 AM SSSV:NONE Last WO: 10/25/2015 34.98 6/24/1988 • Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date CTD a Window.0.07.., Last Tag:SLM 7,940.0 11/24/2015 Rev Reason:ADD LATERALS,GLV C/O lehallf 1/27/2016 HANGER;33.0 103/1 Casing Strings - - r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED • f Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 4,707.3 4,090.3 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �._,..,PRODUCTION 7 6.276 33.0 8,145.8 6,814.2 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID/n) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-2015 WO- 3 1/2 2.990 33.0 7,634.6 6,397.2 9.30 L-80 EUE 8rd UPPER CONDUCTOR;36.0-115.011 1 COMPLETION Completion Details alNominal ID GAS LIFT;2.708.6 '11-.' Top(ftKB) Top(ND)(ftKB) Top Inal(°) Item Des Com (in) l33.0 33.0 0.09 HANGER Tubing Hanger 3.500 ll7,613.0 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.8 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection OSN Tubing SNA OH;3,495.9 TUBING-2015 WO- 3 1/2 2.992 7,620.2 7,886.0 6,601.2 9.30 L-80 EUE 8rd LOWER 1.1 COMPLETION Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com _ (in) GAS LIFT;4,217.3 7,620.2 6,385.6' 36.36'PACKER Baker F packer 4.000' - 7,623.5 6,388.2 36.34 PBR '80-40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE HES 3.5 X 2.82 X nipple 2.812 J 7,797.4 6,529.1• 35.56•Liner '5.5 X 14#J-55 STC Wear sox 5 15/16"OD on Wear 5.000 rings Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;35.0-4,707.3 .7 It.' Top(ND) Top Incl Top(060) (ftKB) (°) Des Com Run Date ID(in) 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5"X 5.5"Whipstock Set 1° 12/16/2015 ROHS orientation,RA Tags at 7862.35 ft. GAS LIFT;5,414.9 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shotsif Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,328.6 7,849.0 7,859.0 6,571.1 6,579.2 A-3,30-06 6/5/1989 12.0 APERF 60 deg.phasing(Strips Kinked @ 35 deg.);2 1/8"EnerJel 7,867.0 7,891.0 6,585.7 6,605.3 A-2,30-06 6/5/1989 12.0 APERF 60 deg.phasing;2 1/8" EnerJel GAS LIFT;7,021.4 7,898.0 7,918.0 6,611.0 6,627.4 A-1,30-06 9/23/1988 8.0 (PERF 45 deg.phasing;4 1/7' Ultrapak Csg Mandrel Inserts -- St ati L on Top(ND) Valve Latch Port Size TRO Run GAS LIFT;7,555.9 N Top(ftKB) (ftKB) Make Model OD(in) Sero Type Type (in) (psi) Run Date Com I •( 2,708.6 2,494.7 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,242.0 1/10/2016 2 4,217.3 3,705.9 Camoc MMG 11/2 GAS LIFT GLV RK 0.188 1,235.0 1/10/2016 3 5,414.9 4,642.4 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,234.0'1/9/2016 4 6,328.6 5,355.4 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,229.0 1/9/2016 Locator;7,613.0 5 7,021.4 5,908.2 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 1/9/2016 6 7,555.9 6,333.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 PACKER;7,620.2 ena I, , SEAL ASSY;7,620.5 n'1 Notes:General&Safety PBR;7,623.5 1 a if End Date Annotation t 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 -g 17 7/7/2015 NOTE: WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. _ 10/25/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fall to closed position. NIPPLE;7,752.7Ei X0 Enlarging(Tubing);7,796.4 -I-Ci Liner;7,797.4 APERF;7,849.0-7,859.0-_ ' WHIPSTOCK 7,855.0_A- APERF;7,867.0-7,891.0---t-t. IPERF;7,898.0-7,918.0 PRODUCTION;33.0$145.8 STATE OF ALASKA • AL KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: WAG to PROD j✓ 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-0600 3.Address: 6.API Number: Stratigraphic r Service pr P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21824-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-06 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8172 feet Plugs(measured) None true vertical 6836 feet Junk(measured) None Effective Depth measured 8063 feet Packer(measured) 7620 true vertical 6746 feet (true vertical) 6386 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 4672.3 9 5/8 4707.3 4090' PRODUCTION 8112.8 7 8145.8 6814' RECEIVED Perforation depth: Measured depth: 7849-7859; 7867-7891; 7898-7918 FEB 1.. 0 2016 True Vertical Depth: 6571-6579; 6586-6605;6611-6627 Er 1' �' ; iOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 7886 MD,6601 TVD Packers&SSSV(type, MD,and ND) SSSV= NONE PACKER- BAKER F PACKER @ 7620 MD and 6386 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 265 2733 3454 10 220 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run16.Well Status after work: r Oil ;r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humohrev/Bob Christensen Email: n1139aConoCophillips.com Printed Name bert D. Christensen Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date a ////(0 7-/ii /it Form 10-404 Revised 5/2015 * ...2- 9,6 RBDMS LL FF9 1 0 2016 Submit Original Only • • • 30-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/18/15 CDR2 added 5 Laterals: 30-06L1, L1-01, L1-02, L1-03, & L1-04 01/09/16 SET CATCHER @ 7752' RKB; PULLED DV'S @ 7021', 6328', 5414', &4217' RKB; SET OV @ 7021' RKB. SET GLV'S @ 6328' &5414' RKB. 01/10/16 PULLED DV @ 2709' RKB; SET GLV'S @ 4217' &2708' RKB (OBTAIN GOOD IA DDT) 01/11/16 Well turned to production 0 or KUP PROD 30-06 r ConocoPhillips Well Attributes Max Angle&MD TD til 151i 3,If 1(:. • Wellbore API/UWI Field Name Wellbore Status 'ncl(°i MD(ftKB) Act Btm(ftKB) crnoorrenapc. 500292182400 KUPARUK RIVER UNIT PROD 40.43 5,500.00 8,172.0 --- .+u Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-06,1/272016 9,42:05 AM SSSV:NONE Last WO: 10/25/2015 34.98 6/24/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date CTD4Lwindow u.o, .,,...,.,.,Last Tag:SLM 7,940.0 11/24/2015 Rev Reason:ADD LATERALS,GLV C/O lehallf 1/27/2016 HANGER;33.0 I160- Casing Strings � a CasingONDescription OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(IVO)... Wt/Len6 (I...0 Grade40E Thread CONDUCTOR 16 (in) B) 115.0 115.0 62.50 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 4,707.3 4,090.3 36.00 J-55 BTC r- p. ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread An./.." ',....,...A....".PRODUCTION 7 6.276 33.0 8,145.8 6,814.2 26.00 J-55 'BTC Tubing Strings ai Tubing Description String Ma...ID(in) Top if-6<B) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-2015 WO- 31/2 2.990 33.0 7,634.6 6,397.2 9.30 L-80 EUE 8rd UPPER CONDUCTOR;36.0.115.0 a COMPLETION Completion Details :Nominal ID GAS LIFT;2,708.6 lE Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.8 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection OSTV Tubing Shut Ok;3,495.9VS TUBING-2015 WO- 31/2 2.992 7,620.2 7,866.0 6,601.2 9.30 L-80 EUE 8rd LOWER _ COMPLETION Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) GAS LIFT;4,217.3 7.620.2 6 365.6 36.36 PACKER Baker F packer 4.000 7,623.5 6,388.2 36.34 PBR 80-40 PBR 4.000 rl 7,752.7 6,492.8 35.75 NIPPLE I HES 3.5 X 2.82 X nipple 2.812 ' 7,797.4 6,529.1 35.56 Liner 5.5 X 14#J-55 STC Wear sox 5 15/16"OD on Wear 5.000 rings Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;35.0-1,707.3 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,855.0 6,576.0 35.39 WHIPSTOCK Baker Gen II Delta 3.5"X 5.5"Whipstock Set 1° 12/16/2015 ROHS orientation,RA Tags at 7862.35 ft. GAS LIFT;5,414.9 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;6,328.6 7,849.0 7,859.0 6,571.1 6,579.2 A-3,30-06 6/5/1989 12.0 APERF 60 deg.phasing(Strips Kinked @ 35 deg.);2 1/8"EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2,30-06 6/5/1989 12.0 APERF 60 deg.phasing;2 1/8" EnerJet GAS LIFT,7,021.4 7,898.0 7,918.0 6,611.0 6,627.4 A-1,30-06 9/23/1988 8.0 (PERF 4 GAS LIFT;7,555.9 5 deg.phasing;4..);12/2.1/2" Ultrapak Csg Mandrel Inserts Sl ati on Top(ND) Valva Latch Port Size TRO Run N Top(kKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1� 2,708.6 2,494.7 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,242.0 1/10/2016 2 4,217.3 3,705.9 Camoc MMG 1 1/2 GAS LIFT GLV RK 0.188 1,235.0 1/10/2016 3 5,414.9 4,642.4 Comm MMG 1 1/2 GAS LIFT GLV RK 0.188 1,234.0 1/9/2016 4 6,328.6 5,355.4 Comm MMG 1 1/2 GAS LIFT GLV RK 0.188 1,229.0 09/2016 Locator;7,613.0 5 7,021.4 5,908.2 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 1/9/2016 6 7,555.9 6,333.9 Comm MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 PACKER;7,620.2 SEAL ASSY;7,620.5 Notes:General&Safety PBR;7,623.5 End Date Annotation 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 7/7/2015 NOTE WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. 10/25/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fall to closed position. NIPPLE;7,752.7 TT I. I XO Enlarging(Tubing);7,796.4 Liner;7,797.4 APERF;7,849.0-7,859.0- I WHIPSTOCK;7,855.0 I I APERF;7,867.0.7,891.0 IPERF;7,898.0-7,918.0 PRODUCTION;33.0-8,145.6 ,M E OF ALASKA KRU 30-06 A KA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing F Operations Shutdown fl Performed: Suspend E Perforate E Other Stimulate E Alter Casing E Change Approved Program Plug for Redrill E Perforate New Pool fl Repair Well r Re-enter Susp Well E r' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-060 3.Address: 6.API Number: Stratigraphic 1 Service IF P. O. Box 100360,Anchorage,Alaska 99510 50-029-21824-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU30-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8172 feet Plugs(measured) None true vertical 6836 feet Junk(measured) None Effective Depth measured 8063 feet Packer(measured) 7620 true vertical 6746 feet (true vertical) 6386 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 0 0 SURFACE 4672 9.625 4707 4090 0 0 PRODUCTION 8113 7 8146 6814 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7849-7859, 7867-7819, 7898-7918 - a t{, „''.:P)True Vertical Depth: 6571-6579, 6586-6605,6611-6627 SO**� RECEIVED Tubing(size,grade,MD,and TVD) 3.5, L-80,7886 MD, 6601 TVD DEL. 0 1 2015 Packers&SSSV(type,MD,and ND) PACKER-BAKER F PACKER @ 7620 MD and 6386 ND 1�^°�' CO SSSV: None 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory )- Development I— Service F Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil E Gas E WDSPL E Printed and Electronic Fracture Stimulation Data r GSTOR WINJ F WAG rGINJ r SUSP fl SPLUG fl 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-526 Contact Theresa Lee@263-4837 Email Theresa.M.Lee(&conocophillips.com Printed Name /Theresa Lee Title Wells Engineer Signature ,�f / Phone :263-4837 Date / 39 / i _ t ' 462_,, If RBDMS IVA11015 Form 10-404 Revised 5/2015 i//,//I., Submit ' inal Only Ai KUP INJ M 30-06 ConocoPhiftips Well Attributes Max Angle&MD TD Alaska Inco Wellbore API/UWI Field Name Wellbore Statusncl(°) MS(ftKB) Met Act (ftKB) Crnw.'d'Nritps 500292182400 KUPARUK RIVER UNIT INJ 1 40.43 5,500.00 8,172.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-06,11117/201510.18:31 AM SSSV:NONE Last WO'. 10/25/2015 34.98 6/24/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,923.0 7/19/2015 Rev Reason:WORKOVER lehallf 11/17/2015 HANGER;330 1C1.11.1 VCasing Strings ' '' . ' .Casing Description OD(in) ID(in) Top(ftKB) Set Depth 09(B) Set Depth(TVD)...Wt/Lena Len(I...Grade Top Thred i. CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED 1 { (% Casing Description OD(in) 10(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L SURFACE 95/8 8.921 35.0 4,707.3 4,090.3 36.00 J-55 BTC f 5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread t PRODUCTION 7 6.276 33.0 8,145.8 6,814.2 26.00 J-55 BTC Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection ` '. TUBING-2015 WO- 3 1/2 2.990 33.0 7,634.6 6,397.2 9.30 L-80 EUE 8rd UPPER CONDUCTOR;36.0-115.0 e COMPLETION Completion Details IP Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) GAS LIFT;2,70EsII 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0'- 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.8 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(ND)(...Wt(Ibtft) Grade Top Connection VI' TUBING-2015 WO- 31/2 2.992 7,620.2 7,886.0 6,601.2 9.30 L-80 EUE 8rd QSTVTulang Shut Oftr!•;3,495.9 . LOWER ' COMPLETION Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,620.2 6,385.6 36.36 PACKER Baker F packer 4.000 GAS LIFT;4,217.3 7,623.5 6,388.2 36.34 PBR 80-40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE HES 3.5 X 2.82 X nipple W/XX plug 2.182 7,797.4 6,529.1 35.56 Liner 5.5 X 14#J-55 STC Wear sox 5 15/16"OD on Wear 5.000 HI 1 rings Perforations&Slots Shot SURFACE;35.0-4,707.3 • k Dens Top(ND) Bier(TVD) (shotslf al Top(ftKB) Bins(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,849.0 7,859.0 6,571.1 6,579.2 A-3,30-06 6/5/1969 12.0 APERF 60 deg.phasing(Strips GAS LIFT;5,414.5al Kinked @ 35 deg.);2 1/8"EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2,30-06 6/5/1969 12.0 APERF 60 deg.phasing;2 1/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1,30-06 9/23/1968 8.0 IPERF 45 deg.phasing;4 1/2" GAS LIFT,6,3286 Ultrapak Csg Mandrel Inserts St ati 4 on Tap(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com GAS LIFT;7,021A g: 1 2,708.6 2,494.7 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 2 4,217.3 3,705.9 Camoc MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 It 3 5,414.9 4,642.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 GAS LIFT;7,555 9 4 6,328.6 5,355.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 5 7,021.4 5,908.2 Comm MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 10/24/2015 Locator;7,613.0 (..�. 6 7,555.9 6,333.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 Notes:General&Safety PACKER;7,6202 i•- .i End Dale Annotation SEAL ASSY;7,620.5 E = I 12/1/2010 NOTE'View Schematic w/Alaska Schematic9.0 FOR;7,623.5 11 y II 7/7/2015 NOTE: WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. 1 1 10/25/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fall to closed position. NIPPLE;7,752.7 €'i is 00 Enlarging(Tubing);7796.4 beer;7,797.4 _ APERF;7,849.0-7,859.0 APERF;7,867.0-7,891.0- - -4 . IPERF;7,898.0-7,918.0 PRODUCTION;33.0-8.145.8 ®' • Operations Summary (with Timelog Depths) fint 30-06 ConocdPhiflips h.Srk;3 ' Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKO)' 10/18/2015 10/18/2015 12.00 MIRU MOVE RURD P De-MOB equipment and rig for move 00:00 12:00 10/18/2015 10/18/2015 8.00 MIRU MOVE MOB P Mobilize rig to location and rig up. 12:00 20:00 10/19/2015 10/19/2015 4.00 MIRU MOVE MOB P Rig accepted @ 00:01 hrs. 04:00 08:00 Take on mud and install secondary valves on IA. 10/19/2015 10/19/2015 2.00 MIRU WELCTL MPSP P Plck up and test lubricator.2500 spi. 08:00 10:00 Pull BPV Tbg pressure=1500 psi.IA pressure =1400 psi. 70/19/2015 10/19/2015 1.00 MIRU WELCTL RURD P RU kill lines to tree.and test to 3000 10:00 11:00 psi. 10/19/2015 10/19/2015 6.00 MIRU WELCTL KLWL P Begin kill operation convetional.@ 2 11:00 17:00 BPM @ 1700 psi.Circulated hole volume+to kill tank then turned inside.for 1/2 more volume.total circulated 420 bbls of 12.7#mud. FCP=742 psi @ 3 BPM. 10/19/2015 10/19/2015 0.50 MIRU WELCTL OWFF P Flow check fo 30 min's. 17:00 17:30 10/19/2015 10/19/2015 0.50 MIRU WELCTL RURD P RD kill lines from tree. 17:30 18:00 10/19/2015 10/19/2015 0.50 MIRU WHDBOP MPSP P Install BPV 18:00 18:30 10/19/2015 10/19/2015 2.50 MIRU WHDBOP NUND P ND and pull tree and adaptor. 15K to 18:30 21:00 pull free. 10/19/2015 10/19/2015 0.50 MIRU WHDBOP MPSP P Install test plug 21:00 21:30 10/19/2015 10/20/2015 6.00 MIRU WHDBOP NUND P NU BOPE 21:30 03:30 10/20/2015 10/20/2015 0.50 MIRU WHDBOP BOPE P Test BOPE 250/4500. 03:30 04:00 10/20/2015 10/20/2015 8.50 MIRU WHDBOP BOPE P Continue BOPE test. 00:00 08:30 1)LPR W/2 7/8 TJ,TD HCR pass. 2)UPR W/27/8 TJ,CXhoke 1,2,3,16TD man,RF kill. Pass 3)Choke 4,5,6,HCR kill,HT 38 FOSV pass. 4)Choke 7,8,9,Manual kill.Fail/Pass 5)Super choke/man bean pass. 6)Chioke 10,11„8 Pass 7)Choke 12,13, Pass. 8)Annular with 2 7/8 TJ Pass. 9)BR,HCR choke,Man Kill,HT 38 Dart.Pass 10)Man Choke Pass. 11)Choke 15 Pass 12)Choke 14 Pass.. 13)Annular Pass 14)TPR 8rd FOSV Outer test spool pass 15)LPR, Innner test spool Pass. Draw down: 10/20/2015 10/20/2015 1.50 MIRU WHDBOP RURD P pull test plug and BPV 08:30 10:00 Page 1/6 Report Printed: 11/30/2015 Operations Summary (with Timelog Depths) rr . 30-06 Cotwaccifilitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur{hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/20/2015 10/20/2015 0.50 COMPZN RPCOMP OWFF P Flow check 10:00 10:30 10/20/2015 10/20/2015 0.50 COMPZN RPCOMP PULL P Pick up on tubing to 110 K worked 7,630.0 7,630.0 10:30 11:00 down to 60 K a couple of times.quick dropped to 75 K from 110 K.pulled back up to 110K pulled free.pull a second time to 105K Hanger at floor. 10/20/2015 10/20/2015 0.25 COMPZN RPCOMP OWFF P Filled stack and observed well for flow. 7,630.0 7,630.0 11:00 11:15 Taking fluid. 10/20/2015 10/20/2015 1.75 COMPZN RPCOMP CIRC P CXirculated BU @ 4 BPM @ 850 psi. 7,630.0 7,630.0 11:15 13:00 Bottoms up=12.2 lb/gal. Continue to circulate and condition Mud at 4.0 bpm/840 pst. Final weight check 12.7 lbs/gal in/12.7 lbs/gal out. Total bblas pumped= 385 bbls. 10/20/2015 10/20/2015 0.50 COMPZN RPCOMP OWFF P Monitor Well x 30 minutes. Observe 7,630.0 7,630.0 13:00 13:30 Well static with a very slight drop in fluid level. 10/20/2015 10/20/2015 0.25 COMPZN RPCOMP PULL P Lay down the Tubing Hanger and 7,630.0 7,630.0 13:30 13:45 Landing Joint. 10/20/2015 10/20/2015 0.50 COMPZN RPCOMP CIRC P Mix"dry-job"...15 bbls x 14.2 lb/gal. 7,630.0 7,630.0 13:45 14:15 Slug tubing. 10/20/2015 10/20/2015 9.25 COMPZN RPCOMP PULL P Single down the 2 7/8"completion 7,630.0 0.0 14:15 23:30 while spooling Control Line to the SSSV.Recovered 32 band.and seal assembly 10/20/2015 10/21/2015 0.50 COMPZN RPCOMP RURD P RD Weatherford handling equipment 23:30 00:00 and tongs.Swap equipment over to DP handling equipment. 10/21/2015 10/21/2015 0.50 COMPZN RPCOMP RURD P Continue to swap over equipment to 00:00 00:30 drill pipe and clear floor. 10/21/2015 10/21/2015 0.50 COMPZN RPCOMP RURD P Install Wear ring 00:30 01:00 10/21/2015 10/21/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive unit. 01:00 01:30 10/21/2015 10/21/2015 1.50 COMPZN RPCOMP BHAH P PJSM.Pick up BHA#1.3 1/4"ITco 0.0 223.0 01:30 03:00 spear assembly with 3.291 grapple. 10/21/2015 10/21/2015 9.00 COMPZN RPCOMP PULD P Pick up drill pipe and RIH with BHA# 223.0 7,500.0 03:00 12:00 1 to 7,500-ft....stop for SLCP. 10/21/2015 10/21/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Discuss the duties and 7,500.0 7,500.0 12:00 12:15 hazards associated with Slipping and cutting Drilling Line. 10/21/2015 10/21/2015 1.50 COMPZN RPCOMP SLPC P Slip/Cut Drilling Line(86-ft). Service 7,500.0 7,500.0 12:15 13:45 Drawworks. Adjust brakes. Set Block height. Set Crown-O-Matic 10/21/2015 10/21/2015 0.75 COMPZN RPCOMP CIRC P Circulate bottoms up.at 6.0 7,500.0 7,500.0 13:45 14:30 bpm/1,260 psi. Page 2/6 Report Printed: 11/30/2015 • 4110 Operations Summary (with Timelog Depths) s " 30-06 f iips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time; End Time Dur(fir) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKS)> 10/21/2015 10/21/2015 0.75 COMPZN RPCOMP FISH P Pick up weight=165K. Down weight 7,500.0 7,629.0 14:30 15:15 =95K. Continue in the BHA#1 and stand#79 with the pump on at 0.7 bpm. Tagged the top of the PBR at 7,624-ft. Continue to swallow the PBR down to the stop ring at 7,629-ft. Pick up to confirm the Spear is planted. Confirm swallow again with 15K down at 7,629.0-ft Final depth with OKB difference to 7es Rig Floor(+)8.0-ft= 7,637-ft. 10/21/2015 10/21/2015 0.25 COMPZN RPCOMP FISH P Pull up to 200 K(35K over). Packer 7,629.0 7,600.0 15:15 15:30 sheared free. Pull up hole with a 10 to 15K over pull. 10/21/2015 10/21/2015 3.00 COMPZN RPCOMP CIRC P Circulate 444 bbls @ 3 BPM @ 1130 7,600.0 7,600.0 15:30 18:30 PSI. 10/21/2015 10/21/2015 0.25 COMPZN RPCOMP CIRC P Got SPR's 2BPM @ 775 psi,3BPM 7,600.0 7,600.0 18:30 18:45 1090 PSI. 10/21/2015 10/21/2015 0.25 COMPZN RPCOMP OWFF P Flow check 7,600.0 7,600.0 18:45 19:00 10/21/2015 10/21/2015 4.50 COMPZN RPCOMP TRIP P POOH with drill pipe and fish 7,600.0 223.0 19:00 23:30 10/21/2015 10/22/2015 0.50 COMPZN RPCOMP BHAH P Stood back collars 223.0 23.0 23:30 00:00 10/22/2015 10/22/2015 1.50 COMPZN RPCOMP BHAH P Continue to lay down fish and clear 23.0 0.0 00:00 01:30 floor. 10/22/2015 10/22/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive. 0.0 0.0 01:30 02:00 10/22/2015 10/22/2015 1.00 COMPZN WELLPR BHAH P Make up BHA#2:6 1/8"Bit/string 0.0 225.0 02:00 03:00 mill assembly 10/22/2015 10/22/2015 4.50 COMPZN WELLPR TRIP P RIH with Drill pipe and BHA#2 to 225.0 7,700.0 03:00 07:30 7,700-ft. 10/22/2015 10/22/2015 1.50 COMPZN WELLPR WASH P Up weight=170K. Down weight= 7,700.0 7,950.0 07:30 09:00 100K. Bring pump on line at 1.0 bpm/515 psi. Begin to wash down. Found the top of dill at 7,860-ft dpmd, hard tag...(not washing away). Increase pump rate to 5.0 bpm/1,45 psi. Bring on Top Drive at 60 RMs and break through the"crust top" down to 7,862-ft. Continue to wash down and clean out the Wellbore to 7,950-ft dpmd with no problems....recovering rubber from the lost Packer element,formation sand, and small cement chippings. 10/22/2015 10/22/2015 1.00 COMPZN WELLPR CIRC P Pull up to 7,930-ft. Pump at 45 bbl Hi- 7,950.0 7,930.0 09:00 10:00 Vis Sweep at 5.0 bpm/1480 psi and chase back to surface with 12.7 lb/gal Mud...(no fluid losses). Recovered a few bit of rubber and good slug formation sand. 10/22/2015 10/22/2015 0.50 COMPZN WELLPR RURD P Blow down Top Drive. Rig up Head 7,930.0 7,930.0 10:00 10:30 Pin and lines to reverse circulate for the final clean-out. Page 3/6 Report Printed: 11/30/2015 Operations Summary (with Timelog Depths) 30-06 ConociaPhitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKE) 10/22/2015 10/22/2015 2.00 COMPZN WELLPR CIRC P Reverse in with a 45 bbl His-Vis 7,930.0 7,930.0 10:30 12:30 Sweep. Reverse the sweep back to surface with 12.7 lb/gal Mud at 5.0 bpm/1,535 psi....loosing fluid to the formation due to reversing. Reduce rate to 4.0 bpm...present loss is 30 bbls/hr. Reduce rate to 3.0 bbls/hr with a 12 bbl/hr fluid loss. Reversed well clean with just a trace of sand. here and there in the returns. 10/22/2015 10/22/2015 0.25 COMPZN WELLPR OWFF P Monitor Well Static x 15 minutes. 7,930.0 7,930.0 12:30 12:45 10/22/2015 10/22/2015 0.50 COMPZN WELLPR CIRC P Mix and pump a 15 bbl"dry job". Blow 7,930.0 7,930.0 12:45 13:15 down lines. Drop a 1 15/16"hollow steel rabbit w/100-ft tail. 10/22/2015 10/22/2015 4.25 COMPZN WELLPR TRIP P POOH weith BHA#2 7,930.0 225.0 13:15 17:30 10/22/2015 10/22/2015 1.50 COMPZN WELLPR BHAH P Laid down BHA#2 Clear floor of 225.0 0.0 17:30 19:00 tools. 10/22/2015 10/22/2015 0.50 COMPZN WELLPR SVRG P Service and inspect top drive. 0.0 19:00 19:30 10/22/2015 10/22/2015 0.50 COMPZN RPCOMP RURD P Ru weatherford tbg equipment 19:30 20:00 10/22/2015 10/22/2015 2.50 COMPZN RPCOMP PUTB P Pick up Wear sox/packer assembly 0.0 283.0 20:00 22:30 with J Hyd.setting assembly 10/22/2015 10/22/2015 0.50 COMPZN RPCOMP RURD P RD Weatherford tubing equipment. 283.0 283.0 22:30 23:00 10/22/2015 10/23/2015 1.00 COMPZN RPCOMP RCST P RIH with lower completion on drill pipe 283.0 1,500.0 23:00 00:00 10/23/2015 10/23/2015 4.50 COMPZN RPCOMP RCST P Continue to RIH with the lower 1,500.0 7,886.0 00:00 04:30 completion.Up wt=167K.down wt= 97 K. 10/23/2015 10/23/2015 1.00 COMPZN RPCOMP PACK P Dropped ball and pumped down @ 1 7,886.0 7,620.0 04:30 05:30 BPM @ 525 psi/2 BPM @ 625 psi. 43 BBLs of 12.7 Mud.Seat ball and set packer @ 7620 ft center of the elements©7621.5 ft.Set packer as per Baker.Sheared out @ 185K 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP PRTS P Pick up rill Pipe 1-ft. Test Packer, 7,620.0 7,619.0 05:30 06:00 Casing and the XX Plug at 1,000 psi x 15 minutes. Record on chart. Good. 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP SFTY P Pre-job safety and ops meeting with 7,619.0 7,619.0 06:00 06:30 all. Discuss the hazards associated with pressure,chemicals,need for good communications,and proper PPE. Review pumping stages, volumes,and flow paths. 10/23/2015 10/23/2015 5.50 COMPZN RPCOMP DISP P Finish staging Vac Trucks..complete 7,619.0 7,619.0 06:30 12:00 mixing Deep Clean Pill and Hi-Vis Spacer PIII. Displace the 12.7 lb/gal from the wellbore as follows: Pump a 107 bbl,Deep-Clean Pill. Pump a 101 bbl Hi-Vis Spacer. Pump 53 bbls of Sea Water and observe"Mud/Deep clean interface at surface. Divert returns to the Tiger Tank...continue pumping Sea Water until Sea Water returns are clean. Total Sea Water pumped=352 bbls. Blow down Top Drive. Page 4/6 Report Printed: 11/30/2015 • • 01. Operations Summary (with Timelog Depths) IN Comccifttillips ,, 30-06 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 10/23/2015 10/23/2015 5.50 COMPZN RPCOMP RURD P Clean pits and take on sea water. 7,619.0 7,619.0 12:00 17:30 10/23/2015 10/23/2015 4.50 COMPZN RPCOMP PULD P Single down the 3 1/2"Drill Pipe. 7,619.0 3,680.0 17:30 22:00 10/23/2015 10/23/2015 0.75 COMPZN RPCOMP SVRG P Service and inspect TD 3,680.0 3,686.0 22:00 22:45 10/23/2015 10/23/2015 0.25 COMPZN RPCOMP SFTY P Well contorl drill and AAR with crew. 3,686.0 3,686.0 22:45 23:00 10/23/2015 10/24/2015 1.00 COMPZN RPCOMP PULD P Continue to lay down drill pipe. 3,686.0 2,300.0 23:00 00:00 10/24/2015 10/24/2015 2.00 COMPZN RPCOMP PULD P Continue to lay down drill pipe and J 2,300.0 0.0 00:00 02:00 setting assembly. 10/24/2015 10/24/2015 1.00 COMPZN RPCOMP RURD P Pull wear ring 0.0 0.0 02:00 03:00 10/24/2015 10/24/2015 1.00 COMPZN RPCOMP WWWH P Wash BOPE stack 0.0 0.0 03:00 04:00 10/24/2015 10/24/2015 3.00 COMPZN RPCOMP PUTB P PJSM.Pick up and RIH with upper 0.0 2,500.0 04:00 07:00 completion to—4,135-ft. Pick-up Orbit Valve. 10/24/2015 10/24/2015 1.00 COMPZN RPCOMP SFTY P Safety Stand down review hand injury 0.0 0.0 07:00 08:00 10/24/2015 10/24/2015 3.00 COMPZN RPCOMP PUTB P Continue to Pick up upper completion 2,500.0 4,035.0 08:00 11:00 10/24/2015 10/24/2015 3.00 COMPZN RPCOMP RURD P Rig up Halliburton dual spool control 4,035.0 4,035.0 11:00 14:00 line unit. Hang sheave. Baker Completion Engineers install fittings and control lines to the Orbit Valve. Function and pressure test to 5,000 psi in both directions. (SIMOPS...Safety stand down with crew just returning to the Slope,to review the recent"broken finger" incident). 10/24/2015 10/24/2015 6.50 COMPZN RPCOMP PUTB P Continue to single in with the 4,035.0 7,634.0 14:00 20:30 remainder of the completion,installing cross-coupling clamps to secure the dual control line.Engaged seal assembly with pump on at 1 BPM.got 150 psi pressure increase.SD pump. Fully engage seals mark for space out. 10/24/2015 10/24/2015 2.25 COMPZN RPCOMP HOSO P Space out tubing string. Install hanger. 7,634.0 7,614.0 20:30 22:45 Tie in control lines. 10/24/2015 10/25/2015 1.25 COMPZN RPCOMP CRIH P Circulate in 268 BBLs of CI sea water 7,614.0 22:45 00:00 @ 4BPM @ 425 psi. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP CRIH P Continue to pump CI sea water. 00:00 00:30 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP THGR P Land hanger and RILDS 00:30 01:00 10/25/2015 10/25/2015 2.00 COMPZN 'RPCOMP PRTS P Pressure test tubing to 3500 psi for 15 01:00 03:00 in's. IA to 3000 for 30 min's.Shear SOV.Test from below Orbit valve to 3000 psi/above to 3500 psi.Pumped thru valve to ensure it is open.. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP RURD P RD test equipment pull landing joint 03:00 03:30 10/25/2015 10/25/2015 0.50 COMPZN WHDBOP MPSP P Install BPV and test from below to 03:30 04:00 1000 psi. Page 5/6 Report Printed: 11/30/2015 • w Operations Summary (with Timelog Depths) 0 30-06 411. ConcicoehiHips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time'. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth MKS) 10/25/2015 10/25/2015 7.50 COMPZN WHDBOP SVRG P Complete between well maintenance 04:00 11:30 on BOPE stack 10/25/2015 10/25/2015 1.50 COMPZN WHDBOP NUND P Nipple down the BOP Stack and set 11:30 13:00 back on the stump. 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP NUND P Nipple up Adaptor Head. 13:00 14:00 10/25/2015 10/25/2015 2.00 COMPZN WHDBOP PRTS P Pressure test HAnger void at 14:00 16:00 250/5,000 psi. Good.NU tree. Orientation ok'd by DSO Test tree to 250/5000 Good 10/25/2015 10/25/2015 2.00 COMPZN WHDBOP NUND P Nipple up Orbit Valve control line 16:00 18:00 maniforld. 10/25/2015 10/25/2015 0.50 COMPZN WHDBOP MPSP P Pull TWC 18:00 18:30 10/25/2015 10/25/2015 3.00 COMPZN WHDBOP FRZP P RU LRS and freeze protect well with 18:30 21:30 80 BBL's of Diesel. Let well equalize. 10/25/2015 10/25/2015 0.50 COMPZN WHDBOP MPSP P Installed BPV. 21:30 22:00 10/25/2015 10/26/2015 2.00 DEMOB MOVE RURD P Secure well.Rig released @ 11:59 22:00 00:00 hrs. Page 6/6 Report Printed: 11/30/2015 • Security Level: AK Development .�t DDR -Vendor 3J-10 ConocoPhilhps Report Number: 3 Rig: NABORS 7ES Report Date: 11/25/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 00:30 0.50 MIRU WHDBOP BOPE T Well Choke Nabors Retest CMV 7,9 and 14.Valves Control Manifold Alaska tested 250/3500 psi,all valves System Drilling passed.Witness of retest waived by Matt Herrera,AOGCC Rep. 00:30 02:00 1.50 MIRU WHDBOP MPSP P Pull Blanking plug and BPV. BOLDS.Pick up landing joint and prepare to pull Hanger. 02:00 02:45 0.75 ?Ati tl RPCOMP PULL P Attempt to pull Seal assembly free Co V4 63 from the PBR.Max pull 125K, would not pull free.Leave string in tension for 5 minutes and then work string 50K SOW to 125K PUW. 02:45 09:30 6.75 COMPZN RPCOMP ELNE ,X' QQW4ta0►'keti\ Wait on Schlumberger DSL Unit. rvio,Nte.$4,A All logging crews timed-out until Arc- 06:00 hrs. (SIMOPS load and ;:N.46:"e: r process Drill Pipe. Order out fishing tools,Top Drive inspection, housekeeping). Set Slips with 20K over string weight...install 3 1/2" TIW Valve. 09:30 10:00 0.50 COMPZN RPCOMP ELNE /C� Schlumberger DSL arrive on location. PJSM on rigging up. 10:00 13:45 3.75 COMPZN RPCOMP ELNE Spot equipment and rig-up. PJSM on picking up the lubricator and discuss special concerns with the String Shot and Chemical Cutter tools. Continue with rig up and picking up tool string. 13:45 16:30 2.75 COMPZN RPCOMP ELNE ,)Ser. Logging Downhole Schlumber Make-up 10-ft String Shot. Stab Tools ger Lubricator on Well. Pressure test at 500 psi. Good. Run in with String Shot(10-ft)Tool String. Drop down below the Tubing Patch(6,301'- 6,310')to 6,336-ft. Log back up across GLM#5 to 5,657-ft. No correction needed. Drop back down below the Tubing Patch. Re-log across the tubing Patch. Good. Continue up hole and straddle the cut target at 6,280- ft with the String Shot. Attempt to fire String Shot...however,unable to arm do to low signal. POOH to investigate. 16:30 18:00 1.50 COMPZN RPCOMP ELNE •X f Logging Downhole Schlumber Repair wire,cut 20'off and tie new Tools ger head on. 18:00 21:00 3.00 COMPZN RPCOMP ELNE --X— I g Run in the hole with string shot. Log and correlate string shot 6,273'to 6,283'.CCL to top 11.6',CCL stop depth 6261.4'.String shot fired, POOH for Chem cutter. Page 1/2 Report Printed: 11/30/2015 • * Security Level: AK Development /12 0 DDR -Vendor ,:a 3J-10 �c�0iips Report Number: 3 Rig: NABORS 7ES Report Date: 11/25/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl CTrbl Class Vendor (ftKB) (ftKB) Operation 21:00 23:30 2.50 COMPZN RPCOMP ELNE 4F' L od ng 6,280.0 6,280.0 Run in the hole with Chem cutter. 'p Log and correlate Chem cutter. Chem cut at 6,280'.CCL to cutter 27.6',CCL stop depth 6,252'4'. Chem cutter fired.String held in tension 20K.String bounced in the slips when Chem cutter fired,good cut.POOH 23:30 00:00 0.50 COMPZN RPCOMP ELNE doX' L)gtj< 6,280.0 6,280.0 Rig down DSL and prepare to pull ''j Hanger to the floor. Page 2/2 Report Printed: 11/30/2015 • • Security Level: AK Development 0 DDR -Vendor 0a 3J-10 ConocoPhillips Report Number: 4 Rig: NABORS 7ES Report Date: 11/26/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 01:00 1.00 COMPZN RPCOMP CIRC P 6,280.0 6,280.0 Pull Hanger to the floor and circulate surface to surface. 01:00 08:00 7.00 COMPZN RPCOMP PULL 'P 6,280.0 0.0 Single down 3 1/2"GL completion. Recovered 195 Jt 3 1/2"Tubing,5 GLM, 1 Nipple Assembly,3 1/2"cut -off stub OAL=14.36-ft). (the chemical cut was textbook perfect). 08:00 09:15 1.25 COMPZN RPCOMP RURD / 4. 0.0 0.0 Rig down Weatherford tubing handling equipment. Clear floor. Install Wear Bushing. Prep to run 3 1/2"Drill Plpe. 09:15 09:30 0.25 COMPZN RPCOMP SFTY )( 0.0 0.0 PJSM. Discuss the hazards associated with picking up Drill Collars and Drill Pipe. Review the make-up order of BHA#1. 09:30 10:45 1.25 COMPZN RPCOMP BHAH X 0.0 226.0 Make-up BHA#1 as follows: Cutlip f Guide,5 3/4"Overshot,Extention, Top Sub, Bumper Sub,Oil Jar, Pump-Out-Sub,6 ea x 4 3/4"Drill Collars, Intensifier. 10:45 16:00 5.25 COMPZN RPCOMP PULD 226.0 6,185.0 Single in BHA#1 with 3 1/2"Drill Pipe from the Pipe shed. Establish parameters as follows: Up weight, 130K. Down weight, 112K,SPR Pump#1 at 2.0 bpm/164 psi and at 3.0 bpm/292. SPR Pump#2 at 2.0 bpm/162 psi and at 3.0 bpm/298 psi. RTW at 15 rpms=120K. Blow down Top Drive. 16:00 16:30 0.50 COMPZN RPCOMP FISH 6,185.0 6,273.0 Continue in to the top of the 3 1/2" x cut-off tubing stump. Tag at 6,273- ;ft dpmd. Plant Overshot. Break out Top Drive. Install TIW Valve. Make i -up Top Drive. 16:30 21:15 4.75 COMPZN RPCOMP JAR 6,273.0 6,273.0 Jar Seals free from the PBR at 6,395-ft. Firing Jars at 160K(30K over). Straight pull up to 170K(40K over). Seals pulled free from PBR 170K straight pull weight.PUW 140K after pulling Seals free. 21:15 23:15 2.00 COMPZN RPCOMP CIRC 6,273.0 6,273.0 Circulate 2 surface to surface at 5 bpm to clean out top of PBR. Recovered a fair amount of formation sand...! 23:15 00:00 0.75 COMPZN RPCOMP PULD 6,273.0 5,100.0 POOH laying down 3 1/2"drill pipe and fish(Seal assembly). KO-IV) C « -Tr'tv\olt � \v,.,c, CIA)\) scam A-1 . 40^ . S'Fe � w � ail'ttii 0/4e_ h\ot, 4 As w,q,n.3tvinevti 6.,,,z,;0,,, va b4- il.tvr. bL tote i00,1, Page 1/1 Report Printed: 11/30/2015 Security Level: AK Development DDR -Vendor 3J-10 ConocoPhillips Report Number: 5 Rig: NABORS 7ES Report Date: 11/27/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 05:30 5.50 COMPZN RPCOMP PULD A 5,100.0 0.0 POOH laying down 3 1/2"drill pipe and fish Seal assembly. 05:30 11:30 6.00 COMPZN RPCOMP Pt/LT P 0.0 0.0 Load and process new 3 1/2"GL Completion into the pipe shed. Load Seal Assembly and GLMs in their proper running order. Perform the final jewelry inspection. 11:30 '11:45 '0.25 COMPZN RPCOMP SFTY P 0.0 0.0 PJSM. Discuss the hazards associated with running the completion. Review the final completion running order. 11:45 19:00 7.25 COMPZN RPCOMP2sT P 0.0 6,369.0 Single in with the 3 1/2"Completion hrT? as per the designed program. 19:00 20:00 1.00 COMPZN RPCOMP L-0 P 6,369.0 6,369.0 Pick up joints#196, 197 and 198. FP �-�1 Make up circulating head on joint UTV #98 for Space Out. 20:00 20:30 0.50 COMPZN RPCOMP HOSO P 6,369.0 Tag Locator sub at 9'on joint#198, 6,391'.Tag bottom of PBR at 19.82' on joint#198 Space Out 3',6,403'. Lay down joints#198, 197,and 196.Pick up two 10'pup joints and Joint#196.Locate Seals in PBR at 6403'. 20:30 21:30 1.00 COMPZN RPCOMP )3kJCD P Pick up GEN IV FMC Hanger and TH(r( Make up per FMC Rep. 21:30 22:45 1.25 COMPZN RPCOMP CRIH P Pump 225 bbls of Corrosion Inhibited seawater down the backside taking returns to the pits. Pump 7 bbls of seawater from the pits to clear lines. 22:45 00:00 1.25 COMPZN RPCOMP H 6O P Attempt to land Tubing Hanger, PBR sanded off,start pumps and ease down slowly washing down. Wash down through sand and landed Hanger,RILDS.(will note Sand in the PBR on Handover form). Page 1/1 Report Printed: 11/30/2015 0 0 Security Level: AK Development :i DDR -Vendor 0 01,4 3J-10 ConocoPhillps Report Number: 6 Rig: NABORS 7ES Report Date: 11/28/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 01:15 1.25 COMPZN RPCOMP PRTS P Pressure test the tubing to 3,000 psi for 15 minutes,test good.Bleed tubing pressure to 1,500 psi and pressure IA to 2,500 psi for 30 minutes,test good.Shear open the SOV at 1,850 psi. 01:15 02:15 1.00 COMPZN WHDBOP MPSP P Lay down landing joint and install IS -A BPV.Pressure test to 1,000 psi for 5 minutes,test good. 02:15 06:00 3.75 COMPZN WHDBOP NUND P Nipple down BOP's and set back on stump. 06:00 08:00 2.00 COMPZN WHDBOP NUND P Nipple up Adaptor flange and Tree. 08:00 08:30 0.50 COMPZN WHDBOP PRTS P Pressure test Hanger void at 250/5,000 psi. Good. 08:30 10:00 1.50 COMPZN WHDBOP pAfiee— P Set test Plug. Pressire test tree at 250/5,000 psi. Good. Pull Test P('�,( S Plug. 10:00 10:15 0.25 COMPZN WHDBOP SFTY P PJSM with Lil'Red. 10:15 11:30 1.25 COMPZN WHDBOP FRZP T Wellhead/ Other FMC Bring Lil' Red on line with diesel Tree Corporatio down the IA...taking returns up the n tubing at 1.0 bpm. Pressure Wellhead gradually climbed up and rate as Equipment rate decreased. 0.3 bpm at 2,100 psi.after 18 bbls away. (suspect SOV not sheared all the way open or trash?). Shut down and bleed off pressure. Swap manifold around and pump down the tubing...taking returns from the IA. 2.0 bpm/800 psi x 10 bbls pumped. Good returns. Swap back around to pump down the IA. 11:30 12:45 1.25 COMPZN WHDBOP FRZP P Bring Lil'Red pump on line at 1.5 bpm/400 psi. Good returns from the IA. Increase rate to 2.0 bpm. Continue pumping diesel freeze protect with no further problems. Final 2.0 bpm/1,400 psi x 75 bbls pumped down hole. 12:45 13:45 1.00 COMPZN WHDBOP FRZP P Rig down Lil'Red. U-Tube diesel freeze protect. 13:45 16:00 2.25 COMPZN WHDBOP MPSP T Wellhead/ Other FMC Attempt several times to set BPV. Tree Corporatio No-Joy. Suck out the fluid from the n Tree. Observe a piece of metal Wellhead across the Tubing Hanger. Further Equipment investigation reviled that FMC Serviceman failed to pull the Tree Test Plug even though he thought he did. By attempting to set the BPV the Tree Test Plug was damaged and presently it can not be retrieved. Discuss a path forward with Anchorage Engineer and Supervisor. Secure Well and prep to move off. 16:00 18:00 2.00 DEMOB MOVE MOB P Prep to rig down and move. Rig Released at 1800 hours. Page 1/1 Report Printed: 11/30/2015 • Security Level: AK Development DDR -Vendor ci &Wells 3J-06 ConoccaPhillips Report Number: 1 Rig: NABORS 7ES Report Date: 11/28/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 18:00 '12.:69- MOVE MOB P Move Rig from 3J-10 to 3J-06. Ol."do4,o •__.... - MJF Page 1/1 Report Printed: 11/30/2015 • • Security Level: AK Development 0 DDR -Vendor 3J-06 Conon€ h�iiiiips Report Number: 2 Rig: NABORS 7ES Report Date: 11/29/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 06:00 6.00 MIRU MOVE RURD P Move mats from 3J-10 and set mats at 3J-06. Lay Herculite. Stage DSA,Adaptor Flange,and Tree in cellar area. HAng tree in Sub Base. Spot Rig over 3J-06 Well. Lay Herculite for Pits. Spot Pits.Stage other supports modules. Berm up around Rig,Pits,and Cuttings Tank. 06:00 Mile, 3.50 MIRU WieMea. RURD P Finish berming up. Off load Sea 4k3LIWater in Plts. Accept Rig at 07:00 p ' hrs.continue to build volume in ,,1- `�— — Pits. Install secondary Annulus °t{° Valve. Rig up lines to circulate. ( �14�� GG�L2Q N Blow air through all lines. �1' 09:30 10:00 0.50 MIRU WELCTL RURD P Rig up lines to the Tree. Line up circulating maniford. 10:00 11:45 1.75 MIRU WELCTL MPSP P Pick up Lubricator. Pressure test zat 2,00 psi. Pull BPV. Lay down same. Tbg=800 pai, IA=720 psi, OA=460 psi. 11:45 12:00 0.25 MIRU WELCTL SFTY P PJSM for Well Kill 12:00 14:00 2.00 MIRU WELCTL KLWL P Pressure test lines at 250/3,000 psi. Good. Open Well. Tubing and IA pressures fell to"0". Line up to pump down the Tubing,taking return from the IA. Bring pump on line at 3.0 bpm/425 psi. Increase rate to 4.0 bpm/845 psi. Continue to pump until the returns are clean. Final 4.0 pbm/1,035 psi. Total Sea Water pumped...385 bbls. 14:00 14:30 0.50 MIRU WELCTL OWFF P Monitor Well x 30 minutes. Static. 14:30 15:00 0.50 MIRU WELCTL RURD P Blow down and rif down lines. 15:00 17:30 2.50 MIRU WHDBOP NUND P Nipple down Tree and remove from the cellar.Install adaptor flange for the BOP's. 17:30 21:45 4.25 MIRU WHDBOP NUND P Nipple up BOPE.prep for initial BOP test,(Shell test ram bodies) 21:45 22:15 0.50 MIRU MPSP P Set BPV. 22:15 00:00 1.75 MIRU WHDBOP BOPE P Start initial BOP test.Test Blind rams and Choke manifold 250/3500 psi.AOGCC wintiness of test waived by Jeff Jones,AOGCC Rep. Page 1/1 Report Printed: 11/30/2015 • 4110 Security Level: AK Development Oft; DDR -Vendor 0114w CD5-09 Conocx itbi lips Report Number: 6 Rig: DOYON 19 Report Date: 11/25/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (MKS) (ftKB) Operation 00:00 00:45 0.75 SURFAC CEMENT BHAH P 108.0 149.0 Cont.to M/U BHA#2 as per SLB to 149' 00:45 02:30 1.75 SURFAC CEMENT TRIP P 149.0 2,228.0 RIH f/149'to 2,228' 02:30 03:00 0.50 SURFAC CEMENT OW P 2,228.0 2,228.0 Shallow hole test MWD&cvirc B/U Dij-E- w/675-575 gpm @ 2140-1600 rrll "ill psi,30 rpm @4.5ktrq 03:00 04:30 1.50 SURFAC CEMENT PRTS P 2,228.0 2,228.0 R/U testing equip&test casing to 3500 psi&chart for 30 min(good). R/D testing equip&B/D lines 04:30 08:00 '3.50 SURFAC CEMENT MPDA P 2,228.0 2,228.0 Pull trip nipple&install MPD bearing.Conduct ramp up&ramp down with new software as per MPD advisor.B/D lines. Remove MPD bearing&install trip nipple. 08:00 10:30 2.50 SURFAC CEMENT COCF P 2,228.0 2,324.0 W&R f/2,228'to top of float collar @ 2,324'w/550 gpm @ 1420 psi,30- 5o rpm @ 5 k trq.(Tag TOC @ 2,304') 10:30 12:45 2.25 SURFAC CEMENT DRLG P 2,324.0 2,442.0 Drill out shoe track&rat hole f/2,324'to 2,442'w/550 gpm @ 1060 psi,60 rpm @ 5 k trq. Displace to 9.6 ppg LSND on the fly 12:45 13:00 0.25 SURFAC CEMENT TRIP P 2,442.0 2,237.0 B/D top drive&POOH f/2,442'to 2,237' 13:00 14:00 1.00 SURFAC CEMENT OWFF P 2,237.0 2,237.0 F/C(static) 14:00 14:45 0.75 SURFAC CEMENT TRIP P 2,237.0 2,442.0 RIH f/2,237'to 2,442' 14:45 15:00 0.25 SURFAC CEMENT DDRL P 2,442.0 2,454.0 Drill ahead f/2,442'to 2,454' 15:00 15:30 0.50 SURFAC CEMENT CIRC P 2,454.0 2,454.0 Circ B/U w/550 gpm @ 1060 psi,60 rpm @ 5 k trq.SIMOPS-PJSM on FIT 15:30 16:00 0.50 SURFAC CEMENT TRIP P 2,454.0 2,232.0 POOH f/2,454'to 2,232' 16:00 16:45 0.75 SURFAC CEMENT FIT P 2,232.0 2,232.0 R/U testing equip&FIT to 18.0 ppg 16:45 17:00 0.25 INTRM1 DRILL TRIP P 2,232.0 2,454.0 RIH f/2,232'to 2,454' 17:00 19:15 2.25 INTRM1 DRILL DDRL P 2,454.0 2,550.0 Drill ahead f/2,454'to 2,550'w/750 gpm @ 1840 psi,60 rpm @ 5 k trq. SIMOPS-PJSM on opening reamer. 19:15 20:00 0.75 INTRM1 DRILL CIRC P 2,550.0 2,550.0 Drop 1 1/4"activation ball&pump down w/75 gpm @ 80 psi. Reamer shear @ 1350 psi&open reamer @ 2,526'(11"hole @ 2,424') Reamer closed:750 gpm, 1840 psi, 4140 trpm Reamer open:750 gpm, 1420 psi, 3515 trpm. 20:00 00:00 4.00 INTRM1 DRILL DDRL P 2,550.0 3,082.0 Drill ahead f/2,550'to 3.082'MD 2,547'TVD,ADT 4.35,ECD 10.66 ppg,775 gpm, 1650 psi,PU wt 123 k,SO wt 112 k,ROT wt 117 k,Trq 3.1/5.6 k ft lbs Page 1/1 Report Printed: 11/30/2015 • Security Level: AK Development olf DDR -Vendor rpt CD5-09 Conoc�illips Report Number: 7 Rig: DOYON 19 Report Date: 11/26/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 12:00 12.0 INTRM1 DRILL DDRL P 3,082.0 4,917.0 Drill ahead f/3,082'to 4,917'MD 0 3,476'TVD,ADT 8.98,ECD 11.22 ppg,775 gpm,2100 psi, PU wt 155 k,SO wt 120 k,ROT wt 135 k, 160 rpm,Trq 10/4.5 k ft lbs, 18/20 wob. Pumping high wt nut plug sweeps to aid in BHA balling&hole cleaning 12:00 00:00 12.0 INTRM1 DRILL DDRL P 4,917.0 6,626.0 Drill ahead f/4,917 to 6,626'MD 0 4,344'TVD,ADT 8.81,ECD 11.20 ppg,775 gpm,2320 psi,PU wt 175 k,SO wt 135 k, ROT wt 150 k, 180 rpm,Trq 14.4/7.1 k ft lbs, 18/20 wob.Pumping nut plug sweeps to aid in BHA balling&hole cleaning Page 1/1 Report Printed: 11/30/2015 • • Security Level: AK Development 0 1 DDR - Vendor CD5-09 Conoci�llps Report Number: 8 Rig: DOYON 19 Report Date: 11/27/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 12:00 12.0 INTRM1 DRILL DDRL P 6,626.0 8,075.0 Drill ahead f/6,626'to 8,075'MD 0 5,080'TVD,ADT 8.94,ECD 10.98 ppg,775 gpm,2300 psi,PU wt 190 k,SO wt 145 k,ROT wt 165 k, 180 rpm,Trq 15.4/9 k ft lbs, 13/18 wob. Pumping nut plug sweeps to aid in BHA balling&hole cleaning 12:00 12:45 0.75 INTRM1 DRILL DDRL P 8,075.0 8,169.0 Drill ahead f/8,075'to 8,169'MD 5,127'TVD,ADT.52 12:45 13:30 0.75 INTRM1 DRILL RGRP T -Rig"' Tep-Brive Doyon 8,169.0 8,075.0 POOH f/8,169'to 8,075'.Trouble . l Drilling Inc shoot IBOP actuator linkage.Repair w{ iF'S same.SIMOPS-Inspect&service C-c9t5-01 top drive. 13:30 14:00 0.50 INTRM1 DRILL REAM T Rig i Tap-Bdve Doyon 8,075.0 8,169.0 W&R f/8,075'to 8,169'w/775 gpm WpS Drilling Inc @ 2280 psi, 100 rpm @ 7 k trq 14:00 00:00 10.0 INTRM1 DRILL DDRL P 8,169.0 9,483.0 Drill ahead f/8,169"to 9,483'MD 0 5,800'TVD,ADT 7.59,ECD 11.14 ppg,775 gpm,2560 psi, PU wt 219 k,SO wt 150 k, ROT wt 179 k, 180 rpm,Trq 19/10.5 k ft lbs,24/30 wob. Pumping nut plug sweeps to aid in BHA balling&hole cleaning Page 1/1 Report Printed: 11/30/2015 • III 0 Security Level: AK Development DDR -Vendor CD5-09 ConocoPhiiiips Report Number: 9 Rig: DOYON 19 Report Date: 11/28/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 12:00 12.0 INTRM1 DRILL DDRL P 9,483.0 10,889.0 Drill ahead f19,483'to 10,889'MD 0 6,513'TVD,ADT 9.31, ECD 11.03 ppg,775 gpm,2460 psi,PU wt 265 k,SO wt 157 k, ROT wt 188 k, 180 rpm,Trq 23/14 k ft lbs,20/25 wob. Pumping nut plug sweeps to aid in BHA balling&hole cleaning 12:00 12:30 0.50 INTRM1 DRILL CIRC P 10,889.0 10,889.0 Circ for 30 min w/775 gpm @ 2520 psi, 150 rpm @ 18 k trq. 12:30 13:45 1.25 INTRM1 DRILL MPDA P 10,889.0 10,889.0 B/D top drive.Remove trip nipple& install MPD bearing.SIMOPS-F/C (static) 13:45 14:30 0.75 INTRM1 DRILL CIRC P 10,889.0 10,889.0 Stage up circulation to 775 gpm& 150 Break in MPD bearing.Start weighting up f/9.6 to 10.5 ppg 14:30 19:00 4.50 INTRM1 DRILL DDRL P 10,889.0 11,264.0 Drill ahead f/10,889'to 11,264'MD 6,702'TVD,ADT 3.46,ECD 11.75 ppg,775 gpm,2970 psi, PU wt 250 k,SO wt 160 k,ROT wt 190 k, 150 rpm,Trq 23/14 k ft lbs,20/25 wob. Pumping nut plug sweeps to aid in BHA balling&hole cleaning. Attempting to hold back presure with MPD.Pressure bleeding off through drill pipe. It appears floats are washed out and not holding. 19:00 19:15 0.25 INTRM1 DRILL MPDA T BHA Float subs Schlumber 11,264.0 11,264.0 Install TIW valve on drill string. ger Circulate thru cement line up across top of annulus under MPD bearing. Slowly close MPD chokes to simulate connection. Fluid returns thru drill string.Confirm floats not holding.Decision made to POOH and C/O BHA. 19:15 21:15 2.00 INTRM1 DRILL CIRC T BHA Float subs Schlumber 11,264.0 11,264.0 Drop 1 5/8"ball&close reamer. ger Shear closed @ 2170 psi Reamer Open @ 775 gpm,2970 psi,3632 trpm Reamer Closed @ 775 gpm,3300 psi,4179 trpm 21:15 00:00 2.75 INTRM1 DRILL CIRC T BHA Float subs Schlumber 11,264.0 11,264.0 Circ hole clean for 4 B/U w/775 gpm ger @3260 psi, 150 rpm @ 16-16 k trq. Page 1/1 Report Printed: 11/30/2015 • S Security Level: AK Development DDR - Vendor CD5-09 ConocoPhillips Report Number: 10 Rig: DOYON 19 Report Date: 11/29/2015 Time Log Time Start End Dur P-T- Start Depth End Depth Time Time (hr) Phase Op Code Activity Code X Trbl Code Trbl Class Vendor (ftKB) (ftKB) Operation 00:00 01:15 1.25 INTRM1 DRILL CIRC T BHA Float subs Schlumber 11,264.0 11,170.0 Circ hole clean for 1 B/U w/775 gpm ger @ 3260 psi, 150 rpm @ 16-16 k trq. 01:15 01:30 0.25 INTRM1 DRILL OWFF T BHA Float subs Schlumber 11,170.0 11,170.0 F/C(static)SIMOPS-B/T top drive ger line up to Strip OOH 01:30 02:00 0.50 INTRM1 DRILL TRIP T BHA Float subs Schlumber 11,170.0 10,702.0 Strip OOH f/11,170'to 10,702'as ger per MPD schedule 02:00 02:45 0.75 INTRM1 DRILL CIRC T BHA Float subs Schlumber 10,702.0 10,702.0 Pump 12.5 ppg dry job. B/D top ger drive.Line up MPD and establish circ. 02:45 10:30 7.75 INTRMI DRILL TRIP T BHA Float subs Schlumber 10,702.0 2,331.0 Strip OOH f/10,702'to 2,331'as per ger MPD schedule 10:30 11:00 0.50 INTRM1 DRILL OWFF T BHA Float subs Schlumber 2,331.0 2,331.0 F/C(static) ger 11:00 12:00 1.00 INTRM1 DRILL TRIP T BHA Float subs Schlumber 2,331.0 729.0 Strip OOH f/2,331'to 729'as per ger MPD schedule 12:00 12:30 0.50 INTRM1 DRILL OWFF T BHA Float subs Schlumber 729.0 729.0 F/C(static) ger 12:30 13:45 1.25 INTRM1 DRILL MPDA T BHA Float subs Schlumber 729.0 729.0 Remove MPD bearing. Install trip ger nipple. 13:45 19:00 5.25 INTRM1 DRILL BHAH T BHA Float subs Schlumber 729.0 0.0 Rack back HWDP.L/D BHA#2 as ger per SLB.(Could not break bit from Exceed,tong wrench slipping.Left bit on Exceed&L/D) 19:00 20:15 1.25 INTRMI DRILL BHAH T BHA Float subs Schlumber 0.0 0.0 Clean&clear floor of BHA tools& ger equip.Clean cuttings from flow box. 20:15 22:45 2.50 INTRM1 DRILL BHAH T BHA Float subs Schlumber 0.0 148.0 M/U BHA#3 as per SLB to 148' ger 22:45 00:00 1.25 INTRM1 DRILL TRIP T BHA Float subs Schlumber 148.0 1,483.0 RIH w/BHA#3 f/148' to 1,483' ger Page 1/1 Report Printed: 11/30/2015 OF Tiff , \\V/7 _ ,v, THE STATE Alaska Oil and Gas ti�.-s��,��, of Conservation Commission -_� __ ALASI�:A `•i l-i•, 333 West Seventh Avenue k.00-,__....„,_fi----- ----, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �F *ALAS- ' Fax: 907.276 7542 www.aogcc.alaska.gov Theresa Lee SCANNED SE1 0 2.2I5 Workover Engineer — d ConocoPhillips Alaska, Inc. I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Rive Oil Pool, KRU 30-06 Sundry Number: 315-526 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Al Cathy . Foerster Chair e- DATED this Di day of August, 2015 Encl. RBDMS SEP 0 1 2015 STATE OF ALASKA , • ALASKA OIL AND GAS CONSERVATION COMI1,. .,ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r " Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Sus Well r r P Other.CTU Set-up - Fe 2.Operator Name: 4.Current Well Class. 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 188-060 • 3.Address: Stratigraphic r Service r , 6.API Number: P.0. Box 100360,Anchorage,Alaska 99510 50-029-21824-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No / KRU 30-06 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft)• Plugs(measured). Junk(measured): 8172 - 6836 - 8063' 6746' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 4672 9.625 4707' 4090' PRODUCTION 8113 7 8146' 6814' R E.9 EJ vV O oq- R 3/ AUG 272015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7849'-7859',7867-7891',7898'-7918' ' 6571'-6579',6586'-6605',6611'-6627' 2.875 J-55 7729 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-AVA RHS RETRIEVABLE PACKER MD=7657 TVD=6416 SSSV-OTIS'FMX' MD=1790 TVD=1761 • 12 Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service pr - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2015 OIL r VVINJ J - WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG TA GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Theresa Lee @ 263-4837 Email: Theresa.M.Lee@conocophillips.com Printed Name Theresa Lee Title: Workover Engineer Signature //'��G�� Q Phone:263-4837 Date 45/2..(0/I C Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness -5\5-52-Le Plug Integrity r BOP Test IV Mechanical Integrity Test V Location Clearance r BDP t 7L -fo 45-Do 5DO175 , (7V)P5P I's— 3, 71 ` 7/ �5 / 5Other j�r1 ra va r- p ,-r v« tt f r5- f tvSoO �s, ci , 11 , ./--a_ it- ku-I / r r -vc / Y- ! rti - / '��r,,- fr2 / : lC h . A Arai V"--t-r- 1 3 -ru v, te- c/ / a 61O1,.) p aC /C t o- tC) b z /9 l a c r,2tr( -1ei it, 300 ctbavc the topper7 2044-C 25 41z(10) ) Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O _ *t T A `/—w APPROVED BY Approved by:(447 7�`— COMMISSIONER THE COMMISSION Date./—3/— l-c- ed application is valid tor 12 months tromthe date of appro I. (C Pjl3✓l c! Submit Form and Form 10-403 Revised 5/2015 n R i (' i �i o io� 1 / IDMS Eptaclm Duplicate Iry ConocoPhillipsRECEIVED Alaska AUG 2 7 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A0000 Commissioner State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover the Kuparuk Injector Well 30-06 (PTD# 188-060). 30-06 was originally drilled in November 1988 and completed in the Al, A2, A3 sands. The well was hydraulically fractured in December 1988 and pre-produced for 17 months before it was converted to injection. 30-06 is currently waivered for water injection only due to TxIA communication on gas. There were no signs of TxIA communication while on water injection monitoring in June 2015 and the AA was approved for continued water injection on June 26, 2015. The workover plans to replace the tubing and return the well to normal status. " The CTD set up will allow for 5 A-sand laterals to be drilled from the mother bore. The 30-06 western laterals will improve support towards wells 30-04 and 3R-26 and the eastern laterals will support resources towards 30-08A CTD and 30-11. The proposed workover will pull the 2 7/8"complet)on string and packer then install a new 3 1/2" completion with a 5 1/2"tubing tail and Fl packer. We plan to inspect the exterior of the tubing for corrosion to determine a good setting depth for the new Fl packer. Estimated setting depth proposed be just above the current lowest GLM at 7,600'. CBL from August 2, 1988 shows cement top at 7,250' MD, —600' above the uppermost perforated interval and 350' above the proposed new packer placement. 'V This Sundry application is intended to document the proposed work on the Injection well 30-06 and to request a variance from 20AAC25.412(b) regarding the new packer placement depth. If you have any questions or require any further information, please contact me at 263-4837. Regards, irVireZeA 0 e C.° Theresa Lee �X'� F/o Workover Engineer CPAI Drilling and Wells Theresa.M.Lee@conocophillips.com 4., 50 -Yap per f 30-06 Kuparuk Injector Rig Workover (PTD #: 188-060) Current Status 30-06 is online under water injection only after an approved waiver in June 2015. Scope of Work The proposed workover will pull the 2 7/8" completion string and packer then install a new 3 1/2" completion with a 5 1/2" tubing tail and Fl packer. General Well info MPSP: 3,971 psi using 0.1 psi/ft gas gradient and SBHP from July 19, 2015 Reservoir pressure/TVD: 4,630 psi at 7,870' MD (6,588' TVD) SBHP taken on July 19, 2015 Wellhead type/pressure rating: CIW Gen IV 5K BOP configuration: Annular/ Pipe Rams/ Blind Rams/ Mud Cross/ Pipe Rams MIT Results: MIT-OA passed on October 16, 2013 MIT-IA passed to 3,300 psi on March 27, 2015 Well Type: Injector Estimated Start Date: October 1, 2015 Production Engineer: Scott Pessetto 263-4906/Scott.T.Pessetto@conocophillips.com Workover Engineer: Theresa Lee 263-4837/Theresa.M.Lee@conocophillips.com Pre-Rig Work 1. SL: Pull valve from GLM#6 and leave open. Obtain new SBHP. 2. Ops: Set BPV within 24 hours of rig arrival. Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate 13.9 ppg KWF. Obtain SITP and SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV, ND tree, NU BOPE and test. 4. Pull BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 2 7/8"tubing. a. If PBR will not pull free, RU E-line: Fire a string shot and cut the tubing at 7,626' RKB (middle of the first full joint above the PBR). RDMO E-line. 6. RIH w/overshot dressed for 2 7/8"tubing on 3 1/2"drillpipe, latch onto tubing stub and jar PBR and packer free. 7. RIH w/ Fl packer and 5 1/2" tail pipe on drillpipe. 8. RU DSL to space 5 1/2"tail pipe KOJ on depth prior to setting packer. Set Fl packer and release setting tools. 9. PT the IA to 1,000 psi (with 13.9 ppg in the hole)to ensure packer is set. Swap well over to seawater. POOH laying down 3 1/2" drillpipe. 10. RIH in with new 3 1/2" gas lift completion and deployment valve. Space out 7'from fully located, mark the pipe. Spot corrosion inhibited seawater into the IA. 11. Space out w/pups, MU hanger. MU dual control lines to hanger. Land the hanger, RILDS. 13. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi. PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint, install BPV. PT BPV to 1,000 psi from below. 15. ND BOPE. 16. NU tree. Pull BPV and install tree test plug. Test tree. Pull test plug. 17. Freeze protect well w/diesel. 18. Set BPV. 19. RDMO. Pre-Rig Work 1. Pull 'H' BPV. 2. RU Slickline: a. RIH and pull plug from the 2.813"X nipple. b. RIH and pull the SOV. Run Gas Lift Design for CTD. 3. Reset the well houses and flow lines. 4. Turn well over to Operations and CTD. f KUP INJ 30-06 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska.Inc. Wel API/UWI Field Name Wellbore Status ncl(°) MD(ftK8) Act Btm(ftKB) Crminn iinap. 500292182400 KUPARUK RIVER UNIT INJ40.43 5,500.00 8,172.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-06,7/720151:03:32 PM SSSV:TRDP Last WO: 34.98 6/24/1988 Vertical schematic(actuep Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,923.0 129/2015 Rev Reason:ADD WAIVER NOTE hipshkf 7/7/2015 ....................... 1 rIfCasing rings HANGE'3,330 I Casing Description OD(in) ID(in) Top MB) Set Depth(KKR) Set Depth(ND)... Wt/Len(I...Grade Top Thread I i CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 4,707,3 4,090.3 36.00 J-55 BTC I Casing Description OD(i n) ID(in) lop MKS) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 8,145.8 6,814.2 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB)33.0 Set Depth(ft..Set Depth(ND)(...Wt(IbTt) Grade Top Connection '�TUBING 27(8 2.441 7,728.7 6,473.3 6.50 J-55 EUEBRDMOD Completion Details CONDUCTOR;36.0-115.0 i Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com _ (in) 33.0 33.0 0.09.HANGER CIW TUBING HANGER 2.875 1,790.0 1,760.8 26.96 SAFETY VLV OTIS FMX SAFETY VALVE LOCKED OPEN 8/23/99 2.313 SAFETY VLV,1/90.0 1 II 7,642.7 6,403.7 36.25 LOCATOR AVA LOCATOR SUB 2.441 7,643.2 6,404.2 36.25 PBR AVA HYDRAULIC SHEAR PBR 2.374 7,657.3 6,415.5 36.18 PACKER AVA RHS RETRIEVABLE PACKER • 2.374 I 7,694.2 6,445.3 36.01 NIPPLE CAMCO D NIPPLE 2.250 7,728.3 6,472.9 35.86 SOS AVA BALL SEAT SHEAR OUT SUB,ELMD @TTL 7714' 2 441 GAS LIFT;27767 ON SWS PERF RECORD Perforations&Slots Shot • Dens Top(TVD) Bier(ND) (shotsft Top(ftKB) Btm(ftKB) (6110) (ftKB) Zone Date t) Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3,30-06 6/5/1989 6,605.3 A-2,30-06 615/1989 12.0 APERF 60 deg.phasing(Strips Kinked @ 35 deg.(,2 1/8"EnerJet SURFACE:35.04.707.3--11 IL, 7,867.0 7,891.0 6,585.7 12.0 APERF 60 deg.phasing;2 1/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1,30-06 9/23/1988 8.0 IPERF 45 deg.phasing;4 1/2" GAS LIFT;4,917.4 U9rapak Csg I Mandrel Inserts St ati GAS LIFT;6,220.6I on. N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (MB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com 2,776.7 2,548.9 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 8/24/1999 2 4,917.4 4,255.5 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 8/24/1999 GAS LIFT;6,939.9 3 6,220.6 5,270.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 924/1988 I 4 6,939.9 5,843.4 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/12/1990 5 7,270.3 6,105.9 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 924/1988 6 7,600.5 6,369.7 MERLA TGPD 1 112 GAS LIFT DMY RK 0.000 0.0 12/2/2013 GAS LIFT;7.270.3 Notes:General&Safety End Date Annotation 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;7.600 5 7/7/2015 NOTE:WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. LOCATOR;7,6427 E, PBR;7,643.2 - - PACKER;7,6573 NIPPLE;7,6942 SOS;7,728 3 APERF;7,849.0.7,859.0- APERF;7,867.0-7,691.0 (PERF;7,698.0-7,918.0 PRODUCTION,33.0-8.145 8-r:11 n � 30-06 CohocchiIIips 31/2" x 5 '/Z" CTD setup .o.' Baker Orbit Valve @-3,500' Casing-9 5/8" 36#, J-55 to 4,707' ► Casing-7"26#, J-55 to 8,146' Tubing-3 '/2" 9.3#, L-80, 8rd EUE-Mod to 7,790' ► Camco3 '/2"x1 '/2" MMGGLM's Baker 10' PBR @-7,637' I "1-4— F1 Packer @-7,600' 7GDD • -? I ' I --- 2.813"X-Nipple @-7,735' o o 3'/2'x 51/" Crossover with ports @ 7,785' Liner-2 R3 Jts 5 '/2" 14#, H-40, 7,786'to 7,870' rl lb ® OD Wearsox every-3'on CTD Laterals KOP 7,850' ► 6" �- lower joint of 5 1/2" liner lec A3Perfs 7,849'to7,859' �� iii___ E la A-2 Perfs 7,867'to 7,891'—► IF A-1 Perfs 7,898'to 7,918' -► G Date: August 10,2015 1 Drawn By: Theresa Lee Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, April 14, 2015 5:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: 30-06 (PTD 188-060) Report of suspect TxIA communication Attachments: image001.png; 30-06 90 Day TIO plot.JPG Chris- 30-06 (PTD# 188-060)was shut in prior to the full 30 days that were scheduled for a monitor period due to a water injection line upgrade to 30 pad. 24 days of the 30 day monitor period were completed but due to the slow nature of the suspected leaks there was not a sufficient amount of time to definitively prove integrity. CPAI intends to bring the well back on water injection only and monitor for an additional 60 days after the well line up grade has been completed. If integrity is proven during the monitor period CPAI intends to request an AA for water injection only or if at any time during the extended monitor period a leak is confirmed the well will be shut in and a plan forward will be formulated. Please let us know if you have any questions or disagree with the plan. Attached is a 90 Day TIO plot for reference. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 41kWELLS TEAM 3CANNEU APR 2 3 2015 From: N • oblem Well Supv Sent: Wednes•-, arch 26, 2014 8:24 PM To: Wallace, Chris D •9 ') Cc: Senden, R. Tyler Subject: 30-06 (PTD 188-060) • -:sit of suspect TxIA communication Chis, As stated in earlier reports 30-06 is suspected to have gas . • thread leaks. Because of the slow rise in IA pressure after the passing diagnostics performed in June 2013,the tubing a , IA were circulated out with clean fluid to remove the existing gas from the well. After an extended bleed of the OA pressu - an MIT-OA passed on 10/16/13. IA and OA pressures have since been bled and monitored for an extended period of time 4 14-3/26/14)with a significant differential pressure between the tubing and IA. The IA and OA have showed no pres . e build up during the monitor period. It is ConocoPhillips intention to bring 30-06 on water-only injection for a monitor period of 30 days 'tti the intention of requesting an AA for water-only injection if no communication is observed. Please contact CPAI if you disagree with this plan. 1 W y Dt o_ a_ cc _ w N W H D v - o U) O O wt a IL t, S O 0, O O N W CO O O. ✓ Z U W m NO O E 04 N- O M Clir CO) O O W N N a ti 4 p N N, • M O JI cr. cO J O O Voo C.-i Ei 0 0 0 A6ap 2 o N W n N o r { I I I I 1 i.a E yr d VC -----1.......,......;i p ICUa C ° yr u 4) as C.) a o to E E 0 U _R y 61 Z O C Z C a - yr LL LL r r r CD O N O N cz Zi.M naz 30> I L ur I • :: �, I E m $ $ l6 R .., 0 0 0 0 0 .-' _ iCI 4 0 0u, 0 yr OdM tam y r•-r N N • 03 171 ISd 7 Cl) 0 w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg n DATE: Friday,April 03,2015 P.I.Supervisor i'14•4( (iS SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-06 FROM: Chuck Scheve KUPARUK RIV UNIT 30-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvar • NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-06 API Well Number 50-029-21824-00-00 Inspector Name: Chuck Scheve Permit Number: 188-060-0 Inspection Date: 3/27/2015 Insp Num: mitCS150327165404 Rel Insp Num: Packer Depth Pretest Initial T 15 Min 30 Min 45 Min 60 Min SPT ITest'psi i6oa '}TubIing PTD 1880600ng 1 zoo 3300 3z3o -LL)'pe TeStr W 6415 i 2500 2500 2500 ?T 3200 • _,Well Te In Interval14YRTST IP/F �' OA 520 730 I. I 730 l Notes: Friday,April 03,2015 Page 1 of 1 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 re$can activity or are viewable by direct inspection of the file. Organization (do.e, ~"/'~o-Sided RESCAN DIGITAL DATA 1:3 Color items: O Diskettes, No. o Grayscale items: O Other, No/Type [3 Poor Quality Originals: o Other: TO'i'AL PAGES: "~ ! NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing r] OVERSIZED (Scannable) o Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DA'f E: ISl Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISI PAGES: (at the time of SCANNED BY' BEVERLY BREN~~HERYL MARIA LOWELL RESCANNED BY~ BEVERLY BREN t~~SHERYL M~RIA LOWELL General Notes or Comments about this file: Quality Checked (done} CD (o w a) T a) ~ o O a) (Yl N N v. \ YO (6 •tn m `_, = \ . N - a) c ra ai v O c L a) a 3 Y ° a, U ckt,Ia,Usgotl3 M 2 as Q C a () o M C Y L a I Y a) > E r C-.) 3 -0 O - 5g V 'F, as L � -1 f6 c Y a) r0 Y N a) - a) 0 a1 a) p _0 W "CD in — i - Z .) v `° �� L Q a 2 = a} a) ._..c 0 u� 0 0 '= c CO U) Q ':( Q O0.a aa)) - N a1 a) 0 cu I N 41 T) - 3 ca 6 c c ) C I" o ccu - 7 nh o O ° c / a5 a o , U L J - c^ o5 0 a) 0 I..I dt 0 .) I - Y GJ I I U a Q ca O Y o ■ � - ■ LB E I— ~ dU c o r� U Q N O c - (v Q o O ea N c 4- CO = 7 •,, (6 O c T a) LE c/) cm Q O y i - m Q Q C) U +-' O 0 o O 0 c v 0 p_ OS Y - oc a O al O E a) 0 j� O M Q c a) E E t - --- r R�UIlN N -. `n O Y ~ - — _- VN C CO U a) O ti � 0 .I 0 .0 - NI N 0 -o m Y N - O ca OO O ob 0.7 Y CO 0 +fit N CO N N cu - ' ,, '' as N - 0OQO CO U O 0 - ` - c+) � a) O I- 0. O 0) N 3 - _ L) U 'O^ O fl- ai r�^j - M MU O >- a) c � Y - a vn a _ o •p p i cu 6 - vJ o m Q 1H111L }.O a) C c c O J > a O O N p a) L �- Y Lo 0 c N L ,� *' °• - - A Q N co O N E X- C m .- a) 1-'x a) 0 cu ^ti 00 IA ti •L a) c ra O•- -'t- Y Cn — O o) t = - " m V p 0 -o Y I I - c•t' c• I- --,-11-r c' c P r i r t > — C I� +-' 0 co oQ O> n 0 0 V +-' Y -.c- C a) o 2 Q i'i i i �B p a O (Q U O c Y c p C)Q c-, c-3, _a) U L E4-; d tl 0 cO a) p r n) E - N U u I I O co 0) cti O L. L L CO OD Vt Y ISd °L O w Cu LL Cn I- U) U < t E ' Y Q m n. U o a 0 \ % o E \ 0 0 E E Zr., / E o � C = co > 0 3 ( i \ \ 3 ° _ \ ( \ \ / / \ 2 62 / e > . > k /\ \\ $ = z e\ >" D) o\ \ 5 E _c e 5 2 — f J E \ o_ j \ \ � 20 \ \ = » / ƒ ƒ £ < / E o © y / ._ -0 5 0 & . @ { csi 3 ., 3 \ \ & > 3E \ CNI C o a) G o g t o 0 0 5 a) - 2 z 0 ro § \ / \ • \ ° / $ E / E / \ f / \ � / � / t v j \ < -c a kut • £ § 0 a ` j E _ a) w a a, 4- a / \ / / CL \ k • § { 0 A / / § 2222 + a $ ƒ £ 7 L // / S � - .- - � 0 � � % 2 / § \ \ = § G / � & k cu / 0 0 / $ / A \ -J \ o e o V § / k� � _ £ / � A � 0_ $ �\ 3 S $ m f t •G A f / < \ 6 ° /3 ° 0 2 - £ 2 s n R 0)$ rg � a � / / \ \ \ 0 \.• 3 0 \ 2 i { a k J m ili 2 \ ƒ 8C ...0._ ƒ / ° $ k � 202 \ 22 * v Ea / 3CL • MEMORANDUM To: Jim Regg ~~~ ?(~~(- ( P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July Ol, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-06 KUPARLTK RIV L7NIT 30-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `~~r~ Comm Weil Name: KUPARUK RIV LTNIT 30-06 Insp Num: mitCS090626190109 Rel Insp Num: API Well Number: 50-029-21824-00-00 Permit Number: 188-060-0 Inspector Name: Chuck Scheve Inspection Date: 6/26/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 30-06 Type Inj. G I T'~ 6415 jA 325 2440 ' 2400 2360 2360 P.T.D 1880600 TypeTest SPT Test psi 1603.75 QA 180 200 200 200 200 Interval 4YRTST P~ P ,/ Tubing 3850 3850 385o 3850 3850 Notes: Pretest pressures observed and found stable . ~„`~.~t~.'~w. ~LR` r,` L.i~~~ Wednesday, 7uly O1, 2009 Page 1 of 1 FW: 30-06 (PTD 1880600) Report of suspect IAxOA communication Page I of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, September 04, 2008 2:25 PM `~ ~~~~~v~ To: 'NSK Problem Well Supv' Subject: RE: 30-06 (PTD 1880600) Report of suspect IAxOA communication Infa provided does appear to confirm something other than mechanical integrity as a source of the IA and OR pressures. Based on the info provided, l concur with your request to place this well back on injection. )njection is governed by the provisions of A!O 2B. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, September 04, 2008 2:11 PM To: Regg, James B (DOA) "~~~ Subject: FW: 30-06 (PTD 1880600) Report of suspect IAxOA communication From: Sent: To: Cc: NSK Problem Well Supv Thursday, June 12, 2008 12:06 PM 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 30-06 (PTD 1880600) Report of suspect IAxOA communication Jim, The initial diagnostics have been completed followed with monitoring the wellhead pressures. On 05/28f08 the well passed an MITIA to 2500 psi. The current TIO plot shows no sign of communication between the IA and OA. It is my opinion that the IA had some gas mixed in solution with the diesel causing the IA x OA communication that was resolved by bleeding the IA dawn to common line pressure and reloading the IA with clean diesel. ConocoPhillips would like permission to continue WAG injection under normal well status with out applying for an AA. If any future annular communication is observed, the AOGCC will be notified and further diagnostics will be performed. The appropriate paperwork will be submitted at that time. Attached is the test form far the MITIA performed on 05/28/08 and a current 90 day TIO plot. Please let me know if you have any questions. «30-06 90 day TIO plot.jpg» «MIT KRU 30-06 05-28-08.x1s» Brent Rogers/Martin Walters ~~~~~ SEA i ~ 208 9/4/2008 FW: 30-06 (PTD 1880600) Report of suspect IAxOA communication Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Friday, May 16, 2008 5:03 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 30-06 (PTD 1880600) Report of suspect IAxOA communication Tom and Jim, Kuparuk WAG injector 30-06 was reported with suspect IAxOA communication. The OA was requiring frequent bleeds to maintain pressure below the MAOP. The TIO was 2910/1600/970. The well had a passing MITOA on 03/05/08 and passing Inner Casing Packoff tests passed on 04/18/08. It is ConocoPhillips intention to leave the well on water injection to perform the initial diagnostics, which will include a MITIA. Pending the results of the MITIA, the IA will be bled down below 1000 psi and the OA will be bled down below 500 psi for diagnostic wellhead pressure monitoring not to exceed 30 days. After the 30 day monitoring period, the results will be used to apply for an AA to continue water injection. The well will be added to the monthly report to the AOGCC and updated results from the diagnostics will be reported. Attached is a 90 day TIO plot and schematic. « File: 30-06 90 day TIO plot.jpg » « File: 30-06 schematic.pdf » Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/4/2008 • ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 ~l~~d~G Ally ~ ~ ~DD$ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~,o ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, `/ ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) `~ s~ Date Kuparuk Field 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7!27/2008 10 7/30/2008 RE: 30-06 (PTD 1880600} Report of suspect IAxOA communication. • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, June 12, 2008 12:06 PM ~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 30-06 (PTD 1880600) Report of suspect IAxOA communication Attachments: 30-06 90 day TIO plot.jpg; MIT KRU 30-06 05-28-08.x1s Jim, Page 1 of 2 The initial diagnostics have been completed followed with monitoring the wellhead pressures. On 05/28/08 the well passed anIA to 2500 psi. The current TIO plot shows no sign of communication between the IA and OA. It is my opinion that the iA had some gas mixed in solu#ion with the diesel causing the IA x OA communica#ion tha# was resolved by bleeding the IA down to common line pressure and reloading the IA with clean diesel. ConocoPhillips would like permission to continue WAG injection under normal wail status with out applying for an AA. If any future annular communication is observed, the AOGCC will be notified and further diagnostics will be performed. The appropria#e paperwork will be submitted at that time. Attached is the test form for the MITIA performed on 05/28/08 and a current 90 day T10 plo#. --~ Please let me know if you have any questions. / ~/ «30-06 90 day TIO plot.jpg» «MIT KRU 30-06 05-28-08.x1s» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~ ~NN~~ S E ~ ~ ~ 2008 From: NSK Problem Well Supv Sent: Friday, May 16, 2008 5:03 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 30-06 (PTD 1880600) Report of suspect IAxOA communication Tom and Jim, Kuparuk WAG injector 30-06 was reported with suspect IAxOA communication. The OA was requiring frequent bleeds to maintain pressure below the MAOP. The TIO was 2910/1600/970. The well had a passing MITOA on 03/05/08 and passing Inner Casing Packoff tests passed on 04/18/08. It is ConocoPhillips intention to leave the well on water injection to perform the initial diagnostics, which will include a MITIA. Pending the results of the MITIA, the IA will be bled down below 1000 psi and the OA will be bled down below 500 psi for diagnostic wellhead pressure monitoring not to exceed 30 days. After the 30 day monitoring period, the results will be used to apply for an AA to continue water injection. The well will be added to 8/21 /2008 RE: 30-06 (PTD 1880600) Report of suspect IAxOA communication • Page 2 of 2 • the monthly report to the AOGCC and updated results from the diagnostics will be reported. Attached is a 90 day TIO plot and schematic. « File: 30-06 90 day TIO plot.jpg » « File: 30-06 schematic.pdf » Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 8/21 /2008 KRU 30-06 PTD 188-060 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~~~ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov l OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 30-06 05/28/06 Edelen - LRS Packer Depth Pretest Initial 5 Min. 30 Min. Well 30-06 :Type Inj. W TVD 6,415' Tubing 2,900 2,900 2,900 2,900 Interval O P.T.D. 1880600 - Type test P Test psi 1604 Casing 280 2,500 2,475 2,475 P/F P Notes: Non witnessed diagnostic MITIA OA 260 270 270 270 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type fnj. TVD Tubing Intervai P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 30-06 05-28-08.x1s ~~ ~,~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, May 16, 2008 5:03 PM ~~j~ 5~ 12~c~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) l 77 Cc: NSK Well Integrity Proj; NSK Problem Wetl Supv Subject: 30-06 (PTD 1880600) Report of suspect IAxOA communication Attachments: 30-06 90 day TIO plot.jpg; 30-06 schematic.pdf Tom and Jim, Kuparuk WAG injector 30-06 was reported with suspect IAxOA communication. The OA was requiring frequent bleeds to maintain pressure below the MAOP. The TIO was 2910/1600/970. The well had a passing MITOA on 03/05/08 and passing Inner Casing Packoff tests passed on 04/18!08. ~~ It is ConocoPhillips intention to leave the well on water injection to perform the initial diagnostics, which will include a MITIA. Pending the results of the MITIA, the IA will be bled down below 1000 psi and the OA will be bled down below 500 psi for diagnostic wellhead pressure monitoring not to exceed 30 days. After the 30 day monitoring period, the results will be used to apply for an AA to continue water injection. The well will be added to the monthly report to the AOGCC and updated results from the diagnostics will be reported. Attached is a 90 day TIO plot and schematic. «30-06 90 day TIO plot.jpg» «30-06 schematic.pdf» Please let me know if you have any questions i ~ ~~~ MAY ~ ~ 200 Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 5/ 19/2008 KRU 30-06 PTD 188-060 • • '•.~'~ C4r~ocoPhiNl~ps Alaska, Nn~. SSSV (1790-1791, OD:2.875) Gas Litt IandreVDummy Valve 1 (2777-2778, OD:4.750) Gas Liit IandreVDummy Valve 2 (4917-4918, OD:4.750) Gas Lift IandreVDummy Valve 3 (6221.6222, OD:4.750) Gas Lift IandreVDummy Valve 4 (69446941, OD:4.750) Gas Lift IandreVDummy Valve 5 (7270-7271, OD:4.750) Gas Lift IandreVDummy Valve 6 (76047601, OD:5.460) P8R (764&7644, OD:2.875) PKR (7657-7656, 0 D:6.151) NIP (7694-7695, OD:2.875) TUBING (47729, 0 D:2.875, ID:2.441) Pert (7849-7859) Ped (7867-7891) Perf (7898-7918) KRU 30-06 30-06 API: 500292182400 Well T e: INJ An le TS: 36 de 7806 SSSV T e: LOCKED OUT Ori Com letion: 6/24/1988 An le TD: 35 d 8172 Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference Lo Ref Lo Date: Last U date: 7/20/2006 Last Ta : 7912 TD: 8172 ftK6 Last Ta Date: 7/18/2006 Max Hole An le: 40 de 5500 Casin Strin -CONDUCTOR Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Casin Strin -SURFACE Descri lion Size To Bottom TVD Wt Grade Thread SUR. CASING 9.625 0 4707 4090 36.00 J-55 Casin Strin -PRODUCTION Descri lion Size To Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 8146 6814 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt G rade Thread 2.875 0 7729 6474 6.50 J-55 EUE SRD MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7849 - 7859 6571 - 6579 A-3 10 12 6/5/1989 APERF 60 deg. phasing (Strips Kinked @ 35 deg.); 2 1/8" EnerJet 7867 - 7891 6586 - 6605 A-2 24 12 6/5/1989 APERF 60 deg. phasing; 2 1/8" EnerJet 7898 - 7918 6611 - 6627 A-1 20 8 9/23/1988 IPERF 45 deg. phasing; 4 1/2" Ultra ak Cs Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2777 2549 MMH FMHO DMY 1.0 BK 0.000 0 8/24/1999 2 4917 4255 MMH FMHO DMY 1.0 BK 0.000 0 8/2411999 3 6221 5271 MMH FMHO DMY 1.0 BK 0.000 0 9/2411988 4 6940 5843 MMH FMHO DMY 1.0 BK 0.000 0 3/12!1990 5 7270 6106 MMH FMHO DMY 1.0 BK 0.000 0 9/24/1988 6 7600 6369 Merla TGPD DMY 1.5 RK 0.000 0 8/24/1999 Other lu s, a ui ., etc. -COMPLETION De th TVD T e Descri lion ID 1790 1761 SSSV Otis 'FMX' -LOCKED OUT 8/23199 2.313 7643 6404 PBR AVA 2.374 7657 6415 PKR AVA'RHS' 2.374 7694 6445 NIP Camco'D' Ni le NO GO 2.250 7728 6473 SOS AVA 2.441 7729 6474 TTL ELMD TTL 7714' ON SWS PERF RECORD 2.441 MEMORANDUM TO: Jim Re gg 'T.?¡. . I.l7~ .;{ D'G P.I. Supervisor Nò:qt{ '(. v ) ~ FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV UNIT 30-06 Insp Num: mitJCr060613131420 Rei Insp Num ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-06 KUPARUK RIV UNIT 30-06 \ <{6" O{øO Src: Inspector Reviewed By: .(¡~~ P.I. Suprv,__¡ t';f-' Comm NON-CONFIDENTIAL API Well Number 50-029-21824-00-00 Permit Number: 188-060-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth --T..-..-:--r.---.-r-.--~-----·r- Well 30-06 ¡Type Inj. ¡wi TVD 6415 ~.T. 1880600 iTypeTest I_SPT l.Test psi i__ -160~.75 Interval 4YR~~__._.f/F P _____. Notes 1.3 bbl's pumped for test. Wednesday, June 14,2006 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I ~:r:: 1-':.7 -¡-~::-r2:.:o-1 . T-=--= Tubing I 2850 ,m'l 2850 r----;-850--·-28-5~1----·--·-l-----·-·--·--..- I __._.----L..____.--L..._.--..l... ' SCJ\NNED JUN 2 ï 2006 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: June 28, 2002 THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests PAl 3O multiple KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 30-05 I Typelnj. J G I T.V.D. I 6514 I Tubingl 3750 I 3750 J'3750 I 3750 I lntervall 4 P.T.D.I 1880760 Type testI P I TestpsiJ 1629 J CasingJ 1425 I 2050 I 2040 J 2040 I p/F j,p, Notes: WellI 30-06 I Typelnj. I G I T.V.D. I~,~ I Tubing I~ I~,~ I~ I~ I Interval} 4 P.T.D.I 188O6OO Type testI P I Testpsil 1604 I CasingI 26OO I 3o00 I 2e~o I 298o1 P/[ I ~ Notes: WellI 30-07 J Typelnj. J S I T.V.D. 16502 I'Tubing11500 11500 11500 11500 l intervali 4 P.T.D.I 1880770 ITypetestl P [TestpsiI 1626 ICasingI 950 I 2250 I' 22401 22401 P/FI -" Notes: WellI 30-10 I Typelnj. I G I T.V.D. 16360 I Tubing 13600 13600 I 3600 I 3600 I lntervall 4 P.T.D.I 1880590 ITypetestl P ITestpsil 1590 ICasingI 2550 I 3000 I 2980 I 2970 I P/FI P Notes: "' We,,I 3o-12 I Type,nj.I G I T.V:D. 16404 I Tubing ]3650 I 3650 13650 l. 3650 J lntervall 4 P.T.D.I 1880410 ITypetestl P ITestpsiI 1601 I Casingl 76O I 2O5O I 20501 2OOO1 P/F I ~ Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 1 of 2 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 5 Attachments: none Number of Failures: 0 Total Time during tests: 4 hrs cc: none MIT report form 5/12/00 L.G. mit(l) kru 3o 6-28-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,, 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 59 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 832' FNL, 1904' FWL, Sec. 22, T13N, R9E, UM (asp's 525539, 6021988) 30-06i At top of productive interval 9. Permit number / approval number 1258' FSL, 1307' FEL, Sec.16, T13N, R9E, UM (asp's 522317, 6024068) 188-060 At effective depth 10. APl number 50-029-21824 At total depth 11. Field / Pool 1351' FSL, 1501' FEL, Sec.16, T13N, R9E, UM (asp's 522123, 6024160) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8172 feet Plugs (measured) Tagged Fill (5/20/00) @ 7926' MD. true vertical 6836 feet Effective depth: measured 7926 feet Junk (measured) true vertical 6634 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 181 Sx AS II 115' 115' SURF CASING 4648' 9-5/8" 1650 Sx AS III & 300 G 4707' 4090' PROD CASING 8087' 7" 300 SX CIG & 175 AS I 8146' 6814' Perforation depth: measured 7849 7859'; 7867-7891'; 7898 7918' ; '~', ~I /~ L I \ true vertical 6571 - 6579'; 6586 - 6605'; 6611 - 6627' Tubing(size, grade, and measured depth) 2-7/8", 6.5#, J-55 Tbg @ 7729' MD. R~_...cE~VED Packers & SSSV (type & measured depth) AVA 'RHS' Packer @ 7657' MD. .... Otis 'FMX' - Locked Out 8/23/99 @ 1790' MD. M/~ D ~, ? ;) [~ 01 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaska Oi~ & Gas Cons. Comrnissiot~ Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 1186 - 2726 Subsequent to operation - 1528 - 2654 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service ~,(WAG)~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 30-06i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 2/3/00: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 7849 - 7859' MD 7867 - 7891' MD 7898 - 7918' MD Pumped Stage #1: a) 300 bbls Slick Seawater @ 20 - 26 bpm & 8000 psi, followed by b) 50 bbls Gelled Scour slurry w/1 ppa proppant, followed by c) Shutdown. Pumped Stage #2: d) 500 bbls Slick Water w/1500 lbs Rock Salt Diverter, followed by e) 50 bbls Gelled Scour w/1 ppa proppant, followed by f) Shutdown. ISIP @ 2979. Saw excellent diversion response w/Rock Salt Diverter and pressure drop w/Scour stage. Rigged down. 5120100: RIH & tagged fill at 7926' MD. Returned well to water injection & obtained a valid injection rate. MICROFILMED 10/12/00 DO NOT PLACE ANy NE W MA TERiAL UNDER THIS PAGE 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate m Plugging Pull tubing Alter casing Repair well 2. Name of Operator 1 5. Type of Well: Development X ARCO Alaska, Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 832' FNL, 1904' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1258' FSL, 1307' FEL, Sec. 16, T13N, R9E, UM At effective depth 1324' FSL, 1445' FEL, Sec. 16, T13N, R9E, UM At total depth 1351' FSL, 1501' FEL, Sec. 16, T13N, R9E, UM 81 72' feet Plugs (measured) 6835' feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured 8063' feet Junk (measured) true vertical 674 6' feet None Casing Length Size Structural Conductor 8 0' 1 6" Surface 4672' 9 5/8" 8113' 7" Production Liner Perforation depth: measured 7898'-7918', true vertical 6610'-6627', 6571 -6579, Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 7729' Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 7657' & Otis 'FMX' SSSV @ 1790' Stimulation or cement squeeze summary Intervals treated (measured) 13. 14. Cemented Perforate Pull tubing Other X 6. Datum elevation (DF or KB) RKB 5~)' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-6 9. Permit number/Approval number 88-60/90-009 10. APl number 5o-02~)-21 824 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth Measured depth 181 sx AS II 115'MD 115'TVD 1650 sx AS III & 4707'MD 4090'TVD 300 sx Class G 300 sx Class G 81 46'MD 6814'TVD 175 Sx AS I 7849'-7859', 7867'-7891'MD Treatment description including volumes used and final pressure 6586-6605' TVD RECEIVED APR ! / 1.990 Alaska Oil & Gas Cons, Conigll~ll ch0ra Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 724 421 0 1195 - 4800 650 Tubing Pressure 148 2300 16. Status of well classification as: Water Injector X_ Oil _ Gas Suspended Service Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title ' Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ALASKA O I L AND GAS CONSERVAT I ON COMH I SS I ON MECHANICAL INTEGRITY TEST ,, PRETEST START 15 M IN 30 M IN .Ap *1 TYPE OF PKR CASING TBG REQ TBG TIME TINE TIME WELL *S - ANNULUS lYO S I ZE/WT/CRADE S I ZE lEST ~$G IBG IBG IBG SIARI TIME & COMMENTS NAME *H *N FLU I D MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS " '" ............. , ,, ...... ...... ,,, ...... ...... , , .... ~ ' ,, , ............ ., ...., ,, .... i ...... *1UBING INJECTION FLUID: P = PRODUCE WATER INJ S = SALT,WATER INJ H = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING D.EWS.06 rev 0~/', ANNULAR FLUID: GRADIENTs DIESEL ~,,~..~.~ GLYCOL SALT WATER DRILLING HUD OTHER OTHER AOGCC W I TNESS S I (:;NATURE COMPANY REP SIGNATURE C '~~~'-'~-"~'~ 20 AAC 25.030(a -q AAC 25.q12(c AAC 25.252(d ID:KRU/CI./NU×DRILLING TEL NO:90?-265-6218 ., ~S25 4',,s SCALE F= 2 Idl~ NOTES I.N.L COORDINATES ARE A.$.R. ZONE 4. ~. AL.J. DISTANCES ~,IOWN ARE TRUF.. 3, ELEVATIONS ARE AL~ WELJ,,S LOCATED IN_SEC. 22 ~ 5. Ga ELEVATIONS F'J~OM CED-RIXX' T. !:5 N., R. 9 F_, UMIAT MERIDIAN. - ' 6. HORIZONTAL I~C~ITION BASED ON ~ CoNTROl. MONUMENTS ~ I.OUN~BURY & ................. As-~i .... - O~sT. "DIST. 0.~ '"'P~D Wall . y . x. LATITUDE LONGITUDE £Ni. ': i L" ~ , I 6,0;~ 2,095. :'7 520,478.27 700 ZS~ '~ ?,$38,' 1490 47':~0.897" 724' 184Z' I?.B' 23,9' 2 6,02.2,075. 89 52.5 ~490.94 7002,8, 17.128 ', 149o 47,$0.~26- 745' ~ e.oza,o~2.~ ~,~.07 ~u: ,e,,~" ,4~:,~:~o.,~:: 76~ ~oe7' ,7.7' 4 6,022,030,~ 525,5J5,58 ~28, ~i ,, 149 47,Z9.8~. 78~ 5 6,02Z,~8. ~ 525,528.38 7~Z8, i490 47, 29.4~. 81 I, lSg~; 18. 9 6,OZ I ,S~Z. IZ 5~ ,570. z7 i5.632 149° 47 27,974 89~ 1941 18.4 23.2 I0 6~OZ I ~84~ ~ 525 ,.623.61 ~28' 14:~" 149° 47'26.6~" 975' 1986' 11 6,0~1 ~822. ~ 5~5 ~635.71 ~* 14.651" 1490 47*Z6.Z95" ~7' 1998" 18.8' 23.5' ~z e,ozi ,e~.e7 sas,648.~ 7~28', 14.4~7" 149°47',~.9~'~ 10~9' 2011' 16.8' 13 6,021,779. 16 5~5,66t ,~ ~e~, 14. 223" 149°47 25.5~, 104l~ 2024' 18.9', 2~.~; ,, ,'.o'o': ,,.o, 15 6,021 ~735. 76 5~5 ~6. IZ 1~.~5 149047 24.8~ I0 2048, I~.0, 22.~; 16 6,02 1,714. 15 525,6~. 17 ~028' 13,~5" 14g°47'~4.4~ I1~ 20~ 19. 1 2~9 17 6~Og1,69~ 5~5,710.85 ~' 13,~6~" 149°4T'24.0~ 112~ 207~' 19.0' 219' t8 6,02 1,670.97 525,7~,~ ~Z8' 13. 157" 149047'~3,73~" 1149' 2085' 19.0' i , ...... _. , ,.- , , , ....... I HEEEBY CERTIFY TH&T I AM PROP~:RLY I~GISTEREO AHO L~ENSED TO PRA~ TICE LAND SURVEYING IN TIlE STATE ~ ALASKA ANO THAT THIS PI. AT RE PRESENTS A .LO~ATION SURVEY MAD~ BY ME OR UNDER, MY 8UPER¥1$1ON, AND THAT AI.L DIMENSIO'N~ ANO OTHF.,~ OlETN!~ ~ CO,mELT ,~ C~' We/SS. ARco Alaska Inc. D.S. 3.0 WELL CONO~CTOR ~'~UICT ~: --. --- ...... m~A~~- ' .... LOUNSBURY & &NCHOSAGg, _ ........ ::.:...~A A., ~.n. ~, MO'~ I ~.~ ~' _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMh.'-,SION APPLICATION FOR SUNDRY APPROVAL p 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. Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 832' FNL, 1904' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1258' FSL, 1307' FEL, Sec. 16, T13N, R9E, UM At effective depth 1324' FSL, 1445' FEL, Sec.16, T13N, R9E, UM At total depth 1351' FSL, 1501' FEL, Sec. 16, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 81 7 2' true vertical 6 8 3 5' Effective depth: measured 8 0 6 3' true vertical 6 74 6' Casing Length Size Structural Conductor 8 0' I 6" Surface 4672' 9 5/8" Production Liner Perforation depth: 8113' 7" feet feet feet feet measured 7898'-7918', true vertical 6610'-6627' Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 7729' Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 7657' & Otis 'FMX' SSSV @ 1790' Attachments Description summary of proposal _ Plugs (measured) Cement: Junk (measured) 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-6 9. Permit number 88-60 feet 10. APl number 5o-0~9-21 824 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 9970'-10234' Cemented Measured depth True vertical depth 181 sx AS II 115'MD 115'TVD 1650 sx AS III 4707'MD 4090'TVD & 300 sx Class G 300 sx Class G 8146'MD 6814'TVD & 175 Sx AS I 7849'-7859', 7867'-7891' 6571'-6579', 6586'-6605' 13. Convert well from oil producer to water injector. 14. Estimated date for commencing operation December 20, 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch 15. Status of well classification as: Oil X Gas __ Suspended Service _Water In!ector 17. I hereby certify that the foregoing is true and correct to t,l~ best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integrity Test~,~// Approved by the order of the Commission Location clearance Subsequent form require ORIGINAL SIGNED Bi' LONNIE C. SMITH IApproval No. 10-,)g)z/ ....,.,rove~ C,O~¥ Commissioner Date / Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-6,14,16a Conversion to Water Injection Service Wells 30-6, 14, and 16a are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these three wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. WELL Expected SBHP 30-14 2000 psi 30-16a 2000 psi 30-6 2000 psi 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSi WlRELINE RAMS (VARIABLE SIZE) ..3.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EQU I PMENT m i ARCO Alaska, Inc. Date: April 5, 1989 Transmittal #: 7457 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-01 30-06 30-09 30-02 2Z-13 2Z-13 2Z-01 2D-16 2D-14 30-02 30-O9 30-06 Ku Ku Ku Ku Kui 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Fluid Level Report Camco BHP Report Camco BHP Report Sub-Surface Pressure Report Sub-Surface Pressure Report Sub-Surface Pressure Report 3 - 2 6 - 8 9 Sand 'A' Sand 'A' 2 - 1 5 - 8 9 Sand 'A' 2 - 1 9 - 8 9 Sand 'A' 3 - 2 4 - 8 9 Both Sands 3 - 2 4 - 8 9 Sand 'A' 3-21 -89 Tubing 3-09-89 BHP 3-09-89 BHP 2-1 9-89 #6461 3 2-1 9-89 #6461 3 2-20-89 #29855 ., Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska ........... -.--- ' Anchorage SAPC Mobil Chevron Unocal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~J ABANDONED ~] SERVICE 2. Name of Operator 7. Permit Number 88-60 ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 029-21824 , 4. Location of well at surface 9. Unit or Lease Name 832' FNL, 1904' FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1258' FSL, 1307' FEL, Sec.16, T13N, R9E, UM 30-6 At Total Depth 11. Field and Pool 1351' FSL, 1501' FEL, Sec.16, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool RKB 59'[ ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ' I 15. Water Depth, if offshore 116. No. of Completions 06/18/88 06/23/88 ~/,/~_~/~'~'f1~I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+'I'VD) 19. D~rect~onal Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8172'MD/6835'TVD 8063'MD/6746'TVD YES [i2/ NO []] 1790' feet MD 1700' Capprox~ 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, CAL, GR, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 R,irf !!5' 24" !8! s.v. AS !! 9-5/8" .~R.O# .l-SS Surf 4707' !2-!/4" !550 sx AS II! & 300 oxl Clcss 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) Perforated w/8 spf, 45° 'phasing 2-7/8" 7729' 7657 7898 ' -7918 'MD/6610 '-6627 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addendum, dated 1-24-89 for fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1 Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ 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 NOTE: Drilled RR 6/24/88. Perforated well and ran tubing 9/24/88. Fractured well 12/14/88. Form 10-407 Submit in duplicate Rev. 7-1-80 098/WC5 CONTINUED ON REVERSE SIDE 29, · -'- . ' , .... 30.'. ' .... . . GEoLoGIC MARKERs"" ' ' FORMATION TESTS · :..'..'i-~ .',' .~'/.:~'.... · '_'.'~:' ':', ":~ .~!.'; .-'..:,'::; iTM- ........... ' ..... ~...i':... :..- .... ~,'... .: , '-'-. ' ';' . '."':.' : ,:, ,. · . 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 7798' 6529' N/A Base Kuparuk C 7822' 6548' Top Kuparuk A 7838' 6561 ' Base Kuparuk A 7962' 6663' 31. 32, I hereby certify that the foregoing is true and correct to the best of my knowledge ' , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of .Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (D.F, 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 ADDENDUM WELL: 8/2/88 30-6 Run CBL, Gyro, Gauge ring. No depths given. -D ril lif-SuperV-i~ ADDENDUM WELL: 12/14/88 30-6 Frac Kuparuk "A" sand perfs 7898'-7918' in eight stages per procedure dated 12/8/88 as follows: Stage 1: Pmp 150 bbls gelled diesel pre-pad @ 18-20 BPM, 4500-4100 psi Stage 2: Pmp 525 bbls gelled diesel pad @ 20 BPM, 4120-4000 psi Stage 3: 45 bbls gelled diesel, 2 ppg Carbolite @ 20 BPM, 4000-3800 psi Stage 4: 65 bbls gelled diesel, 4 ppg Carbolite @ 18-20 BPM, 3800-3962 psi Stage 5: 70 bbls gelled diesel, 6 ppg Carbolite @ 20 BPM, 3980-4600 psi Stage 6: 80 bbls gelled diesel, 8 ppg Carbolite @ 20 BPM, 5100-5069 psi Stage 7: 62.5 bbls gelled diesel, 10 ppg Carbolite @ 20 BPM, 5200-5350 psi Stage 8: 48 bbls gelled diesel Flush @ 20 BPM, 5300-5200 psi Fluid to Recover: Sand In Zone: Sand in Csg: Avg Pressure: 979 bbls 64,268# 780# 4600 psi DriIling Supervisor August 19, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80080 Well: 3-o-6 Field: Kuparuk Survey Date: August 2, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA, 3-0-6 KUPARUK ALASKA I NC:. SF'ERRY-SUN WELL SURVEY I NG _C~_~M~'~.N_.Y_ ANCHORAGE ALASKA DATE OF SURVEY AUGUST C:OMPUTAT I ON DATE ............. BO.~ OYRQSCQF.'IC~_ SURVEY___ AUGUST 5, 1988 dOB NUMBER AK-BO-80080 KELLY BUSHING ELEV. OP_E 8_A. TO_R_.-_~.CG! ! I RE VERTICAL SECTION CALCULATED ALONG C:LOSLIRE E'LAGE 1 1988 59.00 FT. TRUE ~,UB-._,EA F:A~ ~R.C;E MEA'.--;URED VERT I CAL VERT I CAL I NCL I NAT I ON 'JEPTH DEF'TH DEPTH DEG M I N 0 0.00 -59.00 0 0 100 100.00 41.00 0 16 200 200.00 141.00 0 17 300 300.00 241.00 0 19 400 400.00 341.00 0 19 500 499.99 440.99 0 22 600 599.99 540.99 0 19 700 699.99 640.99 0 19 800 799.99 740.99 0 17 900 899.99 840.99 0 18 1000 999.98 940.98 i 1 1100 1099.83 1040.83 4 45 1150 1149.57 1090.57 6 48 1200 1199.12 1140.12 8 34 1250 1248.49 1189.49 9 29 1300 1297.68 1238.68 11 8 1350 1346.58 1287.58 12 49 1400 1395.20 1336.20 14 8 1450 1443.56 1384.56 15 14 1500 1491.68 1432.68 16 19 1550 1539.41 1480.41 18 14 1600 1586.57 1527.57 20 31 1650 1633.17 1574.17 21 55 1700 1679.31 1620.31 23 24 1750 1724.81 1665.81 25 32 1800 1769.57 1710.57 27 19 1850 1813.61 1754.61 29 11 1900 1856.81 1797.81 31 13 1950 1899.11 1840.11 33 10 2000 1940.41 1881.41 3:5 26 COLIR:E;E DOG-LEG O I REC:T I ON SEVER I TY DEGREES DEG/100 TOTAL ............. RECTANGULAR COORD i'NATES NORTH/SOUTH EAST/WEST VERT I CAL SECT I ON N 0. 0 N 18.10 N 23.50 N 13.30 N 2.60 N 0.80 N 8.80 N 13.19 N 9.10 N 13.8.9 N 21.30 N :::9. 0 N 40.60 N 43.89 N 46. 0 N 49.3.9 N 52.30 N54. 0 N 55.19 N 56.30 N 57.69 N 58.30 N 58.10 N 58.19 N 58.39 N 58.6.9 N 58.60 N 58.60 N 58.69 N 59.10 E O. 00 0.00 0:'00 E 0.27 0.~.--<"-' N O. 07 E E 0.04 0.68 N 0. '-'~' E 0.06 1.18 N 0.41 E E 0.06 1.73 N 0.49 E E 0 07 2 .:,._ N 0...1 E E 0 ") '~' '- .~.J N 0.55 E .,.0 E O. "-' '- o,:, :~. ,.,( N 0.66 E E 0.04 4. ]'-' . L.,. N 0.76 E E O. 'r-' '- (.:, 4.5b: N 0.87 E W 0.79 5.61 N 0.61 E W :"::.80 9 66 N '-, ':'5: '-~ . ~ ....... ~...~,._ ~'v W 4.11 13.53 N ._,=-.56 W W 3. 65 18. 47 N 10..,:,o'" W W 1..94 24.02 N 15 /"-' .. , ~.:? W W '-' ='--' 30 ' :"~ '~"-' o._ N 27 W .',, ._1._"~ , .,:..- , 0.00 O. 0/.:. 0. 16 0..,...":'9 C). r...-, oJ ..' 0.84 1.13 1.33 !,53 1.71 2. ~2 7,!8 11.98 18.45 24. !~ 34 "~ W 2.26 50.90 N W '"' 26 ='~-' ~,,.~. 55 N W 3, 9! 66,..6~ N W 4.58 75.42 N W 2 W ............. ~. 96 W 4.26 W 3.57 W -_S.'., 74 W 4.'"'~',., o W 3.90 W 4.54 50.01 61.25 73.71 87.78 84.95 N 103.17 ...... '.~.,.;l.~ N ................. 1.1 F', 5:~: 106.00 N 1:37.16 117.61 N 156.14 !27.73 N 176,3.5. 143.03 N 197.82 156.89 N 220.58 171.45 N 244,7! W 45.27 H ............ ~,.. :~.0 W 69.57 ~:_~, 16 W 9'-' W 114.60 W 132.70 . W ...... 151...~,7 W 172.6:3 W 1 .94..92 W _ .. 21'-' ~':' '.-" i W ,.-4._. 7:_=: W 270.37 · -,9o F, ARCO ALASKA 3-0-6 KUPARUK ALASKA I NC. SPERRY-SUN WELL SLIRVEYING E:OMPt~LNY PAGE ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 198:3 COMPUTAT I ON DATE .......... BO~_D_Y~OSCOE, iC ~_,.~~_ ._ '~'a'-' dOB NUMBER AK-BO-80080 AUGUST 5, 1..,~o KELLY BUSHING ELEV. = ~'-. ~ 00 FT. OP~T~R:~L!I~ ........ VERTIC:AL SECTION CALCULATED ALONG CLOSLIRE TRUE SUB-SEA COURSE MEASURED VERT I CAL VERT I CAL I NCL I NAT I ON ]EPTH DEPTH DEPTH DEG M I N 2050 1980.62 1721.62 37 28 2100 2019.80 1960.80 39 19 2150 2058.23 1999.23 40 11 2200 2096.52 2037.52 39 51 2:300 217:3.48 2114.48 :39 :31 2400 2250.88 2191.88 39 3 2500 2328.95 2269.95 38 17 2600 2408.01 2349.01 37 13 2700 2487.66 2428.66 37 11 2800 2567.25 2508.25 37 19 2900 2647.06 2588.06 36 46 3000 2727.16 2668.16 36 46 3100 2807.43 2748.43 36 26 3200 2887.96 2828.96 36 16, 3300 2968.71 2909.71 36, 1 3400 3049.54 2990.54 36 7 3500 3130.31 3071.31 36 7 3600 3211.55 3152.55 35 12 3700 3293.30 3234.30 35 7 3800 3374.91 3315.91 35 28 3900 3455.58 3396.58 36 56 4000 3535.17 3476.17 37 34 4100 3613.99 3554.99 38 22 4-~c~ 3692.10 '-'~'-"-' -- ~'-' ~.. o~o.:,.10 4300 3770.03 3711.03 38 43 4400 3848.10 3789.10 38 37 4500 3926.55 3867.55 38 1 4600 4005.37 3946.37 37 56 4700 4084.15 4025.15 38. 5 4800 4162.87 4103.87 38 3 COLIRSE DOG,LEG TOTAL DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEGREES BEG/lO0 NORTH/SOUTH EAST/WEST SECTION N 59.1 '.'-.'~ W 4.06 1:36.6:3 N 270.21 W q'?:~. '2'3 N 59.60 W .::. 75 202 48 N 296 '.-74 W ._._,.~ 26 'q'-' :39 , - N 59.60 W 1 72 ':'18 66 N :~.4,52 W 1 N ~':~._ .. .60 W O. 68 234 .94 N ~,~,.-':'='---'. 25 W 423.34 N 59.19 W 0.42 267.44 N 407.22 W 487.15 N 59. 0 W 0.49 ~..:.,,r~o.._ ..- .. 96 N 4/-,1 .~.=, W .-~='"'..,,,.,, 44 N 59. 0 W 0.76 '-'-"-' ... ~._-~.. 14 N 515.10 W 61'-~ 90 N ._.~ 7. ,:,'-'c~.-. W 1 . ..6'-' 364.16 N =._,67. ~:_~'- - W 674.11 N._75 :"::c) W 0 ":'/- 3'.96.56 N 618. '~'- ....._, ~., . .... .;,:~ W 7:34, 57 N 55.69 W 0.98 429.98 N 668.81 W 795.11 N F,= · _ ._,. 10 W 0.67 464 .1 '-?. N 718.41 W .:.~,.:,'-'~=. 32 ._,._ 10 W 0 00 498.44 N 7~7,~1 W '::"'1~ 14 · 54 :=:0 ='- N W 0 '-'=' .... . _ . ~"~,:~ . · _,:3,. 69N 816. ~:_¢ W 974.73 N 54.80 W 0.16 566.-'/' _. ~ N 864.78 W 103~ 95 N ._4._,.~ W 0 3! 600,~'~ N .~.l. 2.:B,~ W 1 "-'~' ............ (.) ~..'-.!~;~":'"' N ._4.1. W 0.20 ~,.,~.31 N gAO...7::: W 1151.68 N ~'::' =' '-' · _,0 W 0 41 670 (],z~ N 1008. o4 W 1210 52 ._ ..I. . i . ,. . N..,-.-.-='T'. 0 W 0.41 740.27 N 1100.57 W 1:326. .04 N 51.50 W 0.46 776.05 N 1145.95 W 1383.55 N 51. 0 W . !,~ ~1~,03 N 1192,02 W 1442,~0 N 50.30 W 0.76 851.42 N 1238.84 W 1502.43 N 52.39 W 1.52 889.84 N 1286.89 W 1563.63 N 53. 0 W ............ ~,~ ..... ~2Z.,67 N 13~6,~..W . 1~2~.86 N 52.69 W 0.25 965.52 N 1386.51 W 1688.33 N 52.60 W 0.11 1003.43 N 1436.18 W 1750.61 N ~'~ 10 W :: 0,6o 1040 88 N. "= . , '~ . 1~..,~1W 1.812 43 N 52.80 W 0.20 1077.96 N 1534.73 W 1873.80 N 53.10 W 0.23 1115.07 N 1583.89 W 1935.21 N 53.80 W 0,43 . 11~1.80 N .163~.43.N 1~6.74 ARCO ALASKA, _3-0-6 KUPARUK ALASKA I NC:. VERTICAL SECTION CALC:ULATED ALONG CLOSURE SPERRY-SUN WELL oLRVEYING COMPANY .................................... ~l~ ':~. ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1988 COMPUTATION DATE ............ BO~_..QYJ~Q~.'.OE'.IC~E.v._ AUGI_I'.--~T 5~ 1988 dOB NUMBER AK-BO-80080 KELLY BUSHING ELEV. = ~9.00 FT. ............. O~EB~IOR-MCGI-! [~ .... TRUE ._,UB-oEA COLIRSE MEASURED VERTICAL VERTICAL INCLINATION BERTH DEPTH DEPTH DEG MIN · LUR._,E DOG-LEG. DIRECTION SEVERITY DEGREES DEG/IO0 TOT~AL RECTANGLILAR COORD iNATE~ ....... VERTICAL NORTH/SOUTH EAST/WEST SECT I ON 4900 4241.54 4182.54 :38 11 5000 4319.96 4260.?6 38 30 5100 4398.09 4339.09 38 43 5200 4475.95 4416.95 38 59 5300 4553.46 4494.46 39 23 54£)0 4630.53 4571.53 39 46 5500 4707.02 4648.02 40 26 5600 4784.12 4725.12 38 38 5700 4862.69 4803.69 37 46 5800 4941.58 4882.58 38 3 5900 5020.10 4961.10 38 28 6000 5098.21 5039.21 38 47 6100 5176.00 5117.00 39 4 6200 5253.51 5194.51 39 17 6300 5332.09 5273.0? 37 7 6400 5412.14 5353.14 36 31 6500 54?2.46 5433.46 36 36 6600 5572.57 5513.57 36 54 6700 5652.34 5593.34 37 15 6800 5731.83 5672.83 37 27 6900 5811.14 5752.14 37 35 7000 58?0.52 5831.52 37 18 7100 5?70.05 5911.05 37 19 7200 604?.45 5990.45 37 33 7300 6128.87 6069.87 37 16 7400 6208.52 6149.52 37 7 7500 6288.43 6229.43 36 46 7600 6368.6? 6309.69 36 27 7700 644?.36 6390.36 35 7800 6530.49 6471.49 35 33 N .5:3.8A W 0.13 1188.26 N 1683.25 W 2058.36 '=':~ 69 W O. :33 1224 95 N 1733. '"- - . ..-:5 W 2120· '/8 N .=,,":' '":'( ..... -' ~ ':"-' 57 ,:, .) W 0. Z,-': 1261 '-' =' ,=,._, N 1783.62 W ' [ ~l~ I_1 I· . , N ?,'-' 69 W 0.27 1298 ~'= ""-' .=,, · _._-,. . . ~._, N 1834 '--"-.-"W . ~.~_ ..' ..' 4._. 1.9 N ='-' '--"--~ .... ._,.:,. :::n W O. 40 1.:._6 :~:'..' N 1'-''-'=' _ . . ,:,o._,. 17W '-"-' ' '-' · ...:,oo. 26 N .~":' :--,'9 W O.:.'-:'Fx 1373 90 N 1936 62 W 2.'_::71 '-': N .=['-' 69 0.68 '.-]5 ---. 24:36.15 · _,:,. W 1411. N 1'~:.-:~, 61W N 55..-=;¢)_. W .~.'--'. 1":'._, 1448.84 N 2040.4:--: W ~.'--'A9'~ .... 73 N ._,:,.='F 69 W 1 . 15 148:3. :34 N 2091 . ,_~'~" 1 W 2561 . 56 N ._,6 '-"::' '-''-"--' . c,.~W O. ~'::-' 1516 99 N 2143 '-"-' .,~._'~ W · . z6 .-' ._'~. 01 ~- ~ - ..~..:, - ,_-_, N 56.80 W O. 41 1 ._,._ o. 85 N 21 '- =. 0,:, W 2684.94 N 56 '-"-? 1._,o4 :.]9 N 2247 '-'=' o ~ W 0 '-"-' :'-' .... :,.., W 2747.36 · _-,...], , N .=, 0 2300 '}'-' '-"- · _7. W O. :'::0 1619.26 N . ¢.._ W ~.8 10.21 N .~S '-'""='-' ._7.10 W 0.22 165:'-:. 63 N ~:._',~,.:,. 04 W 287:3.3'.-] N 61 :--: 0 W 3 :.'~- 8 1 6,.~'- ..J =- . '- '--' '-"- '-': . ., . :-~.~ .N 240.6.12 W , -' ....... ~ ~..:~.., .1.~: N 62./-,9_. W 1 .04 171':-'..,. 47 N 245;..?.~.o')'-' W ..-.'-'9c~.~4 . 91 N 63. N 63. N 63. 6._-. OW O. N 63.10 W O. N 63.10 W O. N 63.19 W 0. N 63.39 W O, N 63. ~c . · .,.) W 0 N 6.:.. F:C) W O. N .64.1:-] W N 64.19 W 0. N 64.10 W 0. N 63.89 W 0. 0 W 0 '~¢' -~= o .~.~ 1740.65 N 3054 21 z._,1~.04 W . 0 W 0.30 1767.82 N ..~.~,:3~ W "' o1.1.~.,.76.. 0 W 0.35 1795.20 N 2619.09 W 3173.77 20 1822.75 N 2673.16 W :.~5.£. '-' '--' 14 1,:._,0, :35 N ~7~7, 45 W 28 1877.86 N 2781.68 W 06 1'-'= ~0._,.25 29 1959.73 24 1986.56 42 .2012,92. 47 2064.65 46 2090,27 N 2835.77 W N. ......... 26'?0. O? W N 2944.45 W N 2:]98.63 W 3234.15 32~4.76 3355.26 3415.58 ~476.05 3536.47 3596.57 N .......... ~0~2,66 W ~6~6.28 N 3106.37 W 3715.50 N 3159.55 W 3774.18 N . .8212.0~ W 3832.24 ARCO ALASKA, INC. 3-0-6 KUPARUK ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE SF'ERRY-SUN WELL :=;URVEYIN!D,.C:g,!MPAN¥ .............................................. PAGE ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2, 1.988 COMF'LITAT I ON DATE ..... BOSS. _GYROSCOPIC__ E~JBAZE¥ AUGUST 5, 1. o,=. dOB NUMBER AK-BO-80080 KELLY BLISHING ELEV. = 5'.~.00 FT. TRUE SUB-SEA COUR'.:;E COLIRSE DOG-LEG TOTt~iL ............... MEASURED VERT I CAE VERT I CAE I NC:L I NAT I ON D I RECT I FIN '._--;EVER I TY RECTANGULAR COORD I NATES VERT I CAL ',EPTH DEPTH DEPTH BEG M I N DEGREES DEG/100 NORTH/SOLITH EAST/WEST SECT I ON 7'-} (') (') 6./-. 12 00 ' ~ ~' '-' '-' c ..... ,._., 00 15 N 64. :' ] '-"-'~-" · _,L W 0 46 2115 4:3 N .24 W 388'.~.75 .~m ._ m~ · .... · · ..:,.~. C:Orm /_-, /-, '~:' :'::_ . _, :-:/_-, 66:34, :=-:6 :'::4 ._...5-> N 64,/-,'-.-,'_. W 0, 40 .~.'--'140, 12 N 3316, 13 W :3946,73 :::o~c) /:,7:34 9'0 /-,/-,7.~ '.~o :34 4LE: N /_-,4,:~,c) W 0 48 21 .... · - - - · - ,_,':'100 ,'!-_,775, 'F~/_-,6716, '26 34 4:;: N 64, :30 W o, 04 2164, 7.9 N 3367, ,'!'_,2 W 4003, 40 8172 /- '-'""'= =,,=,-=,._, ¢):=: 6776. C ,=, ._ 4 48 N 64 .;: · . ,'-1o= 61 N ..404, W 4044 16: HORIZONTAL DISF'LACEMENT = 4044.18 FEET AT NORTH 57 DEG. 20 MIN. WEST AT MD = 8172 THE CALCLILATION PROC:EDURES ARE BAS;ED ON THE L.:.E OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD, ARCO ALASKA, 3-0-6 KUPARUK ALASKA I NC:. SF'ERRY-SLIN WELL '.=;LIRVEY!NG C:OMp_A_N_Y_ ............................... ANCHFIRAGE ALASKA C:OMPLITATION DATE_. AUGUST 5, 198:3 ..... p_A_C_~_E ~ DATE OF SURVEY AUGUST 2, 1988 ........... :-ioB-NLiMBER-- ~i--Bo_ 8 0 0 8 0 KELLY BUSHINO ELEV. OPERATOR-MCGU I RE 59.00 FT. ., iINTERPOLATED VALLE.=, FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL *EASURED VERT I CAL VERT I C:AL RE_.TANUL LAR F:A~]RD I NATES MD-TVD VERT I C:AL dEPTH DEF'TH DEPTH NORTH/SOUTH EAST/WEST D I FFERENCE CORRECT I ON 0 0.00 ='- -.., ~. O0 0.00 0.00 0.00 1000 'F~99. ~8 940.98 5.61 N O. 61 E O. 02 O. 02 2000 1940 41 1881 41 171 45 N 244 71 W 59 ='- · ~,~. 57 :30¢~¢~_ ...... 2727.16 2/-.A~ 16 498 .44 N 767 .51 W 272 .84 ~1._'-' 4000 :~:~ 17 :3476 17 '-'= '-"-"~' o._, 1 42 N 1 ~.:,,=, '-' . ........ o4 W 464 ~.~ 191 .... =' ~' 43 - ':'°4 ':¢~ · _,Occ~ Iw. 96 4260 96 1~= N 17:33 iT,6' W 680 04 '-' ~ 1._,. 21 n n .. '-- I ~ i 6000 5 ¢) 9 :=: 21 =']'"':~ '~' c,.-, :35 · _,,..=.~.~1 1584 99 N ~01 79 . ....... ==47 W '-"-' ..... ~ 1 74 7000 ='-"~"' 52 =o.~, - .-, .-, ~,o .. s,. ._,~.o i. 5~ 1877.86 N ~7,=, 1.68 W 1109.48 207. . ....... ¢_~ AA:R4 o/. . . ......... Z140 12 N :3316 13 W 1306 14 1~6.66 8172 :R'-' = ':' '-"-' '-' ' 6~.:.._,. 08 6776. (x=:. _ ,. 1 o~. 61 N o404 · 65 W 1336, 92 30.78 ' 'n-' '-' I '-' OF £:URVATURE METHOD. THE CALCLILATION FRLL. EDUREo ARE BASED ON THE USE OF THREE DIMENSIONAL RAP IUo ARCO ALASKA 3-0-6 KUPARUK ALASKA ~EASLIRED dEPTH 0 159 259 359 459 559 659 759 859 959 1059 1159 1260 1362 1466 1570 1677 1788 I NC:. SF'ERRY-SUN WELL SURVEYING ANCHORAGE ALASKA COMF'UTATION BATE AUGUST 5, 19:_=.'8 DATE OF SURVEY AUGUST dOB NUMBER AK-B0-80080 KELLY BUSHING ELEV. = QPERATQB~Mr:G~ IRE., 1988 _ 59.00 FT. INTERPOLATED VALLIES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SLIB-SEA TOTAL VERT I CAL RECTANGLILAR COORD I NATES MD-TVD VERT I CAL DEPTH NORTH/SOLITH EAST/WEST DIFFERENCE ~:ORRECT ! ~l~ . O. 59. 159. 359. 459. 559. 659. 759. 859. 959. 1059. 1159. 1259. 1359. 1459. 1559. 1659. 175'9. O0 00 O0 O0 O0 O0 O0 O0 O0 00 O0 O0 00 O0 O0 O0 O0 O0 O0 -59. O0 0. O0 O. O0 O. O0 0.00 0.04 N 0.01 E 0.00 100.00 0.49 N 0.16 E 0.00 200.00 0.96 N 0.36 E 0.00 300.00 1.51 N 0.48 E 0.00 400.00 2.07 N 0.50 E 0.01 500.00 2.73 N 0.52 E 0.01 600.00 3.28 N 0.61 E 0.01 700.00 3.82 N 0.73 E 0.01 800.00 4.32 N 0.82 E 0.01 900.00 4.94 N 0.87 E 0,01 l 1000.00 7.4:2: N 0.58 W 0,06 1100.00 14.3::: N 6.30 W 0.4'~ 1200.00 25.24 N 16.90 W !.65 1300.00 38.30 N 32.58 W 3.74 1400. O0 53. ::-: 1 N 53.49 W 7.01 1500. O0 70.13 N 7'P,_~7,.....~, ...................... 1.1.~6~. ...................... .~,~,~6 ......... 1600.00 90.51 N 112.10 W 18.8.9 7.23 1700.00 114.78 N 151.47 W 2'B.10 10.21 O. O0 O. O0 0.00 0.00 O. O0 O. O0 0.00 O. O0 , O. 05 0.43 2.08 3.27 ARCO ALASKA 3-0-6 KUPARUK ALASKA 1EASURED OEF'TH 1.902 2022 2151 2281 2410 2538 2664 278.9 2.914 303.9 316,4 3287 3411 3535 3658 3780 3.904 4030 4157 I NC:. SPERRY-SUN WELL SURVEYING. _C~_C!~_F'.~N.__Y. ................................................................ E'L-'LQE ANCHORAAE ALASKA [lATE OF SURVEY AUGUST '.]', 1.988 COMPUTATION DATE AUGLIST 5, 1.988 '-lOB"NUMBER AI<-BO-80080 KELLY BUSHING ELEV. = . QPER_A..TQR_-_M_g:G~!.!_RE 5.9.0C~ FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERT I CAL DEPTH SLIB-SEA TOTAL VERTICAL RECTANGLILAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE · VERTICAL CORRECTION 185.9. O0 1.95.9, O0 205.9. O0 2159, O0 225.9. O0 235.9. O0 '245.9.00 255.9. O0 265.9.00 2759.00 285.9. O0 2'=.75.9.00 305'.-.?. O0 315'.=?. 00 '=' ".:'.~':,' 00 3359.00 345':.). 00 355.9. O0 365:.~ , 00 1800 00 143 72 N 19::: '- = ..... ~.-, W 43 19 A A 00 178 2'~? N '-' = /- '-~' '-"-' ...... ~.._,6.14 W :,o. 2000.00 218.9':). . N .:,'-"-'=.-.._,. 08 W 92. (}1 ...'---' 1 ¢'}. r).. 002/-,_ 1 . :2:2 N .5::.96 .9. A_ W 1:Z....' ..._,'-.' 2'.:'AA O0 2:0:5:: ":'.=, N 46,7. 1.9 W 151 46 2300 00 344 '='.S N M'-' ....· _,._ o._. 44 W 17.9.28 2400.00 384.82 N 600.03 W 205,02 ~._00.00 426.4.:2: N 663.62 W ~ .:, (.) .'-"-" 62 '-'= ':'~= '.~ 1 2/-,(')('} AO 4z-,9 '.='9 N 7..-._,. 73W . 2700.00 .=; '"' . _ · _ 1 ..:. c)/-, N 787.03 W 280.75 280 (:). 00 ~.~ . _ .... 4 /-.1 N :347.40 W 3:05.07 2.900.00 5.96.8'? N ?07. 14 W ._,':"='c~ .:~. 00 3()C)C} 00 63'.:."~."-'~.~' i',l ':.766.3:3 W :--:.'9'.~ 71 31 C)0.00 6:=:2.54 N 1025.17 W 376, 52 · -, 75 . .j._, :5:: 200.00 7 .-' ._. 42 N 10::31 =' = W :3.9.9.07 :33A0.00 768. '=.79 N 1137.07 W 421.4/-", :=:4A(3.00 '-' .... :,14· 64 N 11.94. :::.=,Ar~ 00 ':' - ':' ......... ~,~ ..... 1:3 N 1 ':,5", :'-:600.00 t~ ! 1 61 N 13'1 = 14.46 20.32 28.13 30.22 27.83 25.74 25.60 25.28 24.85 24.~2 23.~2 23.72 23.8! 22.55 22.3.9 ¥._, W 471.07 25.80 .,:..,.., W 4'28.48 27.41 ARCO ALASKA 3-0-6 KUPARUK ALASKA ~EASURED OEPTH 4'285 4413 4541 46.68 4795 4922 5049 5178 5307 5437 5567 56,95 5822 5949 6078 6207 6333, 6458' 6583 I NC:. SF'ERRY-SLIN WELL SURVEYING C:C!~F'IOLINY ANCHORAGE ALASKA COMPUTATION PATE ALI G I_l'.Z; T._-~,, 1 ¢~.. ~.,=,,:, o ............................. E'AGE 8 DATE OF SURVEY AUGUST 2, 1988 dOB NUMBER AK-BO-80080 KELLY BUSHING ELEV. = 59.00 FT. OF'ERA ~OR=MC:G~J IEeE jINTERPOLATED VALLEo FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERT I CAL RECTANGLILAR COF~RD I NATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I C:AL t::ORRECT ! ON :3759. 3859. 3959. 4059. 4159. 4259. 4359. 4459. 4559. 4659. 4759, 4859. 4959. 5059. 5159. 5259. 5359. 5459. 5559. 00 00 00 O0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 :=:700 00 9/-A 16 N 1:379 47 W 526 86. 3800.6)0 100:E:. 72 N 144:3.10 W 554. :~ .... 9 A (] .00. 1 A. 5_ 6_. 11 N 1 ._,,. ~'] ~._. 9. ri..W 5 A 2.19 4000.00 1103.24 N 1568.1'-'¢, W 609. 4100.00 11 H (') 01 N 1 A :::('). '~'-' .. ......... ~ W 6:36. 4200.00 1196.37 N 1694.33 W 663.22 4300.00 1243.35 N 17.58.34 W 670.91 4400.00 1290. ':"=' N 1 ':'2E' 4 ~ ...... 0 ('). 0 0 1 ::: ::: 9.0 C) N 1 ,:, '=',:,'-' o'-'. ,:,'-' ._, = W 7 4 8 .17 4600.00 1 .~,,:,7.86 N 1955.77 W 778.04 4700.00 1437.4/-._ N ~'-' F.) ~:'-'.:, '~ . 9. 2 W o,.'~'"),:,.'-' 84 4800.00 1481.77 N 2089.42 W 8:36.3:3 4900 00 1='-' = '~' '-~ · ._,~ 4.43 N ~'~ 1 ._, 4 .66 W c~6._, . 12 ~(3(')r) 00 1 79 N 567 .--~,--,(' o,-, ,-,oA ...... ~.). ..-o W o~-. 71 5100 C)0 1611.74 N '-' '~'-''-' . . ,:~o,:,.44 W 919 10 520C).00 i/',~A ...... 02 N ~ ..... ~,. 0 W ;~. ._1.:, .)(.) CJC) 16'~5 1 I N 5400.00 1729.37 N 550C). 00 1763.19 N '--"-' :38 . 28., 0'.:_,' 27.24 26,. 86. 27,04 27. 13 27 ~"' 28.28-: 28. '~'--' -'.. · 87 :'=:0, :~C) .......... :.-~._~ 27.56) 26.79 ..-_ J...'-J · ._'i ;Y 28.97 ~4zo 98 W 97~,7~ .~, '-' ~'¢ '~ ~Z ~4.57 ~4o~.8~ W 999.' .... 2556.28 W 1024.] t~ 24.71 ARCO ALASKA, 3-0-6 KUPARUK ALASKA I NC:. L=;F'ERRY-SLIN WELL :_=;URVEYI. NG C;0.MPANY_. ANF:HORAGE ALASKA C:OMPUTATION DATE · - C'.,, ,:., ,'", ALIGLIST F,, 1;,. .... DATE OF SLIRVEY AUGLIST.....";' 1~88 · · . I<ELLY BUSHING ELEV. =._,="-y. O0 FT. . PP_E_ R_A_T.C!_R_.!'I_C_:_O~_.~! l .R~E .......... INTERPOLATED VALLIES FOR EVEN 10~] FEET OF SUB-SEA DEPTH TRLIE ~EASLIRED VERT I C:AL ,JEF'TH DEPTH SLIB-SEA TOTAL VERT I CAL REL. TAN_,LILAR COORD I NATES MD-TVD DEPTH NURTH/.:,L LITH EAST/WEST DIFFERENCE VERT I CAL CORRECT ! ON 6708 5659. O0 6834 575S~. 00 6'.-.760 5859.00 7086 5959. O0 7212 605'.-.?. 7:--:37 6159.00 7463 6259.00 7._ o7 ,/_-,:'::57.'. 00' 771 I 6459.00 7835 /:,559.00 7957 6659.00 80 7'.-.-.' 675'.-.--'. O0 8172 /.:,835.08 5600.00 17'.~7 .50 N .,...'.::'/- '.')':'_,.,_._,. 60 W 1,U, 4. . :::/-._ _ 5700.00 1832 2o N 2/_-,91 71 W lo7._ ~: ~"'-'' (' '-' ' t'. ............ · _,,:,U ). 00 1 ,=,o L', ':Jo N 276('} 2/', W 1101 '"' ', 5'F~00 · 00 1901.45 N 26:26:. ';'5 W 1127 · 10 6 (:J 0 FJ ..... 00 1 '-:-~ .:,'-' .-,"' ·,-, '=' .-.=l N '.';' ::: 9,/-,. 66 W 11 ..;,._-, ~-'-' . 0._,' ~' 6100.00 1969. 'F/4, N 2.964.97 W 1178.87 6200.00 2003.._-,'-'~._, N 30:32. :-_46 W 1204.26 6:300.00 20 :--:.=; 7 t:, N ":: 0 ':¢ 9 c .-., - - -.. _ ............. ~.~. W 1Z'.-':---: 6400.00 '::.'067 ..... 7 .l N :31/-, ~ '-'=,._, ~' W 1252. 'y:z- '- /_-,5OF~.00 209'.-.-¢ 2'} I'.1 :=:230 ":":' W 1..7=.04 _ . . . - · ...,,_, "] _ . . ' . 1..'.. ,=,. 51 /-,600 00 '-.." 1 '2'~ '7, ~ ~ :32 i? 4 16 W '-"~'-' 6700. O0 '.T.:15'F/./-,:r; ._-,.:,._,7.00 W 1:320.3.:5 6776 · OR 2182 · ¢:, ' :3404 ¢: =' Y~. ..... =,._, W 133.:6. ,--T., 25.34 25.87 26. 13 25.74 25,95 25.82 25.39 24.70 23.96 23. 12 22.47 21.84 16.57 ]"HE CALCLILATION F'ROCEDLIRES USE A LINEAR INTERPOLATION BETWEEN PAD I _.=, i-iF L.i_IRVATL RE ) FO INTS I'HE NEAREST 20 FOOT MD (FROM ' ' il'- .... i' '- ARCO ALASKA~ INC. 3-0-6 KUPARUK ALASKA '.=:F'ERRY-SL~N WELL ~;:URVEY I NG COME:ANY .......................................... E:AGE .i_Q ANCHORAGE ALASKA DATE OF SURVEY AUGUST 2~ 1988 COMPUTATION DATE AUGUST 5, 1988 ,JOB NUMBER AK-BO-80080 KELLY BUSHING ELEV. = 59.0(] FT. 0 F'_E__R A_ T_O.F;-I)lr.~ !J I ~ ............. ~tEASURED ( ZIEPTH i i--, INTERPOLATED VALLE.=, FOR '.--;F'ECIAL SLIRVEY POINTS TRUE VERT I C:AL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR CI]ORD I NATES NORTH/'.=;OLITH EAST/WEST MARKER 7798 7822 7838 7962 8050 8063 8172 6528.86 6548.39 6561.41 6662.68 6734.90 6745.57 6835.08 6469.86 6489.39 6502.41 6603.68 6675.90 6686.57 6776.08 2089.76 N 2095.90 N 20~.99 N 2130.84 N 2152.42 N 2155.64 N 2182.61N 3211.04 W 3223.57 W '3231.~3 W 3296.49'W 3341.91W 3348.59 W 3404.65 W TOP KUPARUK r: " ' · '!1" BASE KUFAR_k. C TOP KUF'ARUK A BASE KUPARUK A · :,LIRVEY DEPTH. ....... PBTD TD ARCO ALASKA, INC~. 3-0-6 STRAT I GRAPH I C SUMMA_R.Y DERIVED USING DIL DEPTHS AND SPERRY SUN SC[ VE-¥-bA - ..... MARKER MEASURED DEF'TH TVD BKB BKB SUB-SEA TOP KUPARUK C 7798 6528.86 646:-}. 86 BASE KUPARUK C 7822 6548.3'P 648'~. 39 TOP KUPARUK A 7838 6561.41 6502.41 BASE KUPARUK A 7'P62 6662.68 6603.68 PBTD 8063 6745.57 6686.57 TD 8172 6:=:35.08 6776.08 ................ C:_CJp_RD_~ N_A T E S THICKNES'.3 WITH REF. TO WELLHEAD VERT I CAL ( OR I G I N- 832FNL 1.904FWL ) SEC 22 T13N RO'PE 208~.76N 3211.04W 20~5.~0N 3223.57W 20~.~N 3231.~3W 2130.84N 32~6.4~W 2155.64N 3348.5~W 2182.61N 3404.65W ..... 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMF'UTER F'ROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA CALCULATION AND INTERF'OLATION BY RA[IUS OF L. LIRVATLRE _ COMPUTATION DATE AUGUST = 1 '- '-"~' DATE OF .'_SU_SVEY A.L..!~U:~....,~, 1'~.88 ,_lOB NUMBER AK-BO-80080 · KEL.LY.._B_~_I~ING [LEV.. ~ . =.,-~ ] ~' .~, .~, ~ 0. F T. SPERRY -.SUN KUPARUK 3-0-6 SCALE INCH TO 500.00 / 500.0 ARCO ALASKA, INC. AUGUST 2, 1988 AK-BO-SO080 8172 1 -3500. CO l TRUE NORTH -2000. CO -1500.00 i -500. CO _,. !-! h .._J.'__ u_. i ;_ L_.,, SPERRY -,SUN SCRLE :- ! INCH TO 1500.00 / 1500.0 KUPRRUK ~8C0 9LRSKA, INC. 3 -8 -6 RUGUST 2. 1988 ~K-BO-80080 0.00 ~500.00 4500. C0 6000.00 \. ,, 'x~ 81 ?2 45 C{,.. CC VE8T!C,~L PROJECTION STATE OF ALASKA ALAb,,^ OIL AND GAS CONSERVATION COMMIS, REPOFIT OF SUNDRY WELL OPEFIATIONS t. -Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate ~ Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other % COHPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 832' FNL, 1904' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1258' FSL, 1307' FEL, Sec.16, T13N, R9E, UM At effective depth 1324' FSL, 1445' FEL, Sec.16, T13N, R9E, UM At total depth 1351' FSL, 1501' FEL, Sec.16, T13N, R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 59 ' Unit or Property name Kuparuk River Unit 8. Well number 30-6 9. Permit number/approval number 88-60/8-546 10. APl number 50-- 029-21824 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8172'MD 6835 ' TVD feet feet Plugs (measured) None Effective depth: measured 8063 'MD true vertical 6746 ' TVD Casing Length Size Structural Conductor 80 ' 16" Surface 4672 ' 9-5/8" Intermediate Production 8113 ' 7" Liner Perforation depth: measured 7898 ' -7918 ' MD true vertical · 6610 ' -6627 ' TVD Tubing (size, grade, and measured depth) feet feet J u nk (measured) Cemented 181 sx AS II 1650 sx AS III & 300 sx Class G 300 sx Class G & 175 sx AS I None Measured depth True vertical depth 115'MD 4707'MD 115'TVD 4090 ' TVD 8146'MD 6814 ' TVD p2-.7/8", J:~5, tbg w/tail ~ 7729' acKersand 5$SV(typeand measured depth) AVA 'RHS' pkr ~ 7657' & Otis 'FMX' SSSV ~ 1790' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A ,R_epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments \ Surveys rur~ Gyro Copies of Logs and Daily Report of Well Operations ~ , 16. Status of well classification as: Oil ~.. Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~ ~-~ Title Area Drillin, En, ineer , /- Form 10-404 Rev 06/15/88 (Dan i ) SW03/043 *NOTE: Completion Well History D ate.,/,¢9('~ .~¢_.. SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructioha: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I Field I Auth. or I 30-6 JWell no. Operator ~'"~"'~J Spudded or ~.~.~1~ Date and depth as of 8:00 a.m. TD: 8172 PB: 8063 SUPV: MDD Complete re~c~day reported IHour2045 HRS rAR~I~v~.O 0 0 0 Prior status if s W.O. The above Ri~ ~/~-7/~" ~ut,,wh '1"~ ~146' MW:IO.O NACL ACCEPT RIG @ 2045 HRS, 9/23/88. ND TREE. NU BOPE AND TEST SAME. PERF 7898'-7918'. RIH W/2-7/8" COMPL. DAILY: $26,383 CUM: $848,708 ETD: $848,708 EFC'. $1,295,000 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK2980 County or Parish NORTH SLOPE ADL: 25513 COMPLETE JAccounting cost center code St at~K 30-6 IWoll no. Operator ARCO APl: 50-029-21824 ~_R.Co. W.,. ~tal number of we',s (act,va or inact,ve) on th,1 56. 0000 lcost center prior to plugging and ab~do__nment of this well [~ur I Prior status if a W.O. 09/23/88 2045 HRS Complete record for each day reported NORDIC I Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. Old TD Released rig 09/25/88 ( 1( TD: 8172 ?B: 8063 SUPV:MDD Classifications (oil. gas, etc.) Producing method RIG RELEASED 7"@ 8146' MW:10.0 NACL FIN RUNNING 2-7/8" COMPL. SET PKR AND REL F/PBR. TEST TBG, ANN, AND SSSV - OK. SHEARED BALL. ND BOPE, NU TREE AND TEST - OK. DISPL WELL W/ DIESEL. RR @ 1800 HRS, 9/24/88. DAILY:S126,106 CUM:$974,814 ETD:S974,814 EFC:$1,295,000 NOTE: OTIS 'FMX' SSSV @ 1790', AVA 'RHS' PKR @ 7657', & TT @ 7729'. tNew TD ~.~ Depth Type completion (single, dual, etc.) reservoir name(s) Potential test data ~ Produc{ng Interval Oil or gas Production ~' no. }Date Pump size, SPM X length Choke size The above j.s/~rrect F~gfl ~nd distril)ution, ~ see Procedures M~10J~l, Section 10, Drilling, Pages 86 and 87. Water % GOR ITitle ~ Test time Gravity corrected Oil on test Allowable per day Effective date ARCO Alaska, Inc. Date: August 26, 1988 Transmittal #: 7276 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-06 Cement Bond Log 8-02-88 51 87-8052 3 O- 08 Cement Bond Log 8 - 01 - 8 8 3 0 85 - 7 6 4 8 3 O- 04 Cement Bond Log 8 - 0 3 - 8 8 6 9 8 0 - 8 8 6 6 30-07 Cement Bond Log 8-02-88 6457-8024 Receipt Acknowledged' DISTRIBUTION; NSK Drilling Chevron(+sepia) State of Alaska(+sepia) SAPC(+sepia) Unocal(+sepia) Mobil(+sepia) ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7223 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 1 1 OH LIS Tape and Listing 7 - 0 8 - 8 8 9 5 2 - 7 7 81 3 O- 1 0 OH LIS Tape and Listing 7 - 0 9 - 8 8 8 5 4 - 8 8 4 3' 3 O- 0 6 OH LIS Tape and Lising 7 - 1 2 - 8 8 4 8 0- 81 31.5 9 Receipt Acknowledged: ........................... Date: DISTRIBUTION: State of Alaska Lynn Goettinger STATE OF ALASKA ALASKA OIL AND GAS GONSERVATION COMM~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing {-2 Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing i-;, Amend order ~ Perforate r~ Other 2. Name of Operator ARCO Alaska, inc. 3. Address P· 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 832' FNL, 1904' FWL, Sec. 22, T13N, R9E, UN At top of productive interval 1320' FSL, 1342' FEL, Sec. 16, T13N, RgE, UN (approx) At effective depth . 1387' FSL, 1403' FEL, Sec. 16, T13N, RgE, UN (approx) At total depth 1415' FSL, 1460' FEL, Sec. 16, T13N, RgE UN (approx) 5. Datum elevation (DF or KB) RKB 59 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-6 8. Permit number 88-60 9. APl number 50-- 029-21 824 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4672 ' 8113' Production 8172'MD feet 6835'TVD feet 8063'MD feet 6745'TVD feet Plugs (measured) N o n e Junk (measured) None Size Cemented Measured depth 16" 181 sx AS II 115'MD 9-5/8" 1650 sx AS III 4707'MD & 300 sx Class G 7" 300 sx Class G 8146'MD ~ue Verticaldepth 115'TVD 4088'TVD 6814'TVD Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None None 12.Attachments WFI I I-I I STORY 13. Estimated date for commencing operation September, 1988 14. If proposal was verbally approved ,~ Name of approver ~:"-'"=~ Description summary of proposal [] Detailed operations program [] Date approved BOP sketch [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)/'Y~)~C, ~,~J~~,,_~ Title Associate Engineer Commission Use Only (SA3/001 8) Date ~-i2_.~ (Dani) Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 ~pproved Copy Returned --%ommissione~- by order of t.e oomm,.s,on 7- Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday afte! a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. ICounty, parish or borough , NORTH SLOPE Lease or Unit ADL: 25513 Title DRILL ISta~ KUPARUK RIVER UNIT 30-6 jwell no. Auth, or W.O. no, AK2980 API: 50-029-21824 JDate 06/18/88 IH°ur Operator ARCO Spudded or W,O, begun SPUD Date and depth as of 8:00 a.m. 06/18/88 ( TD: 115'( SUPV:SC 06/19/88 ( TD: 2496' ( 2 SUPV:SC 06/20/88 ( TD: 4725' ( 2 SUPV:SC 06/21/88 ( TD: 4725'( SUPV:SC 06/22/88 ( TD: 7750'( 3 SUPV:SC 06/23/88 ( TD: 8122'( SUPV:JPS 06/24/88 ( TD: 8172'( SUPV:JPS Complete record for each day reported DOYON 14 0600 HRS ARCO 56.0000 IPrior status if a W.O, 16"@ 115' MW: 9.0 VIS: 51 MOVE RIG TO 30-6. ACCEPT RIG @ 0030 6/18/88. NU DIVERTER. PU BHA. SPUD @ 0600 HRS 6/18/88. DAILY:S20,500 CUM:$20,500 ETD:S20,500 EFC:$1,295,000 ) 15) ) ~81) ~) !29) ) o) ) 25) ) 172) ,) 50) DRILLING 16"@ 115' MW: 9.0 VIS: 51 NAVIDRILL 12-1/4" HOLE TO 2496'. DAILY:S55,723 CUM:$76,223 ETD:S76,223 EFC:$1,295,000 SHORT TRIP 16"8 115' MW: 9.3 VIS: 56 NAVIDRILL 12-1/4" HOLE TO 4725'. CIRC. SHORT TRIP. DAILY:S55,723 CUM:$131,946 ETD:S131,946 EFC:$1,295,000 RIH TO DRILL OUT SHOE 9-5/8"@ 4707' MW: 9.4 VIS: 38 SHORT TRIP. CIRC. POOH. RUN 119 JTS OF 36#, J-55, BTC 9-5/8" CASING. FS @ 4707'. CEMENTED CASING WITH 1650 SX OF 12.0 PPG AS III LEAD, FOLLOWED BY 300 SX OF 15.8 PPG CLASS G TAIL. CIP @ 2045 HRS 6/20/88. NU BOPE AND TEST. SET WB. PU BHA AND RIH. DAILY:S221,361 CUM:$353,307 ETD:S353,307 EFC:$1,295,000 DRILLING 9-5/8"@ 4707' MW: 9.9 VIS: 36 DRILL OUT TO FC. TEST CASING. DRILL OUT FS. CHANGE MUD. TEST FORMATION TO 12.5 EMW. TURBODRILL 8-1/2" HOLE TO 7750'. DAILY:S74,869 CUM:$428,176 ETD:S428,176 EFC:$1,295,000 LOGGING W/SOS 9-5/8"@ 4707' MW:10.0 VIS: 40 TURBODRILL 8-1/2" HOLE TO 8122'. CIRC AND COND HOLE FOR LOGS. RU LOGGERS. RIH WITH OH LOGGING TOOLS. WORKED THROUGH TIGHT SPOT AT 6675'. WENT TO TD. LOGGED W/DIL/SFL/GR/SP, FDC/CNL/CAL. DAILY:S61,910 CUM:$490,086 ETD:S490,086 EFC:$1,295,000 PREP TO CEMENT 7" CSG 7"@ 8146' MW:10.1 VIS: 55 FINISH OH LOGGING. RAN SECOND PASS FDC/CNL/DIL/SFL. MU NEW BHA. DRILL 8-1/2" HOLE TO 8172'. CIRC AND COND HOLE FOR CASING. POOH LDDP. RU AND RIH WITH 7" CASING. CIRC. PREP TO CEMENT CASING. DAILY:S123,271 CUM:$613,357 ETD:S613,357 EFC:$1,295,000 The above is correct Signature ~edic~ sFe% f~;~C e~::lruerPe%r ~4'a°r~u aa ~, Drilling, Pages 86 and 87. IDate ITi,,e A88001ATE ENGINEER 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 submilted also when operations are suspended for an indefinite or appreciable length of time. Orr 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. Accounting cost center code District lCounty or Parish · State ARCO ALASKA INC. ~ NORTH SLOPE AK Field ILease or Unit IWoll no. KUPARUK RIVER UNIT ~ ADL: 25513 30-6 Aoth, or W,O. no. ITit{e AK2980 j DRILL Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a m, Old TD Released rig 06/25/88 ( TD: 8172 PB: SUPV:JPS Classifications (oil, gas, etc.) API: 50-029-21824 l A-R.Co. W,I. rrotal number of wells (active or inactive) on thisj Icost center prior to plugging and 56. 0000 Jabandonment of this well 06/18/88 ! 0600 HRS Complete record for each day reported DOYON 14 Producing method RELEASED RIG 9-5/8"@ 4707' MW: 0.0 CEMENTED 7" CASING W/300 SX CLASS G. BUMPED PLUG. NU TREE AND TESTED TO 3000 PSI. SECURED WELL AND RELEASED RIG @ 1400 HRS, 6/24/88. DAILY:S208,968 CUM:$822,325 ETD:S822,325 EFC:$1,295,000 tNew TD Date / PB Depth Kind of rig Type completion (single, dual, etC.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production O on test Ga~ pe'r da~ " Pump size, SPM X length Choke size T.P.' ' C.P, Water % GOR Gravity AII0wa61e Efiective date corrected ,, The above is correct Drilling, Pages 86 and 87. ASSOCIATE Lbcat~on, Ccner~l ~ Well S~Sn.~ · .~.CCU?:~'~.~TO~ Ccr, eral H~u~.~.cc~ing ~ Rig. ~ ~{ .... . ....... ~ .......... _ ..... :~cs~z'.e "": ~ ' ="" ....... ........ ."''"" .......... ~"'" I~ psi ~ud c'.'~'c;'S ~ V~s~a[ ~ ='.'.__, ' '-, ~:'.:::. Trip Tank ~ __. :ul, ~ ~?,¢~[' Cas Detectors ~ {~ ~ ~,emore ~ Blind8 svitcb cover ~' ~eilx- and Floor Sa. fety Valves ' ~/U, pper }:ell)'~'~esc Press~,re ___ . Lcd'er Keliy__~ . Pipe Rams_ . ......... ~_ Ball Type Blind Rams, :. ....... l , 1::~ ~:,P .... Chok~ Line Val~es___~ .. Choke ,-.ana~ , M.C.R. Valve_ ~ I~o. Vslves Kill Line Valves~ ~ , No. f!a~ges ~ . . Test ~esults: FatIures .... ~A~- res: Time ~hrs gepafr or Eeplacemant of failed e-"~p:.~nr ~o-¥~ m~d~ wig_bin days and Ir:spector/ · BOPE Stack Test Pressure An,~.uTar Preventer . _ _ .... 2~0 ....... ...... 30~ .... ........ ~o00 Check .j Co~nission office notified. D!st r/But/on ,~rtg. - AO,~;CCc cc - O;,erator cc - ~uTervtsor JUN 21 ],986 June 9, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin 'Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-6 ARCO Alaska, Inc, Permit No.. 88-60 Sur. Loc. 832'FNL, 1904'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. 1412'FSL, 1481'FEL, Sec. 16, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly 3/ours, C. V. Chattert~6n Chairman o f Alaska Oil and Gas Conservation Commission BY OFFER OF THE CO~iMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION ~ .)MMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory E3 Stratigraphic Test [3 Development Oil Re-Entry [] DeepenE]I Service [] Developement Gas [] Single Zone I~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field 3. Address 6. Property D,e;~kgnation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513~ ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 832'FNL,1904'FWL,Sec.22,T13N,R9E,UM Kuparuk River Unit Statewide At top of productive interval((~ target) 8. Well nu,mber Number 1320 ' FSL, 1342 ' FEL,Sec · 16,T13N, RgE, UM 30-6 #8088-26-27 At total depth 9. Approximate spud date Amount 1412'FSL,1481 ' FEL,Sec. 16,T13N,RgE,UM 06/18/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth (MD and TVD) property line DS 30-10 8119"/vlo 3376' ~ surface feet 165' @ surface feet ;~560 67~-,5'T¢~ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1 000 feet Maximum hole angle 390 Maximum surface 2402 psig At total depth (TVD) 31 66 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement ....... Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 115 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 4643 35 35 4678 4059' 1650 sx AS Ill & F-ERW 300 sx Class G 8-1/2" 7" 26.0# J-55 BTC 808."' 34 34 811~ ' 6745 100 sx 50/50 Poz Lea F-ERW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations..T, op of G 500 ' above Present well condition summary ~,uparuk Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~: -, ~ ~' ;,, · Surface Intermediate Production ,. Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch 1~ Drilling program '2(3 Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements "21. I hereby cer' hat the fore,~)n i/ g ' true and correct to the best of my knowledge ./ /~Z..~.,//~ ; Date Signed , ~, Title ~,~,,~,,,,,~ n,.~,,,, r~,.,~ Permit Number [ APl number [ Approval date See cover letter I 5o- O;~ -¢[8Z~,I 06 / 09 / 88 for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required ~ Yes ~' No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~ Yes E~ No Required working,,pr.~,~ure for BO~2~ ~ 3M; [] 5M; [] 10M; [] 15M Other: ~t~._.~/,7~~~ by order of Approved by Commissioner the commission Date .'~' ' Su b/~i triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing., Pressure test to 3500 psig. 11) DownsqueeZe Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up t° TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4--8~ 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10+ 4-7 9-12 Drilling F%uid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - ~luid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack Upon completion of the fluid disposal. LWK5 / ih 20" DIVERTER SCHEHATIC II II [~ESCRI PTION I. 16' C~TOR 2. FMC ~I. IP-~N ~ $?ARTIN~ HEAD 3. FMC DIVERTER AS~M~Y WITN 'PafO 2-I/1~' 200O PSI BALL VALVe' 4. 20' 2000 PSi DRRJ,I~ 10' HCR BALL VALVF.~ ~/10' DIVERTER LINFJ. A $1NOLE VALVE OPB~ AUTOIATICALLY I:~rtOTELY CONI'RIXLED TOAOIIEVE ~ DIVEI~ION. 6. 20' 2000 PSI ~ 4 AI~CO ALASKA, INC., ~OLE$1'S ~~ OF THIS DIVERTER SYSTEPI AS A VARIANCE FI~0H 20AAC25.035(b) r"IAINTENANCE & OPERATION 3 2 I I . . UPON INITIAL INSTALLATION. CLOSE PI~VENTEI~ VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLO~ AIR THROUGH DIVEI~TEI~ LINES EVERY 12 ~. CLOSE ANNULAI~ PREVENTER IN THE EVENT THAT INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPI~OPRIATE VALVE TO ACHIEVE D~~NO DIVERSION. DO, NOT SHUT IN WELL UNDER ANY CIRCUHSTANCES 7 6 AO~MJLATC~ ~,PAC1;TY TEST :1. (].E(]( ~ FILL ~TCR RESERVOIR TO PRC;~R LEVEL WITH ~IC R.UID, 2. ~ T~T ~~ ~ I~ ~~I ~TH I~ ~I ~T~ ~ T~ ~~T~. 3. ~~ TI~ T~ ~ ~ ~TS SIXThlY ~ ~TS ~ ~D ~TH ~I~ ~ ~. 4. ~~~ ~'~T. T~ ~~ L~ LI~T IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 ii 3 2 13-5/8' BCP STACK TEST I. FILL ~ STN:]( ~ (3-O~ I~NIF01.D WITH ~IC DIESEL. 2. Q-ECl( THAT ALL LOCK ~ ~ IN N~I.L~ ARE FULLY RETRACTED. SEAT TEST PLUG IN WE1.L~ WITH RI.N~IING JT Ahl) ~ IN L~ SC~I~G. 3. CLOSE ~ PREVE~ AN:) ~ KILL AN:) Q-O(E LIllE V/)I. VES ADJ~ TO BCP STAC~ ~ OTI-ER V~LVES AM) ~ SHtU. D BE ~ 4. PRESSLRE UP TO 250 PSI AM3 I~I.D FOR IO MIN. IN- CREASE PRESSLRE TO 3(300 PSI N~) H~LD FOR I0 MIN. I~_FED I=RE~LRE TO 0 I:~I. 5, CPEN ~ ~NTER AhD ~ KILL AN3 LIllE V/)I. VES. CLOSE TOP PIPE RN~ AhD ~ VALVES CN KILL N~) CHO(E LIhES. 6, TEST TO 250 PSI /e~ 5COO PSI AS IN 5'IEP 4. 7. CCNTI~L[ TESTI~ ALL VALVES, LI~S, ~ WITH A 250 PSI LOW N~ 3000 PSI HIGH, ~EST AS ~ 4. [~ I~i3T PI~'~ TF.C~T ANY Cl413(E THAT ~T/~ p, LL CLOSZNS PCSlTZVE SEN_ Q¢~. CN.Y FL,I~TZON TEST CI"ICI'r~ THAT ~ I~lJI FULLY T~T ~OTTO~ PIPE RN~ TO 2~ PSI N~D ~ I0, Q.O~ IN.]I~ ~ AI~ T~T TO 250 PS! AI~ ~ FLUID. SET ALI. YAI. VI~ IN i~LLII~ PO~ZTICN. I~. TEST STAI~]PE VALVE~ K~J. Yo KEllY ~ DR]U. RC0 '~ALASKA~r--]:ne. ed :30, ~e.l'.l' No, 6 Pr"opoeed upar~uk F:leld,i Nor.~h SI.,.ope, Alaska )00._ )OO. .... RI(B__ELE~AT. t ON_~ r~ ............................................................................................................. ~ ' i .... KO~L_T_I/Q-"_tOOQ:_TIID.-.J 000_. OEP-O' 3 BUILD 3 21- B/ PERMAFROST 27 33'-~i~C----T-VD;2193---THD'2289' DEp-419 )00.. T/ UGNU SI4DS TVD-2689 THD-2924 DEP-815 )00 T/ W SAK SNDS TVD=3459 THD=3gIO DEP=1432 K-12 TVD-3859 THD-4422 DEP-1752 -- 9 5/8" CSt~ PT-- TVD-4059 TMD-4678 DEP-1912 )00 ~ AVERAGE ANGLE 38 DEG 40 HI N )00 I00., 'K-5 TVD=5839 :TMD=6958 DEP=3336 E/ ZONE D: TVD-6389' TMDmZ663 / ZONE C TVDm6460 TMD-?Z54 DEP-3833 /" ZONE-- A'- TVDm6485 THD"??8$- DE AROET CNTR TVD-653T TMD-?852-DEP-$895 TV p/ KUP' SNDS D-6589 TMD-Zglg DEP-3936 ' 'm ~ i i ' m TD (LOG PT) TVD-6745' THD-8I 1 g DEP-40 1000. 2000 3000 4000 .................. VER~ICAL:.SECTION- .... : ...... i ........... , 5000 ' -.i~ 1000 _ 1000 _ 5000 HOR I ZONT AL .PROJECT I ON SCALE 1 IN. = 100~ FEET Proposed SI opeo Al WEST- 4000 3000 TAROET CENT~ TVD,.e$3r DEP-~ NORTH 2152 1,lEST 3246 ,EAST ~.000 000 ) 56 DEG 27 MI N ,895' (TO TARGET ,~ 000 G~fflFACE LOCATIOff' · ,~2' F~L..! I g04' FlA. SEC- 2~, TI311, ~ · ~ · 1800~: 1 850~ 1 900 _ 1 950'-: 2000 2050 2100: _.75~ _ 80C~ .. , . .- 850- 9O.Q;_.- 95Q._ _ .... 9O0- ooo -t I .- ---- 6oo. _ ~ oo( ..,, -- "" 2"9~'0'''2~'0027-00 , ~,~'51_ ..3~-o5- - -' ~'~ 5'o- 3-600 ! soo . X.& I . 1' 4800 I i / 4900 i 050_[ ................. ' _.. :. ................................. · J_80O_. I ........ 105[ ~ ~ , 'T~sO~'~oo I - t" I .... .: .. . . ~ . ~ s~oo 1,,,,,, \~oo-, .... '- -,=~l .1 I01 1 800 1 850 1 900 1 950 2000 2050 2100. , CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee ~ 6/6/~5 (2 thru 8) (8) (3) 6/6/8[? (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~~ ~-ff-f~ (14 thru 22) (23 thru 28) (6) OrI-IER ~ ~//~/~ (29 thru 31) Company /~Z/~C'~'~ Lease & Well No. ~'0-6 YES NO 1. Is the permit fee attached .......................................... ~_ REMARKS 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 fifteen-day wait ...................... Does operator have a bond in force .................................. J~_ Is.a conservation order needed ............ , ......................... ~ Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ ,, 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ......................................... Will surface casing protect fresh water zones ....................... 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 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 ............................ 23. 24. 25. 26. 27. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ,_~Oo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ............ - .................... ~ For exploratory and Stratigraphic wells: ////~ ~ 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... ;''''''~/~ted 31 If an offshore loc., are survey results of seabed conditions 32. Additional requirements ............................................. /,f~' o mz Geology: EngSngering: LCS BEW rev: 02/17/88 6.011 INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE //'9o/0o P(.:-U- l OIL.. f590-_, ltl6c_~ O~ Additional Remarks: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the roadability 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. .o LTS T &'P'E V'ER T_ FZC,~TIO.,g [ZSTZNG LISTING VD, OIO.H02 VE~I:tCATISN, . L!STI"G,,~ P~r-E~ :~ REEL HE~DER X-'~ ,ERVICE ~'-~A:qE :~DTT ~ATE :88/07/!2 IRZGIN : :EEL N~f.'.,S : 72R31 'ONTiNUATION ,~ :]1 'REViCUS REEL : ',OMMENTS :~DZT LZS~EC~ KUPa~UK ~ D-5~aPI ~ 50-02g-21~2~ :~ TAF5 HE~DER ;ERVIC'E N~ME :EDIT lATE : IRIGIN :7283 'APE NAM5 : 'ONTINUATIDN ~REVIDUS T~PS ~OMMEN'TS :EOIT LZS,A'RC'3 KU~ARUK 3 O-8,API ~ 50-029-21824 :* FiLE HEAD:R. ~-'~'~- :ILE N.~ME :EDIT ,OOl ;ERVICE N A'~. E ~ERSiON ~ : }ATE : ~AXIMUM LENGTH : 1024 "ILE TYPE : 'REVI~US FILE : -~* INFO~qATION R'SC~RgS $-I-' ~NEM CONTENTS UNIT TYP~ C~TE SIZE CODE: 'N : ~.RCO ALASKa, INC. 000 000 018 065 ~N : 3 O -6 000 000 008 065 =N : KUOARUK 000 000 008 065 ]ANG: 9E 000 000 002 065 ~OWN: 13N 000 000 003 065 ~ECT: 22 000 000 002 0~5 ]OUN: NORTH SLOPE 000 000 0t2 065 ~TAT: ALaSKa 000 000 008 065 2TRY: US~ 000 000 003 065 MNEN CONTSNTS UNIT 'TYPE CATE SIZE CODE VP OlO.H02 VE~I=IC~TI]N LISTING PAi3E 2 -~L4S~ CO~mUTI>tG CENTER OMP~NY = ~RCq ~L~SK~ ELL = 3 9-6 PI ~ = 5g-~29-21324 iEL~ = KUP:~RUK OUNTY = NORTH SLOPE ~OROUGH TATE = ~L~SK~ ASING YPE FLU~ ENSIT¥ ISCOSiTY H LUID LOSS = 9.525" @ 4?02'(LOGSED,) - BIT SIZE = ~.5" TO BllA'(LOGGER) = LSND = 9.9 L'~/G P,~ = 4.93 @ 53 OF = 36 S R~F = 5.48 ~ 58 OF : 9.5 RMC -= 3.11 ~ 58 OF = 5.0 C3 RM AT BHT = 1.965 ~ 156 DF iATRIX S~NOSTONE OMPUTING CENTER 1.)FILE ED[T.OO.,I CONTAINS DATA OF DUAL INDUCTION (.DIL)~ FORMATION DENSITY VP 01O.HOZ '~,.:.q!~ICflTI3N LIST!',~G P~.SE 3 (.FDC), CO~P~NStTE3 ~,;EUTqeN (.CHL), ~N9 'SA~M~ RAY THRU C&SING (.CSG) 2.)=ILE ~DIT,O02 C?NT~i~,~5 M! ~E5 ~QRM,~TI~N DENSITY (.FDM), C~MoENS~TEO ~EUTR~,~ (.CNM) ~>IPtE9 ~3 1.2" :I~LD RE~a~KS: 1.)~E 1.5" STaNDOfF AN~ Z' H3LE FIN~2~ US~ ON DU&L ZNDUCTZgN. M~TR~X 9ENSZTY 2.55 2.)C~,~L M~T2~X = S~N~STSN:, H~L~ CDRRECTIDN = C~L~P~R -,- .... THTS D&T~ HAS .NOT 3EEN .r)ZPTH SHI=T:D - OVCRL~YS FI~Lu PRINTS .,-.,- ..... SCHL!JM~ERGSR LOGS INCLUDED WITH TNIS MAGNETIC T;~PE: DU&L INDuC~rI'ON SPHERZC~LLY F3CUS-SD LOG (,DIL) 3~T~ ~V~!L~BL:_: 8'10:~' T3 ~702' =~'TION OENS!TY COMPSNS~TED LOG (.FDC) D~T& ~VIIL~.~LE: 8081' T~ 7486' COMP:z[S~'TEO. NEUTRON LOG (.CNL) .~,"- O~T~, AV~IL~3LE: 8065' T~ 7486' FORN~TION ~ENSIT~ CO~'PENS~*EO LOG H! R~ES !.2" V? OlO.H02 Vf~IFIC~TION LiSTiNG DATA FOqM~T NTRY 5L3CKS TYPE SIZE REPP C90E ENTRY Z I 65 0 4 I 66 I 9 4 65 .lin 16 I 66 1 0 ! 66 ,ATU~,. SPEC~F'C:TICN~ ~ 3LOCKS NEM S:RVIr=~.~ q=RVIrE.~_ ,.~ UNIT AP1 AP1 AP1 AP1 :ILE~ SI~~.._ SPL REPR I'D ORDER ~ LOG TYPf CL~SS JEPT FT 90 009 O0 0 0 FLU OIL OHMM O0 220 O1 0 LD OiL 9~M O0 120 45 0 O 4 LM OIL gH~ OC 120 ,44 0 ~P OIL MV O0 010 O1 0 0 4 ;R OIL GA~! O0 310 O! O O 'ENS ~IL LB OC 635 Z1 0 0 ;R F~C ~AP~ O0 BIO 'EMS FDC LB O0 6B5 ',ALI FCC IN OO 28:9 O1 0 O ',HOB FDC G/C3 O0 350 Q2 0 )RHO :FDC S/C, 3 O0 355 )PHI FDC ~U O0 ~90 gO 0 O 4 IFOC :;DC CPS OO 354 O! 0 0 :FDC FDC CPS O0 ~54 N R A ~,. N L 00 42 O 01 0 O 4 :TNR CML OO OOg O0 0 0 4 iP~I CNL Pg ~'0 890 O0 0 0 ~CNT CNL CPS O0 009 ~CFT CNL CPS O0 gO0 ;FTC CNL CPS O0 gO0 'NTC CNL CPS O0 OOg O0 0 0 rEMS CNL L'E O0 635 ~R CML ~I O0 ?!O ;R CSG GAOl go 310 O1 0 O PROCESS COOE (OCTAL) I 68 O00OO9000OO000 1 68 OOOOO900000000 I 68 00000000000000 1 58 00000000000009 1 68 O00OO00000000O 1 68 OOOOO00OO00000 1 58 O00OO00OOOOO00 1 68 OOOOOOO000000O 1 58 O00000000OOOOO 1 68 O0000OO00OO000 I 68 O000OO00000000 1 63 00000000000000 1 63 00000000090000 1 6B OOO0000OO00000 I 68 O0000OOOOOOgO0 1 '68 OOO00OOOO00000 1 68 O00000OO000000 1 68 00000000000000 1 58 OOO00000000000 1 68 O00000000OO000 1 68 O00000OO000000 I 68 00000000000000 ] 58 00000000000000 1 ,68 O00OO00OO00OO0 1 68 O0000OOOO00000 YP 010 H02 V=PlFIC~TIn~' _ . ~ . .... , L. TSTING ~G= = ENS CSS LE g0 5'3~ EPT 812-5. 5000 SFLU 5.,9972 ..- ...'- ~ . P -5.'144~ ~,, 95 8750 ENS 27!~.0000 C~,LI 9.40,63 PHi I 5. 49~3_ N='DC, 59~. 5000 TNR ~.6400 NPHI 42.4338 FTC 55 9. !2~2 CNTC ! 943. ~348 R -999.2500 T~N5 -999.2500 EPT 8109.9000 SFLU 4.9062 P -5.1289 GR 95.9750 ENS 5268.00~0 CALl 9.4063 PHI 15.4923 NFnC 592.5000 TNR 3.6&00 NgHI 42.433R ~TC 559.2242 CNTC 1943.4348 R -999.2500 ~ENS -999.!500 EPT 8900.00.90 SFLU 3..$416 P -10.11'72 GR 93.0625 ENS 5548.0000 C~L! 8.89.84 PHI 1 3. 8955 NFOC 559. 5000 TNR 3.3286. NPHI 39.7152 ,FTC 613.4520 CNTC 1968.7661 ,R '-999.2590 TENS -999.2500 ~EPT 7900.0000 SFLU 24.6708 ,P -30.4375 G~ 66. '5000 ENS 5124.0000 CALI 8.6719 ~PHI 18. 0270 ',!FgC 580. 5000 :TNR 2. 8763 NPHI 28. B'l !53 :FTC 91!.5166 CNTC 2531.3940 ;R -999 ~O0 TENS -09~ ,~c ......... . ,~ .... 00 ~EPT 7800.0000 SFLU 6.7346 ;P -!5.0859 G~ t00.1875 'ENS '~203.0090 CAL'I 9.1641 ~PHI 5.7328 N=OC 567.0000 ITNR 2.7204 NPHI 28.~596 ~TC 885.~065 CNTC 2~7T.40.48 ;R -999.2500 TENS -999.2500 tEPT 7700.0000 SFLU 2.3233 ;P -9.59'38 GR 124.7500 'ENS 5140.0000 CALl 9.2578 )PHI 16.6982 NF:9~C 565.5000 iTNR 3.45:5! NPHt 40.1592 ;FTC 521.0922 CNTC I'800.44S8 ;R -999.'2500 TENS -999.2500 I L J rE NS FF~C ~CNT TE qS 'TENS ~Hqe ~FOC 9CNT TeNS T E ~'~ S RHOB RCNT TENS ILO TENS FFOC RCNT TENS TENS RCNT TENS TENS FFOC RCN'T TENS 1 ,5~ O000OOOOOOO00O 4.5735 It;~ 2714.0000 GR 2.3945 DRHO ~35.5000 TNRA 1879.0964 RC~T 2714.0000 GR 4.4851 ILM 5268.0000 SR 2.3945 DPHG 535.5000 TNRA I~79.0964 RCFT 5263.0000 GP 3.0532 ILM 5548.3000 GR 2.4209 DRHO :¢88.0000 TNR~ 1903.2200 RCFT 5548.0000 GR 18.2783 ILM 512.4.0000 GP 2.3527 DRHO 573.0000 TNRA 2450.92,48 RC='T 5124.0000 GR 3.7622 ILM 5.208.0000 GR 2.5556 ORHO 389.0000 TNRA 2278.0581 RCFT 5208.0000 GR 1.7820 5!40.0090 GR 2.3746 DRHO 540.5090 'TNRa 1750.7241 RCFT 5.1.40.0000 GR 4.7091 95.~750 0.0077 3.5318 509.4097 95.8750 4.5898 95.8750 0.0077 3.5318 509.4087 95.8750 3.1726 93.0625 -0.0038 3.3420 569.7035 93.0625 15.2473 :66.50:00 -0.0065 2.6745 961.2600 66.5000 3.9582 1.00.1875 0.0386 2.7175 78.4.1488 100. 1875 1.8831 12~,. 7500 -0.0086 3.39 5.3 50~.51~6 2 .~+. 75 0 0 )EPT 7600.0000 SFLU 2.6552 ltd .!.. 6825 ILM '1.8225 VP 013.H02 VERi=iCATISN LISTING PaGE 6 P -'9.2422 GR ENS 5228.0000 CALl PHi !3.q437 NFDC TNR 3.6376 NPHI FTC 491.8923 CNTC R -'999 ZoO0 'T~NS EPT 7SOO.g000 S~LU ENS 4 ~8 ~. 0000 CaLl ~PHi 16.6298 NFOC TNR 3.4211 NPH~ ,FTC 523.0856 CNTC ,R -99~.2500 TENS ~EPT 7400.0000 SFLU P -15.0859 GR 'ENS -999. 2500 C,&LI ~PHI -?9 9.25 O0 NFgC iTNR -999.2500 NPHI ,FTC -999. 2500 CNTC ;R -999.2500 TENS iEPT 7309.0000 SFLU ;P -6.968'7 GR 'ENS -999.2500 CfiLI )PHI -999.2500 NFOC ~TNR -999.Z500 NPHI ;FTC -999.2500 CNTC ;R -999.2500 TENS )EPT 7200.0000 SFLU ;P -14.07B1 GR 'ENS -999.2500 C~LI )PHI -999.2500 NFOC ~TNR -999.2500 NPHI 'FTC -;999.2500 CNTC ;R -999.2500 ~ENS )EPT 7100.0000 SFLU ;P -'18.20B1 SR tENS -999.2500 CALI )PHI -999.2500 NFOC ~TNR -999o~500 NPH~ :FTC -999.25-00 CNTC ;R -999.2500 TENS )EPT 7000.0000 SFLU ~P -1Z.0469 GR tENS -999.2500 CAL! )PHI -999.2500 MFOC ~'TNR -999.2~00 NPH~ ;FTC -99~.2500 CNTC ~R -999.2500 TENS 11].8750 B.9062 604.0000 44.~45~ ~.729.92~7 -999.2~00 2.6843 121.1875 9.1797 5~6.5000 &2.0467 !789.0691 -99!).Z500 ~.4336 194.1250 -99~.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.63B6 ,239.6250 .-999.2500 -99'9.2500 -999.2500 -'999.2500 -999.2500 4. 5802 105. 0625 -999. 2500 -999.2500 -999. 2500 -9'99. 2500 -99'9. 2500 3.8841 124.0625 -999.,2B00 -999.2500 -'999.2500 -999.2500 -999.25~0 'r~ 9 '803 122.5000 -'999. 2500 -999.2.~ O0 -99'9.2500 -999. ~,. -999.2500 T E N'S qHi33 ~C TENS ILO TE NS =FDC RC NT TENS ILO T=NS ,_ RHO~ FFOC RCNT TENS ILO TENS FFDC RCNT 'TENS iLO TE NS RHSE FFOC q~CNT T E q S !LO TENS ~HO8 FFOC ~CNT TEMS IL~ TENS ~FgC RCNT TENS 52ZB.O000 GR 2.3441 ORHO $97.0000 TNPA 1716.7627 RC=T 522~.0000 GR 2.2707 458~.0000 GR 2.3757 ORHg 5~9.5000 TNR~ 1767.0024 RCFT 488~.9000 GR 3.6395 !LM 5132.0000 GR -999.2500 DRHO -999.Z500 TNRA -999.2500 RCFT -999.2500 GR 1.9675 ILM 4932.0000 GR -999.2500 DRHO -999.2500 TNRA -999.2500 RCFT -999.2500 ~R 3.4758 ILt4 4~64.0000 GR -999.2500 DRHO -999.2500 TNRA -999.25:00 RCFT -999.25~0 GR ~ 1329 ILM 4772.0000 GR -999.~500 DRHO -999.2500 TNRA -999.2500 RCFT -999.2500 GR 1.9378 iLM 4860.0000 GR -999.25'00 ORHO -999.2500 TN~A -999.25~0 RC=T -999.2500 GP 113.8750 0.0012 3.5846 I13.a750 2.3686 121.1875 -O.O00T 3.4920 491.5251 121.1875 3.7070 .-999.2500 -999.3500 -999.2500 -999.2500 2.0347 -999.2500 '-999.2500 -999.2500 -999.2500 -999.Z500 3.5555 -999.2500 -999.2500 -999.2500 -999,2500 ,-999.2500 3.2445 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 2.0840 -999.2500 -999.]500 -999.Z500 -99'9.2500 -999.2500 VP 010.H0~ V~I~TC~T'ON_ ~ LISTING, m~S~, . ? EPT 6909.0000 S=LU P -10.0675 ENS -999.2=::00 CALl PHI -999.2~OO TNR -999.2590 FTC -999, 2500 CNTC R -99~. 2500 EPT 6900.0000 SFLU P -24. :31 25 SR ENS -999.2~00 C~L! PHI -999,2~00 NFDC TNR -999,2500 NPMI FTC -a. 9 ). 2500 CNTC R -999.2590 TENS EPT 6700.0000 S~LU P -18.4531 ENS -999. 2500 PM! -999,2500 N~gC TNR -999,2590 NPH! FTC -999. 2500 CN'TC .R -999,2500 TENS ,EPT 6500.0030 SFLU .P -19.9531 GR ENS -999. 2500 C~LI tPHI -999,2500 NFOC ',TNR -999. 2590 N~Ht ;FTC -999.~500 CN'TC iR -999..2500 TENS ~EPT 6500.9000 SmLU ;P -18.7t~8 GP 'ENS -999.2500 C~LI ~PHI -999,2500 NFOC ~TNR -999,2500 NPHI ;FTC -999.2500 CNTC ;R -99~.2500 TENS JEPT 6400.0000 SFLU ;P -2B.70B1 GR 'ENS -999,2500 CALl )PHI -999,2500 NFDC ~TNR -999.2500 NPHI ;F'TC -999.2500 CNTC ;R -999,2500 TENS )EPT 6300.0000 SFLU ;P -25.17!.9 ~ ;ENS -999.2~00 CALl )PHI -999.2500 NFOC ~TNR -999,2500 NPHI 1!9,9125 -999.2500 -999.2900 -999,2500 -999.2~00 -999.2500 3,!593 13~.6250 -999,~500 -9qg,2500 -999,25n0 -999,2500 -999.2500 2.9833 113.3750 -999.2590 -999.2500 -999.2F00 -99'9.2500 -999,2500 2.6794 '109.~125 -999.2500 -999.2500 '999.2500 -999,~500 -999,2500 3.2559 112.5625 -999..2500 -999.2500 -'999.2500 -999,2500 -999.2500 2.8741 110.5625 -999.2500 -999.2500 -'999.2500 .-999.3~00 2.8598 !17,7500 '-999.2~00 -999.2500 -'999.2500 '!L'] T E ',l S · ~C TE NS TENS =FDC ~CNT TFNS TENS ~HOB FFOC 'qCNT TENS I t D TENS ~FgC RC N'T 'TENS TENS RH9~ ==DC ~CNT TENS TENS FFOC RCNT TE?~S ILO TENS FF'OC RC~T t.~327 ILM &724.0000 SR -999.2500 ORHO -999.2500 TNRA -999.Z500 RCFT -99'9.2500 3R 2.~15~ ZLM 4552.9000 SR -999.2500 DRHO -999.2500 TNRA -999.2500 RCFT -99~.2500 GR 2.&452 4520.0000 GR -999.2500 DRHO -999.2500 TNR~ -999.2500 RC~T -999.2500 gR Z.4598 ILM 4480.0000 SR -999.2500 DRHO -999.2500 TNRA -999.2500 RCFT -999.2500 GR 2.5025 ILM 4492.0000 GR -999.2500 ORHO -999.2500 TNRA -999.2590 RCFT -999.2500 GR 2.5713 ILM 4540.0000 GR -999.2500 ORHO -999.2500 'TNRA -999°2500 RC~T -999.2500 'GR 2.6861 ILM 444~.0000 GR -999.2500 9RHO -999.2500 TNRA -999.2500 RCFT I.~131 -999.2500 -999.!500 -999,2500 -999,2500 .-999,2500 2.9056 -999.2500 -999.2500 -999.2500 -999.!500 -999.2500 2.6247 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 2.5346 -999.2500 -399.2.500 -999.3500 -999.~500 -999,2500 2.5406 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6416 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7444 -999.2500 -999.2500 -999.2500 -999.2500 VP glO.H02 VEeIFIC~TiON LISTING PAGE FTC -:999.2500 CNTC R -999.2590 TENS EPT 6200.0000 SFLU P -25.9F91 ~P ENS -999.2500 CALI PHI -999.2590 NFDC TNR -99~.2500 NPHI FTC -999.2500 CNTC ,R -999.2500 TENS ,EPT 6100.0000 SFLU ip -30.1406 Gm 'EMS -~9q..,.~590 CALI )PHI -999.2500 N~9C :TN~ -99g.2500 NPHI 'FTC -399.2590 CNTC ;R -99q ~cO0 TENS IEPT 6000.0000 S~LU ;P -3!.1250 gR 'ENS -999.2500 C~LI )PHI -999.2590 NFOC [TNR -999.2500 ~PHI ~F'TC -999.2500 CNTC ;R -99q.2~00 TENS )EPT 5900.0000 SFLU ;P -32.1250 GR FENS -999.2500 CALl )PHI '-999. 2500 NFOC ~TNR -999.2500 NPHI ]FTC -999.2500 CNTC ;R -999. 2500 'TENS )EPT 5800.0000 SFLU ;P -29.1.562 :,gR FENS -999. 2500 C~L'! )PHI -999.2500 NFOC ~TNR -999.2500 NPHI ]FTC -993. 2500 CNTC ;R -999.2500 YENS )EPT 5700.0000 SFLU ;P -3 t. ~594 GR FENS -999.2500 C~L! ]PHI -999.2500 NFDC ~TNR -999. 2500 NPHI ]FTC -999.2500 CNTC ~R -999. 2500 'T~NS ]EPT 5500.0000 SFLU ~P -3'3. Z8:t, 3 gR tENS -999. 12500 CALI -999.2500 -999.2500 95.7500 -99~.2500 -993.2500 -99'9.2590 -~99. 2500 -999.2500 2.8137 107. ~! 25 -999. 2500 -999.2500 -999.2500 -999. 1500 - 99'9.25 O0 3.3516 11! .37.50 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 '2. 9096 1 ! B. ,4375 -999. ZSOO -999.2500 -999.2500 -999. 2500 -999. 2500 2.7753 111.1250 -999. 2500 -9'9'9.2500 · -999.25 O0 -999.2500 -999. 2500 2..7964 103.0000 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 9~.3750 '-999.2500 TENS !LD T=NS FF~C ~CNT TENS ILg TENS FFgC ~CNT 'TENS TENS RHO8 FFDC RCNT TENS TENS '=F DC qC NT T E ~,~ S TENS '~ F DC RCNT T ~ N S ILD TENS RHOB =FDC RCN'T TENS ILO TENS -999.2500 ~R 2.6964 ILM 4320.0000 GR -~99. 2500 ORHG -999. 2500 TNRA -999.2500 RCmT -999. !500 GR 2.5980 ILM 414~.0000 GR -999.2500 ORHO -999.2500 TNRA -999.2~00 RCFT -999.2500 GR 2.9267 ILM 4060.0000 GR -999.2500 DRHO -999.2590 TNRA -999.2500 RCFT -9'99.2500 GR 2.8143 ILM 4000.0000 GR -999.2500 DRHO -999.2500 TNRA -999.2500 RC=T -999,.2500 GR 2.5199 3960.0000 5R -999.2500 -999.2500 TNRA -999.2~,00 RCFT -999.2500 2:.6613 ILM 3884.0000 GR · -999,2500 9RHO -999.2500 TNRA -999.2500 RC~T -999.2500 GR 2.B908 ILM 3~90.0000 GR -999,2500 DRHO -999.2500 2.7651 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6581 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 2.9670 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 2.8523 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.5820 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6938 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 2.9201 -999.!500 -999.2500 VP O!O.HO2 YERI~IC~T!ON LISTING PHI -999.2500 N~OC -999.2500 TNR -999. ZFOO ~PHl -99o.2500 FTC -999. 2500 CNTC -999. 250~ R -999.£590 TENS -999.2500 EPT 55C9.g000 SFLU 3. 0945 P -34 ~ ~' 9~ .... ~2 SR ~. 56 2~, ENS -999.2590 C~LI -999.2~00 PHi -999.2500 NFgC -999.2500 TNR -999.2590 NPHI -999.2500 ,FTC -99~.2F00 CNTC -99?.2500 ,R -999.2590 TENS -999.2500 ~E~T 5~00.0000 SFLU 2.9255 ;P -37.62~0 gR 99.3000 'ENS -999.'2500 C&LI -999. 2590 IPHI -~99.2500 N~OC -999.2500 ',TNR -999. 2500 NPNI -999. ;FTC -999.2500 CNTC -999.~500 ;R -999.2500 TSNS -999.2500 iEPT 5300.0000 SFLU 3.1324 ;P -3~.8750 GR 104.7500 'ENS -999.2500 C,~LI -999.2500 )PHI -999.2590 NFOC -999.2500 ~TNR -999.2590 NPHI -999.~500 ~FTC -999. 2500 CNTC -999. 2590 ;R -999.2500 TENS -999.2500 )EPT 5200.0000 SFLU ;P -39,9062 GR 9~.6250 tENS -999. 2500 C~L~ -999. 2500 )PHI -999.2500 NFDC -999.2500 ~TNR -999. 2500 ~PHI -999.25 O0 ~F'TC -999.2BO0 CNTC -999. 2500 ;R -'999.2~00 TENS -999. 2500 )EPT 5IO0.OODO S~LU 3.5282 ~P -41.!250 GR 99. ~750 ~ENS -999.2500 C~LI -999.2~00 )PHi -999.2500 NFOC -999.2500 ~TNR -999. 2500 NPH~ -999.~500 ~FTC -999.25~0 CNTC -999.2500 ;R --999.2500 TENS -999.2500 )EPT 5900.0000 SFLU 2.;5584 ~P -~3. ~875 ;~ 9~. 5000 tENS -999.2500 CALI -ggg. 2500 )PHI -~9~. ~500 NFgC -999.2500 ~ T N R - g 9 ~. Z 5 O 0 ~'.,J P H I - 999..2500 ;FTC -999. 2500 CNTC -999. ;R -999.2500 TENS -999.2500 )EPT 4900.0000 SPt. L} 2. 3399 =FgC ;~C NT WENS TLr) TEHS RCNT TENS TENS RHgB ,~FgC ~CNT TENS TENS FFgC ~C~T T ~N S !LO TENS ~C~T T~NS ltd T~NS RHOB ~F~C RCNT T E N S ILO T ~ N S RHOB FFOC RCNT TE~S I t g -999.2500 TNR~ -999.Z500 RCFT -999.2500 2.9500 ItU 3?34.0000 -999.Z500 DRHO -999.2500 TNR~ -999.2500 RCFT -999.2500 ~R 2.7994 fL~ 3550.9000 GR -999.~590 DRHO -99'9.2500 TNRA -999.2500 RCFT -999,~500 GR 3.0544 It~ 3620.0000 GR -999.2500 gRHO -999.Z500 TNRA -999.2500 RC~T -999.Z500 2.616~ ItM 3544.9000 GR -999.2500 gRHO -999.2500 TNRA -999.2500 RC~T -999.2500 ~.0301 It~ 356.4.0000 -999.~500 ORHg -999.~500 TNR~ -999.2500 RCFT -999.2500 GR ~.06'79 ILM 3404.0000 GR · -999.2500 DRHD -~99.2500 TNR~ -999.2500 RC~'T -999.2500 2.?695 ILM -999.2500 -999.2500 -999.2500 Z.9811 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.9214 -999.~500 -999.Z500 -~99.2500 -999.~500 -999.2500 3.0638 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.$241 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 2.9869 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.1962 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.69'?9 VP OIO.H02 VERZFIC~T~ON LiSTTqG PAGE P -42.9B'75 GR 94.8750 TENS 3364.0000 GR ENS -999.2500 CALI -999.!500 PHSB -999.2500 DRMO PHI -999.2500 N~DC -999.2500 =FOC -999.2590 TNR~ TNR -99~.2500 NPHT -999.2500 RCNT -999.2500 RC:T FTC -999.2590 £NTC -999.2500 TE~!S -999.2500 GR R -999.2500 TENS -999.2500 EPT 4~00.0000 SFLU 3.089? 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'ENS -999.~500 C~LI -999. )PHi -999.2530 N~9C -99'9. ~TNR -999.2500 NPHI -999. 1500 ILS -999.2500 ILM -99).2500 2530 TE~!S -999.2500 GR -999.2500 2500 ~gB -~99.2500 ORHO -~99.2500 2500 =F~C -999.2590 TNR~ -999.2500 2~00 ~CNT -99~.1500 RCCT -999.2500 !500 tENS -)99.2500 GR -999.2500 gO00 '500 Itg -999-~590 TLM -9o9 2500 2500 TENS -999.2590 GR -999.2500 2500 RHg~ -999.2590 9RHO -999.2500 2500 :~gC -999.2500 TNRA --999.2500 1500 ~CNT -999.!500 RC~T -999.2500 2500 TEqS -999.2590 GR -999.2500 O000 2500 ILO -999.!500 ILM -999.2500 2500 TENS -999.2500 GR -999.2500 2500 RHO~ -999.2500 gRHO -999.2500 2500 FFOC -999.2500 TNRA -999.2500 2500 RCNT -999.2500 RCFT -999.2500 2500 TENS -999.2500 GR -999.2500 OOOO !500 ZL~ -999. 2500 ItM -999.2500 2500 TENS -999. !500 GR -999.2500 2500 RHg~ -999. 2500 DRHO -999. 12500 ~500 :FDC -99~. 2500 TNRA -999. 2500 ;~500 RCNT -999. ,2500 RCF:T -999. 2500 2500 TENS -999.2500 GR -999.2500 OOOO 2500 Itg -999.2500 It~ -999.2500 2500 'TENS -999.~500 GR -999.2500 2500 'RMOB -999.2500 DRHO -999.2500 2500 =FDC -999.2500 TNRA -999.2500 25'00 ~CNT -999.2500 RCFT -999..2500 2500 TENS -999.2500 GR -999.2500 O000 2500 ILO -999.2500 ILM -999.2500 2500 TENS -'999.2500 GR -999.2500 !500 RHO~ '-999.2500 DRHO -999.2500 2500 FFDC -99'9.2500 TNR4 -999.2500 2500 ~CNT -999.2500 RC~'T -999.2500 2500 'TENS -999.2500 gR -999.2500 O000 2500 IL!) -999.2500 ILM -999.2500 2500 TENS -99<9. 2500 GR -9:99. 2500 2500 RHO~ -999. 2500 ORHO -999. 2500 2500 FFOC -999.2500 'TNRA -999.2500 2500 ~C NT - 999.2500 RC~T -999. 2500 YP OIO.HOZ VEoT:ICATION L!.qTTNG m~SE 16 FTC -999.2500 CNTC -99'3 R 54.71'38 TENS 1265 EPT 900. 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