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Home My WebLink About197-229Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1972290 E-Set: 34326 12/07/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-01 50-029-20590-00 906681181 Kuparuk River Production Profile Field & Processed 26-Sep-20 0 1 2 1A-07 50-029-20658-00 906722930 Kuparuk River Leak Detect Log Field- Final 27-Sep-20 0 1 3 1A-07 50-029-20658-00 n/a Kuparuk River Leak Detect Log Field- Final 12-Sep-20 0 1 4 1A-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 11-Sep-20 0 1 5 1A-24 50-029-22984-00 906701351 Kuparuk River Multi Finger Caliper Field & Processed 10-Sep-20 0 1 6 1D-118 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 13-Sep-20 0 1 7 1D-118 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 14-Sep-20 0 1 8 1D-141A 50-029-22967-01 906685052 West Sak Packer Setting Record Field- Final 30-Sep-20 0 1 9 1H-116 50-029-23594-00 9067722868 Kuparuk River Injection Profile Field & Processed 21-Sep-20 0 1 10 1H-113 50-029-23588-00 906714570 Kuparuk River Injection Profile Field & Processed 19-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1972290 E-Set: 34325 12/07/2020 Abby Bell ! 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(* /2/C 155C1A %>" ",B",3:4 F"6",3:0,;4%(?. * 3:0,;(,8 !J( G& !J (4 ,8%&6" 6 *9 7!=/26 10 ! @ 1$(! . .! 2-7/8" 4049' 3830' MD/3610' TVD By Samantha Carlisle at 7:47 pm, Oct 26, 2020 RBDMS HEW 10/27/2020 Abandonment Date 10/10/2020 HEW xGDLB 10/27/2020 DSR-10/27/2020 70.4 SFD 12/22/20 107.4 VTL 5/5/21 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1635' 1609' Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Daily Operations Summary, Schematic, P&A Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: John Peirce Contact Email:john.w.peirce@conocophillips.com Authorized Contact Phone:(907) 265-6471 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: G.L. Alvord Alaska Drilling Manager Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment G. L. Alvord Digitally signed by G. L. Alvord Date: 2020.10.26 15:44:56 -08'00' Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 4,404.0 7/12/2019 1D-118 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: P&A Marker plate welded & Added CMT 10/22/2020 1D-118 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 52.4 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 52.4 Set Depth (ftKB) 4,574.1 Set Depth (TVD) … 4,315.6 Wt/Len (l… 29.70 Grade L-80 Top Thread ABM-BTC Casing Description GRAVEL PACK LINER OD (in) 5.1 ID (in) 4.00 Top (ftKB) 3,829.8 Set Depth (ftKB) 4,260.0 Set Depth (TVD) … 4,016.8 Wt/Len (l… 13.50 Grade L-80 Top Thread Seal Lock HT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 3,829.8 3,610.5 19.85 PACKER Baker SC-1 Gravel Pack Packer 4.000 3,840.7 3,620.7 19.82 SBR Baker Seal Bore Receptacle 3.250 3,845.9 3,625.6 19.80 SLEEVE Gravel Pack Sliding Sleeve 3.480 3,847.6 3,627.2 19.80 SBR Seal Bore 3.250 3,889.4 3,666.6 19.67 SCREEN 3 jts Bakerweld 140 Gravel PK screen 4.5"x30'x.020" gauge w/26' wrapped - FORMATION PERF'd 3/6/98 4.000 3,934.5 3,709.1 19.54 SBR Baker Seal Bore Receptacle 3.250 3,936.7 3,711.2 19.53 PACKER Baker SC-1L Special Isolation Packer 3.875 3,940.1 3,714.3 19.52 SBR Baker Seal Bore Receptacle 3.250 3,945.2 3,719.2 19.51 SLEEVE Gravel Pack Sliding Sleeve 3.480 3,946.9 3,720.8 19.50 SBR Seal Bore 3.250 3,949.5 3,723.2 19.49 PACKER Baker SC-1L Special Isolation Packer 3.930 3,958.7 3,731.9 19.47 SCREEN 3 jts Bakerweld 140 Gravel PK screen 4.5"x30'x.020" gauge w/26' wrapped - FORMATION PERF'd 3/6/98 4.000 4,039.0 3,807.7 19.22 SBR Baker Seal Bore Receptacle 3.250 4,041.2 3,809.8 19.21 PACKER Baker SC-1L Special Isolation Packer 3.875 4,044.6 3,812.9 19.20 SBR Baker Seal Bore Receptacle 3.250 4,049.8 3,817.8 19.19 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,051.5 3,819.4 19.18 SBR Seal Bore 3.250 4,063.2 3,830.5 19.15 SCREEN 3 jts Bakerweld 140 Gravel PK screen 4.5"x30'x.020" gauge w/26' wrapped - FORMATION PERF'd 3/6/98 4.000 4,113.5 3,878.0 18.99 Anchor Baker S-22 Anchor assembly 3.400 4,114.3 3,878.8 18.99 PACKER Baker SC-1L Special Isolation Packer 4.000 4,120.1 3,884.3 18.97 SBR Baker Seal Bore Receptacle 3.250 4,123.2 3,887.2 18.96 PACKER Baker SC-1L Special Isolation Packer 4.880 4,125.3 3,889.2 18.95 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,127.0 3,890.8 18.95 SBR Seal Bore 3.250 4,138.8 3,902.0 18.91 SCREEN 3 jts Bakerweld 140 Gravel PK screen 4.5"x30'x.020" gauge w/26' wrapped - FORMATION PERF'd 3/6/98 4.000 4,228.9 3,987.3 18.59 ANCHOR Baker S-22 Anchor assembly 3.930 4,230.0 3,988.3 18.58 PACKER Baker Model FB-1 Retainer Production Packer 3.250 Tubing Strings Tubing Description TUBING Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 52.4 Set Depth (ft… 3,827.6 Set Depth (TVD) (… 3,608.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Tubing Description LINER STRADDLE String Ma… 2 7/8 ID (in) 2.38 Top (ftKB) 3,826.2 Set Depth (ft… 4,049.4 Set Depth (TVD) (… 3,817.5 Wt (lb/ft) 6.50 Grade L-80 Top Connection Hydril 511 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 3,826.2 3,607.1 19.86 Fishing Neck 5" GS Scoop Head 3.000 3,829.2 3,609.9 19.85 ANCHOR Baker 80-40 Snap Latch 2.500 4,041.7 3,810.2 19.21 SEAL ASSY Baker 80-32 Seals Assmbly 2.438 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 52.3 52.3 0.00 Marker Plate Marker plate info 10/8/2020 0.000 2,639.0 2,521.1 24.93 Cement Retainer Cement retainer 9/2/2020 3,735.0 3,521.4 20.12 Cement Retainer Cement retainer 2/21/2020 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 1,892.0 1,896.0 1,842.7 1,846.4 9/14/2020 4.0 TBG PUNCH 2.0" OD X 4' TUBING PUNCH, 0° PHASE, LOW SIDE ORIENTATION 3,330.0 3,334.0 3,147.1 3,150.7 3/19/2020 4.0 TBG PUNCH 1.56" OD TUBING PUNCH, 4 SPF, 0° PHASE 3,898.0 3,932.0 3,674.7 3,706.7 WS D, 1D-118 3/6/1998 12.0 IPERF 4.5" SWS Ultra-Pack-TCP- 135/45 deg ph 3,964.0 4,034.0 3,736.9 3,802.9 WS B, WS A4, 1D-118 3/6/1998 12.0 IPERF 4.5" SWS Ultra-Pack-TCP- 135/45 deg ph 4,064.0 4,110.0 3,831.2 3,874.7 WS A3, 1D-118 3/6/1998 12.0 IPERF 4.5" SWS Ultra-Pack;TCP 135/45 deg phasing 1D-118, 10/22/2020 12:04:37 PM Vertical schematic (actual) PRODUCTION; 52.4-4,574.1 GRAVEL PACK LINER; 3,829.8- 4,260.0 IPERF; 4,140.0-4,229.0 IPERF; 4,064.0-4,110.0 CMT Sqz; 3,735.0 ftKB IPERF; 3,964.0-4,034.0 IPERF; 3,898.0-3,932.0 Fishing Neck; 3,826.2 GAS LIFT; 3,786.1 Cement Retainer; 3,735.0 CMT IA; 3,735.0 ftKB CMT Tubing; 3,735.0 ftKB TBG PUNCH; 3,330.0-3,334.0 CMT Tubing; 2,640.0 ftKB CMT IA; 2,640.0 ftKB Cement Retainer; 2,639.0 TBG PUNCH; 1,892.0-1,896.0 CONDUCTOR; 52.4-121.0 Marker Plate; 52.3 CMT Tubing; 52.4 ftKB CMT IA; 52.4 ftKB KUP PROD KB-Grd (ft) 47.90 Rig Release Date 12/22/1997 1D-118 ... TD Act Btm (ftKB) 4,595.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292283900 Wellbore Status PROD Max Angle & MD Incl (°) 25.31 MD (ftKB) 3,005.64 WELLNAME WELLBORE1D-118 Annotation Last WO: End Date 7/17/2000 H2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 4,140.0 4,229.0 3,903.1 3,987.4 WS A2, 1D-118 3/6/1998 12.0 IPERF 4.5" SWS Ultra-Pack-TCP- 135/45 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com 3,735.0 4,404.0 3,521.4 4,153.5 CMT IA 2/19/20-12bbls Class G Cmt Tubing & Sqz 3,735.0 4,404.0 3,521.4 4,153.5 CMT Sqz 2/19/20-12bbls Class G Cmt Tubing & Sqz 3,735.0 4,404.0 3,521.4 4,153.5 CMT Tubing 2/19/20-12bbls Class G Cmt Tubing & Sqz 2,640.0 3,735.0 2,522.0 3,521.4 CMT IA 9/2/20 – 58.8 bbls Class G to fill Tubing & IA 2,640.0 3,735.0 2,522.0 3,521.4 CMT Tubing 9/2/20 – 58.8 bbls Class G to fill Tubing & IA 52.4 2,640.0 52.4 2,522.0 CMT IA 9/25/20 – 96 BBLS PERMAFROST C CEMENT to fill Tubing & IA 52.4 2,640.0 52.4 2,522.0 CMT Tubing 9/25/20 – 96 BBLS PERMAFROST C CEMENT to fill Tubing & IA 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 3,786.1 3,569.4 CAMCO KBMM 1 GAS LIFT OPEN 0.000 0.0 4/1/2012 Notes: General & Safety End Date Annotation 10/8/2020 NOTE: AOGCC Witnessed Marker plate info and Weld > than 4' below original ground 5/16/2012 NOTE: Any future rig operations on 1D-118 will require submittal of a form 10-403 to the AOGCC. 4/13/2012 NOTE: WELL SUSPENDED 1D-118, 10/22/2020 12:04:37 PM Vertical schematic (actual) PRODUCTION; 52.4-4,574.1 GRAVEL PACK LINER; 3,829.8- 4,260.0 IPERF; 4,140.0-4,229.0 IPERF; 4,064.0-4,110.0 CMT Sqz; 3,735.0 ftKB IPERF; 3,964.0-4,034.0 IPERF; 3,898.0-3,932.0 Fishing Neck; 3,826.2 GAS LIFT; 3,786.1 Cement Retainer; 3,735.0 CMT IA; 3,735.0 ftKB CMT Tubing; 3,735.0 ftKB TBG PUNCH; 3,330.0-3,334.0 CMT Tubing; 2,640.0 ftKB CMT IA; 2,640.0 ftKB Cement Retainer; 2,639.0 TBG PUNCH; 1,892.0-1,896.0 CONDUCTOR; 52.4-121.0 Marker Plate; 52.3 CMT Tubing; 52.4 ftKB CMT IA; 52.4 ftKB KUP PROD 1D-118 ... WELLNAME WELLBORE1D-118 SUMMARYOPSJOBTYPDTTMSTART 3/19/2020 ABANDONMENT 3/19/2020 ABANDONMENT 9/2/2020 ABANDONMENT 9/12/2020 PUMPING TRACKING ONLY 9/13/2020 ABANDONMENT 9/14/2020 ABANDONMENT 9/25/2020 ABANDONMENT 9/28/2020 ABANDONMENT 10/2/2020 ABANDONMENT 10/6/2020 ABANDONMENT 10/7/2020 ABANDONMENT 10/8/2020 ABANDONMENT 10/9/2020 ABANDONMENT 10/10/2020 ABANDONMENT 1D-118 Plug and Abandon Summary of Operations TAG TOC AT 3365' RKB IN TUBING. LOG SCMT TO DETERMINE TOP OF CEMENT IN IA, DID NOT OBSERVE TOC IN IA FROM 3365' TO SURFACE. PUNCH TUBING FROM 3330' - 3334' WITH 1.56" PUNCHER LOADED 4 SPF, 0 DEG PHASING. CCL TO TOP SHOT = 6.6', CCL STOP DEPTH = 3323.4'. READY FOR LRS INJECTIVITY TEST. PUMP 20 BBLS DIESEL DOWN TUBING AND UP IA, MAX RATE 2 BPM, 675 PSI. Mob 2M to 1D-118, Spot unit, MIRU. M/U BHA #1 cement retainer. Trip in.Tag TOC @ 3365. PUH set cement retainer @ 2640'. Circ 100 BBls 9.6 brinebelow retainer up IA. Batch up and pump 56.8 BBls cement down tubing below retainer and up IA, Freeze protect tubing, RDMO. JOB IN PROGRESS MIT T TO 1500 PSI. (PASSED) DDT TO 0 PSI. (PASSED) MIT IA (PASSED) DDT IA (PASSED) DRIFT TBG & TAG CEMENT RETAINER @ 2638' RKB, PERFORMED CBL FROM 2638' RKB TO SURFACE, TOC IN IA @ ~1940' RKB. IN PROGRESS TUBING PUNCH FROM 1892' TO 1896' RKB W/ 2" x 4' (4 SPF) ZERO DEGREE PHASE TBG PUNCH. PERFORMED CIRCULATION TEST UP TO 2 BPM, T/I = 550/500 PSI, TOTAL OF 70 BBLS OF DIESEL PUMPED. READY FOR FINAL CEMENT PLUG. FLUSH WELL OUT WITH 290 HOT F/W AT 6 BPM, PUMP 96 BBLS PERMAFROST C CEMENT. WELL HAS CEMENT TO SURFACE TUBING AND I/A. (P&A) TUBING AND IA DDT PASSED, T TOC AT SURFACE (BETWEEN HORIZONTAL CASING VALVE AND WELL), IA TOC AT 8" BELOW CASING VALVE. (P&A) REMOVED DUAL SWABS AND ANNULAR VALVES FOR UPCOMING P&A (P&A) IN PROGRESS CUT/REMOVED 7' 5''OF WELLHEAD INSTALLED SHORING CAN. RETURN IN THE MORNING TO EXCAVATE INSIDE SHORING CAN. (P&A) IN PROGRESS/CUT AND REMOVED ADDITIONAL 7'4" OF CONDUCTOR.PREP STUB FOR MARKER PLATE WELDING (P&A) IN PROGRESS-AOGCC INSPECTOR AUSTIN MCLEOD VERIFIED MARKER PLATE INFORMATION AND TOC >4' BELOW ORIGINAL GROUND. WELDED MARKER PLATE TO WELL STUB. BEGAN BACKFILL OPERATION AND CAN INSPECTION. (P&A) Kakivik inspects shore can and noted few spots for repair. Welder made repairs and Kakivik reiinspected.VT/MT OK. Extract shore can in the morning weather permitting. P&A COMPLETED. Extracted 10'x16' shore can. Backfilled subsidence area created by extraction. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (� 10 f6 ,7,. DATE: 10/9/2020 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Kuparuk River Unit 1 D-118 West Sak Oil Pool CPAI - PTD 1972290; Sundry 320-093 10/8/2020: 1 traveled to CPAI's KRU 1 D-118 and met with Roger Mauser to inspect the well to verify all strings had been cemented to surface and the well was cut off at the proper depth. With the pad being "built up" approximately eight feet it was apparent it had been cut off well below the three foot below tundra grade requirement. Roger informed me it was approximately ten feet below tundra grade. I verified cement integrity with a hammer and bar. Outermost string had about a 3 -inch void of no cement which did not concern me. The quarter inch marker plate had all proper information bead welded to it and did not stick out past the outermost casing string. I found no issues with this inspection and informed him it was ok to weld the plate and backfill. Attachments: Photos (4) 2020-1008_Surface_Abandon_KRU_1D-I18_am.docx Pagel of 3 } mi w�0 y#j'r DSR-4/9/2020 VTL 4/10/20 50-029-22839-00-00 SFD SFD 4/10/2020 X NO MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2�j 3'23�Zctt� P.I. Supervisor l� FROM: Bob Noble Petroleum Inspector Section: 23 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Sid Ferguson Casing/Tubing Data (depths are MD): Conductor: 16" - O.D. Shoe@ Surface: n/a O.D. Shoe@ Intermediate: Wireline tag O.D. Shoe@ Production: 8" ' O.D. Shoe@ Liner: S' O.D. Shoe@ Tubing: 3.5' O.D. Tail@ Plugging Data: Test Data: DATE: February 21, 2020 SUBJECT: Well Bore Plug & Abandonment KRU 1D-118 ConocoPhilips Alaska PTD 1972290; Sundry 319-101 11N Range: 10E Meridian: Umiat ' Verified n/a "Total Depth: 4595 It MD - Lease No.: ADL 25650 ' Wireline tag Suspend: P&A: X Casing Removal: 121 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet Feet Csg Cut@ Feet 4574 - Feet Csg Cut@ Feet 4260 Feet Csg Cut@ Feet 4049 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing • Retainer 3735 ft MD 3380 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 1675 1655 1640 1630 IA 370 365 365 360 P OA Initial 15 min 3n min A.q min Recidt Tubing 170 - 200 - 210 - IA 1675 1575 1550 P OA Remarks: Bottom plug on mono bore well. A 2 -inch bailer was used to tag cement. The cement sample had 3 or 4, V -sized hard chuncks of cement. The rest of the sample was semi -dry contaminated cement that had cement color and smell. Photo of bailer contents attached. Tubing and IA pressure tests passed. Attachments: Photo (1) ✓ rev. 11-28-18 2020-0221_Plug_Verification_KRU_1 D-118_bn m m n. O w O U f6 3 (A O N O Z N O m � 6 0 0 C U V w � L d � 4! a: U U COO)o N < p � TN O O) -0O r r = Q O f � F- r Y Q- d N _U IL THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-118 Permit to Drill Number: 197-229 Sundry Number: 320-093 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alasko.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, -P- e Price Chair �j DATED this J day of March, 2020. AMMS MAR 0 4 2020 RECEIVE® STATE OF ALASKA FEB 2 7 20J70 ALASKA OIL AND GAS CONSERVATION COMMISSION Q7-3 3/ 3 2 D APPLICATION FOR SUNDRY APPROVALS AOGCC Lu 1111-- ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdownC] 1. Type of Request: Abandon Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Suspend ❑ ❑ Perforate New Pool ❑ Re-enter Soap Well ❑ Alter Casing ❑ Other. ❑ Plug for Reddll 4. Current Well Class: 5. Permit to Drill Number: 2. Operator Name: 121197-229 Exploratory 11 Development ConocsPhilli s Alaska Inc. Exploratory API Number: 3. Address: Stratigrephic El Service El 50-029-22839-00-00 P. O. Box 100360, Anchorage, Alaska 99510 8. Well Name and Number: 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU ID -118 . Will planned perforatons require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 1o. Field/Pool(s): Kuparuk River Field /West Sak Oil Pool ADL 25650 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD). Junk (MD): ' 4,335' 3735 3521 1500PSI 3735 NONE 4,595' Burst Collapse Size MD ND Casing Length Conductor 80' 16" 121 121 Production 4,533' 75/8 4,574' 4,316' Liner 430' S" 4,260' 4,017' Tubing MD (ft): Pertoretion Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: L-80 4 049, NIA N/A 3.500" Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): N/A N/A 12. Attachments: Proposal Summary El Wellbore schematic 0 13. Well Class after proposed work: ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑+ Service ❑ Detailed Operations Program 14. Estimated Date for 311212020 15. Well Status atter proposed work: • OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ Commencing Operations: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Date: 16. Verbal Approval: ❑ Op Shutdown ❑ Abandoned 21 Commission Representative: GINJ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. John Peirce Contact Name: John Peirce Authorized Name: Contact Email: John.W.Peirce@cop.com Authorized Tide: Sr. Wells Engineer Contact Phone: (907) 265-6471 — Date: 21Z717—'?- 12712'2COMMISSION Authorized Signature: W COMMISSIONUSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O ,. / Plug Integrity Lvl BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other. � 01D C`U C t' re -it S vY � u L C Cc rJ A n Post Initial Injection MIT Req'd? Yes ❑ No of �BQIVISI MAk 0 4 2020 ¢D Spacing Exception Required? Yes No d Subsequent Form Required: �D _1 APPROVED BY`j —5V COMMISSIONER THE COMMISSION Date ,f+ Approved by TL 3/312 0 /%�� RNt�t z 'tit Form and Form 10-003 Revised 4/2017 Approved applica n s a d NAL he date of approval. Attachments in ouplkate wci i NAME 1D-118 WELLBORE 1D-118 KUP PROD WELLNAME 1D-118 WELLBORE 1D-118 ConocoPMaslips alRka, Inc. 10.t1a.iR>/ii9AN.APM CenrErt SQ2keeme VT leabM@(aadal) Top ITV01 etm [Nvl INKBi atm INN91 IRNaI INHBi 3,]35.0 4,406.0 3,521.4 4,1535 Oes SUIt Ga@ com Cement Plug 22112020 Cement below CEMENT RETAINER --------.-------.-""""" Top Mandrel Inserts X NGER: X9 41 on Tep MD) Valve LahM1 Type PO4 TRO Run 4p IPsil Run Gab Cam N Tep lNBa) IRKa) Mage MaGel OG lini Sary Type . 1 3,]96.1 3,569.4 CAMCO KBMM 1 GAS LIFT OPEN 0.000 00 dfi201 Not General & Safely Etre mh Annobaon 7C�MTOR:��10,0 ng on lD-118 will require submitral Dfaform l0 -0031D the AOGCC. npd613OMta 916/2012 NOTE'.Any (uwre DDeralivns NOTE: WELL SUSPENDED u°;>Tss°^K° 6/1M2012 cEMEM RETPINER:ATSG 6192010 NTE: View Schematic w/Alaska SchemaAc9. GM LIFT; 3,T%1 F.NcK 3..2 ANCHOR: 3.M2 (PERF: 3.fl90.W.532D� IPERF 3,581 M,W40� 3EUPssr; 4,w1.> (PERF: 4.M001.11D0�� IPERF; 0.1.".3ffi0�� GRAWLPACKLINER:3.M,6 4.23on PRODUCTION; p74,W4,1 �� ID -118 Plug & Abandon to Surface Proposal It is proposed that 1D-118 be plugged and abandoned with cement from the perforation intervals between 3898 -4229' RKB to surface in the kill string and production casing. Well History Review: 1D-118 was drilled in Dec 1997 and completed in March 1998. During the frac-pack completion, the inner wash was stuck and parted. Nordic 2 recovered all but 30' of the fish which was left across the SC -1L packer at 4041' MD. In 2000, Nordic 3 recovered all of the remaining fish. A seal bore assembly and latch were run to isolate the B & D sands, and an ESPCP completion was run to return 1D-118 to production until the pump eventually failed to restart after a proration. In March 2012, Nordic 3 moved onto 1D-118 to recomplete the well. The 3.5" ESPCP completion was pulled, then casing swaging in 7-5/8" production casing detected casing damage at ^'385' while running a - 6.75" drift that would not pass -385'. Recompletion work plans were then cancelled. The rig set a 3-3/8" IBP at 3800' in 7-5/8" casing then performed an MIT to 1500 psi that passed. A Caliper and Gyro were run in 7-5/8" casing, and then an Eline CAST log found TOC behind 7-5/8" at "'470' RKB. The IBP was then pulled and a 3.5" kill string was installed with an open pocket GLM at 3786' just above kill string tubing tail at 3827' RKB. A WRP was then set at 3900' RKB, and a CMIT was performed to 1550 psi that passed before Nordic 3 moved off well. A Catcher Sub was left on top of the WRP which remains set in the well. An AOGCC 10-404 of 4/30/12 reported 1D-118 as'Suspended'. No further utility exists for 1D-118. A Plug and Abandonment began on 7/12/19 (per the procedure below) to cement the well to surface. The wellhead will be removed, and an ID plate will be welded onto the casing, then 1D-118 will be buried. Note: Steps 1 - 29 below were completed during 7112119 - 2124/20 and were reported on a 10-404 Sundry sent to AOGCC 2127120, since approval #319-101 for P&A to Surface is set to expire on 3/1912020. The new 10-403 attached is submitted per AOGCC request to obtain a new approval # before resuming work to complete the P&A work per steps 30 - 97 (below). 1D-118 Proposed P & A Procedure: Steps I through 29 have been completed, so are shown grayed out. Slickline: Obiectives: CMIT, pull WRP, tag PBTD, SBHPS, B&F, SRIT, & drift dummy Cement Retainer 1. Complete Pre -job Safety meeting. RU SL. PT lubricator and surface lines as required. 2. CMIT to 2000 psi via open pocket GLM at 3786' RKB. Record initial, 15, 30 min T/I/O psi. 3. Pull 2.28" Catcher Sub at "'3900' RKB, and then pull the 2.25" WRP set at 3900' RKB. 4. RIH with sample bailer to tag PBTD. 5. RIH with pressure / temperature gauges to obtain 30 min SIBHP and BHT at 4185' RKB or just above PBTD tag depth (attained in step 4). Perform 15 min gradient check 100' TVD up hole. 6. Brush & Flush 3.5" Tbg at 3715 - 3775' RKB for Cement Retainer set at 3735' RKB on CT (step 13). 7. Perform fullbore Diesel Step Rate injectivity Test (SRIT). Pump Diesel down tubing to verify ability to pump cement to gravel pack liner across perfs from PBTD to planned Cement Retainer set depth in tubing at 3735' RKB. Record SRIT results for 2 or 3 stable rates with WHIP's below 1000 psi max (to stay below Frac pressure). Nordic 3 reported 207 bbls of fluid lost to formation during 2012 RWO. Thus, the formation is expected to take fluid. 8. RIH with 2.75" OD x 10' OAL Dummy Cement Retainer BHA, down to 3735' RKB (middle of a full tubing joint). 9. RD SL & MOL. Coiled Tubing - Cement Plug #1: Objective: Place Cement Plug across all open perforations and squeeze some cement into the perfs, if possible. 2.992" ID Tubing =0.0087 bbl/ft 4.000" ID -average ID of Gravel Pack Liner 6.750" ID Csg x 3.5" OD Tbg (IA) volumes to fill with Cement Plua #1: In 3.5" Tbg above Cement Retainer In 3.5" Tbg below Cement Retainer In -4" ID Gravel Pack Liner from TD to SC -1 Pkr In 6.750" ID Csg x 3.5" OD Tbg Total Cement = 0.0155 bbl/ft = 0.0324 bbl/ft _ (3735 - 3677')(0.0087) = 0.5 bbl _ (3830 - 3735')(0.0087) = 0.9 bbl _ (4595 - 3830')(0.0155) = 11.9 bbl _ (3830 - 3623')(0.0324) = 6.7 bbl = 20.0 bbl 15.8 ppg Class 'G' 10. Schedule pilot testing of P&A cement design. Cement job requires 20 bb Is of pumpable 15.8# Class G Cement. 11. Schedule millable Cement Retainer and Stinger kit for Cement job. 12. MIRU CTU & Cement Van. Conduct PJSM. Inspect wellhead and location for any pre-existing conditions. Mitigate hazards. Establish site control. Mitigate personnel exposure for PT, then PT equipment. Do not mix Cement until requested (in step 16). 13. RIH with Cement Retainer and set it in 3.5" tubing at 3735' RKB targeting the middle of a full joint above open pocket GLM at 3786' RKB. This location is safe distance above open pocket GLM so the Retainer will be set above the GLM without need for depth control. 14. After Cement Retainer has been set, POOH with CT to swap to Stinger BHA. RBIH with CT x Tbg annulus open to tanks. When Stinger is within 100' of Cement Retainer, halt RIH to circulate Diesel until liquid returns are seen to tanks indicating tubing above the Retainer is fully `liquid packed' to surface. RIH & sting into Retainer. Stack weight on Retainer per vendor Rep. 15. Pump Diesel through Retainer with CT x Tbg open to tanks and IA closed to verify good sting integrity into Retainer. No returns from CT x Tbg should be observed to tanks. If Tbg x CT returns are seen to tanks, then faulty sting integrity into Retainer must be corrected before pumping a cement job. Pump Diesel 0.5 bpm until good sting integrity is verified. This pumping should also verify adequate injectivity exists through Retainer to Gravel Pacl< Screens and perf intervals to enable cement placement to fill GP Liner. Injectivity test results in step 7 should look similar to injectivity test results being observed here. 16. Strive to pump 0.5 bpm below Frac Pressure (1000 psi max WHIP), but if we need to go above Frac pressure to achieve 0.5 bpm, then Frac for short duration during cement pumping thru Retainer to get cement down Gravel Pack Liner ("'12 bbls Cement thru Retainer) and to squeeze a small volume of cement to perfs before opening IA to tanks to divert remaining cement ("7.5 bbls) to fill IA. 17. Make a final verification of good sting integrity into Retainer, and verification of ability to pump at 0.5 bpm thru Retainer before proceeding to step 18. 18. Pump 1 CT volume ("'50 bbls) Lead Freshwater Spacer down CT at 0.5 bpm to displace Diesel from CT to formation (takes 100 minutes). Mix up 20 bbls of pumpable 15.8 ppg Cl G Cement while pumping away Freshwater. 19. Pump 20 bbis 15.8 ppg Class G Cement at 0.5 bpm. 20. Pump 10 bbis of Tail Freshwater Spacer at 0.5 bpm. 21. Pump XX bbls Diesel displacement at 0.5 bpm. Calculate Diesel displacement volume needed, which depends on actual CT volume. Note the CT volume and calculate when IA needs to be opened to tanks to enable diverting cement placement to IA. After 12.8 bbls cement has passed thru Retainer, open IA to tanks and pump remaining cement down CT to stack cement into IA. When 19.5 bbis cement has passed the Retainer, PU CT off of Retainer. Calculate Diesel displacement volume needed to get 19.5 bbls of Cement displaced thru the Retainer, which depends on actual CTvolume, and then PU CT off the Retainer to resume pumping the last 0.5 bbl Cement on top of Retainer, followed by continued Diesel pumping to replace voidage while CT POOH. Diesel FP from 2065' RKB; 2000' TVD to surface (18 bbls). RD CTU. Wait on cement at least 48 hours. Slickline J Pumping Obiectives: Tag Cement Plug #1 TOC, and perform AOGCC Witnessed MIT -T & MIT -IA, DDT -T, DDT -IA - 22. Notify AOGCC Inspector of timing of Cement Plug #1 tag and pressure testing. 23. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 24. RU SL. PT equipment as required. 25. RIH with Bailer to tag TOC in tubing at -3677' RKB. Tag must be AOGCC witnessed. Record results. 26. RU pumping unit. PT surface equipment as required. 27. Perform MIT -T to 1500 psi. Record Results. 28. Perform MIT -IA to 1500 psi. Record Results. 29. Perform DDT on Tubing & IA. Record Results. RD & MOL. E -line or DSL / Pumping: Objectives: Log CBL to find IA TOC, Tubing Punch above IA TOC, Circ thru Punch 30. Schedule CBL logging date to log 1D-118 to locate top of cement in IA. Log data will be used to determine where to punch holes in tubing to circulate cement from tubing to IA for Cement Plug #2. Also schedule tubing punch to punch holes above TOC in IA. 31. RU E -line or DSL. Conduct PJSM. Inspect wellhead and worksite to identify any pre-existing conditions. Identify and mitigate hazards. PT equipment as required. 32. RIH with CBL logging BHA to record CBL from surface to TOC in tubing at —3677' RKB, and then log pass back to surface to identify TOC in IA. Evaluate CBL and pick TOC in IA. Expected TOC in IA= 3623' RKB. Max TOC IA = 3059' RKB, if all cement thru Retainer went to IA. Min TOC IA can be below TOC in tubing if the perfs took too much cement. 33. RIH with Tubing Punch BHA to punch 4' OAL at 4 spf, reference CBL for depth correlation. Eline will pick where to shoot punch "50' above IA TOC in middle of full joint if area appears void of cement per CBL with no significant cement stringers above. POOH. Verify ASF. 34. RU Pumping unit. Pump at least 20 bbis Diesel through Punches to verify adequate rate for cement placement (-2 bpm < 2000 psi). This also ensures tubing & IA are fully liquid packed. 35. If -2 bpm circulation rate is not achievable, RIH with another tubing punch and punch holes at -32' above previous holes, and then repeat circ test. 36. RD LRS & MOL. Coil Tubing - Cement Plug #2: Objective: Place 15.8 ppg Class G Cement Plug in 3.5 tubing to -2522' TVD (2640' RKB), and in 6.75" x 3.5" IA to "'2000' TVD (2065' RKB). 2000' TVD is assumed base of permafrost. Leaving TOC —500' deeper in tubing allows for a CBL to find TOC in IA to know where to punch holes. 2.992" ID Tubing 6.750" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement Plug #2: In 3.5" Tbg above TOC In 6.750" ID Csg x 3.5" OD Tbg (IA) above TOC Total Cement = 0.0087 bbl/ft = 0.0324 bbl/ft _ (3677 - 2640')(0.0087) _ (3623 - 2065')(0.0324) = 50.5 bbl = 59.5 bbls 15.8# Class 'G' 37. Verify step 33 (above) circulation test results showed good pump rate through tubing punches before CTU RU on well to pump Cement Plug #2 job. 38. Schedule pilot testing of P&A cement design. Plug #2 Cement job requires 59.5 bbls of pumpable 15.8 ppg Class G Cement. 39. Schedule millable Cement Retainer and cement job date. 40. Order 100 bbls pumpable 9.8 ppg corrosion inhibited NaCl Brine mixed in filtered Freshwater in an 'ultraclean'transport. This fluid will be used to circulate well clean before Cement pumping. Brine temporarily keeps IA freeze protected (9.8 ppg NaCl Brine TCT = -6°F) 41. RU CTU & Cement Van. Do not mix cement batch until Cement Retainer has been set or before we have verified that we can adequately pump through it. 42. Conduct PJSM. Inspect worksite to identify any hazards. Mitigate hazards. 43. PT equipment as required. Mitigate crew exposure to hardline during PT. 44. RIH with Cement Retainer and set it at 2640' RKB, 2522' TVD in 3.5" tubing. Stack weight on Retainer. 45. Open CT x Tbg annulus to tanks and open IA to tanks and then start circulating 100 bbls of 9.8# NaCl Brine down CT at 1 bpm. 46. If good circ rate is seen through Retainer with no returns seen from CT x Tbg to tanks (indicating good Retainer set integrity), then start mixing cement to provide 59.5 bbls pumpable 15.8# Class G Cement. 47. While mixing Cement, continue pumping until all 100 bbls of 9.8# NaCl Brine has been pumped down CT at -1 bpm (100 minutes) to displace all Diesel FP from CT (-50 bbis) and all Diesel from tubing below Retainer (-9 bbls) to IA, then 48. Pump 10 bbls Freshwater Spacer at 1 bpm, followed by 49. Pump 59.5 bbls 15.8 ppg Class G Cement at 1 bpm, followed by 50. Pump 5 bbls Tail Freshwater Spacer at 1 bpm, followed by 51. Pump XX bbls Diesel FP to fill the actual CT volume and to replace voidage created in tubing as CT is POOH to surface. Calculate the volume of Diesel required for this step based on actual CT volume, and voidage replacement needed. 52. After 59.5 bbls of Cement passes thru Cement Retainer, momentarily halt pumping, SI returns from IA to tanks, and then Pu CT off of the Retainer. 53. With CT pulled off of Retainer, POOH while circulating in 5 bbls of Tail Freshwater Spacer in on top of Retainer while taking returns from Tbg x CT to tanks, followed by sufficient volume of Diesel to leave CT Diesel FP and tubing Diesel FP from 2000' ND (2065' RKB) to surface (= 18 bbls). 54. Wash up cement pumps. 55. RDMO. WOC. Tubing is now filled with Diesel FP from Surface to 2065' RKB, Freshwater at 2065 - 2640' RKB (to Cement Retainer), and 15.8# Class G Cement below Cement Retainer (TOC). IA is filled with 9.8# NaCl Brine from Surface to 1756' RKB, 10 bbls Freshwater at 1756 - 2065' RKB, and filled with 15.8 # Class G Cement to 2065' RKB (TOC 'target'). Since 10 bbls Freshwater of lower density ("'8.33 ppg) than 9.8 ppg NaCl Brine will be present in IA, the 9.8 ppg brine can become somewhat diluted by Freshwater and still offer decent FP function (9.6 ppg NACL Brine TCT =1°F, 9.4 ppg NACL Brine TCT = 8°F, etc). Slickline / Pumping Objectives: Tag TOC, MIT -T & MIT -IA, DDT -T, DDT -IA 56. There is no need to notify AOGCC Inspector for Cement Plug #2 tag and PT's. 57. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 58. RU SL. PT equipment as required. 59. RIH with Bailer to tag Cement Retainer in tubing at -2640' RKB. Record results. 60. RU pumping unit. PT surface equipment as required. 61. Perform MIT -T to 1500 psi. Record Results. 62. Perform MIT -IA to 1500 psi. Record Results. 63. Perform DDT on Tubing & IA. Record Results. RD & MOL. E -line or DSL & Pumping: Objectives: Log CBL to find IA TOC, Tubing Punch above IA TOC, Circ thru Punch 64. Schedule CBL logging in 1D-118 to locate top of cement in IA. Log data will be used to determine where to punch holes in tubing to circulate cement from tubing to IA for Cement Plug #3. Also schedule tubing punch to punch holes above TOC in IA. 65. RU E -line. Conduct PJSM. Inspect wellhead and worksite to identify any pre-existing conditions. Identify and mitigate hazards. PT equipment as required. 66. RIH with CBL logging BHA to record CBL from surface to tag Cement Retainer in tubing at -2640' RKB, and then log pass back to surface to identify TOC in IA. Evaluate CBL to pick TOC in IA. Expected -TOC in IA = 2065' RKB (2000' TVD). 67. RIH with Tubing Punch BHA to punch 4' OAL interval at 4 spf, reference CBL for depth correlation. E -line will pick where to punch at -50' above IA TOC in middle of full joint if area appears void of cement per CBL with no significant cement stringers above. POOH. Verify ASF. 68. RU LRS. Pump at least 20 bbls Diesel through the punches to ensure adequate rate for cement placement (-2 bpm < 2000 psi). 69. If -2 bpm circulation rate is not achievable, RIH with another tubing punch to punch holes at ^32' above previous holes, then repeat circ test. 70. RD LRS & MOL. Pumping - Cement Plug #3: Obiective: Place Cement Plug #3 from -2640' RKB Cement Retainer to surface by circulating Cement down 3.5" Tubing 'Kill String' through tubing punches and up IA to surface. 2.992" ID Tubing 6.750" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement Plug #3: In 3.5" Tbg above Cement Retainer In 6.750" ID Csg x 3.5" OD Tbg (IA) above TOC Excess Total Cement = 0.0087 bbl/ft = 0.0324 bbl/ft _ (2640')(0.0087) _ (2065')(0.0324) = 23.0 bbl = 67.0 bbl = 20.0 bbl = 110.0 bbl 15.7# Arctic Set 1 71. Schedule pilot testing of P&A cement design. Plug #3 Cement job requires 110 bbls of pumpable 15.7 ppg Arctic Set 1 Cement. 72. RU Cement Van. Ensure hardline is rigged up to pump down tubing and take returns to tanks from IA. Ensure full opening returns through 2" hardline. 73. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 74. Prepare for fluids and cement to exit a 1" downspout on conductor into drum. Have vacuum truck on hand to manage fluids. 75. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 76. PT surface equipment as required. Mitigate crew exposure to hardlines for PT. 77. Circulate well with ^250 bbls Seawater from a full 290 bbl transport down tubing and up IA at "2 bpm to tanks to get all 9.8# NaCl Brine, Freshwater Spacer, and Diesel out of the well. After having established good circulation, start mixing cement while pumping the circ out. 78. Pump 10 bbls Lead Freshwater Spacer. 79. Pump 110 bbls of 15.7 ppg ARCTICSET* 1 (AS1) Cement. This calculation assumes 20 bbl of excess cement to ensure good cement job to surface in tubing and IA. 80. Monitor returns on surface, taking samples and checking pH/density. 81. Once good cement returns are verified on surface (using mud scale for cement density measurement), shut down and open up surface bypass line to flush all lines with water. 82. Wash up cement pumps. 83. RDMO. 84. WOC 48 hrs. 85. Perform drawdown tests on tubing, IA, and OA. Wellhead Excavation / Final P&A: 86. Remove well house if still installed. 87. Bleed off T/I/O to ensure all pressure is bled off the system. 88. Remove production tree, in preparation for excavation and casing cut. 89. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent ground fill material from falling into the excavation. 90. Cut off wellhead and all casing strings at 4 feet below original ground level. 91. Perform Top Job and verify that cement is at surface in all strings (T/IA/OA). AOGCC witness and photo document required. 92. Send casing head w/ stub to materials shop. Photo document. 93. Photo document. AOGCC Witness is Required. Weld Y4" thick cover plate (16" OD) overall casing strings with this information bead welded onto the top: ConocoPhillips KRU 1D-118 PTD #: 197-229 API #: 50-029-22839-00 94. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 95. Obtain site clearance approval from AOGCC. RDMO. 96. Report Final P&A has been completed to AOGCC (file a 10-407 form). Notify any other agencies as required. 97. Photo document final location condition after all work is completed. _ - -- ID -1 18 Plug and Abandon PM # 197-229 Current Completion J l 16'6250 H-40 Cwdxw -KQ t21'K3 L 90 Tulsrg K01 Snag at 3827.8' KB Tbg 8 A Oimel Filed x 37M KB, 3% KCL Orme n Tba 3768.3800' K6, 3% KCL Miw m N 37M - 31122'99 GLU fapm)at 3786 KS Liner Tap Packer at 36248' KB 2.7)8' 6.5N L80 Lner Straddle 3826.2.40!9.4' Kra Re:uevaWe Bridge PlLq at 390' KB Phis 3696 - 3932' KB 3964 - 4034'M 4084.4t 18 KB 4149.4229' KB 5. t' C iml Pa_k lir -r U29.9 .4289 KB 7-5+6' 29.70 L-60 Roduelan Casinu at 4574.1' KB Proposed P&A N Urtw_nl Tap Jab ent PLg 03, f Amlic5e. 1. at Solace, Io 26447 KB, a 215' KB m1pilg 02, 10 Class G, 3C to 28"40' KG 5:1) abne end er at 2610' KB, C la 2085 KB Knt Pug 01, ' 80 pass G CC to 367TK8 ,IaveL4nt ar at 3735' KB, tC L 3625 K2 AP 2-27-15 Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Tuesday, February 18, 2020 2:50 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]10-403 for 1D-118 Plug and Abandonment Follow Up Flag: Follow up Flag Status: Completed Victoria, OK. We will get Cement Plug #1 pumped before March 19" and then Report all P&A work up to that point on a 10- 404. 1 will also submit a new 10-403 for a new approval to complete remaining 1D-118 P&A work. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 18, 2020 2:45 PM To: Peirce, John W<John.W.Peirce@conocophi11ips.com> Subject: [EXTERNAL]10-403 for 1D-118 Plug and Abandonment John, If the work was to be completed sooner, I would not require another Sundry. However, I think you should close out this 151 cement plug with a 10-404 and submit a new 10-403 for the remaining work. Thal Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCdalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding if, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 oruc lariu , alask,,1 aov From: Peirce, John W <John.W.Peirce@conocoohillios.com> Sent: Tuesday, February 18, 2020 2:40 PM To: Loepp, Victoria T (CED) <victoria loep�alaska -gov> Subject: RE: [EXTERNAL]RE: 10-403 for 1D-118 Plug and Abandonment Victoria, I just talked with the guys on the Slope that are trying to get the P&A work done for their input on how long it will take before we can get 113-118 Surface plug completed. I was told that due to lots of weather delays impacting well work ops, and the amount of work that's been stacking up in the meantime, that realistically it may be 3 to 4 months before we get the surface plug completed in 1D-118, so that's our best guess for now. Thanks, John Peirce From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 18, 2020 2:22 PM To: Peirce, John W <John_.W.Peirce C@ onocophilrips .com> Subject: [EXTERNAL]RE: 10-403 for 1D-118 Plug and Abandonment John, What is the timeframe for completing the surface plug? Thanx, Victoria From: Peirce, John W <John.W.Peirce @conocophillips.com> Sent: Tuesday, February 18, 2020 7:34 AM To: Loepp, Victoria T (CED) <victo_ria.loepp@alaska.xov> Subject: Re: 10-403 for 1D-118 Plug and Abandonment Hi Victoria, At 1D-118, we have so far completed Slickline work steps 1 through 10 of the job procedure approved per the 10-403 to P&A the well (attached below). We now plan to pump Cement Plug #1 (starting with step 11) with Coil Tubing scheduled to be on the well this week after the current cold weather shutdown delay. The 10-403 approval to P&A ID -118 to Surface will become 1 year old as of 3-19-2020, so the current 10-403 approval will expire before we complete all of the work steps in the procedure. Thus, I request guidance on how to extend the Sundry approval to a later date to continue work on the P&A to completion. Can we extend the current approval, or should I report work completed to date under the current approval and submit a new 10-403 Sundry to seek approval for remaining P&A work needed to complete P&A work on 1D-118? Thanks, John Peirce Sr Wells Engr CPA] Drilling & Wells (907)-265-6471 office Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Tuesday, February 18, 2020 2:50 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL110-403 for 1D-118 Plug and Abandonment Follow Up Flag: Follow up Flag Status: Flagged Victoria, OK. We will get Cement Plug #1 pumped before March 19t" and then Report all P&A work up to that point on a 10- 404. 1 will also submit a new 10-403 for a new approval to complete remaining 1D-118 P&A work. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, February 18, 2020 2:45 PM To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]10-403 for ID -118 Plug and Abandonment John, If the work was to be completed sooner, I would not require another Sundry. However, I think you should close out this 1't cement plug with a 10-404 and submit a new 10-403 for the remaining work. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.LoeooCdalaska aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended reciplent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipp@alaska.gov From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Tuesday, February 18, 2020 2:40 PM To: Loepp, Victoria T (CED) <victoria.loeppCa)alaska eov> Subject: RE: [EXTERNAL]RE: 10-403 for 1D-118 Plug and Abandonment Victoria, I just talked with the guys on the Slope that are trying to get the P&A work done for their input on how long it will take before we can get 1D-118 Surface plug completed. I was told that due to lots of weather delays impacting well work ops, and the amount of work that's been stacking up in the meantime, that realistically it may be 3 to 4 months before we get the surface plug completed in 1D-118, so that's our best guess for now. Thanks, John Peirce From: Loepp, Victoria T (CED) <victoria.loepp alaska ¢ov> Sent: Tuesday, February 18, 2020 2:22 PM To: Peirce, John W <John.W.Peirce2conocophillips com> Subject: [EXTERNAL]RE: 10403 for 1D-118 Plug and Abandonment John, What is the timeframe for completing the surface plug? Thanx, Victoria From: Peirce, John W <Jo_hn.W.PeircePconocophillips com> Sent: Tuesday, February 18, 2020 7:34 AM To: Loepp, Victoria T (CED) <victoria.loepp(@alaska eov> Subject: Re: 10-403 for 1D-118 Plug and Abandonment Hi Victoria, At 1D-118, we have so far completed Slickline work steps 1 through 10 of the job procedure approved per the 10-403 to P&A the well (attached below). We now plan to pump Cement Plug #1 (starting with step 11) with Coil Tubing scheduled to be on the well this week after the current cold weather shutdown delay. The 10-403 approval to P&A 1D-118 to Surface will become 1 year old as of 3-19-2020, so the current 10-403 approval will expire before we complete all of the work steps in the procedure. Thus, I request guidance on how to extend the Sundry approval to a later date to continue work on the P&A to completion. Can we extend the current approval, or should I report work completed to date under the current approval and submit a new 10-403 Sundry to seek approval for remaining P&A work needed to complete P&A work on 1D-118? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-118 Permit to Drill Number: 197-229 Sundry Number: 319-101 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.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, Daniel T. Seamount, Jr. Commissioner DATED this 19day f March, 2019. 9041 P�1 SIP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED h1Act 011 2019 Au,c 1. Type of Request: Abandon U Plug Perforations ❑' Fracture Stimulate LJ Repair Well Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[] Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: r 5. Permit to Drill Number: ConocoPhilli s Alaska, Inc. Exploratory ❑ Development El Stratigraphic ❑ Service ❑ 197-229 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029228390000 7. If perforating: 8. Well Name and Number: Dr,6 a What Regulation or Conservation Order governs well spacing in this pool? N/A 9i4lt Will planned perforations require a spacing exception? Yes ❑ No El v KRU ID -118 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 t Kuparuk River Field / West Sak 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): 4,595' 4,335' 3900 3677 1500psi 3900 NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' Production 4,533' 8" 4,574' 4,316' Gravel Pack Liner 430' 5" 4,260' 4,017' Perforation Depth MD (ft): Perforation Depth TVD (ft) ITubing Size: Tubing Grade: Tubing MD (ft): 3898-3932, 3964-4034, 4064- 3675-3707, 3737-3803, 3831- 3.500" L-80 4,049' 4110,4 4D4229 3875 3903-3987 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER- BAKER SC -1 Gravel Pack Packer PACKER- BAKER FB -1 Retainer Packer (see schematic for add'I packers) 3830 MD and 3610 TVD SSSV -NONE 4230 MD and 3988 TVD 12. Attachments: Proposal Summary 0 Wellbore schematic ❑� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑+ Service ❑ 14. Estimated Date for 3/20/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned P] 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: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 Authorized Signature: � 2,1 1 c -r. Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity`❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: / Post Initial Injection MIT Req'd? Yes ❑ No (g Spacing Exception Required? Yes ❑ No d Subsequent Form Required: O — 40 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date. V yL 3//`r/ ORIGINAL RBDMS�MAR 1 9 2019 Submit Form and Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. ` g Atta hmenta in Duplicate aB. 315%19 KUP PROD WELLNAME 1D-118 CO(10cOPI11ll)pS F. �" 1,!,91,1.A ttributes tlme Wellb,eAPUUWI Wegr Alaska, Inc WEST SAK 500292283900C) 6 PROF NONE WELLBORE 1D-118 fpuaznaw+e a.+ut Au Last Tag Vedda4pnbnl�all Annolatkn DapmrdKIR End pa@ I wellbma last Mad By HV4GEn. ae.a cdNDUCTOR140 T,Na pE8EL:9Be WBLIFi; 9,]mf I., NOk, 9.8&z ANCHOR 38292- PLUG 39000 IPEaaa.em.oa.ana- TENP. ae61"0340- SEA-ABar;a,wv PERF 4.oa4oa,noo- IINeaE:4.+4ow.zza.a_ GRAVEL PACK LINER. a,®a azeoo PNODUCTKN.4074S/4.t ' Last Tag 11mospor Last Rev Reason Mnatadon End D. weR.,. Last MW By Rev Reason'. DRILL DEPTHSIDATES 41162013 1D-118 osborl Casing Strings CeaI ues."Ro" ED (in) 1o0n) Top lnnB) CONDUCTOR 16 1506 407 SN DORM MB) see TOM OVD)...MLan dIsinde TOPTh,ead 121.0 121.0 62.58 H40 WELDED Catl,q pesctlptlun pp lln) ID hnl Top IflNB) PRODUCTION ]5/8 687 40.7 BNDepM(N(B) sM DeAM IND) "'MLS, IL..Grtle 4,5]4.1 4,3156 29,70 L40 Tap Throw! ABM -BTC CWnY Deac,iplun pD ON 4-lhol Tdp1eKB1 GRA VEL PACK LINER 5.1 400 3,829.8 9N DePOWER Set CON, IND)... WUlen(1... Wade TOP TI,rcW 0,260.0 4,0168 13.50 L-80 Seal Lock HT Liner Details xommm ID Top lnKe) Top (rvD)(tU(B) Item Dez Com (lp 3,8298 3,610.5CKER Bilker SC -1 Gravel Pack Pacer 6.000 3,8401 ,620]R Baker Seal Bore Receptacle .50 3,845.9 3,625.6EEVE Gravel Pack Sliding Sleeve 3480 3,847.6 3.627.2R 5.1 Bore 3250 !_19 EPACKER 3,889.4 3,6666REEN IN, ke+wel ravel pack screen "x - fk.020° gauge w26-ew r,pped -FORMATION PERF'd 301998 4.000 3,934.5 3,]09.1 R Baker Seal Bore Receptacle 3250 3,936.] 3,711.2 CKER Baker SC -1L Special Isolation Packer 3,875 3,940.1 3,7143 1952 SBR Baker Seal Bore Receptacle 3.250 3,945.2 3,719.2 19.51 SLEEVE Gravel Pack Sliding Sleeve 3.480 3,946.9 3,]20. 19.50 SBR Seal Bore 3.250 3g49'5 3,72. 19.49 PACKER Baker -1 L Special Isolation Pacer 3.930 3,9567 3,) 1947 $ RFEN j6 Ba'Ta's 4 revelpack screen 4S' 4.000 ex.020" gauge w2fi-e wrapped - FORMATION PERPd 3/6/1996 4,090 3,807.7 1922 SBR Baker Seal Bore Receptacle 3.250 4 073,8098 19.21 PACKER Baker SC -1L Special lactation Packer 3,875 4,046.6 3,81. 1920 SBR Baker Seal Bore Receptacle 3,250 4, .8 3,817.8 19.19 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,0515 3,9-174 19.18 BR Seal Bore 32 4, 3.2 3,830.5 19.15 WREEN 3jis Bak:rweldt rave pack streen4. "x 4. ex.020" auge w26 -e wrapped - FORMATION PERF'd 8/1998 -Tuff 4,113.5 Anchor Baker S-22Anchorasaembly 400 4,116.3 ,878a 1= PACKER Baker SC -1L Special Isolation Packer 4000 4,120.1 3,884.31 18.7 SBR Baker Seal Bore ReceptaGe 3250 4,1232 3,8872 l&W PACKER Baker SC -1 L Special Isolation Packer 4.8 0,125.3,8892 1 F. W SLEEVE Grevel Pack Sliding Sleeve 3. 4,127,0 ,890.8 19.75 SBR Seel Bore 25 4,1388 3,9020 18.1 SCREEN ps a.r l4 rave pack sueen d. d. 00 IUc.020" gauge w26nwrapped - FORMATION PERF'd WI998 4,228.9 3,987.3 18.59 ANCHOR Baker S-22 Author assembly 0 82300 3,988.3 188 PACKER Baker Model FB -1 Retainer Production Packer.250 Tubing Strings rubin oesc,lpUon snin Ma_.lDonl TOORK6) aet Da pm lx_sM Dean TID)l... wt(a.) Gude TOpconnmwn TUBING Kill String 3112 2.99 369 3,82].6 3,608.9 9.30 L-80 EUE Completion Details roil lfl8e) mpmol TaPmN Ieael 1.1 nem Des cora rvommaI IOIMI 36.91 We 000 I MANGER j1hTCO GRAY TUBING HANGER 2.950 ruWnO DeaOriptim ead, Me._IpgnI TopllaLB) 9M DepM IR. 8e10epM IND1I... W111Mr1 Grade Tap ConnW40n LINER STRADDLE 2718 2.38 3,826.2 4,0494 3,817.5 6.50 L-80 Hydcl 511 Completion Details TopINDI TOP Incl Nwnl,Nl Top(ma) Ines) 1.1 14m Dee cora ID (in) 3182.2 3.6021 1986 Fishing Neck 5"GS Scoop Head 3000 3,829.2 3,609.9 1985 ANCHOR Baker BO-405nap lakh 2. dou 4,0417 3.8102 19.21 SEAL ASSY Baker 80-,hAssmbly 2.438 Other In Hole ryVimline retrievable plugs, valves, pumps, fish, etc.) roplNol roplul Tap lnKe) IM(al 1'1 Das Com Bun oak IOOnI 39.6 396 000 DIESEL 173 bilis of diesel rFreeze protan 42/2012 3,9000 3,6]6.6 19.84 PLUG RETRIEVABLE BRIDGE PLUG 482012 Perforations & Slots TOPMKB) aMRWE) mill'.) (Wash ebnlrvD) M e) Unkadzw. Dau shoe hens Ishpwn gyp Co. 31898.0 3,9U.0 3,674.7 3706.] WS D,10.118 M/1908 120 WERE 4 5" SWS UIUa_Pack-TCF- 135145 deg ph 3,9640 4,034. 3,]38.9 3,8029 _WTB W A 1D -118 316/1998 12.0 IPERF .5' W aa- ack-T P - IW45 deg ph 4,06X0 4,110.0 3,8312 ,8747 WSA31D-118 3/611996 120 (PERF - W Dlne-PeC; 135145 deg phasing 4,16 0 6,229.0 ].003.1 870 WS -D-118 3'6/1938 120 (PERF W Ultra- ack- 135145 deg ph KUP PROD WELLNAME 1D-118 WELLBORE 1D-118 ConocoPhillips Alaska. Inc. E::] ,o-na v,armiee.0 aun Mandrel Inserts v.�ewlm�.iwp Bt OR _....._ .......................... _............. _.. OR N Topma) roP"IN (ryRB) Make MOOeI On pni 5ary valor Type Lalen TypeCAMCO iii INNGFA: %.e KBMM 1 GAS LIFT OPEN 6/1/2012 Notal: General 8 Safety -EMDa pn.oMlon 1 010 NOTE: View Schematic w/ Alaska Schemauea.0 cONl3LGTORIb7-121.a 4/1WO12 U. WELL SUUPENDED 51182012 NOTE: Any MUM ng operations on 1D-118 will require submittal of a farm 1"03 W the A0G CL DIESEL, 39.8 GPSUFr:3ONI F0vm Nsk 3M2 ANGXOR.3.M2 PLUG:3.B 0 IPERF:38<B.O3 (PERF; 9.PA.O40N.U� SEAL Aa9Y: a,M1] (PERF; e,p24,p.6,110.0� (PERE 41e0p ,=O8 GMYEL MILK LINER, 3829.6 4,zmo PaolwcnoN, wT<,n4,_ 1D-118 Plug & Abandon to Surface Proposal It is proposed that 1D-118 be plugged and abandoned with cement from the perforation intervals between 3898 - 4229' RKB to surface in the kill string and production casing. Well History Review: 1D-118 was drilled in Dec 1997 and completed in March 1998. During the frac-pack completion, the inner wash was stuck and parted. Nordic 2 recovered all but 30' of the fish which was left across the SC-11- packer C-1Lpacker at 4041' MD. In 2000, Nordic 3 recovered all of the remaining fish. A seal bore assembly and latch were ruri to i orate the B & D sands, and an ESPCP completion was run to return 1D-118 to production until the pump eventually failed to restart after a proration. In March 2012, Nordic 3 moved onto 1D-118 to recomplete the well. The 3.5" ESPCP completion was pulled, then casing swaging in 7-5/8" production casing detected casing damage at —385' while running a 6.75" drift that would not pass "'385'. Recompletion work plans were then cancelled. The rig set a 3-3/8" IBP at 3800' in 7-5/8" casing then performed an MIT to 1500 psi that passed. A Caliper and Gyro were run in 7-5/8" casing, and then an Eline CAST log found TOC behind 7-5/8" at —470' RKB. The IBP was then pulled and a 3.5" kill string was installed with an open pocket GLM at 3786' just above kill string tubing tail at 3827' RKB. A WRP was then set at 3900' RKB, and a CMIT was performed to 1550 psi that passed before Nordic 3 moved off well. A Catcher Sub was left on top of the WRP which remains set in the well. An AOGCC 10-404 date 4/30/12 reported 1D-118 as 'Suspended'. No new well work has been performed since April 2012 in 1D-118. No further utility exists for 1D-118. Thus, a Plug & Abandonment will be performed per this procedure to cement the well to surface. T^ The wellhead will be removed, and an ID plate will be welded onto the casing, then 1D-118 will be buried. 1D-118 Proposed P & A Procedure: Slickline: Obiectives: CMIT, pull WRP, tag PBTD, SBHPS, B&F, SRIT, & drift dummy Cement Retainer 1. Complete Pre -job Safety meeting. RU SL. PT lubricator and surface lines as required. 2. CMIT to 2000 psi via open pocket GLM at 3786' RKB. Record initial, 15, 30 min T/I/O psi. 3. Pull 2.28" Catcher Sub at 3900' RKB, and then pull the 2.25" WRP set at 3900' RKB. 4. RIH with sample bailer to tag PBTD. S. RIH with pressure / temperature gauges to obtain 30 min SIBHP and BHT at —4185' RKB or just above PBTD tag depth (attained in step 4). Perform 15 min gradient check 100' TVD up hole. .b b c 6. Brush & Flush 3.5" Tbg at 3715 - 3775' RKB for Cement Retainer set at 3735' RKB on CT (step 13). 7. Perform fullbore Diesel Step Rate injectivity Test (SRIT). Pump Diesel down tubing to verify ability to pump cement to gravel pack liner across perfs from PBTD to planned Cement Retainer set depth in tubing at 3735' RKB. Record SRIT results for 2 or 3 stable rates with WHIP's below 1000 psi max (to stay below Frac pressure). Nordic 3 reported 207 bbls of fluid lost to formation during 2012 RWO. Thus, theformation is expected to tak f6dd 8. RIH with 2.75" OD x 10' OAL Dummy Cement Retainer BHA, down to 3735' RKB (middle of a full tubing joint). 9. RD SL & MOL. Coiled Tubing - Cement Plug #1: Objective: Place Cement Plug across all open perforations and squeeze some cement into the perfs, if possible. 2.992" ID Tubing 4.000" ID -average ID of Gravel Pack Liner 6.750" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement Plug #1: In 3.5" Tbg above Cement Retainer In 3.5" Tbg below Cement Retainer In ^'4" ID Gravel Pack Liner from TD to SC -1 Pkr In 6.750" ID Csg x 3.5" OD Tbg Total Cement = 0.0087 bbl/ft = 0.0155 bbl/ft = 0.0324 bbl/ft _ (3735 - 3677')(0.0087) = 0.5 bbl _ (3830 - 3735')(0.0087) = 0.9 bbl _ (4595 - 3830')(0.0155) = 11.9 bbl =(3830-3623')(0.0324) = 6.7 bbl = 20.0 bbl 15.8 ppg Class 'G' 10. Schedule pilot testing of P&A cement design. Cementjob requires 20 bbls of pumpable 15.8# Class G Cement. 11. Schedule millable Cement Retainer and Stinger kit for Cement job. 12. MIRU CTU & Cement Van. Conduct PJSM. Inspect wellhead and location for any pre-existing conditions. Mitigate hazards. Establish site control. Mitigate personnel exposure for PT, then PT equipment. Do not mix Cement until requested (in step 16). 13. RIH with Cement Retainer and set it in 3.5" tubing at 3735' RKB targeting the middle of a full joint above open pocket GLM at 3786' RKB. This location is safe distance above open pocket GLM so the Retainer will be set above the GLM without need for depth control. 14. After Cement Retainer has been set, POOH with CT to swap to Stinger BHA. RBIH with CT x Tbg annulus open to tanks. When Stinger is within 100' of Cement Retainer, halt RIH to circulate Diesel until liquid returns are seen to tanks indicating tubing above the Retainer is fully 'liquid packed' to surface. RIH & sting into Retainer. Stack weight on Retainer per vendor Rep. 15. Pump Diesel through Retainer with CT x Tbg open to tanks and IA closed to verify good sting integrity into Retainer. No returns from CT x Tbg should be observed to tanks. If Tbg x CT returns are seen to tanks, then faulty sting integrity into Retainer must be corrected before pumping a cement job. Pump Diesel 0.5 bpm until good sting integrity is verified. This pumping should also verify adequate injectivity exists through Retainer to Gravel Pack Screens and— peg intrvals to test results being 16. Strive to pump 0.5 bpm below Frac Pressure (1000 psi max WHIP), but if we need to go above Frac pressure to achieve 0.5 bpm, then Frac for short duration during cement pumping thru Retainer to get cement down Gravel Pack Liner ("'12 bbls Cement thru Retainer) and to squeeze a small volume of cement to perfs before opening IA to tanks to divert remaining cement (^'7.5 bbls) to fill IA. 17. Make a final verification of good sting integrity into Retainer, and verification of ability to pump at 0.5 bpm thru Retainer before proceeding to step 18. 18. Pump 1 CT volume (^'50 bbls) Lead Freshwater Spacer down CT at 0.5 bpm to displace Diesel from CT to formation (takes 100 minutes). Mix up 20 bbls of pumpable 15.8 ppg CI G Cement while pumping away Freshwater. 19. Pump 20 bbls 15.8 ppg Class G Cement at 0.5 bpm. 20. Pump 10 bbls of Tail Freshwater Spacer at 0.5 bpm. 21. Pump XX bbls Diesel displacement at 0.5 bpm. Calculate Diesel displacement volume needed, which depends on actual CT volume. Note the CT volume and calculate when IA needs to be opened to tanks to enable diverting cement placement to IA. After 12.8 bbls cement has passed thru Retainer, open IA to tanks and pump remaining cement down CT to stack cement into IA. When 19.5 bbls cement has passed the Retainer, PU CT off of Retainer. Calculate Diesel displacement volume needed to get 19.5 bbls of Cement displaced thru the Retainer, which depends on actual CTvolume, and then PU CT off the Retainer to resume pumping the last 0.5 bbl Cement on top of Retainer, followed by continued Diesel pumping to replace voidage while CT POOH. Diesel FP from 2065' RKB; 2000' TVD to surface (18 bbls). RD CTU. Wait on cement at least 48 hours. Slickline / Pumping Objectives: Tag Cement Plug #1 TOC, and perform AOGCC Witnessed MIT -T & MIT -IA, DDT -T, DDT -IA. ✓ 22. Notify AOGCC Inspector of timing of Cement Plug #1 tag and pressure t ing 23. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 24. RU SL. PT equipment as required. 25. RIH with Bailer to tag TOC in tubing at -3677' RKB. Tag must be AOGCC witnessed. Record results. 26. RU pumping unit. PT surface equipment as required. n( 27. Perform MIT -T to 1500 psi. Record Results. V v 5hV s� b � >a`��,r5 28. Perform MIT -IA to 1500 psi. Record Results. 29. Perform DDT on Tubing & IA. Record Results. RD & MOL. E -line or DSL / Pumping: Objectives: Log CBL to find IA TOC, Tubing Punch above IA TOC, Circ thru Punch 30. Schedule CBL logging date to log 1D-118 to locate top of cement in IA. Log data will be used to determine where to punch holes in tubing to circulate cement from tubing to IA for Cement Plug #2. Also schedule to mg —punch to punch holes above TOC in IA. 31. RU E -line or DSL. Conduct PJSM. Inspect wellhead and worksite to identify any pre-existing conditions. Identify and mitigate hazards. PT equipment as required. 32. RIH with CBL logging BHA to record CBL from surface to TOC in tubing at -3677' RKB, and then log pass back to surface to identify TOC in IA. Evaluate CBL and pick TOC in IA. Expected TOC in IA = 3623' RKB. Max TOC IA = 3059'VEF i all cement thru Retainer went to IA. Min TOC IA can be below TOC in tubing if the perfs took too much cement. 33. RIH with Tubing Punch BHA to punch 4' DAL at 4 spf, reference CBL for depth correlation. Eline will pick where to shoot punch —50' above IA TOC in middle of full joint if area appears void of cement per CBL with no significant cement stringers above. POOH. Verify ASF. 34. RU Pumping unit. Pump at least 20 bbls Diesel through Punches to verify adequate rate for cement placement (-2 bpm < 2000 psi). This also ensures tubing & IA are fully liquid packed. 35. If -2 bpm circulation rate is not achievable, RIH with another tubing punch and punch holes at -32' above previous holes, and then repeat circ test. 36. RD LRS & MOL. Coil Tubing - Cement Plug #2: Objective: Place 15.8 ppg Class G Cement Plug in 3.5" tubing to "2522' TVD (2640' RKB), and in 6.75" x 3.5" IA to ^'2000' TVD (2065' RKB). 2000' TVD is assumed base of permafrost. TOC —500' deeper in tubing allows for a CBL to find TOC in IA to know where to punch holes. 2.992" ID Tubing 6.750" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement Plug #2: In 3.5" Tbg above TOC In 6.750" ID Csg x 3.5" OD Tbg (IA) above TOC Total Cement = 0.0087 bbl/ft = 0.0324 bbl/ft _ (3677 - 2640')(0.0087) _ (3623 - 2065')(0.0324) = 50.5 bbl = 59.5 bbls 15.8# Class 'G' 37. Verify step 33 (above) circulation test results showed good pump rate through tubing punches before CTU RU on well to pump Cement Plug #2 job. 38. Schedule pilot testing of P&A cement design. Plug #2 Cement job requires 59.5 bbls of pumpable 15.8 ppg Class G Cement. 39. Schedule millable Cement Retainer and cement job date. 40. Order 100 bbls pumpable 9.8 ppg corrosion inhibited NaCl Brine mixed in filtered Freshwater in an 'ultraclean'transport. This fluid will be used to circulate well clean before Cement pumping. Brine temporarily keeps IA freeze protected (9.8 ppg NaCl Brine TCT = -6°F) 41. RU CTU & Cement Van. Do not mix cement batch until Cement Retainer has been set or before we have verified that we can adequately pump through it. 42. Conduct P1SM. Inspect worksite to identify any hazards. Mitigate hazards. 43. PT equipment as required. Mitigate crew exposure to hardline during PT. 44. RIH with Cement Retainer and set it at 2640' RKB, 2522' TVD in 3.5" tubing. Stack weight on Retainer. 45. Open CT x Tbg annulus to tanks and open IA to tanks and then start circulating 100 bbls of 9.8# NaCl Brine down CT at 1 bpm. 46. If good circ rate is seen through Retainer with no returns seen from CT x Tbg to tanks (indicating good Retainer set integrity), then start mixing cement to provide 59.5 bbls pumpable 15.8# Class G Cement. 47. While mixing Cement, continue pumping until all 100 bbls of 9.8# NaCl Brine has been pumped down CT at —1 bpm (100 minutes) to displace all Diesel FP from CT (-50 bbls) and all Diesel from tubing below Retainer (-9 bbls) to IA, then 48. Pump 10 bbis Freshwater Spacer at 1 bpm, followed by 49. Pump 59.5 bbls 15.8 ppg Class G Cement at 1 bpm, followed by 50. Pump 5 bbls Tail Freshwater Spacer at 1 bpm, followed by 51. Pump XX bbls Diesel FP to fill the actual CT volume and to replace voidage created in tubing as CT is POOH to surface. Calculate the volume of Diesel required for this step based on actual CT volume, and voidage replacement needed. 52. After 59.5 bbls of Cement passes thru Cement Retainer, momentarily halt pumping, SI returns from IA to tanks, and then PU CT off of the Retainer. 53. With CT pulled off of Retainer, POOH while circulating in 5 bbls of Tail Freshwater Spacer in on top of Retainer while taking returns from Tbg x CT to tanks, followed by sufficient volume of Diesel to leave CT Diesel FP and tubing Diesel FP from 2000' TVD (2065' RKB) to surface (= 18 bbls). 54. Wash up cement pumps. 55. RDMO. WOC. Tubing is now filled with Diesel FP from Surface to 2065' RKB, Freshwater at 2065 - 2640' RKB (to Cement Retainer), and 15.811 Class G Cement below Cement Retainer (TOC). IA is filled with 9.811 NaCl Brine from Surface to 1756' RKB, 10 bbls Freshwater at 1756 - 2065' RKB, and filled with 15.811 Class G Cement to 2065' RKB (TOC 'target'). Since 10 bbls Freshwater of lower density ("'8.33 ppg) than 9.8 ppg NaCl Brine will be present in IA, the 9.8 ppg brine can become somewhat diluted by Freshwater and still offer decent FP function (9.6 ppg NACL Brine TCT =1°F, 9.4 ppg NACL Brine TCT = 8°F, etc). Slickline / Pumping Objectives: Tag TOC, MIT -T & MIT -IA, DDT -T, DDT -IA 56. There is no need to notify AOGCC Inspector for Cement Plug #2 tag and PT's. 57. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 58. RU SL. PT equipment as required. 59. RIH with Bailer to tag Cement Retainer in tubing at —2640' RKB. Record results. 60. RU pumping unit. PT surface equipment as required. 61. Perform MIT -T to 1500 psi. Record Results. 62. Perform MIT -IA to 1500 psi. Record Results. 63. Perform DDT on Tubing & IA. Record Results. RD & MOL. E -line or DSL & Pumping: Objectives: Log CBL to find IA TOC, Tubing Punch above IA TOC, Circ thru Punch 64. Schedule CBL logging in 1D-118 to locate top of cement in IA. Log data will be used to determine where to punch holes in tubing to circulate cement from tubing to IA for Cement Plug #3. Also schedule tubing punch to punch holes above TOC in IA. 65. RU E -line. Conduct PJSM. Inspect wellhead and worksite to identify any pre-existing conditions. Identify and mitigate hazards. PT equipment as required. 66. RIH with CBL logging BHA to record CBL from surface to tag Cement Retainer in tubing at ^2640' RKB, and then log pass back to surface to identify TOC in IA. Evaluate CBL to pick TOC in IA. Expected -TOC in IA = 2065' RKB (2000' TVD). 67. RIH with Tubing Punch BHA to punch 4' DAL interval at 4 spf; reference CBL for depth correlation. E -line will pick where to punch at —50' above IA TOC in middle of full joint if area appears void of cement per CBL with no significant cement stringers above. POOH. Verify ASF. 68. RU LRS. Pump at least 20 bbls Diesel through the punches to ensure adequate rate for cement placement (-2 bpm < 2000 psi). 69. If —2 bpm circulation rate is not achievable, RIH with another tubing punch to punch holes at -32' above previous holes, then repeat circ test. 70. RD LRS & MOL. Pumping - Cement Plug #3: Objective: Place Cement Plug #3 from —2640' RKB Cement Retainerto surface by circulating Cement down 3.5" Tubing 'Kill String'through tubing punches and up IA to surface. 2.992" ID Tubing = 0.0087 bbl/ft 6.750" ID Csg x 3.5" OD Tbg (IA) = 0.0324 bbl/ft Volumes to fill with Cement Plug #3: In 3.5" Tbg above Cement Retainer = (2640')(0.0087) = 23.0 bbl In 6.750" ID Csg x 3.5" OD Tbg (IA) above TOC = (2065')(0.0324) = 67.0 bbl Excess = 20.0 bbl Total Cement = 110.0 bbl 15.7# Arctic Set 1 71. Schedule pilot testing of P&A cement design. Plug #3 Cement job requires 110 bbls of pumpable 15.7 ppg Arctic Set 1 Cement. 72. RU Cement Van. Ensure hardline is rigged up to pump down tubing and take returns to tanks from IA. Ensure full opening returns through 2" hardline. 73. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 74. Prepare for fluids and cement to exit a 1" downspout on conductor into drum. Have vacuum truck on hand to manage fluids. 75. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 76. PT surface equipment as required. Mitigate crew exposure to hardlines for PT. 77. Circulate well with ^250 bbls Seawater from a full 290 bbl transport down tubing and up IA at "2 bpm to tanks to get all 9.8# NaCl Brine, Freshwater Spacer, and Diesel out of the well. After having established good circulation, start mixing cement while pumping the circ out. 78. Pump 10 bbls Lead Freshwater Spacer. 79. Pump 110 bbls of 15.7 ppg ARCTICSET* 1 (ASI) Cement. This calculation assumes 20 bbl of excess cement to ensure good cement job to surface in tubing and IA. 80. Monitor returns on surface, taking samples and checking pH/density. 81. Once good cement returns are verified on surface (using mud scale for cement density measurement), shut down and open up surface bypass line to flush all lines with water. 82. Wash up cement pumps. 83. RDMO. 84. WOC 48 hrs. 85. Perform drawdown tests on tubing, IA, and OA. Wellhead Excavation / Final P&A: 86. Remove well house if still installed. 87. Bleed off T/I/O to ensure all pressure is bled off the system. 88. Remove production tree, in preparation for excavation and casing cut. 89. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent ground fill material from falling into the excavation. 90. Cut off wellhead and all casing strings at 4 feet below original ground level. 91. Perform Top Job and verify that cement is at surface in all strings (T/IA/OA). AOGCC witness and photo document required. 92. Send casing head w/ stub to materials shop. Photo document. 93. Photo document. AOGCC Witness is Required. Weld X" thick cover plate (16" OD) overall casing strings with this information bead welded onto the top: ConocoPhillips I33R2I13it'l PTD #:197-229 API #: 50-029-22839-00 — 0 0 tZX g 31411 94. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 95. Obtain site clearance approval from AOGCC. RDMO. 96. Report Final P&A has been completed to AOGCC (file a 10-407 form). Notify any other agencies as required. 97. Photo document final location condition after all work is completed. ✓ ,rt `1� KUP PROD 1D-118 t.OtI000YAbillIpS i Vge11ANrlbute6 MakAn..M.' TO 998.440, 100. r -3,Z IZm Xanb waaeaa RYxa a{4 Y m I Mlelm mAs � 1'.Z"', 83g00.QQ WEST UK PM30 2531 399554 4,5950 C X>S fpfm{ Daro roM EnJ Dab K9Sr0inl Ply Pebafa DOM low 1e. xilRalEzn9.av vY SSSV'. NONE Laat NO: I!IIRWO 12/1231997 a -" - --- XaxaEX.Ne eJxW0.oX.01.1Zre n:p9er.».a Jaaur.,ar9ea nnxgxaa:±aaez erax.,, Iar. mzae,aaaaGwa�izp- waes.awaaa eava_ 9Edt.19av, {,YtZ +E9....pd.a..lae �9Epn+.aper+3»a- un aacXur. ueoa LJro Mndaeon Depot 11U®1 EnEpM Lag Tag: Mxptation WIYOa BY learn Pw Reason. DRRL DEPTHStDATE3 mWtl 4!1512013 Caeq Dna4yan CONDUCaeK1306.21 OD In} Unl .p ilUeBi .Np NiDepNIM6i 1210 aX Orytlr it I... 1214 wv m{u..G u625b lvp Oren Hag CACOUCT Phan PRUOVCTpN lq - 1518 ID lwl 6.815 rop IM1K01 60.1 SNDapninKEl 4.363 Mi Ceq�II V(1I... 4.3115 Wl len li... 25.10 ___WELDED 4mOe roprNmd L -PO ABMBTC GRAVELamWan GRAVEL PACKLRIER Wenl 5.1 e, 0.1 40001 aP 3, 3619.8 6el0egx 4.281 4166.4 an Dapm rtvDr... 4D158 wtinal...G t3501kU TopiNaaa Beth Lock Hl k•IR6r pegilt Hg$. iTe,le iter, pINDIIKKDI lop Pl en Poa lin), 19 1,8298 3,610.5 18PACKER Baker SC -1 Gravel Pod Peder 4000 38407 3.6291 I Baker Seal Bea, Re9epacka 3.2 3,826 3 ,27 2 I§WSBR SWB. 3,250 38894 1656. i EN 3;YBakerPeld 140 Gaa,al peek wo 4S-x3D- 4,000 1¢,0M ueage w126 8 mapped - FORNIAMN PERF'd3W1998 39345 3709.1 19M BOB BDkerSml on uga<te 3250 3,936.7 3,7111 1 5 ER Baker SGl L Speda4 WlatanRader.- 3.940.1 3.714,3 19.52 SB Baker Seal Bae ReceDwGe3 260 p+el a , S6.. 34N 39469 3,7208 1950 SEP Seat Ban --37S 9495 -3 723 2 1949 P Beker SC,tLS owl BabM1wl Pa ---am .B. 3319 1947 SCREEN 3 Pa Beteraerki 140 Graeo pad ataeee 45'x,80- .990 ft.M'ga,. wRSA wrappad-FORMATION PERF'tl MWINS 410390 3.607.7 1922 SBBaker Seal Bae Razeptads ,254 4. 1. 3.6098 19.21 PACKEti aA¢Z IL pedalNda¢on Pazka 3.875 4,044. ,81 i. BR Baker S.1 Me fleue.tis 32 4,049.8 3.BI7B 19.19 SL awl Pad Slitirp Siwae 48{1 4,051,5 ,6194 1918 SBR 9m18ae ,250 -0,053.2 3. 1..1TEUR 3;k BakeweiJ 140Gea.F,&..45.3R. 4.000 ftD20"gaego b32" meppeC-FORMATION PERFd 3!5!:598 41135 IVA0 i AncMK IBaker S22 Anahor ever -637 34N 4,114.3 3.8788 18.99 PACKER jBakerSCIL SpesmlMlala,aPacke, 4.000 41..1 84.3 18.97 SBR ealare.ReceW-325 41232 3,16177 10.96 PACKER Be SVr IL e9uu kMatipn ader 4880 4,125.3 3.889.1 18.9 LEEV Gavel Pad Sfitlxry 8leew 3.480 4 1895 98P Berl 9. 3.:50 -- d,13B8Tw2w SCREEN-----) MBglerweldi40Gnvelpad n45'a3D -4 OW ftxOMggwwggee wR4Xwappetl FORMATION PERF -d, 19M 4228,91 39373 18,59 ANCHOR bow S-22 Anchor aseamWY 3430 1,2300 1 1 PAf.KER B3W i Retainer rMxlion Pxkar 32% Tobin Stmps Tap�no'ii<><�mmn sane Pa... IDrw aop In el-i.TDrou mm_sX D.nm new a., a mrrl s�,we mpcmMuiu� RIBING KJI9emg 3@ 2992 35.4 38276 36663 9,30L80 FUF, LompbtbrtDetalk topin%XI TaOI 0`aAI T..Pl YemM Cm X IIn11m 3591 M91000 HANGEP vETCOG Y PR3044NGER 2.950 iOre. A'...".- ""a xa., K" tnp lnle x Dap4m..9XD[p1h{ND1c_mDb'M GrW rpp cunnttXwl LNER STRADDLE 219 2317 ).826.2 4,9994 3.81)5 650L480 1pdnl50 Completion ONW4 rop lnxel iaprtv3607 1 } Ina �,-._.nml pr _cm d 7,60]1 IR95 FroAing twck 5'GS $rgpplYad Kr lD �p'L. SWO 3,8M3 6699 1M AN,0, I Bpker A09up L. ISM 1. Other M fbM {wlmum retticammom pwas, "Meir puns, "WK eta. lap rtvm inp iM lop era ba can Dab m lint 3961 3961 G L eze pxXeq , Y. e 39600 1816. 1999 LU RETRIF.A t 4122012 PealorappM B Slots TOpm DPmI ru,Real ...I K KAr -1571 aMl Deps 1MIeln V�e rem 9D 920 .a 3-6141 3706. WO W85/1993 120 &ERF TSPS BSPack TCP-13&45Mpgr 3.OPT 4,0300 3,141. 3,8029 V58,t A410.11B 99998 112 R 46SW 45de gph 404. , d I Y 38]47 , li 118 19 20 PERF -4-58-5U P9d:T6P 135r45 dap M1., 47g0.0 /,2290 SW].I 3,9810 -M-AT10. 11tl 3511998 120 WEkp deBW9 TCP , -13565 tlep dlphp8 Current Comotetion 1D-118 Plug and Abandon PTD # 197.229 16'62:5#11.40 Crxtcta:ior�t2t'XB �G 3,3'9.3# LM TUbirg KB SlM1g at 3827T KB U 04e a Tbg 4t IA Bieaal FiNcd to 3768' 4(11, 3% KCL Brine in Tbg 3766 -34f}3' KB, 3% KCL Edna in 7'A 3788.3029° KB hg GL#lopen) at 3798' KB Limt Top packer at 3&296' MB ,PT 0,50 L-80Liler Stmddk 30252.4049A' KB Re'aitlateAtWr- Rug at 3900' KO Perfx 3690.3432' KB 3964.4434'KB 4064 - 4t14I' KB 4149.422T KS 5.t' Grghr l Pack Liner 3825.9 -4260' KO r -SV 29,701! L-00 Ft6Abc:+oft Casing at 4574.1' KB Proposed P&A I' CA Cement Top Jab nm nl Pop 93, 71tAreicSe'. 7. IC at Surface, by to 2846 KG, IA to 296T KB nmm1 PRrg a2, iIm Cissa G. rCC ioi640'KB )ad) abave Cunt finer at 2640' KB, GC b 2005 KB i cx w1P#rga1, 8b Gari G. OC to 7877'KB ed} above Cknt irr at 3735! KB, )C to 3623" KO 4� AP 2-27.19 i THE STATE °fALASKA GOVERNOR BILL WALKER Roger Winter WI Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-118 Permit to Drill Number: 197-229 Sundry Number: 318-443 Dear Mr. Winter: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.ciaska.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, Hollis S. French Chair jc DATED this l'll" day of October, 2018. RBDMS) OCi 10 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 11 1'110(18' 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Progni Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Q Conductor Extension❑' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska. Inc Exploratory ❑ Development ❑Q . Stratigraphic ❑ Service ❑ 197-229 ' 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-0292-2839-00-00 ' 7. If perforating: N/A S. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 1D-118 - Will planned perforations require a spacing exception? Yes ❑ No ❑' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 Kuparuk River Field/ West Sak Oil Pool ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Ni Plugs (MD): Junk (MD): 4595' 4335' 3900' 3677' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface Intermediate Production 14533' 75/8" 4574' 4316' Liner 1430' 4.5" 4260' 4017' Perforation Depth MD (ft): Perforation Depth TVD (fq: Tubing Size: Tubing Grade: Tubing MD (ft): 3898'- 4229' 3675'- 3987' 3.5" L-80 3828' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) 7 packers - see schematic, no SSSV 7 packers - see schematic, no SSSV 12. Attachments: Proposal Summary Q Wellbore schematic EJ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Developments Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL Q WIND ❑ 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: Roger Winter Contact Name: Roger Mouser/Roger Winter Authorized Title: 41 Wl field Supe isor Contact Email: D1927(aconocophillips.COm Contact Phone: 659-7506 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , I Il UI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No- o Spacing Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10-41 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 d 1 D tFi V7 -L— !0/9118 RBDMS i OCT 10 2016 Q R I G I NA L Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 12018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D-118, PTD 197-229 conductor extension. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, (/t/ Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Kuparuk Well ID -118 (PTD 197-229) SUNDRY NOTICE 10-403 APPROVAL REQUEST 10-01-18 This application for Sundry approval for Kuparuk well 1D-118 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about T'. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. conocoP illips Alaska.11k;. KUP 1D-118 Well Attributes Mau An le 8 MD TD Wellbofe AVWWI FIeM Name 500292203900 WEST SAK Well3tatUe Incl(°1 Mp InN81 AR Bim IryKBI PROO 25.31 3,005.64 4,5950 Comment H35 (ppml pals SSSV: NONE 0 9rz612011 Anesna n 610 KB-Grel An Rig Rebase... last WO: ears,11 ]12000 12rz21199] Annelalon Degn InKBI Last To, Fna Dave Annotmen Laat Mae 9y Fad Data Rev Reason:DRILLDEPTHS/DATES osbotl 41162013 Casin none CaalnB essential- CONDUCTOR String 0... 16 Stene 1p... TOP In KB) Set OeptlrlL. 9.1 DePIM1INDI-Ste n9 Wl, 15.062 40.7 121.0 121.0 82.58 9trm9-Strin9 H40 TOP Thr. WELDED Casing Description PRODUCTION String 0... 7518 String ID... Top InKB) Set Depth h.. Set Damn (ND)... String WL 6.875 40.7 4,574.1 4,315.6 29.70 spino... LSO ST-9Top Tnrd ABM -BTC Caeing Description GRAVEL PACK LINER Strin9o... 5.1 9tringlD... TOP mere) Sal pepin IL.. Set pePlh(Ner ,, Strin9 Wt^ 4.000 3,829.8 4,260.0 4.016.8 13.50 Strin9... LSO s1.n9 TOP .... Seal Lock HT Liner Details Top Depth (NeI Top Incl NOmI... To RNB) (ANB) (°I Aem Description Comment IDAn) 3,829.8 3,610.5 19.85 PACKER Baker SC -i Gravel Pack Packer 4.000 3,840.] 3,620.8 19.82 SBR Baker Seal Bore Receptacle 3.250 3,845.9 3.625.7 19.80 SLEEVE Gravel Pack Sliding Sleeve 3.480 3,847.6 3,627.3 19.80 SBR Seal Bore 3.250 3889.4 3.666.6 19.67 SCREEN 3j58akelweM 140 Gravel pack screen 4.5'x30.aK.020'gauge wl2&fl 4.000 snapped- FORMATION PERF'd W611998 3,934.5 3,709.1 19.51 SBR Baker Seel Bore Receptacle 3.250 3,036.7 3,711.2 19.53 PACKER Baker SC-11-Spedal Isolation Packer 3.875 3,940.1 3,714.3 19.52 SBR Baker Seal Bore Receptacle 3.250 3945.3 3,719.2 19.51 SLEEVE Gravel Pack Shugh,; Sleeve 3.480 3,947.0 3,720.8 19.50 SBR Seal Bore 3.250 3,949.5 3,723.2 19.49 PACKER Baker SC -1 L Special Isolation Packer 3.930 3,958] 3,732.3 19.57 SCREEN 3 As 6akervreld 140 GravN pack screen 4.5130-nN.021Y' gauge w1265 4.000 wrapped -FORMATION PERFd 31611998 4,039.0 3.807.8 19.28 SBR Baker Seal Bore Receptacle 3.250 4,041.3 3,809.9 19.27 PACKER Baker S6l L Special Isolation Packer 3.875' 4,044.6 3,813.0 19.26 SBR Baker Seal Bore Receptacle 3250 4,049.8 3,817.9 19.24 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,051.5 3,819.5 19.24 SBR heal Bore 3250 4,063.3 3,030.6 19.19 SCREEN 3115 Bakerweld 140 Gravel pack screen 4.5'40.8x.02V gauge wrz64t 4.000 wrapped- FORMATION PERF'd 3/811990 4,113.5 3.078.0 19.01 Anchor Baker S-22 Anchor assembly 3.400 4,114.4 3,078.8 19.01 PACKER Baker SC -1 L Special Isolation Packer 4.000 4,120.1 3,084.3 18.99 San Baker Seal Bore Receptacle 3.250 4,123.2 3,887.2 18.97 PACKER Baker Sol L Special Isolation Packer 4.880 4,125.3 3889.2 18.97 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,127.0 3,8908 18.96 SBR Seal Bare 3.250 4,138.8 3,902.0 18.92 SCREEN 3 A Bakenveld 140 Gravel pack screen 4.5 0-ftx.020- gauge W126 -ft 4.000 wrapped- FORMATION PERF'd 3811998 4.228.91 3,987.3 18.51 ANCHOR Baker S-22Anch:ressembly 3.930 4,230.0 3,908.4 18.51 PACKER Baker Model FE -1 Retainer Production Packer 3.250 Tubina Strin s Tuang Deanlm- spine o... string lD... Topinnel set Depth lI.. Set DapihIND) string WL. smrry _. siring Top Th TUBING qII String 312 2.992 38.9 3.82].6 3,608.4 9.30 L -BO EUE Completion Details ToPDeFth INpI Top TrinnB) (nKB) bcI PI nem 10-iiComment ID (in) 36.9 36.9 -0.3211ANGER VETCOGRAY TUBINUITNUrR 2.950 iubin9 DeaOriptlan string p... Slrisin, ......... SN peINh It Set earth (TVD) String Wl... String... Japan. Top Thid LINER STRADDLE 2]18 2.377 3,826.2 4,049.4 3,817,6 6.60 L-80 Hyddl 511 Completion Details ap Put (ND) Topincl To nKB (nrca) 1°1 nem pcacnpuon Comment Noml... to (in) 3,826.2 3,607.2 19.86 Fishing Neck 5....PH.. 3.000 3,829.2 3,610.0 19.85 ANCHOR Baker 8040 Snap La6h 2.500 4,041.71 3,91031 19.215EALASSY Baker80.32 seals Assmbly 2,438 Other In Hole ireline retrievable Los. valves pumps, fish etc. TOP Depth (ND) Top bcl o (flK81 (nKB) 1°1 Description To, Comment Run Dafe ID (n) 39.fi 39.fi -0.31 DIESEL 173 bbls of diesel for Freeze protect 4/22012 3,900.0 3,6]6.6 19.54PLUG RETRIEVABLEBRIDGEPLUG 4/212012 Perforations B:Slots TOP AKIKBJ Burn (nKB) TOP(Np) (ere) Ban (TVD) IRKS) IDm Dale shin pens (=h'- Type Comment 3,890.0 3,932.0 3,674.7 3,706.7005 D, 1D-118 3/6/1998 12.0 IPERF 4.Y SWS UIpa-Pack-TCP-135/45 deg ph 3S -ma 4,034.0 3.737.3 3,803.1 WS B, WS A4, 1D-118 3/611998 12.O IPERF 4.4'SWS UWa-Pack-TCP-135145 deg ph 4,064.0 4,110.0 3,831.3 3,8]4.7 WSA3, 1D-118 31611998 12.0 IPERF 4.5'SWS UIpaPack;TCP 135145 deg phasing 4,140.0 4,229.0 3,9031 3.907.4 WS A2, 1 D-118 3/6/1998 12.0 IPERF 4.5-SWS Ultra -Pack -TCP -136145 this, ph Mandrel Details 9, N...r. nKB) Trip Deplh (ND) (BKB) Top Incl P) MCXe Meeel pp (in) sery Valw Typa laIg Type Port 91ie TR-RUn (in) (pall Run Dae Com... 1 3,186.1 3,569.4 19.98 CAMCO HBMM 1 GAS LIFT OPEN 0800 0.0 4112012 wvrd'nnllps IGERF. 3,%l�IXM 1D-118 121221199) STATE OF ALASKA AL/ OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL 9PRATIONS 1. Operations Performed: Abandon r Repair w ell E Plug Perforations J ate r Other r Alter Casing r Pull Tubing l✓ Stimulate - Frac r / r r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r" Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r T 197 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service m 50- 029 - 22839 -00 OD 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 - 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,. none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 4595 feet Plugs (measured) 3900 true vertical 4335 feet Junk (measured) None Effective Depth measured 4262 feet Packer (measured) 7 packers - see schematic true vertical 4019 feet (true vertucal) Casing Length Size MD TVD' Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 4533 7.625 4574 $LAtilt. MAY 1 8 Z01 RECEIVED Perforation depth: Measured depth: 3898'- 3932', 3964'- 4034', 4064' - 4110', 4140' -4229 True Vertical Depth: 3675'- 3707', 3737'- 3803', 3831'- 3875', 3903' -3987' MAY 012012 AOGCC Tubing (size, grade, MD, and TVD) kill string 3.5, L -80, 3828 MD, 3608 TVD Packers & SSSV (type, MD, and TVD) 7 packers - see schematic no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 96 216 54 -- 189 Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development E _, Service r Stratigraphic r 16. Well Status after work: , � r � c 3 ' ri G a s r VVDSPL r — Daily Report of Well Operations XXX GSTOR r WINJ r WAG r " GINJ r SUSP 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: none Contact Erik Nelson as 263 -4693 Printed Name Erik Nels. Title Sr. Wells Engineer Signature Phone: 263 -4693 Date PlaDMS MAY 01 2017 4 76:et0077 f - 12-- Form 10-404 Revised 11/2011 5 4 -- Submit Original Only 1D-118 Pre and Post Rig Well Work Summa DATE SUMMARY '212/12 PRE -RWO T POT- PASSED; AOPOT- PASSED; FUNCTION TESTED LD 3/5/12 PULLED SLIP STOP @ 3718' RKB. ATTEMPTED PULL PACKOFF @ 3719' RKB. IN PROGRESS. 3/6/12 PULLED PACKOFF @ 3719' RKB & ESPCP PUMP @ 3727' RKB. DEPLOY CATCHER. PULLED SOV @ 3667' RKB & REPLACED W/ DV. PULL CATCHER. COMPLETE ON 3/8- PUMPED 55 HOT DIESEL DOWN TUBING AND 170 HOT DIESEL DOWN IA. BPV installed on 3 -12. 4/2/12 * ** RIG JOB * ** SET 2.28" CATCHER (OAL =56 ") ON WRP @ 3900' MD. COMPLETE. • • ConocoPhiIlips Time Log & Summary Welwew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/27/2012 4:30:00 AM Rig Release: 4/2/2012 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/27/2012 24 hr Summary Spot rig on well 1 D -118. Spot and test support equipment. Pull BPV. Kill well. Set BPV. ND Tree. Set blanking plug. NU BOPE. Begin the Initial BOPE test 250/3000. 02:00 03:00 1.00 MIRU MOVE MOB T Prep Site, and check Pad Grade (unable to conduct site prep pre -rig due to equipment staged in front of 1D-118). 03:00 04:30 1.50 MIRU MOVE SEQP P Set T -Mats, Set Mats, Move over well, sit down and berm Up. 04:30 07:30 3.00 COMPZ WELCTL PRTS P Rig accepted at 04:30 hrs. RU Kill Lines. Load Pits. Pressure test kill lines at 250/3,000 psi - good test. Spot Support Equipment. 07:30 09:00 1.50 COMPZ WELCTL MPSP P Pull BPV with lubricator Obtain well pressures - 30 psi tbg pressure and 30 psi IA pressure 09:00 10:00 1.00 COMPZ WELCTL OPNW P Bleed gas off TBG and IA to open top kill tank 10:00 13:30 3.50 COMPZ WELCTL KLWL P Reverse circulate 160 bbls of "HOT" sea water w/ 3% KCL at 6 bpm at 500 psi - recovered 74 bbls at kill tank. Reverse another 113 bbls of "HOT" sea water w/ 3% KCL and 67 bbls of "COLD" sea water w/ 3% KCL from rig pits at 6 bpm at 500 psi - recovered 100 bbls at kill tank for a total 174 bbls. 13:30 14:30 1.00 COMPZ WELCTL OWFF P Monitor well for flow for 1 hr. - no flow - TBG and IA on vac. 14:30 15:00 0.50 COMPZ WELCTL MPSP P Dry rod in with BPV Note: Rig went on high line at 15:00 hrs 15:00 18:00 3.00 COMPZ WHDBO NUND T ND Tree, had trouble with studs backing out of DSA, unable to remove 10 seized nuts off of studs by wrench, inadequate space for nut splitter and sweeny wrench. Filled out Hot Work permit and removed with victor wrench. 18:00 21:30 3.50 COMPZ WHDBO NUND P NU 11" 5M BOP stack with 3 -12" Solid Ram Blocks in upper gate and 2 -7/8" X 5" VBR's in lower gate. RU test equipment, flood BOP stack. Page 1 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 COMPZ WHDBO BOPE P PJSM. Begin the initial BOPE test per ConocoPhillips, AOGCC requirements at 250/3,000 psi. The State's right to witness the test was waived by AOGCC Field Inspector John Crisp. 03/28/2012 Perform the initial BOPE test. Rig up to pull the 3 -1/2" ESP Completion. Pull Tubing Hanger to Floor. Circulate and condition the hole. Single down the 3 -1/2" ESP Completion. Clean and Clear Floors / Shed. Set wear ring. Load, MU and TIH with 7 -5/8" Casing Scraper /Clean -out Assembly. Reverse circulate 1.5 times BU. 00:00 01:30 1.50 COMPZ WHDBO BOPE P Continue the initial BOPE test per ConocoPhillips, AOGCC requirements at 250/3,000 psi. Test Annular to 3 -1/2" . The State's right to witness the test was waived by AOGCC Field Inspector John Crisp. Perform Koomey Draw Down Test. Good. All pressure tests were recorded on a chart. 01:30 01:45 0.25 COMPZ WELCTL SFTY P PJSM- Discussed hazards with pulling tubing hanger plugs and unlanding tubing hanger. 01:45 02:30 0.75 COMPZ WELCTL MPSP P Vetco -Gray Service Rep pull the Blanking Plug and the Back Pressure Valve, Set Side Port Isolation Sleeve. 02:30 03:00 0.50 COMPZ WELCTL OWFF P Well Integrity Rep. shoot static fluid level at —30 -ft. 03:00 04:30 1.50 COMPZ RPCOM THGR P MU landing joint. $OLDS. pull, han0Pr to floor, 155k to itn -seat hanger, 85k Up wt. 04:30 05:30 1.00 COMPZ RPCOM CIRC P Line Up Mud Pumps, circulate hot down TBG 5 bpm, ICP 380 psi taking returns up the IA, 1+ hole volume. (180 bbls pumped, 140 bbls return to kill tank) FCP 440 psi. 05:30 06:15 0.75 COMPZ RPCOM OWFF P Monitor well for flow. BDTD. well static. 06:15 13:30 7.25 3,791 27 COMPZ RPCOM PULD P POOH with ESP de completion to ESP equipment, Triple displacing. Found scale on the last 15 jts and around motor. 627- Cannon clamps 2 - Protectolizers 2 - Flat Guards 5 - SS Bands 13:30 15:30 2.00 27 0 COMPZ WELLPF PULD P Break down ESP components and lay down same. Filling hole at 20 bph rate during tear down process. 15:30 16:30 1.00 0 0 COMPZ WELLPF OTHR P Wrap ESP spool and Heat trace spool in preparation for off loading from rig floor. Clean and Clear floor. Off load de- completion. 16:30 17:00 0.50 0 0 COMPZ WELLPF THGR P Set Wear Bushng. Page 2 of 9 1 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 COMPZ WELLPFOTHR P Held PJSM with crane and crews. Conduct critical lift of Spools from rig floor. Reload New ESP and Itec wire spools in rig floor. 18:00 20:30 2.50 0 0 COMPZ WELLPF OTHR P Clean and clear pipe shed, finish off loading de- completion / clamps, Bring in Baker tools and Test plugs. Change over floors 20:30 21:15 0.75 0 25 COMPZ WELLPF PULD P Pl J MI I BHA #1 6 -3/4" Rock Bit (Jets Removed) 7 -5/8" Casing Scraper, Bit Sub, 4 -3/4" Bumper Sub, Oil Jars. Start Loading, Drifting and Tallying 3 -1/2" completion. 21:15 23:30 2.25 25 3,795 COMPZ WELLPF TRIP P TIH with BHA #1 on 3 -1/2" Drill Pipe to 3,795 -ft, kelly up to working joint. 23:30 00:00 0.50 3,795 3,814 COMPZ WELLPF CIRC P Wash down from 3.795 -ft to 3.814 -ft. 90k Up wt, 80k Dn wt. PU to 3,808 -ft reverse circulate 5 bpm. 26Q ICP, little sand across shakers. Continue to Load, Drift and Tally 3 -1/2" completion. Load completion packer and jewelry. 33/29/2012 Reverse circulate 1.5 times BU. TOOH w/ BHA #1, PU MU and TIH w/ 7 -5/8" RBPfTest Packer assembly, set down at 390 -ft. TIH w/ 7 -5/8" RBP to 390 -ft. TIH w/ 6 -1/2" and 6 -5/8" casing swages past 390 -ft. TIH w/ 6 -3/4" casing swage, sat down at 385 -ft. Load, Drift and Tally 3 -1/2" completion. TIH w/ 3 -3/8" IBP. 00:00 00:30 0.50 3,808 3,808 COMPZ WELLPF CIRC P Continue reverse circulate 5 bpm, 260 ICP, little sand across sharkers. circulate 240 bbls, 5 bpm, returns clean, FCP 350 psi. 00:30 01:00 0.50 3,808 3,700 COMPZ WELLPF OWFF P Monitor well for flow. BDTD. well static. 01:00 01:15 0.25 3,700 3,700 COMPZ WELLPF SFTY P PJSM- Discussed hazards with TOOH and laying down BHA #1 01:15 02:45 1.50 3,700 0 COMPZ WELLPF TRIP P TOOH with Casing Scraper /Clean -out assembly fron 3,700 -ft standing back DP. Up wt 90k. Lay down BHA #1. Continue to Load, Drift and Tally 3 -1/2" completion. 02:45 03:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM- Discussed hazards with MU and TIH with BHA #2. 03:00 03:30 0.50 0 36 COMPZ WELLPF PULD P PU MU RBP / Test Plug Assembly-. 7-5/8" Model "G" Lopk -set RBP. Model "L" Retrieving Head, XO, Handling Pup, Model "EA" Retrivamatic Packer L /H, XO, Handling Pup. 03:30 04:00 0.50 36 390 COMPZ WELLPF TRIP T TIH with BHA #2 on 3 -1/2" Drill Pipe, Set down at 390 -ft, unable to work by tight area. 04:00 05:00 1.00 390 0 COMPZ WELLPF TRIP T TOOH w/ BHA #2, no visible marks. Drop Test Packer from Assembly. 05:00 05:30 0.50 0 390 COMPZ WELLPF TRIP T TIH with 7 -5/8" Model "G" Lock -set RBP on Model "L" Retrieving Head. Set down at 390 -ft, unable to work by 05:30 06:00 0.50 390 0 COMPZ WELLPF TRIP T TOOH and lay down BHA #3. Confer with town engineer. Page 3 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 14:00 8.00 0 0 COMPZ WELLPF OTHR T Wait on Tools from Prudhoe. Load 4 -3/4" Drill Collars, Load Centrilift Equipment Tote. 14:00 15:30 1.50 0 420 COMPZ WELLPFTRIP T PJSM- PU MU and TIN with 6 -1/2" swedge on DP, no problem passing 390 -ft. TOOH and lay down BHA #4. 15:30 16:30 1.00 0 420 COMPZ WELLPFTRIP T PJSM- PU MU and TIH with 6 -5/8" swedge on DP, no problem passing 390 -ft. TOOH and lay down BHA #5. 16:30 17:30 1.00 0 385 COMPZ WELLPFTRIP T PJSM - PU MU and TIH with 6 -3/4" swedqe on DP, sat down at 385 -ft. TOOH and lay down BHA #6. 17:30 20:00 2.50 0 0 COMPZ WELLPF OTHR T Confer with Town Engineer. Waiting on IBP and sand from Prudhoe. Notify GYRO Rep and E -line Rep. Clean and Clear floors. Arrange completion run order. 20:00 20:45 0.75 0 0 COMPZ WELLPF OTHR T Bring in Baker IBP, warm tool before running. Bring in sand. 20:45 21:00 0.25 0 0 COMPZ WELLPF SFTY T PJSM- Discuss hazards with MU of IBP, IBP running procedures. 21:00 23:00 2.00 0 3,800 COMPZ WELLPF PULD T PU MU Baker 3 -3/8" IBP BHA #7 and TIH to 3,800 -ft. 23:00 23:30 0.50 3,800 3,800 COMPZ WELLPF CIRC T Circulate 1 pipe volume 1.5 bpm, 100 ICP, FCP 110 psi. Up wt 90k, do wt 85k 23:30 00:00 0.50 3,800 3,800 COMPZ WELLPF PLUG T Drop 1/2" ball, wait for ball to reach setting tool and for fluid temp to climatize in and around IBP. 03/30/2012 Set 3 -3/8" IBP. Dump 20 -ft sand. Tag TOS. MIT IBP / 7 -5/8" casing, good. RU E -line. Run 40 arm caliper and GYRO. RD E -line. Change out production valve on tree and test while waiting on E -line and GYRO log Interpretation. Run 6- 11/16" Swedge. 00:00 00:30 0.50 3,800 3,800 COMPZ WELLPF OTHR T Wait for fluid temp to climatize in and around IBP. 00:30 01:30 1.00 3,800 3,800 COMPZ WELLPF PLUG T Start IBP setting sequence, pressure up to 500 psi x 10 min, 1000 psi x 10 min, 1500 psi x 10 min on chart, setting tool sheared off at 2000 psi, set down 2k, IBP bottom at 3,800 -ft, S � Top of IBP at 3,789 -ft. 01:30 03:00 1.50 3,800 0 COMPZ WELLPF TRIP T PJSM - TOOH with BHA #7, lay down rt setting tools. 0 03:00 04:30 1.50 0 3,740 COMPZ WELLPFTRIP T PJSM -TIH with Bull nose on 3 -1/2" Drill Pipe to 3,740 -ft. 04:30 07:15 2.75 3,740 3,770 COMPZ WELLPF OTHR T Dump 600# ( -20 -ft) of 20/40 river sand, let settle 1 hr, TIH and Tag Of Sand at 3,770 -ft. 07:15 08:45 1.50 3,770 0 COMPZ WELLPFTRIP T POOH from 3,770 -ft standing back DP, Up wt 95k, Dn wt 80k. 08 :45 09:30 0.75 0 0 COMPZ WELLPF PRTS T Close blind rams and PT 7 5/8, 29.7 #, L -80 CSG w/ burst pressure C5.}� �, 6,890 phi to 1 500 psi t i Page 4 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 16:00 6.50 0 0 COMPZ EVALWE RURD T Held PJSM w/ HES E -line, Gyro data and Nordic Rig 3 Crew. RU E -line and MU Memory Caliper and Gyro w/ CCL and GR and RIH to 3,770 -ft and log out of the hole to surface - on surface at 15:30 hrs. RD E -line equipment. 16:00 17:30 1.50 0 358 COMPZ WELLPF TRIP T PJSM, PU and MU BHA #9 (6.688" OD CSG Swage). RIH to 358 -ft and set down, POOH 17:30 19:30 2.00 0 0 COMPZ WELLPF OTHR T Pull Wear ring, Set test plug drain stack. Change out "bad" 3 1/8" 5M production wing valve. Pull Test Plug (unable to utilize test plug due to seal ring above side port) while waiting on E -line and GYRO log Interpretation. 19:30 20:00 0.50 0 0 COMPZ WELLPF PRTS T Pressure Test production valve install against IBP to 250 psi x 5 min and 1500 psi x 5 minutes on chart, good. 20:00 21:00 1.00 0 0 COMPZ WELLPF OTHR T Clean and organize Rig floor and shed while waiting on E -line and GYRO log Interpretation. Confer with town engineer about results of Logs and path forward. 21:00 22:00 1.00 0 0 COMPZ WELLPF PULD T PJSM- Set wear bushing, bring in Baker tools 22:00 22:15 0.25 0 0 COMPZ WELLPF SFTY T PJSM- Discussed hazards with swedge casing at shallow depths, stay off rig floor, overhead, hand placement when MU of tools. 22:15 23:00 0.75 0 318 COMPZ WELLPF PULD T PU MU 6- 11/16" swedge (30" long body), 1 std 4 -3/4" DC's, Tandem Bumper Subs, Oil Jar, 2 stds 4 -3/4" DC's, Intensifier Jars. 23:00 00:00 1.00 318 410 COMPZ WELLPFSWDG T TIH with BHA #10 on 3 -1/2" Drill Pipe, sat down at 385 -ft, Up wt 53k, Dn wt 53k, attempt to work by 15 min w/ tool weight only, no joy, Kelly up, slide thru 385 -ft w/ 25k SO wt, swedge falls out at 388 -ft, PU thru with 25k over pull, work area with little change, TIH from 388 -ft to 410 -ft with no problem, PUH and continue to work 385 to 388 -ft. 03/31/2012 Continue to Run 6- 11/16" Swedge. Run 6 -3/4" Swedge. Run 6- 11/16" Swedge/ 6 -3/4" String Mill Assembly. P/T IBP x 7 -5/8" casing. Off load 3 -1/2" completion and Jewelry. Load Kill String, Drift and Tally. RU E -line. 00:00 01:15 1.25 410 2,125 COMPZ WELLPF SWDG T Continue to work 385 to 388 -ft, SO wt 25k to slide thru, 20K over pull. continue to TIH w/ BHA #10 with no visible tight areas to 2,125 -ft. Page 5 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:45 1.50 2,125 0 COMPZ WELLPF SWDG T PJSM- TOOH with Swedge assembly, Up wt 72k, Dn wt 72k, standing back DP, work area 385 -ft to 388 -ft several times, weights up and down thru tight area the same, SO 25k to pass down thru, 20k overpull to pass up thru. continue TOH, Lay down 6- 11/16" swedge. 02:45 03:15 0.50 0 0 COMPZ WELLPF PRTS T RU test equipment, Close blind rams and PT 7 5/8, 29.7 #, L -80 CSG w/ burst pressure 6,890 psi to 1,500 psi x 5 min on chart, good. RD test equipment. 03:15 04:00 0.75 0 318 COMPZ WELLPF PULD T PJSM- PU MU 6 -3/4" swedge (30" long body), 1 std 4 -3/4" DC's, Tandem Bumper Subs, Oil Jar, 2 stds 4 -3/4" DC's, Intensifier Jar. 04:00 08:00 4.00 318 410 COMPZ WELLPF SWDG T TIH with BHA #11 on 3 -1/2" Drill Pipe, sat down at 385 -ft, Up wt 53k, Dn wt 53k, 45 min to work swedge down thru until tools fell out at 388 -ft, 40k over pull to pull back up thru, continue to work area. 08:00 09:00 1.00 410 2,125 COMPZ WELLPF TRIP T TIH from 385 -ft w/ BHA #11 with no visible tight areas to 2,125 -ft. 09:00 10:30 1.50 2,125 0 COMPZ WELLPF TRIP T PJSM - TOOH w/ BHA #11 from 2,125 -ft, Up wt 72k, Dn wt 70k 10:30 11:00 0.50 0 0 COMPZ WELLPF PRTS T RU test equipment, Close blind rams and PT 7 5/8, 29.7 #, L -80 CSG w/ burst pressure 6,890 psi to 1,500 psi x 5 min on chart, good. RD test equipment. 11:00 11:30 0.50 0 0 COMPZ WELLPF PULD T Lay down 6 -3/4" Swedge. 11:30 12:15 0.75 0 323 COMPZ WELLPF PULD T PJSM- PU MU 6- 11/16 "" swedge (30" long body), 6 -3/4" String Mill, 1 std 4 -3/4" DC's, Tandem Bumper Subs, Oil Jar, 2 stds 4 -3/4" DC's, Intensifier Jar. 12:15 13:00 0.75 323 385 COMPZ WELLPF SWDG T TIH with BHA #12 on 3 -1/2" Drill Pipe, sat down at 383 -ft, Up wt 53k, Dn wt 53k, push down t 385 -ft, 7 attempts to pass 385 -ft, no joy. 13:00 13:30 0.50 385 0 COMPZ WELLPF TRIP T TOOH from 385 -ft w/ BHA #12, Lay down Swedge and String Mill. 13:30 14:15 0.75 0 318 COMPZ WELLPF PULD T PJSM- PU MU 6 -3/4" swedge (30," long body), 1 std 4 -3/4" DC's, Tandem Bumper Subs, Oil Jar, 2 stds 4 -3/4" DC's, Intensifier Jar. 14:15 15:30 1.25 318 410 COMPZ WELLPF SWDG T TIH with BHA #13 on 3 -1/2" Drill Pipe, sat down at 385 -ft, Up wt 53k, Dn wt 53k, work swedge down thru until tools fell out at 388 -ft, 40k over pull to pull back up thru. SO 15k over Dn wt to slide swedge thru tight area. 15:30 17:00 1.50 410 0 COMPZ WELLPF TRIP T TOOH from 385 -ft w/ BHA #13, Lay down complete BHA and load out Baker tools. Page 6 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 0 COMPZ WELLPF OTHR T Pull Wear Bushing 17:30 21:00 3.50 0 0 COMPZ WELLPF OTHR T Off load 3 -1/2" TTC -ESPCP completion, Centrilift and Weatherford reps witness off loading of their equipment. Load, drift and tally 3 -1/2" De- completion Tubing and GLM, left 10 ea.. of 3 -1/2" new tubing to complete Kill String. 21:00 22:30 1.50 0 0 COMPZ WELLPF OTHR T Halliburton AD -HOC crew from Prudhoe on location, 3 new crew members given Rig and Camp Safety expectation / orientation. Spot E -line equipment while continuing to load, drift and tally kill string. 22:30 22:45 0.25 0 0 COMPZ EVALWE SFTY T PJSM- Discussed hazards with rigging up and running E -line tools and equipment. 22:45 00:00 1.25 0 0 COMPZ EVALWE RURD T Bring in equipment and RU HES E -line. 04/01/2012 Run HES CAST tool. RD E -line. Wash sand, equalize and release IBP. Circulate and condition hole. TOOH w/ IBP. Run 3 -1/2" Kill String. RU Slickline, Drift 2 -7/8" Straddle Patch. RD Slickline. RU E -line. RIH w/ 2.25" WRP. 00:00 03:00 3.00 0 0 COMPZ EVALWE ELOG T RIH with HES 3 -1/8" CAST -M tool, Log up from 3,760 -ft at 45 fpm, logs y'6 4 look good, TOC at — 470 -ft, some channeling evident. 03:00 03:45 0.75 0 0 COMPZ EVALWE RURD T PJSM- RD E -line. 03:45 04:00 0.25 0 0 COMPZ WELLPF SFTY T PJSM- Discuss hazards of pulling IBP. 04:00 05:30 1.50 0 3,770 COMPZ WELLPF PULD T PU MU Baker Scoop Head Retrieving Tool assembly and TIH to 3,741 -ft, Kelly up. Tag TOS at 3,770 -ft. 05:30 09:30 4.00 3,770 3,790 COMPZ WELLPF CIRC T Circulate 550 bbls at 8 bpm at 1,100 psi, wash sand from 3,770 -ft to top top of IBP at 3,790 -ft, engage and release IBP, let element relax, Monitor well on trip tank, lost 20 bbls in reverse circulate (90 bbls) 3 times TBG volume to recover 1 -1/2 TBG volume (44 BBLS). 09:30 11:00 1.50 3,790 3,790 COMPZ WELLPF OTHR T Held PJSM on critical lift of replacing full ESP spool to Empty for next well. While maintaining 20 bph hole fill with no pipe movement. 11:00 13:30 2.50 3,790 0 COMPZ WELLPF TRIP T POOH from 3,790 -ft to surface, triple displacing. Lay down IBP - 13:30 14:00 0.50 0 0 COMPZ PLUG OTHR T Held PJSM on changing rig floor over to 3 1/2 TBG equipment and RIH PU 3 1/2 TBG. Change over equipment. 14:00 18:30 4.50 0 3,818 COMPZ PLUG PULD T PU and RIH w/ 1 joint of 3 1/2 EUE 8rd, 1 -GLM assy, 124jts of 3 1/2 TBG. Tagged up at 3,818 -ft. 2.80 -ft in on jt 125. Spaced out for wireline work.• Page 7 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 18:45 0.25 0 0 COMPZ PLUG SLKL T PJSM- discussed hazards with RU and RD of Slickline equipment. 18:45 19:45 1.00 0 0 COMPZ PLUG SLKL T RU HES Slickline lubricator. Pressure test equipment 500 psi. 19:45 21:00 1.25 0 4,000 COMPZ PLUG SLKL T RIH w/ 5 -ft x 2.25" OD Bailer to 4,000 -ft no problems- POOH, slight boble at 3,818 -ft. Rig back Slickline equipment. HES E -line spotting up unit next to Slickline unit at 20:30 hrs. 21:00 21:15 0.25 0 0 COMPZ PLUG SFTY T PJSM- discussed hazards with RU and RD of E -line equipment. 21:15 23:15 2.00 0 0 COMPZ PLUG ELOG T RU HES E -line lubricator. Pressure test equipment 500 psi. 23:15 00:00 0.75 0 4,000 COMPZ PLUG MPSP T RIH with Weight bar, CCL, Button sub, Fireing Head, 1.69" GO Shorty long stroke setting tool, Baker 5 setting sleeve, WF wireline adapter and 2.25" WRP (10.33 -ft CCL to mid element) 04/02/2012 Set 2 25 °WRP Cad 3900 -ft. CMIT 1500 psi. RD E -line. RU Slickline. Set Junk Catcher. RD Slickline. Space out, MU and Land tubing hanger w/ side port isolation sleeve. Test Packoffs. Set TWC and test. ND BOP. NU Tree and test. Pull TWC. Freeze Protect. Set BPV and test. Prep for Rig Move. RDMO. 00:00 01:00 1.00 4,000 0 COMPZ PLUG MPSP T Log up to correlate jewelry at 50 fpm from 4,000 -ft to 3,700 -ft. RBIH and park CCL at 3,889.7 -ft (10.33 -ft CCL to mid element) mid element at 3,900 -ft, set 2.25" WRP, good indication of set- POOH. 01:00 01:30 0.50 0 0 COMPZ PLUG RURD T On surface, tools look good, stand back E -line equipment. RU Test equipment. 01:30 02:30 1.00 0 0 COMPZ PLUG PRTS T Pressure Test Tubing X Casing (CMIT) 1550 psi, 15 min 1525 psi. 30 min 1525 psi on chart, bleed T /IA down to 0 psi, monitor well 30 min for No -Flow test, no flow noticed, good. 02:30 03:15 0.75 0 0 COMPZ PLUG RURD T PJSM- RD E -line and off load equipment. 03:15 03:30 0.25 0 0 COMPZ PLUG SFTY T PJSM- discussed hazards with RU and RD of Slickline equipment. 03:30 04:30 1.00 0 0 COMPZ PLUG RURD T RU HES Slickline lubricator. Pressure test equipment 500 psi. 04:30 06:00 1.50 0 3,900 COMPZ PLUG SLKL T RIH w/ 56" x 2.28" OD Junk Catcher on 2.5" GS; set on top of WRP at 3,900 -ft. POOH RD Slickline. 06:00 08:00 2.00 0 0 COMPZ PLUG HOSO T Space out and MU TBG Hanger. RIH and land hanger. RILDS 08:00 08:30 0.50 0 0 COMPZ PLUG PRTS T Pressure test pack offs at 250 / 5,000 psi for 15 minutes - good test 08:30 09:00 0.50 0 0 COMPZ PLUG MPSP T Install two way check 09:00 10:30 1.50 0 0 COMPZ PLUG NUND T ND BOPE equipment and set back on stump 10:30 12:00 1.50 0 0 COMPZ PLUG NUND T Install tree Page 8 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 0 0 COMPZ PLUG PRTS T Fill tree void with diesel and Pressure test tree and production wing valve at 250 / 5,000 psi - good test 13:30 14:00 0.50 0 0 COMPZ PLUG MPSP T Pull two way check valve 14:00 17:00 3.00 0 0 COMPZ PLUG FRZP T Held PJSM with LRS and Rig crew. RU and PT LRS lines at 2,500 psi. Pump 175 bbls at 2 bpm at 300 psi ICP and FCP. 17:00 17:30 0.50 0 0 COMPZ PLUG PRTS T PT BPV in direction of flow at 1,500 psi - No flow 17:30 18:00 0.50 0 0 COMPZ PLUG OTHR T Clean and Dress tree Final Tubing- 0 psi / IA 0 psi 18:00 20:00 2.00 0 0 DEMOB PLUG RURD T Clean Pits. Secure cellar and prep for Rig Move. (Rig released at 20:00 hours) Page 9 of 9 . • • < . , KUP '1D-118 X41 tt?CCOPliQIpS �' ' - , Wetl Attributes Max Angle & MD TD Alaska, Inc, Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Conoco h 500292283900 WEST SAK PROD 25.31 3,005.64 4,595.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV: NONE 0 9/26/2011 Last WO: 7/17/2000 12/22/1997 - - . Well Canna: - 1D - 118, 4/13/2012 1:17.34 PM Schematic - Actual.. Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SET KILL STRING, SUSPEND WELL osborl 4/13/2012 Casing Strings _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd HANGER, 37 CONDUCTOR 16 15.062 40.7 121.0 121.0 62.58 H -40 WELDED 1 > Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.875 40.7 4,574.1 4,315.6 29.70 L -80 ABM -BTC , ,l 0 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd CONDUCTOR, t' GRAVEL PACK 5.1 4.000 3,829.8 4,260.0 4,016.8 13.50 L -80 Seal Lock HT 41 -121 airliefk "' LINER G y , �,/ ' L Details , Top Depth DIESEL, 40 a V _ 1 � � (WD) Top Inc! Nomi... �, V Top (ftKB) (ftKB) (°) Item Description Comment ID (!n) 3,829.8 3,610.5 19.85 PACKER Baker SC -1 Gravel Pack Packer 4.000 GAS LIFT, 3,786 3,840.7 3,620.8 19.82 SBR Baker Seal Bore Receptacle 3.250 It 3,845.9 3,625.7 19.80 SLEEVE Gravel Pack Sliding Sleeve 3.480 1 3,847.6 3,627.3 19.80 SBR Seal Bore 3.250 Fishing Neck, 3,826 3,889.4 3,666.6 19.67 SCREEN 3 jts Bakerweld 140 Gravel pack screen 4.5 "x30- ftx.020" gauge w /26 -ft 4.000 wrapped - FORMATION PERF'd 3/6/1998 ill 3,934.5 3,709.1 19.54 SBR Baker Seal Bore Receptacle 3.250 ANCHOR, 3,829 P : : : . 1 3,936.7 3,711.2 19.53 PACKER Baker SC -1L Special Isolation Packer 3.875 IMP 3,940.1 3,714.3 19.52 SBR Baker Seal Bore Receptacle 3.250 . <l 3,945.3 3,719.2 19.51 SLEEVE Gravel Pack Sliding Sleeve 3.480 V S 3,947.0 3,720.8 19.50 SBR Seal Bore 3.250 I:. 3,949.5 3,723.2 19.49 PACKER Baker SC-1L Special Isolation Packer 3.930 s I' 3,958.7 3,732.3 19.57 SCREEN 3 jts Bakerweld 140 Gravel pack screen 4.5 "x30- ftx.020" gauge w /26 -ft 4.000 wrapped - FORMATION PERF'd 3/6/1998 4,039.0 3,807.8 19.28 SBR Baker Seal Bore Receptacle 3.250 ' 4,041.3 3,809.9 19.27 PACKER Baker SC-1L Special Isolation Packer 3.875 NI I ' I 4,044.6 3,813.0 19.26 SBR Baker Seal Bore Receptacle 3.250 4,049.8 3,817.9 19.24 SLEEVE Gravel Pack Sliding Sleeve 3.480 Q--- 161 4,051.5 3,819.5 19.24 SBR Seal Bore 3.250 ' 4,063.3 3,830.6 19.19 SCREEN 3 jts Bakerweld 140 Gravel pack screen 4.5 "x30- ftx.020" gauge w /26 -ft 4.000 wrapped - FORMATION PERF'd 3/6/1998 q - h 4,113.5 3,878.0 19.01 Anchor Baker S -22 Anchor assembly 3.400 - 4,114.4 3,878.8 19.01 PACKER Baker SC -1L Special Isolation Packer 4.000 ® 4,120.1 3,884.3 18.99 SBR Baker Seal Bore Receptacle 3.250 r- _ _ 4,123.2 3,887.2 18.97 PACKER Baker SC-1L Special Isolation Packer 4.880 if re ii l 4,125.3 3,889.2 18.97 SLEEVE Gravel Pack Sliding Sleeve 3.480 4,127.0 3,890.8 18.96 SBR Seal Bore 3.250 ii ' 'I 4,138.8 3,902.0 18.92 SCREEN 3 jts Bakerweld 140 Gravel pack screen 4.5 "x30- ftx.020" gauge w /26 -ft 4.000 wrapped - FORMATION PERF'd 3/6/1998 1 1 :; 4,228.9 3,987.3 18.51 ANCHOR Baker S -22 Anchor assembly 3.930 I 4,230.0 3,988.4 18.51 PACKER Baker Model FB -1 Retainer Production Packer 3.250 1 Tubing Strin s f Tubing Description String 0... String ID -.. Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd IPERF, - II , TUBING Kill String 3 1/2 2.992 36.9 3,827.6 3,608.4 9.30 L -80 EUE 3,9644,034 s - ` . Completion Details Top Depth (WD) Top Inc! Nomi... I Top (ftKB) (ftKB) (1 Item Description Comment ID (!n) _ 36.9 36.9 -0.32 HANGER VETCO GRAY TUBING HANGER 2.950 SEAL ASSY, It-1 Tubing Description String 0... (String ID ... Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd 4,042 LINER STRADDLE 2 7/8 2.377 3,826.2 4,049.4 3,817.6 6.50 L -80 Hydril 511 Completion Details Top Depth (WD) Top Inc! Nomi... = Top (ftKB) (ftKB) (1 Item Description Comment ID (In) - 3,826.2 3,607.2 19.86 Fishing Neck 5" GS Scoop Head 3.000 _ 3,829.2 3,610.0 19.85 ANCHOR Baker 80 -40 Snap Latch 2.500 El 4,041.7 3,810.3 19.27 SEAL ASSY Baker 80 -32 Seals Assmbly 2.438 am fir Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) r 1N Top Depth IPERF, 0 ` ® (WD) Top Inc! 4,064 - 4,110 - 02$2 ,I = Top (ftKB) (ftKB) ( ° ) Description Comment Run Date ID (in) -*►+ 39.6 39.6 - 0.31 DIESEL 173 bbls of diesel for Freeze protect 4/2/2012 3,900.0 3,676.6 19.64 PLUG RETRIEVABLE BRIDGE PLUG 4/2/2012 IIII Mandrel Details Top Depth Top Port (WD) Intl OD Valve Latch Size TRO Run It Stn Top (ftKB) (ftKB) (1 Make Model (In) Sery Type Type (in) (psi) Run Date Com... Ell 1 3,786.1 3,569.4 19.98 CAMCO KBMM 1 GAS LIFT OPEN 0.000 0.0 4/1/2012 OM ili IPERF, == _ A .d . - -- 4,140 -4,229 -_- ." Mt GRAVEL PACK` LINER, 3,830 -4,260 3 PRODUCTION, 41 -4,574 N TD, 4,595 • • ,, . s KUP 10-118 ConocoPhillips � COnouifhillips KB -Grd (ft) Rig Release Date "' 12/22/1997 Well Confi9: - 1D-118, 4/13/2012 1:17:34 PM Schematic - Actual i Perforations & Slots ... Shot HANGER, 37 Top (TVD) Btm (TVD) Dens x v ' Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 9 3,898.0 3,932.0 3,674.7 3,706.7 WS D, 1D -118 3/6/1998 12.0 IPERF 4.5" SWS Ultra- Pack -TCP- 135/45 A deg ph CONDUCTOR, 3 4 3 3 WS B, WS A4, 3/6/1998 12.0 IPERF 4.5' SWS Ultra- Pack -TCP- 135/45 a1.1z1 10-118 deg ph 3 4,064.0 4,110.0 3,831.3 3,874.7 WS A3, 1D-118 3/6/1998 12.0 IPERF 4.5" SWS Ultra -Pack; TCP 135/45 deg DIESEL, 40 phasing 4,140.0 4229.0 3,903.1 3,987.4 WS A2, 10-118 3/6/1998 12.0 IPERF 4.5' SWS Ultra- Pack -TCP- 135/45 deg ph GAS LIFT, 3,786 Notes: General & Safety End Date Annotation 8/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Fishing Neck, ) I 4/3/2012 NOTE: WELL SUSPENDED 3,826 Et ANCHOR,': 3,829 ; !: • IP E E E r I PLUG, 3,900 -_ . - I IPERF, 3,898 -3,932 _ I i i { IPERF, 3,984-4,034 = , - j SEAL ASSY, `�� 4,042 IIIII 1. MI - + IPERF, __-- _ ... 4,064 -4,110 _ ' ♦, - - r:::::. �� .4 INIIMIt ; a1 MI LIE IIIIIII q _ q 7I I'.. IPERF, - -- g .e 4,140- 4,229 = ARV GRAVEL PACK :wm-- LINER, 3,830 -4,260 1 r PRODUCTION, 41 -4,574 TD, 4,595 ' • � Page 1 of 2 • Schwartz, Guy L (DOA) From: Nelson, Erik Q [ Erik.Nelson @conocophillips.com] Sent: Wednesday, May 02, 2012 7:19 PM To: Schwartz, Guy L (DOA) Cc: Gober, Howard Subject: RE: D -118 RWO (PTD 197 -229) Guy, I'm writing to summarize our phone conversation in response to your inquiry for additional information on our recent rig workover (RWO) on 1D-118 (PTD 197 -229). The purpose of the RWO on 1D-118 was to install a second barrier above the reservoir. Originally, all West Sak 1C & 1D producers were designed as single- casing packerless electric submersible pump (ESP) wells, which meant only one barrier between the reservoir and the atmosphere. This design was based on the premise that these wells would not flow to surface unassisted; but due to a long period of injection at an I/W ratio greater than 1, this assumption was no longer valid on several of the wells. CPAI adopted a new policy which dictated that we must have two barriers between any energized fluid and the atmosphere. For well 1D-118 it was decided to pull the existing packerless ESP completion, pressure test (PT) the 7 -5/8" casing to insure it's integrity, and recomplete the well with an ESP below a feed -thru packer set below the permafrost layer. We were able to pull the ESP completion without any issue and the clean -up /casing scraper run in the 7- 5/8" casing went fine. However, when we attempted to run our retrievable bridge plug (RBP) in order to PT the 7 -5/8" casing, our assembly stacked out at — 390 ft MD. The seal ring outer diameter (OD) on the RBP is 6.67" which is the same as the seal ring OD on the feed -thru packer we intended to install. Therefore we attempted to swedge open the casing with the goal of opening the tight spot without compromising our casing integrity. These efforts proved futile and it was finally decided that we would not be able to complete the well as originally intended. In order to not throw together a hasty completion that would not satisfy our requirements we moved to secure the well in order to buy time until we could re- evaluate the wells future potential. We then ran an inflatable bridge plug (IBP) into the well in order to PT the casing. This PT was successful so we moved to secure the well with a wireline retrievable plug (WRP). We ran a 3 -1/2" tubing kill string and stabbed it into the top of a straddle patch which had been set on a previous RWO. We then set the WRP just inside the patch (2 -7/8" Hydril 511 tubing). After performing a combo mechanical integrity test (CMIT) to 1500 psi we rigged down and moved the rig off. I agree with your change to "Pull Tubing" and "Plug Perfs" in Box #1 and "Oil" in Box #16 on our submitted Form 10 -404 "Report of Well Sundry Operations ". Thank you for the opportunity to comment on this and let me know if you have any questions and /or comments. Respectfully, Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 5/3/2012 • • Page 2 of 2 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, May 02, 2012 8:30 AM To: Nelson, Erik Q Subject: [EXTERNAL]D -118 RWO (PTD 197 -229) Erik, Please supply a written explanation of what happened on the RWO ... You cannot technically suspend a well without sundry approval. I haven't read the reports yet but will try to get to it today. It appears that the RWO was stopped short of its goal ? ?? ... any submit a synopsis so I can put it in the well file and better determine what status the well should be left as . (SI , suspended, etc). Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 5/3/2012 • Z.t525 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 2, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT / CASTM with ACE Log / Plug Setting Record: 1D -118 Run Date: 3/30/2012 - 4/1/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -118 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50- 029 - 22839 -00 ACE Log 1 Color Log 50- 029 - 22839 -00 stANNI MPv 2 % 2 .012. CAST -M Field print 1 Color Log 50- 029 - 22839 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: q /1 9-, Signed: • t,91 - 2_21 2147o WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 2, 2012 Attn.: r- 1001._rA cEDk1.v1 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: CASTM with ACE Log: 1D -118 Run Date: 3/31/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -118 Data in LAS or DLIS format, Digital Log Image files _ - _ __ •• 1 CD Rom 50- 029 - 22839 -00 SLANNED MAY 62, 5 2012 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 3 Signed: • • ~~ ~~~~~~~ I~° PROAcrive DiAgNOSric SeevicES, INC. To: AOGCC Christine ib4e~rrtken 5k°r'~'a-~~ 333 West 7th Avenue ~ '~ ~;~;13 Suite 100 :'I~~~~a% '~~~'`~' Anchorage, Alaska 99501 ~°~'~'~ (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-5952 - - _ 1) MTT Report 24,Jun-10 1 D-118 1 Report 50-029-22839-00 2) MTT Report 24-Jan-10 1 D-124 1 Report 50-029-22833-00 ~~~-aa~ ±UL 26.2Q1 Signed : Date t,N . D~rr~nais~sior~ Print Name: }d ,~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorage(cr~memorylaa.com WEBSITE : www.memor*~loa.com C:\Documents and Settings\Diane Williams\Desktop\Tcansmit_Conoeo.docx i • Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. -- Well: 1D-118 Log Date: June 24, 2010 Field: West Sak Log No.: 7415 State: Alaska Run No.: 1 API No.: 50-029-22839-00 Pipet Desc.: 3.5" 9.31b L-80 EUE 8RD-M Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage inspection COMMENTS This MTT data is tied into fhe Mandrel Hanger ~ 0' Qepth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" production casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 222'. Changes in metal volume are relative to the calibration points at 59' and 165', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which indude influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates metal loss features over the intervals 9' -18', 41' - 43', 47' - 55' and 70' - 72', with their maximum metal loss indicated in all three passes list in the table below. Depth 9' -18' 41' - 43' 4T - 55' 70' _ 72' Maadmum Metal toss 5Hz 8Hz 11 °r6 390 11%4°16 12% 5% 10% 4% 10Hz 0% 0% 1% 0% A log plot of the entire 5Hz pass and an expanded log plot of ~ top 30' of the 5Hz pass are included in this report. Indications of general isolated metal toss are recorded throughout the majority of the interval logged in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the toot is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. tf all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: WM. McCrossan Analyst: HY. Yang & J. Burton Witness: J. Condio ProActive diagnostic services, Inc. ~` P.~. Box. 3369, Stafford, ~ 77}9? Phone: (281) of (888) 565-9085 Fax: (281) 565-x369 E-rrai+: BDS~a~memoryfoq.com r rude7oe Bay Field Office Pnane: (9C~?) 659-230, Fax: {907) 659-231 `~'"wE~s z and 10Hz Delta Metal Thi Hess Passes Overlay ~, A~,. 5Hz, 1 D-118 June 24, 2010 l°n°Acrivc Dinyn°siic Scwviccs Database File: d:\warriorldatalld-1181overiay.db Dataset Pathname: overlay2 Presentation Format: overlay Dataset Creation: Mon Jun 28 14:17:58 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 Joints 5Hz Delta Metal Delta Metal Thickness 20 40 Delta Metal Thickness 60 of 16" Conductor 80 100 • 120 140 160 180 200 220 Delta Metal Delta Metal Thicknes Metal -50 Delta Metal Thickness 2010 (10Wz) (%) 50 -50 Delta Metal Thickness 2010 (8Wz) (%) 50 -50 Deta Metal Thickness 2010 (5Wz) (%) 50 ``~"`WEusA~ R orded Magnetic Thickness L Data - 5Hz Pass •o o ~ ' M ~ "' 1 D-118 June 24, 2010 PaoAcrivc Oingn°sric Suviccs Database File: d:lwarriorldatal1d-11815hzpass.db Dataset Pathname: 5HzPass Presentation Format: 18 ' Dataset Creation: Mon Jun 28 14:58:172010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness {%) 50 1.8 MTTP01 (rad) 11. 0 Line Speed {ft/min) -200 -7 MTTP12 (rad) - " ~~ 7.625 Collar Line S pee Pups 5; I 3 .5" Collars ~~ 11 % M etal Loss . _. ~ ' Tubing Jt. 1 D elta Met al T hickness " Col 7.625 lar =~ 3.5" Co llar ~9~ 11 % M t l L e a os s 12% Metal Loss - Tubing Jt. 2 60 3.5" Col lar 1 0% Metal Loss ~ Bo ttom of 16" Conductor 7.625" Co lla ~ Tubing Jt. 3 t ' .5 " Cv lla ~ 100 o`~`"~E"sp~,. E anded 5Hz Pass Magnetic T ickness Log Data Qa ~ "' 1 D-118 June 24, 2010 Pw°Acrivc DinyerosTic Scwviccs Database File: d:lwarriorldatal1d-1181expanded 5hzpass.db Dataset Pathname: SHzPass ' Presentation Format: 18 Dataset Creation: Mon Jun 28 14:58:172010 Charted by: Depth in Feet scaled 1'60 ' -50 Delta Metal Thickness {°f°) 50 1.8 0 Line Speed (itlmin} -200 -7 ~~ 7.625" Line Pups 3.5" Collars ~ Delta Metal Thickness 10 11 % Metal Loss 1 -50 Delta Metal Thickness (%) 50 0 Line Speed (ft/min} -200 Tubing Jt. 1 20 30 1_8 -7 MTTP01 (rad) MTTP12 (rad) MTTP01 (rad) MTTP12 {rad) 11.8 11.8 3 `. ~`\,~ KUP ~ 1 D-118 COtIOCOPh1Ii1 IJ5 I At tribu6es __ An le a nnc to ~~,,,Y. . . .._. I (bore A PIIUWI Field Name wdi sr aars ~ too si n0. ebn pnc si-j' II 50029 2283900 WEST SAK PROD 25.31 3.005.64 4,595.0 .., .,. rCamnat SSSV: NONE HTS Ippm) 0 Date 8!27/2008 Arcaot n F Last WO: Satl Date KBGrd gq 7117/2000 Rag RNease Date 12/22/7997 olc ~ - ~ Dto eboa ` s ~ -c-Am,el - Aaraohtlon Dap M Fill Dale Amatalbn Last MOd By End Date Last Tag: Rev Reason: GLV GO Imosbor 1/5/2010 Casln grin Geeing D es n Strlrg PN Pni TuP (~®) Set epih ) (RKB) Shag t (~~) trade 8eingT ltrd CONDUC TOR 1 6 15.08 2 0.0 121.0 121.0 62.58 HAO WELDED PRODUC TION 751 8 6.75 0 0.0 4,574.0 4,315.4 20.70 L-80 ABM-BTC coNDUCroR, 12t ~~ '$~ _ TWYg D ascalpDOn SLlllg D Ia0 D String N Pao ) Top (RKBI __ galh (mod) Set Depth (TVD) (Rim) String Mlt 0bsalt) Strawy taade String Tap ltrd TUBIN 311 2 2.99 2 .0 3,790.0 3,5 .1 9.60 L-80 UESrd- other i n Hole a l Jevye l . rob in Run a R eUievabie Fkh ate. ESP MANDREL, 3 667 Tap ~ (ND) pgce) Tap Intl (•) Dexdglen f ~oaaeaaeaR Rut Date b la4 3,887 3,457.6 20.32 E SP CAMCOlKB MM-2l1lSOVl BKI2000/Comment: 1/4!2010 2.992 M ANDREL 3,725 3,5 2.0 20.16 P ACKOFF S ER K-3 KOF AND SLIP OP [TUBI G 9122/2007 1.437 STOP 1.5`ID] PACKOFF, 3, 2 3,518.6 20.14 UMP SET Centrili tt ES P OG RESSIVE CAV PUMP 9120/2007 0.000 37zs -" (80TP2000) on 9202007 3,763 3,547.7 .0 N I PLE AVA 3.5°slo tted nipple 7h 72000 2.69 3, 8 3,552.4 20.03 S L ESP SEAL /i7/2000 0.000 PUMP 3 732 _ 3.783 3.566.5 19.99 M OR PCES Mator 57 H 1315 26 KMW 7/172000 0.000 , , ~'~ ~ I 3,785 3,568.4 19.98 G AUGE BAlCFR SEN TRY GAUGE 77172000 0.000 NIPPLE, 3,763 ' 3,825 3.606.0 19.86 P ATCH BAKER Patc h 7!172 0 ~~ Pertora tfons 3 S ltris Top (1VD) Ben 11V~ snot Dens ~ Tap Ben 1~i 1~s1 ~a Zane Date (sh.. type Comment 1 3,898 3,932 3,674.7 3,706.7 WS D, 1D-118 3!6!1998 12.0 IPERF 4.5" SWS Ukra-Peck; TCP 135145 ''`a '~I deg phasing 3,964 4,034 3,737.3 3,803.1 WS B, WS A4, 3!6/1998 12.0 IPERF 4.5" SWS Ulha-Pack; TCP 135145 sEOa 3 768 1 D-118 deg phasaag 4,064 4,110 3,831.3 3,874.7 WSA3,10.118 3l 1998 12.0 IPERF 4. 'SWS Ultra-Padc;TCP 135/45 deg phasing 4,140 4,229 3,903.7 ,987.4 WS A2, 10.118 3!6!1998 12.0 IP RF 4. "SWS taae-Pack; TCP 135!45 dsg phasing GAUGE, 3,785 MOTOR. 3,783 ",, [( ~ '}. IPERF, ~ 3.8983.932 ,~ PATCH,3825 S WERF, - 3.964.1.034 ---'-~ - ~ s ee IPERF, ~ >'3 4,060.-077D eea IPERF, H 4,1404,229 s PRODVCTION, 4,574 TD.4.595 RECEIVED OE;r'25 2016 13; db '?61431?125 PD5 C~R~' Jun 251007:454 PD5 Prudhoe ~ 19072314 p.~ f ESP TUBING DETAIL FOR MULTI LATERAL TTCESPCP,~Heat Trace 1 D-118 DATE. Q7/17;66 PHiLUPS ALASKA, INC. 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF ELIUIPMEN7 RU;V ;LENGTH DEPTH TOPS i i 1 Parker Rig 245 RT to LDS 36,94 36.94 -iGR ABB Veico G,ay Tbg H2nger 1.50 3.58 36.44 Pt.`P ;Space cut pups( 7.93'..8"J 3..74 40.52 Jls_# 3-i 20' 3 1 i2" 9.3# ~ 80 EUE 8,~d Mod Tbg. sfi' 2.80 49.26 PUP 3 1/2" 9.3# L-$0 cU~ $rc Mod Pu 5.68 3ssz.06 GLM 3 112" X 1" Cameo KBNM w; OK-1 Dummy GLM (Run Open j 6.85 36G7.74 PUP 3 ' /2' 9.s~f L-t30 EUE Ere Mod ?up 6.10 3674.59 ,lt ~ 2 3 '!2"' 9.3# L-80 EUE 8^d Mod Tbg. 3' .45 3680.68 .!` ;~ 1 3 '!2" 9.3# L-$0 EU1= 8Yd Mod Tbo. 3' ~n 3712.14 PUP 3 1!2' 9.3~ L-80 clsE 8rc Mx Pup 10.11 3743.00 PUP 3 1'e" 9,3~` L-80 EUE 8*c PJx ?up 10.11 3753.71 3 112" Slotted Nipple 3.08 3763.62 t3 1;2" Tubirg TTC XO 1.42 3766.90 - ESP Seal Section GST3 4B 1!. H6 PFS - 5.130 O+J 13.76 3768.32 ESP ;Gearbox 9:1 525 Series -5.25" OD 1-32 3782.66 ESP PCESP Motor 57 HP 1315126 KMH - 5.62" 4D 6.79 3783.40 Motor Centralizer (Baker Sentry Gauge X37135 ' MD 3569' TVD) .60 3790.19 3794.19 HeatTraee Cable Marts 16' up from the "Pin" end Jt# 22 RavChem Cable Length " t7 - "a' Heat Trace F~a cuaras 1 - 3' Heat 'racy =1a: guards C - 4' Meet Tra4s Fla; guises 5 Total Flay 3ar+.ds ---- Centrilift 2 - Protcctoi+zers and 2 - F`at guarc+s up to PALE ;Flies Carron Super Clarnps - 627 total 20 - Single channe x-couc'~ing 98 - ^ua: charnel x-couoiing ~ 1 -Dual channel end shoe c amp 1 2 - 2' IIMiC jcinl dual channr~'' 19 - 3' Aiid joint dual charnel <v - ~ .u,iu rv, i~ ui.c~ t.ua~ars.. ~u - 7 MW jVll ii C:Ud Gf ;c7H'C1 Reorarks~ Str;nc_, 4lieigh[s v~ t~ Blocks' SSK~# Uc, 55K~ Dn. 20K# B"ocks. Rar '20 joints of tuo rg. Drell t~~hirg, Gl.tti". 8 hangar raith 2.867" plastic ra~E:it, LsESI +rrc`,ic Grace A;=t 1Aodified No lead t~~ead cornpaund on al ccnrect;crs. Tabing is ron-mated. Nordic Rig fzs Drr;!,'rtg Suparv;scr Den :^'est~r ~ Brian tl'~e' R~GcIVt=Ta 66~'25J2616 16:46 281431'125 Jun ?~ 1 D t~7:45e PDS Prudhoe t _. PHILLIPS ALASKA, [NC ~`D5 wORP 19072314 TU61NG TALLY p.~ PAGE: 1 of 2 WELL NUMBER: 1 Q-118 Kuparuk River Unit RIG: Nordic Rig ~3 TL81NG DESCi21PTION: 4-tit", 12.6#, L-80, NSCT, Non-Coaled Range 2 -Class A QATE: 7117100 Column 1 Cotumn Z Cotumn 3 Column 4 Column 5 Cbturrm 6 Column 7 Column B No Feet No Feet Nb Fset No Feet No ' Feet No Feet No Feet No Feet 1 31.46 26 31.5E . 51 31.52 T6 ! 30.5 101 30.51 126 i5f 176 2 3'.45 27 3`.»9 52 i 31.4n 77 3'.4fi 102 3'.47 127 152 177 3 31.46 28 3'.d6 53 31.49 T8 j 29.62 103 ?9.53 128 153 178 , 4 ,i 1.»5 29 31.50 ' S4 31.50 e'9 is' .5$ i 04 30.60 129 1$4 179 ', 5 ' 31.42 30 31.45 ' SS 3'..d1 80 31.46 105 ;}1.4s 130 155 1$a 6 ' 3~.2fi 31 31.47 56 3".4$ d1 + 31.50 106 29.59 131 156 181 7 ! 3t.42 , 32 30.b5 57 28.52 82 j 31.49 107 29.43 132 157 i 182 8 29 3$ ' 33 31.40 58 31.52 , 83 '32.48 108 30.70 133 ~ t 58 ! t 83 9 31.53 " 34 31.58 59 34.54 84 31.4'/ 109 2$.36 134 } 159 184 10 3G 23 ~ 35 30.39 60 3?.49 85 3',.54 110 c9.4C 135 ; 160 185 11 3G.47 36 37,33 6t 34.58 86 37.5E 111 30.57 136 161 186 12 31.41 , 37 j '19.75 62 27 ~1 87 31,59 112 30.54 137 162 187 13 30 2.i ' 38 j 30.5:1 63 3 t .39 88 31.52 113 31.51 138 ~ 183 :188 14 31 50 39 ' 3" .•12 84 ; 29.64 89 29 ~ 1 114 _ 29.30 139 ~ 1 fi4 189 15 29.E ', 40 3'..47 65 28.18 90 29.06 , 115 28:33 140 165 190 16 29.Sa ' 41 s?.48 65 31.49 91 30.:0 ' 118 30.50 141 166 191 17 31.35 42 31,c1 67 31.44 92 i 31.59 117 29.89 '~ 142 167 t9Z i8 30.53 43 29.33 68 29.36 93 ~ 31.61 118 31.40 143 168 193 19 ; 31.41 44 .28.59 69 28.45 94 ! 3C 6C i 19 28.55 144 169 194 20 ; :I".47 45 30.03 TO 29.37 95 31.52 120 28.95 145 170 195 21 j 31.42 48 3'..48 71 29.9 96 ~ 3C.55 121 146 171 198 22 30.17 4T 3'.1` 72 27.7? 97 31.19 .. 122 147 17Z 197 23 31.53 46 30,49 73 31.5C 98 29.n0 '.123 148 173 198 24 28.93 49 31.51 74 29.55 99 31.54 ' 124 149 174 199 25 31 41 k 50 37.43 75 2s. •7 10C 28,55 123 , 150 175 200 Tot 771.27 Tot T73 55 Tat 756.58 7oi 7'3.78 Tot 6~JG.43 Tot Tat Tnt TOTAL LENGTH T}iIS PAGE = 3575.7 i TOTAL Jt?INTS THIS PAGE = 12Q Ult{tG I IONS. .«~IO'2«~.* Heat trace starts 2' up €rcm pir erd ~^ ;tom 33 . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \ q1~ 'J..?-~ SQ~NED JUL 1 J 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft cal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/912007 10-103 202-096 5" na 8 6/9/2007 1O-105a 201-202 25" na 38 6/912007 10-106 197-240 2" na 3.2 61912007 10-107 200-177 2" na 3.2 619/2007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/9/2007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/9/2007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/9/2007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 Permitto Drill 1972290 DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. KUPARUK RIV U WSAK 1D-118 Operator PHILLIPS ALASKA INC. APl No. 50-029-22839-00-00 MD 4595 TVD 4335 Completion Dat 7/17/2000g...-" REQUIRED INFORMATION Mud Log N._9 Completion Statu 1-OIL Current Status 1-OIL UIC N Sample No Directional Survey __ No----,-", i.,,; .,_ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Interval Run OH I No Start Stop CH 71 4554 Open (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 1/14/1998 08222 71-4554 Ti' MWD SRVY DGR/EWR4-TVD DGR/EWR4-MD 8222 OH FINAL 121 4331 OH FINAL 109 4590 OH 1,2 OH 1/14/1998 SPERRY 0.-4595. 1/14/1998 121-4331 1/14/1998 109-4590 1/14/1998 8222~ ..... ~PERRY MPT/GR/EWR4 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/i,'~,~ Chips Received? ...... Y'¥"R ........ Analysis ~.,Y../.,,N ..... RP. cP. ivP. d? Daily History Received? '...,Y.,./.)N Formation Tops ,~,.)/N Comments: 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 BI Abandoned r-1 Service E~ 2. Name of Operator 17. Permit Number Phillips Alaska, Inc. ..,---,--,,,-- 97-229 / 300-161 3. Address ~LO~--..~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 V~ 50-029-22839-00 4. Location ofwell at surface ,-. . . ~ 9. Unit or Lease Name -'~ B.~I~;~ i' Kuparuk River Unit 106' FNL, 597' FEL, Sec. 23, T11N, R10E, UM (ASP: 560491, 5959559) :.' ~ ' ~ ~10. Well Number At Top Producing Interval ~'' ~ ;-/"? :-'~'~:~ 1 D-118 At1040'TotalFSL'Depth633' FEL, Sec. 14, T11N, R10E, UM (ASP: 560444, 5960707) ~. ,,~.i''~u¢;;/_~'~i~;':: ..... . 11. Field and Pool 1210' FSL, 648' FEL, Sec. 14, T11N, R10E, UM (ASP: 560428, 5960875) :~ ........ Kuparuk River Field i5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease D~ignation and Serial No. West Sak Oil Pool RKB 37 feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if o~hore 16. No. of Completions December 17, 1997 December 19, 1997 July 17, 2000I WA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey 120. Depth where SSSV set 21. Thickness of Permafrost 4595' MD/4335'TVD 4262' MD/4019'TVD YES ~ No ~I WA feetMD 1635' 22. Type Electric or Other Logs Run G~CDR 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD ~ CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5¢ H-40 Su~ace 121' 24" 9 cu yds High Early 7.625" 29.7¢ L-80 Sudace 4574' 9.875" 354 sx AS III LW, 335 sx Cla~ G & 60 sx AS I 24. Perforations open to Production (MD + TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 3791' WA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3831'-3875' MD 3831'-3875' TVD 12 spf 4140'-4229' MD 3903'-3987'TVD 12 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 25, 2000 Flowing Date of Test Hours T~ted Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/7/2000 6.0 Test Period > 45 18 2 100~ 406 Flow Tubing Casing Pr~sure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) pr~. 15o psi not available 24-Hour Rate > 181 73 8 not available 28. CORE DATA Brief d~cription of lithology, porosi~, fracture, apparent dips and presence of oil, gas or water. Submit core chips. 000 ORIGINAL A~o~oe Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak West Sak A3 Base West Sak GEOLOGIC MARKERS MEAS. DEPTH 3892' 4056' 4359' TRUE VERT. DEPTH 3669' 3824' 4111' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-I-rACHMENTS Summary of Daily Operations 32. I hereby certify that the following is true and correct to the best of my knowledge. Queslions? Call Brian Noel 265-6979 Signed _' ~'~"~~~ .... Randy Thdmas Title Kuparuk Drillinq Team Leader Date ~' ~/~ ' /OW INSTRUCTIONS Prepared by Sharon A//sup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on ail 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ¢-~, ._¢,~. ~ ~, ¢.,~:' ~ Item 28: If no cores taken, indicate "none". Form 10-407 · , .......... '~.du L,,0~;S. ,,u: .,-.' .......... ;~nch0ra.r. ir¢ Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS _ -- WELL:iD-118W0 RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:07/12/00 START COMP:07/12/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22839-00 07/12/00 (C1) TD: 4444' PB: 0' 07/13/00 (C2) TD: 4444' PB: 0' 07/14/00 (C3) TD: 4444' PB: 0' 07/15/00 (C4) TD: 4444' PB: 0' 07/16/00 (C5) TD: 4444' PB: 0' NU BOP MW:10.3 BRINE SUPV:DON WESTER & BRIAN NOEL Accept rig ~ 1530 hrs. 7/12/00. Pull BPV. Pre-kill safety meeting. Pump warm seawater down tubing. POOH W/ MULE SHOE STINGER MW: 0.0 BRINE SUPV:DON WESTER & BRIAN NOEL Kill well. Set BPV and ND tree. Test BOP to 250/3000 psi. CBU and monitor well, hole taking 4 bph. POOH. RIH w/fishing BHA ~1 and tag up ~ 3843'. CBU, oil but no sand in returns. POOH. RIH w/2-3/8" mule shoe joint & 2-3/8" PH-6 to clean out inside screen assembly. RECOVERED 2-7/8" PUP JT. MW: 0.0 BRINE SUPV:DON WESTER & BRIAN NOEL Continue RIH w/3.5" drill pipe to 3843'. Clean out inside GP screens from 3843'-4025' (top of fish). POOH. RIH with BHA #3 and tag fish at 4025' Engage fish w/spear and begin working pipe. Slide to 4040' Check for flow and POOH wet. No fish and grapple missing. RIH w/BHA #4 and tag fish at 4026' Latch fish and begin working pipe. POOH. LAY DOWN 3-1/2" DRILL PIP MW: 0.0 BRINE SUPV:DON WESTER & BRIAN NOEL POOH w/2-3/8" tubing and fishing tools. RIH to fish gravel pack seal assembly. Tag at 4031'. Latch fish and work w/jars. POOH. Full recovery of fish. RIH w/clean out BHA to 3829'. Wash down through gravel pack assembly from 3829' to 4262'. Pump out of hole above SC-1 packer. Reverse circulate BU. Lost brine while reversing. Some carbolite in returns. POOH. PJSM. RUNNING 3.5" ESP COMPLETI MW: 0.0 BRINE SUPV:DON WESTER & BRIAN NOEL RIH w/straddle pack assembly on 3.5" drill pipe. Land 2-7/8" straddle. POOH. PJSM. Test packoff w/1000 psi, OK. RIH w/ESP 3.5" completion. Start Raychem heat trace on joint #22. Continue running completion. Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/17/00 (C6) TD: 4444' PB: 0' YEARLY RIG MAINTENANCE. MW: 0.0 BRINE SUPV:DON WESTER Continue RIH w/ESP completion. Space out Raychem heat trace. Splice Centrilift ESP cable to BIW penetrator. Set BPV. N/D BOPs. N/U tree. test pack off 250/5000 psi, OK. Test tree to 500/5000 psi, OK. Pump diesel down annulus. Set BPV and secure well. Release rig for yearly maintenance @ 2000 hrs. 7/17/00. PH*-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 17, 2000 Mr. Daniel T. Seamount Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 1D-118 (97-229) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 1D-118. If there are any questions, please contact me at 265-6830 or Brian Noel at 265-6979. Sincerely, R. 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WEST SAK / 1D-118 500292283900 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121997 MWD SURVEY JOB NUMBER: AKMM80052 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4528.75 4272.19 4160.79 17 38 N 4.68 W 4595.00 4335.33 4223.93 17 38 N 4.68 W .29 1296.38N .00 1316.39N 50.72W 1297.36 52.36W 1317.43 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1317.43 FEET AT NORTH 2 DEG. 16 MIN. WEST AT MD = 4595 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 357.52 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 4,595.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. WEST SAK / 1D-1i8 500292283900 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121997 JOB NUMBER: AKMM80052 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.40 1000.00 999.27 887.87 2000.00 1940.71 1829.31 3000.00 2847.90 2736.50 4000.00 3770.70 3659.30 .00 N .00 E .00 8.52 N -14.67 E .73 .73 328.51 N 30.17 E 59.29 58.56 748.09 N .21 E 152.10 92.81 1129.60-N 35.55 W 229.30 77.21 4595.00 4335.33 4223.93 1316.39 N 52.36 W 259.67 30.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. WEST SAK / 1D-118 500292283900 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121997 JOB NUMBER: AKMM80052 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.40 111.40 111.40 .00 211.40 211.40 100.00 311.40 311.40 200.00 411.40 411.40 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .20 S .16 E .00 .00 .35 S .16 E .00 .00 .67 S .08 E .00 .00 511.40 511.40 400.00 611.40 611.40 500.00 711.41 711.40 600.00 811.47 811.40 700.00 911.65 911.40 800.00 .65 S .04 W .00 .00 .40 S .12 W .00 .00 .16 S 1.15 E .01 .01 .42 S 4.23 E .07 .06 1.12 N 9.90 E .25 .18 1012.27 1011.40 900.00 1113.95 1111.40 1000.00 1216.33 1211.40 1100.00 1319.62 1311.40 1200.00 1423.87 1411.40 1300.00 10.29 N 15.22 27.86 N 20.33 48.76 N 26.83 73.58 N 33.82 102.63 N 38.32 E .87 .62 E 2.55 1.68 E 4.93 2.37 E 8.22 3.29 E 12.47 4.25 1529.51 1511.40 1400.00 1637.47 1611.40 1500.00 1747.40 1711.40 1600.00 1857.56 1811.40 1700.00 1967.76 1911.40 1800.00 136.58 N 39.72 177.23 N 39.39 222.86 N 37.72 268.94 N 34.60 315.11 N 31.07 E 18.11 5.63 E 26.07 7.96 E 36.00 9.93 E 46.16 10.15 E 56.36 10.20 2077.74 2011.40 1900.00 2187.80 2111.40 2000.00 2298.02 2211.40 2100.00 2408.12 2311.40 2200.00 2518.15 2411.40 2300.00 360.81 N 28.03 406.62 N 24.52 452.75 N 19.93 498.66 N 16.06 544.42 N 12.67 E 66.34 9.99 E 76.40 10.05 E 86.62 10.22 E 96.72 10.10 E 106.75 10.03 2628.39 2511.40 2400.00 2738.68 2611.40 2500.00 2849.11 2711.40 2600.00 2959.62 2811.40 2700.00 3070.24 2911.40 2800.00 590.76 N 10.50 637.23 N 8.28 683.96 N 5.00 730.87 N 1.55 778.02 N 2.11 E 116.99 10.24 E 127.28 10.29 E 137.71 10.43 E 148.22 10.51 W 158.84 10.62 3180.72 3011.40 2900.00 3291.11 3111.40 3000.00 3400.59 3211.40 3100.00 3509.79 3311.40 3200.00 824.87 N 5.41 871.51 N 8.59 915.92 N 12.34 959.65 N 15.85 W 169.32 10.48 W 179.71 10.39 W 189.19 9.48 W 198.39 9.20 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 5 ARCO ALASKA, INC. WEST SAK / 1D-118 500292283900 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121997 JOB NUMBER: AKMM80052 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3617.84 3411.40 3300.00 1000.29 N 20.59 W 3724.48 3511.40 3400.00 1037.07 N 24.93 W 3830.93 3611.40 3500.00 1073.33 N 29.07 W 3937.10 3711.40 3600.00 1108.75 N 33.14 W 4043.17 3811.40 3700.00 1143.89 N 37.19 W 206.44 8.05 213.08 6.64 219.53 6.45 225.70 6.17 231.77 6.07 4148.89 3911.40 3800.00 1178.03 N 40.49 W 4254.52 4011.40 3900.00 1211.90 N 43.65 W 4359.80 4111.40 4000.00 1244.70 N 46.43 W 4464.96 4211.40 4100.00 1277.12 N 49.14 W 4569.89 4311.40 4200.00 1308.81 N 51.74 W 237.49 5.72 243.12 5.63 248.40 5.28 253.56 5.16 258.49 4.93 4595.00 4335.33 4223.93 1316.39 N 52.36 W 259.67 1.18 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD {FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ' 1~ Typ~ o~ i~questi-- A~ndon ~ '-- Suspend _ ---- Operational-shutdown_ Re-enter suspended well _X Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program Pull tubing _ Variance _ Perforate _ Re-completion 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 41 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 106' FNL, 597' FEL, Sec. 23, T11N, R10E, UM 1D-118 At top of productive interval 9. Permit number/approval number 986' FSL, 627' FEL, Sec. 14, T11 N, R10E, UM 97-229 At effective depth 10. APl number 50-029-22839-00 At total depth 11. Field / Pool 1209' FSL, 648' FEL, Sec. 14, T11N, R10E, UM Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured 4595 feet Plugs (measured) true vertical 4335 feet UI11 UlI / L Effective depth: measured 4444 feet Junk (measured) true vertical 4166 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 4533' 7.625" 354 sx AS IIILW, a35 sx Class G 4574' 4315' & 60 sx AS I Production Perforation depth: measured 3898'-3932', 3964'-4034', 4064'-4110', 4140'-4229' JJN 20 2000 true vertical 3675'-3707', 3737'-3803', 3831'-3875', 3903'-3987' AJ88ka Oil & Gas Corm. Commission Tubing (size, grade, and measured depth 2.875", 6.5#, L-80 @ 3656' Anchorage Packers & SSSV (type & measured depth) Baker SC-1 pkr @ 3829', Baker SC-1L isolation packer @ 3936' & 4041' & 4117', Baker FB-1 sump pkr @ 4114'& 4232' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 14. Estimated date for commencing operation 15. Status of well classification as: June 30, 2000 16. If proposal was verbally approved Oil__ Gas __ Suspended __X Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Brian Noel265-6979 Signed ~ - ~---~-J"--- Title: Drilling Engineering Supervisor Date Chip Alvord Prepared b~/ Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity__ BOP Test ~ Location clearance__I 300 -" J,'~ Mechanical Integrity Test _ Subsequent form required 10- ~¢"~ Approved by order of the Commission i-~ "r,vlnr ~pgm¢~Jf~¢ ,O9f _ .. om.missioner Date . Form 10-403 Rev 06/15/88 · ,/ SUBMIT IN TRIPLICATE West Sak 1D-118 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: . RU Slickline unit and RIH with dual gauges to obtain SBHP at +/- 3975' MD (mid A4 sand pen's). Set BPV in tubing. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: . , , , . . , , 10. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV. Displace well with seawater. Shut in and determine kill wt fluid requirements. Load pits and displace well with kill weight brine. Ensure well is dead. ND tree. NU and test BOPE. POOH and lay down 2-7/8" kill string. PU 3-1/2" drill pipe and fishing assembly. RIH and recover 30' gravel pack tool fish. RIH with tapered string and clean out inside screens to PBTD. RIH and set straddle pack-off assembly to isolate D & B sand interval, POOH laying down drill pipe. PU 3-1/2" tubing and run ESP completion. ND BOPE. NU and test tree. Displace well with seawater and freeze protect with diesel. Lower Limit: Expected Case: Upper Limit: 5 days No problems fishing or running completion. 6 days 8 days Difficulties fishing or setting straddle pack assembly. BDN 6/15/00 ,.JUN 2 0 2000 Gas Cons, Post Workover Depth's sh~n are W/L Depth. Nordic depth is W/L depth - 7'. 3-1/2" Vetco-Gray Tubing Hanger 3-1/2" L-80 EUE 8rd Mod tubing w/ESP completion PC pump and heat trace D-Sand Perforations 3/4" 12 SPF 3,898' - 3,932' (No Frac) A4 / B Sand Perforations 3/4" 12 SPF 3,964' - 4,034' (No Frac) A3 Sand Perforations 3/4!' 12SPF 4,064' - 4,110' (14K lbs proppant away) A2 Sand Perforations 3/4" 12 SPF 4,140! - ~,229~ (I58K lbs propp~n! away) 7-5/8" 29.7# L-80 BTC Mod @ 4574' MD Baker SC-1 Packer @ 3,829' MD Baker Straddle Pack Seal Assembly run on 2-7/8" Hydril 511 tubing to isolate D & B sand perfs Baker SC-IL Packer @ 3,936' MD Baker SC-1L Packer @ 4,041' MD Baker FB-1 Packer @ 4,114' MD Baker SC-1L Packer @ 4,119~ MD Baker FB-1 Packer @ 4,232' MD PBTD @ 4444' MD BDN 6/15/00 7-1/16" 000 psi BOP Stack-- h, rdic Rig 3 Kuparuk River Unit Operations Kill Line ] Choke Line 12. 13. Accumulator Capaqity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Te~t 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. Open-top pipe rams and close ~aottom-pipe rams. Test bottom-rams - to 250 psi and 3000 psi for 3 minutes. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. Test stan-dpipe v,~Nes to 3000 psi'f6~:'~'rninutes. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Pedorm BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one q" m,r~t~rt nel i-Iyrira~ ,lit, nat,', ~nH nne _"3." r-,riCt(3 riel K/lanl i~l n~f~ ~ Kill vnlv~__~ - v v... i~, ........... ~ ................ r ........... ~---, ................ are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, '10/01/98, v.2 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY June 19,2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Subject: West Sak 1D-118 Application for Sundry Approval to Re-enter Suspended Well Dear Sirs: Attached for your approval is Sundry Form 10-403 to re-enter the suspended West Sak 1D-118 and complete as per the workover summary procedure. In March 1998 while completing the well with a multi-zone frac pack (4 separate intervals), the inner wash string became stuck. Attempts to fish all the inner string were unsuccessful and Nordic #2 moved to other projects while options were evaluated. Well 1D-118 was left with kill weight brine in the wellbore, a string of open ended 2-7/8" tubing to 3656' MD, and a BPV installed in the tubing hanger. Due to tight 1999 budget constraints and full rig schedules, sundry approval to suspend was granted in January 1999. Phillips Alaska, Inc. plans to use Nordic #3 to resume fishing operations on about July 3, 2000. The workover will fish the remains of the inner string, clean out the wellbore to PBTD, and install a straddle pack assembly to isolate the A4/B and D sand intervals. An ESP completion will be run and the well produced from the already stimulated A2 and A3 sand intervals. A new multi-lateral well (1D-140) will be permitted and drilled later this summer to access the bypassed A4/B and D sand reserves. If there are any questions or additional information is required, please call Brian Noel at 265-6979. Sincerely, C. Alvord Drilling Engineer Supervisor AAI Drilling CA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~.. ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown X Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Plugging__ Perforate__ -- __ Repair well __ Other __ 5. Type of Well: Development X Exploratory -- Stratigraphic _ Service -- 6. Datum elevation (DF or KB) RKB 41' feet 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 8. Well number 106' FNL, 597' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 986' FSL, 627' FEL, Sec. 14, T11N, R10E, UM 1D-118 9. Permit number/approval number 97-229 At effective depth At total depth 1209' FSL, 648' FEL, Sec. 14, TllN, R10E, UM 10. APl number 50-029-22839 11. Field/Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner measured 4595' feet Plugs (measured) true vertical 4335' feet measured 4444' feet Junk (measured) Fish @ 3829' true vertical 4166' feet Length Size Cemented Measured depth 80' 16" 9 CY High Early 121' 4531' 7.625" 354 sx AS III LW & 4574' 335 sx Class G & 60 sx AS I Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3898'-3932',3964'-4034',4064'-4110',4140'-4229' 3675'-3707',3737'-3803',3831'-3875',3903'-3987' 2.875" 6.5# L-80@3656' True vertical depth 121' 4315' ~'~ ~acka Oil & Gas Cons. Cor~ill~issioli Anchora je Baker SC-1 pkr @ 3829', Baker SC-IL isolation pkr @ 3936' & 4041' & 4117', Baker FB-1 sump pkr @ 4114' & 4232' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations -X Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A Tubing Pressure 16. Status of well classification as: Water Injector__ Oil Gas Suspended X Se~ice 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ~.~,__ ~",~_ /~,~' r "~. ~'. J1 o~- Title West Sak Team Leader Form ~-404 Rev 05/17/89 ' Date I I,,.I ,J SUBMIT IN DUPLICATE Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-ii8 WELL ID: AK9005 TYPE: -- AFC: AK9005 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: SPUD: START COMP:03/05/98 RIG:NORDIC # 2 WI: 0% SECURITY:0 API NUMBER: 50-029-22839-00 BLOCK: FINAL:03/29/98 12/17/97 (D1) TD: 1010' (1010 SUPV:DEB 12/18/97 (D2) TD: 3505' (2495 SUPV:DEB 12/19/97 (D3) TD: 4590'(1085 SUPV:DEB 12/20/97 (D4) TD: 4590'( SUPV:DEB 12/21/97 (D5) TD: 4590'( SUPV:DEB 12/22/97 (D6) TD: 4590'( SUPV:DEB MW: 9.0 rISC: 350 PV/YP: 28/47 APIWL: 10.2 DRILLING AT 1650' Move rig 45' from 1D-119 to 1D-118. Accept rig @ 0300 hrs. 12/17/97. NU diverter system and test. Spud at 121' and drill to 1010' MW: 9.1 VISC: 286 PV/YP: 32/52 APIWL: 7.2 DRILLING AT 3950' Drill from 1010' to 3349' MD. Small amount of oil on bottoms up from drilling break @ 3162', in top of Ugnu. Also seeing some oil increased and gas cut to 8.8 ppg while drilling at 3349'. Drill to 3505' MD. MW: 9.2 VISC: 258 PV/YP: 33/46 APIWL: 5.8 RUNNING 7-5/8" CASING Drill from 3505' to 4590' MD. MW: 9.3 riSC: 60 PV/YP: 18/17 APIWL: 10.4 CLEAN OUT 7-5/8" CASING Safety meeting. Run 7-5/8" casing. Pump cement. MW: 6.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED MOVE TO 1D-115 NU BOPE. Drill out plug, stage tool at 1894' and 4' cement. Drill out cement from 4252' to plug on baffle plate at 4444' PBTD. Test casing, OK. Freeze protect well. ND BOP stack. MW: 6.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Install Vetco Gray tubing hanger. NU tree and test to 5000 psi. Secure well. Release rig @ 0200 hrs. 12/22/97. Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:ID-ii8 WELL ID: AK9005 TYPE: AFC: AK9005 STATE:ALASKA 22839-00 AREA/CNTY: NORTH SLOPE EAST FIELD: SPUD: START COMP:03/05/98 RIG:NORDIC # 2 BLOCK: FINAL:03/29/98 WI: 0% SECURITY:0 API NUMBER: 50-029- 03/05/98 (C7) TD: 4590' PB: 4444' 03/06/98 (C8) TD: 4590' PB: 4444' 03/07/98 (C9) TD: 4590' PB: 4444' 03/08/98 (CiO TD: 4590' PB: 4444' 03/09/98 (Cll TD: 4590' PB: 4444' 03/10/98 (C12 TD: 4590' PB: 4444' CIRC/FILTER COMPLETION FL MW: 8.7 KCL SUPV:DLW Wait on Dowell for pickel. Turn key rig move from 1D-105 to 1D-118. Accept rig for operation at 0300 hrs 3/5/98 POSITION TCP POOH @ 0600 MW: 8.7 SUPV:DLW Position TCP-Guns Perforated Zone f/ 3898' - 4229' Circulated & POOH @ 0600 hrs. POOH L/D BHA. KCL RI W/BAKER BETA-FRAC PACK MW: 8.7 KCL SUPV:DLW rop ahor @ 3898' thru 4229' POOH PJSM L/D fired TCP-GUNs. Log on depth and set top of sump packer @ 4232. RIH W/3-1/2" MULE SHOE MW: 8.7 KCL SUPV:DLW Clean out corbolite from string down to top of 2-7/8" fish @ 3613' Break down data frac, and fraced A2 zone w/158, 000 % sand behind pipe FISHING BAKER FRAC ASSEMB MW: 8.7 KCL SUPV:DLW Stuck 111' inside screen assembly & 57' above top 'SC-I' Pr @ 3827' Nordic depth. Top of fish @ 3779', Bottom @ 3938' Nordic depth. POOH L/D overshot and fish 5 joints 2-7/8' 6.4# IJ4S tbg + cut off. Total fish recovered 166.99' Top of fish now @ 3799' LATCHED ONTO 3 1/4" FISH MW: 8.7 BRINE SUPV:MC LD 44.29' of 2 7/8" FL4S and overshot assembly and MU 3 1/4" short catch overshot assembly. POOH w/ short catch overshot assebly standing back 3 1/2" PH6. Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/11/98 TD: 4590' PB: 4444' C13) 03/12/98 TD: 4590' PB: 4444' C14 03/13/98 TD: 4590' PB: 4444' C15 03/14/98 (C16 TD: 4590' PB: 4444' 03/15/98 (C17 TD: 4590' PB: 4444' 03/16/98 (C18) TD: 4590' PB: 4444' 03/17/98 (C19) TD: 4590' PB: 4444' IN HOLE/ATTEMPT BALL RETR MW: 0.0 SUPV:MC PU kelly. Tang & latch onto fish @ 3823' Attempt to work fish free while circ without success. Perform blind backoff. Recover 9.1' of 3 1/4" fish. Made 4 runs w/ Bailer removing fracc sand without making significant progress. More sand than anticipated. RIH W/ 3-1/8" SPEAR. MW: 8.7 BRINE SUPV:MC RU to circ & reverse out Frac Sand from top of Packker & Fish. Made 5 runs w/ various type of ball catchers. Caught ball on final run. POOH standing back 3-1/2" X-95 DP. POOH W/ FISH. MW: 8.7 BRINE SUPV:MC RIH w/ fishing assembly #7. RIH w/ stands T/3856' and single in to 3886. Tag and latch fish. POOH standing back 3-1/2" DP & LD BHA used for cleanout. RU E-LINE ATTEMPT W/CHEMI MW: 8.8 BRINE SUPV:MC PU kelly (70k up, 63k dn). Tag and latch into fish @ 3916' Fish pulled free w/ 240k pull. Lockout Tagout Safety Meeting w/ Gary Haught. Made 2 attempts to enter top of fish without success. LAY DN FISH TOOLS &SC-1 P MW: 8.8 BRINE SUPV:MC POOH and MU 2.35" Swedge. RIH w Swedge and open top of fish. Tag and latch into fish @ 3922' Work pipe & jar on fish until free. Repair spool valves n #1 hydraulic bank. MU Baker SC Packer Retrieving Tool and fishing assembly #10. RIH W/ 4-JOINTS 6-3/8" PI MW: 8.8 BRINE SUPV:MC POOH slow - packer swabbing. LD fishing assembly and 44.76' of fish (Baker SC-1 Packer Assembly and 16.01' of 4-1/2" Blank Joint.) Run #7: 2" RB Pulling Tool, Mule Shoe Bell Guide, De-Centrilizer Tool. Enter 4-1/2" blank joint and latched onto fish. POOH to 200' w/ Schlumberger CCL and 3-1/8" chemical cutter. Jar from 100k to 225k and pull up to 250k. Pulled free while jarring @ 200k. L/D 3.25" BAKER SEAL ASSY MW: 8.8 KCL SUPV:DLW POOH to fish. L/D Fish recovered 61' of Baker screen assy & 17.05' of Baker seal assy. Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 03/18/98 (C20) TD: 4590' PB: 4444' 03/19/98 (C21) TD: 4590' PB: 4444' 03/20/98 (C22) TD: 4590' PB: 4444' 03/21/98 (C23) TD: 4590' PB: 4444' 03/22/98 (C24 TD: 4590' PB: 4444' 03/23/98 (C25 TD: 4590' PB: 4444' 03/24/98 (C26 TD: 4590' PB: 4444' ON BOTTOM W/BAKER SCREEN MW: 8.8 KCL SUPV:DLW Continue to pull tight w/ bottom of seal assembly in SC-1 Packer @ 3933' Work fish up and down from free to tight spot in packer. Hydril rubber failed. R/U and change rubber & seals. PULLED ALL OK L/D FRAC TO MW: 8.7 KCL SUPV:DLW PJSM. RIH on 3.5" workstring to 3831' RIH & locate sliding sleeves w/ smart colet. Faound A3 sliding sleeve @ 4063' on depth. RIH PACKER AT 3492' O.K. MW: 8.7 KCL SUPV:DLW Move 3.5" 15.5~ X-95 DP f/left side of derrick to right. PJSM on chemical cutters. R/D RIH w/ 3.193" spear seal bore receptacle of other packer half. Tool lost in hole21.5' long w/ 1-3/8" Otis fishing neck Walt on slick line unit. FISHING FOR CHEMICAL CUTT MW: 8.7 KCL SUPV:DLW POOH slowly to fish. Total fish recovered. Recovered packer element & 4-1/2 of 6 compression rings. Run drift to 4062' POOH W/ 6" IMPRESSION BLO MW: 8.7 KCL SUPV:DLW Fish for Schlumberger GR/CCL chemical cutter @ 4092' P/U Kelly rotate & try to mill out tight spot, BTM of mill 4014', BTM of anchor 4021' unable to clean out. POOH (SLM) Found damage to pin end of mill only. Looks like 4" ID. POOH MW: 8.7 KCL SUPV:DLW Continue to POOH w/watermelon mill. Found damage to 3.5" IF sholder ID 4" OD 4.5". No marks on mill section. RIH with impression block. Stab into fish @ 4017' Fish coming up hole free, swabbing continue to pull through perforations. POOH. Recovered packer and screen assembly down to 4119' TESTING BOPE MW: 8.7 BRINE SUPV:MC RIH with string mill to 4093'. Unable to engage packer. POOH, observed damaged threads on latch assembly with a small piece of junk (packer ring) wedged to one segment. RIH with sump packer. Set packer at 4107' Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 03/25/98 (C27) TD: 4590' PB: 4444' WAITING ON HEC FRAC FLUID MW: 8.8 BRINE SUPV:MC Set packer @ 4107' Test BOPE @ 300/3000 psi. RIH w/2-7/8" frac pack assembly. Set isolation packers. Pump three series of flow tests and begin data frac. Zone screened out w/14000% behind pipe. Reposition 2-7/8" frac pack assembly for B-sand frac. 03/26/98 (C28) TD: 4590' PB: 4444' MU 1.25" CS HYDRIL MW: 9.2 BRINE SUPV:MC Perform impulse test. Pump data frac. Begin frac, began getting returns up annulus. Shut down when proppant observed in returns. Pull up 5', pipe jumped (parted) PU to reversing position and reverse circ 1 hole volume. Heavy frac sand in returns. Pull assembly above liner top. 03/27/98 (C29) TD: 4590' PB: 4444' RIH W/3.5" PH6 WORK STRIN MW: 9.3 BRINE SUPV:MC/B Continue to monitor well and filter 9.3 kill weight brine into pits. Displace well with brine. POOH with PH6 work string. Well flowing. Reverse circulate to balance uneven fluid in wellbore. Wash from 3843' to 3931' while reverse circulating to cleanout carbolite. RIH with fishing assembly. Tag and latch top of fish @ 3837'. Worked fish free. 03/28/98 (C30) TD: 4590' PB: 4444' FREEZE PROTECT WELL W/DIE MW: 9.3 BRINE SUPV:MC/B POOH with fish. RIH with 2-7/8" tubing. Land kill string @ 3656'. ND BOPE. 03/29/98 (C31) TD: 4590' PB: 4444' RELEASE RIG MW: 9.3 BRINE SUPV:MC/B ND BOPE. NU tree, test packoff and tree to 5000 psi. Freeze protect well. Release rig @ 0800 HRS. 3/29/98. STATE OF ALASKA ALASK,. OIL AND GAS CONSERVATION COMMI,-,olON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend X __ Alter casing __ Repair well _ Change approved program__ Operation Shutdown Re-enter suspended well __ Plugging __ Ti~me extension Stimulate __ Pull tubing __ Variance__ Pe-rrorate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic__ Service 6. Datum elevation (DF or KB) 41' RKB feet 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 106' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM At top of productive interval 986' FSL, 627' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 1209' FSL, 648' FEL, Sec. 14, T11N, R10E, UM 8. Well number 1D-118 9. Permit number 97-229 10. APl number 50-029-22839 11. Field/Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: measured 4595 (approx) true vertical 4335 Effective depth: measured 4444 (approx) true vertical 4166 Casing Length Size Structural Conductor 80' 16" Surface 4531' 7.625" Intermediate Production Liner feet feet feet feet Plugs (measured) Junk (measured) Fish @ 3829' Cemented Measured depth 9cuyds High Early 121' 354 sx AS III LW & 4574' 335 sx Class G & 60 sx AS I True vertical depth 121' 4315' Perforation depth: measured 3898'-3932', 3964'-4034', 4064'-4110', 4140'-4229' true vertical 3675'-3707', 3737'-3803', 3831'-3875', 3903'-3987' Tubing (size, grade, and measured depth) 2.875" 6.5# L-80 @ 3656' Packers and SSSV (type and measured depth) Baker SC-1 pkr @ 3829', Baker SC-IL isolation pkr @ 3936' & 4041' & 4117', Baker FB-1 sump pkr @ 4114' & 4232' 13. Attachments Description summary of proposal X Contact Chip Alvord at 265-6120 with any questions. Detailed operation program__ BOP sketch X 14. Estimated date for commencing operation January 22, 1999 Oil 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed /,/~~ ~'. ~',~ ¢,. ~. t,~. ~'~i~-.~.) Title West Sak Team Leader / FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended X Date Conditions of approval: Notify Commission so representative may witness IApproval Plug integrity BOP Test Location clearance Mechanical ln~grity Test_ Subseque~-form require 10-/,~.O~ ¢4-~"~ ¢,~)0~'~' O~~O~~~''' .~ ;~.~"-O"[ '~. Approved by the order of the Commission Form 10-403 Rev 06/15/88 uc,\qu W. ouhr!s-~or. Commissioner Date /'D-~ 'C~ SUBMIT IN TRIPLICATE &oproved 0ot3¥ ' Re'tUrboed 1 D-118 Current Status Depth's shown are W/L Depth, Nordic depth is WIL depth - 7: D-Sand Perforations 3/4" 12 SPF 3,898' - 3,932' (No Frac) A4 / B Sand Perforations 3/4" 12 SPF 3,964' - 4,034' (No Frac) A3 Sand Perforations 3/4" 12 SPF 4,064' - 4,110' (14K lbs proppant away) A2 Sand Perforations 3/4" 12 SPF 4,140' - 4,229' (158K lbs proppant away) 3~1/2" Vetco-Gray Dummy Tubing Hanger w/back pressure valve installed in tubing hanger 2-7/8" L-80 EUE 8rd Mod tubing (dead string) hung open ended @ 3,656' MD Baker SC-1 Packer @ 3,829' MD Baker SC-1L Packer @ 3,936' MD Top of fish @ 4,039' MD Baker SC-1L Packer @ 4,041' MD Bottom offish @ 4,069' MD Baker FB-1 Packer @ 4,114' MD Baker SC-1L Packer @ 4,119' MD Baker FB-1 Packer @ 4,232' MD ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Request for Shutdown of Well Operations for KRU 1D-118 (West Sak) Dear Blair, Per the attached sundry, ARCO Alaska, Inc. would like to apply for Shutdown of Well Operations status on West Sak well 1D-118. The well, a West Sak producer, was being completed as a multi-zone frac pack (4 separate zones) in March of 1998. The frac pack completion system is designed to stimulate all the separate zones in a single trip of the work string. As the inner wash pipe was being cycled between zones it became stuck while tripping between the 2nd and 3rd zones in preparation of stimulating the 3rd interval. Nordic #2 attempted to fish the inner wash string unsuccessfully from March 9th 1998 until March 28th 1998 (22 days) at which point the rig was moved over to complete well 1D-117 and also allow time to re-evaluate options for the well. 1D-118 was left with the wellbore loaded with kill weight brine, a kill string of open ended 2-7/8" tubing to 3656'MD and a BPV installed in the tubing hanger. Due to extremely tight 1999 budget constraints ARCO Alaska, Inc. finds it necessary to laydown GKA drilling rigs that do not have long term contractual commitments as soon as possible in order to conserve this years capital spending for wellwork performed by rigs that do have long term contracts. The rig that had been working the West Sak completions, Nordic #2, is one of the GKA rigs that does not have a long term contractual commitment and needs to be stacked as soon as possible. ARCO Alaska, Inc. proposes to leave 1D- 118 in the Shutdown of Well Operations mode until some rig time becomes available on Nordic #3's schedule (one of three core GKA rigs), 1999 capital permitting. Tentatively this work would likely occur during the 3rd Quarter of this year. Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling Attachments: Form 10-403 Form 10-404 Well Schematic iD- 118 (West Sak) Daily Reports: Nordic #2 on 1D-118 (3/5/98 - 3/29/98) n FI I I_1_1 I~ G S E I:t~./I ~- G S WELL LOG TRANSMITFAL To: State of Alaska January. 14, 1998 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-118, AK-MM-80052 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22839-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company D !:t I I-I-- I rtl 13 s E FIU'I r- Ei S WELL LOG TRANSMITTAL To-- State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 14, 1998 RE: MWD Formation Evaluation Logs 1D-118, AK-MM-80052 The technical dam listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-118: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22839-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22839-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 0 I::! I I--I-- I I~ G 13-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-118 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 4,595.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 15, 1997 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit West Sak 1 D- 118 ARCO Alaska, Inc. Permit No: 97-229 Sur. Loc.: 106'FNL, 597'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc: 1207'FSL, 666'FEL, Sec. 14, T11N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA . AL :A OIL AND GAS CONSERVATION COl' SSlON PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Reddll lb TypeofWell Exploratory F~ StratigraphicTest FI Development Oil X Re-Entry Deepen Service E~ Development Gas [-'] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 106' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1036' FSL, 647' FEL, Sec. 14, T11N, R10E, UM West Sak 1D-118 (E5) #U-630610 At total depth 9. Approximate spud date Amount 1207' FSL, 666' FEL, Sec. 14, T11N, R10E, UM 12/21/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-04 4626' MD 666' @ TD feet 12.1' @ 1200' feet 2560 4291' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1250' feet Maximum hole angle 36° Maximum surface 1436 psig At total depth 1887 psig (TVD) 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 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 4585' 41' 41' 4626' 4291' 450 Sx Arcticset III & 320 Sx Class G & 60 sx AS I E E ~', r", !,, r" I"~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. L r.. ! v E IJ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetDEC - 199 ' Effective depth: measured feet Junk (measured) true vertical feet ,J~;~l. ski~ 0il & Gas Cons, Commission Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate 'Production Perforati~inn~repth: measured 0RIGINAL true vertical . 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe ' ~~}/'~'//'/~'/~/~~-~~~i~s s :it~esio e Chi ~rilling Superintendent Date Permit Number APl number _ _ ..-. I Approval d_ate . ... /..~..~ See cover letter for ~- ~__.~__.~' 50- ~2.'~--- 2..Z Fir*O' 7 I /,~ - /..~, '" ~"./ other requirements Conditions of approval Samples required E~ Yes I~ No Mud Icg required E Yes ~- No Hydrogen sulfidemeasures [~Yes [~No Directional surveyrequired ~]Yes ~ No Required workingpressureforBOPE~r--12M~ 3M [~ 5M [~ 10M [~ 15M Other: by order of /C;;,~ /,.~.... ,/~ U;'igir;,al $i,~riOd By Commissioner the commission Date Approved by r~,,,~,~ ~ ,., , Form 10-401 Rev. 7-24-89 d W, Joh ston Submit in triplicate Drill and Case Plan for West Sak 1 D-118 (E5) Frac-Packed Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . Run and cement 7-5/8" 29.7# L80 BTC-MOD casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,0~.psi. Pick up 6-3/4" mill tooth bit, 4-3/4" drill collars, and 3-1/2" drill pipe. Trip in and drill out stage collar. Clean out to PBTD. , Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. , Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Nipple down BOP stack. Install production tree and pressure test same. Set back pressure valve. 11. Secure well and release rig. TAB, 12/01/97 Page 1 Completion Plan for West Sak 1D-118 (E5) Four-Staqe, Sin.qle-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. . Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. ! Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. , Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. ! Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. , Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. , Use diesel cap and/or void tubing to achieve desired underbalance. Pressure up on annulus and fire guns. , Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. . Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D Page 2 Stage 1 10. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set gravel pack packer and all isolation packers. Rig up and pressure test frac equipment at surface. 11. Position frac-pack crossover tool as required. Perform data frac for Stage 1. 12. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. 13. Shift crossover tool, and gravel pack Stage 1. 14. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 2 15. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. 16. Position frac-pack crossover tool as required. Perform data frac for Stage 2. 17. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. 18. Shift crossover tool, and gravel pack Stage 2. 19. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 3 20. 21. 22. 23. 24. Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 3. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Page 3 StaRe 4 25. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. 26. Position frac-pack crossover tool as required. Perform data frac for Stage 4. 27. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. 28. Shift crossover tool, and gravel pack Stage 4. 29. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 30. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. 31. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 32. Pick up Centrilift ESP on 2-7/8" production tubing. 33. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 34. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 35. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 36. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 37. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 38. Release rig and turn well over to production. TAB, 12/01/97 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-118 (E5) Drilling Fluid Tyl3e Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 35-70 8-15 10-25 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 10.0 ppg 35-70 20-35 10-25 10-35 5-7 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-118 (E5) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSl-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,667' MDFFVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base in the West Sak 1D-118 (E5) well to surface, the following MASP can be computed: MASP = (4,103 ft)(0.46 - 0.11 psi/fi) = 1436 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Following the clean out operation with the completion rig, a frac-pack completion will be installed, after which the ESP pump, power cable, heat trace and production tubing would be installed. Page 2 Drillinq Area Risks: Drilling risks in the West Sak 1D-118 (E5) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1 D-118 (E5). Well Proximity Risks: The nearest existing well to West Sak 1D-118 (E5) is KRU 1D-04. As designed, the minimum distance between the two wells would be 12' at 1200' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-118 (E5) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 2-7/8" production tubing and prior to the completion rig moving off of the well. TAB, 12/01/97, Rev. 1 Page 3 Creete~ by fin~ For: T MeKAY Dote ~.atted : 28-Oct--g7 Plot Reference is ¥/~ 1D-118/E5 Version ~4. Coord/notes ore in feet reference slot ~118. True Vertical DepChs ore reference ~a(Pl (Porker 250 500 750 lOOO 1250 1500 RKB ELEVATION: 112' ARCO ALASKA, Inc. Structure : Pad 10 Well : E5 Field : Kuparuk River Unit Location : North Slope, Alaska 357.52 AZIMUTH 1143' (TO TARGET) ***Plane of Proposal*** KOP TVI)=1250 TMD=1250 DEP=0 3,50 BEGIN TURN TO TARGET 1-VD=1421 TMD=1421 DEP=O 5.98 7.57 B/ PERMAFROST TVD=1633 TMD=1635 DEP=12 10.16 1750 2O00 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 250 TD LOCATION: 1207' FSL, 666' FEL SEC. 14, TllN, RIOE 2OO I <- West (feet) 100 0 100 TD - g Pt Bose West Sok Sands TARGET - A3 Top West Sek Sond~ End Angle TARGET LOCATION: 1036' FSL, 647' FEL SEC. 14, T11N, RIOE TARGET TVD=3817 TMD=4122 DEP=1143 NORTH 1142 WEST 50 Begin Angle Drop Top Ugnu Sands ~ 13.17 DLS: 3.50 deg per 100 16.38 ~,, 19.68 \ 2~.o4 MAXIMUM ANGLE ~26~is 35.99 DEG 'h, 53.29 W0:2409 TMD=2479 DEP=519 EOC ~ T/ UGNU SNDS ~D=297~ TMD=3177 DEP=728 55.36~BEGIN ANGLE DROP ~D=5057 TMD=5279 DEP=788 32.36 % 29.37~ Bose Permefros( z~.d/ ~ Begin Turn to Torget~ DLS: 5~0 ~ lO0 ft 26.37~ 90 Az 23~7 20.37 ~END ANGLE DROP WD=3526 TMD=3812 DEP=1037 T/ W SAK SNDS ~D=3667 TMD=3962 DEP=1088 TARGET - W SAK A3 TVD=3817 TMD=4122 DEP=1143 B/ W SAK SNDS ~D=4~05 TMD=4426 DEP=1247 TARGET ANGLE ~ TD - CSG PT TVD=4291 TMD=4626 DEP=1815 20 DEG I I I I I I II I I I I 0 250 500 750 1000 1250 1500 Vertical Section (feet) -> 1400 1300 1200 11o0 100o 900 800 700 600 50O 400 300 200 i OO 1 aa Z 0 Azimuth 357.52 with reference 0.00 N, 0.00 E from slot #118 Created by finch For: T McKAY Dote ~ekted : 28-0ct-97 Plot Reference is ¥~ 10--118/E5 Version #4. Coordinates ore in fe~ ~ference slot ~118. T~e Ve~icol Oep~s are ref~ence ~B (P~rk~ ~245) Al?,C 0 ALASKA, Inc. Structure : Pad 1D Well : E5 Field : Kuparuk River Unit Location : North Slope, Alaska 28O 260 240 220 20O 180 160 140 I 120- 20 2O East (feet) -> 40 120 1 O0 80 60 40 20 r ~ ~ [ "~&l 100 ,, ',, ",, -,, '~, 1000 / ,, '~ 9OO 300 ~" '~ 800 "~ 700 ',. 600 '-~ 30o .' ,'.Y900 /--~,~]~ 600.// ~,/ i 2300 300 ..-'8oo/,,' i /2aa 14OO 1300 2OO -'~~300 22OO 2100 : 2000 700 f '-... ¢1900 /"" "-- ~ goo '-.. 600 I · '"-...500 / //' "-,~00 1800¢ 500 4OO 400 ~- ' 1600 1500 300 ~ ...... ~ 1500 '-~ 900 "-~ 800 , 2100 300 ....... .~ 2000 .......... . 1900 .... .._t8oo ...... ~._!.7oo ........ .~3oo 1400 1500 .......... 1300 ............................. 80 1 O0 120 140 160 180 ~ ~ [ I ] t [ ] [ r r ~ 280 26O /.· 1 700 ...--'~'1 O0 1700 ...... ~ t 600 ........................... 240 22O 200 180 16O 140 ~300 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 East (feel) -> 120 1 aa 80 6O 20 8O Z 0 A C~ot,a ~y n~ch For: T McKAY Dote plo~ted : 28-0ct-97 [ Plot Reference is V/5 1D-118/E5 Version ~4. [ ARCO ALASKA, Inc. Structure : Pad 1D Well : E5 Field : Kuporuk River Unit Location : North Slope. Alosko 96O 920 880 840 800 760 720 680 A I 640 .-.I,-,, 6OO (- 560 0 52o 480 - 440 - 400 - 360 320 280 240 East (feet) -> 240 200 160 120 80 40 0 40 80 120 160 200 240 280 320 360 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 2sooL ~ 3000 2700~ 26oo\ 2900 2500 1 2800 \',, 2300 '\" _ 1 2700 "\,i\iO0 2200t "\\ 1899.99 ~ x,\ ~8oo ',,,. ,\,400 ,6ool : ooi ',,,, , oo\ ,' 2300/ ,' / / / , / ,, 2200/ · / / 1,300 , 2100,." ! ! / / · 2000/ / ,, / / · / / ,' 1900/ ,' , / 200 / ,, ,/ / 1800 ,/ ,' ,' ,' " ,' 400 ·/ 1700/" ,,,-'" ,300 · ,,/1400 , 1600 200 ~-~ · 2400 ~, '~ 1200 , ' ' , '"',,,~ i oo ",, 1 4, I I I'~1 I ~ ~2300 I i I I I I I I I i I i I i i i 240 200 160 120 80 40 0 40 80 120 160 200 240 280 320 360 East (feet) -> 96O 92O 880 840 8OO 760 720 680 640 6OO 560 52O 480 440 4OO 360 320 28O 240 Z 0 OS~T 08~ O'08& 08~ 0'08~ 009 0'009 00£ 0'00£ 006 0'006 08£ 0'08£ 009~ 0'08~ 08£ 0'08£ 000~ O'O00T 08£ 0'08£ 09~ O'09~T OS~T O'OS~T 09~ 0'09~ 089 0'0~ O~D O'O~D 088 0'0~ 00~ O'O0~T 090T O'090T O0£T O'O0£T ODO£ O'ODO£ .~.~ GT P~'SD''£# uoTgaaA §D/IZT-CT S~ GI P~a'AD''D# uoTs=sA £~/SET-~I S~ GT P~'££''£# uoTs:aA E£/6gT-CT SM GT P~6'EO''£# uoTs=sA ED/DET-CT SM GI P~6'AH''D# uoTs:aA 4H/AIT-CI SM =I P~6'9a''£# 'SMSA 9~/0ZT-~T S~ ~T P~'9''<,0T98-0> CT P~a'E''<,0A08-0> ~T P~6'S''<,0£68-0> CT p~a'B-S~''AaA.~ns OD&OZ ~T P~a'T''<,S9£8-0> q~dIIa~ ~aa[qo · D'£BD '6'a ,~sTa~ n~ Xq pa~DTpuT a:~ ~aa~ 000T ~req~ s~aI ~o SHON-k~U~H~D DHISX~HHOH= M 00'A6S S 00'90I aa~ s~q~uTpaooa I~aoI ~T£'9£ 0£ 6DT~'£L~'0 8i 0L= s~ uo~DoI 9£~'9S S 0ST~'9LS'ST 9I 0Lu uo ps~uSD S~ 80~zdoad : ;~m mno -~. H 0 6 H H H D 1~ ~ H ~ H q D H D bi ~f-~- S I ~ ~ fl H I 1~ I ~ ~-£ BIT# ~OTS · Dui "krHskrq~ ODH~ West Sak 1D 118 (E5) Proposed Co i letion Diagram Four (4) Stage Frae-Pack 2-7/8" Production 'Tubing 16" Conductor Casing (~ 80' Raycbem Heat Trace (through permafrost) Weatberford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3500 psi Shear circulafin9 valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section ESP Gearbox Centrilifl ESP Motor Section Centdlitt D Sand Frac-Pack Assembly with Screen Bake~ Oil Tools B + A4 Sands Frac-Pack Assembly wi[h Screen B~ker OII Tools A3 Sand Frac-Pack Assembly with Screen Baker Oil Tools A2 Sand Frac-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Surface/Production Casing ~,~- 29.7# L-80 BTC-MOD (Cemented to Surface) ARCO Alaska, inc. TAB, 12/01/97, Rev.1 KUPARUK RIVER UNIT- WEST S~K OPERATIONS 20" DIVERTER SCHEMATIC 6 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 4 3 HCR MAINTENANCE ~ OPERATION 'UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 2(7'- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 0 0 ZZ ~ ~ w o ~ o~ ~ 0 0_-- . ~,^~oo ~~0~o 0 w<~ D.~OMm~W~ ~D±wOuO~'mm ~N~OWO~w ~~w~w~ I-- W I- ,,,, I-- (/) 0 O~ ~ ~ 0 ~wOW~ 8~ 5 DO mR~ .~ ~mO0. ~ _~0~~ 0 ~0~~ P~o~m ~--~0 o~ ~oZ~nO ~O~W 0 -- ~Z~ ~w~Z~ ~~0~ 0 www~w~ 0 0 ~ w Z ~ 0 O_ 0 Z ~ 0~00~ x 8o8~8 id 'llNn XX ]lnOOYt OL ' S~O~{QS S~-~NN~Td S~{33NION.~ ~ ~ NOI.WIAltdO.-INI NOIJ. VOO9 Ol~ S3/ON ~03 ~ ~ .L..R3HS 33S :ON ON~V~JO /..6/Z~0/6 ! Oli~OLgN'l 'ON 3"11...,I 00¥3 'OUl 'e lselv O08V NO//V~07 WoJOnONOO tM3N · SWoI 3nONO3 ONU SIX3 0 0N3~37 37V35 ON 37/t'V I = ,, l :37vos d t?'~l A I INIO IA S/t-IX L-~¥$ .LS3~ SOVZ:GOZ6N #SS)t ~13d I'IINS-SY NOI. LdI~I~)S 30 ~ 8 ['S'( -. ~ g 0 t~L i OEt 6it /.tt · C~tL ~ ~6 (~gOL t Q 0-~ 'S'O _ poo~ Od j blr¥ I/.6//.L/6 Z: I SOV[80Z6)l //8S:X ~t3d ~lnS-sv I NOII cll~OS3d I tidy 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. D.S. B 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-6) C r~..., 0 MONUMENTS PER LHD AND ASSOCIA TLS. '~ 9 ~ARI ~ ~ ~ '~ ~4 ~ 2~, TO,SHIP 11 NOR~, RANGE 10 EAS~ U.M.~ --~~ 5. DRILL SITE 1-0 GRID NOR~ IS ROTA ~D 00' 01' 05" ~ST FROM A.S.P. ZONE 4 GRID NOR~. ~ ........ ~.~ ..... ~ ~CINITY MAP No. ,y, A.S.P.s 'X' LA TI TUDE LONGITUDE ~ ~ i ELE~ ELE~ , 105 5,959,798.99 : 560,490.57 70' 18' 02.6~7' 149' 30' 36.263" I~4' 595' 70.5' 62.0' 106 5,959,76&93 560,490.67 70' 18' 02.341' 149' 30' 36.268" 104' 595' 70.4' 62.3' 109 5,959,72~.89 560,490.60 70" 18' 01.898' 149' 30' 36.280' 59' 596' 70.4' 62.7' S~c. 23, T. 11 N.,.R. 10 E. FN.L:F.E.L. , 115 5,959,603.93 560,490.68 70' ~8' .00.718' 149' 30' ~6.~" 61' ~ 597' 70.4' 6~.4' 118 ' 5,959,55&95 560,490.68 70' 18' 00.276' ~49' 30' ~6.316' ~ I~' 597' 70.4' 6~4' I 119 5,959,513.86 560,490.72 70' 17' 59.832' i 149' ~0' ~6.326" ~51' 598' 70.~' 66.0" 120 5,959,499.01 560,490.77 70' 17' 59.686' ! 149' ~0' ~6.327" ~i 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.538" 149' 30' ~6.335' 18I' 598' 70.5' ~.0 124 5,959,~93.96 560,490.70 70" 17' 5&653' ~49" 30' 36.355' 271" 599' 70.3' 65.0" 129 5,959,27~.92 560,490.79 70' ~7' 5Z472' I49' 30' 36.~0' 391' 600' 70.3' 6~2' ~ 1~0 5,959,259.09 560,490.8~ 70' 17' 5Z~26' ~49' 30' ~6.~3' 4~' 600' 70.5' ~3 5,959,213.89 5~0,490.68 ~ 70' 17' 56.~2' 149' 30' ~6.397' 451" 600' 70.4" 69.0'~ 1~5 5,959,139.02 ~ 560,490.80 ~ 70' 17' 56.~46' 149' 30" ~6.412" 526' 60I' 70.5' 69.4'~ SUR~YOR'S CER~RCA ~ SUPER~SiON ASSOCIATES, [~C. DETAILS ARE CORRECT AS OF AUGUST ~0, 199Z ~~-~~ P~rs sur~o~ ~ ORIEL SI~ 1-D ARCO Alaska. Inc. ,HaSe, - CON UC O,S AS-BUILT cADDFI~ NO. [ IDRA. NGN~ ]~EET: ~04~0 9/02/97 CEA-D1DX-6104DlO 2 ~ 2 ,,,# SEC SEC. PAO O.C. No. ,y, A.S.P. $ ,X, LA TI rUDE L ONGI rUDE L~,~ ELEV. ELEV. S=,c. 14, T. 11 N., R. IO E. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.657' 149" 30' `76.265" 134' 595' 70.5' 62.0' 106 5,959,768.95 560,490.67 70' 18' 02.341' 149' 30' $6.268' 104' 595' 70.4' 62.,7' 109 5,959,72`7.89 560,490.60 70" 18' 01.898' 149' $0' 36.280' 59' 596' 70.4' 62.7' S ;c. 23, T. 11 N., R. 10 E. F.N.L.F.E.L. 115 5,959,605.95 560,490.68 70' 18' .00.718" 149" $0' 36.306" 61' 597' 70.4' 63.4' 117 5,959,575.95 560,490.65 70" 18' 00.425' I49' 30' 36.314" 91' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' $0' 36..;716' 106' 597' 70.4' 6`7.4' 119 5,959,513.86 560,490.72 70' 17' 59.852' 149' ,.TO' ,76.326' I51' 598' 70.6' 66.0' 120 5,959,499.01 560,490.77 70' 17' 59.686' 149' `70' 36.327" 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.5J8' 149' JO' J6. JJ5" 18I' 598' 70.5' 66.0 124 5,959, J9J. 96 560,490.70 70' 17' 58.65J* 149' JO' J6. J55' 271' 599' 70.3' 65.0' 129 5,959,27`7.92 560,490.79 70' 17' 57.472" I49' ,,TO" 36.,580" $91' 600' 70.3' 68.2' 150 5,959,259.09 560,490.81 70' 17' 57.`726' 149' ,.TO' ,76.383' 406' 600' 70.5' 68.2°. 1,7,7 5,959,21,7.89 560,490.68 70' 17' 56.882' 149' ,70' ,76.,797' 451' 600' 70.4' 1,75 5,959,1,79.02 560,490.80 70' 17' 56. I46' 149' ,70' ,76.412" 526' 60I' 70.5' ARCO Alaska, Inc. Kuparuk Drillsite D,. ~pment Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 2, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-118 (E5) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak pool rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-118 (ES), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is December 21, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Thomas A. Brockway~~~''-~- Operations Drilling Engineer Attachments: CC: West Sak 1D-118 (E5) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 WELL PERMIT CHECKLIST NAME · COMPANY WELL Dc.), ,¢, PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg E; ann. disposal para req El FIELD & POOL .. ~/~423/,.~"~__~ INIT CLASS t~,~-" ,/-,~., / GEOL AREA S::".'~<:::::/ UNIT# ,/,..,//~z'~_2 ON/OFF SHORE ~ ~ ADMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached ....................... h 2. Lease number appropriate ................... h 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells ..... ..... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ ~N 18. CMT will cover all known productive horizons .......... !9. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N /~'.~ 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... N 26. BOPE press rating appropriate; test to pslg. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... _N.... 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ...... /4. Y N [exploratory only] / REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ~ RNC ~ co '¢t,s Comments/Instructions: HOW/Ill - A \FORMS\chekhst rev 09/97 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. 0~'0£ 0~'~ 00' £6§ 90I .w0I H,T, II4S ' cI E NflH (/MAI 86-NlfP-60 S~DIAH~S ONIqqIHG NOS-ABII~dS 'DNI 'tf~S~%¥ OO~ 006£SEE6E00~ 8II-GI ~0Z IWOTSXqd 'X~wxqTq 6uT~T~M SI% SAS ................. NMON~NO ....... I0 ...... ~sqmnN uo!~nuI~uoD NMON-MNfl ................ a~wN IaaH S&S ................... uTBT~O 60/I0/86 ..................... Z~SIq ............. aureu aOTA~aS ~ap~aH IaaH 866I 9I:0§:§I 60 uw~ A~TiT~O ueos SIq semi-xeS BuTIIT=O uns-X~dS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 4590.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M. ~gNYAK OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 07 JANUARY, 1998. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4590'MD 4331'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMAR~ PBU TOOL CODE START DEPTH STOP DEPTH GR 71 5 4554.0 ROP 109 0 4590.5 FET 121 0 4546.5 RPD 121 0 4546.5 RPM 121 0 4546.5 RPS 121 0 4546.5 RPX 121 0 4546.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 109.0 4212.0 2 4212.0 4590.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 71.5 4590.5 2331 9039 ROP 8.812 9184.57 199.804 8964 GR 11.7803 115.6 56.3662 8966 RPX 0.1932 1033.32 39.0896 8852 RPS 0.2202 2000 54.8152 8852 RPM 0.2757 2000 87.5029 8852 RPD 0.3417 2000 100.438 8852 FET 0.144 8.9015 0.579078 8852 First Reading 71.5 109 71.5 121 121 121 121 121 Last Reading 4590.5 4590.5 4554 4546.5 4546.5 4546.5 4546.5 4546.5 First Reading For Entire File .......... 71.5 Last Reading For Entire File ........... 4590.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and l°g header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE sUMMARy VENDOR TOOL CODE START DEPTH GR ROP FET RPD RPM RPS RPX $ LOG HEADER DATA DATE LOGGED: SOFTWARE 71 5 109 0 121 0 121 0 121 0 121 0 121 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 4168 4168 4168 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : STOP DEPTH 4175.0 4211 5 4168 0 4168 0 0 0 0 19-DEC-97 ISC 5.06 CIM 5.46 MEMORY 4212.0 109.0 4212.0 .1 25.3 TOOL NUMBER P0891CRG6 P0891CRG6 9.880 9.9 SPUD MUD 173.10 350.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL sTANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.5 450 10.2 3.500 2.320 4.500 5.000 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM' 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 42.3 Name Min Max Mean Nsam DEPT 71.5 4211.5 2141.5 8281 GR 11.7803 102.39 54.3856 8208 RPX 0.1932 1033.32 42.3785 8095 RPS 0.2202 2000 59.5608 8095 RPM 0.2757 2000 95.3114 8095 RPD 0.3417 2000 109.447 8095 ROP 8.812 9184.57 205.563 8206 FET 0.144 3.2994 0.501109 8095 First Reading 71.5 71.5 121 121 121 121 109 121 Last Reading 4211.5 4175 4168 4168 4168 4168 4211.5 4168 First Reading For Entire File .......... 71.5 Last Reading For Entire File ........... 4211.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4169.0 RPD 4169.0 RPM 4169.0 RPS 4169.0 RPX 4169.0 GR 4177.0 ROP 4214.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMEFM ANGLE: MAXIMUM ANGLE: 4546 4554 4590 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL .TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA STOP DEPTH 4546 5 4546 5 4546 5 4546 5 5 0 5 19-DEC-97 ISC 5.06 CIM 5.46 MEMORY 4590.0 4212.0 4590.0 17.6 18.2 TOOL NUMBER P0891CRG6 P0891CRG6 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record .............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.880 9.9 S PUD MUD 175.00 286.0 8.5 450 7.2 4.000 3.100 5.000 3.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHM~ 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 36.7 First Name Min Max Mean Nsam Reading DEPT 4169 4590.5 4379.75 844 4169 GR 46.7341 115.6 77.9049 755 4177 RPX 1.7936 12.1093 3.91687 756 4169 RPS 1.9 11.7692 4.06367. 756 4169 RPM 1.9627 11.0193 3.99818 756 4169 RPD 2.0439 11.0806 4.09639 756 4169 ROP 42.4675 1171.24 139.908 754 4214 FET 0.3133 8.9015 1.40768 756 4169 Last Reading 4590.5 4554 4546.5 4546.5 4546.5 4546.5 4590.5 4546.5 aIT~ SIq ~O pul saoTA~aS I~OTuqoa& 'Xx~qTq 6uTqT~ SI% S~S ................. _/xI~O~ ........... a~N ad~ qx~N I0 ...... ~q~un~ UOTq~nuTqmoo NMONMN_Q ................ ~N ~d~ 60/I0/86 ..................... ~SI% ............. ~o_~u ~00'SIqSAS ........... smwN elT~ Oq ................ ~ctX~ §£S§9''p~oo~ I~OTsXq~ ~n~Tx~ 60/I0/86 ....... uoT~p~sus© ~o 0'0'I ........... ~eqtunN uoTs~A · ''~m~N I~q qns £00'SlqS&S ............. s~u SOTA~SS ~sIl~& alT~ S'06S~ ........... aIl~ a~lqu~ ~o~ BuTppaH qspq 69I~ .......... ~IT~ e~Tqu~ ~o~ 6uTp~eH qs~T~