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Home My WebLink About198-1721. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6245'feet 6020'feet true vertical 4090' feet None feet Effective Depth measured 6020'feet 2889', 2957', 2961', 5568' feet true vertical 3874'feet 1943', 1973', 1974', 3441' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5497' MD 3374' TVD Packers and SSSV (type, measured and true vertical depth) 2889' MD 2957' MD 2961' MD 5568' MD N/A 1943' TVD 1973' TVD 1974' TVD 3441' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Burst Collapse Production Liner 6189' Casing 4075'6230' 121'Conductor Surface Intermediate 16"80' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-172 50-029-22915-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-116 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 110 well continues to stabilize Gas-Mcf MD 750 Size 121' 130 1150100 50 15040 160 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 75 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: WFD Hydro II Packer Packer: P2P Patch Packer Packer: Baker SC-1 Gravel Pack Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Intervention Engineer 5698-5730', 5762-5828', 5854-5900', 5923-5964' 3565-3596',3626-3689', 3714-3759', 3781-3820' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:40 pm, Jun 27, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.06.27 13:57:31-08'00' Foxit PDF Editor Version: 12.1.2 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 4/22/2023 REPAIR WELL PULLED UPPER PATCH 2.72' 'P2P PACKER @ 2892'RKB. PULLED 2.72'' P2P MID PATCH ASSEMBLY @ 2927'RKB. IN PROGRESS 4/23/2023 REPAIR WELL PULLED LOWER 2.72'' P2P PACKER @ 2964' RKB. BAILED FILL FROM TOP OF 3.5'' TBG STOP @ 5443' RKB. ATTEMPTED TO PULL 3.5'' PACKOFF @ 5445'RKB, TOOL SHEARED. IN PROGRESS 4/24/2023 REPAIR WELL ATTEMPT TO PULL 3.5'' PACKOFF @ 5445' RKB(JAR 4HRS)(UNSUCCESSFUL) IN PROGRESS 4/25/2023 REPAIR WELL ((UTILIZING .160'' WIRE)) JARRED ON PACKOFF @ 5445' RKB FOR A TOTAL OF 4 HOURS W/ NO MOVEMENT. IN PROGRESS. 4/26/2023 REPAIR WELL ((UTILIZING .160'' WIRE)) W/ 2.125'' ACCELERATORS & 18' x 2.125'' TOOL STRING JARRED FOR A TOTAL OF 35 MINS & PARTED WIRE @ SURFACE, RECOVERED ALL WIRE & TOOL STRING. RDMO FOR PLAN FORWARD. 5/11/2023 REPAIR WELL RAN BHA-1 W/ 3" GS SPEAR, TAG PACK OFF AT 5414' CTMD. RECOVERED PACK OFF WITH ELEMENT & SEALS ON STINGER. RERAN BHA-1, TAGGED PUMP AT 5421' CTMD, PULLED TO SURFACE, DID NOT HAVE PUMP ON. RERAN BHA-1, LATCHED & RETRIEVED PUMP. VERIFY W/ SWAB, RBIH AND PUMPED OFF PUMP @ 5420' FOR RELAY TO RETRIEVE. FP TUBING S. DIESEL. RDMO. ****READY FOR RELAY**** 5/14/2023 REPAIR WELL PULLED 3-1/2" ESPCP FROM 5408' SLM. RAN ROTATION TEST TOOL TO MOTOR @ 5463' RKB, PIN SHEARED INDICATING MOTOR IS SPINNING. BRUSH & FLUSHED TUBING W/ 60bbls DIESEL, FOCUSED ON PATCH SETTING INTERVAL OF 2800' SLM-3050' SLM. SET NEW 3- 1/2" ESPCP (418.5" OAL) IN MOTOR @ 5463' RKB. SET 2.72" PACKOFF ON TOP OF ESPCP (92" OAL), SET AVA CATCHER ON TOP OF PACKOFF, MADE ONE ATTEMPT TO PULL STA# 3 BK-SOV @ 5374' RKB, UNABLE TO LATCH, IN PROGRESS 5/15/2023 REPAIR WELL PULLED & SET NEW BK-SOV (2000psi, TUBING SHEAR) IN STA# 3 @ 5374' RKB. PULLED 3-1/2" AVA CATCHER FROM 5398' SLM. RAN PACKOFF TEST TOOL, LRS PUMPED 48bbls DOWN TUBING TO ATTEMPT CMIT, NO PRESSURE CHANGE, IN PROGRESS 5/16/2023 REPAIR WELL RAN D&D HOLEFINDER TO TOP OF PACKOFF @ 5398' SLM, GOT A GOOD TEST @ 1000psi, PULLED & RESET NEW PACKOFF (2.72" OD, 92" OAL), RAN PACKOFF TEST TOOL, GOT A GOOD TEST @ 1000psi (CMIT) SET SLIPSTOP ON TOP OF PACKOFF @ 5398' SLM, READYTO SET LOWER FOR PATCH. 5/22/2023 REPAIR WELL SET 2.725" PIIP LOWER PACKER W/ MOE = 2963' RKB, CCL TO MOE = 10.3', CCL STOP = 2952.7'. JOB IS READY FOR SL SERIAL #: CPP35213 1D-116 Tubing Patch Summary of Operations 5/26/2023 REPAIR WELL TEST LOWER 2.72" P2P @ 2960' RKB W/ 3 1/2 TTS TEST TOOL (PASS), SET 2.70" PBR SPACER & ANCHOR LATCH @ 2929.77' RKB (OAL 31.62' / SN: CPBR35032 / CPAL35208), TEST PBR @ 2929' RKB W/ 3 1/2 TTS TEST TOOL (PASS), SET 2.70" PBR SPACER & ANCHOR LATCH @ 2898.99' RKB (OAL 31.62' / SN: CPBR35020 / CPAL35174) TEST PBR @ 2898.99' RKB (PASS). IN PROGRESS. JOB POSTPONED FOR RIG TO PULL ON PAD. 5/29/2023 REPAIR WELL SET 2.72" P2P SPACER ANCHOR LATCH (OAL 10.44' / CPP35310 / CPAL35061) @ 2891' RKB (CE) TOP @ 2888.55' RKB, ATTEMPT TO MIT TBG 2500 W/ 3 1/2 TTS TEST TOOL (FAILED) TBG TEST CANCELED IF TEST TOOL IS FAILING COULD SHEAR SOV, MIT IA 2500 (PASS). JOB COMPLETE. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1D-116 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper patch Assemblies (3 Sections) Total Patch is 72' mid element to mid element 1D-116 5/29/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Weld 6'x10" x 65, .500 pipe over damaged 7 5/8 production pipe from bottom of starter head 1/10/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 Welded PRODUCTION 7 5/8 6.75 40.6 6,229.6 4,075.5 29.70 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.0 Set Depth 5,497.0 Set Depth 3,373.9 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 HANGER 11.000 Vetco Gray Tubing hanger BHGE MB228 2.900 2,898.9 1,947.4 63.95 GAS LIFT 5.375 Camco 3-1/2" x 1" KBMG EUE BxP W/SOV 2000psi IA-tbg shear S# Camco KBMG 2.920 2,956.7 1,972.8 63.92 PACKER 6.890 3-1/2"x7-5/8" Weatherford Hydro II Packer 3-1/2" 9.3# 10rd NU x 10rd NU WFT Hydro II 2.908 3,007.7 1,995.2 63.89 GAS LIFT 5.375 Camco 3-1/2" x 1" KBMG EUE BxP W/DV S# Camco KBMG 2.920 5,373.6 3,258.4 22.82 GAS LIFT 5.375 Camco 3-1/2" x 1" KBMG EUE BxP W/DV S# Camco KBMG 2.920 5,395.2 3,278.4 21.88 DISCHARGE SUB 5.130 Summit presure discharge sub, ACE, 3-1/2" SS Summit ACE-3- 1/2" 2.992 5,463.0 3,341.9 19.58 TTTPCP 5.130 Summit TTTPCP Receiving base Summit 513- BPBSL 2.992 5,467.6 3,346.2 19.52 SEAL 5.130 Seal Summit 5,485.5 3,363.1 19.29 ESP 5.380 GRU to seal adapter Summit 5,487.8 3,365.2 19.26 ESP 5.620 Motor 562 Series, KMS2, 60HP/879V/37A, High Frequency Summit 5,494.2 3,371.2 19.17 GAUGE 3.500 Sensor/Motor Adapter and sensor Summit 5,496.3 3,373.3 19.14 CENTRALIZER 5.620 Centralizer/Motor Guide Summit Top (ftKB) 5,568.2 Set Depth 6,021.0 Set Depth 3,874.7 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) Grade Top Connection ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,568.2 3,441.4 18.20 PACKER 6.490 BAKER MODEL SC-1 GRAVEL PACK PACKER 3.875 5,572.4 3,445.4 18.14 PBR 5.000 80-40 UPPER EXTENSION 3.875 5,576.8 3,449.5 18.08 SLEEVE 5.000 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 5,578.3 3,450.9 18.06 SBE 5.000 80-40 SEAL BORE 3.875 5,580.3 3,452.9 18.04 PBR 5.000 80-40 LOWER EXTENSION 3.875 5,596.0 3,467.8 17.83 XO REDUCING 5.000 XO 3.5 x 4.5 4.500 5,660.0 3,528.9 17.26 SCREEN 4.500 SCREEN 4.5 x .020 3.958 5,960.3 3,816.4 16.24 SCREEN 4.500 SCREEN 4.5 x .012 3.958 6,020.4 3,874.2 16.03 PLUG 4.500 BAKER BULL PLUG 0.000 6,021.0 3,874.7 16.03 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,888.6 1,942.8 63.96 PACKER - PATCH - UPR Set 2.73" Upper PIIP Upper patch assembly with Packer and spacer pipe (OAL = 10.44') CPP3 5310 5/29/2023 1.630 2,892.2 1,944.4 63.96 ANCHOR LATCH ON SPACER PIPE Part of Upper Assembly attached to Upper PIIP packer. CPAL 35051 5/29/2023 1.600 2,894.0 1,945.2 63.96 LEAK Slow leak not pin-pointed. Below 2895' & above 2929' RKB 5/3/2021 2.992 2,899.0 1,947.4 63.95 ANCHOR LATCH ON SPACER PIPE Set MID section of spacer pipe with PBR and Anchor latch (OAL = 31.62') CPPB R3502 0/CPA L3517 4 5/26/2023 1.600 2,925.8 1,959.2 63.94 ANCHOR LATCH ON SPACER PIPE Set LWR section of spacer pipe with PBR and Anchor latch (OAL = 31.62') CPPB R3503 2/CPA L3520 6 5/26/2023 1.600 2,956.0 1,972.5 63.92 LEAK Leak, found w/ Relay 4/17/21 4/17/2021 2.990 2,960.6 1,974.5 63.92 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE = 2963' RKB & WLEG, OAL = 4.01' CPP3 5213 5/22/2023 1.625 1D-116, 6/20/2023 2:05:07 PM Vertical schematic (actual) PRODUCTION; 40.6-6,229.6 IPERF; 5,923.0-5,964.0 IPERF; 5,854.0-5,900.0 IPERF; 5,798.0-5,828.0 IPERF; 5,762.0-5,798.0 IPERF; 5,699.0-5,730.0 IPERF; 5,698.0-5,718.0 PACKER; 5,568.2 ESP ; 5,487.8 ESP; 5,485.5 ESP; 5,451.0 PACKOFF; 5,443.0 SLIP STOP; 5,441.0 DISCHARGE SUB; 5,395.2 GAS LIFT; 5,373.6 GAS LIFT; 3,007.7 PACKER - PATCH - LWR; 2,960.5 PACKER; 2,956.7 LEAK; 2,956.0 ANCHOR LATCH ON SPACER PIPE; 2,925.8 ANCHOR LATCH ON SPACER PIPE; 2,899.0 GAS LIFT; 2,898.9 ANCHOR LATCH ON SPACER PIPE; 2,892.2 LEAK; 2,894.0 PACKER - PATCH - UPR; 2,888.6 CONDUCTOR; 41.0-121.0 HANGER; 36.9 KUP PROD KB-Grd (ft) 112.10 RR Date 9/12/1998 Other Elev 1D-116 ... TD Act Btm (ftKB) 6,245.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292291500 Wellbore Status PROD Max Angle & MD Incl (°) 66.66 MD (ftKB) 1,938.19 WELLNAME WELLBORE1D-116 Annotation Last WO: End Date 4/29/2019 H2S (ppm) 10 Date 12/16/2013 Comment SSSV: NONE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,441.0 3,321.1 19.88 SLIP STOP 3 1/2" SLIP STOP 5/16/2023 5,443.0 3,323.0 19.85 PACKOFF D&D pack off (92" OAL) 5/16/2023 5,451.0 3,330.5 19.74 ESP Summit TTC-PCESP (34'87' OAL) 4/14/2023 5,568.0 3,441.2 18.20 PACKER GRAVEL PACK (icon info only) 1/9/1999 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,898.9 1,947.4 63.95 1 GAS LIFT DMY BK 1 0.0 5/8/2019 Schlumb erger Camco BK 0.000 3,007.7 1,995.2 63.89 2 GAS LIFT DMY BK 1 5/4/2019 Schlumb erger Camco BK 5,373.6 3,258.4 22.82 3 GAS LIFT SOV BK 1 5/15/2023 2000# Schlumb erger Camco BK 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,698.0 5,718.0 3,565.2 3,584.3 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,699.0 5,730.0 3,566.1 3,595.8 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,762.0 5,798.0 3,626.4 3,660.8 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,798.0 5,828.0 3,660.8 3,689.5 WS B, WS A4, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,854.0 5,900.0 3,714.5 3,758.6 WS A3, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,923.0 5,964.0 3,780.6 3,820.0 WS A2, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 1D-116, 6/20/2023 2:05:08 PM Vertical schematic (actual) PRODUCTION; 40.6-6,229.6 IPERF; 5,923.0-5,964.0 IPERF; 5,854.0-5,900.0 IPERF; 5,798.0-5,828.0 IPERF; 5,762.0-5,798.0 IPERF; 5,699.0-5,730.0 IPERF; 5,698.0-5,718.0 PACKER; 5,568.2 ESP ; 5,487.8 ESP; 5,485.5 ESP; 5,451.0 PACKOFF; 5,443.0 SLIP STOP; 5,441.0 DISCHARGE SUB; 5,395.2 GAS LIFT; 5,373.6 GAS LIFT; 3,007.7 PACKER - PATCH - LWR; 2,960.5 PACKER; 2,956.7 LEAK; 2,956.0 ANCHOR LATCH ON SPACER PIPE; 2,925.8 ANCHOR LATCH ON SPACER PIPE; 2,899.0 GAS LIFT; 2,898.9 ANCHOR LATCH ON SPACER PIPE; 2,892.2 LEAK; 2,894.0 PACKER - PATCH - UPR; 2,888.6 CONDUCTOR; 41.0-121.0 HANGER; 36.9 KUP PROD 1D-116 ... WELLNAME WELLBORE1D-116 Annotation Last WO: End Date Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1D-107 50-029-22983-00 n/a West Sak Plug Setting Record Field- Final 4-Apr-21 0 1 2 1D-116 50-029-22915-00 907099354 Kuparuk River Leak Detect Log Field- Final 17-Apr-21 0 1 3 1D-116 50-029-22915-00 907100262 Kuparuk River Multi Finger Caliper Field & Processed 18-Apr-21 0 1 4 1D-116 50-029-22915-00 907128193 Kuparuk River Packer Setting Record Field- Final 2-May-21 0 1 5 1D-116 50-029-22915-00 907099354 Kuparuk River Plug Setting Record Field- Final 17-Apr-21 0 1 6 1E-14 50-029-20751-00 907087089 Kuparuk River Leak Detect Log Field- Final 12-Apr-21 0 1 7 1E-14 50-029-20751-00 907087419 Kuparuk River Multi Finger Caliper Field & Processed 12-Apr-21 0 1 8 1E-14:50-029-20751-00 907109076 Kuparuk River Packer Setting Record Field- Final 28-Apr-21 0 1 9 1F-06 50-029-20820-00 907045708 Kuparuk River Packer Setting Record Field- Final 2-Apr-21 0 1 10 1R-15 50-029-21387-00 907155263 Kuparuk River Plug Setting Record Field- Final 17-May-21 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: 06/01/2021 PTD: 1981720 E-Set: 35181 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1D-107 50-029-22983-00 n/a West Sak Plug Setting Record Field- Final 4-Apr-21 0 1 2 1D-116 50-029-22915-00 907099354 Kuparuk River Leak Detect Log Field- Final 17-Apr-21 0 1 3 1D-116 50-029-22915-00 907100262 Kuparuk River Multi Finger Caliper Field & Processed 18-Apr-21 0 1 4 1D-116 50-029-22915-00 907128193 Kuparuk River Packer Setting Record Field- Final 2-May-21 0 1 5 1D-116 50-029-22915-00 907099354 Kuparuk River Plug Setting Record Field- Final 17-Apr-21 0 1 6 1E-14 50-029-20751-00 907087089 Kuparuk River Leak Detect Log Field- Final 12-Apr-21 0 1 7 1E-14 50-029-20751-00 907087419 Kuparuk River Multi Finger Caliper Field & Processed 12-Apr-21 0 1 8 1E-14:50-029-20751-00 907109076 Kuparuk River Packer Setting Record Field- Final 28-Apr-21 0 1 9 1F-06 50-029-20820-00 907045708 Kuparuk River Packer Setting Record Field- Final 2-Apr-21 0 1 10 1R-15 50-029-21387-00 907155263 Kuparuk River Plug Setting Record Field- Final 17-May-21 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: 06/01/2021 PTD: 1981720 E-Set: 35180 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1D-107 50-029-22983-00 n/a West Sak Plug Setting Record Field- Final 4-Apr-21 0 1 2 1D-116 50-029-22915-00 907099354 Kuparuk River Leak Detect Log Field- Final 17-Apr-21 0 1 3 1D-116 50-029-22915-00 907100262 Kuparuk River Multi Finger Caliper Field & Processed 18-Apr-21 0 1 4 1D-116 50-029-22915-00 907128193 Kuparuk River Packer Setting Record Field- Final 2-May-21 0 1 5 1D-116 50-029-22915-00 907099354 Kuparuk River Plug Setting Record Field- Final 17-Apr-21 0 1 6 1E-14 50-029-20751-00 907087089 Kuparuk River Leak Detect Log Field- Final 12-Apr-21 0 1 7 1E-14 50-029-20751-00 907087419 Kuparuk River Multi Finger Caliper Field & Processed 12-Apr-21 0 1 8 1E-14:50-029-20751-00 907109076 Kuparuk River Packer Setting Record Field- Final 28-Apr-21 0 1 9 1F-06 50-029-20820-00 907045708 Kuparuk River Packer Setting Record Field- Final 2-Apr-21 0 1 10 1R-15 50-029-21387-00 907155263 Kuparuk River Plug Setting Record Field- Final 17-May-21 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: 06/01/2021 PTD: 1981720 E-Set: 35179 Originated:Delivered to:28-May-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1D-107 50-029-22983-00 n/a West Sak Plug Setting Record Field- Final 4-Apr-21 0 1 2 1D-116 50-029-22915-00 907099354 Kuparuk River Leak Detect Log Field- Final 17-Apr-21 0 1 3 1D-116 50-029-22915-00 907100262 Kuparuk River Multi Finger Caliper Field & Processed 18-Apr-21 0 1 4 1D-116 50-029-22915-00 907128193 Kuparuk River Packer Setting Record Field- Final 2-May-21 0 1 5 1D-116 50-029-22915-00 907099354 Kuparuk River Plug Setting Record Field- Final 17-Apr-21 0 1 6 1E-14 50-029-20751-00 907087089 Kuparuk River Leak Detect Log Field- Final 12-Apr-21 0 1 7 1E-14 50-029-20751-00 907087419 Kuparuk River Multi Finger Caliper Field & Processed 12-Apr-21 0 1 8 1E-14:50-029-20751-00 907109076 Kuparuk River Packer Setting Record Field- Final 28-Apr-21 0 1 9 1F-06 50-029-20820-00 907045708 Kuparuk River Packer Setting Record Field- Final 2-Apr-21 0 1 10 1R-15 50-029-21387-00 907155263 Kuparuk River Plug Setting Record Field- Final 17-May-21 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: 06/01/2021 PTD: 1981720 E-Set: 35178 ! 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". 1.)$ !&' $". .1)$ 1 456(789:; 4<<8=>?@AB=896?(C Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1D-116 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled RBP, Changed out SOV, Set Tubing Patch 5/3/2021 1D-116 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 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) 6.75 Top (ftKB) 40.6 Set Depth (ftKB) 6,229.6 Set Depth (TVD) … 4,075.5 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING 3-1/2" ESP W/O 2019 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 0.0 Set Depth (ft… 5,497.0 Set Depth (TVD) (… 3,373.9 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 0.0 0.0 0.00 HANGER Vetco Gray Tubing hanger 2.900 2,956.7 1,972.8 63.92 PACKER 3-1/2"x7-5/8" Weatherford Hydro II Packer 3-1/2" 9.3# 10rd NU x 10rd NU 2.908 5,395.2 3,278.4 21.88 DISCHARGE SUB Summit presure discharge sub, ACE, 3-1/2" SS 2.992 5,463.0 3,341.9 19.58 TTTPCP Summit TTTPCP Receiving base 2.992 5,467.6 3,346.2 19.52 SEAL Seal 5,485.5 3,363.1 19.29 ESP GRU to seal adapter 5,487.8 3,365.2 19.26 ESP Motor 562 Series, KMS2, 60HP/879V/37A, High Frequency 5,494.2 3,371.2 19.17 GAUGE Sensor/Motor Adapter and sensor 5,496.3 3,373.3 19.14 CENTRALIZER Centralizer/Motor Guide Tubing Description GRAVEL PACK - ORIGINAL String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 5,568.2 Set Depth (ft… 6,021.0 Set Depth (TVD) (… 3,874.7 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,568.2 3,441.4 18.20 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 3.875 5,572.4 3,445.4 18.14 PBR 80-40 UPPER EXTENSION 3.875 5,576.8 3,449.5 18.08 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 5,578.3 3,450.9 18.06 SBE 80-40 SEAL BORE 3.875 5,580.3 3,452.9 18.04 PBR 80-40 LOWER EXTENSION 3.875 5,596.0 3,467.8 17.83 XO REDUCING XO 3.5 x 4.5 4.500 5,660.0 3,528.9 17.26 SCREEN SCREEN 4.5 x .020 3.958 5,960.3 3,816.4 16.24 SCREEN SCREEN 4.5 x .012 3.958 6,020.4 3,874.2 16.03 PLUG BAKER BULL PLUG 0.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,892.7 1,944.7 63.96 PACKER - PATCH - UPR 2.72" PIIP UPPER PATCH EXTENSION SECTION W/PACKER & ANCHOR LATCH (MID-ELEMENT SET @ 2895.15' RKB) OAL = 34.88' 5/3/2021 1.590 CPP35031/CP AL35158 2,926.7 1,959.6 63.94 PACKER - PATCH - MID 2.72" PIIP MID PATCH SECTION W/ANCHOR LATCH AND UPPER PIIP. (MID-ELEMENT SET @ 2929.18' RKB) OAL = 35.67' 5/2/2021 1.590 CPP35246/CP AL35131 2,961.6 1,974.9 63.92 PACKER - PATCH - LWR 2.72" LOWER PIIP PATCH PACKER (MID- ELEMENT @ 2964' RKB) 5/2/2021 1.620 CPP35029 5,443.0 3,323.0 19.85 3.5" SLIP STOP 3 1/2" SLIP STOP 5/8/2019 1.500 5,445.0 3,324.9 19.82 3.5" D&D PACKOFF 3.5" D&D PACKOFF ASSEMBLY (76" OAL) 5/4/2019 1.620 5,451.0 3,330.5 19.74 PCESP Summit TTC-PCESP (34'6" OAL) 5/4/2019 0.000 5,568.0 3,441.2 18.20 GRAVEL PACK GRAVEL PACK (icon info only) 1/9/1999 3.875 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,698.0 5,718.0 3,565.2 3,584.3 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,699.0 5,730.0 3,566.1 3,595.8 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,762.0 5,798.0 3,626.4 3,660.8 WS D, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,798.0 5,828.0 3,660.8 3,689.5 WS B, WS A4, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,854.0 5,900.0 3,714.5 3,758.6 WS A3, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,923.0 5,964.0 3,780.6 3,820.0 WS A2, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,898.9 1,947.4 63.95 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/8/2019 2 3,007.7 1,995.2 63.89 Camco KBMG 1 GAS LIFT DMY BK 5/4/2019 3 5,373.6 3,258.4 22.82 Camco KBMG 1 GAS LIFT STS SOV BK 0.000 2,000.0 5/1/2021 Notes: General & Safety End Date Annotation 1/10/2012 NOTE: Weld 6'x10" x 65, .500 pipe over damaged 7 5/8 production pipe from bottom of starter head 1D-116, 5/10/2021 1:11:16 PM Vertical schematic (actual) PRODUCTION; 40.6-6,229.6 IPERF; 5,923.0-5,964.0 IPERF; 5,854.0-5,900.0 IPERF; 5,798.0-5,828.0 GRAVEL PACK; 5,568.0 IPERF; 5,762.0-5,798.0 IPERF; 5,699.0-5,730.0 IPERF; 5,698.0-5,718.0 PACKER; 5,568.2 ESP ; 5,487.8 ESP; 5,485.5 PCESP; 5,451.0 3.5" D&D PACKOFF ; 5,445.0 3.5" SLIP STOP; 5,443.0 DISCHARGE SUB; 5,395.2 GAS LIFT; 5,373.6 GAS LIFT; 3,007.7 PACKER - PATCH - LWR; 2,961.5 PACKER; 2,956.7 PACKER - PATCH - MID; 2,926.7 PACKER - PATCH - UPR; 2,892.7 GAS LIFT; 2,898.9 CONDUCTOR; 41.0-121.0 HANGER; 36.9 KUP PROD KB-Grd (ft) 112.10 Rig Release Date 9/12/1998 1D-116 ... TD Act Btm (ftKB) 6,245.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292291500 Wellbore Status PROD Max Angle & MD Incl (°) 66.66 MD (ftKB) 1,938.19 WELLNAME WELLBORE1D-116 Annotation Last WO: End Date 4/29/2019 H2S (ppm) 10 Date 12/16/2013 Comment SSSV: NONE 1D-116, 5/10/2021 1:11:16 PM Vertical schematic (actual) PRODUCTION; 40.6-6,229.6 IPERF; 5,923.0-5,964.0 IPERF; 5,854.0-5,900.0 IPERF; 5,798.0-5,828.0 GRAVEL PACK; 5,568.0 IPERF; 5,762.0-5,798.0 IPERF; 5,699.0-5,730.0 IPERF; 5,698.0-5,718.0 PACKER; 5,568.2 ESP ; 5,487.8 ESP; 5,485.5 PCESP; 5,451.0 3.5" D&D PACKOFF ; 5,445.0 3.5" SLIP STOP; 5,443.0 DISCHARGE SUB; 5,395.2 GAS LIFT; 5,373.6 GAS LIFT; 3,007.7 PACKER - PATCH - LWR; 2,961.5 PACKER; 2,956.7 PACKER - PATCH - MID; 2,926.7 PACKER - PATCH - UPR; 2,892.7 GAS LIFT; 2,898.9 CONDUCTOR; 41.0-121.0 HANGER; 36.9 KUP PROD 1D-116 ... WELLNAME WELLBORE1D-116 Annotation Last WO: End Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nE-ke; LZu V ik-.v JUN 0 4 2019 1. Operations Abandon❑ lug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ (orate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: C/O ESP ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development E] Exploratory ❑ Stratigraphic❑ Service ❑ 198-172 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-22915-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1D-116 ADL 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,245 feet Plugs measured None feet true vertical 4,090 feet Junk measured None feet Effective Depth measured 6,020 feet Packer measured 2,957 feet true vertical 3,874 feet true vertical 1,973 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 121' MD 121' TVD PRODUCTION 6,189 feet 7 5/8 " 6,230' MD 4075' TVD Perforation depth: Measured depth: 5698-5718, 5699-5730, 5762-5798 5798-5828, 5854-5900, 5923-5964 feet True vertical depth: 3565-3584, 3566-3595, 3626-3660 3661-3689 3714-3759, 3781-3820 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 6,021' MD 3,875' TVD Packers and SSSV (type, measured and true vertical dept[ PACKER - BAKER MODEL SC -1 2,957' MD 1,973' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1124 1107 Subsequent to operation: 106 75 318 1228 1162 14. Attachments (required per 20 Aac 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and Correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: :51 �3(q6 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 263-4627 Authorized Signature, Date: 'p-// �0 �I 6151/I RBDMS�'JUN 5 2019 Form 10-404 Revised 4/2017 /ems/ -70(1,11O Submit Original Only p� KUP PROD WELLNAME ID -116 WELLBORE 1D-116 Conococt dlliS Well Attributes p Maz A ! 8 MD TD n,n�—L.. ....... ESP. B..., ESP..6 ClYi', .w IPERF; S ,,Y .- IPERF', 5,W$ SWOP SCREEN', PLW. con, F4 0030 Operations Summary (with Timelog Depths) -`- - ` "' "' mu equipment and trucks to bullhead. 0.0 ID -116 4/30/2019 2.50 COMPZN WELCTL KLWL Initial TBG=830 PSI. 03:00 Rig: NORDIC 1 Pump down tubing at 2.5BPM at 930 Time Log Job: RECOMPLETION Start Time 4/29/2019 End Time 4/29/2019 our (hr) Phase 1.50 DEMOB Op Code MOVE Adrvify Code Time P -T -X Operation SWrt Depth @Ka) End Depth(rtKa) 08:00 09:30 125 BBL's 8.6# 3% KCI pumped at 4 DMOB P Prep rig to pull off well 0.0 0.0 4/29/2019 09:30 4/29/2019 11:30 2.00 DEMOB MOVE DMOB P Pull rig off well, Stage at pad entrance, 0.0 4/30/2019 4/30/2019 0.50 COMPZN WELCTL RURD Pull mats and herculite from around Final TBG PSI =870 PSI 0.0 4/29/2019 4/29/2019 5.00 MIRU MOVE MOB P well, clean up pad. 11:30 16:30 4/30/2019 03:30 4/30/2019 05:00 Move rig f/ 1J pad to 1D pad 0.0 0.0 4/29/2019 16:30 4/29/2019 19:00 . 250 MIRU MOVE MOB P Set mats and herculite around well, 0.0 tank. From 870-0 psi. Pressure built Spot sub over well and shim, set up . 00 4/30/2019 2.00 COMPZN WELCTL KLWL Handi berm around rig, spot in back up to 47 psi. 4/29/2019 4/29/2019 3.50 COMPZN RPEQPT MPSP cuttings tank, Rig Accepted 1900hrs 19:00 22:30 P Bleetl off gas cap, get lubricator to 0.0 0.0 Initial tubing pressure=220 psi. Bull cellar, R/U and remove 3" H type BPV 4/30/2019 1.50 COMPZN WELCTL OWFF head down tubing at 2BPM Install 3" HPBPV, Pull HPBPV 1000 07:00 08:30 psi of gas on tubing. get lubricator out Monitor well for flow and pressure 4/29/2019 4/30/2019 1.50 I COMPZN WELCTL RIIRD R of cellar. on I cc.ov Ivu:uUI I I a"„_' �� '...,coo wrnny V U 0.0 volume, spot in trucks hook up to annnn pumps and prime lines. 00:00 0030 - -`- - ` "' "' mu equipment and trucks to bullhead. 0.0 4/30/2019 00:30 4/30/2019 2.50 COMPZN WELCTL KLWL Initial TBG=830 PSI. 03:00 Pump down tubing at 2.5BPM at 930 PSI 125 BBL's 8.6# 3% KCI pumped at 4 BPM 4/30/2019 4/30/2019 0.50 COMPZN WELCTL RURD Final TBG PSI =870 PSI 03:00 03:30 RU bleed off line from tree to kill tank. 4/30/2019 03:30 4/30/2019 05:00 1.50 COMPZN WELCTL OWFF Check for flow bleed off tubing to kill tank. From 870-0 psi. Pressure built 4/30/2019 4/30/2019 2.00 COMPZN WELCTL KLWL back up to 47 psi. 0500 07:00 Blow down kill tank line, RU to kill well. Initial tubing pressure=220 psi. Bull 4/30/2019 4/30/2019 1.50 COMPZN WELCTL OWFF head down tubing at 2BPM 07:00 08:30 Monitor well for flow and pressure increase. Bleed off to TT. Shut in choke. pressure increased to 125 psi. shut in at tree blow down kill line and monitor well. Pressure increased to 235 psi. Order 9.8 # 3% KCL NaCl 4/30/2019 4/30/2019 2.50 COMPZN WELCTL KLWL from 1Bused storage. 08:30 11:00 Line up and bull head down tubing with 9.75 PPG 3% KCI NaCl at 3 BPM 4/30/2019 4/30/2019 1.50 COMPZN WELCTL OWFF 720 psi. 11:00 12:30 Bleed Bleedd offff tubing o ubbing and blow down kill line. Well on a vac. OWFF for 30 4/30/2019 1230 4/30/2019 3.00 COMPZN WELCTL MPSP minutes. Set 3" CIW HP-BPV and test dart, 15:30 Pressure test top side of plug to 1000 4/30/2019 15:30 5/1/20198.50 00:00 COMPZN WHDBOP RURD psi ND Tree and adapter and NU BOPE. 5/1/2019 00:00 5/1/2019 19:30 19.50 COMPZN WHDBOP BOPE P M/U test jt, fll stack with water, Test BOP'S annular @ 250/ 1500 psi Rams, choke manifold, Floor valves @ 5/1/2019 5/1/2019 0.50 COMPZN WHDBOP ROPE 250 P / 1500 psi F/ 5 min each. 19:30 20:00 Rig down testing Equip. 5/1/2019 5/1/2019 20:00 20:30 0.50 COMPZN WHDBOP THGR P Pull test dart, check BPV F/ gas, gas under BPV, Operations Summary (with Timelog Depths) �,.. ID -116 F4 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Time 5/1/2019 End Time 5/1/2019 our (hr) Phase Op Code Activit Code Y Time P -T- % Opembon Start Depth (ftKB) End Depth (ftKB) 2.50 COMPZN WELCTL KLWL P Lineup and bull head down tubing 20:30 2300 with 9.75 PPG 3% KCI NaCl at 2 BPM 75 BBL'S at 306 psi. shut inf well, 30 psi on chok, on tubing circ 70 bbls down tubing. 5/1/2019 5/2/2019 1.00 COMPZN WELLPR THGR P M/U landing jt. Close Annular, BOLDS, 23:00 00:00 tubing raised 12" when LDS removed, pull packer, packer released @ 112K, 150 psi on choke, 5/2/2019 5/2/2019 1.50 COMPZN RPEQPT CIRC P Circulate out gas pump 3459 stks, 76 0000 01:30 bbls, down tubing, shut well in, check for psi, 50 psi on annulas, 0 on tubing, circulate tubing volume, check f/psi, 10 on choke, 0 on tubing, 019 5/2/2019 1.00 COMPZN TP -COMP PULD P Pull hanger T/ Rig Floor and UD, lay 01:3 01:30 0230 down landing joint and hanger. 5/2/2019 5/2/2019 0.50 COMPZN RPCOMP KURD P Pull cable over sheave tie into spooler. 02:30 03:00 5/2/2019 5/2/2019 5.50 COMPZN COMP PULL P Lay down 3 1/2 ESP completion string 03:00 08:30 from 5468' PU WT= 45K. continue to lay down 3-1/2" tubing and ESP cable to 3787' KS. tubing started U -tubing. 5/2/2019 5/2/2019 1.00 COMPZN RPCOMP CIRC P Circulate BU=125 bbls 9.5 ppg 3% 08:30 09:30 KCI NaCl @ 3bpm. CP=130 psi. with 25 bbls lost to well. Well on vacuum. 5/2/2019 5/2/2019 9.50 COMPZN RPCOMP PULL P Con't to POOH from -3787-to 3004' 09:30 19:00 disconnect ESP cable from top and bottom of packer continue to POOH with completion. 5/2/2019 5/2/2019 1.00 COMPZN RPCOMP PULD P Lay down esp assembly. 19:00 20:00 5/2/2019 5/2/2019 2.00 COMPZN RPCOMP PULD P off load pipe house of pipe, and 20:00 22:00 jewelry 5/2/2019 5/3/2019 2.00 COMPZN RPCOMP PULD P load pipe house with new esp motor, 22:00 00:00 packer, glm. 5/3/2019 5/3/2019 11.00 COMPZN RPCOMP TU -LD P Make up ESP motor assembly. 0.0 96.0 00:00 11:00 Connect MLE and and make MLE splice, simulateously load pipe shed with 3-1/2" 9.3# L80 EUE strap and drift all joints and jewely to 2.875" 5/3/2019 5/3/2019 0.50 -CO MPZN WPCOMP P PJSM for RIH with tubing 96.0 96.0 11:00 11:30 5/3/2019 5/3/2019 6.00 COMPZN RPCOMP PUTB P RIH with 3-1/2" 9.3# EUE 8rd ESP 96.0 2,550.0 11:30 1730 completion installing cannon clamp everyjoint, to packer 5/3/2019 5/3/2019 3.50 COMPZN RPCOMP PUTB P Make splice on esp cable thru packer. 2,550.0 2,952.8 17:30 21:00 5/3/2019 21:00 5/4/2019 3.00 COMPZN Continue RIH with 3-1/2" 9.3# EUE 2,952.8 3,574.0 00:00 8rd ESP completion installing cannon clamp every joint 5/4/2019 00:00 5/4/2019 5.00 COMPZN RPCOMP PULD P Continue RIH with 3-1/2" 9.3# ELF 3,574.0 5,497.0 05:00 8rd ESP completion installing cannon clamp every joint to 5497' 5/4/2019 05:00 5/4/2019 1.00 COM PZN RPCOMP THGR P MU hanger an landing joint to string. 5,497.0 5,497.0 06:00 Incorrect penetrtaor on location after requesting thta the pentrator be functioned in hanger, I was assured that a function ft of the penetrator was completed prior to stating completion in the well. Page 2/4 Report Printed: 5/6/2019 Operations Summary (with Timelog Depths) 1 D-116 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Act Ay Code The P -T-% Operation (ftKB) End Depth (8KB) 5/4/2019 5/4/2019 3.50 COMPZN RPCOMP WAIT T Wait on penetrator from Summit ESP. 5,497.0 5,497.0 06:00 09:30 Summit provided wrong penetrator. Crew left location to travel to Deadhorse to locate correct penetrator for hanger termination. 5/4/2019 5/4/2019 4.00 COMPZN RPCOMP THGR P Complete ESP termination at the 5,497.0 5,497.0 09:30 13:30 tubing hanger confine continuity meg penetrator and install into hanger. Instal blind penetrators into hanger. 5/4/2019 5/4/2019 0.50 COMPZN RPCOMP THGR P Land completion, PU WT=41 K, 5,497.0 5,497.0 13:30 14:00 SOW=26K land hanger RILDS. Hold PJSM for plan forward with crew. BHGE tested upper and lower seals. lower seal tested to 5000 psi, upper seal tested to 4000 psi and lost all pressure, retested to 3000 psi and lost all pressure. 5/4/2019 5/4/2019 0.50 COMPZN RPCOMP THGR T Pull TBG Hgr to the Floor, inspect and 5,497.0 5,497.0 14:00 14:30 install new OD body seals. 5/4/2019 5/4/2019 1.00 COMPZN RPCOMP THGR T Re -land tubing hanger. RILDS, retest 5,497.0 14:30 15:30 upper and lower seals to 5000 psi for 10 minutes. Pull Landing joint and remove Isolation sleeve, reinstall landing joint. ESP Clamps: 173 Cross collar clamps. 4 Single middamp 6 GLM to tubing cross collar clamps 5 GLM mid joint clamps 2 MLE cross collar clamps 6 Seal calmps 2 Motor clamps Total Clamps in well =198 5/4/2019 5/4/2019 0.50 COMPZN RPCOMP RURD P RU to circulate IA to tubing with 9.5# 15:30 16:00 corrsion inhbited 3% KCL NaCl Simultaneously move slick -line tools to rig. 5/4/2019 5/4/2019 3.00 COMPZN RPCOMP CIRC P Reverse circulate 1%CRW 132 16:00 19:00 corrosion inhibited 9.5# 3% KCI NaCl at 3BPM 5/4/2019 5/4/2019 0.50 COMPZN RPCOMP SFTY P PJSM, rigging up wire line. 19:00 19:30 5/4/2019 5/4/2019 2.50 COMPZN RPCOMP SLKL P Rig up slick line sheaves, bops, and 19:30 22:00 1 1 1 circulateing sub. 5/4/2019 5/4/2019 1.50 COMPZN RPCOMP SLKL P Run in hole W/ ESP motor on slick 22:00 23:30 line.and set @ 5841', POOH with slick line. 5/4/2019 5/5/2019 0.50 COMPZN RPCOMP SLKL P Mitt pack off And start in hole on Slick 23:30 00:00 line 5/5/2019 5/5/2019 0.50 COMPZN RPCOMP SLKL P Continue RIH with pack off and set, 00:00 00:30 PSI 5/5/2019 5/5/2019 2.50 COMPZN RPCOMP SLKL P RIH with test prong and test @ 500 00:30 03:00 psi. POOH and rig dwn w/line equip. 5/5/2019 5/5/2019 2.50 COMPZN RPCOMP PACK P Rig up Hoses, set psi up T/ 3000 set 03:00 05:30 PKR, PSI IA @ 1000 psi, bleed IA off, PSI up on tubing T/ 2500 psi F/ 15 min. bleed tubing to 15 00 psi pressure test tubing 2500 psi F/ 30min, Bleed tubing and shear SOV. 5/5/2019 5/5/2019 0.50 COMPZN WELLPR PULD P Pull landing jt & LID, set BPV, test @ 05:30 06:00 1000 psi from belw. 5/5/2019 5/5/2019 5.00 COMPZN WHDBOP NUND P NIL) BOP'S 06:00 11:00 Page 3/4 ReportPrinted: 616/2019 Operations Summary (with Timelog Depths) 1 D-116 Rig: NORDIC 1 Job: RECOMPLETION Time Log start DepM Start Time End Tore our (hr) Phase Op Code ActVity Code Time P -T -X Operation (ftKB) End Depth (MB) 5/5/2019 5/5/2019 2.00 COMPZN WELLPR NUND P NIU Tree. 11:00 13:00 5/5/2019 5/5/2019 2.00 COMPZN WELLPR RURD P R/U test hoses, test tree @ 250/4700 13:00 15:00 psi, pull test dart & BPV. 5/5/2019 5/5/2019 1.50 COMPZN WELLPR FRZP P R/U to reverse circulate freeze 15:00 16:30 protection, PT LRS hoses @ 3000 psi pump 130 bbls deseil @ 2.5 bbls/min take returns to kill tank. 5/5/2019 5/5/2019 1.50 COMPZN WELLPR RURD P R/D LRS, blow d bluey line. R/U to 16:30 18:00 1 I I I u -tube. set BPV. 5/5/2019 515/2019 3.00 COMPZN WELLPR RURD P Secure well, install flanges, gauges. 18:00 21:00 Rig released @ 21:00 hrs Page 414 Report Printed: 51612019 PTD /`T9- /-7 7- Loepp, Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, April 29, 2019 10:06 PM To: Hampton, Kyle Subject: Re: [EXTERNAL]KRU 1 D-116(PTD 198-172, Sundry 318-566) Rig Change & BOP Stack Configuration Approval Follow Up Flag: Follow up Flag Status: Flagged This was approved. Thanx, Victoria Sent from my Phone On Apr 29, 2019, at 8:06 PM, Hampton, Kyle <Kyle.Hampton@conocophillips.com> wrote: Victoria, We are beginning to nipple up on 1D-116, and we were hoping for some clarification. Based on the note below, did you also approve the removal of the lower VBR ram? It wasn't clear if you approved this part of our plan. As it stands right now, we are still planning to be tied into the double gate rams for our choke and kill lines (as in previous well configurations). To restate, we are seeking approval to remove the lower double gate rams and use the mud cross as a spacer spool. We are planning to test in the morning and look forward to your reply. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 ( Kyle.Hampton@cop.com From: Loepp, Victoria T (DOA) <yictoria.loepp alaska.aov> Sent: Friday, April 12, 2019 1:58 PM To: Hampton, Kyle <KVIe.Hampton@conocophillips.com> Cc: Regg, James B (DOA) <jim.reKR@alaska.eov> Subject: [EXTERNAL]KRU 1D-116(PTD 198-172, Sundry 318-566) Rig Change & BOP Stack Configuration Approval Kyle, Approval is granted for the rig change to Nordic 1. Approval is granted for the BOP stack configuration which uses a mud cross below the blind ram for kill and choke lines instead of tying into the double gate rams. Thanx, Victoria Victoria Lci Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.LoeopOalaska gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907) 793- 1247 or Victoria.Loeoo@alaska.gov From: Hampton, Kyle <KVle.Ham pton@conocophillips.com> Sent: Wednesday, April 10, 2019 9:06 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Hobbs, Greg S <Gree.S.Hobbs@conocophillips.com> Subject: 1D-116 Sundry Change Victoria, 1D-116 has moved to Nordic 1's schedule, coming up after 1J-174 with an approximate start date of 4/24/2019. Do you approve using this rig instead of Nabors 7ES? Also, we are running into a similar wellhead situation as on 1J-174. We would like to remove the lower VBR ram and replace it with a mud cross, maintaining the state and corporate policies for a category 1 well (blind/shear ram, pipe ram, annular preventer). Do you approve this change? I have attached the email James Hayes sent for 1J-174. We would be using the same stack configuration with one exception: using a mud cross below the blind ram for our kill and choke lines instead of tying into the double gate rams. Please give me a call or email if you need any additional information. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 ( Kyle.Hampton@cop.com P7-V148-1:�Z Loepp Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, April 12, 2019 1:58 PM To: Hampton, Kyle Cc: Regg, James B (DOA) Subject: KRU 1 D-116(PTD 198-172, Sundry 318-566) Rig Change & BOP Stack Configuration Approval Kyle, Approval is granted for the rig change to Nordic 1. Approval is granted for the BOP stack configuration which uses a mud cross below the blind ram for kill and choke lines instead of tying into the double gate rams. 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 foeoora)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC). State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loenu�aalaska gov From: Hampton, Kyle <Kyle. Hampton @conocophillips.com> Sent: Wednesday, April 10, 2019 9:06 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: 1D-116 Sundry Change Victoria, 1D-116 has moved to Nordic 1's schedule, coming up after 1J-174 with an approximate start date of 4/24/2019. Do you approve using this rig instead of Nabors 7ES? Also, we are running into a similar wellhead situation as on 11-174. We would like to remove the lower VBR ram and replace it with a mud cross, maintaining the state and corporate policies for a category 1 well (blind/shear ram, pipe ram, annular preventer). Do you approve this change? I have attached the email James Hayes sent for 1J-174. We would be using the same stack configuration with one exception: using a mud cross below the blind ram for our kill and choke lines instead of tying into the double gate rams. Please give me a call or email if you need any additional information. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com Loepp. Victoria T (DOA) From: Hayes, lames C <James.C.Hayes@conocophillips.com> Sent: Wednesday, April 10, 2019 8:29 AM To: Hampton, Kyle Subject: FW: 1J-174 Sundry Change Request Attachments: 1J-174 10-403 PULL TUBING, REPAIR WELL, Sundry App.pdf Thanks, James Hayes C: +1918.914.9609 From: Hayes, James C Sent: Thursday, March 21, 2019 9:41 AM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: 1J-174 Sundry Change Request Victoria, Hello I'm reaching out to for approval for two things for 1J -174's workover. The first one is easy, can we use Nordic 1 for the workover verses Nabors 7ES for this work over? Do you approve? This well was changed from Nabors to Nordic and we will most likely be moving there here on April 4th. For my second request I would like to take the planned BOP stack configuration to change from a 4 ram system to a 3 ram system. This well has a max predicted surface pressure of 575 psi. So by the state's requirements I have to a 3 ram BOP system an annular, pipe rams, & blind rams. We are going to have height restrictions on the wellhead system on 11- 174 and we would like to drop off our 0 set of rams (the lower single rams) and run a 3 ram system, below is a schematic of what I am proposing. This well was sundried with a 4 ram system and I'd like to request permission to have it changed to a 3 ram system? Ilon' path is beton' blind Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 0: +1907.265.6927 KR�t Prh 10tsr-17-0 Regg, James B (DOA) From: NSK HSE Admin Assist <n1154@conocophillips.com> ��fl q Sent: Monday, February 4, 2019 3:56 PM cy Z'4I I Subject: HSE Lessons Learned - 1 D-116 ESP Pump Coupling Failure 11 Attachments: 20190613 GKA L2 CPF1 ESP Pump Coupling Failure LL.pdf 1 D-116 ESP Pump Coupling Failure Contact your Safety Dept with comments or for further information. Lessons Learned may also be viewed via the HSE Web Page CLICK HERE Please share with others and post appropriately. NSK HSE Administrative Assistant Conoco Phillips Alaska Work: (907) 265-1369 Email: N1154(@conocophillips.com 1 ConocoPhillips HSE Lessons Learned LCA: 113-116 ESP Pump Coupling Failure Business/Facility /Site: CPF1 Incident Description: ZERO 1D-116 is a WestSak producer employing an ESP progressive cavity pump (ESPCP) for its artificial lift which suddenly stopped surfacing fluids on 6/13/2018. Investigation concluded that the splined drive coupling engaged with the pump system's upper seal section shaft completely broke in half due to hydrogen induced cracking (HIC). Key Findings: • The 17-4 PH stainless steel coupling material was found to not meet NACE MR0175 requirements for wet H2S service due to high hardness which raised the risk of HIC damage, especially during pump shutdown periods allowing the bottom hole pressure, and thus the HIC driving H2S partial pressure, to rise. • No specific material requirements for wet H2S service have been defined to date for NSOD downhole ESP equipment due to the inherently low levels of H2S seen across NSOD. Fluid Intake Wireline Rete Engaging Bat Receiving B; Guide Keys Crossover C, (Splined End I Tungsten Ca Support Beai Seal Head Lessons Learned from Incident: • New NACE requirements are under development for ESP equipment. • Findings will be shared across NSOD D&W's. For suggestions, comments or questions, please contact: Pete Fox WSak DPE THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-116 Permit to Drill Number: 198-172 Sundry Number: 318-566 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wvww.aogcc.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, -10 Daniel T. Seamount, Jr. Commissioner DATED this -day of February, 2019. SCANNED " i 5 ppig STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAc 95 9An ice. t� VLE Ig i� ?eq 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Op tions shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Omer L O i5s)D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑� Stratigraphic ❑ Service ❑ 198-172 3. Address:6. API Number: , P.O. Box 100360, Anchorage, AK 99510 50-029-22915-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU WSAK 1 D-116 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 KUPARUK RIVER / WEST SAK OIL 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): 6230 4076 6230 4075 1.087 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 121 121 Surface 6189 7-5/8" 5480 3023 Intermediate Production Liner 453 4-1/2" 6230 4076 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5698'- 5828', 5854'- 5900', 3565'- 3698'. 3715' - 3759', 3-1/2" L-80 5530 5923'- 5964' 3781' - 3820' Packers and SSSV Type: Packer (Weatherford Feed-Thru Hydro II) Packers and SSSV MD (ft) and TVD (ft): Packer (3005' MD / 1994' TVD) SSSV (n/a) SSV (n/a) 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 5I6`L9 1/20 2 15. Well Status after proposed work: 019 Commencing Operations: OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Dale: 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: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. Wells Engine3r Contact Email: kvle.hamptonloikop.conn 20`� Contact Phone: 263-4627 I�LZ / g Authorized Signature: Date: C' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ltd" Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP i-r5t7b /Soop6 Post Initial Injection MIT Req'd? Yes ❑ No R Spacing Exception Required? Yes ❑ No Subsequent Form Required: /,,,9 — g0 T APPROVED BY 2 Approved by: COMMISSIONER THE COMMISSION Date: J 10-403 Revised 412017 poled application isoi fZ 12(; JhRA"als { rD O chments in Duplicate�4 ti ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 17 December. 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 71h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: IV67rdl C— / r`Q ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1D-116 (PTDIt 198-172). Well 1D-116 was drilled and completed in September 1998 as a Kuparuk producer well. In January 2013, the ESP failed, and a workover was completed to replace the ESP. In September 2014, the ESP failed again, and another workover was performed to replace the ESP. In June 2018, the ESP failed; the well was shut in for the workover. The objective of this rig workover is to pull and replace the production tubing and ESP. We will be replacing the previous string with another ESP at 5,530' RK13 and packer at 3,000' RKB. If you have any questions or require any further information, please contact me at 2634627 Sincerely K e Hampton Senior Wells Engineer CPAI Drilling and Wells ID -116 RWO Procedure West Sak Producer PTD #195-172 Current Status: The well is currently shut in. In May 2017, well passed MITIA to 1500 psi. In June 2017, the well passed MITT to 1500 psi. Scope of Work: Pull 3-1/2" tubing and ESP from 5,500' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). General Well info: MPSP: 1,087 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: West Salk —1,420 psi / 3,330' TVD (8.2 ppg EMW) 8.5 ppg KWF Wellhead type/pressure rating: Gray Horizontal, 3 1/8" 5M BOP Config: Annular / Variable Pipe Ram / Blind Ram / Variable Pipe Ram MIT results: MIT -IA —Passed to 1,500 psig/Opsig on 5/20/2017 Well Type: Producer Estimated Start Date: February 10, 2018 Production Engineers: Pete Fox (265-6481 / Pete.B.Fox@conocophiIIips.com) Workover Engineer: Kyle Hampton (263-4627 / Kyle.Hampton@conocophillips.com) Remaining Pre -Rig Work 1. Function test LDS. Test MIT -IA to 1,500 psi. Test tubing and casing packoffs. 2. Pull lower GLV. 3. Swap to dry hole tree configuration for RU. 4. Install BPV. Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and pump KWF from surface to surface. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure, and weigh fluid as necessary. Complete 30 -minute NFT. Verify well is dead. 3. Set BPV, ND Tree, NU BOPE and test to 25 / 1,500)pr Test annular 250/1,500 psi. a. Notify AOGCC of BOP test 2 hours to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 4. Pull BPV and MU landing joint. S. Pull 4-1/2" tubing and lay down the tubing. Install in 3-Y�" Tubing 6. MU 4 Y" completion with ESP, motor, gauges, and packer. RIH and place the ESP on depth. Set packer with ball and rod. 7. Pressure test tubing to 1,500 psi for 5 minutes. Page 1 of 2 113-116 RWO Procedure West Sak Producer PTD #198-172 8. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. ND BOP, NU Tree 9. Confirm pressure tests, then shear out SOV with pressure differential. 10. Install BPV. 11. ND ROPE. NU dry hole tree. 12. Freeze protect well. 13. RDMO. Page 2 of 2 Well 1D-116 API 2002922915 PTD 198-172 Rig (RKB) Nabors 7ES Max DLS 7.8°/100ft C 1.650- RKB Max Pad H2S 214 ppm Well Category Category 1 ConocoPhillips PROPOSED RWO COMPLETION Network If (Drilling) Network K (Wells) AFE Cost AFE Time Max Angle 66.7° @ 1,940' RKB Max Well H2S 10 ppm H2S Radius of Exposure WELL OBJECTIVE Pull 3-1/2" tubing and ESP from 5,530' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). WELL HISTORY Drilled and completed in September 1998 as a Kuparuk producer well. In January 2013, the ESP failed, and a workover was completed to replace the ESP. In September 2014, the ESP failed again, and another workover was performed to replace the ESP. In lune 2018, the ESP failed; the well was shut in for the workover. HSE CONSIDERATIONS CASING INFO MD (ft RKB) TVD (ft RKB) OD ID (in) (in) Weight (Ib/ft) Grade Thread (top) Thread (btm) Conductor 121' 121' 16" 62.5 H-40 Welded IBTM Surface 6,230' 4,075' 7-5/8" 29.7 L-80 BTCM BTCM Production Liner 6,021' 3,875' 4-1/2" 12.6 L-80 BTCM BTCM Tubing (Previous) 5,530' 3,405' 3-1/2" 9.3 L-80 IBTM IBTM Tubing (Proposed) 5,530' 3,405' 3-1/2" 9.3 L-80 IBTM IBTM Top Perf Bottom Perf PERFORATIONS (RKB) (RKB) West SakD 5,698' 5,798' West Sak B -A4 5,798' 5,828' West Sak A3 5,854' 5,900' West Sak A2 5,923' 5,964' 3,000' IBTM IBTM COMPLETION EQUIPMENT PRESSURE CALCULATIONS SBHP 1,420 psi 3,330' ND 8/19/2012 EMW 8.2 PPg IIBTM Gas Column 333 psi (@ 0.1 SIMMPSP IBTM 1IBTM 1,087 si 3,000' COMPLETION EQUIPMENT MD TVD (R RKB) (ft RKB) OD ID (in) (in) Thread (top) Thread I (btm) I Comments ESP/Motor/Gauge 5,498' IBTM IIBTM 4-1/2"X Nipple 5,420' IBTM 1IBTM 4-1/2" x 30-3/4" Packer 3,000' IBTM IBTM Gas Lift Mandrel 2,860' IBTM IBTM FLUIDS Weight Comments/Additives Primary Workover Fluid 8.5 ppg Seawater Back-up Workover Fluid KWF in hole, no back up fluid Corrosion Inhibitor 8.6 ppg Inhibited brine w/1%CRW-132 Freeze Protection Diesel Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, January 21, 2019 10:30 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1D-116(PTD 198-172, Sundry 318-566) C/O tubing/ESP Attachments: BOP -Choke Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, '�-/h /I 9 This well has been pushed back on the schedule as of now. It is set for mid-April on Nordic 1. The BOP and choke schematics are attached. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 18, 2019 11:28 AM To: Hampton, Kyle <Kyle.Hampton @conocophillips.com> Subject: [EXTERNAL]KRU ID-116(PTD 198-172, Sundry 318-566) C/O tubing/ESP Kyle, 1. Which rig? 2. Commencement date? 3. Please provide BOP and choke manifold schematics. 4. 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. Loeppaalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or ViclonaLoe Aaloska.gov • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend U Perforate U Other Stimulate LI Alter Casing U Change Approved Program U Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Sus WellTubing 0 p ❑ Other: Patch_ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhilljps Alaska, Inc. Development j Exploratory ❑ 198-172 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22915-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1D-116 ADL 0025650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 6,245 feet Plugs measured None feet true vertical 4,090 feet Junk measured None feet Effective Depth measured 6,020 feet Packer measured 3,004 feet true vertical 3,874 feet true vertical 1,994 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 15 121' MD 121'TVD PRODUCTION 6,189 feet 6 5/8" 6,230'MD 4,075'MD RECEIVED JUL. 2.1 2017 AOGCC Tubing(size,grade,measured and true vertical depth) 3.5" L-80 5,529' MD 3,404'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-WEATHERFORD HYDROW 3,004' MD 1,994'TVD NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED! NOV 0 12012 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 335 175 Subsequent to operation: 190 138 230 1330 175 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory ❑ Development ❑r Service Copies of Logs Surveys Run ❑ Stratigraphic ❑— P 9 Y ❑ 16.Well Status after work: Oil 0 Gas Li WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR © WINJ Li WAG ❑ GINJ ❑ SUSP❑ SPLUG 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: Contact Name: Marina Krysinski Authorized Name:Marina Krysinski Contact Email: marina.l.krysinski@cop.com Authorized Title:Senior Drillsite Petroleum Engineer /2-0 I 2-0(., Contact Phone: 907-263-4906 Authorized Signature: - Date: I/TL it/4/i Form 10-404 Revised 4/2017 RBDMS Lk/JUL 2 7 2017 Submit Original Only • • • 1D-116 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/25/17 WITH CMDFIRE! SET 2.72" PARAGON PIIP PACKER MID ELEMENT @ 3504' RKB. WITH MAXFIRE! SET UPPER PARAGON 2.72" PIIP PACKER, SPACER PIPE &SEAL ASSY MID ELEMENT @ 3488' RKB (OAL= 16.61')WITH CMDFIRE! SET WFT 2.74"WIDEPAK ERPACKER MID ELEMENT @ 3427' RKB. SET WFT 2.74"WIDEPAK ER PACKER, SPACER PIPE&SNAP LATCH MID ELEMENT @ 3405' RKB (OAL=22.25') MITT TBG TO 1500 PSI PASS) **NON ANNCOMM PATCH INSTALLED** **MITT PASSED against test tool: INITIAL T/I/FL=750/400/200. HAVE TO BUMP UP TBG 5 TIMES TO OBTAIN TEST. START= 1550/425/200 15 MINS = 1525/425/200 30 MINS = 1500/425/200 45 MINS= 1490/425/200. Executive Installed two retrievable patches over two tubing leaks at 3,498' RKB and 3,415' RKB. The first Summary patch is set from 3,504' RKB-3,488' RKB and the second patch is set from 3,427' RKB to 3,405' RKB. The leak at 3,498' RKB was discovered in 2015 and had been patched previously. Both tubing patches are below the top packer at 3,005' RKB and therefore did not repair an annuluar communication problem. y KUP PROD • 1D-116 Conoc Phillips 4 Well Attributes Max Angle&MD TD Alaska inc. Wellbore API/UWI Field Name Wellbore Status nel(9) MD(ftKB) Act Btm(ftKB) ,,,,,,,,030,.., 500292291500 WESTSAK PROD I 66.66 1,938.19 6,245.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1 D-116 6/26/201712.29 50 PM SSSV:NONE 10 12/16/2013 Last WO: 8/28/2011 9/12/1998 Vertical schematic(actt6.9 ... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason.PULL/SET PATCHES pproven 6/26/2017 HANGER;36.9- 1 - = Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread L ,j CONDUCTOR 16 15.062 41.0 121.0 121.0 H-40 Welded lip' ii Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(1...Grade Top Thread PRODUCTION 75/8 6.750 40.6 6,229.6 4,075.5 29.70 L-80 BTCM '"""fCONDUCTOR;41.0-121.0 Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) (Set Depth M..Set Depth(ND)(...I Wt(Ib/It) (Grade (Top Connection TUBING-WO 2015 3 1/2 2.992 36.9 5,529 3 3,404.5 9.30 L-80 EUE 8rd Mod Completion Details li Nominal ID GAS LIFT;2,877.1 Top(ftKB) Top(TVD)(ftKB) Top Incl(9) Item Des Com (in) 36.9 36.9 0.00 HANGER VETCO GRAY TUBING HANGER 2.950 3,004.2 1,993.6 63.89 PACKER WEATHERFORD HYDROW II ESP FEED-THRU DUAL 2.992 STRING PACKER 5,427.3' 3,308.3 20.48 DISCHARGE BAKER CENTRILIFT WELL LIFT DISCHARGE GAUGE PACKER;3,004.2gg GAUGE UNIT i 5,497.8 3,374.6 19.13 ESP INTAKE BAKER CENTRILIFT TTC RECEIVER XO COUPLING W/J-55 PERFORATED INTAKE in 5,502.2 3,378.9 19.07 SEAL BAKER CENTRILIFT TANDEM SEAL SECTION GAS LIFT;3,0870 - 5,516.0 3,391.9 18.88 GEAR BAKER CENTRILIFT GEAR REDUCTION UNIT REDUCTION UNIT UPPER WFT PATCH;3,405.0 {$'. F' 5,517.3 3,393.1 18.87 ESP MOTOR BAKER CENTRILIFT ESP MOTOR 5,525.5 3,400.9 18.76 MOTOR BAKER CENTRILIFT WELL LIFT MOTOR GAUGE GAUGE 11 LOWER WFT PATCH;3,427.0 II 5,527.3 3,402.6 18.74 CENTRALIZE BAKER CENTRILIFT MOTOR CENTRALIZER R UPPER PATCH;3,488.0 Tubing Description String Me...ID(in) l Top(MB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GRAVEL PACK- 41/2 3.958 5,568.2 6,021.0 3,874.7 LOWER PATCH;3,504.0 • ORIGINAL Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(9) Item Des Com (in) GAS LIFT;5,375.3 IF 5,568.2 3,441.4 18.20 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 3.875 5,572.4 3,445.4 18.14 PBR 80-40 UPPER EXTENSION 3.875 5,576.8 3,449.5 16.08 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 5,578.3 3,450.9 18.06 SBE 80-40 SEAL BORE 3.875 DISCHARGE GAUGE;5,427.3 5,580.3 3,452.9 18.04 PBR 80-40 LOWER EXTENSION 3.875 11,1 5,596.0 3,467.8 17.83 XO Reducing XO 3.5 x 4.5 4.500 at 5,660.0 3,528.9 17.26 SCREEN SCREEN 4.5 x.020 3.958 SLIP-STOP;5,455.0 ' . 5,960.3 3,816.4 16.24 SCREEN SCREEN 4.5 x.012 3.958 AI 6,020.4 3,874.2 16.03 PLUG BAKER BULL PLUG 0.000 ESP PUMP;6464.0 XI( Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl ESP INTAKE;5,497.811_11 1ji Top(ftKB) (658) (9) Des Com Run Date ID(in) SEAL;5,5022 - 3,405.0 2,164.9 65.76 UPPER WFT WFT 2.74"WIDEPAK ER PACKER,SPACER PIPE 6/25/2017 1.730 PATCH &SNAP LATCH MID ELEMENT @ 3405'RKB(OAL GEAR REDUCTION UNIT; "" =22 25' 6516.0 ,c ) ESP MOTOR;5,517.3 3,427.0 2,173.9 65.80 LOWER VvFT WFT 2.74"WIDEPAK ERPACKER 6/25/2017 1.730 MOTOR GAUGE,5,525.5 PATCH CENTRALIZER;5,5273 ( ) 3,488.0 2,198.9 65.94 UPPER UPPER 2.72"PARAGON PIIP PACKER(SN: 6/25/2017 1.610 PATCH CPP35056)SP12'OF 1/16"SPACER PIPE @ ANCHOR LATCH SEAL(SN:CPAL35056)OAL= 16.61'/MIN ID=1.61" PACKER;5,568.2 3,504.0 2,205.4 65.97 LOWER 2.72"PARAGON PIIP PACKER(SN:CPP35115) 6/25/2017 1.610 PBR,5,572.4 / i PATCH OAL=4.01' SLEEVE,5,576.8 I 5,455.0 3,334.3 19.69 SLIP-STOP SLIP STOP 6/12/2017 SBE;5,5783 +., 5,464.0 3,342.8 19.57 ESP PUMP 33.58'x 3 1/2"PCESP(SET PUMP IN TTC XO© '6/12/2017 PER;5,580.3 5460'SLM(5498'RKB)(TOP OF PUMP @ 5464' i� RKB)) SO Reducing;5,596 0 5,568.0 3,441.2 18.20 GRAVEL GRAVEL PACK(icon info only) 1/9/1999 3.875 PACK Perforations&Slots Shot 1 Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I) Type Com 5,698.0 5,718.0 3,565.2 3,584.3 WS D,1D-116 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,698.0-5,718.0 L-' I. 5,699.0 5,730.0 3,566.1 3,595.8 WS D,1D-116 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,6990-5,730.0--, mirI 5,762.0 5,798.0' 3,626.4 3,660.8 WS D,1D-116 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,762.0-5,7980 GRAVEL PACK;5,568.0 SCREEN;5,66001 5,798.0 5,828.0 3,660.8 3,689.5 WS B,WS 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,798.0-5,828.0- A4,1D-116 _ 5,854.0 5,900.0 3,714.5 3,758.6 WS A3,10- 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,854 0-5,900 0- 116 5,923.0 5,964.0 3,780.6 3,820.0'WS A2,10- 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,920-5,9640-s I 116 3 I Mandrel Inserts SCREEN;5,960.3 St ati PLUG,6,020.4 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,877.1 1,937.8 CAMCO KBMG 1 DMY BK-5 12/21/2015 PRODUCTION;40.8-6,229.6 KUP PROD 110 1D-116 11 Conoccilhillips Af1 ". .� A aska,lnc. Conor_oKUM, ••• 1D-116,6/26/2017 122951 PM Vertical schematic(actu, ,..: HANGER,36.9— 1 Mandrel Inserts 1' �. c a ni N Top(TVD) Valve Latch Port Size TRO Run Top(ttKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Dale Corn A.A.PCONDIJCTOR;41.0-121.0 2 3,087.0 2,030.1 CAMCO KBMG 1 SOV BK 5/22/2017 w/200 O PSI TGB SHEA R 3 5,375.3 3,259.9 CAMCO KBMG 1 DMY BK • 11/26/2015 GAS LIFT;2,877.1 Notes:General&Safety End Date Annotation 5/15/2010 NOTE View Schematic w/Alaska Schematic9.0 PACKER;3,004 2 1/10/2012 NOTE Weld 6'x10"x 65,.500 pipe over damaged 7 5/8 production pipe from bottom of starter head GAS LIFT;3,087.0 - 1)UPPER WFT PATCH;3,405.0 i' LOWER WFT PATCH;3,427.0 ] UPPER PATCH;3,488.0 LOWER PATCH;3,504.0 GAS LIFT;5,375.3 DISCHARGE GAUGE;5,427.3 SLIP-STOP;5,455.0 ESP PUMP;5,464.0 0,14 •i ESP INTAKE;5,497.8 1111111 SEAL,5,502.2 GEAR REDUCTION UNIT; 5,516.0 _e ESP MOTOR,5,517.3 MOTOR GAUGE;5,525.5 CENTRALIZER;5,527.3 ` PACKER,5,5682 PBR;5,572 4 SLEEVE;5,576.8 SBE,5,5783 PBR;5,580.3 `r� XO Reducing;5,596 0 I • IPERF;5,698.05,718.0L_ •' IPERF;5,699.05,730.0 III — GRAVEL PACK,5,568.0 SCREEN;5,660 0-, IPERF;5,798.0-5,828.0— IPERF;5,854.0-5,900.0— IPERF;5,923.05,964.0— • SCREEN;5,960.3 PLUG;6,020.4 PRODUCTION;40.66,229.6 r r I 410 • �r� o W x Q1• r v (r',z, a C) '0 s_ ' 0 o z v .9, 0 9`m „:. ao 4--' (0 >, ((00 > J'J ¢,Y 0a � ac 0 Q `o III p U v c > +-, r0 .1- N C Y �p C a 17 a =! ° s u Q = a p ....1[ r r r n r n n r n v O m 0 R R R R co co R R C C C C -, 4-, '- N 1n m b r o OZ Z ! 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D C O MOP C N A 14) O 1n 11n 1n N N 1n 1n to 13 O. O C Ca OC ul a) to fi am W Y $ W Y 14 E E V Cr Q I� t, .O (p CO 17 aJ aj r_il Q O c0 c0 C) in m V V O 1n c0 c0 ym,' QJ C i w E z h0 N z - - - p O O N O O N _ E y v a +1 = 2 v1 2 .J O 6 0 W W p Y Y U' W Q Q E ra H N aJ i CL 0 ^ W N fV fV c`') (V N N zCI) 0 0 OCA oaz ,\` t EEE 'N,,,... a` a F- F- STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COI SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate U Pull Tubing LI Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: tbg patch_Q 2. Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development ❑J Exploratory ❑ 198-172 3.Address: Stratigraphic❑ Service❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22915-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0025650 KRU WSAK 1D-116 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 5529 feet Plugs measured 6020 feet true vertical 3405 feet Junk measured 3874 feet Effective Depth measured 6020 feet Packer measured 3004 feet true vertical 3874 feet true vertical 1994 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 121 121 Surface Intermediate Production 6189 7.625 6230 4076 Liner RECEIVED Perforation depth Measured depth 5698'-5964' feet DEC 2 8 2015 True Vertical depth 3565'-3820' feet AOGCC Tubing(size,grade,measured and true vertical depth) 3.5 L-80 5529 `/ 3405 Packers and SSSV(type,measured and true vertical depth) Weatherford ESPfeed tl 3004 1994 No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A scwat t,,14ii, ' 2 '4:1:1A) 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory El Development' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact: Kelly Lyons/Brent Rogers Email n1617@cop.com Printed Name:Kelly Lyons Title Problem Wells Supervisor Signature / Phone 659-7224 Date 12-24-15 ` Form10-404 Revised 5/2015 1/TI- RBD .'ITEC 2 8 1015 Submit Original Only 1/V// ,- 16 • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED December 24, 2015 DEC 282015 AOGCC Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1D-116 (PTD 198-172) for a retrievable tubing patch set in the tubing below the packer. Please call Brent Rogers or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659-7126 if you have any questions. Sincerely, Kelly Lyons Problem Wells Supervisor Attachments • • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/05/15 RWO completed 11/11/15 SET 3-1/2" SIM PLUG @ 4,215' RKB LRS ESTABLISHED LEAK RATE ON TBG OF .3 BBL/MIN @ 2,850 PSI RAN LDL TO IDENTIFY LEAK IN MIDDLE OF TBG JOINT @ 3,498' RKB EQUALIZED AND PULLED 3-1/2"SIM PLUG @ 4,215' RKB 12/03/15 SET 3-1/2"SLIP STOP @ 5,410' SLM SET STATEWIDE 2.72" PARAGON II PACKER (SER.# CPP35041) @ 3,506' RKB CENTER ELEMENT SET STATEWIDE 2.72" PARAGON II PACKER(SER.#CPP35037)W/11.26' SPACER PIPE AND LATCH ASSEMBLE @ 3,490' RKB SET TTS TEST TOOL IN PATCH @ 3,447' SLM LRS PERFORMED PASSING MIT-T TO 1,500 PSI PULLED TTS TEST TOOL @ 3,447' SLM **non anncomm patch installed** **MITT against test tool: 1st attempt fail: preTIO=450/0, intiial=1550/0, 15min=1450/0, 30min=1425/0. 2nd attempt pass: preTIO=1400/0, initial=1550/0, 15min=1550/0, 30min=1550/0** Executive Installed 16' Statewide Oilfield Service retrievable tubing patch, covering a tubing leak at 3498' Summary RKB. This tubing patch is below the top packer at 3005' RKB and therefore did not repair an annular communication problem. " _ KUP PROD � 1D-116 OClocO 'lips IA Well Attributes ^ e J v� Max Angle&MD TD Alaska,Inc, Wellbore APW WI Field Nam Wellbore Status ncl)') MD((tKB) Act Elm(ftKB) crlrrrtwri0" 500292291500 WESTSAK PROD 66.66 1,938.19 6,245.0 ••• Comment H25(ppm) Dale Annotation End Date KB-Grd(ft) Rig Release Date ID-176,12/22/20153.1005 PM 555V:NONE 10 12/16/2013 Last WO: 8/28/2011 9/12/1998 Venial schematic factual) _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __.___.__,._...__..._..._...-___..__.__._ _.,.....-_.........Last Tag: Rev Reason:GLV C/O pproven 12/22/2015 HANGER;36.9 l Ol 1 Casing Strings I !tr..9 I re / Casing Description OD(In) ID(in) Top(ftKB) Set Depth MB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 H-40 Welded . Casing Description OD(In) ID(In) 'Top($50) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 75/8 6.750 40.6 6,229.6 4,075.5 29.70 L-80 BTCM .^A CONoucroR;41.0-1)1'0 "I ^-'-✓"Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...WI(Ibis) Grade Top Connection ) TUBING-WO 2015 31/2 2.992 36.9 5.529.3 3,404.5 9.30 L-80 ,EUE 8rd Mod Completion Details Nominal ID Top(ftKB) Top(TVD)(MB) Top Incl(i) Item Des Com (in) GAS LIFT;2,877.1 r 36.9 36.9 0.00-HANGER VETCO GRAY TUBING HANGER 2.950 3,004.2 1,993.6 63.89 PACKER WEATHERFORD HYDROW II ESP FEED-THRU DUAL 2.992 STRING PACKER 6,427,3 3,308.3 20.48 DISCHARGE BAKER CENTRILIFT WELL LIFT DISCHARGE GAUGE GAUGE UNIT ' PACKER;3.004.2 _. 5,497.8 3,374.6 19.13 ESP INTAKE BAKER CENTRILIFT TTC RECEIVER XO COUPLING W/J-55 PERFORATED INTAKE 5,502.2 3,378.9 19.07 SEAL BAKER CENTRILIFT TANDEM SEAL SECTION 5,516.0 3,391.9 18.88 GEAR BAKER CENTRILIFT GEAR REDUCTION UNIT REDUCTION GAS LIFT:3,087.0 UNIT A 5,517.3 3,393.1 18.87 ESP MOTOR BAKER CEPITRILIFT ESP MOTOR 5,525.5 3,400.9 18.76 MOTOR BAKER CENTRILIFT WELL LIFT MOTOR GAUGE PATCH;3,490.0 GAUGE 5,527.3 3,402.6 18.74 CENTRALIZE BAKER CENTRILIFT MOTOR CENTRALIZER R Tubing Desedpilon Siring Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IblB) Gratia Top Connection GAS LIFT;5,375.3 a GRAVEL PACK- 41/2 3.958 5,568.2 6,021.0 - 3,874.7 ORIGINAL Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl p) Item Des Corn (In) 1 5,568.2 3,441.4 18.20 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 3.875 DISCHARGE GAUGE:5.427.3 1e A ------iii 5,572.4 3,445.4 18.14 PBR 80-00 UPPER EXTENSION 3.875 5,576.8 3,449.5 18.08 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 3.5'DID PACKOFF(OALm'. 5,578.3 3,450.9 18.06 SBE 80-00 SEAL BORE 3.875 6-);5,456.0 5,580.3 3,452.9 18.04 PBR 80-40 LOWER EXTENSION 3.875 XESP PUMP:5.463.0 5,596.0 3,467.8 17.83 XO Reducing XO3.5x4.5 4.500 5,660.0 3,528.9 17.26 SCREEN SCREEN 4.5x.020 3.958 5,960.3 3,816.4 16.24 SCREEN SCREEN4.5x.012 3.958 ESP INTAKE;5,497.8 ME 6,020.4 3,874.2 16.03 PLUG BAKER BULL PLUG 0.000 SEAL:5,502.2 GEAR REDUCTION UNIT; Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 5,516.0 i^ v, Top(TVD( Top Incl ESP MOTOR:5.517-3 -.. Top(ftKB) (ftKB) 1') Des Com Run Date 113(in) `r ,s 3,490.0 2,199.7 65.94'PATCH STATEWIDE 2.72"PARAGON II PACKER(SER.# 12/3/2015 1.600 MOTOR GAUGE;5,525.5 ari✓ CPP35037)W/11.26 SPACER PIPE AND LATCH CENTRALI2ER;5527.3 } ASSEMBLE AND STATEWIDE 2.72'PARAGON II PACKER(SER.#CPP35041)(OAL=16'-3,490- 3,506) 5,456.0 3,335.3 19.68 3.5"D&D TTC-PCP ESP(OAL 33'6') 11/6/2015 PACKER;5.5682 PACKOFF I 1 (DAL=7'F') P50:0,372.4. I5,483.0 3,341.8 19.58 ESP PUMP TTC-PCP ESP 11/6)2015 SLEEVE:5,576.6 - I.. I 5,568.0 3,441.2 18.20 GRAVEL GRAVEL PACK(icon info only) (/9/1999 3.875 OBE;5,578.3I PACK PBR;5,590.3 I Perforations&Slots XO Reducing,5,598.0 Shot Dens Top(TVD) 01m(TVD) (shots/f Top(ftKB) Stet(859) (855) (ftKB) Zone Date I) Type Com 5,698.0 5,718.0 3,565.2 3,584.3 WS D,10-116 1/5/1999 12.0 IPERF 4.5"HOD BH Chgs 5,699.0 5,730.0 3,566.1 3,595.8 WSD,10-116 1/5/1999 12.0 IPERF 4.5"HOD BH Chgs I 5,762.0 5,798.0 3,626.4 3,660.8 WSD,1D-116 1/5/1999 12.0 IPERF 4.5"HSDBH Chgs IPERF:6.898.0.5,718.0 ' 5,798.0 5,828.0 3,660.8 3,689.5 WS B,WS 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs IPERF;5,099.8'5330.f I I A4,1D-116 I._ 5,854.0 5,900.0 3,714.5 3,758.6 WS A3,1D- 1/5/1999 12.0 IPERF 4.5"HSI)BH Chgs 116 IPERF5PACK:5, 8.05,923.0 5,964.0 - 3,780.6 3,820.0 WS A2,1D- 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs ORAVBOOKEN:5,568.0,1,---- IX:REEN;5,660.0 - - 116 IPERF:5,796.0-5.628.0- - Mandrel Inserts St (PEEP 5,854.8-5,900.0- Ml °n Top(TVD) Valve Latch Pod Size TRO Run -•I H Top(ftKB) (868) Make Model OD(In) Sent Type Type (In) (psi) Run Date Com IPERF;5,9210.5,964.0- II 1 2,877.1 1,937.8 CAMCO KBMG 1 DMY BK-51.2/21/2015 1 2,877.1 1,937.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2015 SCREEN:5,960.3 2 3,087.0 2,030.1 CAMCO KBMG 1 SOV BK 12/21/2015 shears PLUG:6,020.4 I, 22(50 psI 2 3,087.0 2,030.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2015 3 5,375.3 3,259.9 CAMCO KBMG 1 DMY BK 11/26/2015 PRODUCTION;40.6-6,229.6 - KUP PROD ID-116 Conoco -- • i. ,� - Alaska,Inc Cnnowtillino 41 ••• 10-116,122220153'10 05 PM Vathcs(schematic(actual) ._...HANGER;369 j IO 1 INa,andrel Inserts IL(' on Top(TVD) Type Latch Pod Size TRO Run H 7o 5,375.33 (3,25 Make Model 05(In) On' Type Latch (In) (pal) Run Dale Com •�'�CONDUCTOR;41.0-121.0 ti 3 3,259.9.CALICO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/312015 Notes:General&Safety End Data Annotation 5/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 i:ll 1/10/2012 NOTE:Weld 6X10"x 65,.500 pipe over damaged 75/8 production pipe from bottom of starter head GAS LIFT.2 B/7.1 PACKER:3,004.2 GAS LIFT;30670 4S V PATCH;3,490.0 ii l S 1 I GAS LIFT;5,375.3 II 1 DISCHARGE GAUGE:5,427.3 1�'I:.d 3.5•DUD PACKOFF(051=7''- ITIF i 8");5,456.0 ESP PUMP:5.463.0 III. ESP INTAKE;5,497.8 HIM SEAL;5,502.2 GEAR REDUCTION UNIT; f o 5.516.0 ffil ESP MOTOR;5,517.3 MOTOR GAUGE;5,525.5 • CENTRALIZER;5,527.3 ( } PACKER;5,5682 11711• ®.- PBR;5,572.4 SLEEVE:5,576.8 I SBE;5,575.3E. PER;5,560.3 XO Reducing;5.596.0 111 I.. IPERF;5.698.0-5,7185 ti- IPERF;S,695.0-5,730.0 , (PERF,5,762.0-5,758.0 I GRAVEL PACK:5,568.0 SCREEN.5,660.0 - I I IPERF;5,798.0.5,828.0 IPERF;5,854.0-5,900.0- I IPERF;5;923.0-5.964-0- I, I II II SCREEN:5,960.3 PLUG;6,020.4 PRODUCTION;40.6-6,229.6. STATE OF ALASKA ADOA OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations FT Fracture Stimulate r Pull F Operations Shutdown Performed: Suspend L Perforate I : Other Stimulate FT Alter Casing r Change Approved Program Plug for Redrill FT Perforate New Pool FRepair Well 1-7 Re-enter Susp Well r Other: I ••••••. 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen F Exploratory fl 198-172 _ 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphi " Service I 50-029-22915-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU 1D-116 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk Field/West Sak Oil 11.Present Well Condition Summary: Total Depth measured 6245 feet Plugs(measured) 6020 true vertical 4090 feet Junk(measured) None Effective Depth measured 6014 feet Packer(measured) 3004', 5518' true vertical 3868 feet (true vertical) 1994', 3441' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 6189 7625 6230 4076 RECEIVED NOV 042015 Perforation depth: Measured depth: 5698'-5730', 5762'-5828', 5854'-5900', 5923'-5964' True Vertical Depth: 3566-3596', 3627-3690, 3715'-3759', 3780-3820' AOGCC Tubing(size,grade, MD,and TVD) 3.5, L-80,5529 MD, 3404 TVD Packers&SSSV(type,MD,and TVD) PACKER-WEATHERFORD HYDROW II DUAL-STRING PACKER@3004 MD and 1994 TVD PACKER- BAKER MODEL SC-1 GRAVEL PACK PACKER @ 5568 MD and 3441 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable SCANNED JAN 2 92016 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: F Daily Report of Well Operations F Exploratory FT DevelopmentService Stratigraphic Copies of Logs and Surveys Run FT 16.Well Status after work: Oil I:....... Gas L WDSPL Printed and Electronic Fracture Stimulation Data FT GSTOR FT WINJ FT WAG GINJ I ••••••. SUSP I—' SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Danny Kane Email Danny.Kaneic7i.conocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature 265-6048 Date VIZ-- /z-1 z 1 15— Form I0 �� OriginalOnly Form 10-404 Revised 5/2015, /4'6� Submit P KUP PROD • 1D-116 vr ConocoPhillips ft, Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Blm(ftKB) - plr�R: 500292291500 WEST SAK PROD 66.66 1,938.19 6,245.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-116,101//2015 2 41.16 PM SSSV:NONE 10 12/16/2013 Last WO: 8/28/2011 9/12/1998 Vertical schamaec(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WORKOVER smsmith 10/6/2015 HANGER 36.9- IF Casing StringsR. 1Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LCONDUCTOR 16 15.062 41.0 121.0 121.0 H-40 Welded �'" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 5/8 6.750 40.6 6,229.6 4,075.5 29.70 L-80 BTCM -A-~/CONDUCTOR,41.0-121.0 ..r.Tubing Strings Tubing Description String Ma...ID(in) Tap(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-WO 2015 3 1/2 2.992 36.9 5,529.3 3,404.5 9.30 L-80 EUE 8rd Mod • Completion Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) 36.9 36.9 0.00 HANGER VETCO GRAY TUBING HANGER 2.950 GAS LIFT;2,877.1 3,004.2 1,993.6 63.89 PACKER WEATHERFORD HYDROW II ESP FEED-THRU DUAL 2.992 STRING PACKER 5,427.3 3,308.3 20.48 DISCHARGE BAKER CENTRILIFT WELL LIFT DISCHARGE GAUGE GAUGE UNIT PACKER;3,004.2 .. 5,497.8 3,374.6 19.13 ESP INTAKE BAKER CENTRILIFT TTC RECEIVER XO COUPLING W/J-55 PERFORATED INTAKE 11 5,502.2 3,378.9 19.07 SEAL BAKER CENTRILIFT TANDEM SEAL SECTION 5,516.0 3,391.9 18.88 GEAR BAKER CENTRILIFT GEAR REDUCTION UNI CATCHER;3,038.8i(_ REDUCTION UNIT WRP Instar;3,049.1 5,517.3 3,393.1 18.87 ESP MOTOR BAKER CENTRILIFT ESP MOTOR It 5,525.5 3,400.9 18.76 MOTOR BAKER CENTRILIFT WELL LIFT MOTOR GAUGE GAUGE GAS LIFT;3,087.0il 5,527.3 3,402.6 18.74 CENTRALIZE BAKER CENTRILIFT MOTOR CENTRALIZER it R Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Tap Connection GRAVEL PACK- 41/2 3.958 5,568.2 6,021.0 3,874.7 ORIGINAL GAS LIFT;5,375.3 111 Completion Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) 5,568.2 3,441.4 18.20 PACKER BAKER MODEL SC-1 GRAVEL PACK PACKER 3.875 it 5,572.4 3,445.4 18.14 PBR 80-40 UPPER EXTENSION 3.875 5,576.8 3,449.5 18.08 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 DISCHARGE GAUGE;5,427.3.: 5,578.3 3,450.9 18.06 SBE 80-40 SEAL BORE 3.875 5,580.3 3,452.9 18.04 PBR 80-40 LOWER EXTENSION 3.875 -- 5,596.0 3,467.8 17.83 XO Reducing XO 3.5 x 4.5 4.500 5,660.0 3,528.9 17.26 SCREEN SCREEN 4.5 x.020 3.958 ESP INTAKE;5,497.8 ':aim 5,960.3 3,816.4 16.24 SCREEN SCREEN 4.5 x.012 3.958 SEAL;5,502.2 _ 6,020.4 3,874.2 16.03 PLUG BAKER BULL PLUG 0.000 GEAR REDUCTION UNIT; 5,516.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ESP MOTOR;5,517.3 ^= .e,,. Top(ND) Top Incl MOTOR GAUGE;5,525.5 t1 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) -- 3,038.8 2,008.9 63.87 CATCHER Junck Catcher:2.70"OD x 2"ID x 10.39'Long 10/4/2015 2.000 CENTRALIZER;5,527.3 3,049.2 2,013.5 63.87 WRP install WRP:2.78"OD x 3.85 Long 10/4/2015 0.000 5.568.0 3,441.2 18.20 GRAVEL GRAVEL PACK(icon info only) 1/9/1999 3.875 PACK PACKER;5,568.2 -s Perforations&Slots PER;5,572.4 Shot SLEEVE;5,576.6 Dena Top(TVD) Btm(ND) (shotsrf SBE;5,578.3 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Data t) Type Com 5,698.0 5,718.0 3,565.2 3,584.3 WS D,1D-116 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs PER;5,580.3 00 Reducing;5.596.0 5,699.0 5,730.0 3,566.1 3,595.8 WS D,1D-116 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs 5,762.0 5,798.0 3,626.4 3,660.8 WS D,1D-116 1/5/1999 12.0 (PERF 4.5"HSD BH Chgs 5,798.0 5,828.0 3,660.8 3,689.5 WS B,WS 1/5/1999 12.0 (PERF 4.5"HSD BH Chgs A4,1D-116 5,854.0 5,900.0 3,714.5 3,758.6 WS A3,1D- 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs 116 5,923.0 5,964.0 3,780.6 3,820.0 WS A2,1D- 1/5/1999 12.0 IPERF 4.5"HSD BH Chgs 116 (PERF;5,698.0-5,718.0 (PERF;5,699.0-5,730.0- i,,„ Inserts St ati mik on Top(ND) Valve Latch Port Size TRO Run IPERF;5,762.0-5,798.0 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GNAVEL PACK;5.66U.0-, -1 2,877.1 1,937.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2015 SCREEN;5,660.0, IPERF;5,798.0-5,828.0 All 2 3,087.0 2,030.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2015 3 5,375.3 3,259.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2015 IPERF;5,854.0-5,900B- ` Notes:General&Safety ► End Date Annotation 5/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;5,923.0-5,964.0- 11 i 1/10/2012 NOTE:Weld 6'x10"x 65,.500 pipe over damaged 7 5/8 production pipe from bottom of starter head minH SCREEN;5,960.3 PLUG;6,020.4 PRODUCTION;40.6-6,229.6 • !► Daily Operations Summary 1D-116 Conacownillips Rig: NABORS 9ES Job: RECOMPLETION Daily Operations Start Date Last 24hr Sum 9/29/2015 Pull the pits away for the sub and stage at the end of the pad. Move the sub off well 1 D-06,move mats over to 1D-116,and spot sub over well 1 D- 116. Spot the pits to the sub,spot the cuttings box,and set up berming. 9/30/2015 Finish rig acceptance checklist and accept the rig at 01:00 hours. Load BST#2 with 8.5 ppg filtered seawater with 3%KCL. RU lubricator, PT to 1000 psi(good test),pull BPV,and RD lubricator. RU circulating equipment for well kill operation. Test hard line with air and PT hard line with water to the kill tank to 2500 psi(good test). Attempt to kill the well with 8.5 ppg filtered seawater with 3%KCI. Final pressures: SITP=92 psi and SICP= 104 psi. Wait for new KWF to arrive from MI mud plant in Deadhorse while monitoring the well. Load BST#2 with 9.0 ppg filtered brine with 3%KCI. Begin circulating 9.0 ppg filtered brine with 3%KCI down the tubing up the IA taking returns to the kill tank. 10/1/2015 Circulated 180 bbls of 9.0 ppg filtered brine with 3%KCI down the tubing up the IA to the kill tank and bullheaded 100 bbls down the tubing. Attempt to bleed the tubing and IA to 0 psi unsuccessful. Circulate an additional 130 bbls of brine and allow time for the well to equalize. Monitor the well for flow for 30 minutes,well static. Install 3"'H'BPV with dry rod,ND tree,and NU BOPE. RU BOPE testing equipment,fill the BOP stack with fresh water,and purge lines. 10/2/2015 Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2"test joint;test annular to 250/3000 with 3-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Louis Grimaldi via email on 9/28/15 at 16:07 hours. RU Centrilift ESP sheave and GBR Tubing tongs pipe handling equipment. Pull test dart,check for pressure under,observed gas/slight flow,pull dry rod,and closed the blinds. Circulate 17 bbls down the tubing out to the cutting box. Opened the blind rams,check for pressure under BPV,no pressure,and pulled BPV. MU land joint into tubing hanger, unseat tubing hanger, and continue to PU to shear release packer at 150K. Observe the well for flow,gas seen at surface,and shut in the well with the annular. Circulated out the packer gas,open the annular,observe the well,and the well is static. Pull tubing hanger to the rig floor. Lay down tubing hanger and landing joint. Well out of balance,circulate 25 bbls down the tubing,observe the well for flow for 30 minutes,and the well is static. POOH standing back 3-1/2"EUE 8rd Mod tubing,spooling ESP cable,and removing cannon clamps from 5514'to 4940'at midnight. 10/3/2015 Continue to POOH standing back 3-1/2"tubing spooling ESP cable from 4940'RKB to 2898'RKB. Well out of balance,stabbed TIW,closed TIW, and MU the TD. Circulate 15 bbls down the tubing out the IA to the cutting box. Observe the well for flow;well static. Lay down 2 GLM assemblies and packer assembly. Continue to POOH standing back 3-1/2"tubing. Lay down ESP assembly. PT the annular and 4"HT-40 TIW to 250/3000 psi with 3-1/2"test joint. PU and MU ESP assembly. 10/4/2015 Continue to MU ESP cable to ESP motor and MU Tec wire to discharge gauge unit. Test ESP cable and Tec wire. RIH with ESP completion per tally testing the ESP cable every 1000'. Had to change out 1 collar and 1 joint due to galled threads during de-completion. MU landing joint and MU tubing hanger. Install ESP cable penetrators into the tubing hanger. Assembly lower ESP cable connector. 10/5/2015 Connect ESP cable connector to ESP cable penetrators in the tubing hanger,land tubing hanger,and RILDS. PT lower and upper tubing hanger seal to 250/5000 psi. Fill the tubing with diesel with LRS and bullhead 105 bbls down the IA with LRS. Pressure up to 3600 psi to set Weatherford Hydrow II packer. PT the IA to 1500 psi for 30 minutes(good test). PT the tubing to 3000 psi for 10 minutes;lost 100 psi on the first test and 50 psi on the 2nd test. Install BPV, ND the BOP,and secure to the stump. NU tree and attempt to PT void but dummy penetrator is leaking. ND tree, replace 0-ring on dummy penetrator,NU tree,and PT void to 250/5000 psi(good test). Pull BPV, install TWC,and PT tree to 250/5000 psi(good test).Pull TWC with dry rod and install'H'BPV with dry rod. Secure the well and release the rig at 23:59 hours. Page 1/1 Report Printed: 11/3/2015 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ ~ -" ( ~2 File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ,_~z./,. Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha owell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Damtha Nathan Lowell Date: ~si • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 15, 2012 [ Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 5LAWIED At, G 2 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor /sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 5/15/2012 1C,1D,1E,2L,3H PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API .# PTD # cement pumped cement date inhibitor sealant date ft bbls ft 4al - 1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1 D -116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E -123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L -304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L -319 50103205520000 2071120 112" 1.00 _ 20" 3/30/2012 6 5/14/2012 2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 3H -17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 • • LA SKA STATE OF A ALASKA OIL AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair w ell ❑ Rug Perforations ❑ Stimulate ❑ Other d SC Repair Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdow n ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ _ R 198 -172 3. Address: 6. API Number. Stratigraphic ❑ Service ❑ P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22915 - 00 — O Q 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 _1 D - 116 9. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 6245 feet Plugs (measured) 6020 true vertical 4090 feet Junk (measured) none Effective Depth measured 6014 feet Packer (measured) 3018 true vertical 3868 feet (true vertucal) 2000 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 .16 121 121 0 0 PRODUCTION 6189 7.625 6230 4076 0 0 0 0 0 j,, ai: ... ., 0 0 0 0 0 0 0 ° RECEIVED Perforation depth: Measured depth: 5698 -5730, 5762 -5828, 5854 -5900, 5923 -5964 True Vertical Depth: 3565 -3596, 3627 -3690, 3715 -3789, 3780 -3820 JAN 1 8 2012 Alaska Oil & as Cans. CotIIh$$IOti Tubing (size, grade, MD, and TVD) 3.5, L - 80, 5514 MD, 3529 TVD Anc115rsy0 Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD HYDROW II DUAL - STRING PACKER @ 3018 MD and 2000 TVD NONE - Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory (j Development j Service ❑ Stratigraphic ❑ X 15. Well Status after work: Oil (� Gas ❑ WDSPL r Daily Report of Well Operations GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -390 Contact MJ Loveland /Martin Walt Printed Name MJ Lovela d Title Well Integrity Project Supervisor Signature P n 659 -7043 Date 1/14/12 C v Gi RBDJ�S JAN 18 20 /- q-r z 47,a- Form 10 04 Revised 10/2 0 '',y. JAN .l 8 Submit Original Only • 0 1D-116 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/26/11 Removed 7' 5" of conductor. Chipped cement and buffed SC. SC appeared to have corrosion through out. Kakivik notified to perform inspection. 01/01/12) Notified stateman (Jeff Jones) of opportunity to inspect damaged SC. I 01/08/12 Cooper heat heated up starter head to 500* F. Welded upper and lower 6" x 8" X65.500 A &B bands on SC. 01 /10 /121Installed and welded 6' X 10" X65 .500 sleeve over damaged piece of SC. I 01/11/12 Initial T /I= SI /0. Performed MITIA (passed) to 3000 PSI for 30 min test. 15 min- 2900. 30 min- 2900. Installed and welded 7' 4" X 16" 62.58# .375 conductor casing. 01/11/121 Denso wrap sleeve. I . • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 14, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1D -116, PTD 198 -172, Sundry 311 -390 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincer , MJ L eland ConocoPhillips Well Integrity Projects Supervisor • Name of Recipient Page 2 of 2 01/14/12 w � . � '' � � nb: • b e ilk y ay v- v ' x e sue, w i s e k't r'' y 6 � '' ` }> �" �` q `o,° .� a ' : r a s + ' 4 - y €. ' 40+ 4 `w ,£ j ; .=•Y .. '+ ",± x t $ .= sf`wd , �ti .'"8; 'w t 1' 9° Xc , • t -,� � w„ � fi x: z r r x �yr V $ a ♦ Y *1 : i -: a ,-.:-ti- '+S'r'�ti . -"f•: F Y w '.:1"!, , 1,.. =. .. , kW we" , s.,x ` ' '. N y'�C 3 , .:.. . �.. �� t x^? �,, ;= � � 'e x a` y ,r 1G. °�- v m at+ E t � Ya x* ;,•". O�onocoPhillips Alaska, Inc � ; This photo is copyright by " ConocoPhillips Alaska, inc. and cannot be released or �^ ' • published without express written consent of }.< ConacoPhillips Alaska I ty r ' peitstestooj "4", ' 0'.' x 4,. LC v v I. r y ' •, } J � . Air I' kk;"''"" P b ' F t ©Conoco Phillips Alaska, Inc This phot is copyright by k x ; ` Cono coPhilli s Alaska, Inc. '-' f p 4 r' �' { ;Mj d cannot b e released of or '4:, � ed wit hout se nt express ar , � + I.. s Alaska '�_ • • Cq Tr t A . (, ' � 146 SEAN PARNELL, GOVERNOR v-Q) h ! - 9 >_ t� ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. i at - 1 /7 a_ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-116 Sundry Number: 311 -390 Dear Ms. Loveland: - r Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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. eamount, Jr. Chair DATED this day of December, 2011. Encl. • • ConocoPh Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 15, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1D -116, PTD 198 -172 surface casing inspection and repair. Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures • STATE OF ALASKA (,LL 1 �� ALAS�IL AND GAS CONSERVATION COMMISS 0 ' A' ' ' U E C 2 0 2011 APPLICATION FOR SUNDRY APPROVALS h' 20 AAC 25.280 Alaska (lii & Gas GM. C011111ini3f 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change RaitiV181 r Suspend r Rug Perforations r Perforate r Pill Tubing r Time Extension r Operational Shutdow n r Re-enter Susp. Well r Stimulate r Alter casing r Other: SC Repair p 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J, Exploratory r 198 -172 . 3. Address: Stratgraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22915 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r • 1D -116 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25650 • Kuparuk River Field / West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6245 - 4090 • 6014' 3868' 6020' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' PRODUCTION 6189 7.625 6230' 4076' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5698 -5730, 5762 -5828, 5854 -5900, 5923 -5964 3565 -3596, 3627 -3690, 3715 -3789, 3780 -3820 3.5 L -80 5514 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - WEATHERFORD HYDROW 11 DUAL - STRING PACKER MD= 3018 TVD= 2000 NONE - -SSSV MD= TVD= 12. Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: / r /O 4O2- 011 r - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r / Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of , ; knowledge. , MJ Loveland /Martin Walters Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature Phone: Date /4 — 0 5'— // Commission Use Only Sundry Number31 I -390 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: — Ai a'f rr ,L , - "s o r r,..S r ho�i 4- to 1 e Lek. do c........4,_-6,...4-ten, e .�7-2 Subsequent Form Required: /0 — Lj0 L( APPROVED BY Id 2-7 � / Approved by: COMMISSIONER THE COMMISSION Date: Form TRJ S MSseUEi 23 I e • iy Zt Submit in Duplicate / Zv t\ ,itet.3 vi- w M • ConocoPhillips Alaska, Inc. Kuparuk Well 1D -116 (PTD 198 -172) SUNDRY NOTICE 10 -403 APPROVAL REQUEST 12/15/11 This application for Sundry approval for Kuparuk (WestSak) well 1D -116 is for the proactive inspection ,% and repair of the surface casing near surface. This well was a single casing packer - ESP well that was drilled and completed in 1998. During proactive casing inspection work the production casing was discovered to have several areas with localized near surface corrosion and significant wall loss. The well is currently secured with a tubing plug post rig workover. While the well is still secured, before being prepared for production, ConocoPhillips intends to excavate around the well head approximately 10' _ deep, remove the conductor, and patch the suspected areas on the surface casing. With approval, inspection and possible repair of the production casing will require the following general steps: v 1! Ensure the well is Secure with a tubing plug. - complete 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel from around well head to an approximate depth of 10' 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove all of then exposed of conductor if needed. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 12/15/2011 STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well 17 Plug Perforations [ Stimulate r Other r Alter Casing r Pull Tubing izro Perforate New Pool r Waiver r Time Extension E Change Approved Program r Operat. Shutdow n Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development N,- Exploratory r - 198 -172 3. Address: 6. API Number: Stratigraphic I' Service r P. O. Box 100360, Anchorage, Alaska 99510 " 50-029-22915-00- CPO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 • e. 1D-116 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 6245 feet Plugs (measured) 6020 true vertical 4090 feet Junk (measured) None Effective Depth measured 6014 feet Packer (measured) 3018, 5568 true vertical 3868 feet (true vertucal) 2000, 3441 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 6189 7.625 6230 4076 SEP 29 201 Perforation depth: Measured depth: 5698'- 5730', 5762'- 5828', 5854'- 5900', 5923' -5964' g i True Vertical Depth: 3565'- 3596', 3627'- 3690', 3715'- 3759', 3780' -3820' r $k8 Oh Gas Cons. Commission Ancnoradjo Tubing (size, grade, MD, and TVD) 3.5, L -80, 5514 MD, 3390 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD HYDROW II DUAL - STRING PACKER @ 3018 MD and 2000 TVD PACKER - BAKER MODEL SC -1 GRAVEL PACK PACKER @ 5568 MD and 3441 TVD NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data . Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development "y Service r Strati r 15. Well Status after work: • Oil I7 Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP I` SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson a a.. 263 -4693 Printed Name Eri • elsot, Title Senior Wells Engineer Signature �/ Phone: 263 -4693 Date Q Form 10 -404 Revised 10/2010 s SEP 2 9 ZQ1� 1 Original Only `/0/ Off" 3�/ ill KU P • 1 D -116 , z Well Max Angle & MD TD .Inc i Attributes F a Well staves Id N Intl (3 IMD (8K8) Act Rim (ftKe) 66 -66 1,938 19 6,245 0 r ilr rxal'FUINp^. 500292291500 WEST S__ _ PROD An ) , L Last WO - End Date KBGrd (ft) Rig Rl se Data • Last Taon Depth (ftKB) End ( Dat. ) Rev Reason W Last WO 8/28/2017 "End Date SSSV NONE � 0 'Date 8!77/2009 Last Mod ..."End Date g �, .__ � R mnam 1 9/11/2011 ; Casing Strings HANGER, 37- ; .: Casing Description I51ring 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.062 410 121.0 121.0 11 Welded a: . Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set De (ND) .. String W[... Siring ... String Top 1 r PRODUC11051 75/8 6.7 40.6 6,229.6 4,075.5 29.70 L-80 BTCM rind Tubing Strings Tubing Description Stony O .. String ID ... Top (1106) Set Depth (1... Set Depth (ND) .. String Wt... String String Top Thrd 1 UBING Details 3 1 2 992 I 36 9 I 5,514.0 I 3 389.8 l 9 30 L L I EU E8RDMOD CONDUCTOR. Lon D 1 Comple 41 -121 .. 1 Top Depth I 7 (TVD) Top Ind Nomi... Top (008L MKS) (1 Nam Description Comment ID(in) t ' 36.9 36.9 -1.17 HANGER VETCO GRAY TUBING HANGER 2.950 3,018.5 1,999.6 63.49 PACKER WEATHERFORD HYDROW II DUAL-STRING PACKER 3.250 5,411.8 3,293.9 21.16 GAUGE WELLIFT DISCHARGE GAUGE UNIT 2.992 GAS LIFT,_ - 2694 - - . : " 5,482 3,359.3 17.87 INTAKE TTC RECEIVER XO COUPLING w/ PERFORATED INTAKE (P/N: 2.992 CSE8442XA) 5,486.4 3,363.6 17.86 SEAL TANDEM SEAL SECTION (P /N C309160) 5,500.2 3,376.7 17.81 GEARBOX GEAR REDUCTION UNIT (S/N 11624881) 5,502.0 3,378.4 17 "80 MOTOR ESP MOTOR,76 HP KMH 1360V/34A (S/N: 11726209) PACKER, a01a -- __ I 5,510.2 3,386.1 17.77 GAUGE WELLIFT MOTOR GAUGE UNIT (SIN: 192-00616) 5,512.1 3,387.9 17.77 Centralizer MOTOR CENTRALIZER. (P/N: C63569) : Tubing Descrpton String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd GRAVEL PACK 4 12 _ 3.958 5,568.2 6,021.0 3,874.5 Completion Details GAS LIFT,. -- Top Depth 3,132 (TVD) Top Intl Nomi... Top (NKBL B) (") Item D i Comment ID (in) „r 5,568.2 3,441.3 17.58 PACKER BAKER MODEL SC -1 GRAVEL PACK PACKER 3.875 5,572.4 3,445.3 17.56 PBR 80-40 UPPER EXTENSION 3.875 5,576.8 3,449.5 17.55 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 3.875 GAUGE, 5,412 - ___.... . - ' 5,578.3 3,450.9 17.54 SBE 80-40 SEAL BORE 3.875 5,580.3 3,452.9 17.54 PBR 80-40 LOWER EXTENSION 3.875 5,596.0 3,467.8 17.48 XO Reducing X0 3.5 x 4 5 4.500 5,660.0 3,528.9 17.26 SCREEN SCREEN 4.5 x 020 3.958 INTAKE, 5,482 - - -- -- � 5,960.3 3,816.0 15A9 SCREEN SCREEN 4.5 x 012 3.958 6,020.4 3,874.0 15.49 PLUG BAKER BULL PLUG 0.000 SEAL, 5,486 - -__ , " 5960000. __ Other In Hole ireline retrievable _plugs, valves pumps, fish, etc.) Top Depth MOTOR, 5,502 -' ' (TVD) Top Inc! To (NKBi, ( 88121 ) () Description Comment Run Date ID(in) GAUGE, 5,510 .' 5,568 3,441.1 17.58 Gravel Pack GRAVEL PACK (Icon into only) 1/9/1999 3.875 Centralizer,_ 5,512 ... Perforations. & Slots _ Shot Top (ND) Btet (TVD) Dens Top (ftKB) Btrn (ftKB) (ftKB) (6158) Zone Date (sh... Type Comment 5,698 5,718 3,565.2 3584.3 WS D, 1D 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs PACKER, S,56B _ - 5,699 5,730 3,566.2 3,595.8 WS D, 1D 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs PBR, 5,572 - `5,762 5,798 3,626.5 3,660.9 WS D, 1D -116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs SLEEVE, 5,577 5,798 5,828 3,660.9 3,689.6 WS B, WS A4, 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 889, 5,578 -- ? 1D Airmen PBR, 5,580 4/ 5,854 5,900 3,714.5 3,758.6 WS A3, 1D -116 1/5/1999 12.0 IPERF 4.5 "1-180 BH Chgs Xo Redoing, `.-`" 5,923 5,964 3,780.1 3,819.6 WS A2, 1D-116 1/5/1999 12.0 IPERF 4.5" HSD BH Chgs 5,596 1 _.. _. _.___ ._._ ___.. ' ` Notes: General & Safety End Date _ Annotation I 5/15/2010 NOTE: View Schematic w/ Alaska Schematic9 0 i Q , 1 li t IPERF, l 9 ;„ IPERF. wxm„ 5,699 -5730 IPERF," I. 5,762-5,798 1 iik Gravel P .560_ ' . 5,060 , SCREE i IPER - ) IPERF, -. 5.798 -5.828 I Mandrel Details IPERF, i r +) Top Depth Top Port 5,8545,900 (TVD) Inc! OD Valve Latch S e TRO Run II Stn Top (ftKB) (11013) () Make Model (in) S Type Type On) (Psi) Run Date C •1 2 895 3 1 942 ` 62.71 CAMCO ! I I KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 828/2011 IPERF ■ 5,923 -5,980 2 3,131 7 I 2,049.5 64.21 CAMCO KBMG 1 GAS LIFT IDMY BK -5 0.000 0.0 8/28/2011 I ' 1 SCREEN, 5,960 11 Il PLUG, 6,020 -.- I: PRODUCTION, 41"6,230 TD, 6,245 1D-116 Pre and Post Rig Well Work Summary DATE SUMMARY 8416/11 MEASURED BHP @ 5405' SLM, PU D 1" SOV @ 5450' RKB, SET 1" DMY VAlk SAME, GOOD INJECTIVITY TEST @ 1 & 2 BPM MAX PRESSURE 950 PSI, TESTED TBG FROM @ 5433' RKB TO 2500 PSI GOOD TEST. COMPLETE. 8/18/11 RAN 2.75" OD BAKER MICRO VERTILOG (MVRT) FROM 250' TO SURFACE. RAN HALLIBURTON MTT -X AND 24 -ARM MULTIFINGER IMAGING TOOL FROM 250' TO SURFACE FOR PIPE INSPECTION. 8/19/11 PRE RWO - T -POT (PASSED), T -PPPOT (PASSED), LDS'S WERE FUNCTION TESTED 8/28/11 Bullheaded 300 -bbl hot - diesel flush down the IA to assist in cleaning tubing and ESP cable, pre -RWO. Pumped 180 -deg F diesel, 1.0 -bpm, max IA pressure 1000 -psi. 9/9/11 SET AVA CATCHER ON WRP @ 3145' RKB. IN PROGRESS. 9/9/11 PULLED 1" DV @ 3131' RKB. PUMPED 35 BBL DSL FREEZE PROTECT. SET 1" DV @ SAME. GOOD DRAW DOWN TEST ON IA. COMPLETE. • • Conoco Phillips Time Log & Summary We!Mew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/1/2011 4:00:00 PM Rig Release: 9/10/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/01/2011 24 hr Summary Completed Well 1D-127. RDMO. MIRU on 1 D -116 Well Slot. Test lines. Circulate Well with 8.6 lb /gal Brine. 16:00 20:30 4.50 MIRU MOVE MOB P Move Rig over from 1D-127 to 1D-116. MIRU. Berm Rig. Accept Rig @ 16:00 hours. Spot Equipment and Tanks. R/U treating iron. 20:30 21:30 1.00 COMPZ WELLPFTHGR P Pick -up Lubricator. Pull the BPV. Lay down same. Tubing pressure = 230 psi. Casing pressure = 180 psi. 21:30 00:00 2.50 COMPZ WELCTI KLWL P PJSM. Notify Security and Pad Operator prior to venting gas. Test lines at 250/3,000 psi. Circulate Well with 8.6 lb /gal Brine w /3% KCL at 4.0 bpm /220 psi. Maintaining back pressure with Choke. 09/02/2011 Complete Well Kill. Install BPV. ND Tree. Install Blanking Plug. NU BOP Stack. Perform initial BOP test. Pull 3 1/2" ESP /HT Completion. 00:00 01:30 1.50 MIRU WELCTL KLWL P Finished circulating Well with 8.6 lb /gal Brine w /3% KCL at 4.0 bpm /200 psi. Returns clean. Total bbls circulated = 278. Close choke and Bullhead an additional 50 bbls into the formation. Monitor Well. Blow down lines. 01:30 02:00 0.50 MIRU WELLPFTHGR P PJSM. Install BPV. 02:00 04:00 2.00 MIRU WHDBO NUND P PJSM. Nipple down Tree. Inspect Lift threads. Good. Install Blanking Plug. 04:00 06:30 2.50 MIRU WHDBO NUND P Nipple up BOP Stack. _ 06:30 14:30 8.00 MIRU WHDBO PRTS P Rig up test equipment. Test BOPE _ rA r per ConocoPhillips and AOGCC requirements at 250/3,000 psi. l 6 Perform Koomey draw down test. Record pressure tests on chart. The State's right to witness the test was waived by C. Scheve 14:30 22:00 7.50 MIRU WHDBO BOPE P Perform Initial BOP test. State Waived Witness to Test. (Waived by Chuck Scheve) 22:00 23:30 1.50 MIRU WHDBO RGRP T Had to change out both Kelly Valves on the Top Drive. 23:30 01:00 1.50 MIRU WHDBO RGRP T Replace Leaking Lower Kelly Valve on Top Drive system. Continue With testing Operation. Page 1 of 8 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 COMPZ WHDBO PRTS P Continue with and completed BOPE test. Tested the Kelly Valves at 250/3,000 psi. Rig down test equipment. 04:00 05:30 1.50 MIRU WHDBO BOPE P Done with testing operation. Rig down hoses and testing equipment. Clear Floor of Spools and Un- needed equipment, test joints etc. 05:30 06:00 0.50 COMPZ WHDBOTHGR P PJSM. Pull Blanking Plug. Pull BPV. Well on slight vacuum. Install Side Isolation Sleeve in Tubing Hanger. 06:00 07:30 1.50 5,514 5,488 COMPZ WHDBOTHGR P PJSM. Pick -up and make -up Landing Joint. BOLDS. Tubing Hanger broke free at 105K.. Pulled the Tubing Hanger to Floor at 90K. 07:30 09:00 1.50 5,488 5,488 COMPZ RPCOM CIRC P Circulate and condition Well with 8.6 lb /gal Brine at 4.0 bpm /170 psi. Total circulated = 250 bbls. 09:00 10:30 1.50 5,488 5,456 COMPZ RPCOM PULL P PJSM. Ready Floor. Remove Penetrators from Tubing Hanger. Hang sheaves and string ESP and Heat Trace Cables over same. Beging to pull 3 1/2" ESP /HT Completion., 09/03/2011 Single down the 3 1/2" ESP /HT Completion. MU the clean -out BHA TIH and clean -out Well to 6,000 -ft. TOOH. LD BHA. Pick -up and TIH with 7 5/8" Test Packer and RBP. Test Casing. 00:00 14:00 14.00 5,456 37 COMPZ RPCOM PULL P Continue to single down the 3 1/2" ESP /HT Completion. Recover (1) 6" Flat Bands, (43) LaSalle Clamps, (2) Protectorlizers,(1) 6' Heat Trace End Shoe, (472) 6' Heat Trace Flat Guards, (23) 4' Heat Trace Flat Guards, (20) 3' Heat Trace Flat Guards, (1702) Flat Bands. There was 96 Jts covered by heat trace. 14:00 15:30 1.50 37 0 COMPZ RPCOM PULD P Lay Down Pump Intake and Pump. Obtain oil sample from motor. Centrilift Serviceman found a broken shaft between the Motor and the Pump. 15:30 19:30 4.00 0 0 COMPZ RPCOM OTHR P Kick out 3.5" Completion and ESP Equipment and Clear and Clean floor. (Discussed the need for a Reverse Circulating Junk Basket run to recover any possible Flat Bands that may have fallen off and remain in the Well). Recovered 10 additional Flat Bands from the BOP Stack. Total recovered = 1,712 ea. 19:30 21:30 2.00 0 0 COMPZ FISH PULD P PJSM. Install Wear Bushing in the Wellhead. Organize Pipe Shed. Bring Baker Tools to Pipe Shed. Tally and inspect same. Page2of8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 1,540 COMPZ FISH TRIP P PJSM. Pick -up BHA #1. Single in with 3 1/2" Drill Plpe from Pipe Shed. Up Weight = 64K. Down Weight = 58K. 39/04/2011 RIH w /Rev Circ Junk Basket to 5,561 -ft. TOOH. TIH with BHA #2 and clean -out to 6,000 -ft. TOOH. TIH with test Packer and RBP. Test Casing. TOOH. RU E -Line and record Logs. 00:00 00:30 0.50 1,536 1,568 COMPZ FISH FISH P Drop 7/8" Ball. Bring Pump on line at 8.0 bpm. Ball on seat. Pressure increase to 1,550 psi. Work RCJB from 1,536' to 1,568'. , 00:30 02:15 1.75 1,568 4,570 COMPZ FISH FISH P Continue to TIH to 4,473 -ft. Work RCJB at 8.0 bpm /2,200 psi. from 4,470' to 4,570' 02:15 04:00 1.75 4,570 5,561 COMPZ FISH FISH P Continue to TIH to 5,538 -ft. Work RCJB at 8.0 bpm /2,330 psi from 5,535' to 5,559' (tag). Continue to work down to 5,561 -ft. (SC -1 Pkr) No further progress. Worked RCJB several more times on bottom. Up Weight = 98K. Down Weight = 76K. 04:00 05:30 1.50 5,561 695 COMPZ FISH TRIP P PJSM. Trip out with BHA #1, standing back the 3 1/2" Drill Pipe in Derrick. 05:30 06:00 0.50 695 695 COMPZ FISH OWFF P Stop at 695 ft and monitor well. 6.6 BPH loss. 06:00 06:45 0.75 695 0 COMPZ FISH TRIP P Continue out hole f/ 695 ft. Up wt 50k. 06:45 07:30 0.75 0 0 COMPZ FISH PULD P Inspect and cleanout RCJB. Recover 4 SS Bands and 5 small pieces of parted bands. MU same BHA for another clean out trip. 07:30 10:00 2.50 0 5,538 COMPZ FISH TRIP P TIH down to 5538 ft, up wt 102k, do wt 98k. 10:00 10:30 0.50 5,538 5,561 COMPZ FISH CIRC P Screw in to top drive and cirulate down to 5,561 ft at 8 bpm, 2450 psi. Seeing 5k down weight from 5,558 ft to 5,561 ft, had to rotate at 15 rpm to reach neutral weight. 10:30 14:00 3.50 5,561 307 COMPZ FISH TRIP P Blow down top drive. PJSM. TOOH to check RCJB. Up Wt 105k 14:00 14:15 0.25 307 307 COMPZ FISH OWFF P Stop and Monitor well for flow. Crane on Location to Swap out spools. 14:15 14:30 0.25 307 307 COMPZ FISH SFTY P Hold PJSM with Crane operator and rig crew. Discuss hazard for lifting operation. 14:30 15:15 0.75 307 307 COMPZ FISH PULD P Unload used ESP spool and Load new ESP cable spool. 15:15 15:45 0.50 307 0 COMPZ FISH TRIP P Continue OOH with Drill Collars and RCJB. 15:45 16:15 0.50 0 0 COMPZ FISH PULD P Remove and Inspect Junk Basket. Had one small pieces of SS Band. Call Out Corrosion Team (Steve Leslie) to Inspect De- Completion Equipment. 16:15 17:00 0.75 0 0 COMPZ RPCOM PULD P PJSM. Clear and Clean Floor. Change handling equipment to run 2 7/8" PAC Drill Pipe. Page3of8 II Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 524 COMPZ FISH TRIP P PJSM. Single in with 2 7/8" PAC Drill Pipe from Pipe Shed to 524 -ft. Stop to change handling equipment to handle 4 3/4" Drill collars and 3 1/2" Drill Pipe. 18:00 21:30 3.50 524 5,558 COMPZ FISH TRIP P Continue to build BHA #3 as follows: XO, Csg Scraper, Bumper Sub, Oil Jar, 6 ea 4 3/4" Drill Collar. Continue to trip in hole with 3 1/2" Drill Pipe from the Derrick to 5,558 -ft. Up Weight = 95K. Down Weight = 75K. 21:30 00:00 2.50 5,558 6,013 COMPZ FISH WASH P Bring Pump on line at 5.0 bpm /710 psi. Had to wash with slow progress through trash down to top of SC -1 Packer at 5,561 -ft dpmd. Once inside Packer continue washing down inside the Screen Assembly section with rapid progress to 5,574 -ft. Stop and reverse circulate 150 bbls at 5.0 bpm /200 - 425 psi. Saw no solids in returns. Continue in hole with Pump off looking for top of Fill. Stop at 5,765 -ft. Reverse circulated bottoms up at 5.0 bpm /540 psi. Continue in hole with pump off. Tagged top of fill at 5,946 -ft. Wash down to 5,957 -ft. Reverse circulate bottoms up at 5.0 bpm /900 psi. Continue washing down to 6,013 -ft dpmd. Set down solid on the Bull Plug at the bottom of the Screen assembly. X9/05/2011 Rev Circ Well clean from 6,013 -ft dpmd. TOOH with Clean -out BHA. RIH with test Packer and Retrievable Bridge Plug. Test Casing. Spot sand on top of RBP. RU E -Llne Unit and record Logs. RD E -Line. TIH. Wash sand and release RBP. POOH and single down 3 1/2" Drill Pipe. 00:00 05:00 5.00 6,013 5,545 COMPZ FISH CIRC P Reverse circulate from 6,013 -ft. Reverse in a 30 bbl Hi -Vis Sweep and reverse back to surface at 5.0 bpm /925 psi. Unable to see any solids in returns due to thick oil in returns. Monitor Well. Slight flow coming back up the Annulus. Circulate the long way to balance Well. Still have a very slight flow from the Annulus. Pull BHA out of / the Screen assembly and Park at 1� 5,545 -ft. Monitor Well. Shut in Well r 7 � (Upper Pipe Rams) to monitor pc SIDPP. Drill pipe pressure at 10 psi and stable. Notify Supervisor that Well was Shut in. 05:00 09:30 4.50 5,545 5,545 COMPZ RPCOM OWFF T Move Fluids in Pits and prep to weight up to 8.7 lb /gal. Notify AOGCC and Anchorage Engineer that the Well had been shut in. Page 4 of 8 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:45 3.25 5,545 5,545 COMPZ RPCOM CIRC T PJSM. Circulate well over to 8.7 ppg Brine w/ 3% KCL. Pump rate at 5 bpm, 780 psi. Pumped 345 bbls total (1.5 Times wellbore volume). 12:45 13:15 0.50 5,545 5,545 COMPZ RPCOM OWFF T Observe Well for flow. Hold PJSM, Discuss hazard for Tripping operations. No Flow from wellbore. 13:15 15:15 2.00 5,545 520 COMPZ RPCOM TRIP P TOOH standing back drill pipe & drill collars. Up wt= 98k. 15:15 17:30 2.25 520 0 COMPZ RPCOM PULD P Single Down 2 7/8" PAC Drill Pipe. Change over to handle 3 1/2" Drill Pipe. Clear Floor. 17:30 18:00 0.50 0 0 COMPZ WHDBO BOPE P PJSM. Pull Wear Bushing. Set Test Plug. Rig up test equipment. 18:00 19:00 1.00 0 0 COMPZ WHDBO PRTS P Pressure test the Upper Pipe Rams and Valves 2,5,6 at 250/3,000 psi per Conoco /Phillips requirements. The State's right to witness the test was waived by C. Scheve. The test was recorded on a chart. 19:00 20:00 1.00 0 0 COMPZ WHDBO PRTS P Rig down test equipment. Pull Test Plug. Install Wear Bushing. 20:00 22:30 2.50 0 5,525 COMPZ RPCOM TRIP P PJSM. Bring Baker Bridge Plug and Packer to Floor. Inspect same. Trip in with Baker Model G Lock -Set RBP, Retrieving Head, Baker Retrievamatic Packer, and Drill Collars. Continue to trip in with 3 1/2" Drill Pipe. 22:30 23:30 1.00 5,525 5,493 COMPZ RPCOM PACK P Up Weight = 100K. Down Weight = 75K Set the Baker Model "G" Lock -Set RBP at 5,525 -ft (center element). Release from RBP. Top of Fish Neck at 5,520 -ft. Lay down 1 Joint of Drill Plpe. Set Baker MOdel "L" Retrievamatic Packer at 5,493 -ft. (center element). 23:30 00:00 0.50 5,493 5,493 COMPZ RPCOM PRTS P PJSM. Rig up test equipment. Pressure up on the Drill Pipe and test the RBP at 2,000 psi x 15 minutes, Good. Record on Chart. Bleed pressure down to "0" psi. 09/06/2011 Test Csg. TOOH and LD Pkr. TIH and spot Sand on top of RBP. TOOH. RU E -Line and record Logs. 00:00 00:45 0.75 5,493 5,493 COMPZ RPCOM PRTS P Pressure up on the 7 5/8" x 3 1/2" Drill Pipe Annulus to 2,000 _psi x 15 minutes. Good. Record on chart. Rig down test equipment. 00:45 05:00 4.25 5,493 0 COMPZ RPCOM TRIP P PJSM. Release Packer. Trip out, standing back the 3 1/2" Drill and the 4 3/4" Drill collars in the Derrick. Lay down the Packer. 05:00 07:30 2.50 0 5,491 COMPZ RPCOM TRIP P Pick -up Baker Retrieving Head. Trip in with 3 1/2" Drill Pipe. 07:30 09:45 2.25 5,491 5,512 COMPZ RPCOM OTHR P Dump 300# sand on RBP. Let Sand Settle, Flush Drill Pipe with charge pump. RIH and tagged top of sand at 5,512.0 Page 5 of 8 time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 5,512 0 COMPZ RPCOM TRIP P PJSM. Blow Down Top Drive. TOOH racking back 3 1/2" Drill Pipe. Up Wt =100k, Dn Wt =75k. 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD P Lay Down BHA. Clean & Clear Rig Floor, Un -load Baker Tools. 13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM with HES E -Line Crew and Rig Crew. 13:15 15:30 2.25 0 0 COMPZ RPCOM PULD P MIRU E -Line Unit. Load E -Line equipment and tools to Rig Floor. Start Loading 3.5" Tubing to Pipe Shed. 15:30 23:00 7.50 0 5,510 COMPZ RPCOM ELOG P RIH w/ HES 40 -arm caliper & memory with Gyro down to 5,510' and Log back to Surface. 23:00 23:30 0.50 0 0 COMPZ RPCOM PULD P On Surface with logging tools, Caliper arms closed @ 23:22. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P Lay Down tools, Check Memory Data, Bring in Baker logging tools. 39/07/2011 Continue E -line Logs. TIH and wash sand off of RPB. Release same and stand back 3 1/2" Drill Pipe. Prep for 3 1/2" Completion. TIH with TTC -ESPCP 3 1/2" Tubing Completion with Feed -thru Packer. 00:00 00:30 0.50 0 0 COMPZ RPCOM ELOG P PU MU Baker MicroVertiLog / CCL / GR. 00:30 02:30 2.00 0 1,767 COMPZ RPCOM PULD P TIH with Barker MicroVertiLog / CCU GR on 12 -ft of 2" weight bar to 1,767 -ft (65° deviation) attempt to work deeper, log up to surface, Lay down and kick out Barker tools. RDMO E -line unit 02:30 03:15 0.75 0 0 COMPZ RPCOM OTHR P Bring in Baker Retrieval Head and ESP completion equipment. 03:15 03:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM w/ Barker Rep, Tripping in Hole with DP. 03:30 06:00 2.50 0 5,515 COMPZ RPCOM PULD P PU MU Baker Retrieving Head and RIH on 3 1/2" DP. 06:00 08:30 2.50 5,515 5,525 COMPZ RPCOM CIRC P Taq Top Sand at 5,515 ft, Qirculate sand out to 5,525 ft. Pump 30 bbls Hi -Vis sweep around at 5 bpm, 590 psi, pump until clean 8.7 ppg brine was seen at surface. Latch and Release RBP. 08:30 09:00 0.50 5,525 5,525 COMPZ RPCOM OWFF P Monitor well for flow. Well on a slight vac. 09:00 09:15 0.25 5,525 5,525 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for TOOH and Monitor hole fill. 09:15 12:00 2.75 5,525 0 COMPZ RPCOM TRIP P TOOH w/ RBP. Up Wt= 105k. Lay down RBP and Kick -out. 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD P Change Out Floor Equipment. Pull Wear Ring. 13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with Centrilift and Rig Crew. Discuss Hazard with handling and Making up Lower ESP Section. 13:15 17:30 4.25 0 0 COMPZ RPCOM RCST P MU motor centralizer, welllift sensor and motor. P/U gear reduction unit and tandem seal section and fill complete section with ESP Oil. Page 6of8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 23:30 6.00 0 0 COMPZ RPCOM OTHR T Found that the slotted Intake on the TTC receiver XO Coupling was damaged. Attempt to drift damaged Intake with solid 10' x 2.803 ", will not pass bottom of slotted intake. Hotshot for Intake pulled from prior completion. TTC receiver not the same as new model TTC receiver, send to Baker Machine to swap out slotted intakes. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR T TTC receiver XO coupling with replaced slotted intake on site, bring in ESP equipment. 09/08/2011 TIH with TTC -ESPCP 3 1/2" Tubing Completion with Feed -thru Packer. PU MU and Land TBG Hanger, RILDS and Test. TIH to Set WRP. 00:00 01:00 1.00 0 3,000 COMPZ RPCOM PULD T PJSM with Centrilift and Rig Crew. Discuss Hazard with handling and Making up Lower ESP Section. PU MU ESP Cable and TEC wire to Lower ESP section. 01:00 05:30 4.50 3,000 3,000 COMPZ RPCOM TRIP P Continue TIH w/ TTC- ESPPCP 3 1/2" completion with Feed -thru pkr. 05:30 09:00 3.50 3,000 3,018 COMPZ RPCOM PACK P Stop and make splice at the ESP Feed -Thru Packer. 09:00 12:30 3.50 3,018 5,480 COMPZ RPCOM RCST P Continue in hole f/ 3,018 ft. Up Wt =87k / 62 K. 12:30 13:00 0.50 5,480 5,480 COMPZ RPCOM THGR P Pick -up and Make up Tubing Hanger , and Landing Joint. Up wt 91k / Dn wt 64k 13:00 16:00 3.00 5,480 37 COMPZ RPCOM OTHR P Perform Final Splice of ESP Cable at tubing hanger. 16:00 16:15 0.25 37 37 COMPZ RPCOM THGR P Land Completion and RILDS. Clamp Count: 4 ea. Protectolizers 3 ea. Flat Guards 3 ea. Single Channel Cross Coupling Clamps 95 ea. 2' Mid Joint Dual Channel Clamps 16:15 16:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for removing riser and installing shooting flange. 16:30 19:00 2.50 0 0 COMPZ RPCOM PULD P Nipple down Riser and Install shooting flange. 19:00 19:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Rigging up Slickline Equipment. 19:15 20:30 1.25 0 0 COMPZ RPCOM PULD P Bring in Slickline equipment and Rig Up same. Pressure test 3000 psi. 20:30 22:00 1.50 0 1,850 COMPZ RPCOM SLKL P RIH w/ Slickline KOT to locate Lower GLM, unable to fall past 1,850 -ft POOH add weight bar to toolstring 22:00 23:30 1.50 0 3,115 COMPZ RPCOM SLKL P RIH w/ Slickline tools, locate Top of Lower GLM at 3,115 -ft, Flag Wire - POOH Page 7 of 8 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 3,146 COMPZ RPCOM SLKL P RIH with 3" WRP on HES 1 11/16" DPU to 3,146 -ft, DPU set to stroke at 00:22 on 09/09/11 09/09/2011 Set WRP. Pump 110 bbls gelled diesel to IA. Set PKR. MIT IA. Freeze protect TBG. Set Catcher. NU TBG Head. Make Final Checks. RDMO 00:00 01:00 1.00 3,146 3,146 COMPZ RPCOM SLKL P 3" WRP on HES 1 11/16" DPU at 3,146 -ft, DPU set to stroke at 00:22 01:00 01:30 0.50 3,146 0 COMPZ RPCOM SLKL P POOH w/ DPU, WRP Set 01:30 01:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM with Relief Slickline Crew on job Hazards. 01:45 02:15 0.50 0 3,145 COMPZ RPCOM SLKL P RIH w/ Catcher (27" oal) on 3" GS: Set on WRP at 3,146 -ft- POOH w/ Catcher due to poor tool action. 02:15 03:00 0.75 0 3,145 COMPZ RPCOM SLKL T RIH w/ Catcher (27" oal) set at 3,145 -ft POOH, load KOT 03:00 03:30 0.50 0 0 COMPZ RPCOM T Waiting on Transport of Gelled Diesel, Transport was loaded and delivered earlier with only 85 bbls, Transport now has 119 bbls. 03:30 06:30 3.00 0 0 COMPZ RPCOM PACK P Pressure test line and equipment. Load IA with 110 bbls Gelled Diesel at 1/2 bpm, increase rate to 3/4 bpm at 400 psi. 06:30 12:00 5.50 0 0 COMPZ RPCOM PACK P Circulate and Pressure up tubing to set hydrow II packer. Increase pressure from 1500,2000,2500,3000 and 4000 psi and set packer. Bled psi to zero and PT IA 1680 psi for 30 mins. Bled per schedule. ✓ 12:00 14:30 2.50 0 0 COMPZ RPCOM SLKL P PT Lubricator and RIH with slick -line to pull DV. Bullhead 35 bbls Diesel down tubing at 3 bpm, 250 psi. RIH set DV & test tubing to 400 psi. Set TWCV. 14:30 14:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Rigging down Slick -line. 14:45 15:45 1.00 0 0 COMPZ RPCOM SLKL P RDMO Slick -line & Equipment from Rig Floor. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM w/ Crane operator and rigger. 16:00 17:00 1.00 0 0 COMPZ RPCOM OTHR P Remove ESP Spool from Rig floor and Install a empty spool. 17:00 19:30 2.50 0 0 COMPZ RPCOM NUND P Nipple Down BOPE and Nipple Up Tree. Rig Off Shore Power at 17:00 19:30 22:00 2.50 0 0 COMPZ RPCOM PRTS P Test Hanger Void 5000 psi. Test Tree 5000 psi and chart. 22:00 00:00 2.00 0 0 COMPZ RPCOM RURD P Pull 2 way check and install CIW 3" 'H' BPV. Clean Cellar. Prep for Move. PJSM- Rig Move. RDMO. Nordic Rig 3 released @ 24:00 on 09/09/2011. Centralift Final Checks: Phase to Phase 2.2, Phase to Ground 5.4G Page 8 of 8 • • WELL LOG TRANSMITTAL PROAcTiWE DiACNosTic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 n '�` SE 1 5 ZU Li 2a 1 Caliper Report 06- Sep-11 1D-116 1 Report / CD 50- 029 - 22915 -00 2) Caliper Report 08- Sep -11 1Y -19 1 Report / CD 50-029 - 22391 -00 Signed : , Date : 3 eZfVl,l Print Name: b Ist->i t,r j_ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAX: (907)245 - 8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WERSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distributian\ TransmittalSheeis \ConocoPhilips_Transmit.docx � 9 F 1 • • .... 0 Memory Multi- Finger Caliper Log Results Summary ' Company: ConocoPhillips Alaska, Inc. Well: 1D-116 Log Date: September 6, 2011 Field: Kuparuk (West Sak) 1 Log No.: 10184 State: Alaska Run No.: 2 (1 x MTT, 1 x MIT) API No.: 50- 029 - 22915 -00 Pipet Desc.: 7.625" 29.7 Ib. L -80 BTCM Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 5,510 Ft. (MD) 1 Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : 1 This log is correlated to the Sperry Sun Induction Gamma Ray Log dated September 8, 1998. This log was run to assess the condition of the surface casing with respect to corrosive and mechanical 1 damage, as well as to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate the 7.625" surface casing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross - sectional 1 wall Toss or I.D. restrictions recorded. Although no significant I.D. restrictions are recorded, the caliper recordings indicate slight buckling from —400' to —650', —740' to —780', —860' to —1,035', and — 1,110' to — 1,130', with areas of slight ovality due to I mild buckling at 503', 543', and 1,128'. An overlay of the centered and off - center caliper recordings highlighting the areas of slightly buckled 7.625" surface casing is included in this report. Although PDS has run a Magnetic Thickness Tool (MTT) once in this well, this is the first time a PDS caliper 1 has been run. MAXIMUM RECORDED WALL PENETRATIONS: 1 No significant wall penetrations (> 17 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall loss (> 5 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the surface casing logged. 1 1 1 I I Field Engineer: E. Gustin Analyst: C. Waldrop Witness: R. Ober & S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565-1369 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 —� ?). 1� 1 • • t> PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk ( West Sak) Well : 1D -116 Date : September 6, 2011 1 Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing. Maximum Diameter Depth 3 -D Log (Off- Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) I 6 inches 8 1ft.600ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° Minimum Diameter I 6 inches 8 I 6 Nominal I.D. inches 8 t i p - ' ; 1 � � ! a 75 f - IN � 11 I M111111i1111 ` Num RE ��M�� 100 . r r i -" 111 : WIN EIIIIIIMIIIIIIIIIIIIII ell,- t IMIt11111111111111111MMi 125 MIME IMI III♦ 1111111111M1111111111=1111= orm.... IX ��Idi� ell• 150 a =NMI i i ii it 1aii 1l 11= 175 . y 1 m. t�1�� 225 say. , isI IMMI ' �131�i�I� "� - '17. IIIIIIIIID IIIMI i1•111M1• �13��t� 250 1 1 11 1111 I .10111111 i(elitNIMEIMMIN■ MEMEl�l1 .1t> MM= 275 V tom! 1 t1111111 _____ t i si �� 300 . < ., I emiimti �t IMMUNE= e;- mum: I Et>•m1lim 325 IMINilmioommis W MIME )11111111MMINIM _ a- IIIMIIIIIIIIIMIN 1 � 7��1.1•� =�}■��1• 350 r — 1 1..ii = min It IMIIIMIIIIIIIMION MIN E MI �e=r� 375 MI= 1111=1•111111111111111111 _ 4 i.d5eiMIaI• 40 0 �EIIi 1 #1 11111101111r41=111111=111111 r a lit. ∎ia��NM�� 425 - . , 1 t if /0 . ; 4 , 1 ' ,.ii, tnttriVri T li" 04'1 " u i1'o!n. i o' oo?hi t ., }tAI N to -n, le 1911N) U ,inin wad r )4114 e M t. *1 9 ,, , :: t r tt, a. 1,i ii. , is „., 4� —....,4 4 1. `f i ` i {�Ptl, � ,.,. 1ti `' itt. , a , 4 i 4 eT Y ' t I i i i ', °. 1 $11 1 c T � +1 t ' e � '� IT O ,w , at ri a r ' ar ' ' �tlRr N .. "� y m *4 . ottettitikiwos e T x ,,,, . M.-.- ,,,,,,,...i. , , A. ,. -d41 v. -...r ..te t .- it w r ,- sietprolitior d4 _ ,�'. '� M� ,� .� r 7 • , .,p. a... .. Ia., 44 :Y, 444. US E, ht 0 119 0 10 0 10 0 10 0 to G Y9 0 10 0 10 0 119 0 10 1� 0 N 10 IS 0 N 10 1• 0 N 1A 1s 0 N 10 Its 0 of In 119 N 114 t0 40 /0 10 ti ti ti CO CO CO CO 01 • 1�1111111111111111I11I1111111I11IUI111111 11l11I111111111I11111111mI1111 111 i11111111111i1 11111111111111111111111n1I11 1 1�I1111111l1111I111111111111 $111111 1111 11111111111111111111111h1111I11111111111111 1 1111111111h1I1111111I11111111111I1111 1111 IunI11I1111111 11111n1I1s1111l11I1111n111111 1 I nmili111l1111111111111111n111n11n1 Inil 1111111111111111!11111 111111111111111111111111I11111111111111111111111111111111 11II1 g "�1 /tapt#Pww �.� � �rrr1r�1�, - � .., �t# n n'��1 � � .�w�. � fit# e.,�h*r•^ r "* �aleeii t d_ IMihIM tM !�ilr��iill,!!! +l.e.nHtTM� r Ra+.....1 tTCr ..: ...,m, 4M,„.„,p.., � iIi mi l11i1riiiWliiimn11111 ii i iinni11111iilli11111111111III l iiiiiINUI1111111111i 111111111111111111M11111111111111111111111111111111M11111111M11111111111111111111111111111111111 li11111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 Iv1111111111111111111H11M111111111111111111111111111111111111111M1111111111111111111111111111111 1 •_ 1 • ____li1____� - Nomm�rdl�� III•___1111111•IIII•__m 950 =it•ifili11111l••� 1 ____1i11MMIIMI111•II• 975 ■ 111111111•11111MIM IIMM =11111111 i1MIIMMIIII IIMIEMIIII. =EMI _ ,48k IIIIIM-II I If >•____ 1000 1 .......... IIIIiM1•71ii•i a 11111iIMiiUii =��r .1a�� 1 025 ', 1♦111111ME o = .....•■■ - �1•�i(411.1•ii _•__Is}1•_•1= 1050 =��i3i� = == -- 111111•11111i1lfliii1111111 - =MIi��]I�IM�II• 1075 ____I31____ ar 11.MMIVat:inilinlIN -- �iMi liii l 1 i �� =�It71�11M=111• 11 - _ ___ ®J �� == ___!'e'11i_•i - - .... _i_i'Hli_i_ t 1 MNIIfiINI fsaMININIENIIIIIIIIII MI 1125 ___'is1_____ __ I _ __ _IM � fill•l�l�t,#1�MM� 1150 1 ____I 'I,___I_ =i�i(Iliii1M �i_i'3I_�i� �i�il�liiN 5 i ��IIII•tA1�� 11 ____1A1____ 1 ____tI1____ IMi_itgliii= 1111111111111= MIME 1•1== =131111111111=1 1200 mmNI _I'1___ �: - i-i.� — 1 ____,fa____ 1•iINit 11iii� MIIINIMISIM41MIIIIMIIIIMMIII 1 225 v. ____1•�,____M ��11111 �= 1250 =M1 1 � =i41�� =MIS -..- _i_ii 1#liiiMI �iMii /1liiiM MEW H 11111111111111•111 -- 1 MIIIII•ll� 111 =MM= 1275 �i_i' RJiii_ . _ittliii__ MMIMmiim U Nominal I.D. inches 8 Minimum Diameter I 6 inches 8 Maximum Diameter Depth 3 -D Log (Off - Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) 1. MP * — -; - 6 inches 8 1f:600ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° 1 1 1 1 1 1 I • • Correlation of Recorded Damage to Borehole Profile I • Pipe 1 7.625 in. (53.9' - 5506.1') Well: 1 D -116 Field: Kuparuk (West Sak) I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: September 6, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 56 1 10 437 1 20 \ 863 1 30 1290 40 1705 1 50 2120 _ 0 60 2542 c Z ' 70 2968 �- o 0 80 3400 90 3825 I 100 4250 1 110 4674 120 5096 130 5506 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 130 1 1 • • 1 Report Overview S Body Region Analysis 1 Well: 1D -116 Survey Date: September 6, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 40 XR No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7.625 in. 29.7 ppf L -80 BTCM Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7.625 in. 29.7 ppf L -80 BTCM 6.875 in. 7.625 in. 6.0 in. 6.0 in. I Penetration(% wall) Damage Profile (% wall) 150 ■m Penetration body Metal loss body 0 50 100 1 0 E 100 50 0 I 0 to 20% 20 to 40 to over 40% 85% 85% ii Number of joints analysed (total = 131) I 131 0 0 0 50 I Damage Configuration ( body ) 10 5 1 100 I 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 3) 3 0 0 0 0 Bottom of Survey = 130 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf LSO BTCM Well: 1D-116 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. Country: USA Survey Date: September 6, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 54 0 0.03 7 1 6.87 Pu p 1 56 0 0.03 7 2 6.80 2 100 0 0.02 5 2 6.77 3 142 0 0.02 5 1 6.79 4 185 0 0.03 9 4 6.81 5 227 0 0.03 8 2 6.80 6 270 0 0.03 8 4 6.82 7 311 0 0.03 7 2 6.79 8 355 () 0.02 6 2 6.79 I 9 397 0 0.04 9 3 6.76 Slight Buckling. 10 437 0 0.03 9 2 6.79 Slight Buckling. 11 481 0 0.04 10 3 6.75 Slight Ovality due to Mild Buckling. 12 523 0 0.04 10 2 6.75 Slight Ovality due to Mild Buckling. ' 13 565 0 0.03 8 .5 6.79 Slight Buckling. 14 608 0 0.04 11 3 6.83 Slight Buckling. 15 652 O 0.03 8 3 6.82 16 694 0 0.03 8 2 6.80 I 17 737 0 0.03 8 2 6.80 Slight Buckling. 18 780 0 0.03 8 3 6.84 19 823 0 0.04 9 4 6.83 20 863 0 0.03 8 2 6.78 Slight Buckling. 21 907 0 , 0.02 6 1 6.79 Slight Buckling. I 22 949 () 0.03 8 2 6.84 Slight Buckling. 23 993 0 0.03 7 2 6.80 Slight Buckling. 23.1 1036 0 0 0 0 6.77 Tam Port Collar 24 1038 0 0.03 8 2 6.82 I 25 1081 0 0.04 10 2 6.78 26 1124 0 0.03 9 1 6.81 Slight Ovality due to Mild Buckling. 27 1165 0 0.03 7 2 6.83 28 1206 0 0.03 7 1 6.81 I 29 1249 0 0.03 , 7 2 6.80 30 1290 0 0.03 7 2 6.79 31 1333 0 0.02 5 2 6.79 32 1376 0 0.02 6 1 6.78 I 33 1419 0 0.02 6 2 6.82 34 1461 0 0.03 9 3 6.79 35 1501 0 0.03 7 1 6.81 36 1538 0 0.03 8 2 6.79 37 1578 0 0.03 9 2 6.82 I 38 1620 0 0.04 9 2 6.79 39 1663 0 0.03 9 2 6.77 40 1705 0 0.04 11 2 6.78 41 1748 0 0.03 8 2 6.81 I 42 1785 0 0.03 7 2 6.79 43 1827 0 0.03 8 2 6.78 44 1869 0 0.03 8 2 6.79 45 1912 0 0.04 10 2 6.82 I 46 1951 0 0.03 7 1 6.77 47 1994 0 0.03 8 2 6.80 48 2036 0 0.03 8 2 6.81 Body 1 Metal Loss Penetration BBody Page 1 1 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.62 5 in. 29.7 ppf L-80 BTCM Well: 1 D -116 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA Survey Date: September 6, 2011 I Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 2077 0 0.03 8 1 6.77 50 2120 0 0.02 6 2 6.79 • 51 2160 0 0.03 8 2 6.81 • 52 2199 0 0.03 7 2 6.77 I 53 2243 0 0.03 7 2 6.82 54 2286 0 0.02 6 2 6.82 55 2329 0 0.04 10 2 6.79 56 2372 () 0.03 8 2 6.79 57 2413 0 0.02 6 1 6.78 I 58 2456 0 0.02 5 1 6.81 59 2498 0 0.02 6 1 6.79 1 60 2542 0 0.03 7 2 6.78 61 2585 0 0.03 7 2 6.81 C I 62 2628 0 0.03 7 1 6.79 63 2672 0 0.02 5 1 6.77 64 2715 0 0.02 6 1 6.79 1 65 2758 0 0.02 5 1 6.79 1 I 66 2795 0 0.03 7 2 6.78 1 67 2838 0 0.03 7 I 6.77 68 2881 0 0.03 7 1 6.78 69 2925 0 0.03 8 1 6.78 • 70 2968 0 0.04 11 1 6.81 • I 71 3012 0 0.03 7 2 6.75 72 3055 0 0.03 7 1 6.79 1 73 3098 0 0.02 6 2 6.77 74 3141 0 0.03 8 2 6.78 • I 75 3184 0 0.03 7 1 6.79 76 322 7 0 0.02 5 1 6.77 1 77 3270 0 0.04 9 2 6.80 C 78 3314 0 0.03 7 2 6.76 ' 79 3357 0 0.03 7 2 6.79 80 3400 0 0.02 5 1 6.79 81 3444 0 0.02 6 1 6.77 II 82 3487 0 0.03 8 1 6.69 • I 83 3526 84 3570 0 0.03 7 2 6.78 0 0.03 7 2 6.79 85 3612 0 0.03 8 2 6.80 • 86 3652 0 0.03 8 1 6.79 • 87 3696 0 0.03 7 2 6.76 li I 88 3739 89 3782 0 0.04 9 3 6.81 0 0.03 7 1 6.79 • Ai • 90 3825 0 0.03 9 2 6.79 91 3868 0 0.05 13 3 6.77 Shallow Pitting. C I 92 3911 93 3952 0 0.03 7 2 6.73 0 0.03 7 1 6.81 94 3995 0 0.02 6 2 6.80 II 95 4039 0 0.03 7 1 6.77 I 96 4082 0 0.03 8 2 6.77 97 4123 0 0.03 7 1 6.78 98 4164 0 0.03 8 1 6.82 II • Penetration Body I 'Penetration Loss Body Paget I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.62 5 in. 29.7 ppf L-80 BTCM Well: 1 D -116 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA Survey Date: September 6, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 99 4207 0 0.03 7 2 6.80 100 4250 0 0.03 7 1 6.84 101 4291 0 0.03 7 2 6.81 102 4334 0 0.04 11 2 6.80 I 103 4377 t1 0.03 7 1 6.80 104 4420 0 0.03 7 2 6.81 105 4463 0 0.03 7 2 6.82 106 4502 0 0.02 6 2 6.78 107 4545 0 0.03 7 2 6.81 I 108 4588 0 0.02 6 2 6.80 109 4631 0 0.03 7 2 6.82 110 4674 0 0.03 8 2 6.81 111 4717 0 0.03 8 1 6.79 I 112 4758 113 4802 0 0.04 10 2 6.81 ■ 0 0.07 17 3 6.81 Shallow Pitting. si 114 4844 0 0.03 7 " 1 6.78 115 4885 0 0.04 9 1 6.79 I 3 1 16 492 7, 0 0.03 7 3 6.82 117 4970 0 0.03 8 1 6.80 118 5013 0 0.04 12 2 6.78 Shallow Pitting 119 5055 0 0.03 8 2 6.80 120 5096 0 0.03 7 2 6.78 I 121 5140 0 0.03 7 2 6.77 122 5181 0 0.04 9 3 6.80 123 5222 0 0.03 8 2 6.80 124 5263 0 0.03 9 2 6.77 I 125 5306 126 5347 0 0.03 7 2 6.79 0 0.03 8 2 6.78 127 5385 0 0.03 7 2 6.79 128 5429 0 0.03 8 2 6.78 I 129 5471 130 5506 0 0.03 8 2 6.80 0 0.02 5 1 6.78 I Penetration Body I Metal Loss Body I I I Page 3 I I I • • 014 ConocoPhillips Alaska, Inc. KRU 1 D -116 I 1D-116 TUBING . API: 500292291500 Well Type: PROD Angle () TS: deg (ca (0-5490, SSSV Type: NONE Oriq Completion: 9/12/1998 Angle (ca TD: 15 deg 0, 6245 i oD:3.500, A nnular Fluid: RN Last W /O: Rev Reason: Reset Pump 0:2.992) Assembly Production t r Reference Loq: Ref Log Date: Last Update: 8/21/2004 (0-6230 , i ^ Last Tag: TD: 6245 ftKB OD :7.625, IV "VI Last Tag Date: Max Hole Angle: 67 deg @ 1938 U r. - Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread PUMP L Conductor 16.000 0 121 121 0.00 H -40 Welded (5453 -5470, Production 7.625 0 6230 4076 0.00 L -80 BTCM II ii 00:2.750) 0 0 Tubing String - Size Top Bottom TVD Wt Grade Thread 3.500 0 5490 3368 9.30 1-80 EUE 8RD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment I I , 1 5698 - 5699 3565 - 3566 WS D 1 12 1/5/1999 IPERF 4.5" HSD BH Chgs 5699 - 5718 3566 3584 WS D 19 24 1/5/1999 IPERF 4.5" HSD BH Chgs 5718 - 5730 3584 - 3596 WS D 12 12 1/5/1999 IPERF 4.5" HSD BH Chgs 5762 - 5828 3627 - 3690 WS B,WS 66 12 1/5/1999 IPERF 4.5" HSD BH Chgs A4 5854 - 5900 3715 - 3759 WS A3 46 12 1/5/1999 IPERF 4.5" HSD BH Chgs NIP 5923 - 5964 3781 - 3820 WS A2 41 12 1/5/1999 IPERF _ 4.5" HSD BH Chgs (5487 -5492, ! ! Gas Lift MandrelsNalves _ 00:3.500) St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date VIv I 11 I Mfr Run Cmnt 1 5398 3281 CAMCO KBMM CAMCO SOV 1.0 BK 0.000 0 8/7/2004 (1) i 1. 2000 psi Other (plugs, equip., etc.) - JEWELRY SEAL , Depth ND Type Description ID (5492 -5505, 5453 3333 PUMP 180ML2000 KUDU retrievable pump reset VV/SLIP STOP & NEW PACKOFF 0.000 oD:5.130) 8/18/2004 GEARBOX 5472 3351 GAUGE BAKER SENTRY GAUGE ATTACHED TO MIDDLE OF 2ND 10' PUP 0.000 (5505 -5506, 5487 3365 NIP Slotted nipple 2.992 I OD:5.250) 5492 3369 SEAL Tandem Seal GSB3 DB IL H6PFS 0.000 5505 3382 GEARBOX Gear Reduction Unit 9:1 525 Series 0.000 ° 5506 3383 MOTOR 57 HP 1315/26 KMH w /motor centralizer 0.000 MOTOR 5568 3441 Gravel Pack Gravel pack asssembly 3.875 (5506 -5507, 00:5.620) I r —, I 1 I 1 - I I Gravel Pack (5568 -6021, • OD:6.490) . Pert a_ • • • (5698 -5718) • • • • 1 Perf • • I (5762-5798) • _ • Perf • • • (5798 -5828) • • • I Pert — • • (5854 -5900) • • • • Per • • • (5923 -5964) i • • • I • Page 1 of 2 Regg, James B (DOA) • From: Schwartz, Guy L (DOA) Sent: Tuesday, September 06, 2011 8:41 AM To: Nelson, Erik Q Cc: Brooks, Phoebe L (DOA); Regg, James B (DOA) Subject: RE: Notice of BOPE usage on Nordic #3 - 1D-116 (PTD# 198 -172) Thanks Eric .. good call on using Pipe rams vs annular. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Nelson, Erik Q [ mailto: Erik.Nelson ©conocophillips.com] Sent: Monday, September 05, 2011 11:24 AM To: Schwartz, Guy L (DOA) Cc: Gober, Howard; Packer, ).Brett; Toomey, Ian A; Nordic 3 Company Man Subject: Notice of BOPE usage on Nordic #3 - 1D -116 (PTD# 198 -172) Mr. Schwartz, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE usage on Nordic 3 with a written report. Date, Time of BOPE Use: 9/05/11 04:00 hrs Well Location / API# / PTD #: 1D-116 Kuparuk River Unit w 1 stp (Sundry # if applicable) API# - 50- 029 - 22915 -00 " PTD# - 198 -172 Sundry# - N/A Rig Name: Nordic 3 Operator Contact: Erik Nelson 907 - 263 -4693 - Erik. Nelson(a�conocophillips.com Operations Summary: The rig had just completed cleaning the 7-5/8" casing down to 5493 ft MD along with the gravel pack screens down to 6,013 ft MD utilizing 3 -Y2" IF drill pipe with 520' of 2 -7/8" PAC drill pipe below the 7-5/8" casing scraper assembly. As the target depth was reached the well was reverse circulated to clean any fill or debris from the wellbore. Pumping operations were concluded and the well was monitored before tripping out of the well. A small amount of flow was observed from the drill pipe by casing annulus. The well was circulated down the tubing taking returns from the drill pipe by casing annulus in order to try and balance the well. After circulating one hole volume the well was again monitored for flow. Again, the well had a slight flow from the drill pipe by casing annulus. In order to remove the 2 -7/8" PAC drill pipe from the 3.958" inner diameter gravel pack screens the drill pipe was tripped out of the hole to just above the gravel pack packer and parked at 5,545 ft MD. While tripping, fluid levels were maintained by flowing fluid into the drill pipe by casing annulus from the trip tank. A hard shut in was then performed as per ConocoPhillips policy by closing the upper pipe rams and appropriate choke valves. Drill pipe pressure was monitored and stabilized at 10 psi after — 120 minutes. BOPE Used: Upper Set of 3 - %2' Pipe Rams and choke manifold valves 5, 6, and 2. Reason for BOPE Use: Control flow of fluids from the wellbore due to reservoir differential. Actions Taken / To Be Taken: Calculate a new brine weight from the Shut In Drill Pipe Pressure (SIDPP). Move fluid in the mud pits to weight up current brine from current 8.58 ppg to 8.7 ppg. Circulate 150% of wellbore volume and monitor to confirm well is static. The drill pipe will then be tripped out of the well. Once on surface, we will set a test plug and test the BOP components that were utilized before 9/8/2011 • Page 2 of 2 continuing operations. Let me know if you have any comments and /or questions. Erik Q. Nelson Workover /Wells Engineer ConocoPhdlips Alaska, Inc. Office #1590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 9/8/2011 '. ~. 7~- PROACTIVE DIACINOSTIC SERVICES INC. • ~~~~ L Ti~~4/V~/T~~4L a~ j - , - y„ . Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j MTT Report 21-May-10 1 D-116 1 Report ~~' e.- t ~Q~~ ~~~ Signed Print Name: 50-029-22915-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (9071245-88952 E-MAIL : ~d~~n;:°~Hi?S~C~2(t7sF38P97C3P"faf3fd.L'Df33 WEBSPTE : L•V+AfsN.s32~EflPVit3e~.~t>P'19 D:\09_Temporary\ 1 D-116\CD_Pazts\Transmit_Conow.docx Memory Magnetic Thickness Toad Log Results Summary Company: ConocoPhillipsAlaska, Inc. Well: 1D-116 Log Date: May 21, 2010 Field: West Sak Log No.: 10634 State: Alaska Run No.: 1 API No.: 50-029-22915-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 214 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvl1.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 214 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log Intvl1.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection ' COMMENTS This MTT data is tied into the Mandrel Hanger @ d' Depth. ' 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 and 7.625" 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 214'. Changes in metal volume are relative to the ' calibration poin#s at 70' and 160', where the readings are assumed to represent undamaged pipe. All other readings are rela#ive to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the filtered average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 6% relative metal loss over the interval (5' - 30') for the 5Hz pass, while only up to 3% relative metal loss is indicated in the 8Hz pass and no relative metal loss is indicated in the 10Hz pass. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) in this interval. A log plot of the entire SHz pass is included in this report. Indications of a broad line of isolated metal loss are recorded throughout the interval logged in this plot. Notable isolated metal loss events are indicated over the interval {~60' to 64') in all three passes. An expanded log plot of the 5Hz pass from 55' to 70' is included in this report to show the detail of these isolated metal loss events. A maximum ^'6% circumferential metal loss is indicated in the interval between 5' - 30' in the 5Hz pass. (Three tubing pup joint collars appear to be masking some potential casing damage in this interval. ) A maximum ~'3% circumferential metal loss is indicated in the interval between 50' - 70' in the SHz pass The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Field Engineer: G. Etherton Analyst: HY. Yang /J. Burton (MTT) Witness: J. Rowell Profi~ctive Diagnostic Services, Inc. J P, O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~'`a~memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 ~4~-~~-a a`£~" ~Eus 5Hz, ~z and 10Hz Passes Delta IIlI~I Thickness Overlay Q~ AFcs t` 1 D-116 May 21, 2010 PR°ACTIYE DIACfV°STIC SERVICES Database File: d:lwarrior\datal1d-11612nd cal overlay.db Dataset Pathname: run/overlay Presentation Format: overlay Dataset Creation: Sun May 2319:03:04 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 0 Pup 20 Delta Metal Thickness 2010 Metal Thickness 2010 40 Delta Metal Thickness 201C (1 60 80 Bottom of 16" 120 140 160 Metal Thickness 2010 180 200 Delta Metal Thickness 2010 (10F -Delta Metal Thickness 2010 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz} (%) 50 o`~"`wE"s ~ Detail of 5Hz MTT Re~rdings Q~ Arc; 1 D-116 May 21, 2010 1 P11O1~ETIYE ~IhC~NOSTIC SERVICES Database File: d:lwarrior\datal1d-116t5hzpass.db Dataset Pathname: SHzPass ' Presentation Format: 1.8 scale Dataset Creation: Mon May 2410:40:34 2010 Charted by: Depth in Feet scaled 1:150 ' P50 Delta Metal Thickness (%) 50 1.8 0 Line Speed (ft/min) 200 -7 Tree _ - 1 I Ha~ Line Speed - '`' - - R Pup ~ - -~ 5" Collar ' % Metal Loss Pup .5" Collar ~ 3% Metal Loss ' ' Pup i ,,:. 3.5" Collar ~ 20 ~ ' - - _.. Pup - - ~ I ~ 4% Metal Loss ` .5" Collar - % Metal Loss 1 1 Delta Metal Thickness Tubing Jt. 1 7.625" Collar ' % Metal Loss .5" Collar ~ ' Fn 3% Metal Loss Isolated Metal Loss Isolated Iv Tubing Jt. 2 Bottom of 16" Conducto - - - - - - 7.625" Colla - -" ' 3.5" Collar ~ . MTTP01 (rad) MTTP12 (rad) ne of Isolated Metal of Isolated Metal Lass of Isolated Metal Loss solated of Isolated Metal Losses ~ Line of Isolated M~Line of Isolated a-t~ ~ a~ I 11.8 3 A I Q`~"' ~E"s Detail 5Hz MTT Recordings Shov~ Isolated Metal Loss Q4 Fc~7 N 1 D-116 May 21, 2010 Pn°Acriv[ Dinyn°sric SEAYICES Database File: d:lwarriorldatalld-11615hz (55' - 70').db Dataset Pathname: SHaPass Presentation Format: 1.8 scale Dataset Creation: Mon May 2410:40:34 2010 Charted by: Depth in Feet scaled 1:10 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) 200 -7 MTTP12 (rad) 3 3% Metal Loss 'S Line S ed `~ ~4 56 Delta Metal Thickness I Tubing .1t. 1 ! ) ty 3.5" Collar ~ - i 58 -_ ,~ I t `. ~:~ ~. Tubing Jt. 2 60 ~~ i ~i Isolated Metal Loss ~ S 3% Metal Loss Isolated Metal Loss ' I ~ 1 i ~~ I 2% Me tal L oss Isolat ed M eta l Los s 64 i Tubing Jt. 2 ~ ~i> ~ ~ j + i a +~ ~ ~ ~~ { 66 I l F ~ i } (~ i ''. s 68 ,, } S{ l D M ~ t l Thi k i 1 r' e t a a e c ness '~ Lin e S pee d r 1 I ~ k ~ t -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 ~ 0 Line Speed (ftlmin) 200 -7 MTTP12 (rad} 3 • • i~ GanocoPhillips Alaska, Inc. KRU 1 D-11 1 D-116 API: 500292291500 Well T PROD An le TS: de TUBING (D-5aso SSSV T e: NONE Ori Com letion: 9/12/1998 An le TD: 15 de 6245 , oD:3.5o0, Annular Fluid: FW Last W/O: Rev Reason: Reset Pump iD:2s92) Assembl Proaudion r'{ ` Reference L Ref Lo Date: Last U date: 8/21/2004 (o-s23o, D 7 625 " ' Last Ta TD: 6245 ftK6 : . ) O © Last Ta Date: Max Hole An le: 67 de 1938 . Casin Stri -ALL STRINGS i Descri tion Size To Bottom ND Wt Grade Thread PUMP Conductor 16.000 0 121 121 0.00 H-40 Welded (5a53-5a7o, OD:2 750) Production 7.625 0 6230 4076 0.00 L-80 BTCM . Tubin Strin - Size To Bottom ND Wt Grade Thread 3.500 0 5490 3368 9.30 I-80 EUE 8RD Perforations Summar Interval ND Zone Status Ft SPF Date T Comment 5698 - 5699 3565 - 3566 WS D 1 12 1/5/1999 IPERF 4.5" HSD BH Ch s 5699 - 5718 3566 - 3584 WS D 19 24 1/5/1999 IPERF 4.5" HSD BH Ch s 5718 - 5730 3584 - 3596 WS D 12 12 1!5/1999 IPERF 4.5" HSD BH Ch s 5762 - 5828 3627 - 3690 WS B,WS 66 12 1/5/1999 IPERF 4.5" HSD BH Chgs A4 5854 - 5900 3715 - 3759 WS A3 46 12 1/5/1999 IPERF 4.5" HSD BH Ch s NIP ` 5923 - 5964 3781 - 3820 WS A2 41 12 1/5/1999 IPERF 4.5" HSD BH Ch s (5as7-5as2, Gas Lift Ma ndrel sNalves OD:3.500) St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 5398 328 1 CAMCO KBMM CAMCO SOV 1.0 BK 0.000 0 81712004 1 1. 2000 si Other lu s e ui .etc. -JEWELRY S~'~ De h ND T Descri ion ID (sas2-ssos, 5453 3333 PUMP 180ML2000 KUDU retrievable pump reset W/SLIP STOP & NEW PACKOFF 0.000 OD:5.130) $/1$/2004 GEARBOX 5472 3351 GAUGE BAKER SENTRY GAUGE ATTACHED TO MIDDLE OF 2ND 10' PUP 0.000 (5505-5506, "-'~ ~ 5487 3365 NIP Slotted ni le 2.992 OD:5.250) 5492 336,q SEAL Tandem Seal GSB3 DB IL H6PFS 0.000 ~ ~ 5505 3382 GEARBOX Gear Reduction Unit 9:1 525 Series 0.000 5506 3383 MOTOR 57 HP 1315/26 KMH w/motor centralizer 0.000 MOTOR (5506-5507, 5,568 3441 Gravel Pack Gravel pack assembly 3.875 OD:5.620) Gravel Pack (556&6021, ~ ~ • • ~ _ ~ Pert • • • (5698-5718) • • • Pert • • • (5762-5798) • • • Perf ~ • • • (5798-5828) • • - _ Perf - ~ • • (5854-5900) - • • • • Pert • • • (5923-5964) • • • • ~. • CASING /TUBING /LINER DETAtL Tubing or Liner escri~tion ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Comaanv 1 D-116 DATE: 1!10/99 1 OF 1 PAGES # REMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Centritift TOPS Note:11 flat bands 3- 6' Flat Guards 195 Preformed band 43 LaSalle Clamps 2 Protectoriizers on pump Raychem Heat Trace -3016' Note: 1 Heat Trace End Shoe 6' 456 Heat Trace Flat Guards 6' 42 Heat Trace Flat Guards 4' 36 Heat Trace Ftat Guards 3' 1536 Flat Bands If well is ever pulled=need to count jts. Covered by heat trace. FINAL COMPLETION RIG FLOOR TO LDS -Parker 248 36.90 HGR ABB Vetco Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod pup jt. 3.42 5.35 36.90 PUPS 3-1/2" EUE 8rd AB MOD Spaceout pu s -6.09=8.21=8.14 22.44 42.25 Jts 3 -172 3-1/2" EUE 8rd AB MOD tubing 5333,40 64.69 3-1/2"x1" CAMCO'KBMM' GLM 5.39"OD - 2.867"ID 6.80 5398.09 Jts 1&2 3-1/2" EUE 8rd AB MOD (full jts) 62.19 5404.89 3-112" EUE 8rd AB MOD Spaceout Pup 3.5"OD - 2.99"ID 10.14 5467.08 3-1/2" EUE 8rd AB MOD Handling Pup 3.5"OD - 2.99"ID 10.13 5477.22 Slotted Nipple 3.50" OD - 2.992 ID 3.00 5487.35 3-1/2" Tubing TTC Crossover 3.50" OD - 2.992" iD 1.51 5490.35 ESP Tandem Seai GS63 DB tL H6PFS 13.80 5491.86 ESP Gear Reduction Unit 9:1 525 Series 1.31 5505.66 ESP Motor 57 HP 1315!26 KMH 6.86 5506.97 E5P Motor Centralizer .50 5513.83 (Note=run 25 stds. S single tart heat trace 8' up from top of single. ) 5514.33 Note: Raychem Heat Trace attached aQ 8' up from box end on jt 76 Note: BOT Outside Sentry Gauge attached to middle of 2nd 10' pup Remarks: String Weights with Blocks: 65 K# Up, 35K# Dn, 6K# Blocks. Ran 172 joints of tubing . Drifted tubina~_ GLMs. & hanger with 2.867° niastie rabbit Used Arctic Grade APt ModNie d No Lead thread compound on all connections. Tubing is non-coated. Nordic Rig #2 Drilling Supervtsor. M.C. HE/M '~ CASING /TUBING !LINER DETAIL Tu6iQg or Liner Descr' tion ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company 1 D-116 DATE: 1/70/98 2 OF 2 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Through-Tubing-Deployed Items set with rig & slickline. ESP Pump assembl -includes pump adapter sub, flex shaft, 180ML2000 36.60 KUDU pump, rotor stop, bow spring centralizer, and KOBE seal bore. ESP 3" Packoff Stinger, 2.72" OD - 1.62" ID .25 ESP SCH 80 SS line pipe collar 2.725" OD - 2.22" ID .25 ESP SCH 80 SS line pipe nipple 2.38" OD - 2.00" ID 5.00 ESP 3" Tubing Packoff 2.72" OD - 1.62" ID 2.20 ESP 3" AA Tubing Stop 2.72" OD - 1.50" ID 1.16 (Note) Bottom of pum 5490.00' Top of pump @5453.40' Top of tbg. Stop @ 5444.54' GRAVEL PACK ASSEMBLY BELOW ESP Baker mode! "SC-1" Gravel pack packer 4.20 5568.21 80-40 upper extention 4.35 5572.41 80-40 gravel pack sliding sleeve 1.50 5576.76 80-40 seal bore 2.08 5578.26 80-40 lower extention 15.65 5580.34 x-o .79 5595.99 shear out safety jt. (53K shear) 3.14 5596.78 Blank pipe 4.5" 60.11 5599.92 10 jts. Bakerweld gravel pack screen 4.5" x .020 gauge 300.26 5660.03 2 jts. Bakerweld gravel pack screen 4.5" x .012 gau a 60.14 5960.29 4.5" baker bull plug .57 6020.43 PKD RKB 6021.00 KelliarKS: rump set & tested to 300(Y#. Nordic Rig #2 Drilling Supervisor. M.C. HE/M ~.._ J CASING /TUBING /LINER DETAIL Tubing or Csg Descrigt qn ARCO Alaska, inc. Subsidiary of Atlantic rtichfleid Company WELL: 1 D-116 DATE: 9/11/98 1 OF t PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to tandin Rin 40.64 Vetco Gray Fluted Mandrel Casin Han er & Pu 2.57 40.64 23 Jts. 7-5/8" 29.7# L-80 ABM-BTC Gasin Gts#123 - #145) 983.00 43.21 Tam Port Collar 2.44 1026.21 109 Jts. 7-5/8" 29.7# L-80 ABM-BTC Casing (Jt #14-122 4601.38__ .__,_1028.65 Marker Pup Jt. 7-5/8" 29.7# L-80 ABM-BTC Casin 21.03 5630.03 Marker Pu Jt. 7-5/8" 29.7# L-80 ABM-BTC Casin 21.56 5651.06 1 i Jts. 7~/8" 29.7# L-80 ABM-BTC Casin __ (Jts #3-#13)__ 470.90 5672.62 GEMOCO Float Collar PBTD 1.29 6143.52 2 Jts. 7-5/8" 29.7# L-80 ABM-BTC Casing Jts.#1 &#2 83.30 6144.81 GEMOCO Float Shoe 1.49 6228.11 6229.60 TD b245.00 Marker Jt. Between Jt.#13 8r 14 TAM Port Collar Between Jt#122 & 123 Centralizers Jt.#1 Bow sprin on st collar in middle of Jt. Jt.#2 2 S irogfide centralizers w/ st collar in middle of Jt. Jt.#3 Bow spring on st collar in middle of Jt. Jt.#413 2 S irogBde centralizers w/sto colar in middle of each Jt.(20 tot al Bows ring on c I .Of 1 b, 19, 22, 25, 28, 31, 34, 37, 40 43, 46, 49 52 55, 58, 61, 64, 67, 70, 73, 76, 79, 82 85, 88, 9l, 94, 97, 100, 103 106, 109, 112, 115, 118, 121, 124, 127, 13Q 133, 136, 139 42 total Remarks: Ran 145 Jts 29.7# L-80 BTC Mod Csg Used API Mod T hread Com pound Up Wt - 290K Dn Wt - 115K Parker Rig #2d5 Drlll/ng Supervisor.• tul~rick/Herbert • i Page 1 of 1 Regg, James B (DOA) ~ ~ ~~_~ ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~~~' G' ~a(~~=~ Sent: Friday, May 14, 2010 9:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1 D-116 (PTD 198-172) Report of failed ESP motor Tom, Jim, Guy West Sak ESP producer 1 D-116 (PTD 198-172) has a suspected broken shaft in the ESP motor and is no longer functional. Currently the well is SI and will require a RWO to repair. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 r~ fir,, I II~~ 4~, f ~~l lv 5/17/2010 . . ConocJPhillips 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 tOO Anchorage, AK. 99501 S~ JULl12007 \ a.. t:¡¡ ~ \ 1 'ð- 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. Surface 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 gal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/912007 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 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 61912007 10-117 197-237 2" na 1 6/912007 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 6/912007 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 ') ) Tom, Here is the well orientation plot for the 1320 requested on lE-114,. Also, included are the cementing reports for each one of these wells. Six wells were seen -to intersect the 1320 plot: . CÁ ",'" a,.^...... -,'"-,,,',"1,{).../ ~ -,-U lE-168 V ~;:~.ö~-7)a() " . lE-123 / :)ù4.. O"ì.::\ ~ ';:..::a \ ~\r:J <;$'k -0 y. ID-116 .~\'\~- t~~ 1 D-113 ~ ,~~- \'~ C6 1 D-112 ,t.c.. C". -, \ v" ""L / '\, 1:> ð ..:) . ~ c 1 D-l 03 ' ,.90 '2>- -- Oq (~ - <è"~\ ~ ~\-«cl '''\ I, s- -0 L\ All the wells had good cementing operations with the exception of ID-I03. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 T~~\~ ~ðC0M..Cs,A- ~Ú-l7 ~~'\ D\ -\~ fAC\CQ \- O-l-7S~S. SCt:,';j ~ð r \--\:1;:\ \£ ,~\t:-\\~ l-L~l..~~ ld-. \~L \:D', ..:;\~-:>~ \ ~\'-- ~_CD'\~ ~,"> \)QX~'- ? \o(:£d\ ~ \-~, ~~F\-\-.J~ ,ç,\ L.. ~ ~ \ ~ \\.'::> \J'-JU-<rCJQ ~'\-."-,,\r-~ .\ Q \^'Q-...JL 0-c.œp\-cd;' \<$ \ ~"\-eC']('-'L ~ ' ß1-~~ ~ ~-¡ t C-O .:> SCANNED FES 1 ¿1 2DD5 ") , , , '-) / / / I Kul Kuparuk IE Pad, lE-123, lE-123 V2 I .../ / I Kuparuk ID Pad, ID-I03, ID-103 VI I 7000- ANTl,COLLISION SETfINGS YPh'811* CÇ)noco 'I IpS 3538 3598 Interpolation Method:TVD Interval: 1.000 Depth Range From: 3478.000 To: 3788.250 Maximum Range: 1376,200 Reference: Definitive Survey 1000- I Kuparuk IE Pad, lE-168, lE-168 Yl I -../ .3598 I Kuparuk ID Pad, ID-112, ID-112 V2 l ,,¡'if' , '. .~~ ~', I Kuparuk IE Pad, Lr-1l4, lE-114 ['" '~'>~ ~~~"~()'\)'ð1 "'~788 ~ ~~~\ 3778 ,1\ S ,6;1'ð .~/ 'J¿f1.,'ð 3538 JJ Kuparuk IE Pad, lE-168, lE-168Ll V3 P 3~?$:/ ,I // 6000- 5000- 4000- '2 ~ 0 0 0 ::::, 3000- £ '€ 0 ~ ~ 0 r:/J 2000- ~ -/ /' 3718 I Kup~ruk ID Pad, ID-116, ID-116 V2 l rJtK 3658 " : i '.... t-.... " , c y 3598 ',~ i~718 í Ii 3538 ~ --'478 -~ 3> 'i::98 / ./ Cir~/es Of _IOOO~~~ ~ " .:5:: "-. ~.. """",......,;~~",;,~,;':l, ¡:,;:~,,~'~S - ~~ ~~ ~ }.... ' ,', ,: " ":.':,::t:S,?:: :~:~;> ;::'~:. ; ;":":<':.' ',- ",',', þ ~\% ...., ' ,," ...', ,I', ,,:,.' ", ' ~ pad,IE-22, lE-22 VI ",,,,,\,,,% ' " Kuparuk IE Pad, I~ Kuparuk IE Pad, lE-33, lE-33 V2 [II -', "', ~ (¡) , ',34' " -2000- ' " " I } , , , , I I l I I I I I I I I I I I I I I I I I I--r--¡ I I I I I I I I I I I I 20bo 3000 4000 5000 6000 7000 8000 :r.Da-.-t '~Y-!5Un W est( - )/East( +) [1 OOOftlin] "'''1" .iNoI'a "'...AV'''''''''''''' 0- \ U\f.tnu MIUI, .""..."" ) ) Page 1 of 5 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 10-116 Common Well Name: 1 0-116 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 9/8/1998 00:00 - 18:00 18.00 DRILL DRLG PROD 18:00 - 19:30 1.50 CIRC PROD 19:30 - 23:00 3.50 TRIP PROD 23:00 - 00:00 1.00 PULD PROD 9/9/1998 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 03:00 2.50 TRIP PROD 03:00 - 03:30 0.50 CIRC PROD 03:30 - 23:00 19.50 DRILL DRLG PROD 23:00 - 00:00 1.00 CIRC PROD 9/10/1998 00:00 - 01 :30 1.50 CIRC PROD 01 :30 - 09:30 8.00 TRIP PROD 09:30 - 12:00 2.50 TRIP PROD 12:00 - 14:00 2.00 TRIP PROD 14:00 - 16:00 2.00 CIRC PROD 16:00 - 19:00 3.00 TRIP PROD 19:00 - 20:30 1.50 PROD 20:30 - 00:00 3.50 PROD 9/11/1998 00:00 - 03:30 3.50 CASE RUNC PROD 03:30 - 04:00 0.50 CIRC PROD 04:00 - 07:30 3.50 CASE RUNC PROD 07:30 - 11 :30 4.00 CIRC PROD 11 :30 - 14:00 2.50 CEMENT PUMP PROD 14:00 - 15:00 1.00 CASE DEaT PROD 15:00 - 16:30 1.50 PROD 16:30 - 17:00 0.50 PROD 17:00 - 18:30 1.50 TRIP PROD 18:30 - 19:30 1.00 PROD 19:30 - 20:00 0.50 PROD 20:00 - 22:00 2.00 TRIP PROD 22:00 - 23:00 1.00 NUND PROD 23:00 - 00:00 1.00 RIGMNT RSRV PROD 9/12/1998 00:00 - 03:00 3.00 CMPL TN CMPL TN 12/30/1998 00:00 - 05:00 5.00 NUND CMPL TN 05:00 - 08:30 08:30 - 1 0:30 3.50 WELCTL BOPE CMPL TN 2.00 WELCTL BOPE CMPL TN Spud Date: 9/7/1998 End: 9/12/1998 Group: Start: 9/7/1998 Rig Release: 9/12/1998 Rig Number: 245 Description of Operations Drlg fl 460' to 3703'. ADT - 12.8 hrs Circ and condition mud. POH. Pump out of hole 2700' to 1716' due to swabbing. Change bits. Reset motor. Orient tools. Download Sperry Sun. Service Rig & Top Drive RIH to Bttm, Wash & Ream from 180' to 300', Tight from 2850' to 3500' Circ Bttms up to clean up hole after trip Drlg 9 7/8" Hole from 3703' to 6245' ADT = 13.16 hrs Circ & Cond hole for Hole Opener run Circ & Cond Hole for Hole Opener run. Monitor well, Drop Survey & Pump slug. POOH, Tight & Swabbing from 5412' to 3422'. Pump out & ream from 5035' to 3422'. 50k overpull max. Download LWD info & UD BHA. M/U Hole Opener Assy. & TIH. TIH wI Hole Opener, Wash & Ream from 5050' to 5100' & 5280' to 5400'. Circ & Cond hole for Casing run. POOH wI Hole Opener, UD BHA Rig up to run casing & Hold Pre job Safety meeting wI Arco Co. men & Toolpusher Run 7 5/8",29.7#, L-80 Casing. Install Cent's as directed. Circ 1 casing volume @ 2000' Run 7/58",29.7#, L-80 Casing. Push casing in hole from 2368' to 3995' Circ 1 casing volume @ 6 bpm wI 500 psi Run 7 5/8",29.7#, L-80 Casing. Work & push casing into hole from 3995' to 4700'. Continue to run casing slow (no Dn Wt.) to 6245' Circ & Cond mud for cement job. Pumped 1560 bbls @ 8 bpm wi 625 psi. Cement wI Dowell, Flush lines wI 5 bbls H2O, P.T.lines to 3500, Pump 20 bbls Preflush, 40 bbls Spacer, 504 bbls L. cmt @ 10.5 ppg, Drop plug, 70 bbls T. cmt @ 15.8 ppg, Drop plug, 20 bbls H2O. Displace cmt wI Rig pump, Pump 262 bbls H2O, Bump plug. CIP @ 1400 hrs. Ck fits. Test casing to 3000 psi for 30 min. UD cmt head, Lnd jt, csg equip, RID flow line & riser. Wash out annular, R/U flow line & riser Install wear bushing TIH to 5000' wI DP (open ended) Freeze protect well wi 74 bbls diesel Drain riser & U-tube diesel TOOH wI DP. Fill hole wI 33 bbls diesel. Pull wear bushing Nipple down diverter stack, install wellhead & test outer seal to 1000 psi (OK). Cut drilling line 81' Install tbg and tree. Press test failed. Re-torque head. Test failed.. Remove tree. Replace o-rings. NU tree. Test tree to 5000 psi. Set BPV. Release rig @ 0300 hrs. 9/12/98. 0 ring seal on wellhead failed Replace 0 rings and pressure test Check Tree & ann. for psi = transfer brine fluprite tank to pits = R/U firlter unit = Pull BPV install 2 way check R/U hardline to flowtank = NU BOPE. Function test BOPE & test same, floor valves, draw down. Blow water out of stack = B.O.L.D.S.= Pull and LD hanger = Set Wear Ring = Check Crown- 0- matico Printed: 2/7/2005 9:27:44 AM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 0-11 6 Common Well Name: 1 0-11 6 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 12/30/1998 10:30 - 13:00 2.50 CMPL TN RUNT CMPL TN 13:00 - 15:00 2.00 CMPL TN 15:00 - 16:00 1.00 CMPL TN 16:00 - 21 :00 5.00 CMPL TN 21 :00 - 23:00 2.00 WELLSR CMPL TN 23:00 - 00:00 1.00 RIGMNT RSRV CMPL TN 12/31/1998 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 07:30 5.00 CMPL TN 07:30 - 11 :00 3.50 CMPL TN 11 :00 - 12:00 1.00 CMPL TN 12:00 - 14:00 2.00 WELLSR CMPL TN 14:00 - 16:00 2.00 CMPL TN RUNT CMPL TN 16:00 - 18:30 2.50 CMPL TN 18:30 - 19:00 0.50 CMPL TN 19:00 - 21 :30 2.50 WELLSR CMPL TN 21 :30 - 00:00 2.50 LOG OTHR CMPL TN 1/1/1999 0.50 LOG OTHR CMPL TN 00:00 - 00:30 00:30 - 05:00 4.50 LOG OTHR CMPL TN 05:00 - 11 :30 6.50 CMPL TN 11 :30 - 14:00 2.50 CMPL TN RUNT CMPL TN 14:00 - 14:30 14:30 - 15:30 15:30 - 22:30 0.50 RIGMNT RSRV CMPL TN 1.00 CMPL TN 7.00 STIM CMPLTN 22:30 - 00:00 1.50 STIM CMPL TN 1/2/1999 00:00 - 00:30 0.50 CIRC CMPL TN 00:30 - 15:00 14.50 WELCTL KILL CMPL TN 15:00 - 17:30 2.50 WELCTL KILL CMPL TN 17:30 - 20:00 2.50 CMPL TN 20:00 - 20:30 0.50 CMPL TN Page 2 of 5 Spud Date: 9/7/1998 End: 9/12/1998 Group: Start: 9/7/1998 Rig Release: 9/12/1998 Rig Number: 245 Description of Operations M/U 6 3/4" bit and tandem scrapers and RIH on 3 1/2" tubing, drifting. Hit Ice plug = P/U Kelly = Drilled out ice from 2240' to 2320'. Insufficient diesel for freeze protection. Pump more diesel. Test Kelly = Blown down & SB. Continued to RIH = Tagged @ 6092' = Reverse circ. fill out of hole = solid cement @ 6092' = Displaced well w/ Seawater @ 6092'. POOH, Short trrip to top scraper. Cut & Slip 50 ft. drilling line = Adjust brakes = check Crown-O-matic. RIH w/BHA!1 & 3-1/2" WS to 6092' = PJSM = RlU Dowell & pumped Caustic Wash while rotating & recip. Displaced Caustic Wash w/8.7 Filtered Compl. Fluid Blow dwn. SB Kelly = RlU cement line = PJSM on Acid = Pumped Acid pickle @ 1/2 BPM T/end of work string = Rev. @ 2 BPM 200 psi Rev. out 2 additional ws vol. @ 4 BPM - 390 psi = NT Us 6 in 24 out. POH w/tubing, bit & scrapers, LD. MU and RIH with 5 3/4" Wash Shoe to 5899' - 200' above TD. RlU Dowell = Pumped 2800 # of 20/40 sand and displaced to end of WS = Pulled tubing up to 5836' = wait 1 hr. let sand fall. RIH tagged top of sand @ 6010' = POH LD 10 jts. POH stand back workstring. RlU E-line = P/U equipment & tools = #1 run C.P.L log could not reach bottom. Stacked out on ice at 1800' = POOH. Ice in well bore prevented logs from reaching bottom. Circulate in warm brine prior to POOH. R/D wireline tools & equipment. Ice in well bore. See previous comment. See previous comment. M/U Bit & Scraper = RIH tag ice plug @ 1821' = P/U Kelly = Drill through ice plug F/ 1821' to 1860' = Work scraper & circ. BU @ 1790' to 1860' = RIH to 3017' = Circulate BU w/hot brine = POOH. Ice in well bore. See previous comment. See previous comment. RlU wireline equip. = RIH w/Logging equip to 6014' = Logged = RlU lubricator = PJSM = M/U guns and perforated 12 SPF, w/ 4-1/2" guns w/HSD Big Hole Charges @ following 5964' - 5923' = POOH UD wireline tools. M/U wash over shoe & RIH on 3-1/2" tubing to 5712.90' = up wt. 85K = dwn wt. 35K. Service Rig. Pull Wear Ring & Land Hanger. RlU Dowell for Frac = PJSM w/Dowell, ARCO and rig crew = Press. test lines = Pumped high rate breakdown, HEC breakdwon & scour, & Data Frac as per schedule. Re-design frac schedule with data frac. Pumped 84K # in format @ 20 BPM max treating press - 3794, tip screen out. Monitor well = 645 psi, bled down to 625 psi = Reverse circulate & clean out hole. Bleed down balooning from frac. job. Reverse circ. clean hole = monitor well, bleed down = press. 430 psi flowing back at 26 BPH Continue to flow back until rate came down to 12 BPH = shut in and press = 175 psi. RlU and pump kill wt fluid 9.8 ppg = monitor well = dead. RID frac lines = M/U kill line = B.O.L.D.S. = UD hanger = P/U DP, run in and tagged top of sand @ 5925' = P/U 120' and dumped 200# of 20/40 sand dwn tbg, chased w/brine. Wait 30 min. = tagged top of sand @ 5922'. Printed: 2f7/2005 9:27:44 AM ') ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-11 6 Common Well Name: 1 0-116 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 1/2/1999 20:30 - 22:00 1.50 CMPL TN 22:00 - 00:00 2.00 CIRC CMPL TN 1/3/1999 00:00 - 00:30 0.50 CIRC CMPL TN 00:30 - 03:00 2.50 WELLSR CMPL TN 03:00 - 05:00 2.00 CMPL TN 05:00 - 09:00 4.00 CMPL TN 09:00 - 11 :00 2.00 CMPL TN RUNT CMPL TN 11 :00 - 13:00 2.00 CIRC CMPL TN 13:00 - 18:00 5.00 STIM CMPL TN 18:00 - 19:30 1.50 CIRC CMPL TN 19:30 - 00:00 4.50 STIM CMPL TN 1/4/1999 00:00 - 01 :00 1.00 CIRC CMPL TN 01 :00 - 04:00 3.00 CIRC CMPL TN 04:00 - 04:30 0.50 CMPL TN 04:30 - 07:00 2.50 CIRC CMPL TN 07:00 - 09:30 2.50 WELLSR CMPL TN 09:30 - 16:00 6.50 CMPL TN 16:00 - 18:00 2.00 CMPL TN RUNT CMPL TN 18:00 - 00:00 6.00 STIM CMPL TN 1/5/1999 00:00 - 08:30 8.50 08:30 - 09:00 0.50 09:00 - 11 :00 2.00 11 :00 - 12:00 1.00 12:00 - 16:00 4.00 CIRC CMPLTN CMPL TN CIRC CMPLTN CMPL TN CIRC CMPLTN 16:00 - 18:30 18:30 - 23:00 TRI P CMPL TN CMPL TN 2.50 4.50 1/6/1999 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 0.50 RIGMNT RSRV CMPL TN 0.50 TRIP CMPLTN 1.50 TRI P CMPL TN 1.50 CMPL TN 03:00 - 04:00 04:00 - 08:30 08:30 - 10:30 10:30 - 11 :30 11 :30 - 18:00 1.00 4.50 2.00 1,00 6.50 CIRC CMPLTN CMPL TN CMPL TN CI RC CMPL TN CMPL TN Page 3 of 5 Spud Date: 9/7/1998 End: 9/12/1998 Group: Start: 9/7/1998 Rig Release: 9/12/1998 Rig Number: 245 Description of Operations Dumped 175# sand, chased wlbrine, wait 30 min. = tagged @ 5909' Circ. clean, hot 9.8 brine to 34 NTUs. Finish circ. & filter brine to 34 NTUs = tag sand @ 5909'. POOH lay dwn 9 jts , stand back 60 stands. R/U wireline equipment for perforating = Load guns in pipe shed. Perforated well from 5854' to 5900' = RD wireline. RIH w/3-1/2" workstring & wash shoe to 200' above top perf. R/U frac lines & kill line = Displace 9.8 ppg brine w/8.7 ppg brine = Land hanger & RILDS PJSM = Press test all lines = Frac A-3 sand = Pumped 86,300 # in formation at 20 BPM max treating pressure 3960 psi = Tip screen out build net press. Reverse circ. hole clean = shut in well for 15 min. = SITP-310 psi = SICP-310 psi. Open well to pits = monitor flow rate = initial rate 40 BPH = Final rate 12 BPM = Shut in well and monitor for 15 min. = SITP-120 psi = SICP-120 psi. R/U to kill well w/9.8 ppg filtered brine = SICP-120 psi = SITP-120 psi = Cleaned #2 pit & monitor well. Killed well wI 9.8 ppg filtered brine = B.O.L.D.S. = Pull hanger Lay down same and landing jt. RIH & tagged top of sand @ 5837 = POOH to 5739'. Reverse circ. & filter 9.8 brine to 35 NTUs. POOH w/workstring PJSM = R/U wireline = RIH and perforated from 5828' to 5798' & 5798' to 5762' = RID wireline. RIH w/3-1/2" workstring and washshoe to 5556' = land hanger and shut BOPE. R/U frac equip. = Displace well to 8.7 ppg brine = PJSM = Test lines 8400 psi = Fraced B/A4 sand, pumped 94,700# 16-20 Carbolite proppant at 20 BPM = Slowed rate to 10 BPM = No tip screenout = Max treating press. 3939 psi. Reverse & clean frac sand from well=sitp 350#=bled to 230#=pump 9.8 brine=monitor well. Bolds=r/u kill line to bop=pull hanger & lay down same. R/u circ. equip=tbg. flowing=reverse circ=clean pit 2 & 3. Rih=tag sand @ 5748. Dump 200# sand down dp & pump down @ 1 bpm=pick up 100'=allow sand to settle=rih & tag sand @ 5740'.=pick up 100'=filter fluids to 41 ntu. Poh fl perforating. R/u sws=safety meeting wI all hands=rih wI perf guns=perf from 5699-5730=poh & rId sws. Fill hyd. scrubber in blocks. Rih wI clean out shoe. Rih to 5460. Make up & land hanger @ 5493=rilds=change kill line over to 7 5/8" annulus=hook up frac lines. Displace well to 8.7# fluid. Fluid pac frac lines=test to 8800#=Frac 'd' sand as per on site engineer. Shut in pressure 750#=bleed off to 600# Reverse circ=70 spm-500#. Bleed down pressure fl formation @ 30 bph to 10 bph. Printed: 2/7/2005 9:27:44 AM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-11 6 Common Well Name: 1 D-116 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 1/6/1999 18:00 - 00:00 6.00 CMPL TN 1/7/1999 00:00 - 01 :00 1.00 RIGMNT RSRV CMPL TN 01 :00 - 03:30 2.50 CIRC GMPL TN 03:30 - 07:00 3.50 CMPL TN 07:00 - 16:00 9.00 CMPL TN 16:00 - 18:00 2.00 CIRC CMPL TN 18:00 - 22:30 4.50 CIRC CMPL TN 22:30 - 00:00 1.50 CIRC CMPL TN 1/8/1999 00:00 - 01 :30 1.50 CIRC CMPL TN 01 :30 - 10:30 9.00 CMPL TN 10:30 - 11 :00 0.50 RIGMNT RSRV CMPL TN 11 :00 - 12:30 1.50 CIRC CMPL TN 12:30 - 13:00 0.50 TRIP CMPL TN 13:00 - 14:00 1.00 CMPL TN 14:00 - 16:30 2.50 TRIP CMPL TN 16:30 - 18:00 1.50 CMPL TN 18:00 - 00:00 6.00 CMPL TN 1/9/1999 00:00 - 02:00 2.00 TRIP CMPL TN 02:00 - 04:00 2.00 CIRC CMPL TN 04:00 - 05:30 1.50 CMPL TN 05:30 - 07:00 1.50 CIRC CMPL TN 07:00 - 07:30 0.50 CMPL TN 07:30 - 09:30 2.00 CMPL TN 09:30 - 13:00 3.50 CMPL TN GRVL CMPL TN 13:00 - 14:00 1.00 CIRC CMPL TN 14:00 - 14:30 0.50 TRIP CMPL TN 14:30 - 15:00 0.50 CMPL TN 15:00 - 17:00 2.00 CIRC CMPL TN 17:00 - 20:00 3.00 TRIP CMPL TN 20:00 - 21 :30 1.50 CMPL TN 21 :30 - 23:30 2.00 PULD CMPL TN 23:30 - 00:00 0.50 TRIP CMPL TN 1/10/1999 00:00 - 03:30 3.50 TRIP CMPL TN 03:30 - 06:30 3.00 SUN CMPL TN 06:30 - 07:00 0.50 RIGMNT RSRV CMPL TN 07:00 - 08:30 1.50 TRIP CMPL TN 08:30 - 09:00 0.50 CMPL TN 09:00 - 14:30 5.50 CMPL TN RUNT CMPL TN 14:30 - 00:00 9.50 CMPL TN RUNT CMPL TN 1/11/1999 00:00 - 04:00 4.00 CMPL TN RUNT CMPL TN Page 4 of 5 Spud Date: 9n /1998 End: 9/12/1998 Group: Start: 9n /1998 Rig Release: 9/12/1998 Rig Number: 245 Description of Operations Attempt to change out unimatic hook on blocks=failed to get bolts out=spring is broke in hook. Rig equipment failure. Repair equipment. Cut drlg. line. Rig up lines=reverse circ. capacity of well=recovered crude=gas & brine. Circ. clean up well. Pull hanger & lay down=make up safety valve closed=hang off work string on 3-1/2" pipe rams wI 35k down wt. Rig up rotating head. Single in wI kelly fl 5457=reverse circ. each jt.=tag sand @ 5740=cleaning out sand to 6014. Circ.=clean hole=(Load esp cable & equip.=heat trace & gravel pack screens while circ.) Circ.=clean hole @ 5954. Pull 4 stds. pipe to 5618.=circ. & clean well. Continue to reverse & filter fluid to 54 ntu,s. Monitor & attempt to stabilize well=flow slowed to 10 bph=would not stabilize. PJSM=ser. rig while thawing lines. Pump 8.8# brine complete circ. to stabilize well. Rih=tag sand @ 6017'. Pull rotating head insert & install flowline. Poh f/ bakerweld screens to gravel pack. Change riser on stack to accept wear ring. PJSM=pick up gravel pack assembly=rih wI same @ 3 min. per std. Rih wi gravel pack assembly @ 3 min. per stand. Drop ball & circ. down=set packer @ 6016 WI 3100#=pressure annulus 1500#=hold 15 mins. ok=p?u 9' & reverse out ball. R/U dowell=PJSM=test lines to 4000#=begin gravel pack=dowll pump broke down. Equipment failure. Dowell pump went down while attempting a gravel pack. Replace Dowell Unit and repair equipment. Circ. capacity of well while changing out dowell pump. Begin gravel pack=dowell pump broke down. See previous comment. See previous comment. Dowell pump down=repair same. See previous comment. See previous comment. Gravel pack well as per on site engineer=used 4800# sand. Monitor pressure=pump 9.1# pill down dp. Pull 5 stds.=rig up to monitor well. Monitor well=30# back pressure. Mix & displace well wI 9.0# brine. Monitor well=well stable=poh fl 3-1/2" tbg. Lay down gravel pack assembly & load out same. Load pipe shed wI 3-1/2" tbg.=thaw-drift-strap & ring same. Pick up & run tbg. in hole. Picking up 3-1/2" tbg. & rih wI same. PJSM=rig up slick line wI 2.80 drift & 31/2" tbg. to 5368=poh & rig down hawco. Service rig. Poh wI tbg. Pull wear ring. Pick up & make up esp motor=baker sentry gauge=wire line set pump & test to 3000# 15 mins. ok. PJSM=run completion as per program. Finish running completion=space out=make up hanger & install Printed: 2f1/2005 9:27:44 AM ) ) Page 5 of 5 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 0-116 Common Well Name: 1 0-11 6 Event Name: ROT - DRILLING Contractor Name: Parker Drilling Rig Name: Parker 245 Date From - To Hours Code Sub Phase Code 1/11/1999 00:00 - 04:00 4.00 CMPL TN RUNT CMPL TN 04:00 - 11 :00 7.00 CMPL TN 11 :00 - 12:30 1.50 CMPL TN 12:30 - 13:00 0.50 CMPL TN 13:00 - 17:30 4.50 NUND CMPL TN 17:30 - 22:30 5.00 CIRC CMPL TN 22:30 - 00:00 1.50 CMPL TN Spud Date: 9/7/1998 End: 9/12/1998 Group: Start: 9/7/1998 Rig Release: 9/12/1998 Rig Number: 245 Description of Operations penetrators. Splice heat trace=take out 14'. Test same ok. Splice esp cable & baker sentry cable. Land hanger & lay down landing jt.=rilds. PJSM=n/d bope=n/u tbg. adapter & tree=final conductivity test=pull bpv=set test plug=test tree & tbg. hanger to 5000# ok.=pull test plug. Hook up & test circ. lines=displace well w/140 bbls. diesel freeze protect=allow diesel to equalize. (tp=230=ap 220.) Rig down circ. lines=secure cellar. (release rig @ 2400 hrs.) Printed: 2/7/2005 9:27:44 AM ...... Daily Drilling Report ~" ARCa Alaska, Inc. AFC No, Date Rpt No Rig Accept - hrs Days Since AccepUEst: 4.35 I 5.7 Rig Relase - hrs: AK9597 09/11'98 5 09/07'98 03:30:00 PM Well: 1D-116 Depth (MDITVD) 6245/4090 Prey Depth MD: 6245 Progress: 0 Contractor: PARKER Daily Cost $ 230728 Cum Cost $ 577406 Est Cost To Date $ 830000 Rig Name: RIG # 245 Last Csg: 16" @ 121' Next Csg: 7 5/8" @ 6366' Shoe Test: NIA Operation At 0600: Upcoming Operations: MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO, INCIDENT LAST BOP/DIVERT LAST BOPIDRILL LSND N TST 09'09/98 09'07'98 WEIGHT ROTwr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 06/08/98 08'28198 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 84sqc 290 N SPACE 09/08/98 07'15/98 PVIYP sowr TYPE TYPE TYPE FUEL & WATER 33 I 32 115 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 5435 10/151 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 0 4 09'08/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 0.Om1/30 min INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 1R-18D PERSONNEL DATA HOLE VOLUME PUMP PRES ADT'AST ADTIAST SOURCE WELL TEMP of 35 287bbl 650 III I I 1D-116 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 9 17.5 11131 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 9.4 5.5 1 5.5 I 5.5 I LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF 23.71 8.4% 95111 Water Base Muds 1265 PIT VOL GPM2 JETS JETS Cement ARCO PERSONNEL 2 575 339111 I1III IIIII 815 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $2165.32 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 10 $30805.09 III III III 2080 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 5 BAROID III III II I 5850 PERSONNEL TIME I END HOURS I OPS CODE HOLE SECT 12:00 AM 03:30 AM 3.50 RUN_CSG PROD 03:30 AM 04:00 AM 0.50 CIRC PROD 04:00 AM 07:30 AM 3.50 RUN_CSG PROD 07:30 AM 11:30 AM 4.00 CIRC PROD 11:30 AM 02:00 PM 2.50 CMT_CSG PROD r ) I[J-//fe I PHASE OPS Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing 02:00 PM 03:00 PM 1.00 TEST_CSG PROD Casing and Cementing 03:00 PM 04:30 PM 1.50 OTHER PROD Casing and Cementing 04:30 PM 05:00 PM 0.50 OTHER PROD Other 05:00 PM 06:30 PM 1.50 TRIP_IN PROD Other 06:30 PM 07:30 PM 1.00 OTHER PROD Other 07:30 PM 08:00 PM 0.50 OTHER PROD Other 08:00 PM 10:00 PM 2.00 TRIP_OUT PROD Other 10:00 PM 11:00 PM 1.00 NU_ND PROD Other 11:00 PM 12:00 AM 1.00 RIGS PROD Other 24.00 Daily Drilling Report: 1 D-116 09/11/98 ) TOTAL I OPERATIONS FROM 0000 - 0000 Run 7158", 29.7#, L-80 Casing. Push casing in hole from 2368' to 3995' Circ 1 casing volume @ 6 bpm wI 500 psi 47 Run 7 5/8", 29.7#, L-80 Casing. Work & push casing into hole from 3995' to 4700'. Continue to run casing slow (no Dn Wt.) to 6245' Circ & Cond mud for cement job. Pumped 1560 bbls @ 8 bpm wI 625 psi. Cement wI Dowell, Flush lines w/5 bbls H2O, P.T. lines to 3500, Pump 20 bbls Preflush, 40 bbls Spacer, 504 bbls L cmt @ 10.5 ppg, Drop plug, 70 bbls T. cmt @ 15.8 ppg, Drop plug, 20 bbls H2O. Displace cmt wI Rig pump, Pump 262 bbls H2O, Bump plug, CIP @ 1400 hrs. Ck fits. Test casing to 3000 psi for 30 min. UD cmt head, Lnd jt, csg equip, RID flow line & riser. Wash out annular, RIU flow line & riser Install wear bushing TlH to 5000' wI DP (open ended) Freeze protect well wI 74 bbls diesel Drain riser & U-tube diesel TOOH wI DP. Fill hole wI 33 bbls diesel. Pull wear bushing Nipple down diverter stack Install well head & test outer seal to 1000 psi (OK) Cut drilling line 81' Page 5 ) ..~ ~" ARCa Alaska, Inc. I Well Name: 1D-116 Rig Name: RIG # 245 Casing Size 7 5/8" Hole Diameter: I Angle thru KRU: 95/8" 16 Deg thru West Sak Report Date: 09111/98 AFC No.: AK9597 Shoe Depth: " 6230 ",. State type used. intervals covered and spacing Ran 1 bowspring centralizer per Jt on stop rings on Jt #1 and #3. Ran 1 bowspring on cplg every 3rd jt fl Jt #16 to surface. Ran 2 Spiroglldes per jt on Jt #2 and #4 - #13. Weight: PV(prior cond): 9.8/9.6 51 Centralizers Comments: Mud Comments: Gels before: 18/27 Gels after: 10115 Wash Comments: Type: ARCO Wash 0 Spacer Comments: 0 Type: ARCO Lead Cement 0 Comments: Type: AS III Ute Mix wtr temp: 70 PV(after cond): 33 Total Volume Circulated: 1500 bbls Volume: 20 Volume: 40 No. of Sack?,,' 640 ~ Tail Cement 0 Comments: Mix wtr temp: 70 Additives: G+50% D124 + 3.5% D44 + .4% D46 + 30% D53 + 1,5% S1 + 1.5% D79 No. of Sacks: 340/ Type: G Displacement 0 Comments: Additives: G + 2% S1 + .2% D46 + .55% D156 + .3% D65 Rate(before tail at shoe): 8 Reciprocation length: 15' Theoretical Displacement: 282 Calculated top of cement: Surface Rate(tail around shoe): 8 Reciprocation speed: 10 fpm Actual Displacement: 281 ') .~/(y cemen\ing Details I Report Number: 5 Field: LC Depth: 6144 % washout: YP(prior cond): 58 YP(after cond): 32 Weight: 8.4 Weight: 10.5 Weight: 10.5 ' Yield: J 4.42 Weight: -../ 15.8 Yield: 1.15 Str. WI. Up: 290k Str, WI. Down: 115k Str. WI. in mud: CP: Date:9/11/98 Time:14:00 hrs Remarks:Ran csg to bottom wI no problems. Circ and conditioned mud. Pumped lead and tail cements. Displaced wI FW wI rig pumps.Had 10.5 cement to surface 181 bbls into displacement. Circ out 100 bbls cement Bumped plug. Tested csg to 3000 psi f/30 min, Floats OK. Had full returns throughout entire Job, Reciprocated csg until approx 125 bbls lead cement around shoe, Pipe became sticky. I Cement Company: DS I Rig Contractor: PARKER Bumped plug: yes Floats held: yes Approved By: Lutrick/Herbert /"-;' -'- ~ ~ MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PA'GE Saved as M:/weepie/microfilm_marker.doc "198,172.0 KUPARUKRIVUWsAK 1D_l16 50. 029222915200 ?~L'L2S~X§KAINC Roll #1: Start: Stop Roll #2: Start Stop MD 06245 TVD 04090 Completion Date: 1/11/99 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D V D 8760 1,2 SPERRY MPT/GR/EWR4 OH 10/28/98 10/28/98 L DGR/EWR4-MD 1,2 121-6245 ..~...?~f.~ OH 11/4/98 11/4/98 L DGR/EWR4-TVD 1,2 121-4090 &.~i-.,i~, OH 11/4/98 11/4/98 ~, R SRVYCALC BH 121-6245. OH 3/29/99. 3/30/99 · / R SRVY RPT SPERRY 0-6245. OH 10/13/98 10/14/98 Thursday, January 25, 2001 Page 1 of 1 correction to completion report for 1 D-116 Subject: correction to completion report for 1D-116 Date: Tue, 13 Feb 2001 11:08:40-1000 From: "Sharon Allsup-Drake" <SALLSUP~ppco.com> To: steve_davies~admin.state.ak.us Dear Mr. Davies - the completion report for 1D-116 as submitted on 3/29/99 mentioned a Neu/Dens log was run on this well. This log was never run on this well. The only logs that were run were the GR/Res and CCL. Sharon Allsup-Drake 1 ofl 2/15/01 8:20 AM correction to completion report for 1 D- 116 Subject: correction to completion report for 1D-116 Date: Mon, 12 Feb 2001 14:57:35 -1000 From: "Sharon Allsup-Drake" <SALLSUP~ppco.com> To: steve_davies~admin.state.ak.us CC: "Michael B Mooney" <MMOONEY~ppco.com> Dear Mr. Davies, the completion report for 1D-116 as submitted on 3/29/99 mentioned a USIT leg was run on this well. This is incorrect. Our records show there was no USiT log run. Sorry for the inconvenience. Sharon Allsup-Drake 1 of 1 2/12/01 5:09 PM ARCO Alaska, Inc. ~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-116 (Permit No. 98-172) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-116. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG .. ' · . ~. ? . 1 Status of Well Classification of Service Well OIL ~] GAS E]]] SUSPENDED [~ ABANDONED~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-172 3 Address i8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22915 4 Location of well at surface ? ' ..... - .... At Top Producing Interval ¢_~_~" 10 Well Number At Total Depth ~ .... . r 11 Field and Pool 1093' FSL, 796' FWL, Sec. 14, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 07-Sep-98 09-Sep~98 11 -Jan-99 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6245' MD & 4090' TVD 6014' MD & 3868' TVD YES M NO U NA feet MD 2310 APPROX 22 Type Electric or Other Logs Run SE-I-rING DEPTH MD I CASING SIZE Wl- GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" 9 cu yds High Early 7.625" 29.7# L-80 SURF. 6230' 9.625" 640 sx AS III L & 340 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5514' N/A 5699'-5730' MD 3566'-3596' TVD 12 spT 5762'-5798' MD 3627'-3661' TVD 12 SPF 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5798'-5828' MD 3661'-3690' TVD 12 spT DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5854'-5900' MD 3715'-3759' TVD 12 spT 5699'-5730', 5762'-5798', see attachments 5923'-5964' MD 3781 '-3820' TVD 12 spf 5798'-5828', 5854'-5900', 5923'-5964' 27 PRODUCTION TEST ~ i ~ I ~ L., Date First Production Method of Operation (Flowing, gas lift, etc.) 3/11/99 F owing Date of Test Hours Tested PRODUCTION FOIOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3/26/99 6.00 TEST PERIOI: 93 43 6 100I 506 Flow Tubing 'Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 205 0 24-HOUR RATE: 358 181 24 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. ~ 30. -~' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5697' 3564' Base West Sak 6145' 3994' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and co. of my knowledge.signed.~~~.,,,...¢~ ~ ' Title~"~" '~'" Jt'~/~ ~' l'~'~/2//~' -/-"/'/"~'~--'"~ ~'-~~ ~---~ DATE J/~~f Prepared by Name/Number Sharon Allsup~Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement~ lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-ii6 WELL ID: AK9597 TYPE: AFC: AK9597 STATE:ALASKA AREA/CNT¥: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/07/98 START COMP:12/29/98 RIG:NORDIC # 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22915-00 09/07/98 (D1) MW: 9.5 riSC: 300 PV/YP: 33/44 APIWL: 5.9 TD: 460' (460) DRLG SUPV:CUNNINGHAM/LUTRICK Release rig from 1D-123 and move to 1D-116. Accept rig @ 1530 hrs. N/U diverter and test. Drill from 121' to 460' 09/08/98 (D2) TD: 3703'(3243) SUPV:LUTRICK/HERBERT MW: 9.5 VISC: 265 PV/YP: 39/53 DRLG @ 4050" Drilling from 460' to 3703' APIWL: 5.9 09/09/98 (D3) MW: 9.5 VISC: 298 PV/YP: 45/54 APIWL: 4.6 TD: 6245' (2542) POOH FOR HOLE OPENER SUPV:LUTRICK/HERBERT RIH to bttm, wash & ream from 180' to 300', tight from 2850' to 3500' Drilling 9-7/8" hole from 3703' to 6245' 09/10/98 (D4 MW: 9.6 VISC: 252 PV/YP: 45/51 APIWL: 4.4 TD: 6245' ( 0) RIH W/ CSG (15 JTS OFF BOTTOM AT REPORT TIME) SUPV:LUTRICK/HERBERT Circ and condition hole for hole opener. POOH, tight & swabbing from 5412' to 3422' Pump out & ream from 5035' to 3422' TIH w/hole opener. Wash & ream from 5050' to 5100' and 5280' to 5400'. Run 7-5/8" casing. 09/11/98 (D5 MW: 9.6 riSC: 84 PV/YP: 33/32 APIWL: 4.0 TD: 6245' ( 0) SUPV:LUTRICK/HERBERT Run 7-5/8" casing. Pump cement. Freeze protect well. ND diverter. Install wellhead. 09/12/98 (D6) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 6245'( 0) RIG RELEASED SUPV:LUTRICK/HERBERT Install tree and test. Test failed. Remove tree and replace o-rings. NU tree and test to 5000 psi. Date: 1/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-iI6 WELL ID: AK9597 TYPE: AFC: AK9597 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/07/98 START COMP:12/29/98 RIG:NORDIC # 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22915-00 12/29/98 (C7 TD: 0' PB: 0' 12/30/98 (C8 TD: 0' PB: 0' 12/31/98 (C9 TD: 0' PB: 0' 01/01/99 (Ci0) TD: 0' PB: 0' 01/02/99 (Cll) TD: 0' PB: 0' 01/03/99 (C12) TD: 0' PB: 0' SUPV:RICK OVERSTREET Move rig from 1D-123 to 1D-116. MW: 8.7 BRINE DISPLACING W/CLEAN FILTER MW: 8.7 BRINE SUPV:RICK OVERSTREET NU BOPE and test. RIH and hit ice plug, drilled out ice from 2240' to 2320'. Reverse circ fill out oh hole, solid cement @ 6092', displaced well w/seawater @ 6092' R/U E-LINE, RUNNING C.P.L MW: 8.7 BRINE SUPV:RICK OVERSTREET Pump caustic wash. Displace caustic wash with filtered completion fluid. Pump acid pickle. Pump 20/40 sand. Tag top of sand at 6010'. Attempt to run log, could not reach bottom. KILLING WELL WITH 9.8 PPG MW: 8.7 BRINE SUPV:RICK OVERSTREET RIH tag ice plug @ 1821' Drill ice plug from 1821' to 1860' RIH w/logging equipment. Perforated 12 spf at 5964'-5923'. Pump high rate breakdown, HEC breakdown and data frac. PERFORATING A-3 -SAND. MW: 9.8 BRINE SUPV:RICK OVERSTREET Reverse circ clean hole. Continue to flow back. Shut in. Pump kill weight fluid 9.8 ppg, well dead. RIH tagged top of sand @ 5925' Dump 20/40 sand down tubing. Chase with brine. CIRC. & FILTERING 9.8 PPG MW: 9.8 BRINE SUPV:RICK OVERSTREET Perforated well from 5854' to 5900'. Frac A-3 sand. Date: 1/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 01/04/99 {C13) TD: O' PB: 0' FLOWING WELL BACK. MW: 9.8 BRINE SUPV:RICK OVERSTREET Kill well with 9.8 ppg filtered brine. Tag top of sand @ 5837'. Perforate from 5828' to 5798' and 5798' to 5762' Frac B/A4 sand. 01/05/99 (C14) TD: 0' PB: 0' DATA-FRAC MW: 9.8 BRINE SUPV:M.C. HEIM Reverse and clean frac sand from well. Dump sand down DP and pump down. RIH w/perforating guns. Perf from 5699'-5730' 01/06/99 TD: 6245' PB: 0' C15) RIG UP ROTATING HEAD MW: 9.8 BRINE SUPV:M.C. HEIM Frac 'D' sands. Attempt to change out hook on blocks, failed to get bolts out, spring is broke in hook. 01/07/99 TD: 6245' PB: 6014' C16) STABILIZE WELL F/ RUNNING MW: 8.7 SUPV:M.C. HEIM Circ. clean up well. Clean out sand to 6014' BRINE 01/08/99 TD: 6245' PB: 6014' C17 CIRC. CAPACITY OF WELL=WH MW: 8.8 BRINE SUPV:M.C. HEIM Continue to reverse and filter fluid. Monitor and attempt to stabilize well, flow slowed to 10 bph, would not stabilize. Pump brine complete circ. to stabilize well. RIH w/gravel pack assembly. 01/09/99 (C18 TD: 6245' PB: 6014' DRIFTING 3-1/2" TBG. W/ H MW: 8.8 BRINE SUPV:M.C. HEIM RIH w/gravel pack assembly. Set packer @ 6016' Begin gravel pack job. Well stable. 01/10/99 (C19 TD: 6245' PB: 6014' SPLICING HEAT TRACE CABLE SUPV:M.C. HEIM Run completion w/esp motor. MW: 9.0 BRINE 01/11/99 (C20 TD: 6245' PB: 6014' N/U BOPE MW:15.7 DOILW SUPV:M.C. HEIM Finish running completion. N/D BOPE. N/U tree and test to 5000%, OK. Freeze protect well. Rig down. Release rig @ 2400 hrs. Date 01/01/99 U p(~is-Cning Well Name 1D~116 Job Num 1230980840.2 AFC AK9597 Prop 18WSTF Service Type PUMPING Unit 0 Uploaded to $ Desc of Work "A2" SANDS FRAC Supervisor CHANEY Contractor Key Person DS-YOAKUM Complete [~ Successful Accident E~ Initial Tbg Press 25 Final Tbg Press 625 Injury E} Initial Int Csg Press 25 Final Int Csg Press 625 Spill [~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary "A2" SANDS FRAC COMPLETED. PUMPED 87048 LBS OF PROP AND PLACED 84069 LBS OF PROP IN THE FORM. W/9# PPA OF #16/20 BW OF PROPNET @ THE PERF'S. LEFT 2979 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL TO BE @ 5815' RKB. AVG WHTP PSI. TSO OBTAINED. [Frac-Refrac] Date printed: 01129199 at: 14:57:54 Date 01/03/99 Updbf'ning E] Well Name 1D-116 Job Num 1230980840.2 Service Type PUMPING Unit Desc of Work "A3" SANDS FRAC Supervisor CHANEY Contractor Key Person Complete [~ Successful [~ Accident [~] Initial Tbg Press 45 Injury ~ Initial Int Csg Press 45 Spill ~ Initial OutCsg Press 0 Summary AFC AK9597 0 Prop 18WSTF Uploaded to S DS-YOAKUM Final Tbg Press 675 Final Int Csg Press 675 Final Out Csg Press 0 "A3" SANDS FRAC COMPLETED. PUMPED 88616 LBS OF PROP AND PLACED 86338 LBS OF PROP IN THE FORMW/9# PPA OF #16/20 OF PROPNET @ THE PERF'S. LEFT 2278 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL TO BE @ 5771' RKB. AVG WHTP 376 TSO OBTAINED. [Frac-Refrac] Date printed: 01129199 at: 14:58:16 Date 01/04/99 Well Name 1D-116 Service Type PUMPING Desc of Work "A4/B" SANDS FRAC Supervisor CHANEY Complete [~ Accident [~] Injury ~-~ Spill E~ Summary Upc0-~d~ing Job Num Unit 123O98O840.2 AFC AK9597 Prop 18WSTF Uploaded to S Contractor Key Person DS-YOAKUM Successful [~ Initial Tbg Press 45 Initial Int Csg Press 45 Initial Out Csg Press 0 Final Tbg Press 650 Final Int Csg Press 650 Final Out Csg Press 0 "A4/B" SANDS FRAC COMPLETE, PUMPED 95849 LBS OF PROP AND PLACED 94719 LBS IN THE FORM WI 9# PPA OF #16/20 & 1% BW PROPNET @ THE PERF'S. LEFT 1130 LBS IN THE WB & EST FILL LEVEL TO BE @ 5721' RKB. AVG WHTP 3380 PSI. NO TSO. [Frac-Refrac] Date printed: 01129/99 at: 14:58:27 Date 01/06/99 Well Name 1D-116 Service Type PUMPING Desc of Work "D" SANDS FRAC Supervisor SMITH Complete [~ Accident ~] Injury r~ Spill E~ Summary Up6o~r~ing Job Num 1230980840.2 Unit AFC AK9597 Prop 18WSTF Uploaded to S Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 DS-YOKUM FinaITbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 "D' SANDS FRAC COMPLETED. PUMPED 103847# OF 16/20 PROP, 100907# OF PROP IN THE FORMATION W/10.0# PPA & 1% BW OF PROPNET. LEFT 2940# IN THE WELLBORE. AVG WHTP WAS 3249 PSI. NO TSO. [Frac-Refrac] Date printed: 01/29/99 at: 14:58:38 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00348 Sidetrack No. __ Page 1 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245. Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#116/E1 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. ~irr~ WELL DATA Target TVD (ET) Target Coord. N/S . Slot Coord. N/S -76.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/VV Slot Coord. ENV -597.00 Magn. Declination 27.400 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft~ 30m~ 10m[~ Vert. Sec. Azim. 286.80 Magn. to Map Corr. 27.400 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) (DD) (DD) (FI') (FT) (F-T) (FT) (Per 100 FT)'Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT --. 07-SEP-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH 1C-AKO-1.7deg. -- 07-SEP-98 MWD 175.00 0.75 310.00 54.00 175.00 0.32 0.23 -0.27 1.39 1.39 GYRO S/S 07-SEP-98 MWD 290.21 2.00 289.41 115.21 290.17 3.03 1.38 -2.74 1.15 1.08 _ ,, 07-S E P-98 MWD 379.55 4.12 287.82 89.34 379.38 7.79 2.88 -7.27 2.37 2.37 08-SEP-98 MWD 468.72 7.63 287.37 89.17 468.07 16.92 5.63 -15.97 3.94 3.94 -0.50 08-SEP-98 MwD 559.57 13.34 287.09 90.85 557.37 33.44 10.51 -31.76 6.29 6.29 -0.31 08-SEP-98 MWD 650.28 16.20 286.80 90.71 645.07 56.57 17.25 -53.88 3.15 3.15 -0.32 08-SEPt98 MWD 740.23 19.03 285.43 89.95 730.79 83.78 24.78 -80.03 3.18 3.15 -1.52 , 08-sEP-98 MWD 830.65 21.95 286.89 90.42 815.48 115.42 33.61 -110.42 3.28 3.23 1.61 -- 08-SEP-98 MWD 921.53 24.85 286.89 · 90.88 898.88 151.51 44.10 -144.95 3.19 3.19 0.00 08-SEP-98 MWD 1013.94 30.49 288.44 92.41 980.69 194.40 57.16 -185.81 6.15 6.10 1.68 08-SEP-98 MWD 1104.87 35.80 289.99 90.93 1056.80 244.05 73.56 -232.72 5.91 5.84 1.70 , ,. 08-SEP-98 MWD 1195.70 38.27 288.51 90.83 1129.30 298.70 91.58 -284.37 2.89 2.72 -1.63 08-S E P-98 MWD 1285.56 42.73 287.87 89.86 1197.61 357.03 109.78 -339.80 4.98 4.96 -0.71 08-SEP-98 MWD 1376.7i 47.68 286.68 91.15 1261.82 421.68 128.95 -401.55 5.51 5.43 -1.31 08-sE P-98 MWD 1467.44 52.14 287.41 90.73 1320.23 491.08 149.31 -467.89 4.95 4.92 0.80 08-SEP-98 MWD 1559.76 56.22 286.49 92.32 1374.25 565.92 171.11 -539.49 4.49 . 4.42 -1.00 08-SEP-98 MWD 1650.55 63.25 285.97 90.79 1419.98 644.28 193.00 -614.73 7.76 7.74 -0.57 08-SEP-98 MWD 1938.18 66.66 286.55 287.63 1541.73 904.81 265.97 -864.85 1.20 1.19 0.20 08-SEP-98 . MWD 2220.76 65.21 286.02 282.58 1656.95 1162.82 338.33 -1112.51 0.54 -0.51 -0.19 08-SEP-98 MWD 2506.07 64.92 285.96 285.31 1777.24 1421.50 409.60 -1361.22 0.10 -0.10 -0.02 08-SEP-98 MWD 2788.36 64.02 286.48 282.29 1898.90 1676.21 480.74 -1605.80 0.36 -0.32 0.18 08-SEP-98 MWD 3074.69 63.85 287.76 286.33 2024.71 1933.41 556.45 -1851.61 0.41 -0.06 0.45 SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0451-00348 Sidetrack No, Page 2 of 2 Company ARCO ALASKA, INC, Rig Contractor & No, PARKER DRILLING,CO - #245, Field KUPARUK RIVER UNIT Well Name & No, PAD 1D/1 D#116/E1 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. i ~Jlll~rL=~ WELL DATA Target TVD (ET) Target Coord, N/S Slot Coord, N/S -76,00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~] SS~- Target Description Target Coord, ENV Slot Coord, ENV -597,00 Magn, Declination 27,400 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: lOOft[~ 3Omni lOm[~ Vert. Sec, Azim. 286.80 Magn. to Map Corr. 27.400 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) '/W(-) DL Build (+) Right (+) Comment Type .(FO (DD) (DD) (ET) (FT) _ (F-T) (FO (Per ~00 FT) Drop (-) Left (-) 08-SEP-98 MWD 3359,80 65,66 288,93 285.11 2146,31 2191,18 637,63 -2096,36 0,74 0.63 0,41 8"MACH 1C-AKO-1,7deg. -- 08-SEP-98 MWD 3638,25 66,26 287,58 278.45 2259,74 2445.39 717,28 -2337.85 0,49 0,22 -0,48 ', _ -- 09-SEP-98 MWD 3923,80 62.38 284,45 285.55 2383.49 2702,62 788,36 -2585,09 1,68 -1,36 -1,10 8"MACH 1 C-AKO-1,5deg, 09-SEP-98 MWD 4209,08 65,23 286,28 285,28 2509,41 2958,48 856,23 -2831.87 1,1 5 1,00 0,64 -- 09-SEP-98 MWD 4493,10 64,48 288,25 284,02 2630,11 3215,56 932,51 -3077,37 0,68 -0.26 0,69 09-SEP-98 MWD 4587,90 60,35 287,78 94,80 2673,99 3299,54 958,50 -3157,26 4,38 -4,36 -0,50 09-SE P-98 MWD 4681,81 55,32 286,88 93,91 2723,97 3379.01 982.19 -3233,12 5,42 -5,36 -0,96 09-SEP-98 MWD 4777,25 49,95 286,57 95,44 2781,87 3454,83 1004,02 -3305,73 5,63 -5,63 -0,32 09-SEP-98 MWD 4873,09 45,59 286,34 95,84 2846,27 3525,78 1024,12 -3373,77 4,55 -4,55 -0,24 09-SEP-98 MWD 4968,65 42,04 286,76 95,56 2915,22 3591,93 1042,95 -3437.18 3,73 -3.71 0.44 09-SEP-98 MWD 5062,64 36,51 288,15 93,99 2987,95 3651,40 1060.75 -3493,93 5,96 -5,88 1,48 09-SEP-98 MWD 5157,31 31,49 288,40 94,67 3066,41 3704.30 1077,34 -3544,19 5,30 -5,30 0,26 ___ 09-SEP-98 MWD 5253,17 28,00 284,92 95,86 3149,63 3751,84 1091.04 -3589,70 4,06 -3,64 -3,63 09-SEP-98 MWD 5347,63 23,95 284,24 94,46 3234,53 3793,17 1101,47 -3629,73 4,30 -4,29 -0,72 09-SEP-98 MWD 5441,25 19,87 286,57 93,62 3321,37 3828,08 1110.69 -3663,41 4,46 -4.36 2,49 ...... 09-SEP-98 MWD 5631',71 17,36 286,58 190,46 3501,86 3888,87 1128,03 -3721,68 1,32 -1,32 0,01 09-SEP-98 MWD 5916,35 16,39 285,36 284.64 3774,24 3971,48 1150,7.8 -3801,10 0,36 ..0,34 -0,43 09-SEP-98 MWD 6180,19 15,49 282,78 263,84 4027,93 4043,84 1168,44 -3871,36 0,43 -0,34 -0,98 09-SEP-98 MWD 6245,00 15,49 282,78 64,81 4090,39 4061,11 1172,27 -3888,24 0,00 0,00 0,00 PROJ*BHC=4061,11 @ 286;78deg, ,, Kuparuk Unit Kuparuk 1D ID-116 SURVEY REPORT October, 1998 Your Ref: A PI-500292291500 Last Survey Date 09-September-98 Job# AKMMS0369 KBE- 112.10' Sl~,mr~-sur~ DRILLING SERVICES ORIGINAL OCT 1 ~ 1998 Oil & Gas Cons. Commission Survey Reft svy78 Sperry-Sun Drilling Services Survey Report for 1D-116 Your Ref: API-500292291500 Kuparuk Unit Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) 0.00 0.000 0.000 -112.10 121.00 0.000 0.000 8.90 175.00 0.750 310.000 62.90 290.21 2.000 289.410 178.07 379.55 4.120 287.820 267.28 468.72 7.630 287.370 355.97 559.57 13.340 287.090 445.26 650.28 16.200 286.800 532.97 740.23 19.030 285.430 618.69 830.65 21.950 286.890 703.38 921.53 24.850 286.890 786.78 1013.94 30.490 288.440 868.59 1104.87 35.800 289.990 944.70 1195.70 38.270 288.510 1017.20 1285.56 42.730 287.870 1085.51 1376.71 47.680 286.680 1149.72 1467.44 52.140 287.410 1208.13 1559.76 56.220 286.490 1262.15 1650.55 63.250 285.970 1307.88 1938.18 66.660 286.550 1429.63 2220.76 65.210 286.020 1544.85 2506.07 64.920 285.960 1665.14 2788.36 64.020 286.480 1786.80 3074.69 63.850 287.760 1912.61 3359.80 65.660 288.930 2034.21 3638.25 66.260 287.580 2147.64 3923.80 62.380 284.450 2271.39 4209.08 65.230 286.280 2397.31 4493.10 64.480 288.250 2518.01 4587.90 60.350 287.780 2561.89 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 121.00 0.00 N 0.00 E 175.00 0.23 N 0.27W 290.17 1.38 N 2.74W 379.38 2.88 N 7.27W 468.07 5.63 N 15.97W 557.36 10.51N 31.76W 645.07 17.25 N 53.88W 730.79 24.78 N 80.03W 815.48 33.61N 110.42VV 898.88 44.10 N 144.95W 980.69 57.16 N 185.81W 1056.80 73.56 N 232.72W 1129.30 91.58 N 284.37W 1197.61 109.78 N 339.80W 1261.82 128.95 N 401.55W 1320.23 149.31 N 467.89W 1374.25 171.11 N 539.49W 1419.98 193.00 N 614.73W 1541.73 265.97 N 864.85VV 1656.95 338.33 N 1112.51W 1777.24 409.60 N 1361.22W 1898.90 480.74 N 1605.80W 2024.71 556.45 N 1851.61W 2146.31 637.63 N 2096.36W 2259.74 717.28 N 2337.85W 2383,49 788.36 N 2585.09W 2509.41 856.23 N 2831.87W 2630.11 932.52 N 3077.37W 2673.99 958.50 N 3157.26W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) Vertical Section (ft) 5959588.90 N 560490.63 E 0.00 5959588.90 N 560490.63 E 0.000 0.00 5959589.12 N 560490.36 E 1.389 0.32 5959590.26 N 560487.87 E 1.150 3.03 5959591.72 N 560483.34 E 2.375 7.79 5959594.40 N 560474.61E 3.937 16.92 5959599.16 N 560458.79 E 6.285 33.44 5959605.71 N 560436.61 E 3.154 56.57 5959613.03 N 560410.40 E 3.180 83.78 5959621.62 N 560379.94 E 3.278 115.42 5959631.83 N 560345.33 E 3.191 151.51 5959644.57 N 560304.37 E 6.152 194.40 5959660.59 N 560257.33 E 5.913 244.05 5959678.19 N 560205.54 E 2.891 298.70 5959695.94 N 560149.96 E 4.985 357.03 5959714.62 N 560088.05 E 5.509 421.68 5959734.44 N 560021.55 E 4.954 491.08 5959755.66 N 559949.78 E 4.493 565.92 5959776.95 N 559874.36 E 7.759 644.28 5959847.90 N 559623.66 E 1.200 904.82 5959918.26 N 559375.43 E 0.541 1162.82 5959987.53 N 559126.16 E 0.103 1421.50 5960056.70 N 558881.01 E 0.360 1676.22 5960130.43 N 558634.60 E 0.406 1933.41 5960209.64 N 558389.21E 0.735 2191.18 5960287.34 N 558147.08 E 0.492 2445.39 5960356.43 N 557899.28 E 1.680 2702.62 5960422.30 N 557651.96 E 1.153 2958.48 5960496.61 N 557405.85 E 0.681 3215.56 5960521.95 N 557325.76 E 4.379 3299.54 Kuparuk 1D Comment Continued... 12 October, 1998 - 14:50 - 2- DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-116 Your Ref: API-500292291500 Kuparuk Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 4681.81 55.320 286.880 2611.87 2723.97 982.19 N 3233.11 W 4777.25 49.950 286.570 2669.77 2781.87 1004,02 N 3305.73 W 4873.09 45.590 286.340 2734.17 2846,27 1024.12 N 3373.77 W 4968.65 42.040 286,760 2803.12 2915.22 1042.96 N 3437.18 W 5062.64 36.510 288.150 2875.85 2987.95 1060.75 N 3493.93 VV 5157.31 31.490 288.400 2954.31 3066.41 1077.34 N 3544.18 VV 5253.17 28.000 284.920 3037.53 3149.63 1091.04 N 3589.70 W 5347.63 23.950 284.240 3122.43 3234.53 1101.47 N 3629.73 W 5441.25 19.870 286.570 3209.27 3321.37 1110.69 N 3663.41 VV 5631.71 17.360 286.580 3389.76 3501.86 1128.03 N 3721.68 VV 5916.35 16.390 285.360 3662.14 3774.24 1150.79 N 3801.10 VV 6180.19 15,490 282.780 3915.83 4027.93 1168.44 N 3871.36 VV 6245.00 15.490 282.780 3978.29 4090.39 1172.27 N 3888.24 VV 5960545.03 N 557249.71E 5960566.27 N 557176.92 E 5960585.83 N 557108.72 E 5960604.15 N 557045.16 E 5960621.49 N 556988.27 E 5960637.68 N 556937.89 E 5960651.01N 556892.26 E 5960661.12 N 556852.15 E 5960670.06 N 556818,40 E 5960686.93 N 556759.99 E 5960709.05 N 556680.39 E 5960726.14 N 556609.99 E 5960729.83 N 556593.08 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 286.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6245.00ft., The Bottom Hole Displacement is 4061.11ft., in the Direction of 286.778° (True). 5.417 5.632 4.553 3.727 5.957 5.305 4.061 4.299 4.455 1.318 0.363 0.434 0.000 Vertical Section (ft) 3379.01 3454.83 3525.78 3591.93 3651.40 3704.30 3751.84 3793.17 3828.O8 3888.87 3971.48 4043.84 4061.11 Kuparuk 1D Comment Projected Survey Continued... 12 October, 1998 - 14:50 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-116 Your Ref: API-500292291500 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 6245.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4090.39 1172.27 N 3888.24 W Comment Tie-on Survey Projected Survey 12 October, 1998 - 14:50 - 4 - DrillQuest WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 4, 1998 1D-116, AK-MM-80369 The technical data listed below is being submitted herewith. Please address any problems or ex)nc, ems to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~,-G, Anchorage, AK 99518 1I)-116: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22915-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22915-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A r3na_~e,~.r Inrhl.~fri~__~ Ina WEIJ, LOG TRANSMITTAL To: State of Alaska October 28, 1998 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~.~ MWD Formation Evaluation Logs 1D-116, AK-MM-80369 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22915-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 sper, m j-sLJr, 13-0ct-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 1D-116 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,245.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECi iVED OCT i 4 1998 A!a~a 0ii ~ ~a~ ~,~. Commission Ancb.0rage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 1, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kupamk River Unit 1 D- 116 ARCO Alaska, Inc. Permit No: 98-172 Sur Loc: 76'FNL, 597'FEL, Sec. 23. T11N. R10E. UM Btmhole Loc. 1107'FSL, 763'FWL, Sec. 14, T11N. RIOE. UM Dear Mr. McKav: Enclosed is the approved application for permit to drill thc 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 arc made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. ID-116. Please note that any disposal of fluids generated from this drilling operation which arc pumped down the surface/production casing annulus of a permitted existing well on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Robert N. Christcnson. P.E. Commissioner BY ORDER OF THE COMMISSION dlffEnclosurcs Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMM'~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas SingleZone X MultipteZone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 7]' 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) 76' FNL, 597' FEI_,, Sec. 23, T1 IN, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1066' FSL, 899' FWL, Sec. 14, TIIN, R10E, UM 1D-116 #U-630610 At total depth 9. Approximate spud date · Amount 1107' FSL, 763' FWL, Sec. 14, T11N, R10E, UM 9/9/98 $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-117 6366' MD 763' @ TD feet 12.9' @ 380' feet 2560 4173' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AA(::; 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle64.96° Maximum su,a~1393psig At total depth (TVD)1831psig 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 MOl': 6325' 41' 41' 6366' 4173' 633 Sx Arcticset III & 330 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural R E C E IV E[ Intermediate Perforation depth: measured true vertica~ Alaska 0ii & Gas Cons, 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X Drilling p~}~/I ~;~ Ddliing fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I~thattheTeg~ng~ct tO the best Of my knO~edge( [ "'7"~/~_ ~/~ /~/~F Signed / ('A'¢"V'~ ~1°/' '~~¢~¢O Title Kuparuk Drilling Team Leader Date Commission Use Only Permit Number APl nuh=~erApproval date letter for [ ¢--! ISeec°ver - ~ other requirements Conditions of approval Samples required Yes ~ Mud log required Yes Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure for BOPE 2M d~') 5M 10M 15M Other: ORIGINAL SIGNED BY by order of ¢~,~ ] ~. ¢¢ Approved by RoI~I~ N, ~hd-~t~n.~n Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA .:,~ .... ALASi'~t OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RY, J~ 4]', Pad 7]' feet Kuparuk River Field 3. Address 6. Properly Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD[, 25650, A[,K 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 76' FNL .59?' FEL, Sec. 2.3, T1 IN, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1066' FSL, 899' FWL, Sec. 14, TllN, R10E, UM 1D-Il6 #U-630610 At total depth 9. Approximate spud date Amount 1 ]07' FSL, 763' FW[,, Sec. ]4, T! IN, R]0E, U~ 9/9/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ]D-] ]7 6366' MD 763' @ TD feet 1~-.9' @ 380' feet 2560 4173' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 64.96° Maximum surface1393 >~g At 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~ Wei~]ht Grade Couplin~l Length MD TVD MD TVD (include staoe data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOC 6325' 41' 41' 6366' 4173' 633 Sx Arcticset III & 330 Sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Tru _e~e[~cq~eiNh i % Structural Conductor Surface Intermediate Production Liner Perforation depth: measured DUPLICATE true vertical ~,ia$[~a 0il & G~,$ COBS. Anch0rag~ 20. Attachments Filing fee X Property plat BOP Sketch X DiverterSketch X Ddlling program X Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X Signed / ~ ~v' -{I ~ ~'-'"'~'°~%CommissionO Titleuse Kuparuk Drilling Team Leader Date Onh/ Permit Number APl nu"'h~r ~'-',,~,~2.- 50-O ~--~'"" ~-~ ~---~'")'.-~' [ Approvaldate ¢,..l ... ~ ] See cover letter fOrother requirements Condltions of approval Samples required Yes (1~ Mud log required Yes Hydrogen sulfide measures Yes (.No~') Directional survey required ~ No Required working pressure for BOPE 2M ~ 5M 10M 15M Othen OJ~JGJN'/~LRobert N. ~h , ,,~SJGNED BY by order of Approved by ---r,$~.~Fr) _~,~ Commissioner the commission Date ED Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. '- -' Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 19, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-116 West Sak Phase lB 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 designated as a monobore production well using a single 7 5/8" casing string, With 3-1/2" tubing. 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 and West Sak 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-116, such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany There have been ten (10) Kuparuk wells and (20) 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. R E C [ IV E D AUG Nask~ Oil & Gas Cons. Commission An~h~qrBQO 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. lO) 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. Please note that the anticipated spud date for this well is September 9, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Operations Drilling Engineer CC: West Sak 1D-116 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-116 (El) Drilling Fluid T. ype 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 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10~35 5-10 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 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface/production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-116 (El) 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. 1D-116 (El) Page I SG,08/19/98,v. 1 Based on actual well test data from the nearby WSI-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 I:MW (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.? ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,54?' MD/TVD. 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 to surface, the following MASP can be computed: MASP = (3981 ft)(0.46-0.11 psi/fi) = 1393 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 casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 7 5/8" 29.7# LBO BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-116 (El) 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. Well Proximity Risks: The nearest existing well to West Sak 1D-116 (El) is WS 1D-117. As designed, the minimum distance between the two wells would be 12.9' at 380' 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 a permitted 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-116 (El) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1D-116 (El) Page 2 SG,08/20/98,v.1 Drill, Case and Completion Plan for West Sak 1D-116 (El) Frac Pack Producer General Procedure: 1. 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. 3. 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. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 7 5/8" casing _+1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar,{a top job may be performed in lieu of utilizing the port collar. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper _+2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1D-116 (El) Page I SG, 08/19/98, v.1 Completion Plan for West Sak 1 D-116 (El) Four-Stage, Single-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. Drop bar 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 1D-116 (El) Page 2 SG, 08/19/98, v.1 Stage 1 10. 11. 12. 13. 14. Stage 2 15. 16. 17. 18. 19. Stage 3 20. 21. 22. 23. 24. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frae for Stage 1. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 1. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 2. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 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. 1D-116 (El) Page 3 SG, 08/19/98, v.1 Stage 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. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 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. Circulate well to clean brine. TOH with workstring. Change rams to 3 1/2" and pressure test same unless VBR's are available. Pick up Centrilift ESP on 3 1/2" production tubing. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 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. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required, and set back pressure valve in tubing hanger. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. Release rig and turn well over to production. 29. 30. 31. 32. 33. 34. 35. 36. 37. 38. 1D-116 (El) Page 4 SG, 08/19/98, v.1 3-1/2' Production Tubing 9.3~ L-80 EUE 8RD-Mod Power Cable for ESP Centrilift West Sak Well 1D-116 (El) Four (4) Stage Frac-Pack 16" Conductor Casing @ 80' Raychem Heat Tmce (through permafrost) 2178' MD/1641' TVD TAM International 7 5~8" Port Collar Set at approximately 1000' TVD Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze Protection purposes) ESP Pump Section Centrilift ESP Gearbox Centdlift ESP Motor Section Centrilift D Sand Frec-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Fmc-Pack Assembh/with Screen Baker Oil Tools A3 Sand Fmc-Pack Assembly with Screen Baker Oil Tools 7-5/8" Comb/nation Surface/Production Casing, 29.7# L-80 BTC-MOD Set at 6366' MD/4173' TVD A2 Sand Fmc-Pack Assembly with Screen Baker Oil Tools ARCO Alaska, Inc. SG, 08/19/98 c.~o,.. ~ ,~. For: GOLDBERG D~tc Dlot~c~: 17-Jul-9~ Plot RI/ltence ;~ ~ lD-116/[1 verl. ~(. Coa~d{~te~ ore ;n ARCO Alaska, Inc. Structure : Pad 1D Well : 116 Field : Kuparuk River Unit Location : North Slope, Alaska I v 4200 TO LOCATION: 1107' FSL, 765' FWL SEC. 14, T11N, RIOE 300 6O0 900 1 200 500 1 800 2100 2400 2700 3O00 3.300 5600 3900 4200 4500 <- West (feet) 3900 3600 3300 5000 2700 2400 I I I I I I I I I I I I I 2100 I 1800 1500 1200 900 600 300 0 I I I I I I I t I I I I I TARGET LOCATION: 1066' FSL, 899' FWL SEC. 14, TllN, RIOE TARGET TV0=3694 ' TMD=5867 0EP=3952 NORTH 1 !42 RKB ELEVATION: 112' KOP TVD=400 TMD=400 DEP=0 5.00 I 0.00 15.00 20.00 DLS: 5.00 deg per 100 ft 25.00 30.00 35.00 40.00 45.00 50.00 I'OOEoC TVD=1458 TMD=1699 OEP=661 ~ WEST 3784 se permo(ro$t "~oc 286.8 AZIMUTH (TO 300 i 1500 I1200 I900 i600 300 0 L300 I SURFACE LOCATION: 76' FNL, 597' FEL SEC. 23, T11N, RIOE 8/ PERMAFROST TVD=1641 TM0=2178 DEP=1095 MAXIMUM ANGLE 64.96 DEG BEGIN ANGLE DROP TVD=2643 TMD=4-544- DEP=3238 60.00 50.00 45.00 T/ UGNU SNDS 'rVD=2953 TMD=5055 0EP=3639 ¢0.00 DLS: 5.00 deg per 100 ft 35.00 30.00 25.00 20.00 END ANGLE DROP TV0=3355 TMD=5513 DEP=3852 T/ W SAK SNDS WD=35¢7 TMO=5713 DEP=3909 TARGET - A3 TVD=3694 TMD=5867 DEP=3 TARGET ANGLE 16.5 DEG B/ W SAK SNDSTVD=3981 TM0=6166 OEP=4037 TD - CSG PT TVD=4173 TMD=6366 DEP=4094 i i I 300 600 I I J I I I I II I I I ! I I I I I I I 900 1200 1500 1800 21 O0 2400 2700 3000 3300 3600 Vertical SecHon (feet) -> Azimuth 286.80 with reference 0.00 N, 0.00 E from slot #116 ! 3900 I I t 4200 4500 /k I Z 0 ARCO Alaska, Inc. Pad LD 116 slot ~116 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNC-~.TAINTIES by Baker Hughes INTEQ Your ref = WS 1D-IlS/E1 Vets. #4 Our ref = prop2210 License = Date printed = 16-Jul-98 Date created = 17-Apr-9? Last revised : 16-Jul-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 0.568,w1%9 30 36.313 Slot Grid coordinates are N 5959588.687, E 560490.578 Slot local coordinates are 76.00 S 597.00 W Projection type= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 286.80 0.00 0.00 N 0.00 E 400.00 0.00 286.80 400.00 0.00 N 0.00 E 500.00 5.00 286.80 499.87 1.26 N 4.17 W 600.00 10.00 286.80 598.99 5.03 N 16.67 W 700.00 15.00 286.80 696.58 11.28 N 37.38 W 800.00 20.00 286.80 791.93 19.97 N 66.16 W 900.00 25.00 286.80 884.28 31.03 N 102.78 W 1000.00 30.00 286.80 972.96 44.37 N 146.97 W 1100.00 35.00 286.80 1057.27 59.89 N 198.39 W 1200.00 40.00 286.80 1136.58 77.48 N 256.65 W 1300.00 45.00 286.80 1210.28 96.99 N 321.31 W 1400.00 50.00 286.80 1277.82 118.29 N 391.87 W 1500.00 55.00 286.80 1338.68 141.21 N 467.80 W 1600.00 60.00 286.80 1392.39 165.58 N 548.51 W 1699.12 64.96 286.80 1438.18 190.98 N 632.64 W 1699.13 64.96 286.80 1438.18 190.98 N 632.65 W 2000.00 64.96 286.80 1565.54 269.75 N 893.60 W 2178.25 64.96 286.80 1641.00 316.42 N 1048.20 W 2500.00 64.96 286.80 1777.20 400.66 N 1327.26 W 3000.00 64.96 286.80 198~.85 531.58 N 1760.93 W 3500.00 64.96 286.80 2200.50 662.49 N 2194.59 W 4000.00 64.96 286.80 2412.15 793.40 N 2628.26 W 4500.00 64.96 286.80 2623.81 924.31 N 3061.92 W 4544.18 64.96 286.80 2642.51 935.88 N 3100.24 W 4643.31 60.00 286.80 2688.30 961.28 N 3184.38 W 4743.31 55.00 286.80 2742.01 985.64 N 3265.10 W 4843.31 50.00 286.80 2802.87 1008.56 N 3341.02 W 4943.31 45.00 286.80 2870.41 1029.86 N 3411.58 W 5043.31 40.00 286.80 2944.11 1049.38 N 3476.24 W 5054.87 39.42 286.80 2953.00 1051.51 N 3483.30 W 5143.31 35.00 286.80 3023.42 1066.97 N 3534.50 W 5243.31 30.00 286.80 3107.74 1082.49 N 3585.92 W 5343.31 25.00 286.80 3196.41 1095.83 N 3630.11 W 5443.31 20.00 286.80 3288.77 1106.88 N 3666.73 W 5513.31 16.50 286.80 3355.24 1113.22 N 3687.72 W PROPOSAL LISTING Page 1 Your ref = WS 1D-116/E1 Vers. #4 Last revised ~ 16-Jul-98 Dogle~ Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 5.00 4.36 5.00 17.41 5.00 39.05 5.00 69.11 5.00 107.36 5.00 153.52 5.00 207.24 5.00 268.09 5.00 335.63 5.00 409.34 5.00 488.65 5.00 572.96 5.00 660.83 EOC 5.00 .660.84 0.00 933.43 0.00 1094.92 Base Permafrost 0.00 1386.42 0.00 1839.41 0.00 2292.41 0.00 27%5.%0 0.00 3198.39 0.00 3238.42 Begin Angle Drop 5.00 3326.31 5.00 3410.62 5.00 3489.93 5.00 3563.6% 5.00 3631.17 5.00 3638.55 Top Ugnu Sands 5.00 3692.03 5.00 3745.74 5.00 3791.90 5.00 3830.16 5.00 3852.08 End ~gle Dro~ 5713.31 16.50 286.80 3547.00 1129.63 N 3742.10 W 0.00 5866.62 16.50 286.80 3693.99 1142.22 N 3783.78 W 0.00 5866.63 16.50 286.80 3694.00 1142.22 N 3783.78 W 0.00 6000.00 16.50 286.80 3821.88 1153.16 N 3820.04 W 0.00 6165.95 16.50 286.80 3981.00 1166.79 N 3865.17 W 0.00 6365.95 16.50 286.80 4172.76 1183.20 N 3919.55 W 3908.88 Top West Sak Sands 3952.42 TARGET - West Sak A3 3952.42 WS 1D-E1 Rvsd 26-Jan-98 3990.30 %037.44 Base West Sak Sands 0.00 4094.24 TD - Casing Pt All data is in feet unless other~cise stated. Coordinates from slot #116 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.2% on azimuth 286.80 degrees from wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Calculation uses the =~nimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Comments in we11path MD TVD Rectangular Coords. Comment ........................................................................................................... 400.00 400.00 0.00 N 0.00 E KOP 1699.12 1438.18 190.98 N 632.64 W EOC 2178.25 1641.00 316.42 N 1048.20 W Base Permafrost 4544.18 2642.51 935.88 N 3100.24 W Begin Angle Drop 5054.87 2953.00 1051.51 N 3483.30 W Top U~nu Sands 5513.31 3355.24 1113.22 N 3687.72 W End Angle Drop 5713.31 3547.00 1129.63 N 3742.10 W Top West Sak Sands 5866.62 3693.99 1142.22 N 3783.78 W TARGET - West Sak A3 5866.63 3694.00 1142.22 N 3783.78 W WS 1D-E1 Rvsd 26-Jan-98 6165.95 3981.00 1166.79 N 3865.17 W Base West Sak Sands 6365.95 4172.76 1183.20 N 3919.55 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with this wellpath ====== ~ = ===_-_-==_-==--=--= = Target name Geographic Location T.V.D. Rectangular C~ordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 286.80 0.00 76.00 S 597.00 W 400.00 0.00 286.80 400.00 76.00 S 597.00 W 500.00 5.00 286.80 499.87 74.74 S 601.17 W 600.00 10.00 286.80 598.99 70.97 S 613.67 W 700.00 15.00 286.80 696.58 64.72 S 634.38 W 800.00 20.00 286.80 791.93 56.03 S 663.16 W 900.00 25.00 286.80 884.28 44.97 S 699.78 W 1000.00 30.00 286.80 972.96 31.63 S 743.97 W 1100.00 35.00 286.80 1057.27 16.11 S 795.39 W 1200.00 40.00 286.80 1136.58 1.48 N 853.65 W 1300.00 45.00 286.80 1210.28 20.99 N 918.31 W 1400.00 50.00 286.80 1277.82 42.29 N 988.87 W 1500.00 55.00 286.80 1338.68 65.21 N 1064.80 W 1600.00 60.00 286.80 1392.39 89.58 N 1145.51 W 1699.12 64.96 286.80 1438.18 114.98 N 1229.64 W 1699.13 64.96 286.80 1438.18 114.98 N 1229.65 W 2000.00 64.96 286.80 1565.54 193.75 N 1490.60 W 2178.25 64.96 286.80 1641.00 240.42 N 1645.20 W 2500.00 64.96 286.80 1777.20 324.66 N t924.26 W 3000.00 64.96 286.80 1988.85 455.58 N 2357.93 W 3500.00 64.96 286.80 2200.50 586.49 N 2791.59 W 4000.00 64.96 286.80 2412.15 717.40 N 3225.26 W 4500.00 64.96 286.80 2623.81 848.31 N 3658.92 W 4544.18 64.96 286.80 2642.51 859.88 N 3697.24 W 4643.31 60.00 286.80 2688.30 885.28 N 3781.38 W 4743.31 55.00 286.80 2742.01 909.64 N 3862.10 W 4843.31 50.00 286.80 2802.87 932.56 N 3938.02 W 4943.31 %5.00 286.80 2870.41 953.86 ~ 4008.58 W 5043.31 40.00 286.80 2944.11 973.38 N 4073.24 W 5054.87 39.42 286.80 2953.00 975.51 N 4080.30 W 5143.31 35.00 286.80 3023.42 990.97 N 4131.50 W 5243.31 30.00 286.80 3107.74 1006.49 N 4182.92 W 5343.31 25.00 286.80 3196.41 1019.83 N 4227.11 W 5443.31 20.00 286.80 3288.77 1030.88 N 4263.73 W 5513.31 16.50 286.80 3355.24 1037.22 N 4284.72 W PROPOSA5 LISTING Page 1 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 5.00 4.36 5.00 17.41 5.00 39.05 5.00 69.11 5.00 107.36 5.00 153.52 5.00 207.24 5.00 268.09 5.00 335.63 5.00 409.34 5.00 488.65 5.00 572.96 5.00 660.83 EOC 5.00 660.84 0.00 933.43 0.00 1094.92 Base Permafrost 0.00 1386.42 0.00 1839.41 0.00 2292.41 0.00 2745.40 0.00 3198.39 0.00 3238.42 Begin Angle Drop 5.00 3326.31 5.00 3410.62 5.00 3489.93 5.00 3563.64 5.00 3631.17 5.00 3638.55 Top Ugnu Sands 5.00 3692.03 5.00 3745.74 5.00 3791.90 5.00 3830.16 5.00 3852.08 End Angle Drop 5713.31 16.50 286.80 3547.00 1053.63 N 4339.10 W 0.00 5866.62 16.50 286.80 3693.99 1066.22 N 4380.78 W 0.00 5866.63 16.50 286.80 3694.00 1066.22 N 4380.78 W 0.00 6000.00 16.50 286.80 3821.88 1077.16 N 4417.04 W 0.00 6165.95 16.50 286.80 3981.00 1090.V9 N 4462.17 W 0.00 6365.95 16.50 286.80 4172.76 1107.20 N 4516.55 W 3908.88 Top West Sak Sands 3952.42 TARGET - West Sak A3 3952.42 WS 1D-E1 Rvsd 26-Jan-98 3990.30 4037.44 Base West Sak Sands 0.00 4094.24 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees fram wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-IlS/E1 Vets. #4 Last revised ~ 15-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 400.00 76.00 S 597.00 W KOP 1699.12 1438.18 2178.25 1641.00 4544 18 2642.51 5054 87 2953.00 5513 31 3355.24 5713 31 3547.00 5866 62 3693.99 5866 63 3694.00 6165.95 3981.00 6365.95 4172.76 114.98 N 1229.64 W EOC 240.42 N 1645.20 W Base Permafrost 859.88 N 3697.24 W Begin Angle Drop 975.51 N 4080.30 W Top Ugnu Sands 1037.22 N 4284.72 W End Angle Drop 1053.63 N 4339.10 W Top West Sak Sands 1066.22 N 4380.78 W TARGET - West Sak A3 1066.22 N 4380.78 W WS 1D-E1 Rvsd 26-Jan-98 1090.79 N 4462.17 W Base West Sak Sands 1107.20 N 4516.55 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot ~D Bot TVD Rectangular Coords. Casing 0.00 0.00 76.00S 597.00W 6365.95 4172.76 1107.20N 4516.54W 7 5/8" Casing Targets associated with this we11path ....... ===================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1066.22N 4380.78W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C O O R D PROPOSAL LISTING Page 1 Your ref: WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 N G ~ L A R Vert Ellipse Semi Axes Minor I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 286.80 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 400.00 0.00 286.80 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 5.00 286.80 499.87 1.26 N 4.17 W 4.36 1.34 1.31 0.75 286.80 600.00 10.00 286.80 598.99 5.03 N 16.67 W 17.41 1.84 1.59 0.90 286.80 700.00 15.00 286.80 696.58 11.28 N 37.38 W 39.05 2.72 1.90 1.06 286.80 800.00 20.00 286.80 791.93 19.97 N 66.16 W 69.11 4.10 2.26 1.24 286.80 900.00 25.00 286.80 884.28 31.03 N 102.78 W 107.36 6.07 2.66 1.45 286.80 1000.00 30.00 286.80 972.96 44.37 N 146.97 W 153.52 8.67 3.11 1.71 286.80 1100.00 35.00 286.80 1057.27 59.89 N 198.39 W 207.24 11.95 3.60 2.04 286.80 1200.00 40.00 286.80 1136.58 77.48 N 256.65 W 268.09 15.96 4.12 2.45 286.80 1300.00 45.00 286.80 1210.28 96.99 N 321.31 W 335.63 20.71 4.65 2.95 286.80 1400.00 50.00 286.80 1277.82 118.29 N 391.87 W 409.34 26.19 5.18 3.54 286.80 1500.00 55.00 286.80 1338.68 141.21 N 467.80 W 488.65 32.39 5.70 4.23 286.80 1600.00 60.00 286.80 1392.39 165.58 N 548.51 W 572.96 39.26 6.19 5.01 286.80 1699.12 64.96 286.80 1438.18 190.98 N 632.64 W 660.83 46.66 6.63 5.87 286.80 1699.13 64.96 286.80 1438.18 190.98 N 632.65 W 660.84 .46.66 6.63 5.87 286.80 2000.00 64.96 286.80 1565.54 269.75 N 893.60 W 933.43 69.24 7.96 8.51 286.80 2178.25 64.96 286.80 1641.00 316.42 N 1048.20 W 1094.92 82.67 8.75 10.09 286.80 2500.00 64.96 286.80 1777.20 400.66 N 1327.26 W 1386.42 106.91 10.17 12.95 286.80 3000.00 64.96 286.80 1988.85 531.58 N 1760.93 W 1839.41 144.64 12.37 17.40 286.80 3500.00 64.96 286.80 2200.50 662.49 N 2194.59 W 2292.41 182.39 14.57 21.86 286.80 4000.00 64.96 286.80 2412.15 793.40 N 2628.26 W 2745.40 220.14 16.77 26.32 286.80 4500.00 64.96 286.80 2623.81 924.31 N 3061.92 W ]198.39 257.91 18.96 30.78 286.80 4544.18 64.96 286.80 2642.51 935.88 N 3100.24 W 3238.42 261.25 19.16 ]1.18 286.80 4643.31 60.00 286.80 2688.30 961.28 N 3184.38 W 3326.31 268.15 19.64 31.99 286.80 4743.31 55.00 286.80 2742.01 985.64 N 3265.10 W 3410.62 274.44 20.16 32.73 286.80 4843.31 50.00 286.80 2802.87 1008.56 N 3341.02 W 3489.93 280.03 20.70 33.39 286.80 4943.31 45.00 286.80 2870.41 1029.86 N 3411.58 W 3563.64 284.87 21.26 33.95 286.80 5043.31 40.00 286.80 2944.11 1049.38 N 3476.24 W 3631.17 288.97 21.81 34.43 286.80 5054.87 39.42 286.80 2953.00 1051.51 N 3483.30 W 3638.55 289.36 21.88 34.48 286.80 5143.31 35.00 286.80 3023.42 1066.97 N 3534.50 W 3692.03 292.33 22.35 34.83 286.80 5243.31 30.00 286.80 3107.74 1082.49 N 3585.92 W 3745.74 294.98 22.87 35.14 286.80 5343.31 25.00 286.80 3196.41 1095.83 N 3630.11 W 3791.90 296.99 23.34 35.38 286.80 5443.31 20.00 286.80 3288.77 1106.88 N 3666.73 W 3830.16 298.41 23.76 35.56 286.80 5513.31 16.50 286.80 3355.24 1113.22 N 3687.72 W 3852.08 299.15 24.02 35.66 286.80 5713.31 16.50 286.80 3547.00 1129.63 N 3742.10 W 3908.88 301.28 24.79 35.95 286.80 5866.62 16.50 286.80 3693.99 1142.22 N 3783.78 W 3952.42 302.90 25.38 36.17 286.80 5866.63 16.50 286.80 3694.00 1142.22 N 3783.78 W 3952.42 302.90 25.38 36.17 286.80 6000.00 16.50 286.80 3821.88 1153.16 N 3820.04 W 3990.30 304.32 25.89 36.37 286.80 6165.95 16.50 286.80 3981.00 1166.79 N 3865.17 W 4037.44 306.10 26.53 36.61 286.80 6365.95 16.50 286.80 4172.76 1183.20 N 3919.55 W 4094.24 308.23 27.29 36.90 286.80 All data is in feet u~less otherwise stated. Coordinates from slot #116 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees from wellhead. Vertical section is from wellhead on azimuth 288.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: WS 1D-116/E1 Vers. #4 Last revised : 16-Jul-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Sur'vey Tool Error Model Major Minor V~rt. 0 6366 ARCO (H.A. Mag) User specified 308.23 27.29 36.90 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak ~anual. Comments in we11path MD TVD Rectangular Cocrds. Comment 400.00 400.00 0.00 N 0.00 E KOP 1699.12 1438.18 190.98 N 632.64 W E0C 1178.25 1641.00 316.42 N 1048.20 W Base Permafrost 4544.18 2642.51 935.88 N 3100.24 W Beg£nAngle Drop 5054.87 2953.00 1051.51 N 3483.30 W Top Ugnu Sands 5513.31 3355.24 1113.22 N 3687.72 W End Angle Drop 5713.31 3547.00 1129.63 N 3742.10 W Top West Sak Sands S866.62 3693.99 1142.22 N 3783.78 W TARGET - West Sak ~ 5866.63 3694.00 1142.22 N 3783.78 W WS 1D-E1 Rvsd 26-Jan-98 6165.95 3981.00 1166.79 N 3865.17 W Base West Sak Sands 6365.95 4172.76 1183.20 N 3919.55 W TD - Casing Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-0ct-96 ARCO Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1D,116 Your ref : WS 1D-116/E1 Vers. Kuparuk River Unit,North Slope, Alaska Last revised : 16-Jul-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S Dogleg Vert G R I D C 0 0 R D S Deg/100ft Sect Easting Northing 0.00 0.00 286.80 0.00 0.00N 0.00E 0.00 0.00 560490.58 5959588.69 400.00 0.00 286.80 %00.00 0.00N 0.00E 0.00 0.00 560%90.58 5959588.69 500.00 5.00 286.80 %99.87 1.26N 4.17W 5.00 4.36 560486.39 5959589.91 600.00 10.00 286.80 598.99 5.03N 16.67W 5.00 17.41 560473.87 5959593.58 700.00 15.00 286.80 696.58 11.28N 37.38W 5.00 39.05 560453.11 5959599.67 800.00 20.00 286.80 791.93 19.97N 66.16W 5.00 69.11 560424.27 5959608.12 900.00 25.00 286.80 884.28 31.03N 102.78W 5.00 107.36 560387.56 5959618.87 1000.00 30.00 286.80 972.96 %4.37N 146.97W 5.00 153.52 560343.26 5959631.85 1100.00 35.00 286.80 1057.27 59.89N 198.39W 5.00 207.24 560291.72 59596%6.96 1200.00 40.00 286.80 1136.58 77.%8N 256.65W 5.00 268.09 560233.33 595966%.07 1300.00 45.00 286.80 1210.28 96.99N 321.31W 5.00 335.63 560168.52 5959683.06 1400.00 50.00 286.80 1277.82 118.29N 391.87W 5.00 409.3% 560097.80 5959703.78 1500.00 55.00 286.80 1338.68 141.21N %67.80W 5.00 488.65 560021.69 5959726.08 1600.00 60.00 286.80 1392.39 165.58N 548.51W 5.00 572.96 5599%0.79 5959749.79 1699.12 64.96 286.80 1%38.18 190.98N 632.64W 5.00 660.83 559856.%7 595977%.50 1699.13 64.96 286.80 1438.18 190.98N 632.65W 5.00 66.0.8% 559856.%6 595977%.50 2000.00 64.96 286.80 1565.5% 269.75N 893.60W 0.00 933.43 559594.90 5959851.1% 2178.25 64.96 286.80 16%1.00 316.%2N 10%8.20W 0.00 1094.92 559%39.9% 5959896.55 2500.00 6¢..96 286.80 1777.20 400.66N 1327.26W 0.00 1386.42 559160.23 5559978.51 3000.00 $%.96 286.80 1988.85 531.58N 1760.93W 0.00 1839.41 558725.55 K960105.88 3500.00 64.96 286.80 2200.50 662.49N 2194.59W 0.00 2292.%1 558290.88 5960233.25 4000.00 64.96 286.80 2412.15 793.%0N 2628.26W 0.00 2745.40 557856.21 5960360.62 4500.00 64.96 286.80 2623.81 92%.31N 3061.92W 0.00 3198.39 557421.53 5960%87.99 %544.18 64.96 286.80 26%2.51 935.88N 3100.24W 0.00 3238.%2 557383.13 5960499.24 4643.31 60.00 286.80 2688.30 961.28N 3184.38W 5.00 3326.31 557298.79 5960523.95 4743.31 55.00 286.80 2742.01 985.64N 3265.10W 5.00 3410.62 557217.89 5960547.66 4843.31 50.00 286.80 2802.87 1008.56N 3341.02W 5.00 3489.93 557141.79 5960569.96 4943.31 45.00 286.80 2870.%1 1029.86N 3411.58W 5.00 3563.64 557071.06 5960590.68 5043.31 40.00 286.80 2944.11 1049.38N 3476.24W 5.00 3631.17 557006.26 5960609.67 5054.87 39.42 286.80 2953.00 1051.51N 3483.30W 5.00 3638.55 556999.18 5960611.75 5143.31 35.00 286.80 3023.%2 1066.97N 3534.50W 5.00 3692.03 556947.86 5960626.78 5243.31 30.00 286.80 3107.74 1082.%9N 3585.92W 5.00 37%5.74 556896.32 5960641.89 5343.31 25.00 286.80 3196.%1 1095.83N 3630.11W 5.00 3791.90 556852.03 596065%.87 5443.31 20.00 286.80 3288.77 1106.88N 3666.73W 5.00 3830.16 556815.32 5960665.62 5513.31 16.50 286.80 3355.24 1113.22N 3687.72W 5.00 3852.08 556794.29 5960671.79 5713.31 16.50 286.80 35%7.00 1129.63N 3742.10W 0.00 3908.88 556739.78 5960687.76 5866.62 16.50 286.80 3693.99 11%2.22N 3783.78W 0.00 3952.%2 556698.00 5960700.00 5866.63 16.50 286.80 3694.00 1142.22N 3783.78W 0.00 3952.%2 556698.00 5960700.00 6000.00 16.50 286.80 3821.88 1153.16N 3820.04W 0.00 3990.30 556661.65 5960710.65 616~.95 16.50 286.80 3981.00 1166.79N 3865.17W 0.00 4037.4% 556636.42 5960723.90 6365.95 16.50 286.80 4172.76 1183.20N 3919.55W 0.00 4094.24 556561.92 5960739.87 #4 Ail data in feet unless otherwise stated. Calculation uses minimLun curvature method. Coordinates from slot #116 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is %094.24 on azimuth 286.80 degrees from wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1Do116/E1 Vets. #4 Last revised = 16-Jul-98 Comments in we11path MD TVD Rectangular Coords. Comment 400.00 400.00 0.00N 1699.12 1438.18 190.98N 2178.25 .1641.00 316.42N 4544.18 2642.51 935.88N 5054.87 2953.00 1051.'51N 5513.31 3355.24 1113.22N 5713.31 3547.00 1129.63N 5866.62 3693.99 1142.22N 5866.63 3694.00 1142.22N 6165.95 3981.00 1166.79N 6365.95 4172.76 1183.20N 0.00E KOP 632.64W EOC 1048.20W Base Permafrost 3100.24W Begin Angle Drop 3483.30W Top Uguu Sands 3687.72W End Angle Drop 3742.10W Top West Sak Sands 3783.78W TARGET - West Sak A3 3783.78W WS 1DOE1 Rvsd 26-Jan-98 3865.17W Base West Sak Sends 3919.55W TD - Casing Pt Casing positions in string ~At Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with ~his we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-0ct-96 IOeo~ed by {inch For: GOLDDERGI Dote plotted: 1?-Jul-98 Plot Reference is WS 10-116/[I Vets. ~4. Coord;natc'~ ore in lcct reference slot J116. ARCO Alaska, Inc. Structure : Pod 1D Well: 116 Field : Kuporuk River Unit Locotion : North Slope, Alosko 800 320 280 240 200 160 120 8O 40 4O 80 120 160 200 240 <- West (feet) 760 720 680 640 600 560 520 480 4.40 400 360 320 280 240 200 160 120 BO 40 0 40 80 1500 2700 1400 2600 2500 5100 SO00 2900 2400 2800 ~ ',~".,",, ,,',, ',,~2oo\ ', '. 86~ ~00 ~ "'C'-. ",,",, '~ X ',8oo ~ ..,.::.....,,,:,,,~oo ~o~ ~',, ~o~ "...:>... ',,:::,.,, ?' ~<,,,, '~, "~ ~ ",,.",, 900",",, 1100 800',, 1200 ~ ", '" ", ", ',, - "'-" ',, ",,'",, ',,90~k .... ' 1400 "','",, 71 'X~O~, ',, ',, 1000 800 ~', "-, 60~" 100( 1500 '",, '"x,gO0 50~"., 1500 2100 ",.,,70~,,,~ 800""~ 60 2500 2OOO ~900 ~800 900 12~, ' ........ ~ 0 1200 500" 600 1700 16OO ~00 1100 7OO 2700 1000 2600 900 25OO 8O0 ~ 2400 ......... ~2300 ...... ~~.~2200 500(~f/' ~ 1700 .... ~'""----..~100 5001~. ............................ ,vw .......................... 1300 ~ - 1300r-~-, ............... 1200 ~u. .................... 1100 .... ~Juu ~-~ ............. ~uuu 900 -- ~ 500 ..................... 8OU ............. 5oo~.4oo ........... /~16oo 50~zm1800 8oo ................. 2100~10g~ 500 .J 19~ ................ 12oo I T '--'T~ I I I I ~"----'1 F ~' I--'--~I I I I I I I I I I ~ I I I I I I I I 800 760 720 680 640 600 560 520 480 440 400 360 320 280 24.0 200 160 120 80 40 0 40 80 <'- West (feet) 320 280 240 200 160 120 BO 4O 8O 120 160 200 240 Z Crco~.o o7 ri. ch For: GOLDBERG} Dote plotted: 17-Ju1-98 ~ J Plot Rcf ...... i, WS 1D-116/£1 V .... ~. / J Coordlnot ..... 'n tcct ret ....... lot ~, '6. / ARCO Alaska, Inc. Structure : Pod lO Well : 116 Field : Kuporuk River Unit Locofion : North Slope, Alosko <- West (feet) 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1 I00 1000 900 800 700 60~ · O0 1 1000 '"'"~'"" '", "' 1000 ".,"', ', '~ 1700 90£ ~- '"'","-2J O0 ",, ",, SO0 800 . . ~~..,.~ ""~,"'. 1500 '"' ~ t · ~ ",::,,, '¢l- 800 ~oo ",,::.::,::%,, 700 21 O0 '"~",',,, 1 300 600 I ,%o. ........... z 0 0 ~ '-.,..1700 4,00 '-'"'-"~ 9 oo"~--------_.~ ; oo ,oo ............ 1.??o 2900 3~00 ~ -"'-'---,-._3900 ...... ~ 200 2700 3 ........................... 2500 29o-6'¢-- ................................... 2300 lOO o ....................... 2100 ....................... 1900 ................. ~.1700 loo 2o0 600 "+- 500 4-00 0 Z 500 200 100 1 oo 200 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 <- West (feet) Creotea I~, fincin For: GOLDI~EHG I oo~,¢ plol.%cCl: 17-Ju~-98 ~ PIO~ Rcfcronce J~ WS 10-116/EI Vcr~. ~, ~ rru~ Vc~col Ocpth~ arc reference RK~ (Porker ~245).l ARCO Alaska, Inc. Structure : Pod lO Well : 116 Field : Kuparuk River Unit Location : North Slope. Alaska 1800 1600 1400 1200 1000 BOO 600 400 200 200 400 600 800 <- West (feet) 4-800 4-600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 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 I I I I I I I I I I '-.....,. ',,. ,,, ',,\;soo \ ~7oo '"'?i" 1 gO0 '.. ". ".X3300 '..... '",, "', ", ", ',,. \ 2 I00 250~'",,'", ~ 900 ~ 700", ',, ,,, \ 1400 -,..'-,., ',,, ',., ~ 9oo ',,. \ '-,:::,,, ',,,',, ,7o~,,, ~c -,.::,.,,,,,. ',,,::,,,, ,,,,. ~ ,~oo r~.. 41oo ........... .~.5oo _550 [~02900 2300'.", 1700 "..".. .... 3100 '".". 'x" [~.-' ........ 2900 "~u~700 ',.:.,. 1500 ,,", '~700 ............. 2700 '"'""~500 '":::',. ',,',,,,! 700~ 1000 % 6500 ............. ~' 2~00 '""""'" '"?" ~6300 ......... 2500 -'-~aul 2108'%, 1500 ~oo A ~~oo ............. ~ oo ~~ ~o~%~ ~ ~oo ......... :"'"--~- ...... '~L ",~oo ~oo ~o ~ ~7oo , ' .......... -~!°° ~ 7oo~ ~ ~oo .,,,,, .~ - ........... ~ 700 ~'7~./~,7' "-" 700 '"~ ...... [~3_1..0.?__3700 3500 3100 "g0" ~~ 3900 ...... !'5-9,?./->.._ 200 ~ .............................. ~..~ 2700 2500 3~OO~'~'"--~~O? ~ ~ v ................... ~oo ~oo ' ~oo~.~:~ ................. 2100 1§00 ........................................ t ?.o..o.~ o ~o0 ..... -~, 200 1500 ................. 1700 ..................... 2100~ 1900 .................... _~_...~-ff~. ~.~ 400 ~,oo ...................... ~ 2300 ....................... ~ '~'"~'~'nn ...... 2500 ........... 600 5500 2900 2..7..0.0. ................ , ~ 2700......ff,~500 ~,oo ~?..o. ................. ~.-~¢,=~ ,,oo .... , to?......->~ ~.~ ~ ......... ,~oo ~- ~oo I '1 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 I : I I I'' -I 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 <- West (feet) ARCO Alaska, Inc. Structure : Pod 1D Well : 116 Field : Kuporuk River Unit Location : North Slope, Alosko WELL PROFILE .....Point .....~lO Inc Oir ~0 r~e on 0.~0 0.00 288.80 0.00 KOP 400.00 0.00 286,80 ~0.~ ~ of HOld 4544.1~ 64.g6 2B~.80Z642.51 ~d Of ~Op 5513.31 16.~ 286.B0~55.24 T.0. ~ ~d of H01d 6365.g5 16.50 286.804172.76 DATA No?th Eest V. SectOeq/1 O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1 g0.98 -632.65 560.84 5, DO 955.88-3100.24 113.22-3687.725lt52.08 5.00 142.22-'~783.78 3952.'l.2 0.00 165.79-.3116~.17 40~7.~,4 0.00 1183.20 -.391g.55 4094.240.00 320 330 35O 340 \, TRUE NORTH 0 10 2O ,,~0 13oo C,.otcd ~,~ For: GOLDBERG Dote plotted : 1?-Jul-g8 PJ~t Refgrence ;~ ~ 10--116~1 Vets. ~&_ true Vedlc~ 0egth~ crc re,grace RKB (Pcr~ 310 50 500 290 7O 280 270 500 8O go 260 100 250 1!0 240 2O 230 220 · · .- 2OO ~0 Normol Plone Trovelling Cylinder - Feet 900 9OO 180 170 160 150 ~p" All depths shown ore Meosured depths on Reference Well ARCO Alaska, Inc. Pad 1D 116 slot #116 Kuparuk River Onit North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : WS 1D-116/E1 Vets. #4 Our ref : prop2210 License : Date printed : 17-Jul-98 Date created : 17-Apr-97 Last revised : 16-Jul-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n?0 18 0.568,w149 30 36.313 Slot Grid coordinates are N 5959588.687, E 560490.578 Slot local coordinates are 76.00 S 597.00 W Projection type= alaska - Zone 4, Spheroid= Clarke - 1866 · Reference North is True North Object wellpath PMSS <O-4414'>,,121,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <Oo4590'>,,118,Pad 1D PMSS <O-5205~>,,117,Pad 1D P~S <O-4850'>,,109,Pad 1D PHSS <O-5126'>,,106,Pad 1D PHSS <381-6092~>,,105,Pad 1D PMSS <195?-5265'>,,133,Pad 1D PMSS <0-5015~>,,135,Pad 1D PMSS <O-5047~>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGHS <0-8365'>,,1,Pad 1D PGMS <0-9783~>,,2,Pad 1D PG~MS <0-8070'>,,3,Pad 1D PG'MS <O-7502'>,,4,Pad 1D PGMS <0-8930'>,,5,Pad 1D PG'MS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0-5142'>,,liS,Pad 1D PMSS <0 - 7340'>,,10,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 7432~>,,127,Pad 1D PMSS <0 - 6716~>,,126,Pad ID PMSS <0 - 6472~>,,131,Pad 1D PMSS <377 - ???~>,,134,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-Jun-98 103.3 450.0 450.0 2-Jun-98 89.2 425.0 425.0 2-Jun-98 73.5 425.0 5620.0 2-Ju~-98 30.0 100.0 100.0 2-Jun-98 12.9 380.0 380.0 2-Jun-98 135.0 100.0 100.0 2-Jun-98 178.2 725.0 725.0 2-JLtno98 209.5 300.0 300.0 2-Jun-98 372.1 340.0 340.0 2-JLul-98 450.0 120.0 120.0 2-Jtul-98 191.6 475.0 475.0 21-May-98 527.0 40.0 40.0 10-Dec-9? 299.1 875.0 875.0 4-Aug-92 191.5 575.0 575.0 4-Aug-92 69.3 625.0 6365.9 4-Aug-92 47.2 20.0 20.0 13-Nov-97 167.1 20.0 400.0 13-Nov-97 287.0 20.0 20.0 6-Nov-97 407.0 400.0 400.0 29-Apr-98 59.3 475.0 475.0 2-Jun-98 15.0 180.0 180.0 28-Apr-98 480.0 120.0 120.0 2-Jun-98 314.3 300.0 300.0 2-Jun-98 329.9 400.0 400.0 6-Jul-98 238.4 300.0 300.0 1-Jul-98 223.9 360.0 360.0 15-Jul-98 345.0 100.0 100.0 17-Jul-98 434.2 300.0 300.0 F~OPll KUPURI~K TOOL HOUSE FAX HO s 659 7&BI g?-2?-gg 13=15 2 I ~ . I ~ ~ ~ Ill ~' 122~) I' ~ 1~ ! ' 132 t _~o ~' , I ~o ~ ~ ' i i ii o r~s~ c~cr~s ~ LOUNSBURY ii ~ i i i ii i i ii ANCO Al~eka, In~. dk ~'~ ~ '-a ~ ~ST ~ ~A~ I B - ~ C0N~C~S " "~ ~'~ ~' I o,/~/~ I~"°"~ ~': i~ ~e~.,6 _ CEA-D1DX-61~16 , ~ ~ 2 e-Kun: KUPURRK TOOL HOUSE' NOTE5 COOROJNA i'E$ SHOV~ AR~ A~P. ZONE ¢, N,A.D. 2X LEVEL. A~ ~~ ~0~ ARE MONU~NT~ PER ~D AND 7/8/9~ FIELD aK. L~-50, / I c~c~$ ~-&. ~-o~ox-6~o~o ~-o~ox-~o~3 F~ c~cr~s ~ ~ ~ ~ I I No. Y ,~ Cat. Long. F'.E..L. F'.E.L, Pod ;oa ~,s,.~a.x~ ~6o.4~o.~z ~'0' re" oz.o.~* ~o" ~' ~.~,,~'~'x.e' ..~e~' ~' 111 5,959,69.,[~5 5~0,4g0.60 I 70' la" ~.~" r4g' ~" ~287' ..; ~ ~' ~.8' Sec. 23, ~11 N,, R. IO E, F.N.L?F[L. P~ 0.~ l~Z ~ 5, B~9,~~ ~0,4~05 ~' tS" O~.IEO' ~49' ~' ~2~' I6' ~E' 7~E' 114 I f95S, 619.07 56~49~62 ~j ~' ~g* ~.867' Mg' ~0" ~04' ~ ~ ~' ~' 122 &959, 469.06 ~4~.~ ~' ~ 59J92' ~49' ~' ~.~ I~' ~' 12J 5,959,45181 ~4~69 ~' I~ ~.2~Z' ~49' ~' ~t' 2tf' 5~* ~6' i, P .e3 SUR~. .YOR°S., CERTIFICATE I HEREBY CEI~TIFY thai' L ICENSEO TO PRACTIC~ L~ ~A$~ ~ T~T THiS AS ~ J~ Y 2~, 1998. ARCO Alaska, Inc. FILE NO. DRAWING NO: LKE 10a,16 1D-116 Cement Volumes Surface Hole Casing Depth Casing OD Casing Weight Hole ,Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' 'I-VD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess !feet feet feet Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time ~pPg ft3/sx gal/sx hours i% % % % % Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours 499 633 bbls sacks / bbls sacks Z0" DIVERTER SCHEMATIC Kuparuk River Unit West Sak Operations 5 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. 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 2. 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. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 19, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-116 West Sak Phase lB 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 1 D pad. The well is designated as a monobore production well using a single 7 5/8" casing string, with 3-1/2" tubing. 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 and West Sak 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-116, such as shallow gas. There have been ten (10) Kuparuk wells and (20) 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. RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AUG 21 1998 Alaska 0il & Gas Cons. Commission 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. Please note that the anticipated spud date for this well is September 9, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, '" , ~,.~" ~ Scott Goldberg Operations Drilling Engineer CC; West Sak 1D-116 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-116 (El) Drilling Fluid Type 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 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 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 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-116 (El) 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. 1D-116 (El) Page I SG,08/19/98,v.1 Based on actual well test data from the nearby WS1-01 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 9.7' ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,$47' MD/TVD. 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 to surface, the following MASP can be computed: MASP = (3981 ft)(0.46- 0.11 psi/ft) = 1393 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 casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 7 5/8" 29.7# L80 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-116 (El) 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. Well Proximity Risks: The nearest existing well to West Sak 1D-116 (El) is WS 1D-117. As designed, the minimum distance between the two wells would be 12.9' at 380' 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 a permitted existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-116 (El) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1D-116 (El) Page 2 SG,08/20/98,v.1 Drill, Case and Completion Plan for West Sak 1D-116 (El) Frac Pack Producer General Procedure: 1. 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. 3. 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. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 7 5/8" casing ___1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port o~1~ ~-'~i~r;.~vt?a ,~-- ~,_j¢c Collar~,a top job may be performed in lieu of utilizing the port collar. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Rig up and run workstring to TD. Circulate the well with seawater and freeze protect the upper_+2000' with diesel 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig 1D-116 (El) Page I SG, 08/19/98, v.1 Completion Plan for West Sak 1D-116 (El) Four-Staqe, Sinqle-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. Drop bar 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 1D-116 (El) Page 2 SG, 08/19/98, v.1 Stage 1 10. 11. 12. 13. 14. Stage 2 15. 16. 17. 18. 19. Stage 3 20. 21. 22. 23. 24. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 1. Using 16-20 mesh carbolite proppant, proceed to frac Stage I with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 1. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 2. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 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. 1D-116 (El) Page 3 SG, 08/19/98, v.1 Stage 4 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. 36. 37. 38. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 4. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 4. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 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. Circulate well to clean brine. TOH with workstring. Change rams to 3 1/2" and pressure test same unless VBR's are available. Pick up Centrilift ESP on 3 1/2" production tubing. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 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. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required, and set back pressure valve in tubing hanger. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. Release rig and turn well over to production. 1D-116 (El) Page 4 SG, 08/19/98, v.1 3-1/2" Production Tubing 9.3# L-80 EUE 8RDoMod Power Cable for ESP Centrilift w-est Sak Well 1D-116 Four (4) Stage Frac-Pack 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) 2178' MD/1641' TVD TAM International 7 5/8" Port Collar Set at approximately 1000' TVD Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Fmc-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker Oil Tools A3 Sand Fmc-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Set at 6366' MD/4173' TVD A2 Sand Frac-Pack Assembly with Screen Baker Oil Tools ARCO Alaska, Inc. SG, 08/19/98 :c,~ot,a ~y ~.=. For; GOLDBERG Oa~ ploRed : 17-Ju1-98 plol Reference ;s WS 1D-116/E1 Vern. ~. aska, !nc. Structure : Pod 10 Well: 116 I Field : Kuparuk River Unit Location : North Slope, Alasl<oI I V <- West (feet) 4200 3900 5600 3300 3000 2700 2400 2100 '1800 1500 '1200 gOO 600 300 0 I I f I ! f I I ~ t I I ~ I T i 1 t I I I I f I I I I i i TO LOCATION: 1 · pt ondS ~, ~ Co.s),ng_t Sak S_ ,. ~3 1107' FSL, 763' FWL / SEC. 14, TllN, RiOE Ir~z~' ~ -~lXl~u~. -,- "~'Sa~ $o~a$ ,I TARGET LOCATION: ~ \~ NN¢~:~ Oro~_ as I 1066' FSL, 899' FWL 1;----'""--._ I~, ~d An§~nu sonu J SEC. 14 T11N, RIOE 6 ..... , ................ ~ ~ ~ . ~nnl~ urov TARGET ~ ~"--~ ~egm ~' ~ TV0=3694 ' . ~ TMD=5867 ~ 0EP=3952 ~ NORTH 1 !42 WEST 3784 0 RKB ELEVATION: 112' permafrost ZOO KOP TVD=400 TMB=400 DEP=0 s.oo 286.8 AZIMUTH 6C0 90O 1200 1 1500 4 1800 -I 2100 2400 270O 3CO0 3300 3600 3gCC 4200 4500 10.00 15.00 20.00 DLS: 5.00 dee per 100 ft !5.00 30.00 35.00 40.00 45.00 50.00 }'OOEoc TVD=1438 TMD=1699 DEP=661 3952' (TO TARGET) B/ PERMAFROST 1-VD=1641 TMD=2178 DEP=1095 MAXIMUM ANGLE 64.96 DEC SURFACE LOCATION: 76' FNL. 597' FEL SEC. 23, 'T11N, RIOE BEGIN ANGLE DROP TV0:2643 TM0=4544 0EP=3238 60.00 50.00 ¢5.00 T/ UGNU SNDS 1-VD=2§55 TMD=5055 DER=5639 40.00 DLS: 5.00 deg per 100 ft 35.00 50.00 ,25.00 20.00 ENO ANGLE DROP TV0=3355 TM0=5513 0EP=3852 T/ W SAK SNDS TV0=3547 TM0:5713 0EP=3909 TARGET - A3 TVD=3694 TMD=5867 DEP=3 TARGET ANGLE 16.5 DEC 8/ W SAK SNOT TV0=3981 TM0=6166 DEP=4037 TD - CSG PT TVD:41?3 TMD=6366 DEP=4094 0 3C0 600 i i t i i i i i i i i i i i i i i i i I 900 1200 1500 1800 21 O0 2400 2700 3000 3500 5600 Vertical Section (feet) -> Azimuth 286.80 with reference 0.00 N, 0.00 E from slot #116 i i t i I 3900 4200 4500 300 ; !500 ~ 1200 ~00 h soo - 300 P C L 3O0 A I Z ARCO Alaska, Inc. Pad 1D 116 slot #116 Kuparuk River Unit North Slope, Alaska PROPOSAL L I ~ T I NG INCLUDING POSITION UNC.~.TAINTIES by Baker Hughes INTEQ Your ref : WS 1D-116/E1 Vets. #4 Our ref : prop2210 License : Date printed : 16-Jul-98 Date created : 17-Apr-97 Last revised : 16-Jul-98 Field is centred on nT0 16 18.§76,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 0.568,w149 30 36.313 Slot Grid coordinates are N 5959588.687, E 560490.578 Slot local coordinates are 76.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED AUG 21 1998 Alaska Oil & Gas Cons, Commission Anchorage 2%RCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 286.80 0.00 0.00 N 0.00 E 400.00 0.00 286.80 400.00 0.00 N 0.00 E 500.00 5.00 286.80 499.87 1.26 N 4.17 W 600.00 10.00 286.80 598.99 5.03 N 16.67 W 700.00 15.00 286.80 696.58 11.28 N 37.38 W 800.00 20.00 286.80 791.93 19.97 N 66.16 W 900.00 25.00 286.80 884.28 31.03 N 102.78 W 1000.00 30.00 286.80 972.96 44.37 N 146.97 W 1100.00 35.00 286.80 1057.27 59.89 N 198.39 W 1200.00 40.00 286.80 1136.58 77.48 N 256.65 W 1300.00 45.00 286.80 1210.28 96.99 N 321.31 W 1400.00 50.00 286.80 1277.82 118.29 N 391.87 W 1500.00 55.00 286.80 1338.68 141.21 N 467.80 W 1600.00 60.00 286.80 1392.39 165.58 N 548.51 W 1699.12 64.96 286.80 1438.18 190.98 N 632.64 W 1699.13 64.96 286.80 1438.18 190.98 N 632.65 W 2000.00 64.96 286.80 1565.54 269.75 N 893.60 W 2178.25 64.96 286.80 1641.00 316.42 N 1048.20 W 2500.00 64,96 286.80 1777.~0 400,66 N 1327.26 W 3000.00 64.96 286.80 1982.85 531.58 N 1760.93 W 3500.00 64.96 286.80 2200.50 662.49 N 2194.59 W 4000.00 64.96 286.80 2412.15 793.40 N 2628.26 W 4500.00 64.96 286.80 2623.81 924.31 N 3061.92 W 4544.18 64.96 286.80 2642.51 935.88 N 3100.24 W 4643.31 60.00 286.80 2688.30 961.28 N 3184.38 W 4743.31 55.00 286.80 2742.01 985.64 N 3265.10 W 4843.31 50.00 286.80 2802.87 1008.56 N 3341.02 W 4943.31 45.00 286.80 2870.41 1029.86 N 3411.58 W 5043.31 40.00 286.80 2944.11 1049.38 N 3476.24 W 5054.87 39.42 286.80 2953.00 1051.51 N 3483.30 W 5143.31 35.00 286.80 3023.42 1066.97 N 3534.50 W 5243.31 30.00 286.80 3107.74 1082.49 N 3585.92 W 5343.31 25.00 286.80 3196.41 1095.83 N 3630.11 W 5443.31 20.00 286.80 3288.77 1106.88 N 3666.73 W 5513.31 16.50 286.80 3355.24 1113.22 N 3687.72 W PROPOSAL LISTING Page 1 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 5.00 4.36 5.00 17.41 5.00 39.05 5.00 69.11 5.00 107.36 5.00 153.52 5.00 207.24 5.00 268.09 5.00 335.63 5.00 409.34 5.00 488.65 5.00 572.96 5.00 660.83 EOC 5.00 .660.84 0.00 933.43 0.00 1094.92 Base Permafrost 0.00 1386.42 0.00 1839.41 0.00 2292~41 0.00 2745.40 0.00 3198.39 0.00 3238.42 Begin Angle Drop 5.00 3326.31 5.00 3410.62 5.00 3489.93 5.00 3563.64 5.00 3631.17 5.00 3638.55 Top Ugnu Sands 5.00 3692.03 5.00 3745.74 5.00 3791.90 5.00 3830.16 5.00 3852.08 End Angle Drop 5713.31 16.50 286.80 3547.00 1129.63 N 3742.10 W 0.00 5866.62 16.50 286.80 3693.99 1142.22 N 3783.78 W 0.00 5866.63 16.50 286.80 3694.00 1142.22 N 3783.78 W 0.00 6000.00 16.50 286.80 3821.88 1153.16 N 3820.04 W 0.00 6165.95 16.50 286.80 3981.00 1166.79 N 3865.17 W 0.00 6365.95 16.50 286.80 4172.76 1183.20 N 3919.55 W 3908.88 Top West Sak Sands 3952.42 TARGET - West Sak A3 3952.42 WS 1D-E1 Rvsd 26-Jan-98 3990.30 4037.44 Base West Sak Sands 0.00 4094.24 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #116 and TVD from RF~B (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees from wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ A~RCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Comments in wellpath ========== MD TVD Rectangular Coords. Comment 400.00 400.00 0.00 N 0.00 E KOP 1699.12 1438.18 2178.25 1641.00 4544.18 2642.51 5054.87 2953.00 5513.31 3355.24 5713.31 3547.00 5866.62 3693.99 5866.63 3694.00 6165.95 3981.00 6365.95 4172.76 190.98 N 316.42 N 935 88 N 1051 51 N 1113 22 N 1129 63 N 1142 22 N 1142 22 N 1166 79 N 1183 20 N 632.64 W EOC 1048.20 W Base Permafrost 3100.24 W Begin Angle Drop 3483.30 W Top Ugnu Sands 3687.72 W End Angle Drop 3742.10 W Top West Sak Sands 3783.78 W TARGET - West Sak A3 3783.78 W WS 1D-E1 Rvsd 26-Jan-98 3865.17 W Base West Sak Sands 3919.55 W TD - Casing Pt Casing positions in string 'A' ==============2 Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 286.80 0.00 76.00 S 597.00 W 400.00 0.00 286.80 400.00 76.00 S 597.00 W 500.00 5.00 286.80 499.87 74.74 S 601.17 W 600.00 10.00 286.80 598.99 70.97 S 613.67 W 700.00 15.00 286.80 696.58 64.72 S 634.38 W 800.00 20.00 286.80 791.93 56.03 S 663.16 W 900.00 25.00 286.80 884.28 44.97 S 699.78 W 1000.00 30.00 286.80 972.96 31.63 S 743.97 W 1100.00 35.00 286.80 1057.27 16.11 S 795.39 W 1200.00 40.00 286.80 1136.58 1.48 N 853.65 W 1300.00 45.00 286.80 1210.28 20.99 N 918.31 W 1400.00 50.00 286.80 1277.82 42.29 N 988.87 W 1500.00 55.00 286.80 1338.68 65.21 N 1064.80 W 1600.00 60.00 286.80 1392.39 89.58 N 1145.51 W 1699.12 64.96 286.80 1438.18 114.98 N 1229.64 W 1699.13 64.96 286.80 1438.18 114.98 N 1229.65 W 2000.00 64.96 286.80 1565.54 193.75 N 1490.60 W 2178.25 64.96 286.80 1641.00 240.42 N 1645.20 W 2500.00 64.96 286.80 1777.20 324.66 N 1'924.26 W 3000.00 64.96 286.80 1988.85 455.58 N 2357.93 W 3500.00 64.96 286.80 2200.50 586.49 N 2791.59 W 4000.00 64.96 286.80 2412.15 717.40 N 3225.26 W 4500.00 64.96 286.80 2623.81 848.31 N 3658.92 W 4544.18 64.96 286.80 2642.51 859.88 N 3697.24 W 4643.31 60.00 286.80 2688.30 885.28 N 3781.38 W 4743.31 55.00 286.80 2742.01 909.64 N 3862.10 W 4843.31 50.00 286.80 2802.87 932.56 N 3938.02 W 4943.31 45.00 286.80 2870.41 953.86 ~ 4008.58 W 5043.31 40.00 286.80 2944.11 973.38 N 4073.24 W 5054.87 39.42 286.80 2953.00 975.51 N 4080.30 W 5143.31 35.00 286.80 3023.42 990.97 N 4131.50 W 5243.31 30.00 286.80 3107.74 1006.49 N 4182.92 W 5343.31 25.00 286.80 3196.41 1019.83 N 4227.11 W 5443.31 20.00 286.80 3288.77 1030.88 N 4263.73 W 5513.31 16.50 286.80 3355.24 1037.22 N 4284.72 W PROPOSAL LISTING Page 1 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 5.00 4.36 5.00 17.41 5.00 39.05 5.00 69.11 5.00 107.36 5.00 153.52 5.00 207.24 5.00 268.09 5.00 335.63 5.00 409.34 5.00 488.65 5.00 572.96 5.00 660.83 EOC 5.00 .660.84 0.00 933.43 0.00 1094.92 Base Permafrost 0.00 1386.42 0.00 1839.41 0.00 2292.41 0.00 2745.40 0.00 3198.39 0.00 3238.42 Begin Angle Drop 5.00 3326.31 5.00 3410.62 5.00 3489.93 5.00 3563.64 5.00 3631.17 5.00 3638.55 Top Ugnu Sands 5.00 3692.03 5.00 3745.74 5.00 3791.90 5.00 3830.16 5.00 3852.08 End Angle Drop 5713.31 16.50 286.80 3547.00 1053.63 N 4339.10 W 0.00 5866.62 16.50 286.80 3693.99 1066.22 N 4380.78 W 0.00 5866.63 16.50 286,80 3694.00 1066.22 N 4380.78 W 0.00 6000.00 16.50 286.80 3821.88 1077.16 N 4417.04 W 0.00 6165.95 16.50 286.80 3981.00 1090.79 N 4462.17 W 0.00 6365.95 16.50 286.80 4172.76 1107.20 N 4516.55 W 3908.88 Top West Sak Sands 3952.42 TARGET - West Sak A3 3952.42 WS 1D-E1 Rvsd 26-Jan-98 3990.30 4037.44 Base West Sak Sands 0.00 4094.24 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees from wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 400 1699 2178 4544 5054 5513 5713 5866 5866 6165 6365 00 400 12 1438 25 1641 18 2642 87 2953 31 3355 31 3547 62 3693 63 3694 95 3981 95 4172 .00 76.00 S .18 114.98 N .00 240.42 N .51 859.88 N 00 975.51 N 24 1037.22 N 00 1053.63 N 99 1066.22 N 00 1066.22 N 00 1090.79 N 76 1107.20 N 597.00 W 1229.64 W 1645.20 W 3697.24 W 4080 30 W 4284 72 W 4339 10 W 4380 78 W 4380 78 W 4462 17 W 4516 55 W KOP EOC Base Permafrost Begin Angle Drop Top Ugnu Sands End Angle Drop Top West Sak Sands TARGET - West Sak 43 WS 1D-E1 Rvsd 26-Jan-98 Base West Sak Sands TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 76.00S 597.00W 6365.95 4172.76 1107.20N 4516.54W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1066.22N 4380.78W 9-Oct-96 ARCO Alaska, I~c. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 286.80 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 400.00 0.00 286.80 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 5.00 286.80 499.87 1.26 N 4.17 W 4.36 1.34 1.31 0.75 286.80 600.00 10.00 286.80 598.99 5.03 N 16.67 W 17.41 1.84 1.59 0.90 286.80 700.00 15.00 286.80 696.58 11.28 N 37.38 W 39.05 2.72 1.90 1.06 286.80 800.00 20.00 286.80 791.93 19.97 N 66.16 W 69.11 4.10 2.26 1.24 286.80 900.00 25.00 286.80 884.28 31.03 N 102.78 W 107.36 6.07 2.66 1.45 286.80 1000.00 30.00 286.80 972.96 44.37 N 146.97 W 153.52 8.67 3.11 1.71 286.80 1100.00 35.00 286.80 1057.27 59.89 N 198.39 W 207.24 11.95 3.60 2.04 286.80 1200.00 40.00 286.80 1136.58 77.48 N 256.65 W 268.09 15.96 4.12 2.45 286.80 1300.00 45.00 286.80 1210.28 96.99 N 321.31 W 335.63 20.71 4.65 2.95 286.80 1400.00 50.00 286.80 1277.82 118.29 N 391.87 W 409.34 26.19 5.18 3.54 286.80 1500.00 55.00 286.80 1338.68 141.21 N 467.80 W 488.65 32.39 5.70 4.23 286.80 1600.00 60.00 286.80 1392.39 165.58 N 548.51 W 572.96 39.26 6.19 5.01 286.80 1699.12 64.96 286.80 1438.18 190.98 N 632.64 W 660.83 46.66 6.63 5.87 286.80 1699.13 64.96 286.80 1438.18 190.98 N 632.65 W 660.84 .46.66 6.63 5.87 286.80 2000.00 64.96 286.80 1565.54 269.75 N 893.60 W 933.43 69.24 7.96 8.51 286.80 2178.25 64.96 286.80 1641.00 316.42 N 1048.20 W 1094.92 82.67 8.75 10.09 286.80 2500.00 64.96 286.80 1777.20 400.66 N 1327.26 W 1386.42 !06.91 10.17 12.95 286.80 3000.00 64.96 286.80 1988.85 531.58 N 1760.93 W 1839.41 144.64 12.37 17.40 286.80 3500.00 64.96 286.80 2200.50 662.49 N 2194.59 W 2292.41 182.39 14.57 21.86 286.80 4000.00 64.96 286.80 2412.15 793.40 N 2628.26 W 2745.40 220.14 16.77 26.32 286.80 4500.00 64.96 286.80 2623.81 924.31 N 3061.92 W 3198.39 257.91 18.96 30.78 286.80 4544.18 64.96 286.80 2642.51 935.88 N 3100.24 W 3238.42 261.25 19.16 31.18 286.80 4643.31 60.00 286.80 2688.30 961.28 N 3184.38 W 3326.31 268.15 19.64 31.99 286.80 4743.31 55.00 286.80 2742.01 985.64 N 3265.10 W 3410.62 274.44 20.16 32.73 286.80 4843.31 50.00 286.80 2802.87 1008.56 N 3341.02 W 3489.93 280.03 20.70 33.39 286.80 4943.31 45.00 286.80 2870.41 1029.86 N 3411.58 W 3563.64 284.87 21.26 33.95 286.80 5043.3i 40.00 286.80 2944.11 1049.38 N 3476.24 W 3631.17 288.97 21.81 34.43 286.80 5054.87 39.42 286.80 2953.00 1051.51 N 3483.30 W 3638.55 289.36 21.88 34.48 286.80 5143.31 35.00 286.80 3023.42 1066.97 N 3534.50 W 3692.03 292.33 22.35 34.83 286.80 5243.31 30.00 286.80 3107.74 1082.49 N 3585.92 W 3745.74 294.98 22.87 35.14 286.80 5343.31 25.00 286.80 3196.41 1095.83 N 3630.11 W 3791.90 296.99 23.34 35.38 286.80 5443.31 20.00 286.80 3288.77 1106.88 N 3666.73 W 3830.16 298.41 23.76 35.56 286.80 5513.31 16.50 286.80 3355.24 1113.22 N 3687.72 W 3852.08 299.15 24.02 35.66 286.80 5713.31 16.50 286.80 3547.00 1129.63 N 3742.10 W 3908.88 301.28 24.79 35.95 286.80 5866.62 16.50 286.80 3693.99 1142.22 N 3783.78 W 3952.42 302.90 25.38 36.17 286.80 5866.63 16.50 286.80 3694.00 1142.22 N 3783.78 W 3952.42 302.90 25.38 36.17 286.80 6000.00 16.50 286.80 3821.88 1153.16 N 3820.04 W 3990.30 304.32 25.89 36.37 286.80 6165.95 16.50 286.80 3981.00 1166.79 N 3865.17 W 4037.44 306.10 26.53 36.61 286.80 6365.95 16.50 286.80 4172.76 1183.20 N 3919.55 W 4094.24 308.23 27.29 36.90 286.80 All data is in feet unless otherwise stated. Coordinates from slot #116 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees from wellhead. Vertical section is from wellhead on azimuth 286.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-116/E1 Vets. #4 Last revised = 16-Jul-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6366 ARCO (H.A. Mag) User specified 308.23 27.29 36.90 1 Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Cocrds. Comment 400.00 400.00 0.00 N 0.00 E KOP 1699.12 1438.18 190.98 N 632.64 W EOC 1178.25 1641.00 316.42 N 1048.20 W Base Permafrost 4544.18 2642.51 935.88 N 3100.24 W Begin Angle Drop 5054.87 2953.00 1051.51 N 3483.30 W Top Ugnu Sands 5513.31 3355.24 1113.22 N 3687.72 W End Angle Drop 5713.31 3547.00 1129.63 N 3742.10 W Top West Sak Sands 5866.62 3693.99 1142.22 N 3783.78 W TARGET - West Sak A3 5866.63 3694.00 1142.22 N 3783.78 W WS 1D-E1 Rvsd 26-Jan-98 6165.95 3981.00 1166.79 N 3865.17 W Base West Sak Sands 6365.95 4172.76 1183.20 N 3919.55 W TD - Casing Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-116/E1 Vets. #4 Last revised : 16-Jul-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 286.80 0.00 400.00 0.00 286.80 400.00 500.00 5.00 286.80 499.87 600.00 10.00 286.80 598.99 700.00 15.00 286.80 696.58 0.00N 0.00N 1.26N 5.03N 11.28N 0.00E 0.00 0.00 560490.58 5959588.69 0.00E 0.00 0.00 560490.58 5959588.69 4.17W 5.00 4.36 560486.39 5959589.91 16.67W 5.00 17.41 560473.87 5959593.58 37.38W 5.00 39.05 560453.11 5959599.67 800.00 20.00 286.80 791.93 900.00 25.00 286.80 884.28 1000.00 30.00 286.80 972.96 1100.00 35.00 286.80 1057.27 1200.00 40.00 286.80 1136.58 19.97N 31.03N 44.37N 59.89N 77.48N 66.16W 5.00 69.11 560424.27 5959608.12 102.78W 5.00 107.36 560387.56 5959618.87 146.97W 5.00 153.52 560343.26 5959631.85 198.39W 5.00 207.24 560291.72 5959646.96 256.65W 5.00 268.09 560233.33 5959664.07 1300.00 45.00 286.80 1210.28 1400.00 50.00 286.80 1277.82 1500.00 55.00 286.80 1338.68 1600.00 60.00 286.80 1392.39 1699.12 64.96 286.80 1438.18 96.99N 118.29N 141.21N 165.58N 190.98N 321.31W 5.00 335.63 560168.52 5959683.06 391.87W 5.00 409.34 560097.80 5959703.78 467.80W 5.00 488.65 560021.69 5959726.08 548.51W 5.00 572.96 559940.79 5959749.79 632.64W 5.00 660.83 559856.47 5959774.50 1699.13 64.96 286.80 1438.18 2000.00 64.96 286.80 1565.54 2178.25 64.96 286.80 1641.00 2500.00 64.96 286.80 1777.20 3000.00 34.96 286.80 1988.85 190.98N 632.65W 5.00 66.0.84 559856.46 5959774.50 269.75N 893.60W 0.00 933.43 559594.90 5959851.14 316.42N 1048.20W 0.00 1094.92 559439.94 5959896.55 400.66N 1327.26W 0.00 1386.42 559160.23 5959978.51 531.58N 1760.93W 0.00 1839.41 558725.55 ~960105.88 3500.00 64.96 286.80 2200.50 4000.00 64.96 286.80 2412.15 4500.00 64.96 286.80 2623.81 4544.18 64.96 286.80 2642.51 4643.31 60.00 286.80 2688.30 662.49N 2194.59W 0.00 2292.41 558290.88 5960233.25 793.40N 2628.26W 0.00 2745.40 557856.21 5960360.62 924.31N 3061.92W 0.00 3198.39 557421.53 5960487.99 935.88N 3100.24W 0.00 3238.42 557383.13 5960499.24 961.28N 3184.38W 5.00 3326.31 557298.79 5960523.95 4743.31 55.00 286.80 2742.01 985.64N 3265.10W 5.00 3410.62 557217.89 5960547.66 4843.31 50.00 286.80 2802.87 1008.56N 3341.02W 5.00 3489.93 557141.79 5960569.96 4943.31 45.00 286.80 2870.41 1029.86N 3411.58W 5.00 3563.64 557071.06 5960590.68 5043.31 40.00 286.80 2944.11 1049.38N 3476.24W 5.00 3631.17 557006.26 5960609.67 5054.87 39.42 286.80 2953.00 1051.51N 3483.30W 5.00 3638.55 556999.18 5960611.75 5143.31 35.00 286.80 3023.42 1066.97N 3534.50W 5.00 3692.03 556947.86 5960626.78 5243.31 30.00 286.80 3107.74 1082.49N 3585.92W 5.00 3745.74 556896.32 5960641.89 5343.31 25.00 286.80 3196.41 1095.83N 3630.11W 5.00 3791.90 556852.03 5960654.87 5443.31 20.00 286.80 3288.77 1106.88N 3666.73W 5.00 3830.16 556815.32 5960665.62 5513.31 16.50 286.80 3355.24 1113.22N 3687.72W 5.00 3852.08 556794.29 5960671.79 5713.31 16.50 286.80 3547.00 1129.63N 3742.10W 0.00 3908.88 556739.78 5960687.76 5866.62 16.50 286.80 3693.99 1142.22N 3783.78W 0.00 3952.42 556698.00 5960700.00 5866.63 16.50 286.80 3694.00 1142.22N 3783.78W 0.00 3952.42 556698.00 5960700.00 6005.00 16.50 286.80 3821.88 1153.16N 3820.04W 0.00 3990.30 556661.65 5960710.65 616'~.95 16.50 286.80 3981.00 1166.79N 3865.17W 0.00 4037.44 5566]6.42 5960723.90 6365.95 16.50 286.80 4172.76 1183.20N 3919.55W 0.00 4094.24 556561.92 5960739.87 All data in feet unless otherwise stated. Calculation uses minim%un curvature method. Coordinates from slot #116 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 4094.24 on azimuth 286.80 degrees from wellhead. Total Dogleg for wellpath is 113.41 degrees. Vertical section is from wellhead on azimuth 286.80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Kughes INTEQ ARCO Alaska, Inc. Pad 1D,116 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-116/E1 Vers. #4 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 400.00 0.00N 0.00E KOP 1699.12 1438.18 190.98N 632.64W EOC 2178.25 1641.00 316.42N 1048.20W Base Permafrost 4544.18 2642.51 935.88N 3100.24W Begin Angle Drop 5054.87 2953.00 1051.51N 3483.30W Top Ugnu Sands 5513.31 3355.24 1113.22N 3687.72W End Angle Drop 5713.31 3547.00 1129.63N 3742.10W Top West Sak Sands 5866.62 3693.99 1142.22N 3783.78W TA~RGET - West Sak A3 5866.63 3694.00 1142.22N 3783.78W WS 1D-E1 Rvsd 26-Jan-98 6165.95 3981.00 1166.79N 3865.17W Base West Sak Sands 6365.95 4172.76 1183.20N 3919.55W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6365.95 4172.76 1183.20N 3919.54W 7 5/8" Casing Targets associated with ~his wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-E1 Rvsd 26-Jan 556698.000,5960700.000,0.0000 3694.00 1142.22N 3783.78W 9-0ct-96 lCreoted by finch For: GOI.I)I]EI{G Dote plotted: I?-dul-9~ [ Plot Reference is WS 1D-116/E1 Vers. Coordlnatcs arc in /cot reference slot ~116. J ARCO A]laska, l~ne. Structure : Pad 1F, Well: 116 Field : Kuporuk River Unit Location : North Slope, Alaska A I 800 320 28O 240 200 160 120 40 40 80 120 160 200 800 760 720 680 640 600 560 520 480 44,0 4-00 360 320 280 240 200 160 120 80 <-- West (feet) <- West (feet) 760 720 680 640 600 560 520 480 440 400 360 520 280 24(] 200 160 120 80 40 0 40 80 I I I I t I I I I I I I I I I I I t I t t I J I I I I I I I I I I I I I t I I ~ -- '-...;...... ...;;.... '?o, '"..~oo "\ ~o~, 600 ' -....:....... ',,, ~oo-.~."-.::-... ',,:',,. ';,,,~o~',,, ',, "-~, ', \ - 700 700-~ ~ . .... , oo '"':::',,, '",,, "', "', ......... ~ ' ',,,' .. ',,',,"~.~ooX,,",, ',, ........ ~ ", ". 900"',", 1100 800',, *", ',, , ............. ',,.....,. ........... ~.o.o ~, oo"-~ ~-.'.:-.3."°° ..,.,........, oo~OO ,,,.o,o ........ ~ ",, '-, 800',, %. 606", N":~ - ' 2,.oo' ~~~~'~-Z~'-..':.., ',,, '-..?o 'e~ - - ....... ~-- 'lUOO "~ ~. ",2-. 1201~, ' ..... ' " 1800 :uu , ', -- vuu 3100 ~ 00_ .... 30~ O0 ..................................... 1000 900 800 013 500 ......................... 5oor~ 4-00 ......... -,,~1600 500/,~1800 goo .................. 2000/- ! ? .o.p_ ................................. 120021~0~.¢~ .500 ............................... ,~o~~o~,~_..e T ....... 'T---'---1------1 T---- T'-' -'1-- ..... 40 0 40 80 320 28O 240 2OO 160 120 40 120 160 200 240 Z 0 1100 1 oo0 900 800 7O0 600 50O 400 300 Created b~ finch l"or: GOLDBERG] Dote plotted : I7-Jul-98 Plat Rc~crence is WS lO- 116/E I Vcrs. ~4. / Coord~natc~ arc in fcct reference =slot ~1 16. / ARCO Alaska, ][nc. Structure : Pod lO Well : 116 Field : Kuporuk Rfver Unif Locotion : North Slope, Alosl<o 2OO lO0 100 200 <- West (feel) 2800 2700 2600 2500 2400 2300 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 I I I I I I [ I I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I [ t I I I __ '...'... "~ l~pO '"'""'"' '" '" 9 O0 ~ '-..'-~j oo ',, ',_ ~;~ ..... ~ '",,',',',,.,15oo '",,~ · . ~ '"-:::,,, ',~ 800 goo I-..:...~ 6oo .............. 400 ...... .. 230O 4500 ----- .... "'- ........... ~ 1 700 4100 ~ ............. 3900 ~ ' .... ' ....... .... 3700 --~ ........ ~ ~ ....... 1500 3500 ~ ........ 3300~-~~_~39oo ~7oo ..... '"'~-"- 3100----~..._ ~._~_0 3300 2900 2700 ~000'-~ ~ 3300 3100 ............................... 2900 ............................ 2700 ............... 2500 ................... 2300 .................................. 2100 ............................... 1900 .............. 1700 2800 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1 O00 900 800 700 600 <- Wesf (feel) /k I z 300 ~ 20O 100 100 200 Dote plotted: 17.-Jul-98 I Plot Relerence is WS 1D-Ill/E1 Vets. 14. I Coordinotca ore in feet reference :slot #l'J6. I ARCO Al[aska, Inc. Structure : Pad 1D Well : 116 .... F i~!__O_ :__K_~ p~__k._Rj~_~_r.._ U_.~ i_t_ __<o c_?_! ~2_~__:__N_.o~L .h_s ~ o___p ~_, ~! o ~__k_._. 1 BO0 1600 1400 1200 1000 A 800 I ~'~ 6O0 400 o Z 2o0 200 4.00 6OO 800 <- West (feet) 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 ~ 400 1200 ~ 000 800 600 I I I I I I I I I II I I II I I I I I I I I I I II I I I I I I } I ~ I I ~ I I I ,,,., ,,,, "" '" 2100 ", ",, 2100 ",. \3500 2700'-,",, '"' '" 190;',. ",, ",, ", ", ", : 900 2500",, ",, 1900 1 700", ", "",, '....'... '.,, ',. ~ goo ',, "..'.'.'-.. ".Y,. ~ ~o6',, E~. ~oo ~ "-.'.".. '",".. ",, ......... 35oo LUS-L.33oo ~.£;.-~,'-, .7~ ", ', ', ~ .... 3100 ~-. 2900 z.~uu '.'x ~ uu ',,',, ' ~ ......... 99oo "<C~7oo "':::-. ~.~oo",,",, '-¢yo ........... ~.~oo "---.?o'%.. ,,.,:,,:~oo~ ',,...6soo .......... ~ ".'.:.. ',,',, '"',~oo .......... ~.~oo ~,,~.o 2~o~:::-.. ~oo ",::,,% ........ ..... '.'.. , oo ~,.voo . - .... ---...t¥o ~ voo'~-. ' 'r;.. rTG1 ........... ~ ~ 500 ...... 2900 5900 ....... 3,300 310 3500 2700 ..................... 2700 2500 .................... 2300 .............. _ .......................... ............. ~ ~ oo ~ goo / 1300 .--~- 1500 ................... ~ 1900 ........... 2500 .................. /2500 .. .... '" - 1 700.--" 2~oo ............ ~.-------~o .. "' .--~.--_ .-" 1300 '5~00 290"'(')--'~'~7'!)"0" ....... : ........... ~"'-"31(~0 2900 . . ...... ~../'-1300 I~_ 4 ~oo ...... 37oo_ ...... v: ................ ~ 3soo ~ goo ...... ..>-" .... -]---- I I I ---T--'"'--I ......... 'T '1 ....... I------T----'-I T'--'-'T'--'---"'I ......... l .... 1 T J- I '[-----'J------T- .... ] ...... I f I----- I I--'--'-J r"--- ii ---T'I 1 ...... r-----'l ........ -I ......... 1 ..... T I- .... T .... T--- 4800 4600 4400 4200 4000 5800 5600 5400 5200 3000 2800 260(] 2400 2200 2000 1800 1600 1400 1200 1000 800 600 <- West ('feel) 1800 1600 1400 1200 1000 800 A I Z 600 O .-4- ¢~00 ~, .--t-. 200 ~ 200 4O0 600 800 ARCO Alaska, Inc. S}ructure : Pad 10 Well: 116 Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA .....P¢int ..... ~O Ir~¢ O;r ~ Norlh East V. Sect Oeg/1 CO ~e an O.CO O.CO 286.80 0.00 0.00 O.O0 O.CO KCP 400.C~ O.CO 285.80 400.CO 0.0{3 0.00 0.CO O.CO I£na of Build 1699.15 64.96 286.801458.18190.98 --632.65660.84 End o! Ho~d ¢544.1§ 6~.96 285.80264,2.51 9.35.88 -3100.243258.4.2 £ncl of C~'op 5.'313.31 16.50 286.80.3355.24 111.3.22 -`3687.72 3852.d8 jTcrget W5 1C1-[1 Rvsd 2 5856.65 16.50 286.80`3664.00 1142.22 --3783.78 3952.4.2 O.COI iF'nd of Hc~d 616,5.9516.50 286.803g§l.CO1165,79 -3805.17¢O37.44 O.00 iT,0. & Emd of HO;d 6365.g5 16.50 286.804.172.76 118.3.20 --3919.55 ~394.24 0.00 320 35O 340 TRUE NORTH 510 10 o/ 20 ,~50 I I I 1300 c,¢ote~ b~ f,,c~, For: GOLDBERG[ 0otc ptctted : 17-J~-98 i P~t ,Reference ;s ~ 1D-1~6/[[ Vets. ~4. i C~rd]nat{s are ~n fe~[ r~er{~c~ s~t ~1~. ] True Venice[ Oe~ths crc refer~ce RK~ (F~rker ~245).~ 300 0~) 290 70 28O 270 26O 2 50O ~ 8O 0 1802 o --I c 0 i00 25O 1!0 240 ~20 230 220 ., 2~0~ 2OO 190 180 Normol Plone Trovelling Cylinder - Feet 900 1 goo % ~ 1.50 160 170 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 116 slot $116 Kuparuk River U~it North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref = WS 1D-116/E1 Vets. #4 Our ref : prop2210 License : Date printed : 17-Jul-98 Date created : 17-Apr-97 Last revised : 16-Jul-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 0.568,w149 30 36.313 Slot Grid coordinates are N 5959588.687, E 560490.578 Slot local coordinates are 76.00 S 597.00 W Projection tYl~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object we11path PMSS <0-4414'>,,121,Pad 1D PMSS <O-4530'>,,120,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <O-4590'>,,118,Pad 1D PMSS <O-5205'>,,117,Pad 1D PI~FS <0-4850'>,,109,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <0-5047'>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D POMS <0-9783'>,,2,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <O-5142'>,,115,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PMSS <O-5462'>,,129,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D PMSS <377 - ???'>,,134,Pad 1D Closest approach with 3-D Last revised Distance 2-Jun-98 103.3 2-Ju~-98 89.2 2-Jun-98 73.5 2-Jun- 98 30.0 2-Jun- 98 12.9 2-Jun- 98 135.0 2-Jun- 98 178.2 2-Jun-98 209.5 2-Jun-98 372.1 2-Jun-98 450.0 2-Jun-98 191.6 21-May-98 527.0 10-Dec-97 299.1 4-Aug-92 191.5 4-Aug-92 69.3 4-Aug-92 47.2 13-Nov-97 167.1 13-Novo97 287.0 6-Nov-97 407.0 29-Apr-98 59.3 2-Jun-98 15.0 2S-Apr-98 480.0 2-Jun-98 314.3 2-Jun-98 329.9 6-Jul-98 238.4 1-Jul-98 223.9 15-Jul-98 345.0 17-Jul-98 434.2 Minimum Distance method M.D. Diverging from M.D. 450.0 450.0 425.0 425.0 425.0 5620.0 100.0 100.0 380.0 380.0 100.0 100.0 725.0 725.0 300.0 300.0 340.0 340.0 120.0 120.0 475.0 475.0 40.0 40.0 875.0 875.0 575.0 575.0 625.0 6365.9 20.0 20.0 20.0 400.0 20.0 20.0 400.0 400.0 475.0 475.0 180.0 180.0 120.0 120.0 300.0 300.0 400.0 400.0 300.0 300.0 360.0 360.0 100.0 100.0 300.0 300.0 F ROH; KUPUR~K TOOL HOUSE FAX HO.: 659 768t 9?-2?-98 13:15 p REVJ r'J'~(~ J blYI AlaP I~ OE$~:RIPTi(~ l'J~Yl ~ATF' ] OY ILC~'4~P" ~ .... , ~~Tt~', ~'~ ~ 1121 ' ~ 116 I~ I : ~ 121 122 ' ' ' "" ] '" '" ,- '" , '~ ' ' I N ~~ND o t~s.,c c~ucr~s ~ LOUNSBURY .... ~, ~ , , , ~ ~ILL 9~ I-0 ARCO Alaska, Inc. ~r ~ST SAK ""A~ Ia - ~ CONOUC~RS A~BUlLT I. C~RD/NArES ~0~ aR~ ~P. Z~E ¢, N,A.D. 2X ~ - ( .S, 1B .... ~A LEAL. ALL ~$r~5 ~o~ ARE ~UE. ~ONU~N~; P~R ~D AND AS~A~S, ~ PiT ~ ORaL ~ I-0 ~O N~ IS ~T4 TED 00' Ol' ~' ~A-DPDX--~t~t5 F~ C~OUCT~ I25- t28 ~ t31.132, f34 Sec. 14, [11 N., R. IO ~. I I TIJ iii .... i i i No. Y ~ Lot. ~. ~.~L.'F.~.L, Pod 0.~, i i i i ~ 5~959. 7~ 560.49~5~ 70' 18' 02.045' I49' ~ 3~.2~" 74' 5~* ~.6' ~.4' 110 5.959.~0~86 5~.4~ 70' ~8' OLXSO' 149' ~* ~2E~~ 4~' ~' ~E* 64.5' Sec. 23, T, 11 N., R. IO E. F.N.L.F.~L. Po= O.~. ,i ;~3 j 5.959,6~.93 ~0,49~56~ 70' 18' O;.OIJ' 149' ~* ~.J02' ~' 59~ 7~8' 6~2' 1;4 I ~95~,519.07 58~490.62 . ~' 18' 00.867' 149' ~O' 3~04' ,22 5,95,.469.0s ~0.490.~ 70' ,,' 59.~92'i ,2J 5.959.,5~8, ~ 56~4~.69 70' ,~ 59.2,2' AS OF J~ Y 22, 1998. ..... ~ct ........ '~ ' " ~[A: 10 - ~ : Ol ~ oa~ a[ ~-o ARCO Alaska, Inc. ~r~ ~ ~.~ ~. - ~ c~oucTo, s AS-~ILT L0~~S I i '1 I CFA-DIDX-610~16 2 1D-116 Cement Volumes Surface Hole Surface Casing Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess feet inches Ibs/ft inches bbl/ft bbl/ft feet feet feet Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours % % % % % % Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours bbls sacks 70 bbls 330 sacks 3-5/8" 5000 psi BOP S' Kuparuk River Unit West Sak Operations - Producer Wells 4 3 2 ! I 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity 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 Test 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. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi 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. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 3" DIVERTER SCHEM .TIC Kuparuk River Unit West Sak Operations DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. 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 2. 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. DiverterLineWilIBe Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 · WELL PERMIT CHECKLIST COMPANY ~,,"-~_..~ WELL NAME .Z~ /,/~-'///'2~ PROGRAM' exp [] de~v/,~"redrll [] serv [] wellbore segll ann. disposal para reqll FIELD & POOL GEOL AREA ,~-~ UNIT# //'~ ON/OFF SHORE N ADMINISTRATION . 8. 9. 10. 11. 13. ENGINEERING GEOLOGY 1. Permit fee attached ....................... 2. Lease number appropriate ................... 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 .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. 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... 22. Adequate we,bore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE ,Y N N- N. / Permit can be issued w/o hydrogen sulfide measures ..... Y N ~. Data presented on potential overpressure zones ....... ~yY NN..~/~ Seismic analysis of shallow [las zones ............. Seabed condition survey (if off-shore) ............. Con, tact.nam, e/phone.for weekly progress reports ....... // Y N lexptora~ory onlyj With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste, .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEObO.,GY: ENGINEERING: UIC/Annular JDH .~,,¢..~.. COMMISSION' DWJ RNC CO £0~1~ M:chel~list rev 05/29/98 dlf:(,:'tlnsoffico\wordian\diana\ctleckli::;l Y N Y N Y N A.nnular disposal has not b~n rcqucstcd as part of thc Permit to Drill a ' .' ' River Unit Well No I D-I~ rz~r. ,,,-,t,. ,h .... , _ _ . ppl~cauon for Kuparuk .. , , · . PI ............ at an.,,' msposai ottlu~ds gcncrated from this drilling opcrauon wnicl~ arc pumped down thc surf'acc/production casing romulus ora pcrmi~c.d well on Drill Site 1D must comply u.'ith thc rcqulrcmcnts and limitations ' cxisting ..-Xpproval of this pcrmit to drill dc;cs not.... [.~.' --~.~. , .... ,,. of 20 AAC".:5.080. than 35.000 barrels throuizh tt~c ann.l.~,-~-,,~-_,~,)c ui. sp,osai o.r. cln,!,ng x,.astc In a ,'olume greater ...... vacc ora s~nglc xvcll or 1' x ear. or a pcnod longer than one Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillir- Services LIS Scan Ut.~ ,_ty Mon Oct 26 12:28:19 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/26 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEAI)ER KUPARUK RIVER UNIT (WEST SA/<) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM- 80369 P. SMITH D. LUTRICK 1ST STRING 1D-116 500292291500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 26-0CT-98 MWD RUN 2 AK-MM- 80369 S. BURKHARDT D. LUTRICK 23 lin 10E 76 597 .00 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9.875 6245.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH MIKE WERNER OF ARCO ALASKA, INC. ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA P~AY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. WELL 1D-116 REACHED A TOTAL DEPTH OF 6245'MD, 4090'TV/D. 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. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/26 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 SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 78.0 6201 5 RPM 78 0 6201 5 RPS 78 0 6201 5 RPX 78 0 6201 5 GR 86 0 6209 0 FET 120 5 6201 5 ROP 122 0 6245 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH ME'RGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BA~E 1 121.0 3703.0 2 3703.0 6245.0 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 Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max DEPT 78 6245 GR 10.9668 127.846 RPX 0.6435 2000 RPS 0.7181 2000 RPM 0.6762 2000 RPD 0.1889 2000 ROP 5.4524 652.572 FET 0.0843 9.8526 Mean Nsam 3161.5 12335 64.7032 12247 119.415 12248 135.789 12248 173.246 12248 261.462 12248 280.633 12247 0.367101 12163 First Reading 78 86 78 78 78 78 122 120.5 Last Reading 6245 6209 6201.5 6201.5 6201.5 6201.5 6245 6201.5 First Reading For Entire File .......... 78 Last Reading For Entire File ........... 6245 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF Fi~e Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RJIW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 78.0 78 0 78 0 78 0 86 0 120 5 122 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: STOP DEPTH 3659.0 3659.0 3659.0 3659.0 3666.5 3659.0 3702.5 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) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 08-SEP-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3703.0 121.0 3703.0 2.0 66.6 TOOL NUMBER P1062CRG6 P1062CRG6 9.880 9.9 SPUD 9.20 250.0 10.4 300 5.9 7.000 MUD AT MAX CIRCULATING ~ERMPERATURE: 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 5.362 8.000 6.000 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 1 API 4 1 RPX MWD 1 OHMM 4 1 RPS MWD 1 OHMM 4 1 RPM MWD 1 OHMM 4 1 RPD MWD 1 OHMM 4 1 ROP MWD 1 FT/H 4 1 FET MWD 1 HOLIR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 28.6 Name Min Max Mean DEPT 78 3702.5 1890.25 GR 10.9668 122.71 63.596 RPX 0.6435 2000 195.754 RPS 0.7181 2000 223.711 RPM 0.6762 2000 288.056 RPD 0.1889 2000 438.484 ROP 17.3499 650.586 283.873 FET 0.0887 1.0681 0.279253 First Nsam Reading 7250 78 7162 86 7163 78 7163 78 7163 78 7163 78 7162 122 7078 120.5 Last Reading 3702.5 3666.5 3659 3659 3659 3659 3702.5 3659 First Reading For Entire File .......... 78 Last Reading For Entire File ........... 3702.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/26 Maximum Physical Record..65535 File Type ................ LO Next.File Name ........... STSI,~n.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/26 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 RIINNI/MBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 3659.5 RPD 3659 5 RPM 3659 5 RPS 3659 5 RPX 3659 5 GR 3667 0 ROP 3703 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 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A/FD 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 6201.5 6201.5 6201.5 6201.5 6201.5 6209.0 6245.0 09-SEP-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 6245.0 3703.0 6245.0 15.5 65.2 TOOL NI/MBER P1062CRG6 P1062CRG6 9.880 9.9 LSND 9.50 298.0 ~ PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: 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 9.1 300 4.6 10.000 7.190 7.000 3.900 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 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 37.8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 3659.5 16 5489 2 3029 2 3501 2 3981 2 6569 5 4524 0 0843 First Max Mean Nsam Reading 6245 4952.25 5172 3659.5 127.846 66.2627 5085 3667 607.386 11.8797 5085 3659.5 188.658 11.9373 5085 3659.5 128.933 11.5184 5085 3659.5 113.185 12.0996 5085 3659.5 652.572 276.07 5085 3703 9.853 0.489379 5085 3659.5 Last Reading 6245 6209 6201.5 6201.5 6201.5 6201.5 6245 6201.5 First Reading For Entire File .......... 3659.5 Last Reading For Entire File ........... 6245 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0. _r Date of Generation ....... 98/10/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File