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HomeMy WebLinkAbout201-2251. 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: 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 10515'feet 7224'feet true vertical 6445' feet 10488' feet Effective Depth measured 7224'feet 7648', 8571'feet true vertical 6040' feet 6290', 6455' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8601' MD 6454' TVD Packers and SSSV (type, measured and true vertical depth) 7648' MD 8572' MD N/A 6290' TVD 6455'' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool- SUSPENDED 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: 26# FHL Rtvbl Packer Packer: ZXP Packer and TieBack SSSV: None Dusty Freeborn Dusty.Freeborn@conocophillips.com 907-659-7224Staff Well Integrity Engineer 7850-7860', Slotted Liner: 9182-10454' 6380-6384'', Slotted Liner: 6464-6447' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 150' ~~~ SUSPENDED ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-225 50-029-23056-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025520 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3N-19 Plugs Junk measured Length Production Liner 8728' 1916' Casing 6461' 3-1/2" 8756' 10488' 6446' 3619' 150'Conductor Surface Intermediate 16" 9-5/8" 120' 3649' 3621' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:52 am, Sep 26, 2025 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E=Dusty.Freeborn @conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:25:23-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn RBDMS JSB 100225 J.Lau 11/5/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 9, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 3N-19 (PTD 201-225) Dear Commissioner Chmielowski: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit Well 3N-19 (PTD 201- 225). The well was suspended during a failed RWO operation and is being evaluated for re-drill operations. The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E= Dusty.Freeborn@conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:26:23-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: CTMD 10,030.03N-19 1/31/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut & pulled fish 3N-19 5/19/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Nipple Reducer @ 7,757' RKB is comprimised (Is not locked in, moves up, and will not test)4/6/2018 famaj NOTE: WORKED TOOLS, POOH W/ PLUG BODY. NIPPLE REDUCER INTEGRITY SUSPECT.2/21/2018 pproven NOTE: SUSPECTING THAT NIPPLE REDUCER PULLED OUT OF PROFILE 2/21/2018 pproven NOTE: PULLED HEAVIER THAN EXPECTED WHILE POOH W/ 1.81" PLUG & HUNG UP IN PATCH @ 7423' RKB; 2/21/2018 pproven 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 30.0150.0150.062.50 H-40 WELDED SURFACE 9 5/8 8.84 29.7 3,649.1 3,620.7 40.00 L-80 BTC PRODUCTION 7 6.28 28.0 8,755.8 6,461.2 26.00 L-80 BTC-Mod LINER 3 1/2 2.99 8,571.6 10,488.0 6,446.0 9.30 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 1,926.0 Set Depth … 1,904.0 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 25.025.00.06 Hanger 11.000 FMC hanger 4.5" x 11" HYD 563 topop and bottom FMCGen 54.000 Top (ftKB) 7,420.1 Set Depth … 8,600.6 Set Depth … 6,454.1 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,426.16,164.3 52.04 GAS LIFT 5.968 3-1/2" X 1-1/2" MMG GLM w/ RP shear valve, RK Latch Camco MMG2.920 7,633.86,282.7 59.17 PBR 5.870 Baker 12' 80-40 PBR w/ 12' seals inside Baker 80-403.000 7,647.5 6,289.7 59.68 PACKER 5.968 7", 26# FHL Retrievable Packer Baker FHL 3.000 7,757.4 6,341.9 63.60 SLEEVE-O 4.520 Sliding Sleeve w/ Camco DS profile, 2.812" ID (CLOSED 11/17/2017) 2.81" x 1.81" Nipple reducer set 02/05/18 Baker CMU 1.810 7,934.06,408.3 72.76SLEEVE-O 4.520 Sliding Sleeve w/ Camco DS profile, 2.75" ID (CLOSED 11/17/2017) Baker CMU 2.750 8,572.86,454.691.49 LOCATOR5.000 LOCATOR SUB Baker 3.000 8,574.06,454.691.45 SEAL ASSY5.870 Baker 80-40 Seal Assembly Baker 80-403.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,378.0 6,134.5 51.50 CEMENT RETAINER Baker 3BB CICR, set at 7,378' tested to 2000 PSI, put 6 BBLS CMT on top, 6 BBLS CMT under Baker Hughes 3BB H4002 13BB9 0STD 6/10/20230.000 7,423.0 6,162.4 52.01 PATCH OWEN XSPAN PATCH OAL 22.4' 2/16/2018 2.259 7,426.0 6,164.2 52.04 LEAK LEAK FOUND AT ~7440 THE BOTTOM PUP OF GLM #5 (7426 RKB) 10/9/2017 2.992 7,612.06,271.4 58.35 CUT 2" RCT TBG CUT AT 7612' RKB 4/29/2023 2.992 7,614.06,272.5 58.43CUT 2" RCT (EXTENDED) TBG CUT AT 7614' RKB 5/17/2023 2.992 7,662.06,297.060.23 SAND Dump bailed 10' of Safe Carb on top of HEX plug 4/26/2023 0.000 7,671.86,301.860.58 TUBING PLUG INTERWELL 1.81" HEX PLUG, MOE = 7675', OAL = 5.86' INTERW ELL HEX 3/31/2023 0.000 7,757.4 6,341.963.59 NIPPLE REDUCER 2.81" X 1.81" "D-PROFILE" SET IN THE SLIDING SLEEVE PROFILE 2/5/2018 1.810 8,615.06,454.090.23 VALVE KNOCKOUT ISOLATION VALVE (KOIV) MILLED OUT 4/26/2002 Baker 1/3/2002 10,488.0 6,446.0 91.66 FISH FISH LOST DURING DRILLING & COMPLETION 1/10/2002 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,571.66,454.7 91.52 PACKER 5.750 ZXP Packer & Tie Back Sleeve Baker 5.250 8,594.7 6,454.290.84 PBR 5.000 80-40 Polished Bore Receptacle Baker 80-40 4.000 8,606.9 6,454.0 90.47 XO 5x3.5" 5.000 XO - 5" L-80 Stub ACME x 3-1/2" L-80 EUE 8rd 2.992 8,617.4 6,454.090.16 XO 4.5x3"4.500XO- 4-1/2" SLHT box x 3-1/2" EUE 8rd Pin 2.992 10,453.66,447.091.66 BUSHING3.500 Pack-off bushing 2.992 3N-19, 9/3/2025 12:08:36 PM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 SHOE; 10,454.8-10,488.0 BUSHING; 10,453.6-10,454.8 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 FLOAT SHOE; 8,754.3-8,755.8 FLOAT COLLAR; 8,669.4- 8,670.7 VALVE; 8,615.0 PBR; 8,594.7-8,606.9 HANGER; 8,585.4-8,594.7 SEAL ASSY; 8,574.0 PACKER; 8,571.6-8,585.4 LOCATOR; 8,572.7 SLEEVE-O; 7,934.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 SLEEVE-O; 7,757.4 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 PBR; 7,633.8 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 CEMENT RETAINER; 7,378.0 Plug – Plug Back / Abandonment Plug; 7,224.0 ftKB Annular Fluid - Saltwater/Brine; 2,508.0-7,224.0; 6/12/2023 SURFACE; 29.7-3,649.1 FLOAT SHOE; 3,647.4-3,649.1 FLOAT COLLAR; 3,566.9- 3,568.4 Annular Fluid - Diesel; 25.0- 2,508.0; 6/12/2023 CONDUCTOR; 30.0-150.0 HANGER; 29.7-30.9 HANGER; 28.1-30.9 Hanger; 25.0 KUP PROD KB-Grd (ft) 62.56 RR Date 1/17/2002 Other Elev… 3N-19 ... TD Act Btm (ftKB) 10,515.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305600 Wellbore Status PROD Max Angle & MD Incl (°) 97.97 MD (ftKB) 9,743.44 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 200 Date 1/24/2017 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,850.0 7,860.0 6,380.0 6,383.7 A-3, 3N-19 1/14/2002 6.0 IPERF 4.5" BHC, 60 deg phase 9,182.010,454.06,463.96,446.9 A-2, A-3, A-6, A- 5, A-3, 3N-19 1/10/2002 99.0 IPERF SLOTTED LINER Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,850.0 7,860.0 1 4/22/2002 154,000.0 0.0 0.00 0.00 3N-19, 9/3/2025 12:08:38 PM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 SHOE; 10,454.8-10,488.0 BUSHING; 10,453.6-10,454.8 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 FLOAT SHOE; 8,754.3-8,755.8 FLOAT COLLAR; 8,669.4- 8,670.7 VALVE; 8,615.0 PBR; 8,594.7-8,606.9 HANGER; 8,585.4-8,594.7 SEAL ASSY; 8,574.0 PACKER; 8,571.6-8,585.4 LOCATOR; 8,572.7 SLEEVE-O; 7,934.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 SLEEVE-O; 7,757.4 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 PBR; 7,633.8 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 CEMENT RETAINER; 7,378.0 Plug – Plug Back / Abandonment Plug; 7,224.0 ftKB Annular Fluid - Saltwater/Brine; 2,508.0-7,224.0; 6/12/2023 SURFACE; 29.7-3,649.1 FLOAT SHOE; 3,647.4-3,649.1 FLOAT COLLAR; 3,566.9- 3,568.4 Annular Fluid - Diesel; 25.0- 2,508.0; 6/12/2023 CONDUCTOR; 30.0-150.0 HANGER; 29.7-30.9 HANGER; 28.1-30.9 Hanger; 25.0 KUP PROD 3N-19 ... WELLNAME WELLBORE “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/29/2025 InspectNo:susSTS250908163557 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:6/12/2023 #323-339 Tubing:0 IA:0 OA:270 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Initial Well Name:KUPARUK RIV UNIT 3N-19 Permit Number:2012250 Wellhead Condition Well head is in excellent condition and inside a heated wellhouse. Valves turn easily, no signs of leaks, tree is separated from any flow lines. Surrounding Surface Condition clean and free of debris, no subsidence Condition of Cellar cellar is filled with gravel to surface , grating is in good condition Comments Operator states this well's Initial Suspension inspection was missed due to a lack of communication with the rig that was last on it in 2023. Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (3) attaached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, October 29, 2025           2025-0906_Suspend_KRU_3N-19_photos_ss Page 1 of 2 Suspended Well Inspection – KRU 3N-19 PTD 2012250 AOGCC Inspection Rpt # susSTS250908163557 Photos by AOGCC Inspector S. Sullivan 9/6/2025 2025-0906_Suspend_KRU_3N-19_photos_ss Page 2 of 2 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing 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): 11. Present Well Condition Summary: Total Depth measured 10515'feet 7224' 7672' feet true vertical 3797' feet 10488'feet Effective Depth measured 10030'feet 7648'feet true vertical 6434' feet 6290'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)4-1/2" (klll string) 3-1/2" L-80 L-80 1926' 8601' 1904' 6454' Packers and SSSV (type, measured and true vertical depth)7648' 8572' N/A 6290' 6455' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk 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: 323-339 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Baker FHL Retrievable Baker ZXP SSSV: None James Ohlinger james.ohlinger@conocophillips.com (907) 2653-4529CTD Engineer 7850'-7860', 9182'-10454' 6380'-6384', 6464'-6447' 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) 0 Gas-Mcf MD 0 Size 150' 0 00 0 00 0 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-225 50-029-23056-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025520 KRU 3N-19 Plugs Junk measured Length Production Liner 8726' Casing 6461'8756' 10488' 6446' 3619' 150'Conductor Surface 16" 9-5/8" 120' 1916' 3-1/2" 3649' 3621' Burst Collapse Fra O s 6. A PG , C Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 10. Field/Pool(s): Kuparuk River Field/ Kuparuk River Oil Pool By Grace Christianson at 1:22 pm, Jul 05, 2023 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E= James.J.Ohlinger@cop.com Reason: I am the author of this document Location: Date: 2023.07.05 13:07:29-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger Page 1/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/15/2023 00:00 5/15/2023 07:30 7.50 MIRU, MOVE RURD P Complete rig down of rig and support buildings prep to move, lay over derrick 0.0 0.0 5/15/2023 07:30 5/15/2023 10:30 3.00 MIRU, MOVE MOB P Move shop, pits,and rig offices to 3N 0.0 0.0 5/15/2023 10:30 5/15/2023 16:00 5.50 MIRU, MOVE MOB P Move sub base from 3F to 3N pad 0.0 0.0 5/15/2023 16:00 5/15/2023 18:45 2.75 MIRU, MOVE MOB P Hang tree in cellar, lay herculite and rig mats around 3N-19, spot sub base over 3N-19, lay herculite and mats for pit, spot pits to sub base, spot mud lab 0.0 0.0 5/15/2023 18:45 5/16/2023 00:00 5.25 MIRU, MOVE RURD P Raise derrick, tie back bridle lines, burm around rig, pits and camp, hook up interconnect lines, work on rig acceptance checklist Bring on 14 PPG mud to pits Obtain RKB's for 7 ES G/L = 28.31' LLDS = 26.41' ULDS =- 24.19' TBG = 2100 PSI IA = 2200 PSI Rig accepted at 00:00 HRS 5-16-23 0.0 0.0 5/16/2023 00:00 5/16/2023 01:00 1.00 MIRU, WELCTL RURD P RIg up circ lines in cellar to tiger tank, bring on mud to pits, load pipe shed with DP 0.0 0.0 5/16/2023 01:00 5/16/2023 01:45 0.75 MIRU, WELCTL RURD P Prime mud pumps, R/U circ lines and sensors, blow air thru lines 0.0 0.0 5/16/2023 01:45 5/16/2023 02:00 0.25 MIRU, WELCTL SFTY P PJSM - Circ 14 PPG KWF 0.0 0.0 5/16/2023 02:00 5/16/2023 06:00 4.00 MIRU, WELCTL CIRC P Flood lines to tiger tank, test to 3,500 PSI Burp IA to tank, shut in let PSI stabilize at 2000 Initial IA PSI = 2200 Initial TBG PSI = 2100 Bring on pumps @ 2 BPM 2065 PSI, holding 2150 PSI on IA, Stage up to 4 BPM maintaining 2150 on IA until KWF turned corner then follow DP schedule Pump 22.5 BBL Deepclean pill Chase with BBLS 14 PPG LSND mud 0.0 0.0 5/16/2023 06:00 5/16/2023 07:00 1.00 MIRU, WELCTL CIRC P Finish circulating well to 14# LSND in and out. Sim ops loading DP in the pipe shed 0.0 0.0 5/16/2023 07:00 5/16/2023 08:30 1.50 MIRU, WELCTL OWFF P Blow down surface lines. OWFF. Simops MU testing equipment RU slings to T.D. for pulling tree. 0.0 0.0 5/16/2023 08:30 5/16/2023 09:00 0.50 MIRU, WELCTL MPSP P Set BPV Test under plug to 1000 PSI with rolling test injection at 1.5 BPM at 1000 PSI tree open to atmosphere. plug not leaking to surface. 10 BBL's pumped away to formation. 0.0 0.0 5/16/2023 09:00 5/16/2023 10:00 1.00 MIRU, WELCTL OWFF P Bleed trapped pressure off formation to 0 flow and OWFF for 30 minutes. 0 flow for 30 minutes. 0.0 0.0 5/16/2023 10:00 5/16/2023 12:00 2.00 MIRU, WELCTL NUND P RD hardline and circulating equipment in cellar. Bleed adapter void to 0 psi. ND tree and adpater. function test all LDS. inspect and clean hanger threads. install HP dart in BPV. 0.0 0.0 5/16/2023 12:00 5/16/2023 14:00 2.00 MIRU, WHDBOP NUND P NU BOP's. install riser, 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 2/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/16/2023 14:00 5/16/2023 15:00 1.00 MIRU, WHDBOP RURD P fill stack with water purge air out of lines and install test joint and arrange safety valves. Perform shell test. IBOP failed on initial shell test. 0.0 0.0 5/16/2023 15:00 5/16/2023 20:30 5.50 MIRU, WHDBOP BOPE P Obtain good shell test continue with BOP Testing Initial BOPE test, Tested annular W/3 1/2" test JT to 250/3500 PSI F/5 min, All other test to 250/4000 PSI F/5 Min each. Test UVBR/LVBR w/3 1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper/lower IBOP valves. Test 3 1/2" HT-38 FOSV/Dart Valve. Test 3 ½” EUE FOSV. Test PH6 FOSV/Dart valve. Test 2" rig floor Demco kill valves. Test manual and HCR kill and choke valves.Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure= 3000 PSI, after closure= PSI, 200 PSI attained = XX sec, full recovery attained =XXX sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= XX sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2055 PSI. Test gas detectors, PVT and flow show. AOGCC Rep. Guy Cook waived witness 5-16-23 at 12:15PM verbal notification. 0.0 0.0 5/16/2023 20:30 5/17/2023 00:00 3.50 MIRU, WHDBOP BOPE T Change out IBOP and Saver sub valve on TD // Re-test good 0.0 0.0 5/17/2023 00:00 5/17/2023 00:30 0.50 COMPZN, RPCOMP SVRG P Service topdrive 0.0 0.0 5/17/2023 00:30 5/17/2023 01:00 0.50 COMPZN, RPCOMP CLEN P Clean floor area from BOP testing, blow down surface lines // 0.0 0.0 5/17/2023 01:00 5/17/2023 01:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV and test dart 0.0 0.0 5/17/2023 01:30 5/17/2023 02:00 0.50 COMPZN, RPCOMP THGR P Pick up landing jt screw in 10.5 turns // Pull up to 195K ~ 15' streach 0.0 0.0 5/17/2023 02:00 5/17/2023 03:30 1.50 COMPZN, RPCOMP CIRC P Circulate and condition mud while waiting on E-line for re-cut of tubing 0.0 0.0 5/17/2023 03:30 5/17/2023 04:30 1.00 COMPZN, RPCOMP PULL P Work pipe pulling up to 195K no movement // waiting on e-line 0.0 0.0 5/17/2023 04:30 5/17/2023 07:30 3.00 COMPZN, RPCOMP CIRC P Circulate condition well. spot in E-line. 0.0 0.0 5/17/2023 07:30 5/17/2023 09:00 1.50 COMPZN, RPCOMP OWFF P BD top drive and circulating lines. OWFF L/D landing joint pick up space out pups for E-line. PU E-line tools to floor. Flow at Flow line. suspect well is out of balance. 0.0 0.0 5/17/2023 09:00 5/17/2023 10:15 1.25 COMPZN, RPCOMP CIRC P Circulate SxS 14# in/out 3BPM 635 PSI. Light spots seen in returns. 0.0 0.0 5/17/2023 10:15 5/17/2023 11:15 1.00 COMPZN, RPCOMP OWFF P Condition pits to 14# while OWFF. Well static. 0.0 0.0 5/17/2023 11:15 5/17/2023 13:00 1.75 COMPZN, RPCOMP RURD P Blow down top drive, space out joints to floor. Rig up E-line. 0.0 0.0 5/17/2023 13:00 5/17/2023 15:30 2.50 COMPZN, RPCOMP ELNE P RIH with Yellow jacket E-line TS with RCT cutter to cut depth. attempt to anchor cutter to cut at 7615' short to toolstring. POOH 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 3/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/17/2023 15:30 5/17/2023 17:00 1.50 COMPZN, RPCOMP ELNE P Break out tools and diagnosis short. 0.0 0.0 5/17/2023 17:00 5/17/2023 20:30 3.50 COMPZN, RPCOMP ELNE P Short discovered at jars. RIH with reconfigured tool string CCL EMA and cutter // on depth CCL @ 7599.8' cut depth 7615' // Slips set 200# over pull fire cutter indication of good cut // Pull up hole with cutting tool // Cutting tool hung up in patch @ 7427' unable to push or pull free pull out of rope socket and continue out of hole // Rig down e- line stage on rig floor 0.0 0.0 5/17/2023 20:30 5/17/2023 21:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 5/17/2023 21:00 5/17/2023 22:00 1.00 COMPZN, RPCOMP PULL P Attempt to pull from cut up to 195K unable to pull free // OWFF at flow line // slight flow at flow line suspect well out of balance 0.0 0.0 5/17/2023 22:00 5/17/2023 23:15 1.25 COMPZN, RPCOMP CIRC P Circulate SxS 14# in/out 3BPM 635 PSI. Light spots seen in returns. 0.0 0.0 5/17/2023 23:15 5/18/2023 00:00 0.75 COMPZN, RPCOMP PULL P Work cut circulate mud waiting on slick line truck 0.0 0.0 5/18/2023 00:00 5/18/2023 01:00 1.00 COMPZN, RPCOMP OWFF P Pick up slick line for fishing e-line tools , OWFF no flow 0.0 0.0 5/18/2023 01:00 5/18/2023 19:00 18.00 COMPZN, RPCOMP SLKL P Rig up slick line tools on well. RIH to fish tools. Latch into E-line tool string work up hole with tool string. Wire parted at drum on S/L unit. Tie rope socket to rope socket and attemtp to shear off fish. Fish appeared to move down 10' lost spangs and cant see jars fire. R.U. to pump. O-ring leaked at otis connection R/D otis cap and replace O-ring. Online at 1BPM Pump down tbg take returns up the IA. Tool string started moving up hole freely. shut down pump swap rope sockets to other side of sheaves. Continue POOH with S/L E-line tools recovered lay down S/L and E-line tools rig down S/L 0.0 0.0 5/18/2023 19:00 5/18/2023 20:30 1.50 COMPZN, RPCOMP CIRC P Circulate and condition mud // 37 spm @ 733 psi // 0.0 0.0 5/18/2023 20:30 5/19/2023 00:00 3.50 COMPZN, RPCOMP ELNE P Rig up e-line and well tech to perform cut @ 7410' // RIH tag top of patch @ 7405 ( CCL depth ... 18' offset) pick up and log collars for accurate depth // Correct to previous logs +4' // Re-tag top of patch in same spot // Pick up to 7392 CCL ( 7410' Cutter Depth ) // Engage cutter 3 min amp drop off and e-line tension drop, overpull on completion release felt on rig // Continue with cutter for 5 min w/o amp flux indicate good cut 0.0 0.0 5/19/2023 00:00 5/19/2023 01:30 1.50 COMPZN, RPCOMP ELNE P After cut made pooh with e-line rack back tools // lay down Welltec cutter indicator shows full cut 3.8" 0.0 0.0 5/19/2023 01:30 5/19/2023 02:15 0.75 COMPZN, RPCOMP PULL P Rack back e-line // remove subs screw in w/ TD // Pull hanger to floor 88k PU wt. pipe free 0.0 0.0 5/19/2023 02:15 5/19/2023 03:15 1.00 COMPZN, RPCOMP CIRC P Circulate S to S condition mud 5bpm 850 psi 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 4/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/19/2023 03:15 5/19/2023 03:45 0.50 COMPZN, RPCOMP OWFF P OWFF no flow 0.0 0.0 5/19/2023 03:45 5/19/2023 04:00 0.25 COMPZN, RPCOMP CIRC P Pump 20 bbl 2 ppg over dry job 0.0 0.0 5/19/2023 04:00 5/19/2023 08:30 4.50 COMPZN, RPCOMP PULL P Pull 3.5" completion F/7410' T/4350' 7,410.0 4,350.0 5/19/2023 08:30 5/19/2023 09:30 1.00 COMPZN, RPCOMP OWFF P Hole not taking correct fluid per trip sheet. Trip tank mud aired up, dump trip tank refill from active with 14# LSND added defoamer. No flow at flow line. 4,350.0 4,350.0 5/19/2023 09:30 5/19/2023 14:00 4.50 COMPZN, RPCOMP PULL P Continue POOH w/3.5" completion F/4350' T/Surface 4,350.0 0.0 5/19/2023 14:00 5/19/2023 15:00 1.00 COMPZN, RPCOMP RURD P Clean and clear floor. Pick up DP joint and install wear ring in tubing head. 0.0 0.0 5/19/2023 15:00 5/19/2023 17:00 2.00 COMPZN, RPCOMP BHAH P Load BHA in pipe shed and verfiy lengths ID and OD's. PU BHA #1 0.0 209.0 5/19/2023 17:00 5/20/2023 00:00 7.00 COMPZN, RPCOMP TRIP P Trip in hole with fishing bha 1 on singles drill pipe 209.0 7,320.0 5/20/2023 00:00 5/20/2023 00:30 0.50 COMPZN, RPCOMP FISH P Wash down Jts. 228 - 229 // Up wt. 150K Dn wt 100K // 3 BPM @ 1130 psi 2 BPM @ 909 psi // Engage fish @ 2 bpm @ 7404' ( 500 psi pressure spike engaging fish ) Pumps off // NG fishing tools @ 7407' // PU wt 165K fish engaged // Left torque 6000 ft/lbs work torque // 12.5 rotations to left // PU wt 150K pump on 2 bpm 950 psi // PU to 7398' 150K 7,320.0 7,398.0 5/20/2023 00:30 5/20/2023 01:30 1.00 COMPZN, RPCOMP CIRC P Circulate B/U ensure good mud properties // 4 bpm @ 1400 psi // 7,398.0 7,398.0 5/20/2023 01:30 5/20/2023 02:00 0.50 COMPZN, RPCOMP OWFF P OWFF no flow 7,398.0 7,398.0 5/20/2023 02:00 5/20/2023 03:30 1.50 COMPZN, RPCOMP SLPC P Slip and cut drill line 7,398.0 7,398.0 5/20/2023 03:30 5/20/2023 04:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 7,398.0 5/20/2023 04:00 5/20/2023 04:30 0.50 COMPZN, RPCOMP CIRC P Circulate well 98 BBL's 4 BPM 7,398.0 7,398.0 5/20/2023 04:30 5/20/2023 05:00 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes 7,398.0 7,398.0 5/20/2023 05:00 5/20/2023 05:15 0.25 COMPZN, RPCOMP CIRC P Pump 20 BBL 1# Dry job. 7,398.0 7,398.0 5/20/2023 05:15 5/20/2023 05:30 0.25 COMPZN, RPCOMP TRIP P TOOH 5 stands. 7,398.0 6,898.0 5/20/2023 05:30 5/20/2023 06:15 0.75 COMPZN, RPCOMP OWFF P OWFF manually strap all pits. No flow at flow line let slug fall DH 6,898.0 6,898.0 5/20/2023 06:15 5/20/2023 06:30 0.25 COMPZN, RPCOMP TRIP P Pull 5 stands F/6898 T/6398 6,898.0 6,398.0 5/20/2023 06:30 5/20/2023 07:00 0.50 COMPZN, RPCOMP OWFF P OWFF well static 6,398.0 6,398.0 5/20/2023 07:00 5/20/2023 08:30 1.50 COMPZN, RPCOMP TRIP P Pull stands on trip sheet monitoring well F/6398 T/3100' 6,398.0 3,100.0 5/20/2023 08:30 5/20/2023 09:00 0.50 COMPZN, RPCOMP SVRG P Service Rough neck 3,100.0 3,100.0 5/20/2023 09:00 5/20/2023 10:00 1.00 COMPZN, RPCOMP TRIP P Cont TOOH F/3100' T/209.5 209.5 209.5 5/20/2023 10:00 5/20/2023 10:15 0.25 COMPZN, RPCOMP OWFF P OWFF for 15 minutes. top off hole before LD BHA. 209.5 209.5 5/20/2023 10:15 5/20/2023 12:00 1.75 COMPZN, RPCOMP BHAH P LD BHA and fish. MU BHA#2 overshot stop. Torque all connections on BHA. 209.5 209.7 5/20/2023 12:00 5/20/2023 15:00 3.00 COMPZN, RPCOMP TRIP P TIH W/BHA#2 overshot BHA to top of fish at 7419' PUW=150 K SOW=90K 209.7 7,419.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 5/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/20/2023 15:00 5/20/2023 15:30 0.50 COMPZN, RPCOMP FISH P Establish fishing parameters. 20 RPM 2 BPM 600PSI, free tq=4500. washed down 2 times at 7419' 7es RKB 850 PSI after tag unable to get any purchase on fish. PU 7,419.0 7,419.0 5/20/2023 15:30 5/20/2023 18:00 2.50 COMPZN, RPCOMP CIRC P Circulate 3BPM at 600 PSI. gas and oil in returns close in LPR and circulate through Gas Buster at 1.5 BPM. 7,419.0 7,419.0 5/20/2023 18:00 5/20/2023 19:00 1.00 COMPZN, RPCOMP OWFF P OWFF no flow 7,419.0 7,419.0 5/20/2023 19:00 5/21/2023 00:00 5.00 COMPZN, RPCOMP TRIP P TOOH 5 stands @ 50'/min observe for swabbing // Pump dry job // Continue out of hole slowly to minimise swab effect // Indications of swabbing stop OWFF no flow at surface continue to TOOH slowly 40'/min 7,419.0 4,800.0 5/21/2023 00:00 5/21/2023 02:00 2.00 COMPZN, RPCOMP TRIP P TOOH controlled speed minimize swabbing 4,800.0 210.0 5/21/2023 02:00 5/21/2023 03:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA#2 210.0 0.0 5/21/2023 03:00 5/21/2023 03:30 0.50 COMPZN, RPCOMP OTHR P Suck out stack // Pull wear ring install test plug 0.0 0.0 5/21/2023 03:30 5/21/2023 04:30 1.00 COMPZN, RPCOMP BOPE P Pressure Test Upper Pipe rams 250/4000 // Function test Annular 25 sec 0.0 0.0 5/21/2023 04:30 5/21/2023 05:00 0.50 COMPZN, RPCOMP OTHR P Pull test plug and install wear ring 0.0 0.0 5/21/2023 05:00 5/21/2023 07:00 2.00 COMPZN, RPCOMP BHAH P Pick up BHA# 3 Short catch overshot w/ washpipe 0.0 247.8 5/21/2023 07:00 5/21/2023 09:45 2.75 COMPZN, RPCOMP TRIP P TIH on stands F/248' filling the DP every 15 stands. T/4500' Well started flowing down F/L with pumps off. Shut in annular, lined up to close choke, checked casing pressure. 10 PSI at wellhead and superchoke. 247.8 4,500.0 5/21/2023 09:45 5/21/2023 12:00 2.25 COMPZN, RPCOMP KLWL P Circulate 14# LSND through gas buster at 16 SPM @ 500 PSI. maintaining DP PSI. 14# LSND in and out. 4,500.0 4,500.0 5/21/2023 12:00 5/21/2023 12:30 0.50 COMPZN, RPCOMP OWFF P Open annular and monitor well for flow for 30 minutes. 4,500.0 4,500.0 5/21/2023 12:30 5/21/2023 13:30 1.00 COMPZN, RPCOMP TRIP P TIH on stands fill DP F/4500 T/5000' Fill DP verify fill up volume. Con't TIH filling DP every 15 stands. F/5000 T/7342 4,500.0 7,342.0 5/21/2023 13:30 5/21/2023 15:00 1.50 COMPZN, RPCOMP CIRC P Circualte SxS off bottom work pump up to 5 BPM 1800 PSI 7,342.0 7,342.0 5/21/2023 15:00 5/21/2023 15:30 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes 7,342.0 7,342.0 5/21/2023 15:30 5/21/2023 16:15 0.75 COMPZN, RPCOMP FISH P Wash over fish. PUW=145K SOW=95K, Rot wt=120K, Free torque=4500 pr=1BPM wash down F/7342' - T/7427'. engage fish and PU 35K ensure grapple is seated. Work pipe down attepting to break seals loose. striaght pull up to 35K attempt to pull seals out of PBR. No movement. Work torque down the string 4800 Ft/Lbs worked down 6 rotations torque broke back, worked 6-1/2" more rotations down string, able to pick up clean. PU to 7405' line up to circulate. 7,342.0 7,427.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 6/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/21/2023 16:15 5/21/2023 18:15 2.00 COMPZN, RPCOMP CIRC P Circulate BUS at 2 BPM 950 PSI 7,405.0 7,405.0 5/21/2023 18:15 5/21/2023 23:00 4.75 COMPZN, RPCOMP TRIP P Pull 5 stands wet control trip speed minimize swab effect // OWFF no flow // Pump dry job // Continue to TOOH filling backside w/ 14.1# LSND 7,405.0 235.0 5/21/2023 23:00 5/21/2023 23:45 0.75 COMPZN, RPCOMP BHAH P Lay down BHA#3 // BHA backed off leaving XO and short catch overshot on mandrel 235.0 0.0 5/21/2023 23:45 5/22/2023 00:00 0.25 COMPZN, RPCOMP CLEN P Clean up floor for testing Annular and trip in hole 0.0 0.0 5/22/2023 00:00 5/22/2023 00:30 0.50 COMPZN, RPCOMP SVRG P Service DW and TD 0.0 5/22/2023 00:30 5/22/2023 01:15 0.75 COMPZN, RPCOMP OTHR P Suck out stack // Pull wear ring install test plug 0.0 0.0 5/22/2023 01:15 5/22/2023 02:15 1.00 COMPZN, RPCOMP BOPE P Pressure Test Annular 250/3500 // Pressure Test HCR Choke 250/4000 0.0 0.0 5/22/2023 02:15 5/22/2023 02:45 0.50 COMPZN, RPCOMP OTHR P Pull test plug and install wear ring 0.0 0.0 5/22/2023 02:45 5/22/2023 03:45 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 4 ( BHA# 3 wo XO and Overshot ) 0.0 205.0 5/22/2023 03:45 5/22/2023 07:15 3.50 COMPZN, RPCOMP TRIP P TIH on stands filling pipe every 15 stands F/205' T/7320' screw into DP. line up to circulate 205.0 7,320.0 5/22/2023 07:15 5/22/2023 09:45 2.50 COMPZN, RPCOMP CIRC P Circulate SxS condition well 14# in adn out at end of circulation. 2BPM at 1000 PSI 7,320.0 7,320.0 5/22/2023 09:45 5/22/2023 18:30 8.75 COMPZN, RPCOMP FISH P Establish parameters for engaging overshot. PUW = 150K SOW= 95K 10 RPM rot wt=120K free tq=4700 Wash down last stand to tag. Screw into grapple get over pull up to 175K Rotate work torque down to grapple. work up to 8K RH torque down string/ continue working string attempt to free grapple. Mix 30 BBL 2% 776 lube pill while working string Pump 30 BBL pill spot 776 at EOP. Continue to work pipe not able to get grapple off decision made to back off bha 7,320.0 7,386.0 5/22/2023 18:30 5/22/2023 19:15 0.75 COMPZN, RPCOMP CIRC P Pump SxS condition well 14.1# 7,386.0 7,386.0 5/22/2023 19:15 5/23/2023 00:00 4.75 COMPZN, RPCOMP TRIP P Pull 5 stands wet check for flow/ Swabbing // No Flow // Pump dry job // TOOH BHA 7,386.0 230.0 5/23/2023 00:00 5/23/2023 01:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA drive sub and washpipe left in hole 230.0 0.0 5/23/2023 01:00 5/23/2023 01:30 0.50 COMPZN, RPCOMP CLEN P Clean rig floor 0.0 0.0 5/23/2023 01:30 5/23/2023 02:15 0.75 COMPZN, RPCOMP BHAH P Pick up milling BHA# 5 0.0 250.0 5/23/2023 02:15 5/23/2023 04:15 2.00 COMPZN, RPCOMP TRIP P TIH w/ Junk Mill 250.0 6,000.0 5/23/2023 04:15 5/23/2023 06:15 2.00 COMPZN, RPCOMP SLPC P Slip and cut drill line 6,000.0 6,000.0 5/23/2023 06:15 5/23/2023 07:00 0.75 COMPZN, RPCOMP TRIP P TIH with 6-1/8" Junk mill 6,000.0 7,311.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 7/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/23/2023 07:00 5/23/2023 09:45 2.75 COMPZN, RPCOMP CIRC P Pump SxS condition mud for milling ops // Observed light spots in mud continue circulating to get 14.1 around 7,311.0 7,311.0 5/23/2023 09:45 5/23/2023 11:00 1.25 COMPZN, RPCOMP MILL P Obtain free spin numbers Tag top of sub 7390' 5 bpm = 2000 psi Dn Wt. Non-Rot = 99K Up Wt. Non-Rot = 142 RPM 85 TQ 4600 Mill F/ 7390' T/ 7391' Pump sweeps x 2 - 10 bbl & 15 bbl sweeps Seeing metal on magnets 7,311.0 7,390.0 5/23/2023 11:00 5/23/2023 17:00 6.00 COMPZN, RPCOMP MILL P Continue milling ahead 5 bpm, 87 stk/min, 1,850 psi WOB = 24-28k RPM = 101. TQ = 6,200 Mill F/ 7,390' T/ 7,392' No progress ~ 6hrs decision made to TOOH check mill 7,390.0 7,392.0 5/23/2023 17:00 5/23/2023 19:30 2.50 COMPZN, RPCOMP CIRC P Circulate mud // Light spots in returns weight up returns even out mud // 14.1 in and out 7,392.0 7,385.0 5/23/2023 19:30 5/23/2023 23:00 3.50 COMPZN, RPCOMP TRIP P TOOH to inspect mill 7,385.0 230.0 5/23/2023 23:00 5/24/2023 00:00 1.00 COMPZN, RPCOMP BHAH P Lay down BHA inspect tools 230.0 0.0 5/24/2023 00:00 5/24/2023 01:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA 6 // 6-1/8" junk mill with boot baskets w/ 6 ea 4.75" drill collars 0.0 230.0 5/24/2023 01:00 5/24/2023 03:45 2.75 COMPZN, RPCOMP TRIP P Trip in hole on stands with junk mill filling pipe every 25 stands 230.0 7,385.0 5/24/2023 03:45 5/24/2023 05:45 2.00 COMPZN, RPCOMP CIRC P Circulate SXS volume 5 bpm, 87 stks/min @ 2,015 psi Nothing to report 7,385.0 7,385.0 5/24/2023 05:45 5/24/2023 09:45 4.00 COMPZN, RPCOMP MILL P Obtain F/S parameters 5 bpm, 87 stk/min, 1,547 psi Begin milling on Fish WOB = 10k RPM = 95 TQ = 5,800 Mill F/ 7,391' T/ 7,392.8' Pump 15 bbl sweep, nothing seen at surface 7,385.0 7,392.0 5/24/2023 09:45 5/24/2023 10:15 0.50 COMPZN, RPCOMP MILL P Continue Milling ahead 5 bpm/87 stks/min/1,981 psi RPM = 81, TQ = 6,400, WOB = 11k Dn Wt. Non-Rot = 99K Up Wt. Non-Rot = 142 Mill F/7392' T/7392.8 7,392.0 7,392.8 5/24/2023 10:15 5/24/2023 11:45 1.50 COMPZN, RPCOMP MILL P On bottom milling Lower pump rate and change torque to find sweet spot 1.5 bpm/21 stks/min/1,232 psi RPM = 80, TQ = 6,500, WOB 12k Mill F/7,392' T/7392.9' 7,392.8 7,392.8 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 8/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/24/2023 11:45 5/24/2023 12:15 0.50 COMPZN, RPCOMP OWFF P Started losing fluid 1 bpm, confirm nothing changed in pits. Checked OA pressure 260 psi PU off fish, Shut down pump, monitor well, total losses 23 bbl OA pressure dropped to 240 psi Bring pump back online 5 bpm, 87 stks/min, 1,974 psi Normal pressures, without losses, OA pressure 300 psi Shut down pump, function closed Annular, PT 7" to 500 psi and monitor OA pressure. Good test 7,392.8 7,392.8 5/24/2023 12:15 5/24/2023 17:15 5.00 COMPZN, RPCOMP MILL P Go back to milling 3 bpm, 51 stks/min, 1,215 psi RPM = 62, TQ 6,600 Dn Wt. Non-Rot = 100K Up Wt. Non-Rot = 145K Dn Wt. Rot = 99K Up Wt. Rot = 125K Mill F/7,392.8' T/7,393" 7,392.8 7,393.0 5/24/2023 17:15 5/25/2023 00:00 6.75 COMPZN, RPCOMP MILL P Continue Milling ahead 5 bpm/87 stks/min/1,966 psi RPM = 60, TQ = 6,400, WOB 16k Mill F/7,392' T/7400 7,393.0 7,400.0 5/25/2023 00:00 5/25/2023 05:00 5.00 COMPZN, RPCOMP MILL P Continue Milling ahead 5 bpm/87 stks/min/1,966 psi RPM = 60, TQ = 6,400, WOB 16k Mill F/7,400' T/7,410' 7,400.0 7,410.0 5/25/2023 05:00 5/25/2023 05:30 0.50 COMPZN, RPCOMP MILL P 7,410', recip pipe, dragging up hole, pulled heavy Pull 30k over pickup wieght popped free 7,410.0 7,400.0 5/25/2023 05:30 5/25/2023 07:15 1.75 COMPZN, RPCOMP CIRC P Circulate SxS voilume Pump 10 bbl dry job 7,400.0 7,400.0 5/25/2023 07:15 5/25/2023 09:45 2.50 COMPZN, RPCOMP TRIP P TOOH 7,400.0 0.0 5/25/2023 09:45 5/25/2023 10:15 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 5/25/2023 10:15 5/25/2023 10:45 0.50 COMPZN, RPCOMP BHAH P Stand back 1 stand of collars LD and inspect BHA Empty boot baskets 0.0 0.0 5/25/2023 10:45 5/25/2023 12:51 2.10 COMPZN, RPCOMP BHAH P Load burn shoe onto rig floor M/U Burn over assembly 0.0 291.4 5/25/2023 12:51 5/25/2023 14:54 2.05 COMPZN, RPCOMP TRIP P TIH, w/BHA #6, KHT FB Shoe, 2 joints of wash pipe, Drive sub, boot basket x 2, Bumper sub, Jars, 6 drill collars, TT = 291.41' 291.4 7,385.0 5/25/2023 14:54 5/25/2023 15:54 1.00 COMPZN, RPCOMP CIRC P Circulate SxS 7,385.0 7,385.0 5/25/2023 15:54 5/25/2023 16:39 0.75 COMPZN, RPCOMP MILL P Obtain pump parameters 5 bpm, 87 stks/min, 1,958 psi No-Rot SOW= 95, PUW = 150k Rot SOW = 90k. PUW = 110k RPM = 60, TQ = 6,200, WOB 12k Creep in hole not rotating notice bobble @ 7,393' Start rotating 60 = RPM, TQ = 6,500 Continue IH to Total depth 7,409' Shut down Top Drive Rotation TOOH, to 7,393', TBIH to 7,409' clean 7,385.0 7,409.0 5/25/2023 16:39 5/25/2023 18:00 1.35 COMPZN, RPCOMP CIRC P TUH Circulate SxS with 30 bbl sweep 7,409.0 7,409.0 5/25/2023 18:00 5/25/2023 22:00 4.00 COMPZN, RPCOMP TRIP P TOOH to BHA 7,409.0 230.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 9/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/25/2023 22:00 5/25/2023 23:00 1.00 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 230.0 0.0 5/25/2023 23:00 5/25/2023 23:30 0.50 COMPZN, RPCOMP CLEN P Clean up floor 0.0 0.0 5/25/2023 23:30 5/26/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service blocks and TD 0.0 0.0 5/26/2023 00:00 5/26/2023 01:00 1.00 COMPZN, RPCOMP BHAH P Pick up burn shoe with 60' washpipe and 6 drill collars 0.0 230.0 5/26/2023 01:00 5/26/2023 04:45 3.75 COMPZN, RPCOMP TRIP P TIH w/ burn shoe BHA# 8 230.0 7,380.0 5/26/2023 04:45 5/26/2023 05:45 1.00 COMPZN, RPCOMP CIRC P Circulate and condition mud for milling 7,380.0 7,380.0 5/26/2023 05:45 5/26/2023 15:45 10.00 COMPZN, RPCOMP MILL P Mill F/ 7417' T/ 7420' 60 RPM // 7-9K WOB // 5 bpm @ 2200 psi Unable to make progress past 7420 decision made to TOOH inspect and swap mills 7,380.0 7,420.0 5/26/2023 15:45 5/26/2023 17:00 1.25 COMPZN, RPCOMP CIRC P Circulate SxS condition mud // 5 BPM @ 2100 psi 7,420.0 7,400.0 5/26/2023 17:00 5/26/2023 17:30 0.50 COMPZN, RPCOMP OWFF P OWFF no flow 7,400.0 7,400.0 5/26/2023 17:30 5/26/2023 20:15 2.75 COMPZN, RPCOMP TRIP P TOOH to inspect/swap mills 7,400.0 230.0 5/26/2023 20:15 5/26/2023 21:30 1.25 COMPZN, RPCOMP BHAH P Lay down and inspect BHA , Burn shoe completely used up , 10.10' ribbon of washpipe recovered 230.0 0.0 5/26/2023 21:30 5/26/2023 22:30 1.00 COMPZN, RPCOMP BHAH P Pick up BHA # 9 , 6-1/8" burn shoe 4- 5/8" ID , 60' wash pipe 2 boot baskets 6 drill collars 0.0 230.0 5/26/2023 22:30 5/27/2023 00:00 1.50 COMPZN, RPCOMP TRIP P TIH w/ Burn shoe BHA# 9 230.0 2,000.0 5/27/2023 00:00 5/27/2023 02:00 2.00 COMPZN, RPCOMP TRIP P TIH with burn shoe BHA# 9 2,000.0 7,380.0 5/27/2023 02:00 5/27/2023 03:00 1.00 COMPZN, RPCOMP CIRC P Circulate SxS condition mud for milling operations // 5 bpm @ 1844 psi 7,380.0 7,380.0 5/27/2023 03:00 5/27/2023 09:00 6.00 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 135K ROT 60 RPM @ 6K Tq 85 spm ( 5 bbl/min ) @ 1890psi Tag TOF @ 7418' Mill ahead F/ 7420' T/ 7422 PP = 2000psi TQ= 6-8K WOB= 5K RPM= 78 7,380.0 7,422.0 5/27/2023 09:00 5/27/2023 10:00 1.00 COMPZN, RPCOMP MILL P Continue Milling Ahead SO Wt. 100K PU Wt. 135K ROT 85 RPM @ 7,700K Tq 85 spm ( 5 bbl/min ) @ 1,971 psi F/ 7,422' T/ 7,422.8' Recip pipe, unable to make it back to bottom 7,422.0 7,422.8 5/27/2023 10:00 5/27/2023 12:00 2.00 COMPZN, RPCOMP CIRC P PUH Circulate BU, while building dry job 7,422.8 7,381.0 5/27/2023 12:00 5/27/2023 14:30 2.50 COMPZN, RPCOMP TRIP P TOOH 7,381.0 224.0 5/27/2023 14:30 5/27/2023 15:00 0.50 COMPZN, RPCOMP SVRG P Service Rig 224.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 10/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/27/2023 15:00 5/27/2023 16:00 1.00 COMPZN, RPCOMP BHAH P LD BHA Heavy scaring on wash pipe Recovered fish inside wash pipe 7.5' long Major wear on burn shoe, measuring 5.5" - 5.95" and no carbide left 224.0 0.0 5/27/2023 16:00 5/27/2023 17:30 1.50 COMPZN, RPCOMP BHAH P Pick up junk mill and string reamer MU BHA #10 0.0 224.0 5/27/2023 17:30 5/27/2023 20:00 2.50 COMPZN, RPCOMP TRIP P TIH w/BHA #10 224.0 4,362.0 5/27/2023 20:00 5/27/2023 21:30 1.50 COMPZN, RPCOMP SLPC P Cut and slip drill line 4,362.0 4,362.0 5/27/2023 21:30 5/27/2023 22:00 0.50 COMPZN, RPCOMP SVRG P Calibrate blocks service rig 4,362.0 4,362.0 5/27/2023 22:00 5/27/2023 22:45 0.75 COMPZN, RPCOMP TRIP P TIH w/BHA# 10 4,362.0 7,380.0 5/27/2023 22:45 5/27/2023 23:45 1.00 COMPZN, RPCOMP CIRC P Circulate SxS ensure mud properties correct for milling 7,380.0 7,380.0 5/27/2023 23:45 5/28/2023 00:00 0.25 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 135K ROT 83 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Tag TOF @ 7422' 7,380.0 7,397.0 5/28/2023 00:00 5/28/2023 06:00 6.00 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 135K ROT 60 RPM @ 6K Tq 85 spm ( 5 bbl/min ) @ 1,890psi Set down w/stalls Mill F/ 7,407' T/ 7,416' WOB= ROT= 83 TQ= 6.2K PP=1,913psi BPM= 5 Multiple stalls @ 7,407' Continue milling down to clean excess washpipe from walls 7,397.0 7,416.0 5/28/2023 06:00 5/28/2023 10:30 4.50 COMPZN, RPCOMP MILL P OBM SO Wt. 100 K PU Wt. 135 K ROT 60 RPM @ 6.7 K Tq 36 spm ( 1.5 bbl/min ) @ 1,000 psi Mill F/ 7,416,' T/ 7,422' WOB 8 K OA pressure 300 psi 7,416.0 7,422.0 5/28/2023 10:30 5/28/2023 14:30 4.00 COMPZN, RPCOMP MILL P OBM SO Wt. 100 K PU Wt. 135 K ROT 60 RPM @ 6.7 K Tq 36 spm ( 1.5 bbl/min ) @ 1,000 psi Mill F/ 7,416,' T/ 7,423' WOB 8 K 7,422.0 7,423.0 5/28/2023 14:30 5/28/2023 16:30 2.00 COMPZN, RPCOMP MILL P SO Wt. 100 K PU Wt. 145 K ROT 62 RPM @ 8.8 K Tq 70 spm ( 4.5 bbl/min ) @ 1,500 psi Mill F/ 7,423' T/ 7,423.4' WOB 18 K Unable to shake debris around sting mill Overpull 210k, on recip, 7,406' OA Pressure 380 psi 7,423.0 7,423.4 5/28/2023 16:30 5/28/2023 18:30 2.00 COMPZN, RPCOMP CIRC P PUH, Circulate BU, Pump dry job 7,423.4 7,381.0 5/28/2023 18:30 5/28/2023 22:15 3.75 COMPZN, RPCOMP TRIP P TOOH to check bottom hole assembly 7,381.0 230.0 5/28/2023 22:15 5/28/2023 23:30 1.25 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 230.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 11/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/28/2023 23:30 5/29/2023 00:00 0.50 COMPZN, RPCOMP SVRG P Service drawworks and blocks 0.0 0.0 5/29/2023 00:00 5/29/2023 00:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 12 0.0 230.0 5/29/2023 00:30 5/29/2023 03:15 2.75 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 12 230.0 7,300.0 5/29/2023 03:15 5/29/2023 04:15 1.00 COMPZN, RPCOMP CIRC P Circulate SxS 7,300.0 7,300.0 5/29/2023 04:15 5/29/2023 06:45 2.50 COMPZN, RPCOMP MILL P OBM 84 strokes/min, 5 bpm, 1,875 psi pump pressure SO Wt. 100 K PU Wt. 145 K ROT 62 RPM @ 8.8 K Tq Mill F/ 7,407' T/ 7,414' WOB 7-8 K 7,414' stall out 7,300.0 7,414.0 5/29/2023 06:45 5/29/2023 07:15 0.50 COMPZN, RPCOMP MILL T Temporarly detained Jar licks x 2, Pull up to 210 k, straight pull to 250 k, Pulled free 7,414.0 7,406.0 5/29/2023 07:15 5/29/2023 11:15 4.00 COMPZN, RPCOMP MILL P PUH to 7,386' Pump 26 spm/1.5 bpm/970 pump pressure Rot = 42 rpm, TQ = 6,700 ft/lbs Work back down hole, trouble getting past 7,406' 7,406.0 7,406.0 5/29/2023 11:15 5/29/2023 11:45 0.50 COMPZN, RPCOMP MILL T Work past F/7,406', T/7,414' Recip pipe Temorarily detained 7,406' Work pipe, jar lick x 6, pulled free 7,406.0 7,414.0 5/29/2023 11:45 5/29/2023 13:15 1.50 COMPZN, RPCOMP CIRC P PUH clean to 7,377' Pump dry job and let fall 7,414.0 7,377.0 5/29/2023 13:15 5/29/2023 16:45 3.50 COMPZN, RPCOMP TRIP P TOOH with fishing assembly BHA #11 7,377.0 227.0 5/29/2023 16:45 5/29/2023 17:30 0.75 COMPZN, RPCOMP BHAH P LD BHA #11 and inspect 227.0 0.0 5/29/2023 17:30 5/29/2023 18:00 0.50 COMPZN, RPCOMP SVRG P Service rig top drive and blocks 0.0 0.0 5/29/2023 18:00 5/29/2023 19:30 1.50 COMPZN, RPCOMP BHAH P Pick up BHA# 12 , burn shoe, washpipe, 6 drill collars 0.0 230.0 5/29/2023 19:30 5/29/2023 22:45 3.25 COMPZN, RPCOMP TRIP P Trip in hole with BHA 12 230.0 7,380.0 5/29/2023 22:45 5/29/2023 23:30 0.75 COMPZN, RPCOMP CIRC P Circulate SxS condition mud for milling ops 7,380.0 7,380.0 5/29/2023 23:30 5/30/2023 00:00 0.50 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 135K ROT 83 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi 7,380.0 7,420.0 5/30/2023 00:00 5/30/2023 03:00 3.00 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 135K ROT 83 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Mill F/ 7420' T/ 7423' PP= 1950 SPM= 85 WOB= 3K TQ= 6500 - 8500 7,420.0 7,423.0 5/30/2023 03:00 5/30/2023 04:00 1.00 COMPZN, RPCOMP CIRC P Circulate SxS pump dry job 7,411.0 7,411.0 5/30/2023 04:00 5/30/2023 07:15 3.25 COMPZN, RPCOMP TRIP P Trip out of hole w/ BHA# 12 7,411.0 289.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 12/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/30/2023 07:15 5/30/2023 08:45 1.50 COMPZN, RPCOMP BHAH P LD BHA #12 Burn Shoe worn w/reduced OD, chunks taken out of leading edge x 4 No fish inside wash pipe 289.0 0.0 5/30/2023 08:45 5/30/2023 11:15 2.50 COMPZN, RPCOMP CIRC P RU stab joint of DP MU to Top Drive Flush stack and surface lines while reciprocating. 0.0 0.0 5/30/2023 11:15 5/30/2023 12:00 0.75 COMPZN, RPCOMP BHAH P LD joint of DP Clean up and prep RF for testing operations Line up to get shell test 0.0 0.0 5/30/2023 12:00 5/30/2023 18:00 6.00 COMPZN, RPCOMP BOPE P Obtain good shell test continue with BOP Testing Bi-weekly BOPE test, #1 Tested Blind Rams, CMV 1,2,3,16, Rig Floor Kill, Outer Test Spool Valve, manual, #2 Blind rams, CMV4, 5,6, HCR Kill, Inner Test Spool valve, and Manual IBOP, #3 LPR, 3.5" EUE FOSV, #4 Annular (3,500 psi), #5 UPR, CMV 7,8,9, Manual Kill, #6 Hydraulic Super Choke and Manual Adjustable Choke (1,500 psi), #7 UPR, CMV, 10, 11 (8), Manual Kill, #8 CMV 12,13,15 (8), HT-38 TIW, #9 CMV 14, HT-38 Dart, #10 HCR Choke, #11 Manual Choke Perform accumulator test. Initial pressure= 1,500 PSI, full recovery attained = 112 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= 24 sec. Simulated blinds= 6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2015 PSI. Test gas detectors, PVT and flow show. AOGCC Rep.Kam StJohn waived witness 5-29- 23 at 06:13 pm email notification. 0.0 0.0 5/30/2023 18:00 5/30/2023 19:00 1.00 COMPZN, RPCOMP CLEN P Clean up floor from BOP test // Put away test equipment // Prep for picking up BHA 0.0 0.0 5/30/2023 19:00 5/30/2023 19:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 13 // Oversize Mill 6.187" OD // boot baskets and 6 collars with jars 0.0 230.0 5/30/2023 19:30 5/30/2023 22:30 3.00 COMPZN, RPCOMP TRIP P TIH w/ BHA# 13 managing speed for oversize mill 230.0 7,305.0 5/30/2023 22:30 5/30/2023 23:30 1.00 COMPZN, RPCOMP CIRC P Circulate 14.1 LSND SxS to ensure good mud for milling ops 7,305.0 7,305.0 5/30/2023 23:30 5/31/2023 00:00 0.50 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 155K ROT 62 RPM @ 6.7K Tq 87 spm ( 5 bbl/min ) @ 1925psi Tag top of tubing 7420.5' // No sign of slab @ 7414' Start milling @ 7415' showing torque down to top of tag 7,305.0 7,422.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 13/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/31/2023 00:00 5/31/2023 06:00 6.00 COMPZN, RPCOMP MILL P Obtain free spin parameters SO Wt. 100K PU Wt. 155K ROT 62 RPM @ 6.7K Tq 87 spm ( 5 bbl/min ) @ 1925psi Tag top of tubing 7420.5' // No sign of slab @ 7414' Start milling @ 7415' showing torque down to top of tag Stall @ 7421.5 PU wt. 160 pull free Continue milling T/ 7421.6' stalled pulled free @ 175K 7,422.0 7,422.5 5/31/2023 06:00 5/31/2023 07:00 1.00 COMPZN, RPCOMP MILL P OBM SO Wt. 100K PU Wt. 135K ROT 60 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Mill F/ 7,424' T/ 7,425' PP= 1950 SPM= 85 WOB= 3K TQ= 6500 - 8500 Stop rot, pound on it x 13 7,422.5 7,424.0 5/31/2023 07:00 5/31/2023 10:30 3.50 COMPZN, RPCOMP MILL P OBM SO Wt. 100K PU Wt. 145K ROT 60 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Mill F/ 7,424' T/ 7,424.3' PP= 1950 SPM= 85 WOB= 3K TQ= 6500 - 8500 Pound on it x 13 7,424.0 7,424.3 5/31/2023 10:30 5/31/2023 14:30 4.00 COMPZN, RPCOMP MILL P OBM SO Wt. 100K PU Wt. 145K ROT 60 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Mill F/ 7,424.3' T/ 7,424.5' PP= 1950 SPM= 85 WOB= 3K TQ= 6500 - 8500 Pound on it x 13 7,424.3 7,424.5 5/31/2023 14:30 5/31/2023 16:30 2.00 COMPZN, RPCOMP MILL P OBM SO Wt. 100K PU Wt. 145K ROT 60 RPM @ 6.2K Tq 87 spm ( 5 bbl/min ) @ 1890psi Mill F/ 7,424.5' T/ 7,424.7' PP= 1950 SPM= 85 WOB= 3K TQ= 6500 - 8500 Pound on it x 6 7,424.5 7,424.7 5/31/2023 16:30 5/31/2023 18:00 1.50 COMPZN, RPCOMP CIRC P Circulate SxS 7,424.7 7,410.0 5/31/2023 18:00 5/31/2023 18:30 0.50 COMPZN, RPCOMP OWFF P OWFF no flow // Pump dry job 7,410.0 7,410.0 5/31/2023 18:30 5/31/2023 21:30 3.00 COMPZN, RPCOMP TRIP P TOOH to inspect tools 7,410.0 230.0 5/31/2023 21:30 5/31/2023 22:00 0.50 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 230.0 0.0 5/31/2023 22:00 5/31/2023 22:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 14 0.0 230.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 14/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/31/2023 22:30 5/31/2023 23:00 0.50 COMPZN, RPCOMP SVRG P Service rig blocks and TD 230.0 230.0 5/31/2023 23:00 6/1/2023 00:00 1.00 COMPZN, RPCOMP TRIP P Tip in hole w/ 6-1/8" junk mill w/ 1.5" pass through in middle of mill 230.0 2,500.0 6/1/2023 00:00 6/1/2023 01:45 1.75 COMPZN, RPCOMP TRIP P Tip in hole w/ 6-1/8" junk mill w/ 1.5" pass through in middle of mill 2,500.0 7,407.0 6/1/2023 01:45 6/1/2023 03:00 1.25 COMPZN, RPCOMP CIRC P Circulate SxS ensure mud good for milling 7,407.0 7,407.0 6/1/2023 03:00 6/1/2023 06:00 3.00 COMPZN, RPCOMP MILL P Obtain Free spin parameters Rot= 62 rpm TQ= 5900 Up wt.= 157K Dn wt.= 99K SPM= 20 PP= 875 Start milling 7423' 6800 tq WOB 16K 7,407.0 7,423.0 6/1/2023 06:00 6/1/2023 09:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 83 rpm TQ= 5,949 ft/ Rot Up wt.= 145 K Dn wt.= 98 K SPM= 0 Pressure = 0 Start milling 7423' 6,990 tq WOB 22 K 7,423.0 6/1/2023 09:00 6/1/2023 12:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 63 rpm TQ= 6,600 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 0 Preassure = 0 Start milling F/ 7424.3' 6,660 tq WOB 36 K 7,423.5 7,423.5 6/1/2023 12:00 6/1/2023 15:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 99 rpm TQ= 6,300 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 88, 5 bpm, Pressure = 2,027 Start milling F/7424' 6,660 tq WOB 36 K 7,423.5 7,424.0 6/1/2023 15:00 6/1/2023 16:30 1.50 COMPZN, RPCOMP MILL P On bottom Milling Rot= 65 rpm TQ= 6,500 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 88, 5 bpm, Pressure = 2,027 No Rot PUW = 151 k No Rot SOW = 95 k Start milling F/7425' 6,660 tq WOB 36 K *** Note: No forward progress, mix dry job 1.5# 10 bbl 7,424.0 7,424.0 6/1/2023 16:30 6/1/2023 18:30 2.00 COMPZN, RPCOMP SLPC P Cut and slip drill line 7,404.0 7,404.0 6/1/2023 18:30 6/1/2023 21:30 3.00 COMPZN, RPCOMP TRIP P TOOH to inspect BHA 7,404.0 230.0 6/1/2023 21:30 6/1/2023 22:00 0.50 COMPZN, RPCOMP BHAH P Lay down and inspect BHA 230.0 0.0 6/1/2023 22:00 6/1/2023 22:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 15 // 4.75" 3-blade junk mill , 2 junk baskets, 6-1/8" string mill, 6 drill collars, bumper sub and oil jars // 0.0 230.0 6/1/2023 22:30 6/2/2023 00:00 1.50 COMPZN, RPCOMP TRIP P TIH w/ BHA# 15 230.0 3,700.0 6/2/2023 00:00 6/2/2023 01:30 1.50 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 15 3,700.0 7,348.0 6/2/2023 01:30 6/2/2023 02:00 0.50 COMPZN, RPCOMP CIRC P Cir B/U 5 BPM @ 2000 psi 7,348.0 7,348.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 15/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/2/2023 02:00 6/2/2023 06:00 4.00 COMPZN, RPCOMP MILL P Obtain Free spin parameters dry tag top of fish @ 7,424' ROT = 100 TQ= 6,200 SPM= 25 PP= 940 Up wt.= 155K Dn wt.= 97K Mill ahead F/ 7,424' T/ 7,422.8' WOB= 10 TQ= 6700 ROT= 100 7,348.0 7,422.8 6/2/2023 06:00 6/2/2023 09:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 65 rpm TQ= 6,500 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 88, 5 bpm, Pressure = 2,027 No Rot PUW = 151 k No Rot SOW = 95 k Start milling F/7425' WOB 10 K *** Note: Stall out, PUH 175 k, pipe moving 7,422.8 7,424.5 6/2/2023 09:00 6/2/2023 12:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 60 rpm TQ= 6,763 ft/lbs, Rot Up wt.= 162 K Rot Dn wt.= 98 K SPM= 65-80, 5 bpm, Pressure = 969 No Rot PUW = 151 k No Rot SOW = 95 k Start milling F/7425' WOB 6 K 7,424.5 7,424.5 6/2/2023 12:00 6/2/2023 13:30 1.50 COMPZN, RPCOMP MILL P On bottom Milling Rot= 80 rpm TQ= 6,275 ft/lbs, Rot Up wt.= 140 K Dn wt.= 98 K SPM= 88, 5 bpm, Pressure = 2,027 No Rot PUW = 151 k No Rot SOW = 95 k Start milling F/7425' WOB 13 K 7,424.5 7,424.8 6/2/2023 13:30 6/2/2023 16:00 2.50 COMPZN, RPCOMP TRIP P TOOH to inspect BHA 7,424.8 235.0 6/2/2023 16:00 6/2/2023 17:00 1.00 COMPZN, RPCOMP BHAH P Stand back DC's, LD & inspect milling assembly 235.0 0.0 6/2/2023 17:00 6/2/2023 18:00 1.00 COMPZN, RPCOMP BHAH P Pick up BHA# 16 Piranha mill 0.0 235.0 6/2/2023 18:00 6/2/2023 20:30 2.50 COMPZN, RPCOMP TRIP P TIH w/ BHA# 16 235.0 7,420.0 6/2/2023 20:30 6/2/2023 21:00 0.50 COMPZN, RPCOMP SVRG P Service TD and Blocks 7,420.0 7,420.0 6/2/2023 21:00 6/3/2023 00:00 3.00 COMPZN, RPCOMP MILL P Obtain Free spin parameters dry tag top of fish @ 7,424' ROT = 100 TQ= 6,200 SPM= 25 PP= 940 Up wt.= 147K Dn wt.= 90K Mill ahead F/ 7,422' T/ 7424 WOB= 10 TQ= 6700 ROT= 100 7,425.0 7,424.0 6/3/2023 00:00 6/3/2023 06:00 6.00 COMPZN, RPCOMP MILL P Obtain Free spin parameters dry tag top of fish @ 7,424' ROT = 100 TQ= 6,200 SPM= 25 PP= 940 Up wt.= 147K Dn wt.= 90K Mill ahead F/ 7,424' T/ 7,425' WOB= 10 TQ= 6,700 - 9500 ROT= 100 7,424.0 7,426.2 6/3/2023 06:00 6/3/2023 09:00 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 80 rpm TQ= 6,700 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 26, 1.3 bpm, Pressure = 950 No Rot PUW = 151 k No Rot SOW = 93 k WOB 30 K 7,426.2 7,427.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 16/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/3/2023 09:00 6/3/2023 10:30 1.50 COMPZN, RPCOMP MILL P On bottom Milling Rot= 80 rpm TQ= 6,400 ft/lbs, Rot Up wt.= 110 K Dn wt.= 98 K SPM= 85, 5.0 bpm, Pressure = 1,971 No Rot PUW = 151 k No Rot SOW = 93 k WOB 15 K 7,427.0 7,429.0 6/3/2023 10:30 6/3/2023 13:30 3.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 78 rpm TQ= 7,271 ft/lbs, Rot Up wt.= 81 K Dn wt.= 98 K SPM= 87, 5.2 bpm, Pressure = 2,375 No Rot PUW = 151 k No Rot SOW = 93 k WOB 30 K 7,429.0 7,430.0 6/3/2023 13:30 6/3/2023 14:30 1.00 COMPZN, RPCOMP MILL P On bottom Milling Rot= 79 rpm TQ= 6,830 ft/lbs, Rot Up wt.= 98 K Dn wt.= 80 K SPM= 00, 0.0 bpm, Pressure = 126 No Rot PUW = 151 k No Rot SOW = 93 k WOB 30 K *** Note:Recep pipe up hole, pull tight @ 7,420', Work pipe free @ 250 k 7,430.0 7,431.0 6/3/2023 14:30 6/3/2023 16:15 1.75 COMPZN, RPCOMP MILL P Work back to bottom Rot= 80 rpm TQ= 5,400 ft/lbs, Rot Up wt.= 98 K Dn wt.= 80 K SPM= 88, 5.2 bpm, Pressure = 2,875 No Rot PUW = 110 k No Rot SOW = 95 k WOB 30 K *** Note: Unable to make progress Pump dry job, LD single Blow down Top Drive 7,431.0 7,431.0 6/3/2023 16:15 6/3/2023 19:15 3.00 COMPZN, RPCOMP TRIP P TOOH with BHA #15 7,431.0 230.0 6/3/2023 19:15 6/3/2023 20:00 0.75 COMPZN, RPCOMP BHAH P Lay down BHALay down boot baskets clean out and clean out mills 230.0 0.0 6/3/2023 20:00 6/3/2023 20:15 0.25 COMPZN, RPCOMP CLEN P Clean rig floor for TIH 0.0 0.0 6/3/2023 20:15 6/3/2023 20:45 0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 17 0.0 230.0 6/3/2023 20:45 6/3/2023 21:15 0.50 COMPZN, RPCOMP SVRG P Service crown, blocks, TD 230.0 230.0 6/3/2023 21:15 6/4/2023 00:00 2.75 COMPZN, RPCOMP TRIP P TIH w/ BHA# 16 230.0 4,000.0 6/4/2023 00:00 6/4/2023 01:15 1.25 COMPZN, RPCOMP TRIP P TIH w/ BHA# 16 4,000.0 7,407.0 6/4/2023 01:15 6/4/2023 02:45 1.50 COMPZN, RPCOMP CIRC P Circulate B/U to clean up aired up mud 7,407.0 7,407.0 6/4/2023 02:45 6/4/2023 06:00 3.25 COMPZN, RPCOMP MILL P Dry tag top of fish 7430' Start milling 7430' SPM= 87 PP= 2000 ROT= 91 TQ= 6500 free 7,430.0 7,432.0 6/4/2023 06:00 6/4/2023 09:00 3.00 COMPZN, RPCOMP MILL P OBM Rot= 80 rpm TQ= 5,300 ft/lbs, Rot Up wt.= 145 K Dn wt.= 98 K SPM= 26, 1.3 bpm, Pressure = 950 No Rot PUW = 151 k No Rot SOW = 89 k WOB 26 K 7,432.0 7,433.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 17/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/4/2023 09:00 6/4/2023 12:00 3.00 COMPZN, RPCOMP MILL P OBM Rot=75 rpm, TQ=7,250 ft/lbs, Stks/min=88, 5.0 bpm, Pressure=1972 psi WOB=30k 7,433.0 7,434.0 6/4/2023 12:00 6/4/2023 15:00 3.00 COMPZN, RPCOMP MILL P OBM Rot=75 rpm, TQ=7,600 ft/lbs, Stks/min=88, 5.0 bpm, Pressure=1972 psi WOB=35k 7,434.0 7,436.0 6/4/2023 15:00 6/5/2023 00:00 9.00 COMPZN, RPCOMP MILL P OBM Rot=80 rpm, TQ=6,700 ft/lbs, Stks/min=36, 2.0 bpm, Pressure=1,050 psi WOB=12k 7,436.0 7,448.0 6/5/2023 00:00 6/5/2023 01:15 1.25 COMPZN, RPCOMP MILL P OBM Rot=80 rpm, TQ=6,700 ft/lbs, Stks/min=36, 2.0 bpm, Pressure=1,050 psi WOB=12k 7,448.0 7,451.0 6/5/2023 01:15 6/5/2023 02:15 1.00 COMPZN, RPCOMP CIRC P Circulate SxS // Pump sweep clean up hole 7,451.0 7,451.0 6/5/2023 02:15 6/5/2023 02:45 0.50 COMPZN, RPCOMP OWFF P OWFF // No flow 7,411.0 7,411.0 6/5/2023 02:45 6/5/2023 05:45 3.00 COMPZN, RPCOMP TRIP P Pull 5 stands pump dry job // TOOH for burn shoe BHA 7,411.0 225.0 6/5/2023 05:45 6/5/2023 06:15 0.50 COMPZN, RPCOMP BHAH P Stand back DC, brake down BHA and inspect Piranha Mill is heavly cored out with damage to face Wash pipe slabs, threads, and debris returned from boot baskets 225.0 0.0 6/5/2023 06:15 6/5/2023 07:45 1.50 COMPZN, RPCOMP BHAH P MU burn shoe, 6 jts wash pipe (5-3/4" OD), drive sub, boot basket x 2, bumper sub, jars, and 6 DC (4-3/4"OD) Float in string 0.0 416.6 6/5/2023 07:45 6/5/2023 10:45 3.00 COMPZN, RPCOMP TRIP P TIH w/BHA #18 416.6 7,445.0 6/5/2023 10:45 6/5/2023 12:00 1.25 COMPZN, RPCOMP CIRC P Circulate BU to conditon fluid in the hole 7,445.0 7,445.0 6/5/2023 12:00 6/5/2023 15:00 3.00 COMPZN, RPCOMP MILL P Obtain pump parameters Rot=64 rpm, TQ=6,300 ft/lbs, Stks/min=52, 2.5 bpm, Pressure=1,733 psi WOB=10k OA pressure 380 psi 7,445.0 7,459.4 6/5/2023 15:00 6/6/2023 00:00 9.00 COMPZN, RPCOMP MILL P OBM Increase pump rate Rot=82 rpm, TQ=6,100 ft/lbs, Stks/min=87, 5.0 bpm, Pressure=2,200 psi 7,459.4 7,487.0 6/6/2023 00:00 6/6/2023 05:00 5.00 COMPZN, RPCOMP MILL P OBM Increase pump rate Rot=82 rpm, TQ=6,100 ft/lbs, Stks/min=87, 5.0 bpm, Pressure=2,200 psi 7506' encounter 100 bbl/ hr loss 7,487.0 7,506.0 6/6/2023 05:00 6/6/2023 06:30 1.50 COMPZN, RPCOMP CIRC P Pick up above fish check for flow // Circulate SxS establish static loss rate // 10 bbl / hr loss rate reducing to no losses 7,506.0 7,443.0 6/6/2023 06:30 6/6/2023 07:00 0.50 COMPZN, RPCOMP OWFF P OWFF no flow 7,443.0 7,443.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 18/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/6/2023 07:00 6/6/2023 07:30 0.50 COMPZN, RPCOMP PRTS P Test casing 500 psi good test 7,443.0 7,443.0 6/6/2023 07:30 6/6/2023 08:00 0.50 COMPZN, RPCOMP CIRC P CBU @ 5 BPM 2200 PSI Wash DN F/7,433' T/7,517' 7,433.0 7,517.0 6/6/2023 08:00 6/7/2023 00:00 16.00 COMPZN, RPCOMP MILL P Mill F/7,517' T/7,544' 3 BPM 2250 PSI 80 RPM 6K TQ off 7-8K TQ on WOB15-20K 145K UP 85K DN 105K ROT 7,517.0 7,544.0 6/7/2023 00:00 6/7/2023 02:30 2.50 COMPZN, RPCOMP MILL P Mill F/7,544' T/7,545' 2-3 BPM 1650/2250 PSI 80 RPM 6K TQ off 7-8K TQ on WOB15-30K 145K UP 85K DN 105K ROT 7,544.0 7,545.0 6/7/2023 02:30 6/7/2023 04:00 1.50 COMPZN, RPCOMP CIRC P Circ sweep around 3.5 BPM 2130 PSI 70 RPM 4600 TQ Stand one stand back T/7,506' 7,545.0 7,506.0 6/7/2023 04:00 6/7/2023 06:00 2.00 COMPZN, RPCOMP OWFF P OWFF - B/D top drive. Fingerprinted flow back. Formation ballooned from injection during milling operations rate decreased in flow rate. 3.9 BBL's in 15 minutes to .6 BBL's in 1.5 HRS. Pulled 4 stands. OWFF for 30 minutes. 7,506.0 7,506.0 6/7/2023 06:00 6/7/2023 06:15 0.25 COMPZN, RPCOMP CIRC P Pumped 10 BBL 15.1# LSND dry job. allow slug to fall. 7,506.0 7,102.0 6/7/2023 06:15 6/7/2023 10:30 4.25 COMPZN, RPCOMP TRIP P TOOH F/7,102' T/416.6' 7,102.0 416.6 6/7/2023 10:30 6/7/2023 11:45 1.25 COMPZN, RPCOMP BHAH P Stand back collars and wash pipe BHA. Approximately 25' of rock recovered in wash pipe 416.6 0.0 6/7/2023 11:45 6/7/2023 12:15 0.50 COMPZN, RPCOMP WAIT T Discuss the options with town for moving forward. 0.0 0.0 6/7/2023 12:15 6/7/2023 14:15 2.00 COMPZN, RPCOMP CLEN T Clear floor, 0.0 0.0 6/7/2023 14:15 6/7/2023 16:15 2.00 COMPZN, RPCOMP BHAH T Move collars from off drillers side to driller side of rig floor. LD BHA and wash pipe prep to TIH with DP. 0.0 0.0 6/7/2023 16:15 6/7/2023 19:30 3.25 COMPZN, RPCOMP TRIP T TIH with mule shoe on DP F/surface T/7,447' 135K UP 100K DN 0.0 7,447.0 6/7/2023 19:30 6/7/2023 20:45 1.25 COMPZN, RPCOMP CIRC T Circualte well to condition mud for slickline and caliper. Stage pumps up to 5 BPM 2060 PSI Start losing mud at 5 BPM, slow pumps down to 4 BPM 7,447.0 7,447.0 6/7/2023 20:45 6/8/2023 00:00 3.25 COMPZN, RPCOMP RURD T POOH T/7,288', B/D top drive, FL CK R/U slickline to RIH with drift run. 7,447.0 7,288.0 6/8/2023 00:00 6/8/2023 01:00 1.00 COMPZN, RPCOMP SLKL T R/U slick line for drift and caliper run 7,288.0 7,288.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 19/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/8/2023 01:00 6/8/2023 03:45 2.75 COMPZN, RPCOMP SLKL T RIH with slickline 2.07" baited drift on GR to tag at 7,510' first time and 7,498' second set down POOH 7,288.0 7,288.0 6/8/2023 03:45 6/8/2023 04:15 0.50 COMPZN, RPCOMP SLKL T L/D drift BHA P/U 24 finger extended caliper tool 7,288.0 7,288.0 6/8/2023 04:15 6/8/2023 11:30 7.25 COMPZN, RPCOMP SLKL T RIH on slick line Tag up at 7498' and 7508' SLMD Log caliper F/7490' T/7288' bottom of DP. 7,288.0 7,288.0 6/8/2023 11:30 6/8/2023 13:30 2.00 COMPZN, RPCOMP CIRC T Circulate while Caliper data processing analyzed. 7,288.0 7,288.0 6/8/2023 13:30 6/8/2023 14:30 1.00 COMPZN, RPCOMP SLKL T RD Slickline 7,288.0 7,288.0 6/8/2023 14:30 6/8/2023 16:00 1.50 COMPZN, RPCOMP CIRC T Circulate while plan is formulated. 7,288.0 7,288.0 6/8/2023 16:00 6/8/2023 17:30 1.50 COMPZN, RPCOMP SLPC T Slip and cut drilling line. Service rig 7,288.0 7,288.0 6/8/2023 17:30 6/8/2023 18:45 1.25 COMPZN, RPCOMP CIRC T Circulate condtion mud 4.5 BPM 1700 PSI 7,288.0 7,288.0 6/8/2023 18:45 6/8/2023 19:15 0.50 COMPZN, RPCOMP OWFF T Blow down top drive, flow check 7,288.0 7,288.0 6/8/2023 19:15 6/8/2023 23:00 3.75 COMPZN, RPCOMP TRIP T TOOH LD mule shoe. PU test packer 7,288.0 0.0 6/8/2023 23:00 6/9/2023 00:00 1.00 COMPZN, RPCOMP TRIP T P/U test packer RIH T/772' 35K UP 35K DN 0.0 772.0 6/9/2023 00:00 6/9/2023 03:00 3.00 COMPZN, RPCOMP TRIP T RIH F/772' T/7,390'' 133K UP 100K DN 772.0 7,390.0 6/9/2023 03:00 6/9/2023 04:15 1.25 COMPZN, RPCOMP PRTS T PJSM - set test packer and test CSG P/U T/7,385' Set test packer and test casing to 2000 PSI. F/30 min COE = 7,380' 7,390.0 7,385.0 6/9/2023 04:15 6/9/2023 04:30 0.25 COMPZN, RPCOMP PRTS T Attempt to perform injectivity test down drill pipe - pump 25 STKS 1000 PSI Unset packer break circultion down DP @ 1.3 BPM 980 PSI Close rams pump down DP inject at 1 BPM 1450 PSI at 35 total STKS, pump total 2 BBLS away into formatiom @ 1 BPM 1340 PSI, pump total of 4.1 BBLS, bleed off get back 2 BBLS 7,385.0 7,385.0 6/9/2023 04:30 6/9/2023 04:45 0.25 COMPZN, RPCOMP OWFF T Flow check 7,385.0 7,385.0 6/9/2023 04:45 6/9/2023 18:15 13.50 COMPZN, RPCOMP CIRC T Circ cond mud @ 4.5 BPM 1700 PSI Service rig and equipment, prepare pits for displacement and CMT job, prep for 4 1/2" kill string 7,385.0 7,385.0 6/9/2023 18:15 6/9/2023 23:00 4.75 COMPZN, RPCOMP TRIP T Flow check, POOH F/7,385' SimOps - clean pits for brine displacement 7,385.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 20/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/9/2023 23:00 6/10/2023 00:00 1.00 COMPZN, RPCOMP BHAH T Clean rig floor, load DP space out pups SimOps - clean pits for brine displacement 0.0 0.0 6/10/2023 00:00 6/10/2023 01:00 1.00 COMPZN, RPCOMP BHAH T Pick up K-1 setting tool with 3BB CICR and 3 1/2" DP pup JTS 10.05', 10.23' T/34' SimOps - clean pits for brine displacement 0.0 34.0 6/10/2023 01:00 6/10/2023 06:00 5.00 COMPZN, RPCOMP TRIP T RIH F/34' T/7378' COE' SimOps - clean pits for brine displacement 34.0 7,378.0 6/10/2023 06:00 6/10/2023 06:30 0.50 COMPZN, RPCOMP MPSP P Space out TJ at floor set CICR at 7378' test casing to 2000 PSI for 5 minutes verify plug is set. Sting out of retainer. pick up 3' 7,378.0 7,378.0 6/10/2023 06:30 6/10/2023 07:30 1.00 COMPZN, RPCOMP PRTS P Close annular, pressure test casing to verify casing and retainer integrity; 2000 PSI for 30 minutes, charted. 7,378.0 7,378.0 6/10/2023 07:30 6/10/2023 10:00 2.50 COMPZN, RPCOMP CIRC P Sting out of retainer. Circulate well over to 9.8# NaCl. Hold pre job safety meeting simultaneously with Nabors and HES for cementing operations. 7,378.0 7,378.0 6/10/2023 10:00 6/10/2023 12:15 2.25 COMPZN, RPCOMP RURD P PUW=135K SOW=110 Sting into retainer LD single joint RU cement head pin and cement line. Flood lines from HES to rig shut in at HES block valve. PT to 5000 PSI 5 minutes PT Nabors standing iron and cement line to DP to 3500 PSI for 5 minutes. 7,378.0 7,378.0 6/10/2023 12:15 6/10/2023 12:30 0.25 COMPZN, RPCOMP CMNT P Perform injectivity test at .25/.5/.75/1/1.25/1.5/1.75 BPM .25 BPM =1960 .5 BPM=2133 .5=2216 .5 =2254 .75=2275 .75=2250 .75=2250 .75= 2245 .75=2241 1=2239 1=2239 1.25BPM=2300 1.25BPM=2350 1.5BPM =2340 1.75 BPM= 2425 1.75BPM 2440 Pump 5 BBLs at 1.75 BPM at 2440 PSI 7,378.0 7,378.0 6/10/2023 12:30 6/10/2023 14:00 1.50 COMPZN, RPCOMP CMNT P Mix water to cement at 12:35 P.M. Start DH with 12 BBLs 15.8PPG Neat class G cement at 12:46 CP=2550 PR=1.45 Drop rate to 1BPM 2250 PSI. Follow with 5 BBl fresh water spacer and 5 BBL contaminate pill. chase 6BBL's of cement to formation w/9.8# NaCl Sting out of retainer.L/D a single and TOOH 4 stands. PUH to 6,970'. allow cement to fall out of DP on top of retainer. CIP @ 13:47 HRS 7,378.0 6,970.0 6/10/2023 14:00 6/10/2023 14:45 0.75 COMPZN, RPCOMP CIRC P Circulate SxS 4000 stks flow check well. 6,970.0 6,970.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 21/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2023 14:45 6/10/2023 15:00 0.25 COMPZN, RPCOMP OWFF P OWFF DP lighter than backside.Well out of balance, screw into DP W/topdrive. 6,970.0 6,970.0 6/10/2023 15:00 6/10/2023 15:45 0.75 COMPZN, RPCOMP CIRC P Circ SxS 2nd time balance well. 6,970.0 6,970.0 6/10/2023 15:45 6/10/2023 16:15 0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 6,970.0 6,970.0 6/10/2023 16:15 6/10/2023 20:00 3.75 COMPZN, RPCOMP RURD P RD from cementing operations and flush stack and cementing manifold. Bring on clean brine to pits 6,970.0 6,970.0 6/10/2023 20:00 6/10/2023 22:45 2.75 COMPZN, RPCOMP TRIP P POOH F/6,970' T/34' 6,970.0 34.0 6/10/2023 22:45 6/10/2023 23:30 0.75 COMPZN, RPCOMP BHAH P L/D K-1 running tool and 3 1/2" DP pups 34.0 0.0 6/10/2023 23:30 6/11/2023 00:00 0.50 COMPZN, RPCOMP WOC P Wait on cement to set up SimOps - change out and test IBOP, clean pits 0.0 0.0 6/11/2023 00:00 6/11/2023 03:00 3.00 COMPZN, RPCOMP WOC P Wait on cement to set up SimOps - change out and test IBOP, clean pits 0.0 0.0 6/11/2023 03:00 6/11/2023 06:15 3.25 COMPZN, RPCOMP TRIP P P/U 3 1/2" mule shoe RIH T/7224' set down 10K circ at 2BPM 200 PSI. 0.0 7,224.0 6/11/2023 06:15 6/11/2023 06:30 0.25 COMPZN, RPCOMP RURD P RU to test casing and cement plug. 7,191.0 7,191.0 6/11/2023 06:30 6/11/2023 07:15 0.75 COMPZN, RPCOMP CIRC P Circulate BUS at 5 BPM 900 PSI while rigging up to test casing and cement plug. 7,191.0 7,191.0 6/11/2023 07:15 6/11/2023 08:00 0.75 COMPZN, RPCOMP PRTS P Pressure test casing and cement plug to 2000 PSI for 30 minutes 7:28 A.M. Initial I/O=2000/580 15 min I/O=2000/480 30 min I/O=2000/430 Bled pressure off casing. 7,191.0 7,191.0 6/11/2023 08:00 6/11/2023 08:30 0.50 COMPZN, RPCOMP RURD P R/D testing equipment, blow down top drive and test lines. 7,191.0 7,191.0 6/11/2023 08:30 6/11/2023 16:00 7.50 COMPZN, RPCOMP PULD P L/D F/7191' T/surface 7,191.0 0.0 6/11/2023 16:00 6/11/2023 17:30 1.50 COMPZN, RPCOMP RURD P Pull W/R R/U to run 4 1/2" kill string 0.0 0.0 6/11/2023 17:30 6/11/2023 20:15 2.75 COMPZN, RPCOMP PUTB P RIH with 4 1/2" kill string T/1,897' 0.0 1,897.0 6/11/2023 20:15 6/11/2023 21:15 1.00 COMPZN, RPCOMP THGR P Make up 4 1/2" HYD 563 pup JTS for landing JT, Make up hanger and landing JT to string Flow check Drain stack Land TBG RILDS 1,897.0 1,926.0 6/11/2023 21:15 6/11/2023 21:45 0.50 COMPZN, RPCOMP MPSP P Make breaks on landing joint and lay down Install BPV 1,926.0 0.0 6/11/2023 21:45 6/11/2023 22:30 0.75 COMPZN, WHDBOP WWWH P Flush stack with H20 Blow down all lines 0.0 0.0 6/11/2023 22:30 6/12/2023 00:00 1.50 COMPZN, WHDBOP SVRG P Perform CPAI BWM SimOps clean pits and under rotary table and pipe rack drains 0.0 0.0 6/12/2023 00:00 6/12/2023 02:30 2.50 COMPZN, WHDBOP SVRG P Perform CPAI BWM SimOps clean pits 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Page 22/22 3N-19 Report Printed: 6/27/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2023 02:30 6/12/2023 04:00 1.50 COMPZN, WHDBOP NUND P N/D BOP and lines, N/U tree, test hanger void to 5000 PSI 10 min SimOps clean pits and under rotary table, and pipe racks 0.0 0.0 6/12/2023 04:00 6/12/2023 05:00 1.00 COMPZN, WHDBOP PRTS P R/U to freeze protect 7" x 4 1/2" tubing and annulus Test lines and tree to 5000 PSI SimOps clean under rig floor and pits 0.0 0.0 6/12/2023 05:00 6/12/2023 05:30 0.50 COMPZN, WHDBOP MPSP P Pull BPV 0.0 0.0 6/12/2023 05:30 6/12/2023 07:00 1.50 DEMOB, MOVE FRZP P Pump 70 BBLS with LRS at 5 BPM 800 PSI Shut down, suck back, blow down lines Final Pressures 0 PSI on TBG 0PSI on IA 230 PSI on OA 0.0 0.0 6/12/2023 07:00 6/12/2023 13:00 6.00 DEMOB, MOVE RURD P R/D lines, clean up around cellar, secure well, clean pits Rig released at 12:00 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 6/12/2023 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: CTMD 10,030.0 3N-19 1/31/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut & pulled fish 3N-19 5/19/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Nipple Reducer @ 7,757' RKB is comprimised (Is not locked in, moves up, and will not test)4/6/2018 famaj NOTE: WORKED TOOLS, POOH W/ PLUG BODY. NIPPLE REDUCER INTEGRITY SUSPECT.2/21/2018 pproven NOTE: SUSPECTING THAT NIPPLE REDUCER PULLED OUT OF PROFILE 2/21/2018 pproven NOTE: PULLED HEAVIER THAN EXPECTED WHILE POOH W/ 1.81" PLUG & HUNG UP IN PATCH @ 7423' RKB; 2/21/2018 pproven NOTE: WHEN PULLING 1.81" CA-2 PLUG @ 7757' RKB 2/21/2018 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 9/8/2009 lmosbor 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 30.0 150.0 150.0 62.50 H-40 WELDED SURFACE 9 5/8 8.84 29.7 3,649.1 3,620.7 40.00 L-80 BTC PRODUCTION 7 6.28 28.0 8,755.8 6,461.2 26.00 L-80 BTC-Mod LINER 3 1/2 2.99 8,571.6 10,488.0 6,446.0 9.30 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.0 Set Depth … 1,926.0 Set Depth… 1,904.0 String Ma… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 25.0 25.0 0.06 Hanger 11.000 FMC hanger 4.5" x 11" HYD 563 topop and bottom FMC Gen 5 4.000 Top (ftKB) 7,420.1 Set Depth … 8,600.6 Set Depth… 6,454.1 String Ma… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,426.1 6,164.3 52.04 GAS LIFT 5.968 3-1/2" X 1-1/2" MMG GLM w/ RP shear valve, RK Latch Camco MMG 2.920 7,633.8 6,282.7 59.17 PBR 5.870 Baker 12' 80-40 PBR w/ 12' seals inside Baker 80-40 3.000 7,647.5 6,289.7 59.68 PACKER 5.968 7", 26# FHL Retrievable Packer Baker FHL 3.000 7,757.4 6,341.9 63.60 SLEEVE-O 4.520 BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.812" ID (CLOSED 11/17/2017) 2.81" x 1.81" Nipple reducer set 02/05/18 Baker CMU 1.810 7,934.0 6,408.3 72.76 SLEEVE-O 4.520 BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.75" ID (CLOSED 11/17/2017) Baker CMU 2.750 8,572.8 6,454.6 91.49 LOCATOR 5.000 LOCATOR SUB Baker 3.000 8,574.0 6,454.6 91.45 SEAL ASSY 5.870 Baker 80-40 Seal Assembly Baker 80-40 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,378.0 6,134.5 51.50 CEMENT RETAINER Baker 3BB CICR, set at 7,378' tested to 2000 PSI, put 6 BBLS CMT on top, 6 BBLS CMT under Baker Hughes 3BB H4002 13BB9 0STD 6/10/2023 0.000 7,423.0 6,162.4 52.01 PATCH OWEN XSPAN PATCH OAL 22.4' 2/16/2018 2.259 7,426.0 6,164.2 52.04 LEAK LEAK FOUND AT ~7440 THE BOTTOM PUP OF GLM #5 (7426 RKB) 10/9/2017 2.992 7,612.0 6,271.4 58.35 CUT 2" RCT TBG CUT AT 7612' RKB 4/29/2023 2.992 7,614.0 6,272.5 58.43 CUT 2" RCT (EXTENDED) TBG CUT AT 7614' RKB 5/17/2023 2.992 7,662.0 6,297.0 60.23 SAND Dump bailed 10' of Safe Carb on top of HEX plug 4/26/2023 0.000 7,671.8 6,301.8 60.58 TUBING PLUG INTERWELL 1.81" HEX PLUG, MOE = 7675', OAL = 5.86' INTERW ELL HEX 3/31/2023 0.000 7,757.4 6,341.9 63.59 NIPPLE REDUCER 2.81" X 1.81" "D-PROFILE" SET IN THE SLIDING SLEEVE PROFILE 2/5/2018 1.810 8,615.0 6,454.0 90.23 VALVE BAKER KNOCKOUT ISOLATION VALVE (KOIV) MILLED OUT 4/26/2002 1/3/2002 10,488.0 6,446.0 91.66 FISH FISH LOST DURING DRILLING & COMPLETION 1/10/2002 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,571.6 6,454.7 91.52 PACKER 5.750 Baker ZXP Packer & Tie Back Sleeve 5.250 8,594.7 6,454.2 90.84 PBR 5.000 Baker 80-40 Polished Bore Receptacle Baker 80-40 4.000 8,606.9 6,454.0 90.47 XO 5x3.5" 5.000 XO - 5" L-80 Stub ACME x 3-1/2" L-80 EUE 8rd 2.992 8,617.4 6,454.0 90.16 XO 4.5x3" 4.500 XO- 4-1/2" SLHT box x 3-1/2" EUE 8rd Pin 2.992 3N-19, 6/29/2023 1:00:46 PM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 VALVE; 8,615.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 CEMENT RETAINER; 7,378.0 Plug – Plug Back / Abandonment Plug; 7,224.0 ftKB SURFACE; 29.7-3,649.1 CONDUCTOR; 30.0-150.0 Hanger; 25.0 KUP PROD KB-Grd (ft) 62.56 RR Date 1/17/2002 Other Elev… 3N-19 ... TD Act Btm (ftKB) 10,515.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305600 Wellbore Status PROD Max Angle & MD Incl (°) 97.97 MD (ftKB) 9,743.44 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 200 Date 1/24/2017 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,453.6 6,447.0 91.66 BUSHING 3.500 Pack-off bushing 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,850.0 7,860.0 6,380.0 6,383.7 A-3, 3N-19 1/14/2002 6.0 IPERF 4.5" BHC, 60 deg phase 9,182.0 10,454.0 6,463.9 6,446.9 A-2, A-3, A-6, A- 5, A-3, 3N-19 1/10/2002 99.0 IPERF SLOTTED LINER Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,850.0 7,860.0 1 4/22/2002 154,000.0 0.0 0.00 0.00 3N-19, 6/29/2023 1:00:49 PM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 VALVE; 8,615.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 CEMENT RETAINER; 7,378.0 Plug – Plug Back / Abandonment Plug; 7,224.0 ftKB SURFACE; 29.7-3,649.1 CONDUCTOR; 30.0-150.0 Hanger; 25.0 KUP PROD 3N-19 ... WELLNAME WELLBORE 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10515'10488' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Adam Klem adam.klem@conocophillips.com 907-263-4529 RWO/CTD Engineer Tubing Grade: Tubing MD (ft): 7648'MD and 6283' TVD 8572' MD and 6455'TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 8601' 6/9/2023 Packer: FHL Retrievable Packer: Baker ZXP SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025520 201-225 P.O. Box 100360, Anchorage, AK 99510 50-02923056-00-00 ConocoPhillips Alaska, Inc. KRU 3N-19 Kuparuk River Oil Pool Kuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6445' 10030' 6434 3855 7672' MD 150' 3621' 150' 3649' 6461'8756' 16" 9-5/8" 120' 3619' Perforation Depth MD (ft): 7850-7860', 9182-10454' 8728' 3-1/2" 6380-6384', 6464-6447' 10488'1916' 3-1/2" 6446' 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:23 pm, Jun 12, 2023 323-339 Adam Klem Digitally signed by Adam Klem Date: 2023.06.09 15:05:47 -08'00' 10-407 SFD 6/12/2023 6/9/2023 SFD DSR-6/12/23 X BOP test pressure to 4000 psig Annular preventer test to 2500 psig X X VTL 6/26/2023JLC 6/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.27 14:23:58 -05'00'06/27/23 RBDMS JSB 062823 3N-19 RWO Procedure Kuparuk Producer RWO PTD #201-225 Page 1 of 3 Remaining Pre-Rig Work 1. Pull patches 2. SBHP 3. Set Hex plug in 3-1/2” tubing ~7675’ RKB, below the FHL packer 4. Open lowest GLM in upper completion. 5. Chem/RCT cut the tubing nominally at ~7612’ RKB in the middle of the full joint above the Baker FHL Packer. 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3N-19. (No BPV will be installed pre-rig due to internal risk assessment for N7ES.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. Completed work to here New Steps already completed: 5. RIH with test packer on drillpipe to 7380’ MD 6. Set packer at 7380’ MD. Test casing from 7380’ to surface to 2000psi for 10 min 7. Perform injectivity test below packer to determine ability to squeeze cement below cement retainer Dropped Steps 8. Pull 3-1/2” tubing down to tubing cut above packer (~7647’ RKB). Cleanout Run 9. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary. Install in 3-½” Tubing with Stack Packer 10. MU 3 ½” completion with overshot, packer, GLMs, and nipple profile. 11. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. Set Packer. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. New Steps to be completed: 14. RIH w/ cement retainer to 7380’. Set cement retainer 15. Sting out of cement retainer & pressure test 16. Displace DP and casing to 9.8 brine 17. Sting back into cement retainer and establish injection 18. Squeeze any cement we can below cement retainer. 19. Sting out of cement retainer 20. Spot 100’ of cement above cement retainer 21. Circulate pipe clean 3N-19 RWO Procedure Kuparuk Producer RWO PTD #201-225 Page 2 of 3 22. WOC. Tag top of cement 23. Hang off 4.5” kill string to ~2200’ MD ND BOP, NU Tree 24. Confirm pressure test 25. Install BPV. 26. ND BOPE. NU tree 27. Pull BPV, freeze protect well 28. RDMO. Post-Rig Work 29. Pull all plugs from tubing string and install GLD 30. Turn over to operations 31. Prepare well for future workover sidetrack General Well info: Wellhead type/pressure rating: FMC Gen III Production Engineer: Kaylie Plunkett Reservoir Development Engineer: Doug Valentine Estimated Start Date: 5/7/23 Workover Engineer: James Ohlinger (265-1102 James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the planned cut at 7612’ RKB, install a new 3-1/2” completion with stacked packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 8/23/2020, Failed TIFL 3/22/2022 CMIT-TxIA Passed 7/8/22 MIT-OA N/A IC POT &PPPOT PASSED – 01/09/23 TBG POT &PPPOT PASSED – 01/09/23 MPSP: 3132 psi using 0.1 psi/ft gradient Static BHP: 3747 psi / 6148’ TVD measured on 07/07/2022 VTL 06/26/2023 State witnessed pressure test and tag required. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: CTMD 10,030.0 3N-19 1/31/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut & pulled fish 3N-19 5/19/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Nipple Reducer @ 7,757' RKB is comprimised (Is not locked in, moves up, and will not test)4/6/2018 famaj NOTE: WORKED TOOLS, POOH W/ PLUG BODY. NIPPLE REDUCER INTEGRITY SUSPECT.2/21/2018 pproven NOTE: SUSPECTING THAT NIPPLE REDUCER PULLED OUT OF PROFILE 2/21/2018 pproven NOTE: PULLED HEAVIER THAN EXPECTED WHILE POOH W/ 1.81" PLUG & HUNG UP IN PATCH @ 7423' RKB; 2/21/2018 pproven NOTE: WHEN PULLING 1.81" CA-2 PLUG @ 7757' RKB 2/21/2018 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.09/8/2009 lmosbor 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 30.0150.0150.062.50 H-40 WELDED SURFACE 9 5/8 8.84 29.7 3,649.1 3,620.7 40.00 L-80 BTC PRODUCTION 7 6.28 28.08,755.86,461.226.00 L-80 BTC-Mod LINER 3 1/22.99 8,571.610,488.06,446.09.30 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,420.1 Set Depth … 8,600.6 Set Depth… 6,454.1 String Ma… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,426.1 6,164.3 52.04 GAS LIFT 5.968 3-1/2" X 1-1/2" MMG GLM w/ RP shear valve, RK Latch Camco MMG 2.920 7,633.8 6,282.7 59.17 PBR 5.870 Baker 12' 80-40 PBR w/ 12' seals inside Baker 80-403.000 7,647.5 6,289.7 59.68 PACKER 5.968 7", 26# FHL Retrievable Packer Baker FHL 3.000 7,757.4 6,341.9 63.60 SLEEVE-O 4.520 BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.812" ID (CLOSED 11/17/2017) 2.81" x 1.81" Nipple reducer set 02/05/18 Baker CMU 1.810 7,934.0 6,408.3 72.76 SLEEVE-O 4.520 BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.75" ID (CLOSED 11/17/2017) Baker CMU 2.750 8,572.86,454.691.49 LOCATOR5.000 LOCATOR SUB Baker 3.000 8,574.0 6,454.6 91.45 SEAL ASSY 5.870 Baker 80-40 Seal Assembly Baker 80-40 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,423.06,162.4 52.01 PATCH OWEN XSPAN PATCH OAL 22.4' 2/16/2018 2.259 7,426.0 6,164.2 52.04 LEAK LEAK FOUND AT ~7440 THE BOTTOM PUP OF GLM #5 (7426 RKB) 10/9/2017 2.992 7,612.0 6,271.4 58.35 CUT 2" RCT TBG CUT AT 7612' RKB 4/29/2023 2.992 7,614.06,272.5 58.43CUT 2" RCT (EXTENDED) TBG CUT AT 7614' RKB 5/17/2023 2.992 7,662.0 6,297.0 60.23 SAND Dump bailed 10' of Safe Carb on top of HEX plug 4/26/20230.000 7,671.8 6,301.8 60.58 TUBING PLUG INTERWELL 1.81" HEX PLUG, MOE = 7675', OAL = 5.86' INTERW ELL HEX 3/31/20230.000 7,757.4 6,341.9 63.59 NIPPLE REDUCER 2.81" X 1.81" "D-PROFILE" SET IN THE SLIDING SLEEVE PROFILE 2/5/2018 1.810 8,615.0 6,454.0 90.23 VALVE BAKER KNOCKOUT ISOLATION VALVE (KOIV) MILLED OUT 4/26/2002 1/3/2002 10,488.06,446.091.66 FISHFISH LOST DURING DRILLING & COMPLETION 1/10/2002 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,571.66,454.7 91.52 PACKER 5.750 Baker ZXP Packer & Tie Back Sleeve 5.250 8,594.7 6,454.290.84 PBR 5.000 Baker 80-40 Polished Bore Receptacle Baker 80-40 4.000 8,606.9 6,454.0 90.47 XO 5x3.5" 5.000 XO - 5" L-80 Stub ACME x 3-1/2" L-80 EUE 8rd 2.992 8,617.4 6,454.0 90.16 XO 4.5x3" 4.500 XO- 4-1/2" SLHT box x 3-1/2" EUE 8rd Pin 2.992 10,453.66,447.091.66 BUSHING3.500 Pack-off bushing 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,850.0 7,860.06,380.06,383.7 A-3, 3N-19 1/14/2002 6.0 IPERF 4.5" BHC, 60 deg phase 9,182.010,454.06,463.96,446.9 A-2, A-3, A-6, A- 5, A-3, 3N-19 1/10/2002 99.0 IPERF SLOTTED LINER 3N-19, 6/9/2023 9:51:26 AM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 SHOE; 10,454.8-10,488.0 BUSHING; 10,453.6-10,454.8 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 FLOAT SHOE; 8,754.3-8,755.8 FLOAT COLLAR; 8,669.4- 8,670.7 VALVE; 8,615.0 PBR; 8,594.7-8,606.9 HANGER; 8,585.4-8,594.7 SEAL ASSY; 8,574.0 PACKER; 8,571.6-8,585.4 LOCATOR; 8,572.7 SLEEVE-O; 7,934.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 SLEEVE-O; 7,757.4 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 PBR; 7,633.8 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 SURFACE; 29.7-3,649.1 FLOAT SHOE; 3,647.4-3,649.1 FLOAT COLLAR; 3,566.9- 3,568.4 CONDUCTOR; 30.0-150.0 HANGER; 29.7-30.9 HANGER; 28.1-30.9 KUP PROD KB-Grd (ft) 62.56 RR Date 1/17/2002 Other Elev… 3N-19 ... TD Act Btm (ftKB) 10,515.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305600 Wellbore Status PROD Max Angle & MD Incl (°) 97.97 MD (ftKB) 9,743.44 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 200 Date 1/24/2017 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,850.0 7,860.0 1 4/22/2002 154,000.0 0.0 0.00 0.00 3N-19, 6/9/2023 9:51:29 AM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 SHOE; 10,454.8-10,488.0 BUSHING; 10,453.6-10,454.8 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 FLOAT SHOE; 8,754.3-8,755.8 FLOAT COLLAR; 8,669.4- 8,670.7 VALVE; 8,615.0 PBR; 8,594.7-8,606.9 HANGER; 8,585.4-8,594.7 SEAL ASSY; 8,574.0 PACKER; 8,571.6-8,585.4 LOCATOR; 8,572.7 SLEEVE-O; 7,934.0 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 SLEEVE-O; 7,757.4 NIPPLE REDUCER; 7,757.4 TUBING PLUG; 7,671.8 SAND; 7,662.0 PACKER; 7,647.5 PBR; 7,633.8 CUT; 7,614.0 CUT; 7,612.0 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 SURFACE; 29.7-3,649.1 FLOAT SHOE; 3,647.4-3,649.1 FLOAT COLLAR; 3,566.9- 3,568.4 CONDUCTOR; 30.0-150.0 HANGER; 29.7-30.9 HANGER; 28.1-30.9 KUP PROD 3N-19 ... WELLNAME WELLBORE 3N-19 Planned Completion COMPLETION INFO Conductor Surface Production Liner Tubing Pre-rig 2" RCT Tubing Cut ~ 7612' RKB HEX Plug ~ 7675' RKB Surface Casing Production Casing Conductor A2-sand perfs GLV 7426' Owen XSPAN Patch7423'-7445' 2.259" ID GLV 6532' Tubing Leak 7426' PBR 7634' Packer 7647' A3-sand @7850' MD perfs Pre-rig 2" RCT Tubing Cut ~ 7612' RKB Cmt Ret set at 7380'MD 100' of cement on top to 7280' On-rig 2" RCT Tubing Cut ~ 7615' RKB Top of 3.5" fish at 7420'Apparent casing exit top at C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-06-07_22542_KRU_3N-19_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22542 KRU 3N-19 50-029-23056-00 Caliper Survey w/ Log Data 07-Jun-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-225 T37757 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.19 08:34:30 -08'00' BOP test to 4000 psig Annular preventer test to 2500 psig X VTL 4/13/23 10-404 MDG 4/10/2023 DSR-4/6/23 X GCW 04/13/23JLC 4/13/2023 04/13/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.13 15:06:27 -08'00' RBDMS JSB 041423 xisting ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTEDDATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-15_22016_KRU_3N-19_LeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22016 KRU 3N-19 50-029-23056-00 Leak Detect Log 15-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-225 T36638 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.24 08:36:41 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-15_22015_KRU_3N-19_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22015 KRU 3N-19 50-029-23056-00 Caliper Survey w/ Log Data 15-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-225 T36636 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.19 10:15:38 -08'00' Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 PTD: 2012250 E-Set: 34123 Received by the AOGCC 10/16/2020 10/20/2020 Abby Bell 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address: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 10488 feet N/A feet true vertical 6446 feet N/A feet Effective Depth measured 10488 feet 7647 feet true vertical 6446 feet 6290 feet 7850 - 7860 Perforation depth Measured depth 9182 - 10454 feet 6380 - 6384 True Vertical depth 6464 - 6447 feet Tubing (size, grade, measured and true vertical depth)3.5" L-80 8601' 6454' Packers and SSSV (type, measured and true vertical depth)7" Baker FHL Retievable Packer 7647' 6290' SSSV N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/25/2020 Contact Phone: 201-225 50029230560000 ADL0025520 KRU 3N-19 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field/Kuparuk River Pool Plugs measured Junk measured Burst Collapse Conductor 120'16''150'150' 8756'6461' Surface 3619'9.625"3649'3621' Liner Production 8728'7'' N/A N/A N/A N/A N/A N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sara Carlisle / Stephanie Pilch n2549@conocophillips.com 659-7126 Well Integrity & Compliance Specialist N/A N/A N/A N/A N/A t Fra O O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:29 am, Aug 26, 2020 Matthew J Miller Digitally signed by Matthew J Miller Date: 2020.08.26 09:09:55 -08'00' DSR-8/27/2020 RBDMS HEW 8/27/2020 SFD 9/1/202010,515' VTL 11/03/20 X P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 26 August 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch extension set across a known tubing leak in producer well KRU 3N-19 (PTD 201-225) The integrity of the patch extension was confirmed with a mechanical integrity test. Please contact Stephanie Pilch, Sara Carlisle or myself at 659-7126 if you have any questions. Sincerely, Matt Miller Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Matthew J Miller Digitally signed by Matthew J Miller Date: 2020.08.26 09:09:20 -08'00' Date Event Summary Executive Summary KRU 3N-19 was found to have a Tubing leak @ 7416' md, directly above a perm patch previously set. A patch extention from the perm patch over the tubing leak was installed. The well passed both an MIT-T & CMIT-TXIA. 06/14/20 SI-TIFL (FAILED DUE TO HIGH INITIAL IA PRESSURE & FLUID LEVEL) T/I/O = SI 1050/1625/240. T FL @ SF. IA FL @ 2064' (decimeter, 4288' above st #4, OV). 08/21/20 OBTAINED PASSING CMIT TO 2500 PSI, RAN LDL & FOUND LEAK POINT @ 7413' TO 7414' RKB. JOB IN- PROGRESS. 08/23/20 SET 2.72" P2P (SN:CPP35136) W/ SPACER PIPE & NOGO STINGER IN OWENS PERM PATCH @ 7407' RKB. SET 3.5" TTS TEST TOOL IN P2P PATCH @ 7407' RKB, SET OV @ 6532' RKB, OBTAINED PASSING MIT & CMIT TO 2500 PSI, PULLED 3.5" TTS TEST TOOL @ 7407' RKB. JOB COMPLETE. Submit to: OOPERATOR: FIELD /UNIT /PA D: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 201-225 Type Inj Tubing 1575 2525 2450 2450 Type Test P Packer TVD 6290' BBL Pump 0.4 IA 625 660 660 675 Interval O Test psi 1573 BBL Return OA 150 150 150 170 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 201-225 Type Inj Tubing 2450 2575 2575 2575 Type Test P Packer TVD 6290 BBL Pump 1.2 IA 800 2500 2400 2350 Interval O Test psi 1573 BBL Return OA 180 360 340 300 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3N Pad Clayton Schmidling / Bryan Harris HES 08/23/20 Notes:MIT-T to test patch extension integrity, Non-Witnessed test. Notes: KRU 3N-19 KRU 3N-19 Notes:CMIT-TxIA to test patch extension integrity, Non-Witnessed test. Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al Int egr i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)3N-19 Patch Extension MIT data 10-426.xlsx Annular Communication Surveillance 27 Well Name:33N-19 Start Date:27-May-2020 25 Days:90 End Date:25-Aug-2020 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 1800 27-May-2030-May-202-Jun-205-Jun-208-Jun-2011-Jun-2014-Jun-2017-Jun-2020-Jun-2023-Jun-2026-Jun-2029-Jun-202-Jul-205-Jul-208-Jul-2011-Jul-2014-Jul-2017-Jul-2020-Jul-2023-Jul-2026-Jul-2029-Jul-201-Aug-204-Aug-207-Aug-2010-Aug-2013-Aug-2016-Aug-2019-Aug-2022-Aug-2025-Aug-20Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 27-May-20Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 10,030.0 1/31/2018 3N-19 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: LDL, Set Patch Extension, P&R OV. 8/23/2020 3N-19 famaj Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 150.0 Set Depth (TVD) (ftK 150.0 Wt/Len (lb/ft 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 29.7 Set Depth (ftKB) 3,649.1 Set Depth (TVD) (ftK 3,620.7 Wt/Len (lb/ft 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 28.0 Set Depth (ftKB) 8,755.8 Set Depth (TVD) (ftK 6,461.2 Wt/Len (lb/ft 26.00 Grade L-80 Top Thread BTC-Mod Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 8,571.6 Set Depth (ftKB) 10,488.0 Set Depth (TVD) (ftK 6,446.0 Wt/Len (lb/ft 9.30 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,571.6 6,454.7 91.52 PACKER Baker ZXP Packer & Tie Back Sleeve 5.250 8,585.4 6,454.3 91.11 HANGER Baker 5" x 7" Flex Lock Hanger 4.281 8,594.7 6,454.2 90.84 PBR Baker 80-40 Polished Bore Receptacle 4.000 8,606.9 6,454.0 90.47 XO 5x3.5" XO - 5" L-80 Stub ACME x 3-1/2" L-80 EUE 8rd 2.992 8,617.4 6,454.0 90.16 XO 4.5x3" XO- 4-1/2" SLHT box x 3-1/2" EUE 8rd Pin 2.992 10,453.6 6,447.0 91.66 BUSHING Pack-off bushing 2.992 Tubing Strings Tubing Description TUBING String Max No 3 1/2 ID (in) 2.99 Top (ftKB) 24.9 Set Depth (ftKB) 8,600.6 Set Depth (TVD) (ftKB 6,454.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Item Des Com Nominal ID (in) 24.9 24.9 0.06 HANGER 3-1/2" FMC Gen V Tubing Hanger 2.992 487.6 487.5 3.01 NIPPLE Camco DS nipple 2.875" ID 2.875 7,633.7 6,282.7 59.17 PBR Baker 12' 80-40 PBR w/ 12' seals inside 3.000 7,647.4 6,289.7 59.68 PACKER 7", 26# FHL Retrievable Packer 3.000 7,757.4 6,341.9 63.59 SLEEVE-O BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.812" ID (CLOSED 11/17/2017) 2.81" x 1.81" Nipple reducer set 02/05/18 1.810 7,933.9 6,408.3 72.76 SLEEVE-O BAKER CMU Sliding Sleeve w/ Camco DS profile, 2.75" ID (CLOSED 11/17/2017) 2.750 8,572.7 6,454.6 91.49 LOCATOR LOCATOR SUB 3.000 8,574.0 6,454.6 91.45 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) Top Incl (°)Des Com Run Date ID (in) SN 7,407.0 6,152.5 51.82 PATCH - UPR PKR 2.72" P2P w/ 13.5' of 2 1/16" P-110 Spacer Pipe and AVA Stinger. OAL 24' 8/23/2020 1.620 CPP35136 7,411.0 6,155.0 51.87 Spacer Pipe / AVA Stinger 2 1/6" P-110 Spacer Pipe and AVA Stinger. 8/23/2020 1.250 7,413.0 6,156.2 51.89 Tubing Leak LDL found leak at 7413'-7414' (Est. leak rate of 1.5 BPM @ 2500 PSI) 8/21/2020 2.992 7,423.0 6,162.4 52.01 PATCH OWEN XSPAN PATCH OAL 22.4' 2/16/2018 2.259 7,426.0 6,164.2 52.04 LEAK LEAK FOUND AT ~7440 THE BOTTOM PUP OF GLM #5 (7426 RKB) 10/9/2017 2.992 7,757.4 6,341.9 63.59 NIPPLE REDUCER 2.81" X 1.81" "D-PROFILE" SET IN THE SLIDING SLEEVE PROFILE 2/5/2018 1.810 8,615.0 6,454.0 90.23 VALVE BAKER KNOCKOUT ISOLATION VALVE (KOIV) MILLED OUT 4/26/2002 1/3/2002 10,488. 0 6,446.0 91.66 FISH FISH LOST DURING DRILLING & COMPLETION 1/10/2002 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,850.0 7,860.0 6,380.0 6,383.7 A-3, 3N-19 1/14/2002 6.0 IPERF 4.5" BHC, 60 deg phase 9,182.0 10,454.0 6,463.9 6,446.9 A-2, A-3, A-6, A-5, A-3, 3N-19 1/10/2002 99.0 IPERF SLOTTED LINER Frac Summary Start Date 4/22/2002 Proppant Designed (lb) 154,000.0 Proppant In Formation (lb) 154,000.0 Stg # 1 Start Date 4/22/2002 Top Depth (ftKB) 7,850.0 Btm (ftKB) 7,860.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,707.2 2,684.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,288.0 2/20/2018 2 4,159.7 4,098.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,279.0 2/20/2018 3 5,485.8 5,024.7 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,276.0 2/20/2018 4 6,531.9 5,643.7 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/23/2020 5 7,426.1 6,164.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/4/2017 High Sealab lity Packin g Notes: General & Safety End Date Annotation 4/6/2018 NOTE: Nipple Reducer @ 7,757' RKB is comprimised (Is not locked in, moves up, and will not test) 3N-19, 8/25/2020 7:24:30 AM Vertical schematic (actual) FISH; 10,488.0 LINER; 8,571.6-10,488.0 IPERF; 9,182.0-10,454.0 PRODUCTION; 28.0-8,755.8 VALVE; 8,615.0 SEAL ASSY; 8,574.0 LOCATOR; 8,572.7 SLEEVE-O; 7,933.9 Stims and Treats; 7,850.0 IPERF; 7,850.0-7,860.0 SLEEVE-O; 7,757.4 NIPPLE REDUCER; 7,757.4 PACKER; 7,647.4 PBR; 7,633.7 PATCH; 7,423.0 GAS LIFT; 7,426.1 LEAK; 7,426.0 Spacer Pipe / AVA Stinger; 7,411.0 Tubing Leak; 7,413.0 PATCH - UPR PKR; 7,407.0 GAS LIFT; 6,531.9 GAS LIFT; 5,485.8 GAS LIFT; 4,159.7 SURFACE; 29.7-3,649.1 GAS LIFT; 2,707.2 NIPPLE; 487.6 CONDUCTOR; 30.0-150.0 HANGER; 24.9 KUP PROD KB-Grd (ft) 62.56 Rig Release Date 1/17/2002 3N-19 ... TD Act Btm (ftKB) 10,515.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305600 Wellbore Status PROD Max Angle & MD Incl (°) 97.97 MD (ftKB) 9,743.44 WELLNAME WELLBORE3N-19 Annotation Last WO: End DateH2S (ppm) 200 Date 1/24/2017 Comment SSSV: NIPPLE STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMI N wiAt 4 B 20't$ REPORT OF SUNDRY WELL OPERATIONS OGCC1.Operations Abandon LI Plug Perforations LJ Fracture Stimulate LI Pull Tubing H Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑., Re-enter Susp Well ❑ Other: Tubing Patch ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑, Exploratory ❑ 201-225 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100630 Anchorage,Alaska 99510 50-029230560000 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025520 KRU 3N-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,488 feet Plugs measured feet true vertical 6446 feet Junk measured feet Effective Depth measured 10,488 feet Packer measured 7647' feet true vertical 6446 feet true vertical 6290' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 150' 150' Surface 3619' 9-5/8" 3649' 3621' Production 8728' 7" 8756' 6461' Liner Perforation depth Measured depth 7850-7860 feet 9182-10,454 SCANNED True Vertical depth 6380-6384 feet 6464-6447 Tubing(size,grade,measured and true vertical depth) 3.5" L-80 8601' 6454' Packers and SSSV(type,measured and true vertical depth) Halliburton XSpan Tubing Patch 7423'MD 6162'TVD FHL Retrievable Packer 7647'MD 6290'TVD Baker ZXP Packer 8572'MD 6455'TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 ASC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 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: Authorized Name: Travis Smith Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well IntegritySu . Contact Email: n2549Ca�conocophillips.com Authorized Signature: i 11111( y��,► Date: .... Contact Phone: 907-659-7126 lib VT- 3//6/iS Form 10-404 Revised 4/2017 RB DM j v KA,r, , ZU15 Submit Original Only I a ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 7, 2018 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for injector KRU 3N-19 (PTD 201-225) for a permanent patch set in the tubing above the packer. The integrity of the patch was confirmed with a mechanical integrity test. Please call Rachel Kautz or myself at 659-7126 if you have any questions. Sincerely, Cl de 4., ',N.. Travis Smith Well Integrity Supervisor ConocoPhillips Alaska,Inc. • DATE OPERATION DETAILS Executive KRU 3N-19 was found to have a leak near gas lift mandrel (GLM) #5 at—7440'. A permanent Summary patch was set across the leak. The well passed a MIT-T following the patch set. PERFORM BASELINE TEMPERATURE LOG FROM SURFACE TO 7755'. BEING LOGGING UP @ 10/9/2017 120 FPM LOOKING FOR LEAK. LEAK FOUND AT—7440 THE BOTTOM PUP OF GLM #5 (7426 RKB). PERFORMED STATION URVEY @ 7446'/7443'/7440'/7435'/7430'/7425'/7420'. CONTINUE LOGGING UP LOOKING FOR LEAKS. NO OTHER LEAKS FOUND. BRUSH n' FLUSH TBG TO 7800' RKB BRUSHED GLM'S & PATCH AREA FROM 7400 TO 7500' 2/5/2018 RKB.TBG OPEN 2.83"TO 7757' RKB. SET 2.81 DS x 1.81 D NIPPLE REDUCER @ 7757' RKB. SET 1.81 CA-2 PLUG @ SAME. CMIT TBG x IA 2500 PASS.SET 3 1/2 AVA CATCHER @ 7757' RKB. PULLED GLV @ 6531' RKB. IN PROGRESS. 2/6/2018 SET DV @ 6532' RKB; PULLED GLV'S&SET DV'S @ 5486' &4160' RKB; PULLED GLV @ 2707' RKB. IN PROGRESS. 2/7/2018 SET DV @ 2707' RKB; W/ HOLEFINDER OBTAIN GOOD TBG TEST @ 7421' RKB; PULLED CATCHER @ 7757' RKB.JOB COMPLETE & READY FOR E-LINE (PATCH). RIH with Owen XSpan tubing patch to seal leak at 7426' (GLM #5), OAL= 22', Min ID= 2.259". Correlated to SLB LDL log 9-OCT-2017 and set patch at 7423' -7445'. After patch was set IA was bled down to 0 psi and tubing held at 1075 psi. LRS RU and PT tubing to 4750 psi for 30 min./0 psi on IA. CONDUCT T-MIT TO 4750 PSI FOR 30 MINUTES WITH 0 PSI ON IA(PASSED),JOB COMPLETE. 2/16/2018 TUBING MIT Results: PRE MIT= 1300/0/175/25. PUMP 0.9 BBLS TO PRESSURE UP MIT=4800/75/225/25 15 MINS=4675/100/225/25 LOST 125 PSI 30 MINS=4625/100/225/25 LOST 50 PSI PASSING MIT. BLED DOWN TBG TO 1300. BLED BACK 1.25 BBLS • -. • KUP PROD • 3N-19 • ConocoPhiIIips 01 Well Attributes Max Angle&MD TD Wellbore APWWI Field Name Wellborn Status ncl)•) MD(ft/(13) Act 13161(f1KB) Air19Ka,Inc. 500297305600 KUPARUK RIVER UNIT PROD 97.97 9.743.44 10,515.0 CmaCaP1t1�1„,„ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date --. SSSV:NIPPLE 200 1/24/2017 Last WO: 62.56 1/17/2002 ON-19,0/5/2018 11:10.27 AM Last Tag Vertical schematic(actual) Annotation Depth MKS) End Date Last Mod By Last Tag:RKB 7,951.0 5/21/2017 pproven HANGER;2a9--'` '' Last Rev Reason _,,..7Annotation End Date Last Mod By Rev Reason:Perm Patch,GLVs 3/5/2018 lama) • ICasing Strings k, 1+ Casing Description OD(int ID(In) Top(ftK8) Set Depth(ttKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 150.0 150.0 6250 H-40 WELDED _� Casing Description OD(In) ID(In) Top(ftK8) Set Depth(ftK8) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 29.7 3.649.1 3,620.7 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(RKB) Set Depth(ft/(B) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 280 8.755.8 6,461.2 26.00 L-80 BTC-Mod Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ttKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread CONDUCTOR:30,0-150.0- a A LINER 31/2 2.992 8,571.6 10.488.0 6,446.0 9.30 L-80 IBT NIPPLE;487.6 TIM5 Liner Details I Nominal ID - -- 1 Top(ttKB) Top(TVD)(1188) Top Ind(*) Item Des Com (In) GAS LIFT;2.707.2 i 8,571.6 6.454.7 91.52 PACKER Baker ZXP Packer&Tie Back Sleeve 5.250 • 8,585.4 6,454.3 91.11 HANGER Baker s"x7"Flex Lock Hanger 4.281 8,594.7 6.454.2 90.84 PBR Baker 80-40 Polished Bore Receptacle 4.000 1 8,606.9 6,454.0 90.47 XO 5x3.5" XO-5"L-80 Stub ACME x 3-1/2"L-80 EUE 8rd 2.992 'I 8,617.4 6.454.0- 90.16 XO 4.5x3" XO-4-1/2"SLHT boxx 3-112-EUE 8rd Pin 2.992 SURFACE;29.7.3.649.1.--.4e1 L 10,453.6 6.447.0 91.66 BUSHING Pack-off bushing 2.992 Tubing Strings GAS LIFT;4,159.7 Tubing Description (String Ma...I ID(in) I Top MKS) (Set Depth ' )h..f 9e1 Depth(TVD)(...I Wt(18)6) (Grade (Top Connection TUBING 3 1/2 2.992 24.9 8.600.61 6.454.1 9.30 L-80 EUE 8rd Completion Details - Top(TVD) Top Incl Nominal GAS LIFT;5,485.8 '"C Top(NKB) (ft1(5) (•) Mem Des Com ID In) 24.9 24.9 0.06 HANGER 3-1/2"FMC Gen V Tubing Hanger 2.992 487.6 487.5 3.01 NIPPLE Camco DS nipple 2.875"ID 2.875 7,633.7 6,282.7 59.17 PBR Baker 12 80-40 PBR w/12'seals Inside 3.000 GAS LIFT: b31.9 7,647.4 6,289.7 59.68 PACKER T.268 FHL Retrievable Packer 3.000 7.757.4 6,341.9 63.59 SLEEVE-O BAKER CMU Sliding Sleeve w/Camco DS profile,2.812"ID 2.812 (CLOSED 11/17/2017) 7.933.9 6,408.3 72.76 SLEEVE-O BAKER CMU Sliding Sleeve w/Cameo DS profile,2.75"ID 2.750- (CLOSED 11/17/2017) LEAK:7426.0 8.572.7 6,454.6 91.49 LOCATOR LOCATOR SUB 3.000 GAS LIFT,7.426,1- PATCH.7,423.0 8,574.0 6.454.6 91.45 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(NKB) (RKB) (°) Des Com Run Dais ID(In) PBR:7,633.7 7,423.0 6,162.4 52.01 PATCH OWEN XSPAN PATCH OAL 22.4'MIN ID 2.25" 2/16/2018 2.250 PACKER;7,647. 7,426.0 6,164.2 52.04 LEAK LEAK FOUND AT-7440 THE BOTTOM PUP OF GLM 10/9(2017 05(7426 RKB) 7,757.4 6.341.9 63.59 NIPPLE 2.81"X 1.81""D-PROFILE"SET IN THE SLIDING 2/5/2018 1.810 REDUCER SLEEVE PROFILE 8,615.0 6,454.0 90.23 VALVE BAKER KNOCKOUT ISOLATION VALVE(KOIV) 1/3/2002 NIPPLE REDUCER.7,757.4 MILLED OUT 4/26/2002 SLEEVED:7,757.4 10,488.0 6,446.0 91.66 FISH FISH LOST DURING DRILLING&COMPLETION 1/10/2002 0.000 Perforations&Slots Shot Dens (PERF;7,850.0.7.6600 - Top(TVD) Btm)TVD) (ehots/N Sums RFd 850,.7.650.0Lf I Top(NKB) Btm(11149) (NKB) (MB) Zone Date I Type _ Com - 7,850.0 7,860.0 6,380.0 6.383.7 A-3.3N-19 1/14/2002 6.0 IPERF 4.5"BHC,60 deg phase 9,182.0 10,454.0 6,463.9 6,446.9 A-2.A-3.A-6.A--1/10/2002 ' 99.0 4PERF SLOTTED LINER 5.A-3,3N-19 Stimulations&Treatments SLEEVE-0:7.933,9--1 ,1 Proppant Designed(Ib) Proppant In Fbrmation(Ib) Date 154.000.0 154,000.0 4/22/2002 Stimulations&Treatments Vol Clean Pump i ix i Stg B Top(9168) Btm(NKB) Date Stlm/Treat Fluid (bbl Vol Slurry(bbl) LOCATOR,8.572.7 1 7,850.0 7,860.0 4/22/2002 1 ra 1 Mandrel Inserts SEAL ASSY;8.574.0 St all ON': Top(TVD) Valve Latch Port Size TRO Run Top MKS) (NKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Corn 1 2,707.2 2,684.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,288.0 2/20/2018 2 4,159.7 4,098.4 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 1,279.0 2/20/2018 3 5,485.8 5,024.7 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,276.0 2/20/2018 4 6,531.9 5,643.7 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 2/20/2018 5 7,426.1 6,164.2 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/4/2017 High VALVE:8,615.0 Seale bllty Pack) ng Notes:General&Safety End Date Annotation 9/8/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemagc9.0 PRODUCTION;28.04755.8-.6. IJ IPERF;9,182.0-10,454.0 LINER;8,57l.6-10.488.0 FISH',10.488.0--AO IP • • 97 N GaL~ tJ9w Cp 10;15,1 N > ai� ()N Z 0o L 3^or ° terIv �, Q YO C . N v L .a O 4-cCIO '.' a3 > ro ro a O E', � u j O o 0 Y v O V a cu .c a cc c >••ro 4 'c Y th-j-ill @ o v a '� < O L u >' Q Q �., � E a a Co 0 Q w ., r- r- r- r- 0 L a1 Ou b -J 0 a a E } L o v) k ; w w 0 0 0 O O c c u L v n H- 0) 0 M v Coo) o 0 0 + I c WI Z Z Q O N M v 0 E \> Ts u . O O c L a.' '' co O 1- � N v N U 0 0 0 0 0 0 0 Lo J J J J J J J c :7- O > W W W W W W W v) N 0 U w t- LL LL LL LL LL LL LL �, a1 a1 a1 "6 a _o > L a1 = 4- Cr, a z z z z z z z a) o 0 0 v eek 0 LL LL LL LL LL LL. LL c L c > - O _0 IT L u O C Z a a1 u > U ,-. 0 c o ( w co �� m a1 Y u L N Z p G. 2 a ~ c D a o 0 MI L'3 C, U = J J Q a1 a in c a ,U" w m a) LL LL LL LL d O T ri 0 c f= V) aJ a ril t) ro . \ a, el O a� c4 o o v .- O 13 (0 a+ O tr.". Z 00 1.d ." ►. et 0 P ' o • vi tno • riff. Lu w w w w w w Q > > > > > > > Z Y Y Y Y Y Y Y 7 7 7 7 7 7 7 < < < < < < W Q Q Q <Q Q Q Q a+ ® LL a a o a a o a 1... o a Y Y Y Y Y Y Y -,` c O M M N N Co 0) X to75 .(0 r' t0 (0 t0 f0 t0 0 E t0 (0 C 0 0 0 0 0 0 0 mom0 0 0 0 0 0 0 0 0 0 0 0 __ ILI V CO 0 0 0 0 0 Cr) > O > U 0 0 CO CO 0 Q V x u '9 WY Q w 0 n O O O O 0 o 0 N •' 0 0 0 0 0 0 0 Q o) o) r� cc o m ao 4.. : • • , OF7'k 7w_>__ y�j/y+A THE STATE Alaska Oil and Gas i��,;,—s�a�, ofLASKA Conservation Commission titt. = "- -.•.�_...,.. 333 West Seventh Avenue k GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �,�""ti Main: 907.279.1433 pipi,tiiii.-sot- -ALAS. Fax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam t,EP 0 , Staff Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 3N-19 Permit to Drill Number: 201-225 Sundry Number: 317-338 Dear Mr. Pedam: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 71-) Cathy . Foerster Commissioner DATED this J1 day of August, 2017. RBDMS \,c' SEP - 5 2017 • • • STATE OF ALASKA REC EIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 4 2017 APPLICATION FOR SUNDRY APPROVALS ors B' �l 20 AAC 25.280 ACS C 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate 0 Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development [2[' 201-225 3.Address: L, 6.API Number: Stratigraphic ❑ Service P. O. Box 100360,Anchorage,Alaska 99510 RA► 50-029-23056-00. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3N-19, Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25520 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,515' 6,445' - 10488 . 6446 . NONE 10488 Casing Length Size MD TVD Burst Collapse Conductor 120' 16" 150' 150' Surface 3,619' 9 5/8 3,649' 3,621' Production 8,726' 7 8,756' 6,461' Liner 1,916' 3 1/2 10,488' 6,466' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7850-7860,9182-10454 ' 6380-6384,6464-6447 3.500" L-80 8,601' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=FHL Retrievable Packer r 7647 MD and 6290 TVD PACKER=BAKER ZXP PACKER / 8572 MD and 6455 TVD SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development 0 Service L 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL VI WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG , 1 GSTOR 0 SPLUG ❑ Commission Representative: VA GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: Staff Co ngineer Contact Email: Sandeep.Pedam@cop.com tie �� 10�� Contact Phone: (907)263-4724 Authorized Signature: j,,, ' .. Date: U J COMMISSION USE CALY Conditions of approval: 'otify Commission so that a representative may witness Sundry Number: Plug Integrity El BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [ R�®�� �� - Spacing Exception Required? Yes ❑ No i1 Subsequent Form Required: /c —4 04 SEP2017 APPROVED BY Approved by: /I COMMISSIONER THE COMMISSION Date: g.. 31. (7 v L e1305 ( AAAA ga.pip- CW 712.0.017 R I '"� Subs n Form and Form 10-403 Revised 4/2017 A O e t IS valid Of� r'12 mon��om the date of approval. Attachments in Duplicate • • ✓ RECEIVED ConocoPhillips JUL 20172 Alaska, Inc. Paul K.Wharton AOGCC Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Pau I.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3N-19 Well Kuparuk River Unit, Alaska ADL 25521, KRU Tract 6; and ADL 25520, KRU Tract 5 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 3N-19 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about June 2, 2017. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Pc Paul Wharton Staff Landman cc: Lynn Aleshire Rebecca Swensen • • 3N-19 Hydraulic Fracturing Notice Letter June 1, 2017 Page 2 Exhibit 1 3N-11 ADL025512 ADL025513 314-09314-�1AL1 314-07AL2 314-11AL2-01 314-0 AL2-03 314-07AL2-02 314_11_ 314-07AL2=01 314-11AL3 3N-11A ADL025520 /� 3N-17 314-07A@1-03 ;N=07 411 3N-13 3N-04 Irt, 3M07A ' 314-07AL1 3N-05L1 \I3N-0511-03 3NVA11411 314-05L1PB1 3140 7AL10 2 ADL025521 i ' 3N-15 314-08 -\�V ' N-4 `" 314-05 ` 314-14APB1 314-08A 3N-14A 314-16AL1PB1 3N-088L1 3N-08B V7 3N-16AP\83 314"16AL1 Z 3N-16AP,B 314-16AL\1-01 \ l49 314-16APB1 '..........'"-.........2.N 16 3N-03 N-06 3N-12 3K-04 314-18L1 3N-19PB13/N/8LlP81 I l 3N-02A\ 314-10 3K-O8AL-2 / 3N-01 3K-08AL2-01 :1:00, 3N-18 T':',3 ,i n N R 9 E 3K-0BAL2-02 1 2 ;• r ------- • Frac Points Well Trajectory ADL025630 --^-M Well Open Interval N ConocoPhillips 1111 Half Mile Frac Point Radius Alaska,Inc. A _ Half Mile Trajectory Radius 3N-19 Wells within Trajectory Radius 0 0.2 0.4 0.6 Lease Plat CPAI Leases Miles 5/9/2017 •3N-19 Hydraulic Fracturing Notice Letter June 1, 2017 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612. 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 3N-19 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton,and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about June 1, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 1st day of June, 2017. /4, • Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 1St day of June, 2017, by Paul K.Wharton. No ary Public, State of Alaska My Commission Expires: �- - --- -- STATE OF ALASKA . s NOTARY PUBLIC k REBECCA SWENSEN Cannoission Ex•roe Au..27,2620. • i Section 1 — Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) III • :4,11 ADL025$13 arIDL025$12 .itJ•fF 14-11A1t :.+,{i7h12 3N-11.4L2-01 3V.]FFL:G3 - _351,5)+12 -/ ':N'Ll rr 3):-11,34,] 3N-1•A ADL025520 r 3N-1? IN 117i4f t3, 3 y`1`'T _ 3+:34 '4kG'h - -1343 sWJ,h11 I3N,XL1 y V 3<4C Ll.B3 3r4 ?A_1-017 314 5.4441 81 JN 4,41.1 t AOL025521 .1111111: 914 15 eR� \\3N-CS . "`-' 3N't 3yiAFI'tit 1if I3+J 141.ffj ,1EdlFP.1 3tt OBELIS, ul A+1EJ�3;f - r 3N,-t4.., j It/. IN-10.,1111, N I ,� 3'a:iNSr'at� a 2N-C34N GG -,,.„,„.."1,47 3K=1135 11 K=11 214 1BLI r 2N-'9)121 3N13_1r61 15.27,4 \ 1 \a "Viet 1n�� N(115/4 J-01 a<f 3513 , 2JlO'JA12{c� , N j r ` r 1•'s ec Pont Welt Trajecto€y ADL025530 1rp'l "......1J`?eli Open inter N Co coPf illips - Half Mile FraoPoint Radius Alaska,Inc. A - Half Mile Trajectory Radius 3N-41 9 Welts wain Trsgectrry;adius ' 0 0,2 0.4 0.6 Lease Plat Leases Miles OP. ( 6,P5l2017 • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1:3N-19 Landowners ..,a4 A0L025512 r A" i?.,j7A1 2 c•1-!litL2-11 3%:!A.2C3 ...< '2'4 VA.:2 C 1 1 A0L025513 3N--fm? ADL025520 3t,1 ITA,;•4.47–'?°7 401 %.13 A,X11 s, ..„1„, • .- 11, 7/7 1!::Ct.4.1 13 NVA..1%.1) .1:VAL1 3,4 6,.171,11 ADL025521 tib. le't 3,4 14APf.0 4\ \ / \<9 W.W.I“Sit • di lkEtt Cifil "lo iN il.in.ifk:€113, '-•-... ., ;11 I 'NI%\ s.'"'"..."`,.....Z14•G N.Y, A-43 3,4 12 X31 di T-4 P4`Pal 24 It.9;,h1 3V.31.4 : ri'7 lE W.1.12 / :di il 1K ON 2 0/7 / "A If • Frac Points —---- -Well TrajeOxy A0L025830 Nirr" ••••••••••Welt Open Interval N ConocoPhillips Ns Half Mite Fra3Point RathilS #41k Alaska,,nc 11111 Half Mile Trajectory Radius 3N-19 Welts within Tmectory Radius 0 0.2 OA 0.6 Lease Plat Miles CPA 1 Leases 519/2017 • • Table 1: Wells within .5 miles API Well Name Well Type Status 500292153700 3N-05 INJ ACTIVE 500292154002 3N-08B INJ ACTIVE 500292154060 3N-08BL1 INJ ACTIVE 500292305670 3N-19PB1 EXPEND PA 500292152701 3N-02A PROD ACTIVE 500292153760 3N-05L1 INJ ACTIVE 500292153763 3N-05L1-03 INJ ACTIVE 500292153770 3N-05L1PB1 EXPEND PA 500292162161 3K-08AL2 INJ ACTIVE 500292162162 3K-08AL2-01 INJ ACTIVE 500292162163 3K-08AL2-02 INJ ACTIVE 500292151900 3N-01 PROD ACTIVE 500292152800 3N-03 INJ ACTIVE 500292152900 3N-04 INJ ACTIVE 500292153800 3N-06 PROD ACTIVE 500292153900 3N-07 PROD PA 500292153901 3N-07A PROD ACTIVE 500292153960 3N-07AL1 PROD ACTIVE 500292153964 3N-07AL2-01 PROD ACTIVE 500292153965 3N-07AL2-02 PROD ACTIVE 500292153966 3N-07AL1-03 PROD ACTIVE 500292153967 3N-07AL2-03 PROD ACTIVE 500292154001 3N-08A INJ PA 500292154100 3N-09 PROD ACTIVE 500292153961 3N-07AL1-01 PROD ACTIVE 500292153962 3N-07AL1-02 PROD ACTIVE 500292153963 3N-07AL2 PROD ACTIVE 500292157600 3N-10 INJ ACTIVE 500292158000 . 3N-11 PROD PA 500292158001 3N-11A INJ ACTIVE 500292158060 3N-11AL1 INJ ACTIVE 500292158061. 3N-11AL2 INJ ACTIVE 500292158062 3N-11AL2-01 INJ ACTIVE 500292158063 3N-11AL3 INJ ACTIVE • S 500292158200 3N-12 INJ ACTIVE 500292158400 3N-13 INJ ACTIVE 500292158900 3N-14 PROD PA 500292158901 3N-14A PROD ACTIVE 500292158970 3N-14APB1 EXPEND PA 500292159200 3N-15 PROD ACTIVE 500292159300 3N-16 PROD PA 500292159301 3N-16A INJ ACTIVE 500292159360 3N-16AL1 INJ ACTIVE 500292159361. 3N-16AL1-01 INJ ACTIVE 500292159370 3N-16APB1 EXPEND PA 500292159372 3N-16APB3 EXPEND PA 500292159373 3N-16AL1PB1 EXPEND PA 500292159400 3N-17 PROD ACTIVE 500292159500 3N-18 PROD ACTIVE 500292159560 3N-18L1 PROD ACTIVE 500292159570 3N-18L1PB1 EXPEND PA 500292160300 3K-04 INJ ACTIVE 500292152700 3N-02 PROD PA 500292154000 3N-08 PROD PA 500292159371 3N-16APB2 EXPEND PA • i Section 3 — Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147. 102(b)(3), "That portions of the aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field • • Section 4 — Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable • 0 SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 ACC 25.030 (g) when completed. See wellbore schematic for casing details. • Section 6 — Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) CASING &CEMENT ASSESSMENTS: The 9 5/8" casing cement pump report on 12/15/2001 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 50 BBLS of CW100 at 8.34 PPG +50 BBLS MudPush at 10.5 PPG,followed with 445 BBLS (561 sacks)AS Lite cement at 10.7 PPG and tailed with 84 BBLS (196 sacks) of Litecrete cement at 11.8 PPG. No problem was reported during cementing operations. The 7" casing cement pump report on 12/27/2001 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 86 BBLS (410 sacks) Class G cement. Full returns were seen throughout the job.The plug was bumped and the floats were checked and they held.TOC estimated at 7536 ftMD based on volume of cement pumped. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits • 0 Section 7 — Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) On 12/28/2001 the 9 5/8" casing was pressure tested to 2,500 psig. it will be tested to 4000 psig On 4/11/2002 the 7" casing was pressure tested to 2,500 psig. It will be tested to 4000 psig. On 4/11/2007 the 3 %2"Tubing was pressure tested to 2,500 psig. It will be tested to 5,000 psig AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,800 Annulus pressure during frac 2,500 Annulus PRVsetpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 4,801 < Nitrogen PRV 6,341 Highest pump trip 6,141 Table 1: AOGCC Required Pressures • • Section 8 — Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) Size Weight, lb/ft Grade API Burst, psi API Collapse, psi 9 5/8" 40 L-80 5,750 3,090 7" 26 L-80 7,240 5,410 3 1/2" 9.3 L-80 10,160 10,540 Table 2: Pressure Ratings • • Stimulation Surface Rig-Up n J Ch C Bieed I Tattle \ (�I Tale Tank _.*',// 2 ail/ "IL,- y a L U IS J N 4) NN yyy N R1 N N c_. o- f- } - > C4 :\ 2a � U N L Hxuldumd 0 Pop-Off Tank `m ...=2. 2411 N d -- Pump Truk Pop-Olt Tank S.Ury roda iii t a)c0. F-J 5. `S N N yi ,,,, r] Frac Pump (`y,} e ' •• Frac Pump a, Frac Pump CN II 44! rirN1 Frac Pump Frac Pump r.J pc° -,f Frac Pump • I Tree Saver With Wellhead Flop OIL STATES P ROPOSA I Energy Services(Canada) inc. QUOTE#: DATE: Maximum Allowable Pumping Rates SIZE ID OD RATE m'lnlin CSG 2.250 3.750 10 m'/min 3 1/2"Big Bore 1.750 2.750 6 m'Imin 2 7/8"&3 1/2" 1.438 2.3607 4 m'Imin 2 3/811 1.000 1.9002 m'hnirr 31116&41116 with tapered mandrel 2.750 4.000 15 m'/min 41/16 X Toot Mandrel 3.610 I 4.750 24 in'/min GPM POSITION CLOUD POSITION 1-v.i e"vxxleu M111111i'I 10,010,41 t'Yies'ttit —• #Y1141t 9rptaleo ^ rwKlia vN;i 1 1 " r / . t • I-11 ). (231.....i. 1 .1.4 4,40'4.41C11 1 '-'* 6 ‘". 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Omer m Hole Innenrn Minable plugs,valves.pump.SAL IMO 1111 711,13£ -V•Y'= •� TM INCE, 4,581 '164 Rua LLS. II 1111.1 4WF,MCP 11,432.i 0,n14 0 60:5 M4:V1 2421.110.740C,24./t120/2110111212.172 0/21101YVALYY RAM 1.122114 Ik-`161 ;2}6+ YZ1ta}Mt 427022 7.222 '1.4032 1,447.0 5'05 TIO+ 1121-11001 154915'1 1.217,41.12X14CC44,11.1014 1110657:11 3001 IIPe0Qr81101I8&Slots Wm I7,67° 1w jAC{ 111554 5455944211. II 76211512.15228'5514 44534 14451 5.... .. Y 74*. Can MO02 2,0161.0 1,3500 5,2577,4311110 4542911 60 0'1.111 4170514,5045703055 I 315'.0 10,4443 5,41-39 5,4469,14.0,5-']144. 2'557° 32D 1141-117 31.0277-547741.74 ♦42'A+2.1.1. 05 .»»s,4°slrla,.w .�::.1.1:.: 11 I 1 1 Shrwulalkne s Treatments 441-7 ..L.,Are .0451 11101,72, 5201215) . ,NN: ,011 11424 104011 17+1 Ora J.Ir - 3,4 1 1,540 5'204 1313.7 MAC 45'_.^.7592 111.41:14.1111.4271-4121120 24102411 0113.,IC322 . 21114 71134",-10451601113 PIM 110-25... ._.. MI Mandrel!melts . 11 ■ L. '5+047604 10L..* 03519,. 186511, M 2 7*P 2521 4501 31445 2515 005.1 lay Tq. 16w 541 5611 11.en D. a *Mr 1 27002 .2.56411 12115 91411 71.2 0142 1,01 131,11 154 152 1x19 4:1.6002 143.2115.542 Ilia2 4,159.7 1,02.4=en= 1210 51,2 042111 UN 194 0:90 1,=.1 11 41222:72 3 5,4350 5.0212 20115 1211:. 112 03531,01 1112 114 5100 1;3710 4272502 4214 47111-.11.1574 4 1.112.9 5.543:7 4.255 01213 7142 0411,11 CJ,' 22 3210 122211 42612242 MN I 511 34_rt1 6:3142 I.2,-tat LTN 1142 455171 GY 1IX. ^3220 0D�1311:C14 M G8n®'S16 Wady I 7456e 115115®11 14,11['.82 1.011,111,7+17CHL5KIIC s'P10 u S a.rr.1rd4D x1413;115114 44YJOl5P5553114*41 5 :t»2;;4,211522 2. 4205.RCi7 150,4114 • 1Y.S'1y4M7 • • Section 9 — Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) CPAI has formed the opinion based on seismic,well and other subsurface information currently available that:The Kuparuk interval is approximately 305'TVD thick. In 3N-19 the top of the Kuparuk is picked at 7470'MD/-6129'TVDSS. The well was drilled horizontal and did not penetrate the base of the Kuparuk formation. The Kuparuk interval is composed of fine-grained sandstone, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 12.5ppg. The overlying confining zone consists of greater than 375'TVD of Lower Kalubik, Upper Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15ppg, 15ppg, and 16ppg respectively. The top of the HRZ was encountered at 6835' MD/-5751'TVDSS. The underlying confinement zone consists of greater than 250'TVD of marine mudstones comprising the Miluveach Shale. 3N-19 does not penetrate the Miluveach Shale. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. Section 10 — Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic,well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing&Cement assessments for all wells that transect the confining zone 3K-08:The 7" casing cement pump report on 10/01/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 335 Sx Class G & 175 Sx AS I. It was displaced with 9.8 ppg brine.The plug bumped at xxx psi and the floats were checked and they held. 3K-04:The 7"casing cement pump report on 07/04/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 320 Sx Class G & 175 Sx AS I. It was displaced with 10.0 ppg brine.The plug bumped at xxx psi and the floats were checked and they held. 3N-10:The 7"casing cement pump report on 04/05/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 300 Sx Class G & 175 Sx AS I. It was displaced with 9.8 ppg brine.The plug bumped at 875 psi and the floats were checked and they held. • 3N-12:The 7" casing cement pump report on 04/22/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 300 Sx Class G & 175 Sx AS I. It was displaced with 9.8 ppg brine.The plug bumped at 875 psi and the floats were checked and they held. 3N-14:The 7" casing cement pump report on 10/30/2007 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 15 bbls of 14.5 ppg mud push at 2 bpm 1600 psi, 16 bbls of 15.8 ppg tail class G cement at 2-2.5 bpm 1650 psi. it was displaced with 12.8 ppg mud at 1.7 bpm and 1700 psi. Dropped wiper dart and visually saw tattle-tail.The plug bumped at 890 psi and the floats were checked and they held. 3N-16:The 7" casing cement pump report on 05/20/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 300 Sx Class G & 175 Sx AS I. It was displaced with 10.0 ppg brine.The plug bumped at 912 psi and the floats were checked and they held. 3N-18:The 7" casing cement pump report on 06/04/1986 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 400 Sx Class G & 175 Sx AS I. It was displaced with 9.9 ppg brine.The plug bumped at xxx psi and the floats were checked and they held. Section 11 — Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic,well and other subsurface information currently available that there are 26 mapped faults that transect the Kuparuk interval and terminate within confining zones inside a one-half mile radius of the 3N-19 wellbore trajectory. Two faults intersect the 3N-19 wellbore in the Kuparuk interval and terminate within the confining layers. Fracture gradients within the confining zones will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zones are discussed in Section 9. The effective fracture half-length is estimated to be 1,900' since this is a single stage frac job along the wellbore. Stress orientation in 3N-19 is interpreted to be approximately North-South and we expect the fractures to propagate parallel to this maximum stress direction. If there are indications that a fracture has intersected a fault during fracturing operations, CPAI will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. 3N-19 Faults MD(ft) TVDSS(ft) Throw(ft) Fault#1 8850 -6403 65 (DTE) Fault#2 10050 -6372 23 (DTE) • • Section 12 — Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 3N-19 was completed in 2002 as horizontal producer in the Kuparuk A sand formation. The well was completed with 3.5" tubing and a 4.5" slotted liner. A single stage frac will be pumped through the perforations. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 12 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 5,975 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 68 bbl breakdown stage (25# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 18 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 6,800 psi. 0 • Section 13 — Post-Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) 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Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-19,7/31/20141:03:35 PM SSSV:NIPPLE 130 11/25/2012• Last WO: 62.56 1/17/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ................................................... .. ...............Last Tag: 10,032.0 4/27/2002 Rev Reason:GLV C/O hipshkf 7/31/2014 HANGER;24.9-. it,l -- ir Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 150.0 150.0 62.50 H-40 WELDED {IL Li� Casing Description OD(in) ID(in) Top MEI) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread SURFACE 95/8 8.835 29.7 3,649.1 3,620.7 40.00 L-80 BTC litiesutaakutatoeutimmaurrimarial whom -Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread l PRODUCTION 7 6.276 28.0 8,755.8 6,461.2 26.00 L-80 BTC-Mod Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 31/2 2.992 8,571.6 10,488.0 6,446.0 9.30 L-80 IBT Liner Details CONDUCTOR;30,0.150.0 a- Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) NIPPLE;487.6 8,571.6 6,454.7 91.52 PACKER Baker ZXP Packer&Tie Back Sleeve 5.250 8,585.4 6,454.3 91.11 HANGER Baker 5"x 7"Flex Lock Hanger 4.281 8,594.7 6,454.2 90.84 PBR Baker 80-40 Polished Bore Receptacle 4.000 GAS LIFT;2,707.2---.1__4 8,606.9 6,454.0 90.47 XO 5x3.5" XO-5"L-80 Stub ACME x 3-1/2"L-80 EUE 8rd 2.992 8,617.4 6,454.0 90.16 X0 4.5x3" XO-4-1/2"SLHT boxx 3-1/2"EUE 8rd Pin 2.992 10,453.6 6,447.0 91.66 BUSHING Pack-off bushing 2.992 Tubing Strings SURFACE;29.73,649.1- Tubing Description I String Ma...I ID(in) I Top(ftKB) I Set Depth(ft...1Set Depth(ND)(...I Wt(Ib/ft) 'Grade I Top Connection TUBING 31/211 2.992 24.9 8,600.6 6,454.1 9.30 L-80 EUE Ord Completion Details GAS LIFT;4,159.7- Nominal ID Top(ftKB) Top(ND)(81(111) Top Incl(") Item Des Com (in) 24.9 24.9 0.06 HANGER 3-1/2"FMC Gen V Tubing Hanger 2.992 487.6 487.5 3.01 NIPPLE Camco DS nipple 2.875"ID 2.875 abs UFT;5.465.97,633.7 6,282.7 59.17 PBR Baker 12'80-40 PBR w/12'seals inside 3.000 7,647.4 6,289.7 59.68 PACKER 7",26#FHL Retrievable Packer 3.000 111_}' � 7,757.4 6,341.9 63.59 SLEEVE-0 BAKER CMU Sliding Sleeve w/Camco DS profile,2.812" 2.812 GAS LIFT;6,531.9--- ID(OPEN 4116/2007) 14 7,933.9 6,408.3 72.76 SLEEVE-O BAKER CMU Sliding Sleeve w/Camco DS profile,2.75" 2.750 ID(OPENED 6/27/2010) 8,572.7 6,454.6 91.49 LOCATOR LOCATOR SUB 3.000 GAS LIFT;7,426.1-----.1 L 8,574.0 6,454.6 91.45 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) PBR;7,633.7 6,454.0 90.23 VALVE BAKER KNOCKOUT ISOLATION VALVE(KOIV) 1/3/2002 PACKER;7,647.4. MILLED OUT 4/26/2002 10,488.0 6,446.0 91.66 FISH FISH LOST DURING DRILLING&COMPLETION 1/10/2002 0.000 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotslf SLEEVE-0;7.757.4 I j Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,850.0 7,860.0 6,380.0 6,383.7 A-3,3N-19 1/14/2002 6.0 IPERF 4.5"BHC,60 deg phase 9,182.0 10,454.0 6,463.9 6,446.9 A-2,A-3,A-6, 1/10/2002 99.0 IPERF SLOTTED LINER A-5,A-3,3N- 19 FRAC;7,850.0 Stimulations&Treatments (PERF;7,7.850.0.7,860.0---11 II Min Top Max 8tm -- Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 7,850.0 7,860.0 6,380.0 6,383.7 FRAC 4/22/2002 FRAC PUMPED THRU TWO SLIDING SLEEVES @ 7757'&7934';154#BEHIND PIPE SLEEVE-0;7,933.9 11 11 Mandrel Inserts St aft C on Top(TVD) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date in ® 1 1 2,707.2 2,684.4 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,297.0 4/28/2002 LOCATOR;8,572.7- 2 4,159.7 4,098.4 Camco MMG 11/2 GAS LIFT GLV RK 0.250 1,326.0 4/28/2002 n 3 5,485.8 5,024.7 Camco MMG 1 1/2 GAS LIFT GLV RK 0.250 1,311.0 4/28/2002 SEAL ASSY;8,574.0 4 6,531.9 5,643.7 Camco MMG 11/2 GAS LIFT GLV RK 0.250 1,302.0 4/28/2002 5 7,426.1 6,164.2 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 7/30/2014 Notes:General&Safety End Date Annotation 9/8/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 VALVE;8,615.0 lin . PRODUCTION;28.0-6,755.6- IPERF;9,182.0.10,454.0 J L I I LINER;8,571.6-10,488.01. FISH;10,458.0 • • Bettis, Patricia K (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Wednesday,August 2, 2017 4:44 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 3N-19 (PTD 201-225): Fracture Stimulate Sundry Application Attachments: 3N-19 Frac Sundry Section 9 and 11 Update.docx;well_3N_19_frac_sundry.png; Occurence of Lost Circulation for AOGCC.DOCX Patricia, Thanks for your email. Please see below: Well 3N-19 Footages Townshi Location FNL FEL p Range Section Meridian Surface 3720' 5209' T13N R9E 28 Umiat Top Open Interval 1176' 3299' T13N R9E 33 Umiat 1)Bottomhole 2976' 1361' T13N R9E 33 Umiat 2) Please see attachment 3) Please see attachment 4) Please see attachment Please let me know if you need anything else. Regards, Sandeep From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,July 26, 2017 2:33 PM To: Pedam, Sandeep<Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL]KRU 3N-19 (PTD 201-225): Fracture Stimulate Sundry Application Good afternoon Sandeep, On Form 10-403, Boxes 4, 13 and 15, ConocoPhillips states that KRU 3N-19 is a service WAG well. AOGCC records show the current well status as an oil development well. Please verify. Also please provide the following information for the sundry application: 1. Please provide the legal description of the well (surface,top production interval and bottomhole locations) include township, range and section, and footage from section lines. 2. Discuss the location of,orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. 1 i I a. For location and orientation, please provide a fault map of all 26 mapped faults that transect the Kuparuk interval and terminate within confining zones inside %2 mile radius of the KRU 3N-19 wellbore trajectory. 3. The table for the 3N-19 Faults only list two of the 26 faults. Please provide a complete table for all 26 faults in the AOR with depths(MD and TVDss)and vertical displacement. 4. Discuss any occurrences of lost circulation that may have occurred while drilling across these faults in KRU 3N- 19 and in the adjacent wells that are within the one-half mile AOR of KRU 3N-19. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 S 3N-19 Section 9: CPAI has formed the opinion based on seismic,well and other subsurface information currently available that:The Kuparuk interval is approximately 305'TVD thick. In 3N-19 the top of the Kuparuk is picked at 7470'MD/-6129'TVDSS. The well was drilled horizontal and did not penetrate the base of the Kuparuk formation. The Kuparuk interval is composed of fine-grained sandstone, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 12.5ppg. The overlying confining zone consists of greater than 375'TVD of Lower Kalubik, Upper Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15ppg, 15ppg, and 16ppg respectively. The top of the HRZ was encountered at 6835' MD/-5751'TVDSS. The underlying confinement zone consists of greater than 250'TVD of marine mudstones comprising the Miluveach Shale. 3N-19 does not penetrate the Miluveach Shale. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. Section 11: CPAI has formed the opinion based on seismic,well and other subsurface information currently available that there are 28 mapped faults that transect the Kuparuk interval and terminate within confining zones inside a one-half mile radius of the 3N-19 wellbore trajectory. Two faults intersect the 3N-19 wellbore in the Kuparuk interval and terminate within the confining layers. No other wellbores within the one- half mile radius intersect the faults crossed in 3N-19 within the Kuparuk or confining zones. Fracture gradients within the confining zones will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zones are discussed in Section 9. The effective fracture half-length is estimated to be 420'. Stress orientation in 3N-19 is interpreted to be approximately North-South and we expect the fractures to propagate parallel to this maximum stress direction. If there are indications that a fracture has intersected a fault during fracturing operations, CPAI will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Faults Intersected in 3N-19 Wellbore Fault MD(ft) TVDSS(ft) Throw(ft) 1 8850 -6403 65 (DTE) 2 10050 -6372 23 (DTE) Faults Within One-Half Mile Radius Fault Orientation Throw(ft) 1 North-South 20-70 DTE 2 North-South 20-30 DTE 3 North-South 5 DTW 4 North-South 20-25 DTW 5 North-South 10 DTE • 6 East-West 20-30 DTN 7 East-West 25-35 DTN 8 North-South 50-70 DTE 9 North-South 5-15 DTW 10 East-West 5 DTS 11 North-South 10-20 DTE 12 North-South 5 DTE 13 East-West 30-45 DTS 14 East-West 30-60 DTS 15 East-West 5 DTN 16 East-West 5 DTN 17 East-West 15-20 DTN 18 North-South 20 DTE 19 North-South 40 DTE 20 East-West 5 DTN 21 North-South 15-20 DTW 22 East-West 10-15 DTN 23 East-West 10-20 DTS 24 East-West <5 DTN 25 North-South <5 DTE 26 East-West 10-15 DTN 27 North-South 10 DTW 28 East-West 15-20 DTS • Two faults intersect the 3N-19 wellbore in the Kuparuk interval and terminate within the confining layers. No other wellbores within the one-half mile radius intersect the faults crossed in 3N-19 within the Kuparuk or confining zones. According to 3N-19 drilling report,while drilling through Fault#1 @ 8850 MD(ft), we experienced minor losses.These losses were fully mitigated by progressively raising mud weight from 12.4 PPG to 12.8 PPG. The hole was successfully cased and cemented. While drilling the lateral section of the well through Fault#2 @ 10050 MD (ft), we also experienced minor losses that were fully mitigated by progressively increasing mud weight from 10.5 PPG to 12.5 PPG. This lateral section was ultimately completed with a 3-1/2" slotted liner. It is worth reiterating that Fault#1 and Fault#2 crossed by 3N-19 in the Kuparuk interval do not intersect any other wellbore within%2 mile radius in the Kuparuk interval. • AD L02•3 ADL025512 7#7 ADL025520 ADL025521 `.�.� 3N-15 314=14 3N-14APB1 � 314-14A 314-16AL1 314 16APB3 3N-16A 3N-16AL1-01 314- .16A3 314161 11 3N-16 3K-04 114.44 3N-12 N441 04, 4 314-18L1 3N-19PB1 3N4'8L1P81 11111 \ 3lo / / 3K-08AL2-01 3N-18 3K-08AL2 3K-08AL2-02 /10," - Frac Points — Well Trajectory Si Well Open Interval ADL025630 .AA Q Half Mile Frac Point Radius N ConocoPhillips Half Mile Trajectory Radius Alaska,Inc. Faults within Frac Point Radius 3N-19 Wells within Frac Point Radius 0 0.2 0.4 0.6 Frac Plat CPAI Leases Miles 5/9/2017 • • N A• O a) N a CO CO CO CO CO m CO m m r-+ E. Y YY Y Y Y Y Y o 0 Y tz a p m E a a 0.. 0.. a a °. a u ti °- V u u +-' o = o oio .�. 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'. ` u•••••••••• .. � c,CD = ° ` ° , a, a � o. .i Li. .4.., tev v L. c o a ba a, 'CU v c cx 3 c ;� c v v u H tT t Q: u Q cu O a c a V � q h e `ti 'n v o a v a u -�, a n cu 0 0 cc o. v I ul ._ a Er'.., c .. = H p Q • S N M1. O QJ N GJ ' Ts m 0 o L.) a 00 Q M a..+ M •� ▪u M OJ • t 0 U z >I. C L }+ 0 VN ncu •- •••• 4.n CL Q N a ri .=• N i • L Zin i 0 v be L.) a --- a. i "° -0 z v I M I6 0- s 000 ( `0en ce `� IL 00 QUi i C N -a LA p o v H N Z c v, is G1 vii s c 4-, ° < E ., c c 3' a 0 � o0 E s. av O Z � `o - ,I N ' o •a a : y n, aa (1) O v CS m O O a H i off, or O Q • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, July 26, 2017 2:33 PM To: Pedam, Sandeep Subject: KRU 3N-19 (PTD 201-225): Fracture Stimulate Sundry Application Good afternoon Sandeep, On Form 10-403, Boxes 4, 13 and 15, ConocoPhillips states that KRU 3N-19 is a service WAG well. AOGCC records show the current well status as an oil development well. Please verify. Also please provide the following information for the sundry application: 1. Please provide the legal description of the well (surface,top production interval and bottomhole locations) include township, range and section, and footage from section lines. 2. Discuss the location of,orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. a. For location and orientation, please provide a fault map of all 26 mapped faults that transect the Kuparuk interval and terminate within confining zones insideY2 mile radius of the KRU 3N-19 wellbore trajectory. 3. The table for the 3N-19 Faults only list two of the 26 faults. Please provide a complete table for all 26 faults in the AOR with depths(MD and TVDss) and vertical displacement. 4. Discuss any occurrences of lost circulation that may have occurred while drilling across these faults in KRU 3N- 19 and in the adjacent wells that are within the one-half mile AOR of KRU 3N-19. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 _/S 2.'5 1 WELL LOG 2 TRANSMITTAL ITTAL ". . DATA LOGGED M.K.BENDER PROACTIVE DIAgNOSTIC SERVICES, INC. RECEIVED To: AOGCC Makana Bender JUN 1 3 2017 333 West 7th Avenue Suite 100 AOGCC Anchorage, Alaska 99501 Vt✓ (907) 793-1225 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: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 'JUN 2 2017 1) Caliper Report 29-May-17 3��"' 1 Report /CD 50-029-23056-00 2) Caliper Report 27-May-17 2M-12 1 Report /CD 50-103-20181-00 Signed : f2cLdiZ41Z1J5ILh4 ' Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D 1AchivesNasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhil lips_Transmitdocx 0 RECEIVED 2° `-�"?`� 106 JUN 13 2017 Memory Multi-Finger Caliper - , s L.....i. AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3N-19 Log Date: May 29, 2017 Field: Kuparuk Log No.: 12782 State: Alaska Run No.: 1 API No. 50-029-23056-00 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 7,693 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 5 at 7,426 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to fair condition, with wall penetrations of 25%, 23%, and 22% in a line of pits in joint 240 (7,608 ft), joint 239 (7,571 ft), and joint 241 (7,671 ft) respectively. No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : Percent Wail Penetration Line of Pits 25 240 7,608 Ft. (MD) Line of Pits 23 239 7,571 Ft. (MD) Line of Pits 22 241 7,671 Ft. (MD) No other significant wall penetrations (> 17%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. R. Holden C. Waldrop J. Fama ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • . Correlation of Recorded Damage to Borehole Profile 1111 Pipe 1 3.5 in (49.7'-7,692.9') Well: 3N-19 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 29, 2017 ■ Approx.Tool Deviation . Approx. Borehole Profile 1 -■ 53 25 818 7-0I 50 1,597 i 75 2,374 GLM1 — 100 .. 3,173 F Z 125 3,947 t GLM 2 -• O . ) 150 4,744 GLM 3 175 5,537 200 6,311 GLM 4 —� 225 7,107 GLM 5 241 7,657 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=241 i • PDS Report Overview Body Region Analysis Well: 3N-19 Survey Date: May 29,2017 Field: Kuparuk Tool Type: UW MFC 24 No.211387/218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD 2.992 in. 50 ft. 7,693 ft. Penetration (%wall) Damage Profile(%wall) 300 Imo Penetration body Imo Metal loss body 0 50 100 250 0.1 F 200 150 100 45 50 0 C 0 to 20 to 40 to over _— 20% 40% 85% 85% GLM 1 92 7= Number of joints analyzed(total=257) 254 3 0 0 Damage Configuration(body) GLM 2 (12:00) 30 139 k 20 - GLM 3 (1:00) 186 10 GLM 4(10:30) 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (5:00) 233 -. Number of joints damaged(total=42) 16 0 26 0 0 Bottom of Survey=241 • ILI it PDS Report Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ((Ye,wall) (in.) (in.) % (in.) 0 50 100 0.1 50 0 0.01 6 2 2.90 Pup Lt. Deposits. 1 53 0 0.03 13 6 2.95 1.1 83 0 0.02 9 4 2.90 Pup Lt. Deposits. 1.2 89 0 0.02 7 2 2.92 Pup Lt. Deposits. 1.3 93 0 0.03 12 8 2.93 Pup Lt. Deposits. 1.4 95 0 0.03 11 2 2.91 Pup Lt. Deposits. 2 105 0 0.03 13 6 2.94 3 137 0 0.03 13 6 2.95 4 168 0 0.03 11 7 2.92 Lt.Deposits. 5 199 0 0.03 10 6 2.95 6 229 0 0.02 9 6 2.95 7 261 0 0.02 9 2 2.95 8 292 0 0.03 12 4 2.95 9 323 0 0.03 10 4 2.95 10 354 0 0.03 11 6 2.94 11 384 0 0.03 13 5 2.94 12 416 0 0.03 11 4 2.95 13 446 0 0.04 14 4 2.95 14 477 0 0.03 13 4 2.95 14.1 509 0 0 0 0 2.88 CAMCO DS NIPPLE 15 510 0 0.03 10 4 2.93 Lt.Deposits. 16 541 0.04 0.03 13 4 2.92 Lt.Deposits. 17 571 0 0.02 9 4 2.94 18 602 0 0.02 7 3 2.94 19 633 0 0.03 10 3 2.94 20 665 0 0.02 8 2 2.94 21 696 0 0.02 9 4 2.93 Lt.Deposits. 22 727 0 0.03 11 4 2.95 23 757 0.04 0.04 14 5 2.95 24 789 0 0.03 11 4 2.93 25 818 0 0.03 10 4 2.94 26 850 0 0.03 10 3 2.95 27 881 0 0.03 11 4 2.95 28 911 0 0.03 13 3 2.93 Lt.Deposits. 29 943 0 0.02 8 4 2.94 30 973 0 0.02 7 4 2.93 Lt.Deposits. 31 1004 0 0.02 9 4 2.95 32 1035 0 0.02 8 3 2.91 Lt.Deposits. 33 1067 0 0.02 9 4 2.94 34 1098 0 0.02 9 4 2.94 35 1129 0 0.02 8 3 2.93 Lt.Deposits. 36 1161 0 0.03 13 7 2.92 Lt.Deposits. 37 1192 0 0.03 11 4 2.95 38 1223 0 0.02 9 4 2.95 39 1254 0 0.03 10 3 2.95 40 1285 0.04 0.03 13 7 2.94 41 1316 0 0.03 11 4 2.95 42 1347 0 0.02 8 4 2.95 43 1379 0 0.03 13 5 2.93 Lt.Deposits. 44 1410 0 0.03 10 4 2.94 IPenetration Body Metal Loss Body Page 1 • • IIII PDS Report Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Descripiion Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 45 1441 0 0.03 10 3 2.95 46 1472 0 0.02 9 2 2.94 4 47 1504 0 0.03 13 5 2.93 ■ 48 1535 0 0.03 10 4 2.95 • 49 1566 0 0.03 12 6 2.92 Lt.Deposits. 50 1597 0 0.03 11 7 2.94 ii 51 1629 0 0.03 10 3 2.93li 52 1659 0 0.03 10 4 2.94 • 53 1689 0 0.04 15 5 2.90 Shallow Pitting. Lt Deposits. ■ 54 1720 0 0.03 13 5 2.94 • 55 1750 0 0.03 11 7 2.94 ii 56 1782 0 0.03 12 6 2.95 i 57 1813 0 0.04 14 7 2.93 58 1844 0 0.02 9 5 2.95 59 1875 0 0.03 11 6 2.93 Lt.Deposits. 60 1906 0 0.02 9 3 2.94 i 61 1937 0 0.03 10 3 2.93 Lt.Deposits. r 62 1968 0 0.03 11 6 2.93 Lt.Deposits. • 63 1999 0 0.03 12 2 2.95 • 64 2031 0 0.03 13 2 2.93 Lt.Deposits. • 65 2062 0 0.03 10 2 2.93 Lt.Deposits. 66 2093 0 0.02 8 2 2.92 Lt.Deposits. 67 2124 0 0.02 7 2 2.94 3 68 2156 0 0.03 11 2 2.94 • 69 2187 0 0.03 13 2 2.93 • 70 2218 0 0.04 15 2 2.95 Shallow Pitting. w 71 2249 0 0.03 13 3 2.92 Lt.Deposits. 72 2280 0 0.02 9 2 2.92 Lt.Deposits. 73 2312 0 0.04 15 2 2.94 Shallow Pitting. • 74 2343 0 0.03 10 2 2.92 Lt.Deposits. ■ 75 2374 0 0.03 11 3 2.93 Lt.Deposits. ■ 76 2405 0 0.03 11 3 2.93 Lt.Deposits. ■ 77 2437 0 0.03 11 2 2.93 Lt.Deposits. ■ 78 2468 0 0.03 11 2 2.94 • 79 2498 0 0.03 11 3 2.92 Lt.Deposits. • 80 2529 0 0.03 10 2 2.92 Lt.Deposits. r 81 2561 0 0.03 11 2 2.94 • 82 2592 0 0.03 12 2 2.94 83 2623 0 0.02 8 2 2.91 Lt.Deposits. 2 84 2655 0 0.02 7 2 2.93 Lt.Deposits. 85 2686 0 0.03 12 2 2.93 Lt.Deposits. ■ 85.1 2717 0 0.03 11 2 2.92 Pup Lt. Deposits. 85.2 2723 0 0 0 0 2.90 GLM 1 (NO DEVIATION) 85.3 2732 0 0.03 10 2 2.90 Pup Lt. Deposits. • 86 2738 0 0.03 13 2 2.93 im 87 2769 0 0.02 9 2 2.92 Lt.Deposits. J 88 2800 0 0.04 15 3 2.93 Shallow Line of Pits.Lt. Deposits. ■ 89 2832 0 0.04 15 2 2.95 Shallow Line of Pits. ■ 90 2863 0 0.03 12 2 2.93 Lt.Deposits. N 91 2893 0 0.03 10 2 2.94 IPenetration Body Metal Loss Body Page 2 • III tii 0, PDS Report Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 92 2923 0 0.04 15 2 2.94 Shallow Pitting. ■ 93 2954 0 0.04 14 3 2.93 Lt.Deposits. ■ 94 2985 0 0.03 12 2 2.94 • 95 3017 0 0.04 14 2 2.93 Lt.Deposits. ■ 96 3048 0 0.03 11 2 2.93 Lt.Deposits. ■ 97 3079 0 0.03 13 2 2.94 _ • 98 3110 0 0.04 14 2 2.94 • 99 3141 0 0.03 11 3 2.94 100 3173 0 0.02 9 2 2.92 Lt.Deposits. 101 3204 0 0.03 10 2 2.92 Lt.Deposits. 102 3235 0 0.02 8 2 2.93 103 3267 0 0.03 11 3 2.92 Lt.Deposits. a 104 3296 0 0.03 11 2 2.94 ■ 105 3327 0 0.03 13 2 2.94 • 106 3356 0 0.03 10 3 2.92 Lt.Deposits. ■ 107 3387 0 0.03 13 3 2.92 Lt.Deposits. • 108 3418 0 0.03 12 2 2.91 Lt.Deposits. a 109 3450 0.04 0.03 . 13 3 2.93 Lt.Deposits. • 110 3481 0 0.03 11 2 2.93 Lt.Deposits. E 111 3512 0 0.03 13 2 2.94 • 112 3542 0 0.03 12 3 2.93 Lt.Deposits. • 113 3573 0 0.04 14 3 2.93 Lt.Deposits. 114 3604 0 0.02 9 2 2.93 Lt.Deposits. 115 3636 0 0.03 13 2 2.93 ■ 116 3667 0 0.03 12 3 2.93 Lt.Deposits. • 117 3698 0 0.03 11 2 2.94 ■ 118 3729 0 0.03 13 3 2.91 Lt.Deposits. • 119 3760 0 0.03 13 3 2.92 Lt.Deposits. ■ 120 3792 0 0.03 13 2 2.92 Lt.Deposits. ■ 121 3823 0 0.04 14 2 2.91 Lt.Deposits. • 122 3854 0 0.03 12 2 2.94 • 123 3885 0 0.03 11 3 2.93 Lt.Deposits. ■ 124 3916 0 0.03 11 3 2.93 Lt.Deposits. • 125 3947 0 0.03 11 2 2.95 ■ 126 3978 0 0.03 11 2 2.94 • 127 4009 0 0.03 12 2 2.92 Lt.Deposits. ■ 128 4040 0 0.03 13 2 2.93 Lt.Deposits. ■ 129 4071 0 0.03 10 2 2.93 Lt.Deposits. ■ 130 4101 0 , 0.03 13 2 2.94 ■ 131 4133 0 0.03 13 3 2.92 Lt.Deposits. • 131.1 4164 0 0.04 14 1 2.94 Pup 131.2 4170 0 0 0 0 2.92 GLM 2(LATCH @ 12:00) 131.3 4178 0 0.02 8 2 2.90 Pup Lt. Deposits. 132 4184 0 0.03 12 2 2.93 Lt.Deposits. • 133 4215 0 0.03 13 2 2.91 Lt.Deposits. 134 4247 0 0.02 9 2 2.93 135 4277 0 0.02 9 3 2.92 Lt.Deposits. 136 4308 0 0.03 11 2 2.93 Lt.Deposits. • 137 4339 0 0.03 10 2 2.94 ■ 138 4370 0 0.04 14 2 2.93 Lt.Deposits. IPenetration Body Metal Loss Body Page 3 • • IIII PDS Report Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 139 4402 0 0.03 13 3 2.92 Lt.Deposits. • 140 4433 0 0.03 10 2 2.93 • 141 4464 0 0.03 10 2 2.93 J 142 4495 0 0.03 13 3 2.93 Lt.Deposits. 111 143 4525 0 0.02 9 3 2.93 Lt.Deposits. r 144 4557 0 0.03 11 3 2.91 Lt.Deposits. 145 4588 0 0.02 9 2 2.92 Lt.Deposits. 146 4619 0 0.03 12 2 2.91 Lt.Deposits. li 147 4650 0 0.02 9 3 2.90 Lt.Deposits. 148 4682 0 0.02 9 3 2.90 Lt.Deposits. 149 4712 0 0.03 12 2 2.91 Lt.Deposits. • 150 4744 0 0.03 12 2 2.90 Lt.Deposits. s 151 4775 0 0.03 11 2 2.90 Lt.Deposits. ■ 152 4805 0 0.03 11 3 2.93 • 153 4836 0 0.03 10 4 2.93 • 154 4867 0 0.03 12 2 2.92 Lt.Deposits. • 155 4898 0 0.03 11 2 2.91 Lt.Deposits. • 156 4929 0 0.03 13 2 2.91 Lt.Deposits. • 157 4960 0 0.03 12 3 2.93 Lt.Deposits. • 158 4992 0 0.03 12 4 2.91 Lt.Deposits. a 159 5023 0 0.04 15 2 2.93 Shallow Pitting. Lt Deposits. • 160 5054 0.04 0.04 14 4 2.90 Lt.Deposits. • 161 5083 0 0.03 12 2 2.92 Lt.Deposits. in 162 5115 0 0.03 12 2 2.92 Lt.Deposits. • 163 5145 0 0.04 14 2 2.91 Lt.Deposits. • 164 5176 0 0.03 13 2 2.92 Lt.Deposits. • 165 5207 0 0.03 11 2 2.92 Lt.Deposits. • 166 5237 0 0.03 13 2 2.93 Lt.Deposits. moi 167 5268 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 168 5299 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 169 5331 0 0.03 11 2 2.93 Lt.Deposits. • 170 5362 0 0.03 11 2 2.92 Lt.Deposits. • 171 5393 0 0.03 12 2 2.93 Lt.Deposits. • 172 5423 0 0.03 11 2 2.93 Lt.Deposits. • 173 5454 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 173.1 5486 0 0.03 11 2 2.94 Pup 173.2 5491 0 0 0 0 2.90 GLM 3(LATCH 0 1:00) 173.3 5500 0 0.02 9 2 2.90 Pup Lt. Deposits. 174 5506 0.04 0.04 14 2 2.90 Lt.Deposits. • 175 5537 0 0.03 13 2 2.91 Lt.Deposits. • 176 5568 0 0.03 11 2 2.91 Lt.Deposits. m 177 5599 0 0.03 13 2 2.91 Lt.Deposits. • 178 5631 0 0.03 13 3 2.91 Lt.Deposits. a 179 5660 0 0.04 14 3 2.91 Lt.Deposits. • 180 5691 0 0.03 12 2 2.92 Lt.Deposits. • 181 5721 0 0.03 13 2 2.90 Lt.Deposits. • 182 5753 0 0.04 15 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 183 5784 0 0.03 13 3 2.92 Lt.Deposits. • 184 5815 0 0.04 15 3 2.90 Shallow Line of Pits.Lt. Deposits. ■ 185 5844 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page 4 • • Ili PDS Report�,� 104, po t Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 186 5875 0 0.04 15 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 187 5906 0 0.04 15 2 2.92 Shallow Pitting. Lt Deposits. ■ 188 5937 0 0.04 15 3 2.90 Shallow Pitting. Lt Deposits. ■ 189 5968 0 0.03 13 2 2.92 Lt.Deposits. ■ 190 5999 0 0.03 13 2 2.91 Lt.Deposits. ■ 191 6030 0 0.04 16 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 192 6062 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 193 6093 0 0.04 14 3 2.90 Lt.Deposits. ■ 194 6124 0 0.04 14 2 2.93 Lt.Deposits. ■ 195 6155 0 0.04 14 2 2.92 Lt.Deposits. ■ 196 6186 0 0.04 14 2 2.89 Lt.Deposits. ■ 197 6217 0.04 0.04 15 2 2.90 Shallow Pitting. Lt Deposits. ■ 198 6248 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 199 6279 0 0.04 15 3 2.93 Shallow Line of Pits.Lt. Deposits. ■ 200 6311 0 0.04 15 2 2.90 Shallow Pitting. Lt. Deposits. ■ 201 6341 0.04 0.04 15 4 2.88 Shallow Line of Pits.Lt. Deposits. ■ 202 6371 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 203 6402 0.04 0.04 15 3 2.93 Shallow Pitting. Lt Deposits. a 204 6433 0 0.03 13 2 2.93 Lt.Deposits. ■ 205 6464 0 0.03 13 3 2.93 Lt.Deposits. ■ 206 6496 0 0.04 14 2 2.91 Lt.Deposits. 206.1 6527 0 0.02 9 1 2.92 Pup Lt. Deposits. 206.2 6533 0 0 0 0 2.90 GLM 4(LATCH @ 10:30) 206.3 6542 0 0.03 12 2 2.93 Pup Lt. Deposits. a 207 6548 0 0.03 12 3 2.91 Lt.Deposits. • 208 6579 0 0.03 13 3 2.92 Lt.Deposits. ■ 209 6611 0 0.04 14 3 2.91 Lt.Deposits. ■ 210 6641 0 _ 0.03 10 2 2.92 Lt.Deposits. ■ 211 6672 0 0.03 11 4 2.92 Lt.Deposits. ■ 212 6703 0 0.04 15 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 213 6735 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. m 214 6766 0 0.04 14 3 2.93 Lt.Deposits. ■ 215 6797 0 0.03 13 2 2.92 Lt.Deposits. ■ 216 6827 0.04 0.03 13 3 2.92 Lt.Deposits. ■ 217 6859 0 0.03 13 3 2.91 Lt.Deposits. ■ 218 6889 0 0.04 15 2 2.91 Shallow Pitting. Lt Deposits. m 219 6920 0 0.04 15 3 2.90 Shallow Pitting. Lt Deposits. ■ 220 6952 0 0.04 14 3 , 2.91 Lt.Deposits. ■ 221 6983 0 0.03 13 4 2.92 Lt.Deposits. a 222 7014 0 0.04 16 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 223 7045 0 0.03 13 4 2.92 Lt.Deposits. ■ 224 7075 0 0.04 15 3 2.90 Shallow Pitting. Lt Deposits. ■ 225 7107 0 0.04 14 3 2.89 Lt.Deposits. ■ 226 7138 0.04 0.04 14 2 2.90 Lt.Deposits. ■ 227 7169 0 0.04 15 2 2.91 Shallow Pitting. Lt Deposits. ■ 228 7200 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 229 7231 0 0.04 14 2 2.89 Lt.Deposits. ■ 230 7263 0 0.04 14 2 2.90 Lt.Deposits. ■ 231 7294 0 0.04 15 3 2.89 Shallow Pitting. Lt Deposits. ■ 232 7325 0 0.04 15 2 2.89 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page 5 • • 110, PDS Report Joint Tabulation Sheet Well: 3N-19 Survey Date: May 29, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. 50 ft. 7,693 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 233 7356 0.04 0.04 15 3 2.90 Shallow Pitting. Lt Deposits. 234 7388 0 0.04 14 2 2.90 Lt.Deposits. 234.1 7419 0.04 0.04 15 3 2.92 Pup Shallow Line of Pits.Lt. Deposits. 234.2 7426 0 0 0 0 2.89 GLM 5(LATCH @ 5:00) 234.3 7433 0 0.03 11 1 2.93 Pup Lt. Deposits. 235 7439 0 0.03 11 3 2.89 Lt.Deposits. 236 7470 0 0.03 13 3 2.90 Lt.Deposits. 237 7502 0 0.03 13 3 2.90 Lt.Deposits. 238 7532 0 0.04 17 2 2.89 Shallow Line of Pits.Lt. Deposits. 239 7563 0.04 0.06 23 4 2.89 Line of Pits. Lt.Deposits. 240 7594 0.05 0.06 25 4 2.84 Line of Pits. Lt.Deposits. 240.1 7626 0 0.04 15 2 2.89 Pup Shallow Line of Pits.Lt. Deposits. 240.2 7632 0 0 0 0 2.74 BAKER 80-40 PBR W/SEALS 240.3 7647 0 0 0 0 2.66 7" FHL RETRIEVABLE PACKER 241 7657 0 0.06 22 6 2.82 Line of Pits. Lt.Deposits. IPenetration Body Metal Loss Body Page 6 • • 111111 PDS Report Cross Sections Well: 3N-19 Survey Date: May 29,2017 Field: Kuparuk Tool Type: UW MFC 24 No.211387/218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 240 at depth 7,608.310 ft. Tool speed=49 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% / Tool deviation=56° 1 Finger=20 Penetration=0.064 in. Line of Pits 0.06 in.=25%Wall Penetration HIGH SIDE=UP S PDS Report Cross Sections Well: 3N-19 Survey Date: May 29,2017 Field: Kuparuk Tool Type: UW MFC 24 No.211387/218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Cross Section for Joint 239 at depth 7,571 .030 ft. Tool speed=49 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=55° 1 Finger= 1 Penetration=0.059 in. Line of Pits 0.06 in.=23%Wall Penetration HIGH SIDE= UP • • • KUP PROD 3N-19 ConocoPhillips <°rl Well Attributes Max Angle&MD TD Alaske,Inc. Wda.or3 A5OOVa Field Name We/bore Status Incl II MD(nap) Act Btn,1111(B)(<nucd 500292305600 KUPARUK RIVER UNIT PROD 97.97 9.743.44 10.5150 .•. Comment w4(pp. End Dace Asa 3N-19.miaow 1:01:35 PM SSSV NIPPLE 130 11/25/2012 Lest WO: 6256 1/17/2002 Oerxr.a..o,aK(email ArnoletiOn Depth MD) rand Daae Annotation Law Mod By End Date Last Tag: 10.032.0 14272002 Rev Reason:GLV C/O HANGER:24.0 bipshb 7/312014 IVO Casing Strings Casing Desctip[Ion OD lin) ID(in) Top ICES) See Depth IttKB) Set Depth 11905..WULen(I...Grade Toa Thread iCONDUCTOR 16 15.062 30.0 1500 150.0 62.50 1+40 WELDED I �1 Casing Deacnptem OD gni (0((n) Top IRKB) Sat Depth(SKe) Sat Depth(TVD)...Wt/L.(1...Grade Top Thread SURFACE 95/8 8.835 29.7 3.649.1 3.620.7 40.00 L-80 BTC .. .., •:.,...•.•..• .mruM 41001 Caawg Oeocnptbn OD(M) O(1n) Top(Ste) Set Depth(/1116) Set Dep111 1(90...WeLan(L..Grade Top Thread PRODUCTION 7 6.276 28.0 8.755.8 6.461.2 26.00 L-80 BTC-Mod Casing Desenptip 013(I0) D lin) Top(SEB) Set Depth MB) Set Depth(1901...WI/Len IL..Grade Tp Thread LINER 3 1/2 2.992 8.571.6 10.488.0 6.446. 9.30 L-80 IRT Liner Details CONDUCTOR:10-0.100.0--a + Nominal ID Top(N®) Top(TV0)(8KB) Tap led 19 Item Dea Com (in) • NwPLE.er.a 8.571_6 6.4547 91.52 PACKER Baker ZXP Packer 8 Tie Back Sleeve 5.250 8.58SX 6.454-3 91.11 HANGER Maker 5'x 7 eFIex Lock Heger 4.281 4 8.594.7 6.4542 90.84 PBR Bak 9097 Polished Bae Receptacle 4.000 OAS 2.707.3 �� 8.606.9 6.454.0 90.97 XO 51(3.5". XO-5'L-80 Stub ACME x 3-1/2'L-60 EUE Bed 2.992 8.617.4 6.454.0 90.16 XO 4-5x3' XO-4-1/2"SLI-17 box x 3-12'EUE 8rd Pin 2992 10.453.6 644/.0 9166 BUSHING Peck-of bushing 2992 • Tubing Strings SURFACE 2O33.0.1--.a de, Tubing DescriptionString Ma...ID(in) Tp OMB) Set Depth(h..Set Depth(TVD)(...WI(113M) Grade Top Connection TUBING I 31/2 2.992 24.91 8.600.61 6454.1 9.301 L-80 EUE Sod Completion Details OAS LIFT:d.tee.7 Nomnw lD Tp(Im8) Tp(TVD)(ttKel Tp itml I') Sam Dee Com (in) 24.9 24.9 0.06 HANGER 3-12'FMC Gen V Tubing Hanger 2.992 4 - 3.01 IP LE mco nipple._.87510 2.875 OAS UFT,5.30.04 - 7.633.7 6.282-7 PBR Baker 12'8040 PBR w/12'seals inside 3.000 7:647.4 .7 PACKER 7'.2611 FHL Retrievehle Pedlar 3.000 .4 ,3A LE BAKER CMU Sliding Sleeve Wl Camco DSprotla.2812' 2.812 OAS LIFT:0,531.0 4 ID(OPEN 4/16/2007) 7.933.9 6.408.3 72-76 SLEEVE-0 BAKER CMU SI i ng Sleeve w/Carnco DS profile.2.75' 2.750 ID(OPENED 6272010) 85723 6.454.6 91.49 LOCATOR LOCAI()4 SUB 3.000 OAS LIFT.7,4aa1 4 8.574.0 6454.6 91 45 SEAL ASSY Bakes 80-40 Seal Assembly 3 000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top I1VD) Tp Incl Top Ira(.) (nOel I') Dee Com Run Date 10(In) P0R:7,033,7 -- 8.6150 6.454.0 90.23 VALVE BAKER KNOCKOUT ISOLA TION VALVE(KOIV) 1/3(2002 PACKER:>.000.3 MILLED OUT 4/26/2002 10.488.0 64460 91.66 FISH FISH LOST DURING DRILLING&COMPLETION 1/102002 0.000 Perforations&Slots Shot Dans Tp KB Bim(TVD) (ahI SLEEVED 7.757.4Tp laKel B.Baca) (.(TI (MUM 2030 Om g Type Gam 7.850-0 7.8600 6.380-0 6.383.7 A-3.3N-19 1/14/2002 6.0 IPERF 4.5"91-1C.60 dog phase 9.182.0 10.454.0 6.463.9 6.446.9 A-2.A-3.A-6. 1/10/2002 99-0(PERF SLO rihD UNEF( A-5.A-3.3N- 19 FRAiPERF;7.350.0-; :o-11 I 1 Stimulations&Treatments Min Tp Max Bbn Depth Depth Top ITVD) Blm(TVD) OMB) (MB) (MB) (aK8) Type Date 11310 ■ 7.850.0 7.860.0 6.380.0 6.383.7 FRAC 4222002 FRAC PUMPED THRU TWO SLIDING SLEEVES 7757'8 1934';1548 BEHIND PIPE sLeeUe.o:7.000,0 I Mandrel Inserts St I. al l C ... IIo Tp MID) Valve Isdr part alas IRO Run m Tp(SKS) (MUM Melte Modal OD(ai) Sere TYpe Type 1071188 ni (esti Ran Uwe 1 2.7072 2.684.4 Carnes WAG 1 12 GAS LIFT GLV RKT 0.188 1297.0 4/28/2082 LOCATOR:0.072.0 2 4.1591 4.0984 Cameo MMC 1 12 GAS LIFT GLV RK 0250 1.326.0 4/28/2002 SEAL ASSY,0.0,4.3 3 5.485.8 5.024.7 Carrico MAG 1 12 GAS LIFT GLV RK 0150 1.311.0 4282002 4 6.531.9 5.643.7 Ceneco min 1 12 GAS LIFT GLV RK 0250 1.302.0 428/2002 5 7.426.1 6.1642 Comm MMG 1 12 GAS LIFT 'OV RK 0150 0 0 7/30/2014 Notes:General S Safety End Date Annotation 9/8/2009 NOTE:VIEW SCHEMATIC W/Aleske Schomo6c9.0 1 Vu.vE,aetap PROODCTION:28.041.75.0 s A WPERF.e.tad O.t0.4sr.o / LINER;t .e orrdL 4aeFL4H:113,4811.0--1, 41 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3N-19 Run Date: 7/2/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 3N-19 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23056-00 Production Profile Log 1 Color Log 50-029-23056-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. SCANNED J U Ni 2 3 20!? Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 9/14 /12- Signed: ALL.. • • `/ ConocoPh i I 1 i ps Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~, C ~o ~ - d/-~ Dear Mr. Maunder: ~J ~ ~ , f Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 19, 2008 and the corrosion inhibitor/sealantwas pumped October 21, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,~ ~~ ~~~~ ~ ~~ ~~~$ ` ~ `, `~ ~~~~ ~' MJ La eland 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 n~to 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10!21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 01/24/07 Schlumbepger NO. 4121 Schlumberger -DCS 'l.Qt)? 2525 Gambell Street, Suite "!º9..I.~.ED JAN S \) Anchorage, AK 99503-283~' A TTN: Beth ,I/\N 2. 9 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n" 80 1- d~Š-- Field: Kuparuk Well Job # Date BL Color CD Log Description 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05107 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 NIA GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y·22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'-\ . . . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc I ~ hi]"  èJ \ ~ DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012250 Well Name/No. KUPARUK RIV UNIT 3N-19 MD 10515 ,.--. TVD 6445 ,...--- Completion Date 1/16/2002 " .r- Operator CONOCOPHILLlPS ALASKA INC )f1~ III~~ I API No. 50-029-23056-00-00 Completion Status 1-01L ----_____.0 - - ------ ---'-'-------'-'~'._"-------'---------'---------------------- REQUIRED INFORMATION Mud Log No Samples No - - - . ~-----_.__._---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Ty'pe Med/Frmt ED D Electr Dataset Number v1'0768 ~571 ffi25 See Nòtes . Log Log Scale Media Run No 1 1 1 Name LlSVèrificatidri. . See Ndtès ~ ~767 ~4 D C ~572 C Log J1r~q~èti(11Î .... 5 Blu ----------------- -------"------------- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y 1 N Daily History Received? Chips Received? Y 1 N Formation Tops Analysis Received? Y/N -----.--------- --.-.------ --------"-'--------------. -----.-----------.--- -"-------'-----'----'----'-- Current Status 1-01L UIC N --------- .---------------.--- .------------ ---"---'---.------ Directional Survey Yes"- ----- --,------,----- (data taken from Logs Portion of Master Well Data Maint) ( Interval OH / Start Stop CH Received Comments 89 10464 Open 4/19/2002 PB1 89 10515 Case 2/18/2003 Digital Well Logging Data 89 10483 Case 12/6/2002 Digital Well Logging Data 1 Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity PB1 10431 Open 4/19/2002 PB1 89 89 10515 Case 12/6/2002 Digital Well Logging Data 1 Rate of Penetration, Dual' Gamma Ray, Electromagnetic Wave Resistivity Digital Well Logging Data PB1 ~~ 89 10483 Case 2/18/2003 200 8030 Case 12/20/2002 ---------.-.-.----- Sample Set Number Comments @/N cYÞN DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012250 Well Name/No. KUPARUK RIV UNIT 3N-19 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23056-00-00 MD 10515 TVD 6445 Completion Date 1/16/2002 Completion Status 1-01L Current Status 1-01L UIC N Comments: ptJ ~ f-- :-.-. ((;;, (~ M (, C e/lY1,t.-vJ--lbðv-.tÍ.- ~. I À.. J ~ ~),. ~ 'tò~ ~ ?~ÅD co.--L I~. ~Pliance Reviewed By: ~=~~-~~~~-=-_~_m~ ---~---"--------------_...'_.._--_._-----,------"--_..'''-'- ------------ Date: -~.-=~.'J-7:~-~==:¡~~-------_.__P._. ( C-- ( { ( aOJ~d~ 5 /151;? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 12,2002 RE: MWD Formation Evaluation Logs 3N-19 PBl, AK-:MM-11209 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3N-19 PDt: Digital Log Images 50-029-23056-70 1 CD Rom ~~ REceiVED FEB 1 8 2003 Alaska on & Gas Cons. ConIOiIiDn Anchcnge (' (' aO{~~d5 1157/ WELL LOG TRANSMI1TAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 l\nchorage,Alaska 99501 November 12, 2002 RE: MWD Formation Evaluation Logs 3N-19, AK.J\.1M-11209 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., l\nchorage, AK 99518 3N-19: Digital Log Images 50-029-23056-00 1 CD Rom ~~ REceiVED FE8 1 B 2003 Alaska Oil & Gas Cons. ~ Andtœage 12/11/02 Scblumbepgep NO. 2602 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description ( Date BL Sepia CD Color 1R-14 ,c~-/5? I LEAK DETECTION 11/30/02 1 1 Y -16 rÇ '3-Dt./¿J RST-WFL 11/28/02 1 3H-01 rr¡-I J 0 PRODUCTION PROFILE 12/01/02 1 3N-19 ¿j\O/-dJ)~ PRODUCTION PROFILE I 12/03/02 1 liiio.... ECEi'1 I~ t SIG~~ ED DATE: DEC 20 2002 A\aeka Od & Gas COns. COmmission And'torage Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ,I. ( ~: aÒ/-dd5 II c¡ d5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 12,2002 RE: MWD Formation Evaluation Logs 3N-19 PB1, AK-MM-11209 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3N-t9 PDt: Digital Log Images 50-029-23056-70 1 CD Rom RECEIV,ED DEC 06 2002 ,AJaaka O¡i & Gas Com~. Commjoion Anchcnge ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 12,2002 RE: MWD Formation Evaluation Logs 3N-19, AK-MM-11209 aO/-dd~ II'IdV The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3N-19: Digital Log Images 50-029-23056-00 1 CD Rom RECE\VEO DEC 06 2002. þJ ita Qtl &. Gas Cons. Commi~ion as Anchorage ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 16, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3N-19 (201-225) Dear Commissioner: ( Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent well work operations on the KRU well 3N-19. If there are any questions, please contact me at 263-4574. Sincerely, ;1u(~ M. Mooney Wells Team Leader Phillips Drilling MM/skad in RECEIVED JUN "I 2 2002 Alaska Oil & Ga~ GO( f. \ÞŒwfì¡~~1;jÜ! Anehn(A~1f: ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface Development _X Exploratory - Stratigraphic - Service Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 29.7 feet 7. Unit or Property name 1. Operations performed: Operation shutdown- Pull tubing - Stimulate _XX Alter casing - 5. Type of Well: 3717' FNL, 5206' FEL, Sec. 28, T13N, R9E , UM At top of productive interval 1176' FNL, 1981' FWL, Sec. 33, T13N, R9E, UM At effective depth (asp's 518471, 6013799) Kuparuk Unit 8. Well number 3N-19 9. Permit number 1 approval number At total depth 2975' FNL, 1360' FEL, Sec. 33, T13N, R9E , UM 12. Present well condition summary Total depth: measured true vertical (asp's 522343, 6009273) 201-225 / 10. API number 50-029-23056 11. Field / Pool Kuparuk Oil Pool (asp's 520396, 6011068) 10515 feet 6445 feet Plugs (measured) Effective depth: measured 1 0488 feet Junk (measured) true vertical 6446 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 150' 16" 345 sx AS 1 150' 150' SURFACE 3586' 9-5/8" 563 sx AS Lite & 196 sx LiteCrete 3649' 3621' PRODUCTION 8693' 7" 410 sx Class G 8756' 6461' LINER 610' 3-1/2" (included above) 9182' 6464' SLOTTED LINER 1272' 3-1/2" none 1 0454' 6447' OPEN HOLE 33' 1 0488' 6446' Perforation depth: measured 7850' - 7860' true vertical 6380' - 6384' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 8601' MD. JUN "I 2 2002 Packers & SSSV (type & measured depth) BAKER FHL RETRIEVABLE PACKER @ 7647' MD; BAKER ZXP FAlaÐkaDiill&~fSQÊ!~v[;¡~f~~ftM~; CAMCO 'OS' @ 488' MD. ,Anchoraoe 13. Stimulation or cement squeeze summary Intervals treated (measured) 7850' - 7860' Treatment description including volumes used and final pressure 154M# behind pipe, 10 ppa on perfs 14. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl 2398 1510 16 CasinQ Pressure TubinQ Pressure 269 248 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Oil- X Gas- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2246 1506 13 Suspended - Service - Questions? Call Mike Mooney 263-4574 ~::rod b ,!~c:,i!o~~63~612 Signed Michael Moone Title: Wells Team Leader Form 1 0-404 Rev 06/15/88 . ORIGINAL ~ SUBMIT IN DUPLICATE Date 04/10/02 04/11/02 04/12/02 04/13/02 04/14/02 04/16/02 04/17/02 04/19/02 04/20/02 04/22/02 04/25/02 04/25/02 04/26/02 04/28/02 ( ( 3N-19 Event History Comment DRIFTED TBG -3' X 2.7311 DRIFT TO 8071' WLM. INSTALLED DV @ 2707' RKB. IN PROGRESS. [TAG] INSTALLED SPARTEK @ 7425' RKB, DV @ 4160' RKB. PTTBG & CSG TO 2500#. BOTH GOOD TESTS. [GL V] LEFT TOOLSTRING & CUTTER BAR IN WELL. IN PROGRESS [FISH] FISHED CUTTER BAR & TOOLSTRING. UNABLE TO PULL E-LlNE TOOLSTRING. SET OVERSHOT. READY FOR CTU. [FISH] ATTEMPTED TO FISH SLB / BAKER SETTING TOOL STRING FROM PLUG SET @ 7955' MD. AFTER 4 JAR LICKS (6K TO 16K# OVER), BAIT SUB PULLED OFF FISH. CTU STILL RIGGED ON LOC. WI INJECTORfT-BAR BACK TO ALLOW SLlCKLlNE ROOM TO RIG UP IN A.M. [FISH] RAN 2.7811 LIB, TAGGED TOP OF E-LlNE ROPE SOCKET @ 7926' WLM, GOOD IMPRESSION OF ROPE SOCKET. IN PROGRESS [FISH] PLANTED 2.7211 X 4811 BOWEN OVERSHOT ON E-LlNE TOOL STRING @ 7926' WLM, COMPLETE [FISH] LATCHED BAIT SUB AT 7915' CTM WI WEATHERFORD FISHING BHA (MHA,WGT. BAR, UP/DOWN JARS, DISCON, CIRC SUB, GS). FISH PULLED FREE (VERIFIED BY ATTEMPTING TO CLOSE MASTER ONCE AT SURFACE). PULLED 35' E-LlNE TOOLSTRING FROM 7923' WLM, PRESSURE TESTED TBG TO 4500 PSI, GOOD TEST, OPENED BOTH CMU SLIDING SLEEVES @ 7934' & 7757' RKB COMPLETE. PUMPED A SAND FRAC. PLACED 154M# BEHIND PIPE, 10 PPA ON PERFS, FLUSHED TO COMPLETION. PLACED 100% OF DESIGN. SAW TSO -53 MINUTES INTO JOB, GOOD PRESSURE BUILD SEEN THROUGH LATER STAGES OF JOB. [FRAC-REFRAC] CLOSED CMU @ 7757' RKB. ATTEMPTED CLOSE CMU @ 7934' RKB. IN PROGRESS. [OPEN-CLOSE C SAND] PERFORMED A REVERSE FILL CLEANOUT TO 7951'.4' CTMD. TOP OF COMPOSITE BRIDGE PLUG. FREEZE PROTECT WELL TO 2500'. LEAVE SHUT IN FOR WIRELlNE ATTEMPT OF CLOSING BAKER CMU. CLOSED LOWER CMU @ 7934' RBK. TESTED TBG 2500 PSI, OK. REMOVED A COMPOSITE PLUG FROM 7952.1' CTMD. RAN IN HOLE TO 10,032' CTMD TO INSURE THAT WE DRILLED UP ALL OF THE PLUG. IN SEVERAL AREAS WE APPEAR TO BE DUNNING AS WE RIH. WE WORKED THROUGH THESE AREAS TO CONTINUE ON. PULLED SPARTEC SPG @ 7426' RKB. INSTALLED NEW GLVS. OPENED LOWER CMU @ 7934' RKB. [GLV, PRESSURE DATA, OPEN-CLOSE A SAND] Page 1 of 1 5/15/2002 ( a O/-das ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska April 10,2002 RE: MWD FOffilation Evaluation Logs 3N-19, AK-:MM-11209 1 LDWG fOffilatted Disc with verification listing. API#: 50-029-23056-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNJNG A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. ~chorage, Alaska 99518 DRfCEßLED Sign~~D~ I L P;J '1 0 iJOO? ~ -¡ ¡ \ . / L ..... Alaska Oil & Gas Cons. Commission Anchorage aO/--d a s { WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7t11 Avenue, Suite 100 Anchorage, Alaska April 10,2002 RE: MWD Formation Evaluation Logs 3N-19 PBI, AK-MM-11209 1 LDWG formatted Disc with verification listing. llPI#: 50-029-23056-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEßlED Signed:c7)~ 1J200p/J f. r'0 ,¡ 9 000? f\r~/r\ ~ L IJ.. Alaska Oil & Gas Cons. Commission Anchorage ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 March 27,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3N-19 (201-225) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 3N -19. If you have any questions regarding this matter, please contact Scott Reynolds at 265-6253. Sincerely, ~~ R. Thomas f Greater Kuparuk Team Leader P AI Drilling ,!(: RT/skad RECEIVED APR 1 za02 Al88kaOll&GllConI.COInIIIiIiOO AndØ8g8 ~" &~I ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator . tOt::Aro~ 7. Permit Number Phillips Alaska, Inc. YflnFitÐ 201-225 3. Address S<~l F"Y""" 8. API Number J P. O. Box 100360, Anchorage, AK 99510-0360 .;'". ~ 50-029-23056-00 4. Location of well at surface .". j~~~"".~~...~~";;:j 9. Unit or Lease Name ~~ 1~; ~..-:. 1560' FSL, 71' FWL, Sec. 28, T13N, R9E, UM n' - (asp's: 518471, 6013799) Kuparuk River Unit At Top Producing Interval ~J!í.~~..L.. 10. Well Number 1176' FNL, 1981' FWL, Sec. 33, T13N, R9E, UM \,.'ò'" ',' (asp's: 520396, 6011068) 3N-19 At Total Depth .--AL'n 11. Field and Pool -.. 2305'FSL, 1355'FEL,Sec.33,T13N,R9E,UM '0"" (asp's: 522343, 6009273) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Pool RKB 29.7 feet ADL 25520 ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions December 11,2001 January 2, 2002 January 16, 2002 N/A 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 10515' MD / 6445' TVD 10488' MD / 6446' TVD YES 0 No 0 Camco Landing Nipple 488' 1730' 22. Type Electric or Other Logs Run GR/Res, US IT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 150' 24" 345 sx AS 1 9.625" 40# L-80 Surface 3649' 12.25" 563 sx AS Lite & 196 sx LiteCrete 7" 26# L-80 Surface 8756' 8.5" 410 sx Class G 3.5" 9.3# L-80 8572' 10488' 8.5" (included above) 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" 8601' 7647' & 8571' 7850' - 7860' MD 6380' - 6384' TVD 6 spf 9182' - 10453' MD slotted liner 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 8, 2002 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/12/2002 15 hours Test Period> 790 1214 17 100 827 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 203 psi not available 24-Hour Rate> 1269 1950 27 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RECeiVED APR 1 2002 Al8kaCl&GllConI.C01IIßIi&Iion AndtOJIge Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ i\ ~ 1\ I - 0 f ~ ~ \J l~\ LR B 0 M 5 B F l APR Submit in duplicate () ,1 2002 29. \ GEOLOGIC MARKERS 30. (' FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 7550' 7663' 7800' 10152' 6238' 6298' 6360' 6442' Annulus left open. freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 ~ .,- \ Signed \ ~ \ ~ -- ~ Tnle R. Tho as KUDaruk Drillina Team Leader Date "3 (2 6( () 2 Prepared by Sharon Allsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 :( Page 1 of19 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From- To Hours Code 11/12/2001 20:00 - 00:00 4.00 MOVE RURD MOVE 11/13/2001 00:00 - 05:30 5.50 MOVE DMOB MOVE 05:30 - 07:00 1.50 MOVE DMOB MOVE 07:00 - 12:00 5.00 MOVE DMOB MOVE Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of . Operations 12:00 - 00:00 12.00 MOVE DMOB MOVE 11/14/2001 00:00 - 04:00 4.00 MOVE DMOB MOVE 04:00 - 08:00 4.00 MOVE DMOB MOVE 08:00 - 00:00 16.00 MOVE MOVE MOVE 11/15/2001 00:00 - 01 :00 1.00 MOVE MOVE MOVE 01 :00 - 02:30 1.50 MOVE OTHR MOVE 02:30 - 05:00 2.50 MOVE MOVE MOVE 05:00 - 08:00 3.00 MOVE RURD MOVE 08:00 - 09:30 1.50 MOVE OTHR MOVE 12/10/2001 00:00 - 04:30 4.50 DRILL RIRD SURFAC RID topdrive (changed pipe handler to 5" to break saver sub out). Finished RID topdrive (4.5 hrs). Prepared B all Mill for move, cleaned dewater pit. Cut 94' of drlg line. Slip extra line on drum Prepared to skid floor back. Prepared to se parate modules. Drove Power Module away f rom Sub Module. Removed boiler stacks on sub module, moved Ball Mill to end of pad. Spot Power Module to remove tire (to be rep aired in Prudhoe). Removed cattle chute. Skid rig floor back. Moved Sub Module to c enter of pad. Removed BOP eqpt. Removed kill line. Installed Booster Assy. Held PJ SM prior to new tasks wI all hands involved. Unload repaired wheel & tire from truck. Pi n rear booster wheel assy to Sub Module. I nstall wheel & tire on rear of Power Module and air up. Removed windwall bubbles from Sub Module & put in pipe shed. Load items in pipe shed Fuel both modules, air up tires, drive bot h modules to 2T pad entrance. Move Sub & Power modules from 2T pad to 0 liktok Staging Area. Moved both modules to 3K pad turnoff. Fueled both modules. Refilled dye tank. C hecked all tires, 150 psi. Finished moving both modules to Oliktok Sta ging Area. Still have the camp to move. Spot Sub Module in center of pad. Spot Po wer Module next to Sub Module & hook up se rvice lines between modules. Skid rig floor out & install hand rails and hook up service lines to floor. Moved camp to Oliktok Staging Area. RIG CAMP ARRIVED @ 18:00 hrs. In order to g et things back to being fair between Nabors & PAl.... we SUBTRACTED OUT 8.5 HRS FR OM 18:00 HRS. This was the time spent on 2T pad laying down the topdrive. So this is how we did it.... This is the final report for this event. PLEASE NOTE - this DIMS report is the 5th report for Well 3N-19. The 4th report was dated 15th November 2001. THE EVENT BE TWEEN THESE TWO REPORTS WAS THE RIG MODIFICATION TO HERC MODE & CHANGE OUT OF RIG CAMPS ON AFE AX2165. RIG A C C E P TED TO A F E A K 021 7 AS 0 F 00: 00 H R S 10th D e c 2 0 0 1 0 r 2 4 : 0 0 H R S9 t h Dee 2 0 0 Printed: 3/12/2002 4:25:34 PM ( i( PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 12/10/2001 00:00 - 04:30 4.50 DRILL RIRD SURFAC 04:30 - 07:00 2.50 DRILL RIRD SURFAC 07:00 - 08:00 1.00 DRILL RIRD SURFAC 08:00 - 09:30 1.50 DRILL RIRD SURFAC 09:30 - 12:00 2.50 DRILL RIRD SURFAC 12:00 - 12:30 12:30 - 13:00 0.50 DRILL RIRD SURFAC 0.50 WELCT BOPE SURFAC 13:00 - 14:00 1.00 DRILL PULD SURFAC 14:00 - 15:00 1.00 DRILL PULD SURFAC 15:00 - 17:00 2.00 DRILL PULD SURFAC 17:00 - 21 :30 4.50 DRILL PULD SURFAC 21 :30 - 22:00 0.50 DRILL RIRD SURFAC 22:00 - 23:00 1.00 DRILL PULD SURFAC 23:00 - 00:00 1.00 RIGMNT RGRP SURFAC 12/11/2001 00:00 - 00:30 0.50 DRILL SFTY SURFAC 00:30 - 02:00 1.50 RIGMNT RGRP SURFAC 02:00 - 04:00 2.00 DRILL PULD SURFAC 04:00 - 07:30 3.50 DRILL PULD SURFAC 07:30 - 08:30 1.00 RIGMNT RGRP SURFAC 08:30 - 09:30 1.00 DRILL TRIP SURFAC 09:30 - 10:00 0.50 DRILL DRLG SURFAC Page 2 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations 1. Modified bell nipple. Circ'd mud in pits & checked for leaks, OK. N/U diverter system. Install diverter line & post sign. Install strip-o-matic track & strip-o-matic. PIU jt of 5" dp. Function test bag & knife valve on diverter I ine, OK. Weld pad eyes on riser for turnbuc kles. LID 5" subs & floor valves. Take 5" dp & HWDP out of pipe shed. Instal I turnbuckles on riser, circ thru flowline & c heck for leaks. Work on hydraulic man ride r installation. Pressure test hi pressure lines, OK. Perform diverter test of annular & knife valv e in diverter line + Koomey unit. Start loading pipe shed with 4" HT-38 drillp ipe. Prepare floor to P/U 105 jts of drillpi pe. (Also installed last section of diverter I ine... waited on this to allow easier access for water trucks). Inspect derrick before P/U drillpipe. Also P JSM on laydown machine. Finished loading pipe in pipe shed. Finish work on man riding tugger. PJSM prior to P IU drillpipe. PIU 4" drillpipe. Repaired leak on drawwork s spear (10 minutes). Finished P/U 4" drillp i p e. Changed elevators & jaws on iron roughneck to 5". P/U 5" HWDP ( 29 jts). Repaired hydraulic hose on iron roughneck. Pre-spud walk around and check list. Finished repairing hydraulic leak on iron rou ghneck. P/U 5" HWDP & jar and rack in derrick. PI U 5" subs and floor valves (TIW & ISBOP). P/U BHA and surface checked mud motor & MWD (Directional + GR). Installed strip-o-matic and had to work it an d clean it out to get it from being seized up Tagged ETD @ 150'. Fill 16" conductor and circ'd and checked for leaks, OK. Calibrate d Sperry Sun. (EPOCH not up and running y et. We do have H2S and Total Gas heads th at belong to the rig at key locations and fun ctioning. EPOCH had some eqpt failure & t hey are working on it.. ) D rid 1 2 - 1 I 4" h 0 I, e f I 1 5 0 - 1 5 6 I . ART = O. 2 5 hrs & AST= 0 hrs. (Yes, this was a little sl ow. The reason was that we wanted to chec Printed: 3/12/2002 4:25:34 PM (' / ~ ~ ~ (PHILL¡¡'S~ lUi { PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase .. Code 12/11/2001 09:30 - 10:00 0.50 DRILL DRLG SURFAC 10:00 - 10:30 0.50 RIGMNT RURD SURFAC 10:30 - 00:00 13.50 DRILL DRLG SURFAC 12/12/2001 00:00 - 05:30 5.50 DRILL DRLG SURFAC 05:30 - 07:00 1.50 DRILL CIRC SURFAC 07:00 - 08:30 08:30 - 10:30 1.50 DRILL WIPR SURFAC 2.00 DRILL RIRD SURFAC 10:30 - 12:00 1.50 RIGMNT RGRP SURFAC 12:00 - 13:00 1.00 DRILL WIPR SURFAC 13:00 - 13:45 0.75 DRILL CIRC SURFAC 13:45 - 22:45 9.00 DRILL DRLG SURFAC 22:45 - 23: 15 0.50 RIGMNT RGRP SURFAC 23:15 - 00:00 0.75 DRILL DRLG SURFAC 12/13/2001 00:00 - 20:30 20.50 DRILL DRLG SURFAC 20:30 - 21 :30 1.00 DRILL CIRC SURFAC Page 3 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations k out the new cuttings transfer system over to the ball mill. Glad we did, it was not wo rking as good as we needed it to.) Installed mud jet into auger system at the d rop off point to the cuttings tank. Fluid ha d been trying to go past this point and into the "backup I safety tank". Finished install ing jet, tested, OK. Drld 12-1/4" hole fI 156 - 884' md (803' tvd) ART=3.0 hrs & AST= 5.25 hrs. Started of f with slower gpm until we saw that the tran sfer pumps fromt the cuttings tank to the ba II mill were working good. We had scribed the BHA into the well and after +1- 50', we were below steel interference on the MWD. Nudged well for close approach near 598' md & 1600' md. Drld 12-1/4" hole f/ 884 - 1121' md. ART= 0 .5 hrs & AST= 4 hrs. (Drld the BHA + HWD P down + 2 jts of 5" dp. We used the 2 jts of 5" dp as rathole for any fill on the trip. This way, if we did have fill we had room to get the 5" BHA in the hole and start the 4" dp so we could screw into it with the topdriv e. ) Circulated just 2 bottoms up, as well is ess entially vertical. Flow checked well, no flo w . B I e w d 0 w n top d r i v e &, mud I i n e s wit h air. Did not pump slug. POOH to 156'. Changed saver sub on topdrive from 4-1/2" I F to 4" HT-38 thread. Observed well on tri p tank thru out. Changed mud bucket to 4". Replaced seals in top drive positioning sens or cylinder. TIH, hole in good shape in and out. No fill Circulated and conditioned mud until able to pump at drillings strokes and not too much mud going to cuttings pit. Mud was thick and aereated. Drld 12-1/4" hole fI 1121 - 1957'. Drld wit h 425-450 gpm thru Permafrost. Once below we eased the gpm up. Generators kicking out the SCR's. One gen erator taking all the load. Repaired same. Dlrd 12-1/4" hole fI 1957 - 2029' md (2006.6 'tv d). Total ART= 6.75 hrs & AST= 3 hrs si nce 1121' md. Drld 12-1/4" hole from 2029 - 3662' md (363 3' tvd). Circulated 1 bottoms up. f low. Flow checked, no Printed: 3/12/2002 4:25:34 PM ,( ( Page 4 of 19 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From- To Hours Code Sub Phase Code 12/13/2001 21:30 - 23:15 1.75 DRILL CIRC SURFAC 23: 15 - 23:45 0.50 DRILL OBSV SURFAC 23:45 - 00:00 0.25 DRILL WIPR SURFAC 12/14/2001 00:00 - 05:30 5.50 DRILL WIPR SURFAC 05:30 - 07:00 1.50 DRILL WIPR SURFAC 07:00 - 11 :00 4.00 DRILL CIRC SURFAC 11 :00 - 11 :45 0.75 DRILL OBSV SURFAC 11 :45 - 15:30 3.75 DRILL TRIP SURFAC 15:30 - 17:30 2.00 DRILL PULD SURFAC 17:30 - 20:45 3.25 CASE RURD SURFAC 20:45 - 00:00 3.25 CASE RUNC SURFAC 12/15/2001 00:00 - 02:30 2.50 CASE RUNC SURFAC 02:30 - 03:00 0.50 CASE CIRC SURFAC Spud Date: 12/11/2001 End: 1/17/2002 G rou p: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations Circulated 2 more bottoms up. Flow checked well, no flow... no losses. Pu mped slug. Blew topdrive and lines down wi t h air. Start POOH for wiper trip to point of last wi per trip @ 1122'. POOH to 2609'. From 2889 - 2609', had nu merous spots of 30-40K Ibs over pull. Hol e seemed good... just acted like we had som ething above us and could not get clear of it in this vertical hole. One the last stand, trying to swab & taking some wt down.. De cided to pump out with drlg strokes f/ 2609 - 2029'. Rotated at 30-40 rpm... hole look s fine. By 2029', we had pumped 2 bttms up Decided to try POOH again. POOH to 11 1 5' . TIH to 3662'. Did not pump to bttm, no fill. Circ'd and conditioned mud. Dropped the v is down from 150-160 to 120, to help reduce any swab tendency. (( Note: In the Herc c onfiguration, we do not have any scalping s hakers.. as such, 2 of the linear shkrs have 50 mesh and the 3rd 38 mesh screens. Not much screening going on.... took awhile to g et back up to full strokes due to clays blindi ng the screens. Need to consider converted one or more shakers to Hi-G type.. possibly by simply changing out motors.)) Flow checked well, no flow & no losses. Pu mped slug and blew down topdrive and lines. POOH and took SLM ( 2.75' difference). LID BHA & bit. R/U to run 9-5/8" casing. Took longer than usual. The new pipe shed does not have an y overhead chain winches to move eqpt arou nd so all csg eqpt came up thru beaver slide As we tried to PIU the Frank's fill up tool ...discovered that the 4" HT-38 crossover on top of their tool was too big for the topdriv es pipe guide. Decided to not run the fill u p tool, as this is a near vertical well. Held PJSM. Made up float shoe & float coil ar joints as per program ( 2 jts between the m). Tested and floats hold and able to pum p thru. Ran casing and centralizers as per program. Ran 9-5/8" casing to 2003'. Ran at 40-50 f tlmin. Ran centralizers as per prgm. Filii ng up every 2 jts. Circulated 1.5 bttms up... (precautionary). Printed: 3/12/2002 4:25:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date { ( Page 5 of 19 PHILLIPS ALASKA INC. Operations Summary Report 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Sub From"' To Hours Code Code Phase 12/15/2001 03:00 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 - 12:30 12:30 - 13:30 13:30 - 17:00 17:00 - 19:30 19:30 - 20:30 20:30 - 00:00 12/16/2001 00:00 - 09:30 4.00 CASE RUNC SURFAC 1.00 CASE RUNC SURFAC 2.00 CEMEN CIRC SURFAC 2.50 CEMEN PUMP SURFAC 1.00 CEMEN DISP SURFAC 3.50 CEMEN RURD SURFAC 2.50 DRILL RIRD INTRM1 1.00 WELLS INTRM1 INTRM1 3.50 WELCT INTRM1 9.50 WELCT Spud Date: 12/11/2001 End: 1/17/2002 G roup: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations Finished running a total of 89 jts of 9-5/8" 4 0 ppf L-80 BTC casing (includes float & sho e jts). No port collar run. Ran casing, hol e in excellent shape. Full returns, no losse s during running. ((Only problems were onc e again with GBR. The stabber was no cutti ng it. Either not enough experience and/or too short.)) Madue up 9-5/8" standard fluted hgr for 16" conductor (no mods to hgr). Made up landin g joint. Landed hanger @ 29.66' from rig fl oor... spot on. R/U cmt head & cmt lines. Circ'd & conditioned mud rheology and mud wt down for cmt job. Held PJSM during con ditioning of mud. Tested cmt manifold & lines to 3500 psi for 5 minutes, OK. Preceded cmt with 50 bbls 0 f CW100 @ 8.34 ppg + 50 bbls MudPush @ 1 0.5 ppg followed with 445 bbls (561 sxs) AS Lite cmt @ 10.7 ppg and tailed with 84 bbls (196 sxs) Lltecrete cmt @ 11.8 ppg. No pr obI ems during cmtg. Displaced the cmt using mud pump 1 (we ha d already taken suction screens out as a pre caution). Displaced as per pgrm @ 6 bpm. Slowed down to 3 bpm on last 16 bbls. Fi nal pressure @ 3 bpm = 700 psi. Bumped p lug within 18 strks of calc and pressured up fI 700 to 1200 psi. Held 5 min, no leakoff Bled off slowly. Floats holding. Left ca sing open at surface. (( Started getting Re d Dyed Mud Push at surf after pumping 25 b bls of displacement. Subtracting out 47.5 b bls of mud push gives 194 bbls of cmt to sur face. Caught good cmt samples in cellar. R eciprocated csg thru out job, up to release of top plug. Did not try to move csg after t op plug released. )) Held pressure 5 minutes & bled pressure off slowly... actually bumped plug @ 12:31. Checked floats... no flow. Drained cmtg he ad & flushed and blew down lines. Flushed riser & diverter and hanger area. RID cmt h e ad, qui c k c.o n n e c t bus h i n g, c m t Ii n e san d c asing eqpt & long bails. Nippled down surface (diverter) stack & dive rter valve & diverter line sections. Installed FMC speed head. Csg head and t ubing head oriented as per drawings from w e b. PJSM. Rig up and set BOPE eqpt on wellhe ad. R/U kill line, kill HCR valve, target tee for Printed: 3/12/2002 4:25:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( (' PHILLIPS ALASKA INC. Operations Summary Report 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Sub From-To Hours Code Code Phase 12/16/2001 00:00 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 21 :30 21 :30 - 00:00 12/17/2001 00:00 - 04:00 9.50 WELCT NUND INTRM1 1.00 WELCT EaRP INTRM1 1.50 DRILL PULD INTRM1 1.00 DRILL PULD INTRM1 4.50 DRILL PULD INTRM1 0.50 DRILL RIRD INTRM1 1.00 WELCT BOPE INTRM1 2.50 WELCT BOPE INTRM1 2.50 WELCT BOPE INTRM1 4.00 WELCT BOPE INTRM1 04:00 - 05:00 INTRM1 05:00 - 08:00 3.00 DRILL RIRD INTRM1 08:00 - 10:30 2.50 DRILL PULD INTRM1 10:30 - 12:30 2.00 DRILL PULD INTRM1 12:30 - 13:30 1.00 RIGMNT RGRP INTRM1 13:30 - 14:00 0.50 DRILL PULD INTRM1 14:00 - 16:30 2.50 DRILL PULD INTRM1 16:30 - 17:00 0.50 DRILL RIRD INTRM1 17:00 - 18:00 1.00 RIGMNT RSRV INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:00 1.00 WELCT SFTY INTRM1 Page 6 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations kill line, target tee for choke line, choke lin e, choke HCR. Torque stack to speed head. Pick up flare line & panic line. Begin mod ifications to bell nipple, hook up turnbuckle s and install Koomey lines. Opened upper BOP bonnet and changed out r ams from 4-1/2" x 7" VBR rams to 4" rams. LID casing bales and PIU drlg bales & dp el evators. Cleared and cleaned rig floor in pr ep for picking up additional 4" dp. RID casi ng fill up line. LID 15 jts of 5" HWDP. Changed iron roughneck to 4". PIU 105 jts ( 35 stds of 4" dp and racked in derrick) usin g the mousehole.. 62 stds in derrick now. Will pick up remainder required on TIH with B HA. Intalled bell nipple. R/U to test BOP eqpt & manifolds. Various complications due to switch over to Herc mode. Leak in kill line in a hard to re ach area. Fixed leaks and changed some eq pt configuration. HCR control lines reverse d. Continue testing BOP eqpt 300 psi 10 & 5000 psi hi. Tested annular to 300 psi 13500 P si. Tested lines & ISBOP and floor valves t 0 300 psi 15000 psi. Finished testing BOP eqpt to 250 psi & 5000 psi. Tested upper VBR rams & Lower pipe ram & blind ram. Tested choke & kill HCR v alves & ISBOP and TIW valves & kill line to rig floor. RID BOP testing joint & lines & chart record e r . Modify bell nipple to match up better to the flo-line. PJSM. PIU BHA - make up bit, motor, stab and MWD I LWD. Unable to upload the LWD tools. Finally ze roed it down to being a bad cable from the MWD shack computer. Uploaded data. Welder had to seal a leak in the bell nipple. PIU 3 flex collars. PIU 60 jts of 4" HT-38 pipe while RIH. Hooked up kelly hose. Nabors engineer inspected main tugger shea ve. Continued PIU 4" HT-38 while RIH. Conducted a Stripping Drill. Eqpt & personn el operated properly. Printed: 3/12/2002 4:25:34 PM (" Page 7 of 19 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From -To Hours Code Sub Phase Code 12/17/2001 20:00 - 20:45 0.75 DRILL PULD INTRM1 20:45 - 22:00 1.25 DRILL TRIP INTRM1 22:00 - 23:00 1.00 DRILL CIRC INTRM1 23:00 - 00:00 1.00 WELLS DEQT INTRM1 12/18/2001 00:00 - 00:30 0.50 FRMTST PULD INTRM1 00:30 - 01 :00 0.50 DRILL SFTY INTRM1 01 :00 - 02:00 1.00 RIGMNT INTRM1 02:00 - 04:00 2.00 DRILL DRLG INTRM1 04:00 - 05:00 1.00 DRILL CIRC INTRM1 05:00 - 06:00 1.00 FRMTST SIPB INTRM1 06:00 - 08:00 2.00 WELCT COND INTRM1 12/19/2001 12/20/2001 08:00 - 09:00 1.00 LOG OTHR INTRM1 09:00 - 11 :00 2.00 DRILL DRLG INTRM1 11 :00 - 12:30 1.50 DRILL OTHR INTRM1 12:30 - 00:00 11.50 DRILL DRLG INTRM1 00:00 - 08:00 8.00 DRILL DRLG INTRM1 08:00 - 10:00 2.00 DRILL CIRC INTRM1 10:00 - 12:00 2.00 DRILL WIPR INTRM1 12:00 - 14:00 2.00 DRILL OTHR INTRM1 14:00 - 14:30 0.50 DRILL SFTY INTRM1 14:30 - 15:30 1.00 DRILL WIPR INTRM1 15:30 - 16:30 1.00 DRILL CIRC INTRM1 16:30 - 00:00 7.50 DRILL DRLG INTRM1 00:00 - 12:30 12.50 DRILL DRLG INTRM1 12:30 - 16:00 3.50 DRILL CIRC INTRM1 16:00 - 18:30 2.50 DRILL WIPR INTRM1 18:30 - 19:30 1.00 DRILL CIRC INTRM1 19:30 - 20:30 1.00 DRILL FIT INTRM1 20:30 - 22:15 1.75 DRILL OTHR INTRM1 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description.of Operations Continued PIU 4" HT-38 while RIH. Finished RIH with stands from derrick. Was hed down to above float collar. Did not cle an out. Circulated 1-1/2 bottoms up... precautionary in case of any green cmt. Rigged up to pump down the dp and the kill line. Pumped air out of both lines & closed bag. Pressure tested 9-5/8" casing to 2600 psi for 30 minutes.. no leak off. Bled all t he mud back. RIG DOWN FROM CSG TEST - BLOW DOWN L IN E S PJ S M CHANGE OIL IN TD DRILL OUT FLOAT EQUIP AND 20' OF NEW H 0 L E CIRC AND CONDITION MUD FOR F.I.T. I L.O .T R/U AND PERFORM F.I.T RID - BLOW DN IN ES. EMW=13.3 DISPLACE WITH NEW MUD, MW=8.5- CHANG E SCREENS ON ALL SHAKERS, CLEAN POSS UM BELLY AND SHAKER TRAYS-FLOWLINE. PWD BASELINE DRLG F/3682' TO 3845' - 3810' TVD AST 31 4 ART 1/2 AUGER LUGGED OFFI SPERRY SUN DETECT ION PROBLEMS WITH TOOL DRLG F/3845' T/4880'AST - 4 1/2 1/2 TVD = 4660' Drilled from4880' to 5714'. TVD = 5160' A RT41/2 AST1 Pumped Hi-Vis sweep - circulate 4 bottoms up - monitorwell - blow down. Trip from 5714' to 9 5/8" csg shoe. Cut 55' Drlg line - Service Top Drive & Draw works. PJSM wlhands involving checking TD oil. TIH - 21 stands - disp. good. CBU DRLG from 5714' to 6482'. Dilling 81/2" hole f/ 6482' to 7455' (6183' T VD) ART= 9 hours AST= 1/2 hour. Circ & Cond mud for Wiper trip. Check well f or flow, pump dry job. POOH to shoe @ 3649'. Pulled good, had pr oper fill. Circ out dry job for FIT. Rig up & perform FIT to 12.5 ppg EMW. Mud weight 10.5 ppg, 7455' MD, 6183' TVD, 650 psi. PJSM. Service Rig & Top Drive ART - 3 Printed: 3/12/2002 4:25:34 PM l. < Page 8 of 19 PHILLIPS ALASKA INC. Operations Sum maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Date From - To Hours Code Sub Phase Code 12/20/2001 22:15 - 00:00 1.75 DRILL WIPR INTRM1 12/21/2001 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 01 :00 - 07:00 6.00 DRILL DRLG INTRM1 07:00 - 12:00 5.00 WELCT COND INTRM1 12:00 - 16:00 4.00 WELCT COND INTRM1 16:00 - 17:30 1.50 DRILL DRLG INTRM1 17:30 - 00:00 6.50 WELCT COND INTRM1 12/22/2001 00:00 - 09:00 9.00 WELCT COND INTRM1 09:00 - 10:00 1.00 DRILL DRLG INTRM1 10:00 - 12:00 2.00 DRILL DRLG INTRM1 12:00 - 14:30 2.50 DRILL DRLG INTRM1 14:30 - 15:30 1.00 DRILL CIRC INTRM1 15:30 - 16:30 1.00 DRILL DRLG INTRM1 16:30 - 17:30 1.00 DRILL CIRC INTRM1 17:30 - 18:30 1.00 DRILL DRLG INTRM1 18:30 - 19:30 1.00 DRILL CIRC INTRM1 19:30 - 20:30 1.00 DRILL DRLG INTRM1 20:30 - 21 :30 1.00 DRILL CIRC INTRM1 21 :30 - 22:30 1.00 DRILL DRLG INTRM1 22:30 - 23:30 1.00 DRILL CIRC INTRM1 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of. Operations RIH to bottom, No problems. Circ bottoms up after trip. Drilling 8-1/2" Hole fI 7455'-7668' (6299 TV D) AST=3 hours ART=1.75 hours Encountered gas to surface, well not flowing but gas breaking out circ & raise mud weig ht fI 10.5 to 11.1. Monitor ECD's Gas & oil coming fI C1 sand? Circ & raise mud weight slowly to 11.4 ppg. (ECD's 11.8). Monitor ECD's. Drilling 8-1/2" hole fI 7668'-7731' (TVD 632 9') Raise weight wI drilling. Monitor ECD's ( 11.9) Control influx wI ECD's Circ & monitor well. Shut down pumps (4 Mi ns) & circ bottoms up excessive gas & oil to surface on bottoms up. Circ & increase mud weight to 12.0 ppg slowly, Monitor ECD's ( 12.5). ECD's keeping influx from coming in t 0 well bore. Circ & Cond, Weight up Mud slowly to 12.2 P pg, monitor ECD's (12.7), MOnitor gas cut m u d. Drilling 8-1/2" hole fI 7731'-7753' (TVD 634 0') AST=1 hour Had trouble sliding & getting good reaction. Concern about missing target, (lost some a ngle due to length of circulation wI weightin 9 up). Circ & monitor ECD's. WOO. Drilling 8-1/2" Hole fI 7753'-7828' AST=2 h ours ART=.25 hours Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" hole fI 7828'-7877' AST=1 h our Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" Hole fI 7877'-7925' AST=1 h our Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" Hole fI 7925'-7975' AST=1 h our Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" Hole fI 7975'-8020' AST=1 h our Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Printed: 3/12/2002 4:25:34 PM f ( ~ ..... ~ (PHlLLiPs1 PHILLIPS ALASKA INC. Page 9 of 19 1rÐ) Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Spud Date: 12/11/2001 Event Name: ROT - DRILLING Start: 11/14/2001 End: 1/17/2002 Contractor Name: Nabors Rig Release: 1/17/2002 Group: Rig Name: Nabors 16E Rig Number: 16E Date From - To Hours Code Sub Phase Description of Operations ... Code 12/22/2001 23:30 - 00:00 0.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" H 0 I e fI 8020'-8030' TVD 6435 , AST=.5 hours 12/23/2001 00:00 - 01 :00 1.00 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" H 0 I e f I 8030'-8070' AST=1 h r 01 :00 - 02:00 1.00 DRILL CIRC INTRM1 C i rc bottoms up to prevent cuttings loa d to i ncrease EC D 's above acceptable Ie ve Is. Rot ate & r e c i p pip e. S P R. 02:00 - 03:30 1.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" H 0 I e fI 8070'-8117' AST=1.5 hrs. 03:30 - 04:30 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease EC D 's above acceptable Ie ve Is. Rot ate & r e c i p pip e. 04:30 - 06:00 1.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 Ie fI 8117'-8170' AST=1.5 hrs 06:00 - 07:00 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease EC D 's above acceptable I eve Is. Rot ate & r e c i p pip e. 07:00 - 08:30 1.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 I e fI 8170'-8212' AST=1.5 hrs 08:30 - 09:30 1.00 DRILL CIRC INTRM1 C i rc bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 09:30 - 10:00 0.50 RIGMNT RGRP INTRM1 Replace cap gasket #2 MP. C i rc w/ one pu m p. @ 100 spm 10:00 - 11 :00 1.00 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 I e fI 8212'-8258' AST= 1 h r 11 :00 - 12:00 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 12:00 - 13:30 1.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 I e fI 8258'-8307' AST=1.5 hrs 13:30 - 14:30 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 2900 un its gas @ BU 14:30 - 15:30 1.00 DRILL DRLG INTRM1 Drilling 8-1/2" h 0 Ie fI 8307'-8357' AST=1 h r 15:30 - 16:30 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 2450 un its gas @ BU 16:30 - 17:30 1.00 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 I e fI 8357'-8403' AST=1 h r 17:30 - 18:30 1.00 DRILL CIRC INTRM1 C i rc bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 2300 un its gas @ BU 18:30 - 19:00 0.50 DRILL DRLG INTRM1 Dr ill i n g 8-1/2 h 0 Ie fI 8403'-8453' AST=.5 h r s 19:00 - 20:00 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot ate & r e c i p pip e. 1800 un its gas @ BU 20:00 - 21 :00 1.00 DRILL DRLG INTRM1 Dr ill i n g 8-1/2" h 0 I e fI 8453'-8500' AST=1 hr 21 :00 - 22:00 1.00 DRILL CIRC INTRM1 C i r c bottoms up to prevent cuttings loa d to i ncrease E CD's above acceptable I eve Is. Rot Printed: 3/12/2002 4:25:34 PM (" PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 12/23/2001 21 :00 - 22:00 1.00 DRILL CIRC INTRM1 22:00 - 23:00 1.00 DRILL DRLG INTRM1 23:00 - 00:00 1.00 DRILL CIRC INTRM1 12/24/2001 00:00 - 01 :30 1.50 DRILL DRLG INTRM1 01 :30 - 03:00 1.50 DRILL CIRC INTRM1 03:00 - 04:30 1.50 DRILL DRLG INTRM1 04:30 - 05:30 1.00 DRILL CIRC INTRM1 05:30 - 06:30 1.00 DRILL DRLG INTRM1 06:30 - 08:00 1.50 DRILL CIRC INTRM1 08:00 - 08:30 0.50 RIGMNT RGRP INTRM1 08:30 - 10:00 1.50 DRILL DRLG INTRM1 10:00 - 12:00 2.00 DRILL CIRC INTRM1 12:00 - 16:00 4.00 DRILL CIRC INTRM1 16:00 - 20:00 4.00 DRILL CIRC INTRM1 20:00 - 23:00 3.00 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL WIPR INTRM1 12/25/2001 00:00 - 00:30 0.50 DRILL WIPR INTRM1 00:30 - 10:00 9.50 DRILL WIPR INTRM1 10:00 - 12:30 2.50 DRILL WIPR INTRM1 12:30 - 18:00 5.50 DRILL CIRC INTRM1 18:00 - 23:00 5.00 DRILL TRIP INTRM1 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Page 10 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations ate & recip pipe. 1600 units gas @ BU Dilling 8-1/2" hole fl 8500'-8550' AST=1 hr Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" hole f/ 8550'-8596' AST=1 hr Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Dilling 8-1/2" hole fI 8596'-8645' AST=1.5 hrs Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Drilling 8-1/2" hole f/ 8645'-8692' AST=1 hr Circ bottoms up to prevent cuttings load to i ncrease ECD's above acceptable levels. Rot ate & recip pipe. Repair #1 MP (cap gasket) #2 MP suction sc reen plugged. Drilling 8-1/2" hole f/ 8692'-8765' (TD) AST =.5 hrs ART=.75 hrs TVD 6464' Circ Bottoms up, Raise mud weight .2 ppg P er circulation. Circ & raise mud weight to 12.6 ppg monitor ing ECD's (13.0 max) Monitor well for flow, Work stand, (15 min). Circ Bttms up, 1000 units gas on BU. Contin ue circ & raise mud weight to 12.8 ppg. Mon itor ECD's (13.2 max) Monitor well for flow (static) work pipe wlo pumps for 15 min. Circ bottoms up, 300 unit s gas on BU. Continue to circ to make sure weight is even. Monitor well, pump dry job, Blow down Top Drive. POOH "slow" for wiper trip. Limit trip speed to 3 min/std. Tight @ 8691' POOH "slow" Tight @ 7620' Back ream thru tight spots fI 7620' to 7250'. Tight, very erratic torque. POOH f/ 7250' t 0 6775' without problems. RIH to bottom "slow", no problems enCQunte red. C i r c & Con d mud for cas i ng. Beg i n c i r c s I ow & stage up rate to 93 spm wI watching for I osses. No losses.180 units gas on BU. Moni tor well for (static) Pump dry job. POOH to shoe, limit trip speed to 30 fpm. N 0 hole problems encountered, Hole took goo d fill. Monitor well @ shoe (OK) weight up 13.1 pp Printed: 3/12/2002 4:25:34 PM ( ( Page 11 of 19 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 12/25/2001 23:00 - 00:00 1.00 DRILL CIRC INTRM1 12/26/2001 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 05:00 3.50 DRILL TRIP INTRM1 05:00 - 06:30 1.50 DRILL OTHR INTRM1 06:30 - 07:30 1.00 DRILL PULD INTRM1 07:30 - 09:30 2.00 WELCT EaRP INTRM1 09:30 - 11 :00 1.50 CASE RURD INTRM1 11 :00 - 12:00 1.00 RIGMNT RSRV INTRM1 12:00 - 17:00 5.00 CASE RUNC INTRM1 17:00 - 18:30 1.50 CASE CIRC INTRM1 18:30 - 21 :00 2.50 CASE RUNC INTRM1 21 :00 - 22:00 1.00 CASE CIRC INTRM1 22:00 - 00:00 2.00 CASE RUNC INTRM1 12/27/2001 00:00 - 03:00 3.00 CASE RUNC INTRM1 03:00 - 04:00 1.00 CASE CIRC INTRM1 04:00 - 07:00 3.00 CASE RUNC INTRM1 07:00 - 09:00 2.00 CEMEN CIRC INTRM1 09:00 - 10:00 1.00 CEMEN RURD INTRM1 10:00 - 13:00 3.00 CEMEN CIRC INTRM1 13:00 - 14:30 1.50 CEMEN PUMP INTRM1 14:30 - 16:00 1.50 CEMEN DISP INTRM1 16:00 - 17:00 1.00 CEMEN RURD INTRM1 17:00 - 18:00 1.00 WELCT EORP PROD 18:00 - 19:00 1.00 WELCT EaRP PROD 19:00 - 20:00 20:00 - 21 :00 1.00 RIGMNT RGRP PROD 1.00 CASE RURD PROD 21 :00 - 00:00 3.00 WELCT BOPE PROD Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations g. Wait up to 13.1 wI @ shoe. Monitor well, pu mp dry job. POOH, set back HWDP, 1 std flex DC's. Download LWD info. Break motor, change motor alignment, LID m otor, LWD, MWD tools, bit Pull strip-o-matic off hole, pull wear bush in g, set test plug. Change rams to 7" & test d oors to 3500psi. PJSM, rig up to run 7" casing. Service Rig & Top Drive PJSM, Run 7",26# L-80 casing to 2100'. Lim it running speed to 20 fpm. Circ & Cond mud, lower mud to 12.8 ppg. Run 7" casing to shoe. Limit running speed t 0 20 fpm. Circ & cond mud, lower MW to 12.8 ppg. Clr c @ 4 bpm wI 500 psi. Run 7", 26# L-80 casing. Limit running spee d to 20 fpm. Run 7", 26#, L-80 casing (20 FPM). Circ & Cond mud @ 6430' Run 7", 26#, L-80 casing (20 FPM). Make u p casing hanger & landing joint, Land casing @ 8754' Circ & Cond for cement job, raise rate slowl y to 4 bpm. Circ Bottoms up. LID Franks circulating tool, MIU cement hea d. Circ & Cond for cement job. Raise rate to 5 bpm. Hold PJSM for cement job. Batch mix cement wI circulating. Test lines to 3500 psi & cement wI Dowell. Drop bottom plug, pump 40 bbls Mud push X L @ 14 ppg, Drop 2nd bottom plug, Pump 86 bbls cement @ 15.8 ppg Drop top plug, 5 b bls H2O. Displace cement wI rig pumps @ 5 bpm. Rec ip casing until last 20 bbls disp left. Slow r ate to 3 bpm last 20 bbls. Bump Plug wi 385 5 stks. CIP @ 1535 hrs. Check floats. LID landing joint, cement head, valves, hos e s. Drain & flush stack, Install 7" X 9-5/8" pac k off, test same to 5000. (OK) Change top pipe rams f/ 7" to 3-1/2" X 6" va riables. Change out lube oil on Top Drive. Remove casing bales, XO & 2" hose fI casin g run, clear floor. Rig up to test BOPE. Test BOP's compl ete t 0 250 & 5000, annular to 250 & 3500 psi. pe Printed: 3/12/2002 4:25:34 PM ( Page 120f 19 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Date 12/27/2001 12/28/2001 12/2912001 12/30/2001 12/31/2001 From - To Hours Code Phase 21 :00 - 00:00 3.00 WELCT 00:00 - 01 :00 1.00 WELCT BOPE PROD 01 :00 - 03:00 2.00 DRILL PULD PROD 03:00 - 07:00 4.00 DRILL PULD PROD 07:00 - 08:00 1.00 DRILL TRIP PROD 08:00 - 10:00 2.00 RIGMNT RSRV PROD 10:00 - 15:00 5.00 DRILL TRIP PROD 15:00 - 16:00 1.00 DRILL CIRC PROD 16:00 - 17:00 1.00 DRILL OTHR PROD 17:00 - 21 :30 4.50 CEMEN DSHO PROD 21 :30 - 00:00 2.50 DRILL CIRC PROD 00:00 - 01 :00 1.00 DRILL CIRC PROD 01 :00 - 02:00 1.00 DRILL FIT PROD 02:00 - 02:30 0.50 DRILL OTHR PROD 02:30 - 11 :30 9.00 DRILL DRLG PROD 11 :30 - 13:00 1.50 DRILL CIRC PROD 13:00 - 13:30 0.50 DRILL TRIP PROD 13:30 - 00:00 10.50 DRILL OTHR PROD 00:00 - 02:00 2.00 DRILL OTHR PROD 02:00 - 03:00 1.00 DRILL TRIP PROD 03:00 - 04:00 1.00 DRILL CIRC PROD 04:00 - 08:30 4.50 DRILL OTHR PROD 08:30 - 10:00 1.50 DRILL CIRC PROD 10:00 - 12:00 2.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 00:00 - 09:30 9.50 DRILL DRLG PROD 09:30 - 10:30 1.00 DRILL CIRC PROD 10:30 - 14:30 4.00 DRILL TRIP PROD 14:30 - 20:00 5.50 RIGMNT RGRP PROD Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations rform accumulator test. Witnessing of test w aived by AOGCC rep. Chuck Scheve. RID Test equipment, Install wear bushing. Rig up floor & LID HWDP & flex DC's fl derri c k. PJSM, P/U BHA, Program & orient tools. P/U 3 Flex DC's & jars PIU 27 joints 4" DP. Cut Drilling line 85', Rig up kelly hose, Ser vice rig & top drive. Shallow test MWD tools & RIH to 8657' (Tag CMT). Fill pipe every 30 stds. Circ Bottoms up. Cement contaminated mud. Rig equipment & test casing to 2500 psi 1 30 min. lost 60 psi. Drilling cement, float equipment, plugs 7 30 , new hole to 8795' ADT= .5 hrs. Circ & Condo Swap out 12.8 ppg mud w. 11.0 ppg mud. Clean out possum belly & troughs under shakers. Circ & Cond for FIT. 11.0 ppg mud weight. Perform FIT to 12.8 EMW. 600 psi, 11.0 ppg mud weight, 6463' TVD. Perform PWD baseline test. Drilling 6.125" hole f 8795' to 9280' AST= 1.5 hrs, ART= 4.5 hrs TVD= 6465' Circ bottoms up POOH to shoe to clean pits for Baradril-N m ud swap. Clean mud pits for Baradril-N mud swap. We ight up 300 bbls fI 9.3 ppg to 9.8 ppg. Weight up mud in pits to 9.8 ppg. Clean pits RIH, Tight @ 8800'. Work pipe to 9100' (Sto pped) Ream fl 9100' to 9280' Circ Bottoms up Set back 1 std. & work pipe, Clean pit 5, re build spacer. Clean trip tank. Displace well wI 9.8 ppg Baradril-N mud, Mo nitor well, Clean flow line & Shakers. Drilling 6.125" hole fI 9280'-9358' ART= 1 hr. Drilling 6.125" hole fI 9358'-10008' AST= 4 . 5 h r s ART = 5 h r s. T V D = 6,4 1 2 ' Drilling 6.125" Hole fI 10008'-10483' AST=2 .5 hrs ART= 4hrs. TVD= 6457' Decision made to sidetrack well, Circ Sweep around. Lost blower motor for Top Drive. POOH to shoe, Pump out of hole. Tight fl 10 389' to 9637'. Work on Blower motor for Top Drive, PLug in Derrick bad, Replace same. Circ wI workin Printed: 3/12/2002 4:25:34 PM ( Page 13 of 19 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 12/31/2001 14:30 - 20:00 5.50 RIGMNT RGRP PROD 20:00 - 21 :00 1.00 DRILL CIRC PROD 21 :00 - 21 :30 0.50 DRILL REAM PROD 21 :30 - 22:30 1.00 DRILL CIRC PROD 22:30 - 00:00 1.50 DRILL REAM PROD 1/1/2002 00:00 - 02:30 2.50 DRILL CIRC PROD 02:30 - 04:00 1.50 DRILL DRLG PROD 04:00 - 12:00 8.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 1/2/2002 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 12:00 8.00 DRILL CIRC PROD 12:00 - 13:00 1.00 DRILL CIRC PROD 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30 - 14:00 0.50 DRILL OBSV PROD 14:00 - 00:00 10.00 DRILL CIRC PROD 1/3/2002 00:00 - 08:00 8.00 DRILL WIPR PROD 08:00 - 12:00 4.00 DRILL CIRC PROD 12:00 - 17:30 5.50 DRILL CIRC PROD 17:30 - 18:00 0.50 DRILL OBSV PROD 18:00 - 00:00 6.00 DRILL CIRC PROD 1/4/2002 00:00 - 07:00 7.00 DRILL CIRC PROD 07:00 - 08:00 1.00 DRILL TRIP PROD 08:00 - 09:30 1.50 DRILL CIRC PROD Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations g Top Drive. Gas breaking out at surface aft er 1500 stks. Maintain circ rate (71 spm) Mo nitor gas. Circ & Rotate @ shoe, Monitor gas in return s. 1000 to 2000 units. Wash & ream fI 8754' to 9042'. Tight @ 876 5' Circ Bottoms up, monitor gas. Wash & Ream fI 9042' to 9522'. Monitor gas & oil in returns. Circ @ 9522'. Pump sweep (total strokes 12 ,000). Max units of gas 3,600. Open hole sidetrack well @ 9475'. Dril16 1/8" horizontal hole fI 9475' to 9680' (205') TVD = 6448' ART = 1.75 hrs. AST = 4.75 hrs Dril16 1/8" horizontal hole fI 9,680' to 10,2 64' (584') TVD=6451' ART = 4 hrs. AST=4. 5 hrs. Dril16 1/8" hoizontal hole fI 10264' to 1051 5' (251') TVD = 6446' ART = 2.75 hrs. AS T = 0 Circ @ 70 SPM, recip & rotate @ 120 rpm, 2 700 psi. Swivel packing starting to leak. Change out swivel packing while circ @ 71 s pm. Gas units max @ 1400 units. CBU while rotate and recip. Gas units max @ 1900 units. Monitor well. Flowing wI pumps off. Circ and increase mud weight in .2 ppg incr ements, while pulling stands in 1-2 hrs inter vals to minimize hole errosion in one spot. Monitoring pump off/bottoms up gas units. H ole tight and packing off @ 10086'. Free up and circ hole clean wI 10.7 ppg mud weight. Finish POOH to 7" shoe @ 8754'. Pumping 0 ut. MW 10.7 ppg Circulate @ 7" shoe wI 10.7 ppg. 58 SPM, 2 000 psi & 90 RPM. Service top drive & DW. Circulate & increase MW to 10.9 ppg @ 7" s hoe. 58 spm, 2000 psi. Monitor well. Flowing. Circ and increase MW fI 10.9 ppg to 11.3 pp g. With 11.3 ppg in hole, circ press 1250 ps i @ 38 spm wI 12.3 ppg ECD. Circ 11.3 ppg @ 7" shoe. 45 SPM = 1300 ps i. (8755' MD) TVD = 6464' Flow check well. Wash in hole to 9456'. RIH wlo pumps to 97 50'. Did not see old hole Break circ. Survey to see if in sidetracked well. OK. CBU wI 11.3 ppg mud. 900 strok es = 1000 units gas 1800 strokes = 1000 un Printed: 3/12/2002 4:25;34 PM 1 15/2002 ( PHILLIPS ALASKA INC. Operations Summary Report 13:00 - 13:30 0.50 DRILL OBSV PROD 13:30 - 17:00 3.50 DRILL TRIP PROD 17:00 - 19:30 2.50 DRILL OBSV PROD 19:30 - 22:00 2.50 DRILL TRIP PROD 22:00 - 00:00 2.00 DRILL OBSV PROD 00:00 - 07:00 7.00 DRILL TRIP PROD Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From -To Hours Code Sub Phase Gode 1/4/2002 08:00 - 09:30 1.50 DRILL CIRC PROD 09:30 - 11 :00 1.50 DRILL TRIP PROD 11 :00 - 13:00 2.00 DRILL CIRC PROD 07:00 - 12:00 5.00 DRILL PULD PROD 12:00 - 14:30 2.50 DRILL PULD PROD 14:30 - 15:00 0.50 DRILL PULD PROD 15:00 - 21 :00 6.00 DRILL TRIP PROD 21 :00 - 21 :30 0.50 DRILL CIRC PROD 21 :30 - 00:00 2.50 WELCT CIRC PROD 1/6/2002 00:00 - 06:00 6.00 WELCT CIRC PROD 06:00 - 08:00 2.00 DRILL CIRC PROD 08:00 - 08:30 0.50 DRILL TRIP PROD 08:30 - 10:30 2.00 DRILL CIRC PROD 10:30 - 11 :00 0.50 DRILL TRIP PROD Page 14 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations its gas 1900 strokes = 1250 units gas 2600 strokes = 100 units gas 2800 strokes = 58 units gas Continue to wash in hole fI 9750' to 10515'. Reamed bridge @ 10,112 - 10,117'. Circ to balance mud to 11.3 ppg. Max gas 650 units @ 2200 strokes. Circ total of 477 5 strokes- gas @ 190 units- 11.3ppg MW in - 11.1 MW out with pressure scales. Observe well for flow. POOH wI pumps to 8310'(23 stands out). P ump 12 SPM. Pull @ 30' to 40'; per min. Co rrect fill. Observe well for flow. 1710 hrs = rate 1.75 BBL per hr 1723 hrs = rate .84 BBL per h r 1750 hrs = rate well static POOH wlo pump, slow. 25' to 30' min rate. Total of 48 stands out of hole to 6000'. 15 bbls to fill 25 stands 4" DP. Correct fill. Observe well for flow. 2200 hrs = rate .286 BBLS per hour 2215 hrs = rate .130 BBLS P er hour 2300 hrs = rate .102 BBLS per hour Refill trip tank wI 11.3 ppg mud. POOH wI BHA # 3 to run 3 1/2" slotted liner. Pulling slow to minimize swab effect. 25-3 0' per min., slow off slips. Good hole fill. Retrieve 1.92" rabbit. Observe hole @ BHA fI 10 min. L/D BHA. Lef t 31.5' of fish in hole. (Bit & 14.5' of housin g + 16.45' of rotor). Prepare to PU BHA locate fish in hole & pus h or leave on bottom. MU BHA # 4 RIH wI DP to 8670'. Fill pipe every 20 stand s, run @ 3 min / stand. Circ @ 8670' (stand 88). Shut in well after 1 965 strokes. Record. pressure. Circ with driller's method through choke. Continue to circ thru choke using driller's m ethod, 11.3 ppg mud to surface. Open well- static. Blow down choke line. Cir c long way @ 45 SPM, 1100 psi. Bottom's up gas 6 units. Increase rate to 50 spm @ 140 0 psi. Max gas 300 units. Pumped total of 4 700 strokes. MW in & out 11.3 ppg. Check fl ow- static. Pump in hole fI 8670' to 9150' @ 50 spm. To ok 10k wt @ 8800'. Circ 50 spm @ 9150'. Bttm's up gas 1350 un its. Mud out 9.5 ppg. Circ total of 5850 stro kes. Zero gas units. Pump in hole fI 9150' to 9630'. Did not see old hole. Printed: 3/12/2002 4:25:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/6/2002 117/2002 1/8/2002 119/2002 ( PHilliPS ALASKA INC. Operations Summary Report 3N-19 3N-1 9 ROT - DRILLING Nabors Nabors 16E Sub From - To Hours Code Code Phase 11 :00 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 00:00 00:00 - 02:00 02:00 - 11 :00 11 :00 - 12:30 12:30 - 14:30 14:30 - 18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 00:00 - 06:30 06:30 - 09:00 09:00 - 09:30 09:30 - 12:30 12:30 - 13:00 13:00 - 15:30 15:30 - 16:00 16:00 - 20:00 20:00 - 23:00 23:00 - 00:00 00:00 - 02:30 02:30 - 03:00 1.50 DRILL CIRC PROD 1.00 DRILL TRIP PROD 1.50 DRILL CIRC PROD 2.00 DRILL CIRC PROD 7.00 DRILL TRIP PROD 2.00 DRILL TRIP PROD 9.00 DRILL CIRC PROD 1.50 DRILL TRIP PROD 2.00 DRILL CIRC PROD 3.50 DRILL TRIP PROD 2.00 DRILL TRIP PROD 1.00 WELCT OBSV PROD 2.00 WELCT KILL PROD 1.00 WELCT OBSV PROD 6.50 WELCT KILL PROD 2.50 WELCT KILL PROD 0.50 DRILL TRIP 3.00 WELCT KILL 0.50 DRILL TRIP 2.50 WELCT KILL 0.50 DRILL TRIP 4.00 DRILL CIRC 3.00 DRILL TRIP PROD PROD PROD PROD PROD PROD PROD 1.00 DRILL TRIP PROD 2.50 DRILL CIRC PROD 0.50 DRILL TRIP PROD Page 15 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations Circ @ 9630' @ 50 spm , 1480 psi. Circ tota I of 4000 strokes. No gas on bottom's up. Pump in hole to 10112'. Worked through tigh thole @ 10060' to 10080'. Took 10-30 k. Wo ked 4-5 times then free. Circ @ 10,112' , 50 spm @ 1500 psi. Pumpe d 700 strokes, hole packed off. Work pipe to 10,066' and regained circ. Continue to wor k pipe, hole packing off. Lost +1- 20 bbls wh ile working up to 10016'. Continue to back ream out of hole, tight & packing off @ 9942' to 9948'. Clean up tight spots. Back ream f/ 9920' to 9824' free. Work back in hole cleaning up tight spots as needed and circulating to 10,299'. Trip in hole, cleaning up tight spots as need ed to top of fish. Found fish to be @ 10488' Circ, rotate @ 100 RPM. Pump sweep. Displ ace hole wI new mud. Back ream a stand eve ry 30 min. f/ 10488' to 9820'. Pump back in hole f/ 9820' to 10485'. Ream past ledges @ 10056',10076-10081',10122' Circulate and condition mud and hole f/ trip out for liner. Pump out of hole wI 15 spm, pulling 20-30 ft Imin. f/ 10485' to 8100'. Flow check well. Pump out of hole wI 15 spm, pulling 20-30 ft Imin f/ 8100' to 7585'. Well flowing. Shut in well DP = 60 psi. Csg = 80 psi. Circ thru choke @ SPR. Shut down pumps. Bleed to zero. No pressur e buildup in 15 min. Blow down Top drive an d monitor. Monitor well. Flowing. Shut in. Monitor pres sure @ 7585' (TVD = 6250'). Circ thru choke Flow check. Circulate through choke. Rig down pump in s ub. Observe well. Flowing. Trip in hole f/ 7585' to 8174'. Circ through choke. RIH fl 8288' to 8767'. Circ through choke. RIH f/ 8767' to 9151'. Pump @ 50 SPM. CBU the long way. Pump in hole @ 45 spm 1325 psi. fl 9151' t 0 9632'. RIH f/ 9632' to 10,200'. Circ @ 30 spm. Circulate @ 10,200'. Hole in good condition. Trip in hole fl 10,200' to 10488' (TO F). Hol Printed: 3/12/2002 4:25:34 PM ( PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From.. To Hours Code Sub Phase Code 1/9/2002 02:30 - 03:00 0.50 DRILL TRIP PROD 03:00 - 05:00 2.00 DRILL TRIP PROD 05:00 - 08:30 3.50 DRILL CIRC PROD 08:30 - 09:00 0.50 DRILL CIRC PROD 09:00 - 10:00 1.00 DRILL CIRC PROD 10:00 - 12:00 2.00 DRILL CIRC PROD 12:00 - 14:00 2.00 DRILL CIRC PROD 14:00 - 16:30 2.50 DRILL CIRC PROD 16:30 - 17:00 0.50 DRILL OBSV PROD 17:00 - 00:00 7.00 DRILL TRIP PROD 1/10/2002 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 03:30 1.00 CMPL TN RURD PROD 03:30 - 06:30 3.00 CMPL TN SCRN PROD 06:30 - 10:00 3.50 CMPL TN OTHR PROD 10:00 - 12:00 2.00 CMPL TN OTHR PROD 12:00 - 13:00 1.00 CMPL TN CIRC PROD 13:00 - 18:30 5.50 CMPL TN SCRN PROD 18:30 - 21 :00 2.50 CMPL TN CIRC PROD 21 :00 - 00:00 3.00 CMPL TN SCRN PROD 1/11/2002 00:00 - 06:30 6.50 CMPLTN CIRC PROD 06:30 - 07:30 1.00 CMPL TN OBSV PROD 07:30 - 08:30 1.00 CMPLTN CIRC PROD 08:30 - 11 :30 3.00 CMPL TN SCRN PROD 11 :30 - 12:30 1.00 CMPL TN PCKR PROD Page 16 of 19 Spud Date: 12/11/2001 End: 1/17/2002 G roup: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations e in good condition. Circ @ 30 spm working pipe to TOF. Pump out of hole 1/ 10,488' to 9,146'. Hole f ill appeared to be between 7 and 11 bbls. H ole in good shape, in & out. PU wt wI pump s 170 k. SO wt wI pumps 120 k. Circ hole clean. Max gas units 3634. Load Hi-Vis pill into drill sring to bit. Pump out 1/ 9146' to 8739', spotting hi-vis i n open hole. Circ hole clean @ 8739'. Max gas cut to 297 0 units. Displace well wI 12.5 ppg LSND mud in casi n g. CBU wI 12.5 ppg mud @ 30 spm and 600 psi. Choke panel reading 580 psi. SPR @ 20 S PM = 430 psi. Flow check well f/ 15 min. Pump dry job. Blo w down top drive. POOH fl 31/2" liner. Midnight @ 1640'.Hole fill good. taking a little xtra. 8.5 bbls over calc. @ midnight. Finish POOH wI BHA # 4. RU to run 3 1/2" slotted liner. PJSM. Run shoe, (1) 3 1/2" jt blank, packoff bushi ng, (40) 3 1/2" slotted liner and (18) 3 1/2" blank jts. Run 2 1/16" inner string inside slotted liner. Space out 2 1/16" pipe inside liner, MU han ger, packer ,PBR, and inner string. Circ liner capacity and hole capacity (800 st rokes). RIH wI liner on 4" drill pipe to stand 62 in h ole (7900'). Circulate @ 7900' surf-surf @ 25 spm & 100 0 psi. No losses. No gas. RIH f/ 7900' to 8677'. Observe well. OK. Circulate and lower MW f/ 12.5 ppg in casin 9 to 12.3 ppg. Monitor well, OK. Flush mud lines and a cen trifigal pump with water. PU wt 180 K SO w t 138 K Circulate 4" drill pipe and 21/16" inner stri ng with 82 bbls 12.3ppg sodium bromide brin e. RIH wI liner on DP. Washed last 32' in f/ 10 456' to 10488' with 24 bbls 12.3 ppg brine. Circ 2 bpm @ 1200 psi. PU wt 190 K SO wt 122 K Broke off single DP, dropped 1.5" ball, folio wed wI 30 bbls 12.3 ppg brine, then 12.3 we ighted mud. Landed in ball seat @ 75 bbls t Printed: 3/12/2002 4:25:34 PM (' PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Date Sub From- To Hours Code Code Phase 1/11/2002 11 :30 - 12:30 1.00 CMPL TN PCKR PROD 12:30 - 13:30 1.00 CMPL TN OTHR PROD 13:30 - 15:00 1.50 CMPL TN TRIP PROD 15:00 - 20:00 5.00 CMPLTN CIRC PROD 20:00 - 22:00 2.00 RIGMNT RGRP PROD 22:00 - 00:00 2.00 CMPL TN TRIP PROD 1/12/2002 00:00 - 01 :00 1.00 CMPL TN TRIP PROD 01 :00 - 04:30 3.50 CMPLTN TRIP PROD 04:30 - 05:00 0.50 CMPL TN OTHR PROD 05:00 - 06:00 1.00 WELCT BOPE PROD 06:00 - 10:30 4.50 WELCT BOPE PROD 10:30 -11:00 0.50 WELCT BOPE PROD 11 :00 - 17:00 6.00 CMPL TN OTHR PROD 17:00 - 00:00 7.00 CMPL TN OTHR PROD 1/13/2002 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 01 :00 0.50 CMPL TN TRIP PROD 01 :00 - 06:00 5.00 CMPL TN TRIP PROD 06:00 - 09:30 3.50 CMPL TN CIRC PROD 09:30 - 13:30 4.00 CMPL TN TRIP PROD 13:30 - 17:00 3.50 CMPL TN FRZP PROD 17:00 - 18:30 18:30 - 19:30 19:30 - 21 :30 1.50 CMPL TN OTHR PROD 1.00 CMPL TN OTHR PROD 2.00 CMPL TN OTHR PROD 21 :30 - 22:30 1.00 CMPL TN OTHR PROD 22:30 - 00:00 1.50 CMPLTN OTHR PROD Page 17 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations otal pumped. Pressured up to 2500 psi and s et hanger. Slacked off 25 k on hanger slips. Bleed pressure to zero. Rotated to release setting tool 11 liner. Picked up to expose set ting dogs. Slacked off 50 K to set ZXP pack e r. Closed pipe rams and pressured casing to 3 500 psi to test packer 11 15 min. OK. Pulled seals out of hanger assembly & circ @ 2 bpm with 600 psi. PU wt 180 K POOH 21 stands(67 in hole), 2 1/16" bottom @ 833 3'--- ( above KOIV). Test @ 900 psi. OK. With 4" DP @ 6430' and 21/16" @ 8333', CB U, then increase MW to 12.8 ppg. Circ @ 48 spm (4BPM) & 1060 psi. Trip Tank pump motor quit working. Troubles hoot probelm and use kill line to fill hole. Continue to POOH 11 stand 67 to stand 20 D P 11 6430' - 1917' ----- wI 21/16" up to 382 0'. Hole fill good. POOH wI 4" drill pipe and 2 1/16" inner circ string 11 slotted liner. RU and POOH wI 2 1/6" inner circ. string. RID 2 1/16" handling tools. Clean up rig flo 0 r. RU to test BOPE. Test BOPE. Witness of test waived by AOGC C inspector John Spaulding. RID BOPE test equipment. Install wearbushi ng. Blow down choke and kill lines. RU Schlumberger wireline wI lubricator and BOP's for SCMT log run to be followed by pe rf gun run. RIH wI 55' tool string. SCMT 11 cement bond evalution. Reached 7820'. Lubricate rig and top drive. MU BHA. RIH wI 4" dp and bit to TOL @ 8571'. Circ and condition mud to a 12.8 ppg all the way around. POOH. Hole fill good. MU wireline lubricator and BOP's. Freeze pr otect 9 5/8" x 7" annulus while waiting on 10 gging tools. Injectivity, then 300 bbls water, followed wI 70 bbls diesel. Final shut in pr essure 812 psi. MU US IT cement bond logging tools. RIH to 8041' wI US IT tools. Troubleshoot problem with toolstring, line 0 r unit. POOH wI US IT logging tools. Break head. ch eck, OK. Break wirline toolstring, prepare new string, Printed: 3/12/2002 4:25:34 PM .( ( PHILLIPS ALASKA INC. Operations Summary Report 04:00 - 04:30 0.50 CMPL TN SOHO PROD Legal Well Name: 3N-19 Common Well Name: 3N-19 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 1/13/2002 22:30 - 00:00 1.50 CMPL TN OTHR PROD 1/14/2002 00:00 - 00:30 0.50 CMPL TN OTHR PROD 00:30 - 01 :30 1.00 CMPL TN OTHR PROD 01 :30 - 05:00 3.50 CMPL TN OTHR PROD 05:00 - 06:00 1.00 CMPL TN OTHR PROD 06:00 - 09:00 3.00 CMPL TN OTHR PROD 09:00 - 11 :30 2.50 CMPL TN OTHR PROD 11 :30 - 12:30 1.00 CMPL TN OTHR PROD 12:30 - 13:30 1.00 CMPL TN OTHR PROD 13:30 - 15:00 1.50 CMPLTN OTHR PROD 15:00 - 16:30 1.50 CMPL TN RURD PROD 16:30 - 00:00 7.50 CMPL TN RUNT PROD 1/15/2002 00:00 - 01 :00 1.00 CMPL TN RUNT PROD 01 :00 - 04:00 3.00 CMPLTN CIRC PROD 04:30 - 05:30 1.00 CMPL TN DEOT PROD 05:30 - 06:00 0.50 CMPL TN DEOT PROD 06:00 - 07:00 1.00 CMPL TN SOHO PROD 07:00 - 08:30 1.50 CMPL TN DEOT PROD 08:30 - 10:00 1.50 WELCT OTHR PROD 10:00 - 16:30 16:30 - 18:00 6.50 WELCT NUND PROD 1.50 WELCT NUND PROD 18:00 - 18:30 18:30 - 20:30 20:30 - 21 :30 0.50 WELCT OTHR PROD 2.00 WELCT OTHR PROD 1.00 CMPLTNOTHR PROD Page 18 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description. of Operations check out. Break apart W/L US IT tools. MU new toolstri ng. Surface test new tools. RIH wI other US IT toolstring to 8084'. Run US IT log fI 8084' to 6900'. POOH. Rig down logging tools. Evaluate logs fI in town. Interpretation is g ood cement. RU to run 10' perf gun, 6 spf, 60 deg phasin g" 4.5" BH charges. Safety meeting w/ Schl umberger. Press test lubricator to 200 psi. RIH wI perf gun. Perf fI 7850- 7860'. POOH wI perf gun. R/D Schlumberger and related wireline equip ment. RU to run 3.5" completion. MU 3.5" floor saf ety valve. Prejob meeting. RIH wI 3 1/2" completion string as per progr am. Run 3 1/2" completion assembly. RU to spot 10.8 ppg NaBr fI TOL to FHL Pkr. Pump @ 2 bpm. Pump 32 bbls Na Br, follow with 12.8 ppg mud to leave 10.8 ppg NaBr in Annulus and tbg. Locate in PBR, space out bottom seal assem bly. l' above located. Drop Ball and allow t 0 fall to RHC plug. Pressure tbg to 2500 psi fI 5 min., then 350 0 psi fI 10 min to set packer. Bleed pressur e to zero. Test packer by applying 1000 psi to ann fI 5 min prior to shearing PBR. Bleed annulus to zero. Pressure tubing to 1 000 psi and PU to shear PBR. Sheared @ 25 k over PU wt. Space out PBR 1.5' open. PU wt + 1.5' off 10 cator. MU 4 space out pups 1 joint below hn gr, MU hngr and land. Run in lockdown scre ws. Test tubing and seals to 3500 psi.fI 15 min. Bleed pressure on tbg to 1500 psi. Pressur e annulus to 3500 psi fI 15 min. Bleed tubin 9 pressure to zero to shear RP in bottom GL M. Set FMC BPV. L/D landing joint. Clean and c lear rig floor of casing/completion tools. NID BOP stack, set in cradle for moving. NU adaptor & tree. Test packoff to 5000 for 10m in. Pull BPV. Set Two way check. Test tree @ 250 psi and 5000 psi fI 30 min. RU to displace mud in tubing and annulus th rough RP valve in bottom GLM. PJSM with al I involved team members. Printed: 3/12/2002 4:25:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/15/2002 { { PHILLIPS ALASKA INC. Operations Summary Report 3N-19 3N-19 ROT - DRILLING Nabors Nabors 16E Sub From - To Hours Code Code Phase 21 :30 - 00:00 2.50 CMPL TN FRZP PROD 1/16/2002 00:00 - 03:30 3.50 CMPL TN FRZP CMPL TN 03:30 - 04:30 1.00 CMPL TN NUND CMPL TN 04:30 - 05:30 1.00 CMPL TN OTHR CMPL TN 05:30 - 15:30 10.00 CMPL TN OTHR CMPL TN 15:30 - 22:00 6.50 CMPL TN OTHR CMPL TN 22:00 - 00:00 2.00 RIGMNT RSRV CMPL TN 1/17/2002 00:00 - 18:00 18.00 MOVE DMOB CMPL TN Page 19 of 19 Spud Date: 12/11/2001 End: 1/17/2002 Group: Start: 11/14/2001 Rig Release: 1/17/2002 Rig Number: 16E Description of Operations Start displacement down tubing @ 23 spm(2 bpm), initial circ pressure 670-800 psi. Pum p 50 bbls N vis pill, follow with 8.5 ppg sea water, keeping 2150-2300 psi on tubing pres sure. Annular velocity in 7" x 3.5" is 75.75 f t/rn in. Displace well wI Brine & 73 bbls diesel. Allo w fluids to U-tube Nipple up Tree Cap & Retest to 250/5000 psi Rig up Lubricator & Set BPV. LID DC's & DP from Derrick PJSM, Clear floor of tools & Equipment Clea n rig floor, Begin cleaning pits. Cut Drilling line 153', Slip on additional 374 I for laying down Derrick. Continue cleaning pit s Clean mud pits & shakers, flush all lines for move, Concurrent operations; Rig down #1 mud pump, stabbing board prep Top Drive fo r removal, mud lines to rig floor. Release ri g @ 1800 from 3N-19 to begin move 0 Hunte r A. Printed: 3/12/2002 4:25:34 PM ( ( :~;.ii;)i~Ii~~:.:;"~. 11-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 3N-19 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,455.03' MD Window / Kickoff Survey 9,475.00' MD (if applicable) Projected Survey: 10,515.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE\VED FEB 2. 0 2-002. Alaska Oil & Gas Cons. CommisSion Anchorage DEFINITIVE ( Kuparuk River Unit North Slope, Alaska Kuparuk 3N, Slot 3N-19 3N-19 Job No. AKZZ11209, Surveyed: 4 January, 2002 SURVEY REPORT 11 February, 2002 ~ Your Ref: API 500292305600 Surface Coordinates: 6013799.00 N, 518471.20 E (70026' 55.9422" N, 149050' 57.5195" W) Surface Coordinates re/a"vø to Project H Reference: 1013799.00 N, 18471.20 E (Grid) Surface Coordinates relative, to Structure: 1.47 S, 525.01 E (True) Kelly Bushing: 62.56" above Mean Sea Level sp.""'''V-SUI1 pRILLING S&AVICEiiS A Halliburton company Survey Ref: svy9754 Sperry-Sun Drilling Services . Survey Report for 3N.19 Your Ref: API 500292305600 Job No. AKMM11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9455.03 92.650 123.170 6411.04 6473.60 3828.83 8 3082.69 E 6009977.82 N 521563.37 E 4913.01 Tie On Point ( 9475.00 94.780 122.200 6409.74 6472.30 3839.59 8 3099.46 E 6009967.10 N 521580.17 E 11.716 4932.11 Window Point 9551.57 97.520 123.920 6401.54 6464.10 3881.11 8 3163.26 E ' 6009925.74 N 521644.07 E 4.218 5005.18 9648.59 97.530 123.600 6388.83 6451.39 3934.56 8 3243.22 E 6009872.49 N 521724.17 E 0.327 5097.85 9743.44 97.970 124.160 6376.04 6438.60 3986.95 8 3321.25 E 6009820.29 N 521802.32 E 0.747 5188.44 9839.71 90.860 132.760 6368.62 6431.18 4046.59 S 3396.27 E 6009760.84 N 521877.49 E 11.566 5282.57 9935.60 88.590 135.360 6369.08 6431.64 4113.268 3465.17 E 6009694.34 N 521946.55 E 3.599 5378.04 10032.55 88.830 136.210 6371.27 6433.83 4182.73 S 3532.76 E 6009625.04 N 522014.31 E 0.911 5474.78 10128.07 84.700 137.470 6376.65 6439.21 4252.27 8 3597.98 E 6009555.66 N 522079.70 E 4.520 5570.04 10183.29 82.420 139.340 6382.85 6445.41 4293.30 S 3634.40 E 6009514.72 N 522116.23 E 5.326 5624.90 10223.91 87.110 138.430 6386.55 6449.11 4323.77 8 3660.99 E 6009484.32 N 522142.90 E 11.759 5665.33 10320.91 91.350 136.200 6387.86 6450.42 4395.05 S 3726.73 E 6009413.20 N 522208.81 E 4.938 5762.24 10413.32 91.540 136.270 6385.53 6448.09 4461.768 3790.63 E 6009346.65 N 522272.88 E 0.219 5854.49 10447.52 91.660 136.330 6384.57 6447.13 4486.48 S 3814.25 E 6009321.99 N 522296.56 E 0.392 5888.62 10515.00 91.660 136.330 6382.62 6445.18 4535.27 8 3860.83 E 6009273.32 N 522343.26 E 0.000 5955.99 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (62.56' MSL). Northings and Eastings are relative to 1561' FSL & 70' FWL. Magnetic Declination at Surface is 25.9010 (02-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertic~1 Section is from 1561' FSL & 70' FWL and calculated along an Azimuth of 139.310° (True). (- Based upon Minimum Curvature type calculations, at a Measured Depth of 10515.00ft., The Bottom Hole Displacement is 5956.06ft., in the Direction of 139.5930 (True). .. ...",."-.,,..-"-.--. ".' .,.""~~" ""... ....---...--.'...----.'----------.,.-.--..........-....-.-..-....-.-.,.--. .. 7 February, 2002. 15:31 Page 20f3 DrillQuest 2.00.08.005 . Spefry-Sun Drilling Services Survey Report for 3N-19 Your Ref: API 500292305600 Job No. AKMM11209, Surveyed: 4 January, 2002 . Kuparuk River Unit North Slope, Alaska Kuparuk 3N Comments "'-....... Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment ( 9455.03 9475.00 10515.00 6473.60 6472.30 6445.18 3828.83 S 3839.59 S 4535.27 S 3082.69 E 3099.46 E 3860.83 E Tie On Point Window Point Projected Survey Survey tool program for 3N-19 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 10515.00 6445.18 AK-6 BP JFR-AK (3N-19PB1) c- "",,--" .. ....-,--.-.....---....--"--...... ..- ..," 7 February, 2002 - 15:31 Page 3 0(3 DrillQuest 2.00.08.005 - ,L, 11-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3N-19 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,455.03' MD Window / Kickoff Survey 9,475.00' MD (if applicable) Projected Survey: 10,515.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 2 0 2002 Alaska Oil & Gas Cons. Commi88ion Anchorage i~¡; ,.I¡!'J " . -) Kuparuk River Unit North Slope, Alaska Kuparuk 3N, Slot 3N-19 3N-19 MWD Job No. AKMM11209, Surveyed: 4 January, 2002 SURVEY REPORT 7 February, 2002 Your Ref: API 500292305600 Surface Coordinates: 6013799.00 H, 518471.20 E (700 26' 55.9422" H, 149050' 57.5195" W) Kelly Bushing: 62. 56ft above Mean Sea Level ) SPSI'I'Y-SUF1 CAlL-LING SERVices A Halliburton Company SLJlvey Ref: svy9836 Spe;ty-Sun Drilling Services . Survey Report for 3N-19 MWD Your Ref: API 500292305600 Job No. AKMM11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (° /1 OOft) 9455.03 92.650 131.820 6411.04 6473.60 3890.92 S 3018.28 E 6009915.57 N 521499.11 E 4918.10 Tie On Point ) 9475.00 94.780 122.200 6409.75 6472.31 3902.90 S 3034.17 E 6009903.63 N 521515.03 E 49.237 4937.54 Window Point - 9551.57 97.520 130.580 6401.53 6464.09 3948.01 S 3095.40 E 6009858.67 N 521576.37 E 11.453 5011.67 9648.59 97.530 127.310 6388.82 6451.38 4008.46 S 3170.20 E 6009798.41 N 521651.32 E 3.341 5106.27 9743.44 97.970 122.510 6376.02 6438.58 4062.23 S 3247.24 E 6009744.83 N 521728.50 E 5.036 5197.27 9839.71 90.860 137.170 6368.58 6431.14 4123.56 S 3320.65 E 6009683.68 N 521802.06 E 16.875 5291.64 9935.60 88.590 138.380 6369.04 6431.60 4194.56 S 3385.09 E 6009612.84 N 521866.68 E 2.683 5387.48 10032.55 88.830 135.940 6371.22 6433.78 4265.63 S 3450.99 E 6009541.94 N 521932.75 E 2.528 5484.33 10128.07 84.700 139.560 6376.61 6439.17 4336.19 S 3515.09 E 6009471.53 N 521997.03 E 5.745 5579.63 10183.29 82.420 142.170 6382.80 6445.36 4378.74 S 3549.72 E 6009429.07 N 522031.76 E 6.253 5634.4 7 10223.91 87.110 137.370 6386.51 6449.07 4409.60 S 3575.84 E 6009398.27 N 522057.95 E 16.484 5674.90 10320.91 91.350 139.420 6387.82 6450.38 4482.11 S 3640.22 E 6009325.93 N 522122.52 E 4.855 5771.85 10413.32 91.540 137.820 6385.48 6448.04 4551.42 S 3701.29 E 6009256.76 N 522183.75 E 1.743 5864.22 10447.52 91.660 139.840 6384.53 6447.09 4577.16 S 3723.79 E 6009231.09 N 522206.32 E 5.915 5898.41 10515.00 91.660 139.840 6382.58 6445.14 4628.71 S 3767.29 E 6009179.64 N 522249.95 E 0.000 5965.85 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (62.56' MSL). Northings and Eastings are relative to 1561' FSL & 70' FWL. )Magnetic Declination at Surface is 25.869° (07 -Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1561' FSL & 70' FWL and calculated along an Azimuth of 139.310° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10515.00ft., The Bottom Hole Displacement is 5968.03ft., in the Direction of 140.858° (True). - -..-.-..--,..u.-----'-,-., 7 February, 2002 - 15:31 Page 2 of 3 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3N-19 MWD Your Ref: API 500292305600 Job No. AKMM11209, Surveyed: 4 January, 2002 . Kuparuk River Unit North Slope, Alaska Kuparuk 3N Comments .".-) Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) (ffl Comment 9455.03 9475.00 10515.00 6473.60 6472.31 6445.14 3890.92 S 3902.90 S 4628.71 S 3018.28 E 3034.17 E 3767.29 E Tie On Point Window Point Projected Survey Survey tool program for 3N-19 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 10515.00 6445.14 MWD Magnetic (3N-19PB1 MWD) ) ----_.__._--~. -----._w_.--- ....- 7 February, 2002 - 15:31 Page 3 of 3 DrillQuest 2.00.08.005 '-- L 11-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 3N-19PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 10,483.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 2 0 2002 Alaska Oil & Gas Cons. Commi88km Anchorage ~FINITIVE .. .. .;..... u 'f ..... Kuparuk River Unit North Slope, Alaska Kuparuk 3N, Slot 3N-19 3N-19PB1 Job No. AKZZ11209, Surveyed: 4 January, 2002 ( SURVEY REPORT 7 February, 2002 Your Ref: API 500292305670 Surface Coordinates: 6013799.00 N, 518471.20 E (700 26' 55.94228 H, 149050' 57.51958 W) Kelly Bushing: 62.56ft above Mean Sea Level (- ,,1""*"" spe'-''''y-sul! DRILLING SERVices A Halliburton Company Survey Ref: svy9131 Sperry-Sun Drilling Services' . Survey Report for 3N-19PB1 Your Ref: API 500292305670 Job No. AKZZ11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -62.56 0.00 O.OON O.OOE 6013799.00 N 518471.20 E 0.00 AK-6 BP _IFR.AK { 200.69 0.510 34.890 138.13 200.69 0.73 N 0.51 E 6013799.73 N 518471.71 E 0.254 -0.22 287.00 0.440 79.100 224.43 286.99 1.11 N 1.06 E 6013800.11 N 518472.25 E 0.421 -0.15 385.51 1.050 145.570 322.94 385.50 0.44N 1.94 E 6013799.44 N 518473.14 E 0.977 0.93 473.09 2.750 163.060 410.47 473.03 2.23S 3.00E 6013796.77 N 518474.21 E 2.029 3.65 562.32 4.350 164.100 499.52 562.08 7.54S 4.55E 6013791.47 N 518475.77 E 1.794 8.68 650.83 4.790 168.520 587.75 650.31 14.39 S 6.21 E 6013784.63 N 518477.45 E 0.636 14.96 741.95 6.110 169.320 678.46 741.02 22.88 S 7.87 E 6013776.14 N 518479.12 E 1.451 22.48 834.00 7.000 168.730 769.90 832.46 33.20 S 9.87E 6013765.83 N 518481.15 E 0.970 31.61 925.77 9.690 165.970 860.69 923.25 46.18 S 12.84 E 6013752.86 N 518484.15 E 2.963 43.38 1010.89 12.660 159.720 944.19 1006.75 61.88 S 17.81 E 6013737.17 N 518489.16 E 3.763 58.53 1111.97 13.170 156.110 1042.72 1105.28 82.80 S 26.31 E 6013716.27 N 518497.71 E 0.944 79.93 1204.57 13.500 152.470 1132.82 1195.38 102.03 S 35.58 E 6013697.06 N 518507.03 E 0.974 100.56 1301.94 13.140 152.660 1227.57 1290.13 121.94 S 45.91 E 6013677.18 N 518517.42 E 0.372 122.39 1398.56 12.960 154.870 1321.70 1384.26 141.50 S 55.56 E 6013657.64 N 518527.11 E 0.549 143.52 1494.85 12.540 156.350 1415.62 1478.18 160.85 S 64.34 E 6013638.31 N 518535.94 E 0.553 163.91 1590.98 9.430 145.4 70 1509.98 1572.54 176.91 S 72.99 E 6013622.28 N 518544.63 E 3.875 181.73 1686.37 8.700 138.850 1604.18 1666.74 188.78 S 82.17 E 6013610.43 N 518553.84 E 1.333 196.71 ( ,~,..' 1783.25 8.580 139.100 1699.96 1762.52 199.76 S 91.72 E 6013599.47 N 518563.42 E 0.130 211.26 1879.27 7.200 138.350 1795.07 1857.63 209.67 S 100.41 E 6013589.58 N 518572.13 E 1.441 224.44 1974.61 4.850 140.130 1889.88 1952.44 217.23 S 106.97 E 6013582.04 N 518578.70 E 2.472 234.45 2072.74 4.850 139.610 1987.66 2050.22 223.57 S 112.31 E 6013575.71 N 518584.07 E 0.045 242.75 2170.10 3.380 141.170 2084.76 2147.32 228.94 S 116.78 E 6013570.35 N 518588.55 E 1.514 249.73 2266.02 1.050 11 7.120 2180.61 2243.17 231.54 S 119.34 E 6013567.75 N 518591.11 E 2.563 253.37 2362.65 0.690 46.870 2277.23 2339.79 231.55 S 120.55 E 6013567.75 N 518592.32 E 1.080 254.17 2459.56 0.520 53.160 2374.13 2436.69 230.89 S 121.33 E 6013568.41 N 518593.10 E 0.188 254.17 2553.61 0.560 50.200 2468.18 2530.74 230.34 S 122.02 E 6013568.97 N 518593.79 E 0.052 254.21 2649.39 0.570 21.100 2563.95 2626.51 229.59 S 122.55 E 6013569.71 N 518594.32 E 0.297 253.99 2745.73 0.4 90 35.300 2660.29 2722.85 228.81 S 122.96 E 6013570.50 N 518594.73 E 0.159 253.66 2841.95 0.330 15.890 2756.51 2819.07 228.21 S 123.28 E 6013571.10 N 518595.04 E 0.218 253.41 ". .. .-,.-......--...,-.-.--"--- . ."._-"-__'--_M"_-_"~---""._-" "., ... . 7 February, 2002 - 15:30 Page 20f6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 3N-19PB1 Your Ref: API 500292305670 Job No. AKZZ11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2939.71 0.770 23.750 2854.26 2916.82 227.34 S 123.62 E 6013571.97 N 518595.38 E 0.456 252.97 ( 3035.20 2.940 144.660 2949.71 3012.27 228.75 S 125.29 E 6013570.57 N 518597.06 E 3.561 255.13 3131.28 5.990 148.440 3045.49 3108.05 235.03 S 129.34 E 6013564.29 N 518601.12 E 3.187 262.54 3227.45 5.790 146.360 3141.15 3203.71 243.34 S 134.66 E 6013555.99 N 518606.46 E 0.304 272.31 3323.14 5.670 142.580 3236.37 3298.93 251.12 S 140.20 E 6013548.23 N 518612.02 E 0.414 281.82 3420.40 7.020 146.150 3333.03 3395.59 259.87 S 146.43 E 6013539.50 N 518618.28 E 1.445 292.51 3515.22 9.070 148.910 3426.91 3489.4 7 271.08 S 153.52 E 6013528.30 N 518625.39 E 2.199 305.64 3612.27 12.290 150.050 3522.27 3584.83 286.59 S 162.63 E 6013512.82 N 518634.54 E 3.325 323.33 3726.56 15.200 150.700 3633.27 3695.83 310.20 S 176.04 E 6013489.24 N 518648.01 E 2.550 349.98 3821.80 18.550 150.240 3724.40 3786.96 334.24 S 189.67 E 6013465.23 N 518661.70 E 3.520 377.1 0 3918.43 21.460 144.530 3815.20 3877.76 361.99 S 207.56 E 6013437.52 N 518679.66 E 3.624 409.80 4014.07 23.360 143.900 3903.61 3966.17 391.56 S 228.89 E 6013408.01 N 518701.06 E 2.002 446.13 4112.09 25.120 144.660 3992.98 4055.54 424.24 S 252.38 E 6013375.39 N 518724.63 E 1.824 486.22 4208.28 27.550 144.090 4079.18 4141.74 458.92 S 277.24 E 6013340.77 N 518749.57 E 2.540 528.72 4303.81 30.380 145.030 4162.76 4225.32 496.61 S 304.04 E 6013303.14 N 518776.47 E 3.000 574.78 4402.43 33.400 146.650 4246.48 4309.04 539.73 S 333.27 E 6013260.09 N 518805.80 E 3.183 626.53 4495.99 36.300 148.850 4323.26 4385.82 584.96 S 361.76 E 6013214.94 N 518834.41 E 3.378 679.40 4591.76 39.450 150.470 4398.85 4461.41 635.71 S 391.43 E 6013164.27 N 518864.20 E 3.449 737.22 ( 4688.26 42.960 148.310 4471.44 4534.00 690.38 S 423.82 E 6013109.67 N 518896.73 E 3.924 799.80 ~ 4786.44 47.030 147.740 4540.86 4603.42 749.25 S 460.58 E 6013050.90 N 518933.64 E 4.166 868.40 4879.70 51.100 147.950 4601.95 4664.51 808.88 $ 498.07 E 6012991.35 N 518971.27 E 4.367 938.06 4975.79 53.060 143.950 4661.01 4723.57 871.64 S 540.52 E 6012928.70 N 519013.88 E 3.865 1013.33 5071.98 54.170 141 .120 4718.08 4780.64 933.09 S 587.63 E 6012867.37 N 519061.14 E 2.635 1090.63 5168.20 53.350 141.540 4774.96 4837.52 993.68 S 636.12 E 6012806.90 N 519109.78 E 0.922 1168.18 5262.12 52.870 139.930 4831.34 4893.90 1051.83 S 683.66 E 6012748.86 N 519157.46 E 1.463 1243.27 5358.77 54.560 141.480 4888.54 4951.10 1112.13 S 732.98 E 6012688.69 N 519206.94 E 2.174 1321 . 1 5 5455.90 54.610 140.440 4944.83 5007.39 1173.61 S 782.84 E 6012627.33 N 519256.95 E 0.874 1400.27 5551.57 53.890 139.910 5000.72 5063.28 1233.24 S 832.57 E 6012567.83 N 519306.82 E 0.877 1477.91 5647.21 53.520 139.940 5057.34 5119.90 1292;22 S 882.19 E 6012508.97 N 519356.59 E 0.388 1554.99 5743.79 53.370 139.800 5114.86 5177.42 1351.54 S 932.20 E 6012449.77 N 519406.74 E 0.194 1632.56 . .~ ,,,0...,.,,..- ..-.,-...-".... ,-.----- .-.-,.--,.".-..-. '" ---" ..,'..-..-.-- -, 7 February, 2002 - 15:30 Page 30f6 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 3N-19PB1 Your Ref: API 500292305670 Job No. AKZZ11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk .River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5841.81 52.510 139.250 5173.93 5236.49 1411.04 S 982.97 E 6012390.40 N 519457.66 E 0.985 1710.78 I" 5935.10 53.160 140.950 5230.29 5292.85 1468.08 S 1030.65 E 6012333.48 N 519505.48 E 1.611 1785.11 ( 6030.34 53.150 141.470 5287.40 5349.96 1527.48 S 1078.39 E 6012274.19 N 519553.38 E 0.437 1861.29 6126.34 54.120 143.680 5344.33 5406.89 1588.87 S 1125.36 E 6012212.92 N 519600.50 E 2.111 1938.46 6223.02 54.330 143.820 5400.85 5463.41 1652.13 S 1171.74E 6012149.78 N 519647.03 E 0.247 2016.66 6319.02 54.060 143.300 5457.01 5519.57 1714.76 S 1217.99 E 6012087.26 N 519693.43 E 0.522 2094.30 6415.01 53.580 142.610 5513.68 5576.24 1776.61 S 1264.66 E 6012025.53 N 519740.26 E 0.766 2171.62 6513.56 55.520 145.210 5570.84 5633.40 1841.48 S 1311.93 E 6011960.78 N 519787.69 E 2.914 2251.63 6607.63 56.400 146.460 5623.50 5686.06 1905.98 S 1355.70 E 6011896.39 N 519831.62 E 1.445 2329.07 6704.06 56.030 146.210 5677.12 5739.68 1972.68 S 1400.12 E 6011829.79 N 519876.21 E 0.440 2408.62 6798.90 55.730 146.010 5730.32 5792.88 2037.86 S 1443.90 E 6011764.73 N 519920.15 E 0.361 2486.58 6895.54 55.180 146.490 5785.12 5847.68 2104.04 S 1488.13 E 6011698.65 N 519964.54 E 0.701 2565.60 6992.23 54.600 145.930 5840.73 5903.29 2169.78 S 1532.12 E 6011633.02 N 520008.69 E 0.764 2644.12 7088.23 54.000 146.110 5896.75 5959.31 2234.43 S 1575.69 E 6011568.49 N 520052.42 E 0.643 2721.54 7185.46 53.200 145.500 5954.45 6017.01 2299.16 S 1619.67 E 6011503.86 N 520096.56 E 0.965 2799.30 7282.52 52.440 144.930 6013.10 6075.66 2362.67 S 1663.78 E 6011440.46 N 520140.83 E 0.912 2876.22 7377.57 51.490 145.430 6071.67 6134.23 2424.13 S 1706.53 E 6011379.11 N 520183.74 E 1.082 2950.69 7469.16 52.530 145.800 6128.04 6190.60 2483.70 $ 1747.30 E 6011319.64 N 520224.65 E 1.179 3022.44 ( 7569.03 56.740 146.020 6185.83 6248.39 2551.13 S 1792.93 E 6011252.32 N 520270.45 E 4.219 3103.32 7665.44 60.360 145.730 6236.13 6298.69 2619.20 S 1839.07 E 6011184.36 N 520316.75 E 3.764 3185.02 7763.82 63.820 145.880 6282.17 6344.73 2691.10 S 1887.92 E 6011112.59 N 520365.78 E 3.520 3271.38 7860.31 68.350 146.710 6321.27 6383.83 2764.47 S 1936.84 E 6011039.34 N 520414.89 E 4.760 3358.91 7956.26 74.100 146.920 6352.14 6414.70 2840.47 S 1986.54 E 6010963.47 N 520464.78 E 5.996 3448.93 8050.03 78.770 146.520 6374.13 6436.69 2916.65 S 2036.55 E 6010887.41 N 520514.97 E 4.997 3539.30 8146.82 82.580 146.810 6389.81 6452.37 2996.43 S 2089.02 E 6010807.76 N 520567.64 E 3.947 3634.01 8242.67 88.370 146.420 6397.37 6459.93 3076.18 S 2141.58 E 6010728.14 N 520620.40 E 6.054 3728.75 8338.95 89.580 141.000 6399.09 6461.65 3153.74 S 2198.54 E 6010650.72 N 520677.55 E 5.767 3824.69 8435.25 92.080 135.840 6397.70 6460.26 3225.74 S 2262.41 E 6010578.88 N 520741.60 E 5.953 3920.93 8528.82 92.800 128.660 6393.71 6456.27 3288.55 S 2331.57 E 6010516.23 N 520810.91 E 7.705 4013.64 8625.35 89.920 123.030 6391.42 6453.98 3345.04 S 2409.75 E 6010459.95 N 520889.24 E 6.549 4107.44 .. ..-.."" -~- -- -_...._-._- .-.. _M'__""-'-"---".""""."."~"" . 7 February, 2002 - 15:30 Page 4 0(6 1:1:.-. DrnIQuest~O~O~OO5 Sperry-Sun Drilling Services . Survey Report for 3N-19PB1 Your Ref: API 500292305670 Job No. AKZZ11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8696.41 85.720 124.110 6394.12 6456.68 3384.29 5 2468.90 E 6010420.84 N 520948.48 E 6.102 4175.77 ( 8782.31 85.560 129.160 6400.65 6463.21 3435.38 5 2537.61 E 6010369.92 N 521017.32 E 5.865 4259.31 8832.65 89.200 125.110 6402.95 6465.51 3465.73 S 2577.69 E 6010339.67 N 521057.47 E 10.810 4308.45 8879.14 90.370 125.510 6403.13 6465.69 3492.60 5 2615.63 E 6010312.90 N 521095.47 E 2.660 4353.56 8927.64 90.620 126.900 6402.71 6465.27 3521.24 5 2654.76 E 6010284.35 N 521134.68 E 2.912 4400.79 8975.93 90.550 126.640 6402.22 6464.78 3550.155 2693.44 E 6010255.54 N 521173.43 E 0.558 4447.92 9012.94 90.620 127.160 6401.84 6464.40 3572.37 5 2723.03 E 6010233.39 N 521203.08 E 1.418 4484.07 9072.07 90.550 126.270 6401.24 6463.80 3607.725 2770.43 E 6010198.16 N 521250.56 E 1.510 4541.77 9164.13 89.630 124.020 6401.09 6463.65 3660.71 5 2845.70 E 6010145.36 N 521325.97 E 2.640 4631.03 9214.50 86.730 126.660 6402.69 6465.25 3689.82 5 2886.76 E 6010116.34 N 521367.10 E 7.784 4679.87 9263.82 86.560 126.080 6405.58 6468.14 3719.02 5 2926.41 E 6010087.25 N 521406.82 E 1.224 4727.86 9360.93 87.170 125.540 6410.89 6473.45 3775.75 S 3005.04 E 6010030.71 N 521485.59 E 0.838 4822.14 9455.03 92.650 123.170 6411.04 6473.60 3828.83 $ 3082.69 E 6009977.82 N 521563.37 E 6.345 4913.01 9550.69 102.830 118.460 6398.16 6460.72 3877.35 5 3163.94 E 6009929.50 N 521644.74 E 11.704 5002.78 9648.01 103.100 118.400 6376.33 6438.89 3922.50 5 3247.34 E 6009884.56 N 521728.26 E 0.284 5091.39 9743.71 98.280 127.610 6358.54 6421.10 3973.705 3326.06 E 6009833.55 N 521807.10 E 10.711 5181.53 9839.78 91.350 129.750 6350.48 6413.04 4033.50 5 3400.74 E 6009773.94 N 521881.92 E 7.547 5275.56 9935.52 90.310 129.630 6349.10 6411.66 4094.635 3474.40 E 6009712.99 N 521955.74 E 1.093 5369.94 ( 10030.83 88.770 130.340 6349.86 6412.42 4155.875 3547.42 E 6009651.93 N 522028.91 E 1.779 5463.98 10127.23 85.510 135.380 6354.67 6417 .23 4221.33 5 3617.97 E 6009586.65 N 522099.62 E 6.221 5559.61 10220.60 84.950 136.690 6362.44 6425.00 4288.30 5 3682.56 E 6009519.84 N 522164.38 E 1.521 5652.50 10321.09 84.520 137.420 6371.66 6434.22 4361.55 5 3750.74 E 6009446.76 N 522232.74 E 0.840 5752.49 10410.73 81.480 138.340 6382.58 6445.14 4427.53 S 3810.40 E 6009380.93 N 522292.57 E 3.541 5841.42 10483.00 81.480 138.340 6393.29 6455.85 4480.93 5 3857.91 E 6009327.65 N 522340.21 E 0.000 5912.88 Projected Survey .~.-_.~--- ... ."".,,,,.,___e_._.__---.--- ------'_"_'__'---_"_-'"'_'_''''~',''_'h''''' ...""....... .. .""..~. .'. ". ....0 ..',. '... ""'.'...,, ..'~ ".,.-..". -.' ., 7 February, 2002 - 15:30 Page 50'6 ~"...' Dril/Quest 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for 3N-19PB1 Your Ref: API 500292305670 Job No. AKZZ11209, Surveyed: 4 January, 2002 . Kuparuk River Unit North Slope, Alaska Kuparuk 3N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (62.56' MSL). Northings and Eastings are relative to 1561' FSL & 70' FWL. Magnetic Declination at Surface is 25.917° (15-Dec-01) ( The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1561' FSL & 70' FWL and calculated along an Azimuth of 139.310° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10483.00ft., The Bottom Hole Displacement is 5912.89ft., in the Direction of 139.273° (~rue). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 10483.00 6455.85 4480.93 S 3857.91 E Projected Survey ,,,...-. Survey tool program for 3N-19PB1 ( From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 10483.00 6455.85 AK-6 BP JFR-AK . ....,.........,.~N'.___--- --~_..-._~~..._._~.~ -,,-_. _..~,~". ., ...-.. ..,"' .. 7 February, 2002 - 15:30 Page 6 0'6 Dril/Quest 2.00.08.005 ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( ciit:j:JYß~~5::?' 11-Feb-02 Re: Distribution of Survey Data for Well 3N-19PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 10,483.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED F~B 2 0 2002 AlaSka Oü & GasCons.ConIniIIM Anchorage ( Kuparuk River Unit North Slope, Alaska Kuparuk 3N, Slot 3N-19 3N-19PB1 MWD Job No. AKMM11209, Surveyed: 4 January, 2002 SURVEY REPORT 7 February, 2002 Your Ref: API 500292305670 Surface Coordinates: 6013799.00 N,518471.20 E '(70° 26' 55.9422" N, 149050' 57.5195" W) Kelly Bushing: 62.56ft above Mean Sea Level r SpI!!I'I'Y-I5UIJ DAIL.L.ING seRVices A Halliburton Company Survey Ref: svy9835 Sperty-Sun Drilling Services . Survey Report for 3N-19PB1 MWD Your Ref: API 500292305670 Job No. AKMM11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -62.56 0.00 0.00 N 0.00 E 6013799.00 N 518471.20 E 0.00 MWD Magnetic ( 200.69 0.510 35.520 138.13 200.69 0.73 N 0.52 E 6013799.73 N 518471.72 E 0.254 -0.21 287.00 0.440 79.160 224.43 286.99 1.10 N 1.07 E 6013800.10 N 518472.26 E 0.416 -0.14 385.51 1.050 145.940 322.94 385.50 0.43 N 1.94 E 6013799.43 N 518473.14 E 0.980 0.95 473.09 2.750 163.380 410.47 473.03 2.25 S 3.00 E 6013796.75 N 518474.20 E 2.028 3.66 562.32 4.350 164.490 499.52 562.08 7.57 S 4.51 E 6013791.45 N 518475.73 E 1.795 8.68 650.83 4.790 168.870 587.75 650.31 14.43 S 6.12 E 6013784.59 N 518477.36 E 0.634 14.93 741.95 6.110 169.810 678.46 741.02 22.93 S 7.72 E 6013776.09 N 518478.97 E 1.452 22.42 834.00 7.000 169.430 769.90 832.46 33.27 S 9.61 E 6013765.76 N 518480.89 E 0.968 31.49 925.77 9.690 166.680 860.69 923.25 46.28 S 12.42 E 6013752.75 N 518483.73 E 2.963 43.19 1010.89 12.660 159.730 944.20 1006.76 62.01 S 17.30 E 6013737.04 N 518488.65 E 3.825 58.30 1111.97 13.170 156.500 1042.72 1105.28 82.96 S 25.73 E 6013716.11 N 518497.13 E 0.874 79.68 1204.57 13.500 152.750 1132.82 1195.38 102.24 S 34.88 E 6013696.84 N 518506.34 E 0.999 100.27 1301.94 13.140 152.950 1227.57 1290.13 122.20 S 45.12 E 6013676.91 N 518516.62 E 0.373 122.08 1398.56 12.960 155.060 1321.70 1384.26 141.81 S 54.69 E 6013657.33 N 518526.24 E 0.527 143.18 1494.85 12.540 156.570 1415.62 1478.18 161.19S 63.39 E 6013637.97 N 518534.99 E 0.557 163.55 1590.98 9.430 145.870 1509.98 1572.54 177.29 S 71.97 E 6013621.89 N 518543.60 E 3.855 181.35 1686.37 8.700 139.220 1604.18 1666.74 189.22 S 81.06 E 6013609.98 N 518552.73 E 1.337 196.33 r 1783.25 8.580 139.390 1699.96 1762.52 200.26 S 90.55 E 6013598.97 N 518562.25 E 0.127 210.88 1879.27 7.200 138.610 1795.07 1857.63 210.21 S 99.19 E 6013589.04 N 518570.91 E 1 .441 224.06 1974.61 4.850 140.550 1889.88 1952.44 217.80 S 105.71 E 6013581.46 N 518577.45 E 2.474 234.07 2072.74 4.850 139.960 1987.66 2050.22 224.18 S 111.01 E 6013575.09 N 518582.77 E 0.051 242.36 2170.10 3.380 141 .480 2084.76 2147.32 229.58 S 115.45 E 6013569.71 N 518587.21 E 1.514 249.35 2266.02 1.050 117.660 2180.61 2243.17 232.20 S 117.99 E 6013567.09 N 518589.76 E 2.561 252.99 2362.65 0.690 46.960 2277 .23 2339.79 232.22 S 119.20 E 6013567.08 N 518590.97 E 1.085 253.79 2459.56 0.520 53.370 2374.13 2436.69 231.55 S 119.97 E 6013567.74 N 518591.75 E 0.189 253.80 2553.61 0.560 50.610 2468.18 2530.74 231.01 S 120.67 E 6013568.29 N 518592.44 E 0.051 253.84 2649.39 0.570 21.400 2563.95 2626.51 230.27 S 121.21 E 6013569.03 N 518592.98 E 0.298 253.62 2745.73 0.490 35.450 2660.29 2722.85 229.49 S 121.62 E 6013569.82 N 518593.39 E 0.158 253.30 2841.95 0.330 15.780 2756.51 2819.07 228.88 S 121.94 E 6013570.42 N 518593.70 E 0.219 253.05 7 February, 2002 - 15:31 Page 2 0'6 DrillQuest 2.00.08.005 Kuparuk River Unit Measured Depth (ft) Incl. Azim. ( 2939.71 3035.20 3131.28 3227.45 3323.14 0.770 24.080 2.940 145.070 5.990 148.760 5.790 146.800 5.670 142.940 3420.40 7.020 146.470 3515.22 9.070 149.280 3612.27 12.290 150.340 3726.56 15.200 150.930 3821.80 18.550 150.520 3918.43 21.460 144.920 4014.07 23.360 144.280 4112.09 25.120 145.040 4208.28 27.550 144.470 4303.81 30.380 145.410 r- 4402.43 33.400 147.020 4495.99 36.300 149.230 4591.76 39.450 150.950 4688.26 42.960 148.470 4786.44 47.030 146.710 4879.70 51.100 148.540 4975.79 53.060 145.540 5071.98 54.170 143.610 5168.20 53.350 142.640 5262.12 52.870 140.980 5358.77 54.560 141.960 5455.90 54.610 141.220 5551.57 53.890 141.590 5647.21 53.520 140.170 5743.79 53.370 141.130 7 February, 2002 - 15:31 ..t'W ' . ,~~~~::~~, Sperry-Sun Drilling Services Survey Report for 3N-19PB1 MWD Your Ref: API 500292305670 Job No. AKMM11209, Surveyed: 4 January, 2002 Sub-Sea Vertical Depth Depth (ft) (ft) 2854.26 2949.71 3045.49 3141.15 3236.37 3333.03 3426.91 3522.27 3633.27 3724.40 3815.20 3903.61 3992.98 4079.18 4162.76 4246.48 4323.26 4398.85 4471.44 4540.86 4601.96 4661.01 4718.08 4774.96 4831.34 4888.54 4944.82 5000.72 5057.33 5114.86 2916.82 3012.27 3108.05 3203.71 3298.93 3395.59 3489.47 3584.83 3695.83 3786.96 3877.76 3966.17 4055.54 4141.74 4225.32 4309.04 4385.82 4461.41 4534.00 4603.42 4664.52 4723.57 4780.64 4837.52 4893.90 4951.10 5007.38 5063.28 5119.89 5177.42 Local Coordinates Northlngs Eastlngs (ft) (ft) 228.01 5 229.44 S 235.74 S 244.09 5 251.90 S 260.69 S 271.95 5 287.51 S 311.185 335.28 5 363.145 392.85 5 425.68 S 460.52 S 498.40 5 541.71 S 587.12 S 638.09 S 692.94 5 751.50 S 811.01 5 874.58 5 937.67 $ 999.755 1 0518.79 5 1119.745 1181.765 1242.45 S 130:2.25 S 1362.24 S 122.28 E 123.94 E 127.96 E 133.21 E 138.71 E 144.89 E 151.90 E 160.93 E 174.23 E 187.75 E 205.48 E 226.61 E 249.88 E 274.51 E 301.07 E 330.01 E 358.20 E 387.48 E 419.58 E 456.81 E 494.49 E 535.74 E 580.63 E 627.20 E 673.63 E 722.16 E 771.34 E 819.77 E 868.40 E 917.59 E .. ..__.....,~. -""'."-_4__.__.. Page 3 of6 Global Coordinates Northlngs Eastlngs (ft) (ft) 6013571.29 N 6013569.87 N 6013563.57 N 6013555.24 N 6013547.44 N 6013538.67 N 6013527.43 N 6013511.89 N 6013488.26 N 6013464.18 N 6013436.37 N 6013406.71 N 6013373.94 N 6013339.16 N 6013301.35 N 6013258.11 N 6013212.77 N 6013161.87 N 6013107.10 N 6013048.63 N 6012989.22 N 6012925.75 N 6012862.77 N 6012800.81 N 6012741.88 N 6012681.06 N 6012619.15 N 6012558.59 N 6012498.91 N 6012439.04 N 518594.04 E 518595.71 E 518599.74 E 518605.02 E 518610.53 E 518616.73 E 518623.78 E 518632.84 E 518646.20 E 518659.78 E 518677.58 E 518698.78 E 518722.13 E 518746.85 E 518773.50 E 518802.55 E 518830.85 E 518860.26 E 518892.49 E 518929.87 E 518967.70 E 519009.11 E 519054.15 E 519100.87 E 519147.46 E 519196.13E 519245.46 E 519294.05 E 519342.83 E 519392.17 E Dogleg Vertical Rate Section (o/100ft) 0.456 3.562 3.187 0.295 0.422 1 .444 2.201 3.324 2.549 3.520 3.602 2.003 1.824 2.540 3.000 3.181 3.380 3.469 4.011 4.335 252.61 254.78 262.1 8 271.93 281.44 292.1 3 305.24 322.92 349.54 376.64 409.32 445.62 485.68 528.16 574.19 625.90 678.71 736.46 798.97 867.65 4.609 937.34 3.198 1012.44 1.985 1089.54 1.178 1166.97 1.503 1242.01 1.930 1319.86 0.623 1398.95 0.815 1476.54 1.258 1553.60 0.813 1631.15 .;~(i:~ ~ North Slope, Alaska Kuparuk 3N Comment DrillQuest 2.00.08.005 ~~;~~ . Sperry-Sun Drilling Servicés' bJ Survey Report for 3N-19P81 MWD Your Ref: API 500292305670 Job No. AKMM11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5841.81 52.510 140.290 5173.93 5236.49 1422.78 S 967.12 E 6012378.62 N 519441.84 E 1.112 1709.35 { 5935.10 53.160 141.140 5230.29 5292.85 1480.32 S 1014.19 E 6012321.20 N 519489.06 E 1.006 1783.67 6030.34 53.1 50 142.350 5287.40 5349.96 1540.175 1061.38 E 6012261.47 N 519536.39 E 1.017 1859.81 6126.34 54.120 143.690 5344.32 5406.88 1601.92 S 1107.87 E 6012199.83 N 519583.04 E 1.511 1936.95 6223.02 54.330 143.900 5400.84 5463.40 1665.22 5 1154.21 E 6012136.65 N 519629.53 E 0.280 2015.15 6319.02 54.060 143.370 5457.00 5519.56 1727.91 5 1200.37 E 6012074.07 N 519675.85 E 0.529 2092.79 6415.01 53.580 143.590 5513.67 5576.23 1790.18 S 1246.48 E 6012011.92 N 519722.11 E 0.533 2170.06 6513.56 55.520 146.430 5570.83 5633.39 1855.95 S 1292.48 E 6011946.26 N 519768.28 E 3.063 2249.92 6607.63 56.400 147.410 5623.49 5686.05 1921.26 S 1335.03 E 6011881.05 N 519810.98 E 1.273 2327.19 6704.06 56.030 147.130 5677.11 5739.67 1988.68 S 1378.36 E 6011813.74 N 519854.48 E 0.453 2406.56 6798.90 55.730 148.330 5730.31 5792.87 2055.07 5 1420.28 E 6011747.46 N 519896.57 E 1.094 2484.22 6895.54 55.180 147.130 5785.11 5847.67 2122.37 S 1462.77 E 6011680.26 N 519939.23 E 1.170 2562.96 6992.23 54.600 146.590 5840.73 5903.29 2188.60 5 1506.01 E 6011614.14 N 519982.63 E 0.754 2641.37 7088.23 54.000 146.630 5896.75 5959.31 2253.70 5 1548.92 E 6011549.15 N 520025.70 E 0.626 2718.70 7185.46 53.200 146.080 5954.44 6017.00 2318.85 S 1592.28 E 6011484.11 N 520069.22 E 0.940 2796.37 7282.52 52.440 145.220 6013.10 6075.66 2382.69 5 1635.91 E 6011420.37 N 520113.01 E 1.054 2873.23 7377.57 51.490 145.380 6071.66 6134.22 2444.24 S 1678.53 E 6011358.93 N 520155.78 E 1.008 2947.68 7469.16 52.530 146.370 6128.04 6190.60 2504.00 5 1719.02 E 6011299.27 N 520196.42 E 1.420 3019.39 7569.03 56.740 146.930 6185.83 6248.39 2572.02 S 1763.77 E 6011231.36 N 520241.34 E 4.240 31 00.14 r- 7665.44 60.360 146.130 6236.12 6298.68 2640.61 S 1809.13 E 6011162.89 N 520286.87 E 3.821 3181.73 7763.82 63.820 146.290 6282.17 6344.73 2712.855 1857.47 E 6011090.76 N 520335.39 E 3.520 3268.02 7860.31 68.350 146.820 6321.27 6383.83 2786.43 S 1906.07 E 6011017.30 N 520384.17 E 4.722 3355.50 7956.26 74.1 00 146.510 6352.14 6414.70 2862.30 S 1955.97 E 6010941.56 N 520434.26 E 6.000 3445.56 8050.03 78.770 148.000 6374.13 6436.69 2938.955 2005.25 E 6010865.03 N 520483.73 E 5.214 3535.81 8146.82 82.580 147.980 6389.81 6452.37 3019.92 S 2055.87 E 6010784.18 N 520534.55 E 3.936 3630.21 8242.67 88.370 146.730 6397.37 6459.93 3100.34 S 2107.39 E 6010703.89 N 520586.27 E 6.179 3724.78 8338.95 89.580 142.100 6399.09 6461.65 3178.605 2163.39 E 6010625.77 N 520642.46 E 4.970 3820.63 8435.25 92.080 134.630 6397.70 6460.26 3250.52 5 2227.32 E 6010554.01 N 520706.56 E 8.179 3916.83 8528.82 92.800 130.930 6393.71 6456.27 3314.00 S 2295.92 E 6010490.70 N 520775.32 E 4.025 4009.69 8625.35 89.920 131.250 6391.42 6453.98 3377.42 S 2368.64 E 6010427.46 N 520848.20 E 3.002 4105.19 ._'"_..~.._.. '."-""~---_."-'" '-"0- --.-" 7 February, 2002 - 15:31 Page 4 of6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 3N.19PB1 MWD Your Ref: API 500292305670 Job No. AKMM11209, Surveyed: 4 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8696.41 85.720 134.580 6394.12 6456.68 3425.75 S 2420.63 E 6010379.26 N 520900.31 E 7.540 4175.74 ( 8782.31 85.560 129.760 6400.66 6463.22 3483.23 S 2484.09 E 6010321.93 N 520963.92 E 5.598 4260.70 8832.65 89.200 125.790 6402.96 6465.52 3514.02 S 2523.83 E 6010291.24 N 521003.73 E 10.692 4309.95 8879.14 90.370 126.940 6403.13 6465.69 3541.59 S 2561.26 E 6010263.77 N 521041.23 E 3.529 4355.26 8927.64 90.620 127.970 6402.71 6465.27 3571.08 S 2599.76 E 6010234.37 N 521079.80 E 2.185 4402.72 8975.93 90.550 129.530 6402.22 6464.78 3601.30 S 2637.42 E 6010204.24 N 521117.53 E 3.234 4450.19 9012.94 90.620 127.470 6401.84 6464.40 3624.34 S 2666.38 E 6010181.28 N 521146.55 E 5.569 4486.54 9072.07 90.550 128.480 6401.24 6463.80 3660.72 S 2712.99 E 6010145.01 N 521193.25 E 1.712 4544.51 9164.13 89.630 121.420 6401.09 6463.65 3713.43 S 2788.39 E 6010092.50 N 521268.79 E 7.734 4633.64 9214.50 86.730 129.620 6402.70 6465.26 3742.64 S 2829.33 E 6010063.38 N 521309.80 E 17.258 4682.48 9263.82 86.560 128.540 6405.58 6468.14 3773.68 $ 2867.55 E 6010032.44 N 521348.10 E 2.213 4730.93 9360.93 87.170 125.600 6410.90 6473.46 3832.12 S 2944.91 E 6009974.19 N 521425.60 E 3.088 4825.68 9455.03 92.650 131.820 6411.04 6473.60 3890.92 S 3018.28 E 6009915.57 N 521499.11 E 8.808 4918.10 9550.69 102.830 121.750 6398.14 6460.70 3947.61 S 3093.93 E 6009859.07 N 521574.90 E 14.891 5010.41 9648.01 103.100 117.660 6376.30 6438.86 3994.60 S 3176.29 E 6009812.28 N 521657.38 E 4.105 5099.73 9743.71 98.280 131.720 6358.4 7 6421.03 4048.04 S 3253.33 E 6009759.04 N 521734.55 E 15.284 5190.47 9839.78 91.350 133.390 6350.41 6412.97 4112.74 S 3323.79 E 6009694.51 N 521805.18E 7.418 5285.48 9935.52 90.310 136.490 6349.02 6411.58 4180.35 S 3391.55 E 6009627.06 N 521873.10 E 3.415 5380.92 10030.83 88.770 137.010 6349.79 6412.35 4249.77 S 3456.85 E 6009557.81 N 521938.57 E 1.705 5476.13 r 10127.23 85.510 137.660 6354.60 6417.16 4320.56 S 3522.09 E 6009487.18 N 522003.99 E 3.448 5572.34 10220.60 84.950 140.370 6362.36 6424.92 4390.79 S 3583.11 E 6009417.10 N 522065.18 E 2.954 5665.37 10321.09 84.520 140.230 6371.58 6434.14 4467.78 S 3647.03 E 6009340.27 N 522129.29 E 0.450 5765.42 10410.73 81.480 143.270 6382.51 6445.07 4537.63 S 3702.10 E 6009270.56 N 522184.54 E 4,778 5854.29 10483.00 81.480 143.270 6393.22 6455.78 4594.91 S 3744.85 E 6009213.38 N 522227.42 E 0.000 5925.60 Projected Survey . _.m_...,.'_'---'.-."-..'-"---'-'- 7 February, 2002 - 15:31 Page 5 0(6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3N-19PB1 MWD Your Ref: API 500292305670 Job No. AKMM11209, Surveyed: 4 January, 2002 . Kuparuk River Unit North Slope, Alaska Kuparuk 3N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (62.56' MSL). Northings and Eastings are relative to 1561' FSL & 70' FWL. .( Magnetic Declination at Surface is 25.869° (07 -Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1561' FSL & 70' FWL and calculated along an Azimuth of 139.310° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10483.00ft., The Bottom Hole Displacement is 5927.65ft., in the Direction of 140.820° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10483.00 6455.78 4594.91 S 3744.85 E Projected Survey r Survey tool program for 3N-19PB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 10483.00 6455.78 MWD Magnetic '~""" ~._.,-,--_...,...,.~,~- . .--.-----.-.,. ...,.-.-.."..---.-....- '.- 7 February, 2002 - 15:31 Page 6 0'6 DrillQuest 2.00.08.005 3N-19 WELL TEST HISTORY TEST SEP SEP TOTAL DATE LENGTH CHK PRES TEMP FTP WHT OIL WTR GAS GLG %WC FGOR TGLR SAND Mar-OS-0205:18 15.3 30 128 134 181 70 1134 23 472 0 2 416 408 A Mar-11-02 12:47 13.8 100 129 137 170 72 1391 32 1413 0 2 1016 992 A Mar-11-0212:47 13.8 100 129 137 170 72 1391 32 1413 400 2 728 993 A Mar-12-02 18:16 14.9 100 130 137 203 70 1269 27 1950 0 2 1537 1505 A Mar-12-0218:16 14.9 100 130 137 203 70 1269 27 1950 900 2 827 1505 A ) ) 3/13/2002 2:02 PM dÙ)-O~O 0\,0)"- ,q q I~_O'D I ~-' (t7 I ¥-oQ5 l '{7--o <t1 c.J dOI~.d. ;,)5 01 /29/02 Schlombel'gel' NO. 1759 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Sepia (' CD Color Log Description Date BL 1C-121 INJECTION PROFILE 01/20/02 1 1 1 C-125 PRESSURE STATION PBMS 12/28/01 1 1 1 L-14 INJECTION PROFILE 01/22/02 1 1 1 Y -26A PRODUCTION PROFILE W/DEFT 01/20/02 1 1 1Y-32 PRODUCTION PROFILE W/DEFT 01109/02 1 1 3M-19 PRODUCTION PROFILE 01/21/02 1 1 3N-19 22030 SCMT 01112/02 1 - ---- i\ .'I.~¡-"1I :.. .-... ~!- ~!-I V ~LJ \ SIGNED~-GJ2p~ FEB 0 1 2002 DATE: Alaska Oil & Gas Cons. CommisSìm. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage 3N-19 ~4 --J'(S' Subject: 3N-19 1 Date: Tue, 15 Jan 2002 10:00:37 -0900 ~\ From: "Scott D Reynolds" <sreynoI2@ppco.com> .. . Ð To: tom_maunder@admin.state.ak.us ~\ r\\\ CC: "Paul Mazzolini" <pmazzol@ppco.com> :s:. -\-~~'L --\~ f\t.~'«0 T om- I sent the note below last week and got your vacation message. I r -- ~ - '( "\-.r wasn't sure if it got to you so here it is again. ~ ~ ~""'" ~ Scott . ~ ~~ \~~ '\ ::~~nuary 1st, 2002 we performed an open hole (low side) sidetrack of 'II 't "-1 3N-19 after reaching the orignal TD as stipulated in the APD (10,399' MD I ~ \ 6429' TVD). We did dig a bit more hole to 10,483 MD /64521 TVD to find the top of the A sands we lost when we crossed the second fault. Once we found the top of the A3 sands after the 2nd fault and developed a better understanding of the structure, we decided to open hole sidetrack the well to pick up more pay sands. The open hole sidetrack was kicked off at 9475' MD / 6472' TVD. The original wellbore was left open with no plugging back. The sidetrack hole mirrored the original holes directional work staying about 20' to 30' TVD deeper. We gained us about 600 more feet of pay. The TD of the sidetrack was 10,515' MD /6445' TVD. Since we didn't abandon the original well bore and it does contain some pay sands, I think the sidetrack wellbore becomes 3N-19L 1. I'm not sure what the new API number would be? Do I need to work up a Sundry for you or is the final "WELL COMPLETION OR RECOMPLETION REPORT AND LOG" form 407 sufficient? ( Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL (907) 275-7629 PAGER sreynoI2@ppco.com '---I ~ : ,0- t!ft''()'-'J ~II 6~ . ~./-~MA -ftL€-3 Aj- 19 c£~nf-l ~ /1-/:L 4F ~ ~ c:L /1ß.-AJ F /~í I ,<, /r,'/I z{th /I'lL- o~ Ade.- ~ ~ tùlv~, it/'Ld~ ÙJ 3¡J- 19L( /1Y)'1-{. a>on ffPI 4f '!SO-ÓZC¡.Z30S-G-/ # J,;-L -fI~"L- ~--L¿~j/þ1I' I- 2/7/02 4:27 p~ 1 of 1 ( ~V~VŒ lill~ ~~~~~~ (' ALASKA OIL Al\ID GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ""fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Scott D. Reynolds Drilling Engineer . Phillips Alaska, Inc. Po Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 3N-19 Phillips Alaska, Inc. Permit No: 201-225 Sur Loc: 1561 ' FSL, 70' FWL, SEC 28, TI3N, R9E, UM Btmhole Loc. 2834' FNL, 1442' FEL, SEC 33, TI3N, R9E, UM Dear Mr. Reynolds: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 3N-19. 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 the North Slope pager at 659-3607. Sincerely, Úm~~.~ Cammy ~chsli Taylor Chair BY ORDER OF THE COMMISSION . DATED this 28th day of November, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (. l ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 3719' FNL, 5210' FEL, SEC 28, T13N, R9E, UM At target (=Top of A3) 1733' FNL, 3120' FEL, See 33, T13N, R9E, UM At total depth feet psig At total depth (TVD) 3500 at psig 6358' TVD.SS feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured depth True Vertical depth Perforation depth: measured true vertical Drilling Team Leader "I Date z.t. / Þ I No 2M 3M 5M 10M 15M Other: Commissioner by order of the commission Date RECEIVED NOV 2 6 2001 ORIGINAL Alaska 011 & Gas Cons. Commission Anchorage 3N-19 Cement Volumes { (" Subject: 3N-19 Cement Volumes Date: Tue, 27 Nov 2001 16:52:50 -0900 From: "Scott 0 Reynolds" <sreynoI2@ppco.com> To: tom_maunder@admin.state.ak.us Tom- Per your request: 9-5/8": Lead Yield = 4.44 cU.ftlsk Lead Vol = 590 sks (2603 cu.ft) Tail Yield = 2.4 cU.ft/sk Tail Vol = 170 sks (398 cu.ft) 7" Top Set Tail Yield = 1.17cu.ft/sk Tail Vol = 110 sks (128 cu.ft) 7" Long String Tail Yield = 1.17cu.ft/sk Tail Vol = 290 sks (330 cu.ft) 5.5" Drilling Liner Tail Yield = 1 .2cu. ft/sk Tail Vol = 110 sks (125 cu.ft) Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL (907) 275-7629 PAGER sreynoI2@ppco.com 1 of 1 ' 11/28/01 8:59 AM 3N-19 Permit to Drill ( Subject: 3N-19 Permit to Drill Date: Mon, 26 Nov 2001 15:34:15 -0900 From: "Scott D Reynolds" <sreynoI2@ppco.com> To: tom_maunder@admin.state.ak.us cc: "Paul Mazzolini" <pmazzol@ppco.com> Tom- Phillips Alaska, Inc. is in the process of converting Nabors 16E from its current configuration (stacked in mobile carriages) to a Hercable mode for use during the 2001-02 exploration season. Prior to taking 16E out on the ice, we are going drill the Kuparuk Infill Producer 3N-19 to test the rigs operation in Herc mode. The process of tearing the rig down and rigging it up in the Hercable mode was estimated to take 30 days starting from November 12th. I submitted the Permit to Drill for 3N-19 on Wednesday, November 21 st believing that would give the AOGCC 3 weeks to approve the permit; however, Nabors has been rather efficient in getting the rig ready to spud in a mere 15 days, The quick rig conversion is great; unfortunately, it moves the spud date up 15 days to December 1 st. Rather then the December 15th spud date I wrote on the Permit to Drill. Would it be possible to have the Permit to Drill for 3N-19 approved by Friday, November 30th? If you have any questions, give me a call. Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL (907) 275-7629 PAGER sreynoI2@ppco.com 1 of 1 ( 11/27/01 8:50 AM .' ( ( ation for Permit to Drill, Well 3N-19 Saved: 26-Nov-01 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 2S.040(b). For a well with multiple well branches/ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the weN by the commission. The well for which this application is submitted will be designated as 3N-19. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface/ at the top of each objective formation and at total depf.i'7/ referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface/ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration/ (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Sulface NGS Coordinates Northings: 6,013,799.0 Eastings: 518,471.2 13719' FNL, 5210' FEL, SEC 28, T13N, R9E, UM I RKB Elevation I I Pad Elevation I 61.9' AMSL 32.9' AMSL Location at Top of Productive Interval Ku aruk "A3" Sand NGS Coordinates Northings: 6,010,472 1733' FNL, 312O' FEL, Sec 33, T13N, R9E, UM Eastings: 520,578 8 399' 6 389' 6 328' Location at Total De th NGS Coordinates Northings: 6,009,415 Eastings: 522,261 1° 399' 6 429' 6 368' and (0) otl1er inlormation required by 20 AAC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviateft the application for a Permit to 0(1/1 (Form 10-401) must (1) include a plat drawn to a suitable scale/ showing the path of the proposed wellbore/ including all adjacent wellbores Vldthin 2,00' feet of any portion of the proposed wel¿- Please see Attachment 1: Directional Plan and (2) for all wells within 200 leet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records;. and !;;170W that each named operator has been furnished a copy of the application by certified mail/ or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file witl7 tl'7l:' commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25. 03~ 20 AAC 25. ,036, or 20 AAC 25.037, as applicable/ Please reference BOP schematics on file for Nabors 16E. 3N-19 PERM/T IT. DOC Page20f 8 Printed: 26-Nov-01 ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-1336 Email: Dmazzol@DDco.com November 21,2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill 3N-19 Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a permit to drill an onshore production well from the Kuparuk 3N drilling pad. The intended spud date for this well is December 15, 2001. It is intended that Nabors Rig 16E be used to drill the well. The 3N-19 well will target the Kuparuk A Sands with a horizontal production hole. The horizontal production. hole will cross two sealing faults to gain access to isolated reserves in two separate fault blocks. The production hole will be completed with a slotted liner. Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Paul Mazzolini at 263-4603. ~- Scott D. Reynolds Drilling Engineer RECEIVED NOV 2 1 2001 cc: 3N-19 Well File / Sharon Allsup Drake Paul Mazzolini Guy Schwartz AIalkaOiI & Gas Cons. commission Anchorage ATO 1530 ATO 1570 ATO 1280 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ð1V'rt ~, lPllol oj;: \/ if~ ...- ~ ~p- ( ,~', (I 1a. Type of Work Drill X Redrill I 1b Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. KB61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Pool P. O. Box 100360, AnchoraQe, AK 99510-0360 ADL 25520 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) /5f>11' ~ 70' rWL ~ , 1.ã6O~J;St:" SEC 28, T13N, R9E, UM Kuparuk River Unit Statewide At target (= Top of A3) 8. Well number Number f3() g;¡/ ~) FNL, 3120' FEL, See 33, T13N, R9E, UM 3N-19 #U- Ai) At total depth. I ~ 9. Approximate spud date Amount" /4 2. 6a.. 2834' FNL ~~, SE$ 3, T13N, R9E, UM 1~-'!O"M \"1 ~t)- c \ $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in propertyt::b-tJ'.1f1 15. Proposed depth (MD and TVD) Property line 3N-13 10399' MD N/A feet 122' @ 8316' MD Feet 2560 6429' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 MC 25.035(e)(2» Kickoff depth 393' feet Maximum hole angle 95.020 Maximum surface 2811 psig Allotal depth (TVD) 3500 at psig 6358' TVD.SS 18. Casing program SettinQ Depth size Specifications Top Bottom Quantity of cement Hole Casina Weiaht Grade Couplina Lenath MD TVD MD TVD (include staae datal 42" 16" 62.5# H-40 Weld 118' 28' 28' 1461 1461 345 sx 15.8 PPQ AS1 12.25" 9.625" 40# L-80 BTC 3618' 28' 28' 3646' 3622' 560 Sx AS Lite & 194 Sx LiteCRETE 8.5" 7" 26# L-80 BTC-M 8010' 26' 26' 8036' 6258' 110 sx Class G 126 sx 15.8 ppg GASBLOK 7" 5.5" 15.5# L-80 Hvrill511 1243' 7800' 6150' 9043' 6474' wI add. N/A 3.5" 9.3# L-80 EUE 8rd 10376' 23' 23' 10399' 6429' N/A 19. To be completed for Red rill , 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 RECEIVED Conductor Surface Intermediate Production Liner NOV 2 1 2001 Perforation depth: measured true vertical Alaska 011 & Gas Cons. Commi88ion 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch ' .........ing program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I here~ifY that the foregoing is true and correct to the best of my knowledge 1~ýJ1~ Drilling Team Leader Date '121/01 Siç¡ned Paul Mazzolini Title Commission Use Only Permit Number, /.- 22 ç API ~~- 2 -? 0 (" (, ~ I Approval date \ \ \::J-~ IC) See cover letter for 2-0. - 50- ..J" ..J.- ì Other requirements Conditions of approval Samples required Yes ~i Mud log required Yes e:> Hydrogen sulfide measures 8 No Directional survey reqUired@ No Required working pressure for BOPE 2M 3M 5M 10M 15M Other: ~SOO ~«:>\ """""'\ ""'~~ ~\( ~">~ '~ By by order of , t \:d--X /DI Approved by ,,_1: Commissioner the commission Date Form 10-401 Rev. 7-24.89 ,';aJU Submit in tfiplicate OR\GiNAl (' APf~. +ion for Permit to Drill, We1l3N-19 " ~ Saved: 21-Nov-01 Permit It - Kuparuk Well 3N-19 Application for Permit to Drill Document Table of Contents 1. Well Name................................................................... ..............................................,............................................................... 2 Requirements of 20 AAC 25.005 (f) ........ ...,.. ..................,. .... ....... ...................... .... .............. ..,................... .................................2 2. Location Summary..................................................................................................................................................... ..............2 Requirements of 20 AAC 25. 005(c)(2)............................................................................................................................... .........2 Requirements of 20 AAC 25.050(b)............................................................. ............................................................................... 2 3. Blowout Prevention Equipment Information.................................................................................................. ........................2 Requirements of 20 AAC 25.005(c)(3).... ................ ...... ........ ........ ........,........... ...... ............................ ..... .............., ............ ........2 4. Drllll ng Hazards Information...................................................................... .............................................................................. 3 Requirements of 20 AAC 25.005 (c)(4)................... ...... .... .... ........ .................. ....... ........................... ......... ...... ............ ...............3 5. Procedure for Cond uctl ng Formation Integrity Tests............................................................................................................ 4 Requirements of 20 AAC 25.005 (c)(5)..... .............. ...." ....... ",,,,,, ................. ..... ......................................................... ................ 4 6. Casi ng and Cementi ng Program............................................................................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) .... ..., ....... ...,. ............ ....... .............. ...... ......... ..................... ........... ...........................,..... ... 4 7. Dlverter System Information...................................... ............................................... ...............................................................4 Requirements of 20 AAC 25.005(c)(7) .......,.. .... ....,. ...... ..... """""'" ......,...... ... ............, .................................... ....... "'" """"""'" 4 8. DrllU n g FI u id Program................................................................................................................................................ ..............5 Requirements of 20 AAC 25.005(c)(8)...... ............,. ..... """""'" ........... .,....... """"" ...................................... ......... ...........,.... ..... 5 9. Ab normally Pressured Formation Information....................................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(9).. ................. ..... .......... ..... ............ ................ ..............."..... ............. ............................ ..... 5 1 O. Selsm ic Anal ysis ............................................................................................................................. .........................................5 Requirements of 20 AAC 25.005 (c)(10)....... .......... ...................... .........,..... ...., ........... .............. ......................... ..............,......... 5 11 . Seabed Condition Anal ysis...................................................................................... ................................................................5 Requirements of 20 MC 25.005 (c)(11)....... ................ ...".... ............. ............... .........,.. ........... ................. ................. ........... ..... 5 12. Evidence of Bonding................................................................................................... ............................................................. 5 Requirements of 20 MC 25.005 (c)(12)......... ....... ..........,... ......... ""'"'''''''' ..... ......... ........ ........ .......................... .."........ ........." 5 13. Proposed Drill! n9 Program...................................................................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13). """,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ..... ..."..... ...... ........."........... ......... .........., .................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ........................................................................................8 Requirements of 20 AAC 25.005 (c)(14)........ ..................., ...... ...... ...... ....... ............ ..................... .............. "'''''''''' ..................... 8 15. Attachments................................................................................................................ ............................................................. 8 Attachment 1 Directional Plan ..... ............. ... .......... ...... ...,. ... .......... ...... """'" ............ "'''' ......,... ........ .... ......, .... ..... .............. .......8 Attachment 2 Drilling Hazards Summary..... ........,. ...... ...".... .............. ........ ........... .............. ......... .......... ....". ......... .......... ......... 8 Attachment 3 7" Top Set Well Schematic..... ........" ........... .........,........ ....... "'''''''''''''''''''''''''''''''''''' ""'''''''''''''''''''''''''' ............ 8 Attachment 4 7" Long String Well Schematic.. .................... ......... ........." ..... ............. ................ .......................... ............... ........ 8 3N-19 PERM/T IT. DOC Page 1 of 8 Printed: 21-Nov-0 1 .. ( APPI1- 'In for Permit to Drill, Well 3N-19 '- Saved: 21-Nov-01 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and AlY number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3N-19. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dnll must be accompanied by each of the following items, except for an Item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total deptt¡, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Swvey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; /(;b/ &. '7t/ FtlJL 1U' cÆ 'On 3719' FNL,. , SEC 28, T13N, R9E, UM RKB Elevation Pad Elevation Location at Suñace NGS Coordinates Northings: 6,013,799.0 Eastings: 518,471.2 Location at Top of Productive Interval Ku aruk "A3" Sand NGS Coordinates Northings: 6,010,472 1733' FNL, 3120' FEL, Sec 33, T13N, R9E, UM Eastings: 520,578 Location at Total De th NGS Coordinates Northings: 6,009,415 Eastings: 522,261 61.9' AMSL 32.9' AMSL 8 399' 6 389' 6 328' 10 399' 6 429' 6 368' anc/ (D) other infofl77ation required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent well bores withln 20'0 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records;. and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on tìle with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 MC 25. 035, 20 AAC 25.1136,. or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nabors 16E. 3N-19 PERMIT /T. DOC Page2of8 Printed: 21-Nov-01 (' Ap~ +ion for Permit to Drill, We1l3N-19 ~ Saved: 21-Nov-01 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountere4 criteria used to determine it, and maximum potential surfaæ pressure based on a methane gradient,' The 3N-19 wellbore will penetrate 3 fault blocks in the Kuparuk A-Sands. The first fault block has the potential of being over pressured do to injection support in the first fault block. The horizontal wellbore will cross a fault into the 2nd fault block, which is normally pressured. The wellbore will then cross a second fault into the 3rd fault block, which is normally pressured. To mitigate the potential for lost circulation and differential sticking, a string a casing will be set in the shale of the Kuparuk A 1 prior to crossing the first fault. This should isolate the higher-pressure fault block #1 from the normally pressured fault blocks #2 & #3. The injection support for the first fault block was stopped and the well flowed back for 2 months. Current flowback rates suggest the first fault block is now normally pressured. Although the first fault block is close to normal reservoir pressure of 3000 psi, the estimated reservoir pressure of 3500 psi (prior to flowing back the injector for the first fault block) will be used in the pressure calculations for the first fault block. Pressure calculations for the second and third fault blocks will be based on a reservoir pressure of 3000 psi. Fault Block #1: (7" or 5-1/2" casing set in the Kuparuk A 1 Shale prior to crossing fault #1.) Based on offset well data, the expected reservoir pressure in the Kuparuk sand for the 3N-19 well is ....3500 psi at 6419' TVD-RKB, 0.55 psi/ft or 10.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 3N-19 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the Kuparuk A3 sand target at 6389' TVD-RKB: MPSP =(6389 ft)*(0.55 - 0.11 psi/ft) = 2811 psi Fault Blocks #2 & #3: The expected reservoir pressure in the Kuparuk sand for the 3N-19 well is ....3000 psi at 6498' TVD-RKB, 0.462 psi/ft or 8.9 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 3N-19 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the Kuparuk A3 sand target at 6482' TVD-RKB: MPSP =(6482 ft)*(0.462 - 0.11 psi/ft) = 2281 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data conceming potential causes of hole problems such as abnormally geo-pressured strata/ lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 3N-19 PERMIT IT. DOC Page 30fB Printed: 21-Nov-01 ( ApPj: -~tion for Permit to Drill, Well 3N-19 -1 Saved: 21-Nov-01 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: Surface InteNal S ud Mud 9.4-9.6 60-250* 20-70 20-60 10-30 6-15 9.5-10 +10 Intermediate Interval LSND 9.0-11 40-55 8-25 5-25 3-10 5-15 9.5-10 < 60/0 *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Nabors 16E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata a's required by 20 AAC 25.033(f); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (1~) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25. 061 (a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dnlling vessel" an analysis of seabed condItions as required by 20 MC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with tJ'ie commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 3N-19 PERMIT IT. DOC Page 5 of 8 Printed: 21-Nov-O 1 (' APPI'---tion for Permit to Drill, Well 3N-19 -' Saved: 21-Nov-01 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the cornmission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Drill out surface and intermediate casing shoe and perform LOT test or FIT (maximum of 13 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.03~ and a description of any slottetf liner, pre-' perforated liner, or screen to be installed; Casing and Cementing Program I Hole Top 8tm CsglTbg Size Weight Length MDITVD MDITVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 118' 28'/28' 146'/146' 345 sx 15.8 ppg ASl 9-5/8 12-1/4 36.0 J-55 BTC 3618' 28'/28' 3646'/3622' Lead: 560 sx 10.7 ppg AS Lite Tail: 194 sx 12.0 ppg LiteCRETE Planned TOC=Surface 7 8-1/2 26.0 L-80 BTC 8010' 26'/26' 8036/6258' 110 sx 15.8 ppg 'G' w/ add. Planned TOC= 7536' 5-1/2 6-1/8 15.5 L-80 Hydrill511 1243' 7800' / 9043'/6474' 126 sx 15.8 ppg 6150' GASBLOK w/ add. Planned TOC= 7800' 3-1/2 4-3/4 9.3 L-80 EUE 8rd 10376' 23'/23' 10,399'/6429' N/A Mod 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Nabors 16E. 3N-19 PERMIT IT. DOC Page 4 of 8 Printed: 21-Nov-01 ( Ap¡:f +ion for Permit to Drill, We1l3N-19 ~ Saved: 21-Nov-01 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 146' RKB (118' from pad elevation). Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E in Herc Mode. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (:f: 3646' MD' / :f: 3622' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 36.0# L -80 BTC casing to surface using lightweight permafrost cement lead slurry and LiteCRETE tail slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if needed. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. PU Drilling BHA and RIH. Clean out cement to float collar. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results on circular chart and PAl CIT/FIT form. 7. Drill out cement and 20' (minimum) of new hole. Perform formation integrity test not to exceed 13.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to (:f:8036' MD / ::1:6257' TVD) according to directional plan. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Perform Open Hole Leak Off Test. 9.1. If LOT is less then 12.5 ppg, follow steps 10 thru 31. 9.2. If LOT is greater then or equal to 12.5 ppg, follow steps 32 thru 46. 7Y' TOD Set Scenario 10. Run 7" 26.0# L-80 BTCM casing and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Conduct a LOT down the 9-5/8" x 7" casing annulus. Freeze protect the casing annulus to 2000' TVD - use 300 bbls fresh water flush prior to freeze protecting. Fill out a s~parate dailv annular in1ection sheet for this operation and turn into Company Man. 13. PU 4-3/4" Drilling BHA/6.125" milled tooth bit & NBR600 "Near Bit Reamer", l1H. Clean out cement to float collar. 14. Shut in BOP's and pressure test casing to 2500 Dsi for 30 minutes per AOGCC regulations. Record results. Record results on circular chart and PAl CIT/FIT form. 15. Drill out cement and 20' (minimum) of new hole. Perform formation integrity test not to exceed 12.5 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030(0.5 ppg less than the FIT or LOT EMW). 3N-19 PERMIT IT. DOC Page 6 of 8 Printed: 21-Nov-01 ( Appl -'Qn for Permit to Drill, Well 3N-19 " Saved: 21-Nov-01 16. If FIT is good and no remedial shoe work is needed, shear pins in NBR to start opening hole to 7". 17. Drill 6-1/8" to 7" hole to the 5-1/2" casing point @ (:1:9043' MD I :I: 6473' TVD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 18. Run and cement 5-1/2" 15.5# L-80 Hydrill 511 liner and Baker ZXP hanger. Set packer :I: 250' above intermediate casing shoe to provide appropriate liner lap. Clean up hanger area and POOH. 19. Nipple up BOPE and test to 5000 Dsi. Record results. 20. RU SWS and RUN CBL from liner shoe back to the top of the liner. POOH and RD SWS. 21. PU 3-5/8" Drilling BHA; 4.75" PDC bit; Tapered Drill String (:1:2880' of 2-7/8" DP w/AOH connection; 3 joints of 3-1/2 DP w/3-1/2 IF connection; and 4" HT38 DP to surface), TIH. Clean out cement to float collar. 22. Shut in BOP's and pressure test casing to 2500 Dsi for 30 minutes per AOGCC regulations. Record results. Record results on circular chart and PAl CrTlFIT form. 23. Drill out cement and 20' (minimum) of new hole. Perform formation integrity test not to exceed 11.5 ppg EMW. This establishes a minimum FIT required to drill ahead. If formation leaks off prior to achieving a 11.5 ppg FIT, contact the operations drilling engineer or drilling team leader for instructions on how to proceed. 24. Drill 4-3/41' horizontal hole to well TD @ (::1:10,399' MD I ::I: 6429' TVD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH. 25. PU & run 3-1/2" 9.3# Slotted Liner w/BTM Special Clearance Coupling; MU running tool to 2-1/16" hydrill CS inner wash string run in slotted liner. Run completion in hole with DP to TD @ (:1:10399' MD I :I: 6429' TVD). Set ZXP packer :1:100' MD above the 5-1/2" casing shoe. 26. Circulate horizontal annulus to 9.3 ppg brine. Drop ball; set packer and release running tool. Circulate inside of 3-1/2" slotted liner to 9.3 ppg brine. POOH with setting tool and 2-7/8" wash string. 27. PU and run 3-1/2" EUE 8rd tubing and single selective jewelry per completion plan. Run same in hole until seal assembly lands in PBR. Set FAB-l packer. Release and POOH. 28. PU and run 3-1/2" EUE 8rd tubing and GLM's. until seals seat in seal bore assembly. Space out and land tubing hanger. 29. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 30. Freeze protect well. Set BPV. Release rig and turn well over to production. 31. Clean location and RDMO. 7" Long String Scenario 32. Continue to drill 8-1/2" hole to 7" casing point (5-1/2" casing point in directional plan) @ (:1:9043' MD I :I: 6473' TVD). Circulate and condition hole. POOH. 33. Run 7" 26.0# L-80 BTCM casing and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 34. Nipple up BOPE and test to 5000 Dsi. Record results. 35. RU SWS and RUN CBL from liner shoe back to the top of the liner. POOH and RD SWS. 36. Conduct a LOT down the 9-5/8" x 7" casing annulus. Freeze protect the casing annulus to 2000' TVD - use 300 bbls fresh water flush prior to freeze protecting. Fill out a separate dailv annular in1ection sheet for this operation and turn into ComDanv Man. 37. PU 4-3/4" Drilling BHA/6.125" PDC bit, TIH. Clean out cement to float collar. 3N-19 PERMIT IT. DOC Page 7ot8 Printed: 21-Nov-01 ( Apijt tion for Permit to Drill, We1l3N-19 , Saved: 21-Nov-01 38. Shut in BOP's and pressure test casing to 2500 Dsi for 30 minutes per AOGCC regulations. Record results. Record results on circular chart and PAl CIT/FIT form. 39. Drill out cement and 20' (minimum) of new hole. Perform formation integrity test not to exceed 12.5 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 MC 25.030(0.5 ppg less than the FIT or LOT EMW). 40. Drill 6-1/8" horizontal hole to well TD @ (f:10,399' MD / :i: 6429' 1VD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 41. PU & run 3-1/2" 9.3# Slotted Liner w/BTM Special Clearance Coupling; MU running tool to 2-1/16" hydrill CS inner wash string run in slotted liner. Run completion in hole with DP to TD @ (:i:10,399' MD / :i: 6429' TVD). Set ZXP packer :i:100' MD above the 5-1/2" casing shoe. 42. Circulate horizontal annulus to 9.3 ppg brine. Drop ball; set packer and release running tool. Circulate inside of 3-1/2" slotted liner to 9.3 ppg brine. POOH with setting tool and 2-7/8" wash string. 43. PU and run 3-1/2" EUE 8rd tubing and single selective jewelry per completion plan. Run same in hole until seal assembly lands in SBE of ZXP liner hanger. Set FAB-1 packer. Release and POOH. 44. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 45. Freeze protect well. Set BPV. Release rig and turn well over to production. 46. Clean location and RDMO. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on t7/e with N7e commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether tlle operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be hauled to a KRU Class II disposal well. All cuttings will be processed in the 16E Ball Mill. The cuttings slurry will be hauled to a KRU Class II disposal well. At the end of drilling operations, an application may be submitted to permit 3N-19 for annular pumping (per regulation 20 MC 25.080) of fluids occurring as a result of future drilling operations on 3N pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 7" Top Set Well Schematic Attachment 4 7" Long String Well Schematic 3N-19 PERMIT IT. DOC Page 8 of 8 Printed: 21-Nov-01 Target Name Target TVDRTNorthings Eastings Shape TI Point 6389.00 3N-19T2 Point 6442.00 34J6.ÎJ Current Weil Properties Plan: 3N-19 Coordinates . RKB Elevation' North Reference: Units: Data for Pian: 31\1-19 TVDSS ASP4 Y 6328.00 60iO472.00 520578.00 ASP4 X A Halliburton Company 1'- 06' -2000 ü5¡ LLI 0' CD !!) ~ (/) a :ê t -3000 0 Z: 638100 6010368.00 N 520786.00 E 518471.20 E E N, 149" 50' 57.5195' W Sea Level ð 0 0 -4000 ';; .!: '" .S (¡j ø '" (j) 0 Scale: 1 inch 10ooft tOOO 2000 Eastings (1560' FSL & 71' FWL) 3000 Reference is True N0I1h Kuparuk 3N 9 Proposal Data for 31\1-19 (wpO3) MSL FWL 1OO feet (US) ° 0.00 N,O.OO E Vertical Depth Northings Eastings Vertical Section ILOIl '93.iIiI 11.00 IUIO N 7X S S 222.7X S S S 2926.lIk S S S -,436.gB S S S 367i1.14 S S S 4.393.52 S iI.OII L IUIO L L 11.'" L I L 16 L 1655.22 L 2i192.57 L 2i19S.95 "- I 1-. 2645.27 "- 2694.S9 L 14. L L 3779.17 L ¡UiO (I.liO Ii 000 00011 0 (1i){1 hO.O.'" 0 OOil L500 0000 , OliO ¡IUOO 242.91 liS J.cII 3297.69 000 ,,¡UOel 1167 H, 116.710 1 6115.YJ Ó3S6.ïS 6';S9.1I1I 41119.Îk -12S 1.66 44H45 4539./k 5795.40 ,000 A Ha¡¡¡burton Company Œ 000 @J 'D (ïJ ClJ (J) ::.:: 0: L 13. 000 ClJ 0 ro u "¡::; ill > 000 000 9043.0ft MO 6473.5ft NO 52 0 31/2" Uner 1 0399.3ft MO 6429.0f! NO II .!: '" ç ói TI U) 0 1000 :2000 3000 4000 5000 6000 2.00.09.006 , I{ûparuk River Unit . .Nt)rthS/öpe, Alaska . .,.KufJâruk 3N, Slot 3N-19 Plan: 3N-19 - 3N-19 (wp03) Revised: 20 November, 2001 PROPOSAL REPORT 20 November, 2001 ( Your Ref: Based on Prelim Plan Ver. #3.3 Surface Coordinates: 6013799.00 N, 518471.20 E (70026' 55.9422H N, 1490 SO' 57.5195" W) Surface Coordinates relative to Project H Reference: 1013799.00 N, 18471.20 E (Grid) Surface Coordinates relative to Structure: 1.47 S, 525.01 E (True) Kelly Bushing: 61.00ft above Mean Sea Level 5pE!I'''''''V-5U~. DRILLI~~§A.YIc:e!;! A Halliburton Company Proposal Ref: pr09695 Sperry-Sun Drilling Services . Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inc I. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Com ment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 0.00 0.000 0.000 -61.00 0.00 O.OON 0.00 E 6013799.00 N 518471 .20 E 0.00 SHL: X = 518470.80' E & Y = 6013799.15' N (1561' FSL & 70' FWL See 28-T131 N-R9E) 100.00 0.000 0.000 39.00 100.00 6013799.00 N 518471.20 E 0.000 0.00 { 200.00 0.000 0.000 139.00 200.00 6013799.00 N 518471.20 E 0.000 0.00 300.00 0.000 0.000 239.00 300.00 6013799.00 N 518471.20 E 0.000 0.00 393.00 0.000 0.000 332.00 393.00 6013799.00 N 518471.20 E 0.000 0.00 Begin Dir @ 2.0000/100ft : 393.00ft MD, 393.00ft TVD 400.00 0.140 153.000 339.00 400.00 O.OOE 6013798.99 N 518471.20 E 2.000 0.01 500.00 2.140 153.000 438.98 4g!:Ml8 ",. 0.91 E 6013797.22 N 518472.11 E 2.000 1.94 600.00 4.140 153.000 538.82 $Ø9:82 3.39 E 6013792.35 N 518474.61 E 2.000 7.26 700.00 6.140 153.000 638.41 . 699i41,' 7.46 E 6013784.38 N 518478.70 E 2.000 15.97 800.00 8.140 153.000 737.6$ '.. 79ði63 13.10 E 6013773.32 N 518484.37 E 2.000 28.04 900.00 10.140 153.000 836.36'",' ". '897:.36 39.87 S 20.31 E 6013759.18 N 518491.61 E 2.000 43.47 993.00 12.000 153.000 927.62.:.'," 988.62 55.78 S 28.42 E 6013743.29 N 518499.76 E 2.000 60.82 End Dir, Start Sail @ 12.000° : 993.00ftMD ,988.62ftTVD 1000.00 12.000 153.000 934.47 995.47 57.08 S 29.08 E 6013742.00 N 518500.42 E 0.000 62.23 1100.00 12.000 153.000 1032.28 1093.28 75.60 S 38.52 E 6013723.49 N 518509.91 E 0.000 82.43 1200.00 12.000 153.000 1130.10 1191 .10 94.13 S 47.96 E 6013704.99 N 518519.39 E 0.000 102.63 1300.00 12.000 153.000 1227.91 1288.91 112.65 S 57.40 E 6013686.49 N 518528.88 E 0.000 122.83 1400.00 12.000 153.000 1325.73 1386.73 131.18 S 66.84 E 6013667.99 N 518538.36 E 0.000 143.03 1493.00 12.000 153.000 1416.70 1477.70 148.40 S 75.62 E 6013650.78 N 518547.18 E 0.000 161.82 Begin Dir @ 1.500°/1000 : 149(' " MD, 1477.70ft TVD ' 1500.00 11 .895 153.000 1423.55 1484.55 149.70 S 76.27 E 6013649.49 N 518547.84 E 1.500 163.23 1600.00 10.395 153.000 1521.66 1582.66 166.92 S 85.05 E 6013632.29 N 518556.66 E 1.500 182.00 1700.00 8.895 153.000 1620.24 1681.24 181.85 S 92.65 E 6013617.38 N 518564.31 E 1.500 198.28 1730.10 8.443 153.000 1650.00 1711.00 185.89 S 94.71 E 6013613.35 N 518566.38 E 1.500 202.69 Base Permafrost 1800.00 7.395 153.000 1719.23 1780.23 194.47 S 99.09 E 6013604.78N 518570.77 E 1.500 212.05 1900.00 5.895 153.000 1818.55 1879.55 204.78 S 104.34 E 6013594.48 N 518576.05 E 1.500 223.29 2000.00 4.395 153.000 1918.15 1979.15 212.77 S 108.41 E 6013586.50 N 518580.14 E 1.500 232.00 20 November, 2001 - 14:59 Page 2 of 10 Dfl1/Quest 2.00.09.006 Kuparuk River Unit Measured Depth (ft) 2100.00 2200.00 2293.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3127.64 3200.00 3239.14 Incl. Azim. 2.895 153.000 1.395 153.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3300.00 1.826 150.304 3400.00 4.826 150.304 3500.00 7.826 150.304 3544.44 9.159 150.304 3600.00 10.826 150.304 3646.21 12.212 150.304 3700.00 13.826 150.304 3800.00 16.826 150.304 3900.00 19.826 150.304 4000.00 22.826 150.304 Sub-Sea Depth (ft) 2017.94 2117.87 2210.86 2217.86 2317.86 2417.86 2517.86 2617.86 2717.86 2817.86 Vertical Depth (ft) 2078.94 2178.87 2271.86 2278.86 2378.86 2478.86 2578.86 2678.86 27Za~Q6 , 2818:86 2917.86;:", ': ',29i8i~ 3017.aå:" 'i':'9ø78~B6 3045.50 ,', ,', ,,' á1~.5Ó 3117.86<::L 3178.86 3157.00 3218.00 3217.85 3317.67 3417.05 3461.00 3515.72 3561.00 3613.40 3709,.83 3804.75 3897.89 3278.85 3378.67 3478.05 3522.00 3576.72 3622.00 3674.40 3770.83 3865.15 3958.89 Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan VeT. #3.3 Revised: 20 November, 2001 Local Coordinates Northings Eastings (ft) (ft) 218.43 S 221.77 S 222.78 5 222.78 S 222.78 5 222~7a 5 , 222.78$ , 222.781:5, ",' 222.785 ' , , 222.78 S 222.78 5 222.78 S 222.78 S 222.785 222.78 S 223.62 5 228.66 S 238.23 S 243.935 252.30 5 260.32 S 270.84 S 293.80 S 321.11 S 352.70 S 111.30 E 113.00 E 113.51 E 113.5t,E 113.51 E 11a.51E 113.51 E 113.51 E 113.51 E 113.51 E 113.51 E 113.51 E 113.51 E 113.51 E 113.51 E 113.99 E 116.86 E 122.32 E 125.51 E 130.35 E 134.92 E 140.92 E 154.02 E 169.59 E 187.61 E Global Coordinates Northings Eastings (ft) (ft) 6013580.84 N 6013577.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013576.51 N 6013575.66 N 6013570.63 N 6013561.08 N 6013555.38 N 6013547.02 N 6013539.02 N 6013528.51 N 6013505.58 N 6013478.31 N 6013446.77 N 518583.04 E 518584.75 E 518585.26 E 518585.26 E 518585.26 E 518585.26 E 518585.26 E 51858526 E 518585.26 E 518585.26 E 51858526 E 518585.26 E 518585.26 E 51858526 E 518585.26 E 518585.74 E 518588.63 E 518594,.11 E 518597.38 E 518602.17 E 518606.77 E 518612.79 E 518625.94 E 518641.59 E 518659.68 E . North Slope, Alaska Kuparuk 3N Dogleg Vertical Rate Section (°/1000) 1.500 1.500 1.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 Comment 238.18 241.81 242.91 End Dir, Start Sail @ 0.000° : 2293.00ftMD,2271.86ftTVD , 242.91 242.91 242.91 242.91 242.91 242.91 242.91 242.91 242.91 242.91 Top West Sak 242.91 242.91 Begin Dir @ 3.0000/lOOft: 3239.14ft MD, 3218.000 TVD 243.86 249.56 260.37 266.81 Base West Sa!< 27628 285.34 9-518" Csg Pt... Drill out 8-1/2" ~e 9-5/8" Casing 297.23 323.17 354.03 389.73 20 November, 2001- 14:59 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (It) e/10Oft) 4100.00 25.826 150.304 3989.01 4050.01 388.48 S 208.01 E 6013411.04.N 518680.17 E 3.000 430.16 4200.00 28.826 150.304 4077.84 4138.84 428.35 S 230.75 E 6013371.23 N 518703.01 E 3.000 475.21 4300.00 31.826 150.304 4164.14 4225.14 472.20 5 255.76 E 6013327A3N 518728.13 E 3.000 524.77 4400.00 34.826 150.304 4247.69 4308.69 519.925 282.97 E 6013279.78 N 518755.46 E 3.000 578.69 \, 4500.00 37.826 150.304 4328.25 4389.25 571 .37 5 312.32E 6013228.40 N 518784.93 E 3.000 636.83 4600.00 40.826 150.304 4405.59 4466.59 626.425 343.71. E 6013173.44 N 518816.46 E 3.000 699.03 4700.00 43.826 150.304 4479.52 4540.52 684~90 8 3n.06E 6013115.04 N 518849.96 E 3.000 765.12 4800.00 46.826 150.304 4549.82 4610.82 746.6'('S 41229 E 6013053.36 N 518885.34 E 3.000 834~92 4900.00 49.826 150.304 4616.30 4677.30 8~1.54S 44929E 6012988.57 N 518922.50 E 3.000 908.23 5000.00 52.826 150.304 4678.78 47~~~,,". " :819.35 8' 487~96 E 6012920.86 N 518961.34 E 3.000 984.86 5100.00 55.826 150.304 4737.0~ ,; 41~~~". . '949.91 S 528.20 E 6012850.40 N 519001.75 E 3.000 1064.59 5200.00 58.826 150.304 4791.07 ,4852:'07 1023.02 8 569.89 E 6012777.39 N 519043.63 E 3.000 1147.20 5240.47 6O~040 150.304 4811.65' :1~72.ijß-, 1053.29 S 587.16 E 6012747.17 N 519060.96 E 3.000 1181.41 End Ok, 8tart Sail @ 60.040°: 5240.47ftMD,4872.65ftTVD 5300.00 ro.04O 150.304 4841.38 4902.38 1098.09 5 612.71 E 6012702.43 N 519086.63 E 0.000 1232.04 5400.00 60.040 150.304 4891.32 . 4952.32 1173.358 655.63 E 6012627.28 N 519129.73 E 0.000 1317.08 5500.00 60.040 150.304 4941.26 5002.26 1248.61 S 698.55 E 6012552.13 N 519172.84 E 0.000 140201 2 5600.00 60.040 150.304 4991.20 5052.20 1323.87 8 741.47 E 6012476.97 N 519215.95 E 0.000 1481.17 5700.00 60.040 150.304 5041.14 5102.14 1399.138 784.39 E 6012401.82 N 519259.05 E 0.000 1572.21 5800.00 60.040 150.304 5091.08 5152.08 1474.398 827.31 E 6012326.67 N 519302.16 E 0.000 1657.25 5900.00 60.040 150.304 5141.02 5202.02 1549.64 8 870.23 E 6012251.52 N 51934527 E 0.000 1742..30 6000.00 6O~040 150.304 5190.96 5251.96 1624.90 8 913.15 E 6012176.37 N 519388.37 E 0.000 1827.34 \ 6100.00 60.040 150.304 5240.90 5301.90 1700.168 956;07 E 6012101 .21 N 519431.48 E 0.000 1912.39 6200.00 60.040 150.304 5290.84 5351.84 1775.42 S 998.99 E 6012026.06 N 519474.59 E 0.000 1997.43 6300.00 60.040 150.304 5340.78 5401.78 1850.68 8 1041 ~91 E 6011950.91 N 519517.70 E 0.000 2082.47 6400.00 60.040 150.304 5390.72 5451.72 1925.94 S 1084.83 E 6011875.76 N 519560.80 E 0.000 2167.52 6500.00 60.040 150.304 5440.66 5501.66 2001.20 S 1127.15 E 6011800.61 N 519603.91 E 0.000 2252.56 6600.00 60..040 150.304 5490.60 55.51.60 2076.45 S 1170.67 E 6011725.45 N 519647.02 E 0.000 2337.60 6700.00 60.040 150.304 5540.54 5601.54 2151.71 8 1213.59 E 6011650.30 N 519690.12 E 0.000 2422.65 6800.00 60.040 150.304 5590.48 5651.48 2226.97 S 1256.51 E 6011575.15 N 51973323 E 0.000 2507.69 6900.00 60.040 150.304 5640.42 5701.42 2302.23 8 1299.43 E 6011500.00 N 519776.34 E 0.000 2592.73 20 November, 2001- 14:59 Page 4 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/10Oft) 7000.00 60.040 150.304 5690.36 5751.36 2377.49 S 1342.35 E 6011424.85N 519819.44 E 0.000 2677.78 7100.00 60.040 150.304 5740.30 5801.30 2452.75 S 1385.28 E 6011349;69 N 519862.55 E 0.000 2762.82 7200.00 60.040 150.304 5790.24 5851.24 2528.01 S 1428.20 E 6011274.54N 519905.66 E 0.000 2847.87 7300.00 60.040 150.304 5840.18 5901.18 2603.26 S 147~_12 E 6011199.39 N 519948.76 E 0.000 2932.91 { 7400.00 60.040 150.304 5890.12 5951.12 2678.52 S 1514~04 E 6011124.24 N 519991.87 E 0.000 3017.95 7419.79 60.040 150.304 5900.00 5961.00 269~A2S t.522.53¡:: 6011109.36 N 520000.40 E 0.000 3034.79 Upper Kalubik 7500.00 60~O40 150.304 5940.06 6001.06 2753~78 S 1556~96E 6011049.09 N 520034.98 E 0.000 3103.00 7600.00 60.040 150.304 5989.99 6050.99 2829.040$. 1599.88 E 6010973.93 N 520078.08 E 0.000 3188.04 7700.00 60;040 150.304 6039.93 6100.93 29Ø4.30S 1i642.80 E 6010898.78 N 520121 .19 E 0.000 3273.08 7728.94 60.040 150.304 6054.39 61l5,3Q, .,' ,. ,2926.08 S. 165'522 E 6010877.03 N 520133.67 E 0.000 3297.69 Begin Oir @ 5.000o/100ft: 7728.94ft MO,6115.39ft TVD 7800.00 61.011 146.378 6089.36" 6150:36 2978.71 S 1687.69 E 6010824.48 N 520166.27 E 5.000 3358.77 7900.00 62..566 140.984 6136.66 '6197.66 3049.66 S 1739.88 E 6010753.66 N 520218.63 E 5.000 3446.59 8000.00 64.322 135.750 6181.39 .6242.39 3116.46 S 1799~29 E 6010687.01 N 520278.21 E 5.000 3535.98 8036.02 65.000 133.904 6196.81 6257.81 3139.41 S 1822.38 E 6010664.12 N 520301.36 E 5.000 3568.43 7" Csg Pt ... Drill out 6-1/8" Hole 7" Casing 8100.00 66.259 130.675 6223.21 6284.21 3178.61 S 1865.49E 6010625.03 N 520344.56 E 5.000 3626.26 8136.02 66.997 128.886 6237.50 6298.SO 3199.76 S 1890.90 E 6010603.94 N 520310.02 E 5.000 3658.87 TQp Kuparuk 8200.00 68.357 125.755 6261.81 6322.81 3235.63 S 1937.97 E 6010568.18 N 520417.18 E 5.000 3716.76 8200.52 68.369 125.730 6262.00 6323.00 3235.91 S 1938.36 E 6010567.90 N 520417.57 E 5.000 3717 .23 Top Kuparuk D 8300.00 70.596 120.980 6296.88 6357.88 3287.09 S 2016.16 E 6010516.91 N 520495.50 E 5.000 3806.77 8391.90 72.760 116.710 6325.78 6386.78 3329.15 S 2092.57 E 6010475.05 N 520572.01 E 5.000 3888.48 End Ok, Start Sail @ 72.760°: (' 8391.90ftMD,6386.78ftTVO 8399.38 7.2.760 116.710 6328.00 6389.00 3332.36 S 2098.95 E 6010471.85 N 520578.40 E 0.000 3895.07 3N-19 Target 1 8400.00 72..783 116.710 6328.18 6389.18 3332.63 S 2099.47 E 6010471.59 N 520578.93 E 3.687 3895.62 8500.00 76.470 116.707 6354.69 6415.69 3375.96 S 2185.59 E 6010428.47 N 520665.15 E 3.687 3984.63 8600.00 80.157 116.705 6374.94 6435.94 3419.96 S 2273~06 E 6010384.68 N 520752.73 E 3.687 4075:02 8638.13 81 .562 116.704 6381.00 6442.00 3436.88 S 2306J>9 E 6010367.85 N 520786.40 E 3.687 4109.78 Increase in Dir Rate @ 4.000°/1000: 8638.13ft MD, 6442.00ft TVD - 3N-H Target 2 20 November, 2001 - 14:59 Page 5 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services / Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 3N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/10Oft) 8700.00 83.285 118.497 6389.16 6450.16 3465.29 S 2361.03 E 6010339.57N 520840.81 E 4.000 4166.76 8792.49 85.871 121.155 6397.90 6458.90 3511.08 S 2440.90 E 6010293.98 N 520920.80 E 4.000 4253.56 Target - FB#1 (Top A1), Current Targe 8800.00 86.081 121.369 6398.43 6459.43 3514.97 S 2447.30 E 601029Q.11N 520927.20 E 4.000 4260.68 8822.06 86.700 122.000 6399.81 6460.81 3526.53 S 2466.04 E .6010278.59 N 520945.97 E 4.000 4281.67 End Oir, Start Sail @ 86.700°: ( 8822.06ftMD ,6460.81 ftTVD 8900.00 86.700 122.000 6404.30 6465.30 3567.77 S 2532.02 E 6010237.52 N 521012.06 E 0.000 4355.96 9000.00 86.700 122.000 6410.06 6471.06 3620;67 S, 2616~69E 6010184.83 N 521096.85 E 0.000 4451 .27 9033.76 86.700 122.000 6412.00 6473.00 ,3638.53$ . 264527 E 6010167.04 N 521125.48 E 0.000 4483.45 Begin Dir @ 3.0600/lOOft: 9033.76ft MD, 6473.00ft TVD 9043.00 86.935 122.157 6412.51 6473t.5t"., 3643.43 S ' 2653.09 E 6010162.16 N 521133.31 E 3.060 4492.27 5W' Liner ... Drill out 4.75" Hole 5-1/2" Liner 9092.65 88.200 123.000 6414.62, 641$162, 3670.14 S 2694.89 E 6010135.55 N 521175.17 E 3.060 4539.78 End Oir, Start Sail @ 88.200° : \'" 9092.65ftMD,6475.62ftTVD 9100.00 88..200 123.000 6414.8~~': ' ,6475:85 3674.14 S 2701.05 E 6010131.56 N 521181.34 E 0.000 4546.82 '1'\ 9200.00 88.200 123.000 6417.99'::-' 6478.99 3728.58 S 2784.87 E 6010077.33 N 521265.30 E 0.000 4642.76 9300.00 88.200 123.000 6421.13 '." 6482.13 3783.02 S 2868.70 E 6010023.11 N 521349.26 E 0.000 4738.69 9400.00 88.200 123.000 6424.27 6485.27 3837.45 S 2952.52 E 6009968.88 N 521433.23 E 0.000 4834.63 9500.00 88.200 123~000 6427.42 6488.42 3891.89 S 3036.35 E 6009914.65 N 521517.19 E 0.000 4930.56 9592.79 88.200 123.000 6430.33 6491.33 3942.40 S 3114.13 E 6009864.33 N 521595.09 E 0.000 5019.58 Begin Dir @ 5.00001100ft : 9592.79ft MO. 6491.33ft TVD 9600.00 88.555 123.065 6430.53 6491.53 3946.33 S 3120.17 E 6009860.41 N 521601.14 E 5.000 5026.50 9700.00 93.473 123.965 6428.77 6489.77 4001.52 S 3203.51 E 6009805.43 N 521684.62 E 5.000 5122.68 End Dir, Start Sail @ 95.020° : ( 9731.46 95.020 124.250 6426.44 6487.44 4019.11 S 3229.48 E 6009787.91 N 521710.63 E 5.000 5152.96 9731.46ftMO,6487.44ftTVD 9800.00 95.020 124.250 6420.44 6481.44 4057.54 S 3285.92 E 6009749.62 N 521767.17 E 0.000 5218.90 9900.00 95.020 124.250 6411.69 6472.69 4113.60 S 3368.26 E 6009693.76 N 521849.65 E 0.000 5315.10 10000.00 95.020 124.250 6402.94 6463.94 4169.67 S 3450.61 E 6009637.90 N 521932.13 E 0.000 5411.30 10100.00 95.020 124.250 6394.19 6455.19 4225.73 S 3532.95 E 6009582.04 N 522014.61 E 0.000 5507.50 10200.00 95.020 124.250 6385.44 6446.44 4281.80 S 3615.29 E 6009526.18 N 522097.09 E 0.000 5603.70 10300.00 95.020 124.250 6376.69 6437..69 4337.86 S 3697.63 E 6009470.32 N 522179.57 E 0.000 5699.90 10399.27 95.020 124.250 6368.00 6429.00 4393.52 S 3779.37 E 6009414.86 N 522261.45 E 0.000 5795.40 Total Depth: 10399.27ftMD,6429.0OftTVD 3-1/2" Uner 20 November, 2001 - 14:59 Page 6 of 10 DriIlQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 Kuparuk River Unit All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB esf d @ 68' MSL. Northings and Eastings are relative to 1560' FSL & 71' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 139.297° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10399.27ft., The Bottom Hole Displacement is 5795.40ft., in the Direction of 139.297° (True). Comments Measured Station Coordinates Depth TVD Northings (ft) (ft) (ft) 0.00 0.00 393.00 393.00 993.00 988.62 1493.00 1477.70 2293.00 2271.86 3239.14 3218.00 222.78 S 113.51 E 3646.21 3622.00 260.32 S 134.92 E 5240.47 4872.65 1053.29 S 587.16 E 7728.94 6115.39 2926.08 S 1655.22 E 8036.02 6257.81 3139.41 S 1822.38 E 8391.90 6386.78 3329.15 S 2092.56 E 8399.38 6389.00 3332.36 S 2098.95 E 8399.38 6389.00 3332.36 S 2098.95 E 8638.13 6442.00 3436.88 S 2306.69 E 8822.06 6460.81 3526.53 S 2466.04 E 9033.76 6473.00 3638.53 S 2645.27 E 9043.00 6473.51 3643.43 S 2653.09 E 9092.65 6475.62 3670.14 S 2694.89 E 9592.79 6491 .33 3942.40 S 3114.13 E 9731 .46 6487.44 4019.11 S 3229.48 E SHL: X = 518470.80' E & Y = 6013799.15' N (1561' FSL & 70' FWL, Sec 28-T131N-R9E) Begin Dir @ 2.0000/100ft : 393.00ft MD, 393.00ft TVD End Dir, Start Sail @ 12.000° : 993.00ftMD,988.62ftTVD Begin Dir @ 1.5000/100ft: 1493.00ft MD, 1477.70ftTVD End Dir, Start Sail @ 0.000° : 2293.00ftMD,2271.86ftTVD Begin Dir @ 3.0000/100ft: 3239.14ft MD, 3218.00ft TVD 9-5/8" Csg Pt ... Drill out 8-1/2" Hole End Dir, Start Sail @ 60.040° : 5240.47ftMD,4872.65ftTVD Begin Dir @ 5.0000/100ft: 7728.94ft MD, 6115.39ft TVD 7" Csg Pt ... Drill out 6-1/8" Hole End Dir, Start Sail @ 72.760° : 8391.90ftMD,6386.78ftTVD Begin Dir @ 3.687°/100ft: 8399.38ft MD, 6389.00ft TVD 3N-19 Target 1 Increase in Dir Rate @ 4.0000/100ft : 8638.13ft MD, 6442.00ft TVD - 3N-19 Target 2 End Dir, Start Sail @ 86.700° : 8822.06ftMD,6460.81ftTVD Begin Dir @ 3.0600/100ft: 9033.76ft MD, 6473.00ft TVD 5W' Liner ... Drill out 4.75" Hole End Dir, Start Sail @ 88.200° : 9092.65ftMD,6475.62ftTVD Begin Dir @ 5.0000/100ft : 9592.700 MD, 6491.33ft TVD End Dir, Start Sail @ 95.020° : 9731.46ftMD,6487.44ftTVD . North Slope, Alaska Kuparuk 3N ( ( 20 November, 2001- 14:59 DrillQuest 2.00.09.006 Page 7 of1 0 Kuparuk River Unit Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 . North Slope, Alaska Kuparuk 3N Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment Comments (Continued) 10399.27 6429.00 Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 1650.00 0.000 0.142 3045.50 0.000 0.142 3461.00 0.000 0.142 5900.00 0.000 0.142 6237.50 0.000 0.142 6262.00 0.000 0.142 4393.52 S 3779.37 E Total Depth: 10399.27ftMD,6429.0OftTVD ( ;'¡"1711.ÖØ . . 3106.50 ,,3522~OO' . 5961.00 6298.50 6323.00 Profile P .en:eit r.áti 0" Point Measured Vertical $ub-Se~ . Depth Depth',' Dept~,1 (ft) (ft) . (ft): 1730.10 ' 3127.64 " 3544.44 . 7419.79 8136.02 8200.52 Nårthings (ft) Eastings (ft) Formation Name 1650.00 185.89 S 94.71 E Base Permafrost 3045.50 222.78 S 113.51 E Top West Sak 3461.00 243.93 S 125.57 E Base West Sak 5900.00 2693.42 S 1522.53 E Upper Kalubik 6237.50 3199.76 S 1890.90 E Top Kuparuk 6262.00 3235.91 S 1938.36 E Top Kuparuk D ( 20 November, 2001 - 14:59 Page 8 of 10 DrillQuest 2.00.09.006 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surlace> <Surlace> <Surlace> <Surlace> <Surlace> <Surlace> <Surlace> <Surlace> Targets associated with this wellpath Target Name 3N-19 T1 3N-19 T2 Fault #1 Fault #2 FB#1 (Top A 1) To Measured Vertical Depth Depth (ft) (ft) 3646.21 8036.02 9043.00 10399.27 3622.00 6257.81 6473.51 6429.00 Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 . North Slope, Alaska Kuparuk 3N Casing Detail 9-5/8" Casing 7" Casing 5-1/2" Liner 3-1/2" ( Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 6389.00 3332.21 S 2098.55 E Point Current Target Mean Sea Level/Global Coordinates: 6328.00 6010472.00 N 520578.00 E Geographical Coordinates: 70° 26' 23.1645" N 149° 49' 55.9149" W 6442.00 3436.73 S 2306.29 E Point Current Target Mean Sea Level/Global Coordinates: 6381.00 6010368.00 N 520786.00 E Geographical Coordinates: 70° 26' 22.1359" N 149049'49.8174" W 6479.00 3739.71 S 2703.54 E Point Current Target ( Mean Sea Level/Global Coordinates: 6418.00 6010066.00 N 521184.00 E Geographical Coordinates: 70° 26' 19.1545" N 1490 49' 38.1592" W 6476.00 4085.32 S 3350.69 E Point Current Target Mean Sea Level/Global Coordinates: 6415.00 6009722.00 N 521832.00 E Geographical Coordinates: 70° 26' 15.7526" N 149° 49'19.1673" W 6458.90 3511.06S 2440.92 E Point Current Target Mean Sea Level/Global Coordinates: 6397.90 6010294.00 N 520920.81 E Geographical Coordinates: 70° 26' 21.4043" N 1490 49' 45.8661" W 20 November, 2001 - 14:59 Page 9 of 10 DrillQuest 2.00.09.006 Kuparuk River Unit Target Name Targets associated with this wellpath (Continued) FB#1 (Top A2) FB#1 (Top A3) FB#2 (Top A3) FB#3 (TopA1) FB#3 (Top A2) FB#3 (Top A3) Sperry-Sun Drilling Services Proposal Report for Plan: 3N-19 - 3N-19 (wp03) Your Ref: Based on Prelim Plan Ver. #3.3 Revised: 20 November, 2001 . North Slope, Alaska Kuparuk 3N Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Target Shape Type 6412.41 3370.40 S 2174.01 E Point Cu rrent Target ( Mean Sea Level/GlobalCoordinates: 6351.41 6010434.00 N 520653.56 E Geographical Goordinate~: 700 26' 22.7887" N 149049' 53.6999" W 6387.49 3330.20 S 2094.21 E Point Current Target MeaOSèa LêVel/GloblillCoordinates: 6326.49 6010474.00 N 520573.66 E . ßeogt¡:tphicarCoordinates: 700 26' 23.1843" N 1490 49' 56.0421" W '.' 64 76.31 3682.74 S 2713.71 E Point Current Target MeariiSea Level/Global Coordinates: 6415.31 6010123.00 N 521194.03 E Geographical Coordinates: 700 26' 19.7149" N 1490 49' 37.8600" W 6470.72 4126.41 S 3386.58 E Point Current Target Mean Sea Level/Global Coordinates: 6409.72 6009681.00 N 521868.00 E Geographical Coordinates: 700 26' 15.3483" N 149049' 18.1141" W 6444.05 4297.03 S 3637.44 E Point Current Target Mean Sea Level/Global Coordinates: 6383.05 6009511.00 N 522119.28 E Geographical Coordinates: 700 26' 13.6690" N 149049' 10.7532" W 6429.37 4390.87 S 3775.43 E Point Current Target Mean Sea Level/Global Coordinates: 6368.37 6009417.50 N 522257.50 E ( Geographical Coordinates: 70026' 12.7453" N 149049' 06.7044" W 20 November, 2001- 14:59 DrillQuest 2.00.09.006 Page 10 of 10 (' Sperry-Sun Anticollision Report ( --'-----'---""'-"" Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 3N Pad Reference Well: 3N-19 Reference Wellpath: 3N-19 m~OnAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interlwlation Method: MD Interval: 50.0 ft Depth Range: 31.0 to 10399.3 ft Maximwn Radius: 1237.5 ft Date: 11/19/2001 Time: 18:21 :10 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 3N-19, True North 3N-19@61' ASL 61.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: 3N-19WP03 & NOT PLANNED PR RA~ ISCW SA Ellipse Trav Cylinder North Ellipse + Casing ~---...-,----_.__._------_.._--------- Casing Points C-------------..-- . ------------ MD TVD Diameter Hole Size Name ft ft in in -~~~~~~~----~-~~--_._-~.5O?__2~_____------- ~~:p~~~~=PO=--=====- ~~E~pœred~ 10/16/2001 1 From Well Ref. Point l ~ Summary g--~----"------- ".. ...- <;u......-.-...-....... Off!ìct Wellpatb -.-.-.....--.....--..-> Rderence Otfsd Ctr"Ctr. No-Go AUowuble Site Well Welll)ath . MD MD Distance. Area De,'tation Warn'ng l;.;~~~~=~~Ù~L1~~:g~::~=~ Site: Kuparuk 3N Pad Well: 3N-13 Rule Assigned: Major Risk Wellpath: 3N-13 V1 Inter.Site Error: 0.0 ft ...---..----.--,-..--...---.--..,-...-...--,-------..-..----..--...,..-.......--..-.---... ----.---- Reference Offset SeJni.Mt\jor A~ls Ctr.Ctr > No-GO Allowable MD TVD MD TVI) Ref Offset T]?O+AZI TFO.as.. Ca..dog Dtstanc~ .. Area Pevlatton Warning ft ft ft ft ft ft deg dég In It ft ft 8100.0 6284.2 6600.0 5703.1 55.7 13.9 188.79 58.12 1204.8 238.8 1014.6 Pass 8100.0 6284.2 6650.0 5740.2 55.7 14.2 189.38 58.71 1158.2 239.2 966.7 Pass 8118.8 6291.7 6700.0 5777.4 55.7 14.3 189.47 59.74 1111.6 239.6 918.3 Pass 8127.2 6295.0 6750.0 5814.6 55.6 14.5 189.94 60.62 1065.3 239.9 870.4 Pass 8135.8 6298.4 6800.0 5851.9 55.6 14.6 190.48 61.59 1019.3 240.3 822.6 Pass 8144.4 6301.7 6850.0 5889.3 55.6 14.8 191.11 62.64 973.6 240.7 774.9 Pass 8153.1 6305.1 6900.0 5926.6 55.6 15.0 191.82 63.78 928.2 241.1 727.4 Pass 8161.9. 6308.5 6950.0 5964.0 55.6 15.2 192.65 65.04 883.2 241.5 680.1 Pass 8170.8 6311.9 7000.0 6001.6 55.5 15.3 193.61 66.43 838.6 241.9 633.1 Pass 8179.7 6315.2 7050.0 6039.1 55.5 15.5 194.72 67.98 794.6 242.3 586.4 Pass 8200.0 6322.8 7100.0 6076.8 55.5 15.6 195.65 69.90 751.3 242.6 539.9 Pass 8200.0 6322.8 7150.0 6114.5 55.5 15.8 197.42 71.67 708.5 243.1 494.1 Pass 8200.0 6322.8 7200.0 6152.2 55.5 16.0 199.42 73.67 666.7 244.0 448.6 Pass 8216.2 6328.7 7250.0 6190.0 55.4 16.2 201.21 76.24 625.9 244.2 403.9 Pass 8225.5 6332.1 7300.0 6227.9 55.3 16.3 203.54 79.02 586.4 244.5 360.5 Pass 8235.0 6335.5 7350.0 6265.8 55.3 16.4 206.25 82.18 548.4 244.7 318.6 Pass 8~~44.7 6338.9 7400.0 6303.8 55.2 16.6 209.40 85.80 512.4 244.8 278.5 Pass 8254.5 6342.4 7460.0 6341.9 55.1 16:1 213.08 89.95 478.7 245.0 240.8 Pass 8264.4 6345.8 7500.0 6380.1 55.1 16.8 217.35 94.68 447.9 245.2 206.3 Pass 8274.4 6349.3 7550.0 6418.3 55.0 17.0 222.25 100.07 420.5 245.6 175.9 Pass 8284.6 6352.7 7600.0 6456.5 55.0 17.2 227.84 1 06.13 397.1 246.0 151.0 Pass 8~300.0 6357.9 7650.0 6494.7 54.9 17.4 233.91 112.93 378.6 246.4 132.9 Pass 8300.0 6357.9 7700.0 6532.9 54.9 17.6 241.05 120.07 365.7 247.3 122.4 Pass 8315.7 6363.0 7750.0 6571.1 54.7 17.8 248.08 127.84 358.8 247.5 122.0 Pass 8326.4 6366.5 7800.0 6609.2 54.6 17.9 255.43 135.68 358.3 247.7 131.1 Pass 8337.3 6370.0 7850.0 6647.4 54.5 18.1 262.63 143.40 364.4 247.8 149.2 Pass 8341.2 6371.2 7868.0 6661.1 54.5 18.1 265.15 146.10 368.1 247.9 157.7 Pass ._.._¡......._..........,...--_.."-...._-"....,.._.._-,...,--,,,,,,,_..__._......~"",,,-,,,.,,,,,,,-,,,,,,,,,-,,-,,,,,,,,,,-,,,,,,,,.,,-,,,,,,,,,.,,,,,,,,,,,,,,,,,,.._.,..-..-......._...,,",,,~,,--,,,,_.,._,,,,,,,-,--,,,-,,,--,,,,,--,,,,,,,,,,----.-.--....-....------.....,....---....--.-.....,.............."...-.........- ( Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 3N Pad Reference Well: 3N-19 Reference Well path: 3N-19 Site: Kuparuk 3N Pad Well: 3N-17 Wellpath: 3N-17 V1 Sperry-Sun Anticollision Report ( Date: 11/19/2001 2 Co-ordinate{NE) Reference: Vertical (TVD) Reference: Time: 18:21:10 Page: Well: 3N-19, True North 3N-19@61' ASL 61.0 Db: Oracle Reference MD TVD ft ft 10033.7 6461.0 10041.5 6460.3 10048.9 6459.7 10056.3 6459.0 10063.5 6458.4 Offset MD TVD ft ft 7050.0 5294.8 7100.0 5330.3 7150.0 5366.0 7200.0 5401.7 7250.0 5437.5 Semi-Ma.lor Axis Ref Offset TFO+AZI TFO-HS Casing ft ft deg deg in 82.8 22.1 107.29 343.04 82.9 22.3 105.26 341.01 83.1 22.6 103.14 338.89 83.2 22.8 100.95 336.70 83.3 23.0 98.67 334.42 10070.5 6457.8 7300.0 5473.4 83.4 10077.4 6457.2 7350.0 5509.3 83.5 10084.2 6456.6 7400.0 5545.3 83.6 10090.8 6456.0 7450.0 5581.3 83.7 10097.3 6455.4 7500.0 5617.3 83.8 10103.7 6454.9 7550.0 5653.4 83.9 10110.0 6454.3 7600.0 5689.5 84.0 10116.3 6453.8 7650.0 5725.7 84.1 10122.4 6453.2 7700.0 5761.9 84.2 10128.6 6452.7 7750.0 5798.1 84.3 10134.6 6452.2 7800.0 5834.3 84.4 10140.6 6451.6 7850.0 5870.5 84.5 10146.5 6451.1 7900.0 5906.7 84.6 10152.2 6450.6 7950.0 5943.0 84.7 10157.9 6450.1 8000.0 5979.4 84.8 10163.5 6449.6 8050.0 60'15.8 84.9 10168.9 6449.2 8100.0 6052.3 84.9 10174.2 6448.7 8150.0 6088.9 85.0 10179.4 6448.2 8200.0 6125.6 85.1 10184.5 6447.8 8250.0 6162.3 85.2 --- 23.3 96.32 332.07 23.5 93.90 329.65 23.7 91.42 327.17 23.9 88.87 324.62 24.2 86.27 322.02 24.4 83.63 319.38 24.6 80.95 316.70 24.9 78.26 314.01 25.1 75.56 311.31 25.3 72.86 308.61 25.5 70.17 305.92 25.8 67.51 303.26 26.0 64.89 300.64 26.2 62.31 298.06 26.4 59.79 295.54 26.7 57.33 293.08 26.9 54.93 290.68 27.1 52.61 288.36 27.4 50.37 286.12 27.6 48.20 283.95 10189.6 6447.3 8300.0 6199.1 85.3 27.8 46.11 281.86 1------......--.---------..---------...--..---..-.-....--.----.------'----'---'-----'''' Rule Assigned: I nter-Site Error: Ctr-Ctr No-Go Distance Area ft ft 1223.9 336.9 1199.7 337.7 1176.9 338.5 1155.6 339.2 1136.1 340.0 1118.4 340.8 1102.6 341.5 1088.7 342.3 1077.0 343.1 1067.4 343.8 1060.0 345.1 1054.8 345.9 1051.9 346.6 1051.4 347.4 1053.2 348.1 1057.3 348.9 1063.7 349.6 1072.4 350.3 1083.3 351.0 1096.2 351.7 1111.1 352.5 1128.0 353.2 1146.6 353.9 1167.0 354.6 1189.0 355.2 1212.6 355.9 Major Risk 0.0 ft Allowable Deviation ft 1055.8 1024.2 993.5 964.1 936.2 Warning Pass Pass Pass Pass Pass 909.8 Pass 885.1 Pass 862.4 Pass 841. 7 Pass 823.3 Pass 807.2 Pass 793.7 Pass 782.7 Pass 774.4 Pass 768.9 Pass 766.2 Pass 766.3 Pass 769.3 Pass 775.0 Pass 783.3 Pass 794.2 Pass 807.5 Pass 823.2 Pass 841.1 Pass 861.1 Pass 883.1 Pass 0 From Colour 0 200 450 700 950 ]450 1950 2450 2950 :Q50 4200 4950 5700 6450 7200 8200 9200 Toll/ID 200 450 700 950 1450 [950 2450 2950 3450 4200 4950 5700 6450 7200 8200 9200 ¡0200 j 1200 90 AITACHMENT #2 ( ( 3N-19 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole /9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low N/A Monitor well at base of peffilafrost, increased Gas Hydrates Low mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud Running Sands and Gravels Low weight, use weighted sweeps, run gravel isolation stnng. Abnoffilal Pressure in Surface FOffilations Low Diverter drills, increased mud weight > 2000' TVD Reduced pump rates, mud rheology, lost Lost Circulation Low circulation material, use of low density cement slurries 8-1/2" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnoffilal Pressure in BOPE drills, Keep mud weight weight greater Surface FOffilations Moderate then or equal to 11.0 ppg. Check for flow during > 2000' TVD connections and if needed, increase mud weight Reduced pump rates, reduced trip speeds, real Lost circulation Low time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole Hole swabbing on trips Moderate filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices, mud scavengers ATIAŒIMENT #2 ( 6-1/8" Hole / 5-1/2" Drilling Liner ( Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real Lost circulation Low time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole Hole swabbing on trips Moderate filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight greater then or equal to 11.0 ppg. Check for flow during Abnonnal Reservoir Medium connections and if needed, increase mud weight. Pressure Well control drills, increased mud weight. Kuparuk A -sands may be abnonnally pressured due to water injection from 3N-08a Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 4-3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real Lost circulation High time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7"/5.5" shoe, Hole swabbing on trips High mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.3 ppg. Abnonnal Reservoir Medium Check for flow during connections and if needed, Pressure increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers #3 FMC Kuparuk V Wellhead 3N-19 COMPLETION SCH EMA TI C Top Set Scenario 3- 1/2" 9.3# WE Srd tubing Drifted to 2.992" above DS Nipple Nipple - 2.875" ID @ 500' MD 16" Conductor set @ 115' MD 3-112" 9.3# WE 8rd tubing Drifted to 2.867" below DS Nipple 3-1/2")( 1" KBUG GLM's or 3-112")( 1-1/2 "MMG GLM's Estimated of Cement @ 7536' MD Top BAKER 5-1/2" X 7' CPH liNER HANGER PACKER @ 7800' MD 7" LBO, BTM. intermediate @ 3036' MDI 6258' TVD Topof @8136' MO ¡ 6299' TVD Baker CMU -2.813" m I DS Profile BakerCMU Sleeves-2.75" !D I OD DS Profile 3.5", CsglTbgOD 9-5/8",40# 7",26# 5-1/2",15.5# 3-112",9.3# 10.625 8.679 7.6566.151 5.5" 4.825 4.250 2.867 Completion MO TVO Tubing Hanger 3-1/2", 9.3#/ft, EUE-8rd Tubing Cameo OS Nipple (2.875" 10) 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GlM (w/pups)(#5) 2700' 2678' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GlM (w/pups)(#4) 4247' 4180' 3-1/2", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GLM (w/pups)(#3) 5500' 5005' 3-1/2", 9.3#/ft, EUE-8rd Tubing 3-1/2" K8UG GlM (w/pups)(#2) 7000' 5755' 3-1/2", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GlM (w/pups)(#1) 8036' 6202' 3-112", 9.3#/ft, EUE-8rd Tubing (2 jts) 3-1/2 x 5-1/2 FAR-1 PKR 8100' 6284' 3-112", 9.3#/ft, EUE-8rd Tubing 3-1/2" CMU SS (2.831" 10) to be determined 3-1/2", 9.3#/ft, EUE-8rd Tubing w/(20' of BLAST Rings) 3-1/2" CMU SS (2.750" 10) 3-1/2", 9.3#/ft, EUE-8rd Tubing Cameo 0 Nipple (2.250" 10) 3-1/2", 9.3#/ft, EUE-8rd Tubing (ljt) 3-1/2 x 7" IXP liner HGR PKR 8893' 6464' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112", 9.3#/ft, Slotted liner 10399' 6429' (8IM special clearance coupling) 23' 23' 500' 500' to be determined 5.5", 15.5#, L80, HydriliSl1. Drilling Liner Shoe @ 9043' MD I 6474' TVD - 1 00' from fault A TT ACHMENT 3N- 1 9 COMPLETION SCHEMATIC FMC Kuparuk GenV Wellhead ]" Long String Scenario 3-1/2" 9.3# Em 8rd tubing Drifted to 2.992" above DS Nipple Nipple -2.875" ID @ 500' MD 3-1/2" 9.3# WE 8rd tubing Drifted to 2.867" below DS Nipple 3-1/2" x I" KBUG GLM's or 12")( 1-1/2 . MMG GLM's 9-5/8", 40#, LBO, Butt. Surface Casing Set @ 3646' MD/3622' TVD Estimated Top of Cement @ 7636' MD CsglTbg 9-5/8",40# 7" ,26# 3-112",9.3# OD 10.625 8.679 7.656 6.151 4.250 2.867 Completion MD 23' TVO Tubing Hanger 3-112", 9.3#/ft, EUE-8rd Tubing Cameo DS Nipple (2.875" 10) 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GLM (w/pups)(#5) 2700' 2678' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KRUG GlM (w/pups)(#4) 4247' 4180' 3-112", 9.3#/ft, EUE-8rd Tubing 3-1/2" KBUG GLM (w/pups)(#3) 5500' 5005' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GlM (w/pups)(#2) 7000' 5755' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" KBUG GLM (w/pups)(#1) 8036' 6258' 3-112", 9.3#/ft, EUE-8rd Tubing (2 its) 3-112 x 7" FHL PKR 8100' 6284' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112" CMU SS (2.831" ID) to be determined 3-112", 9.3#/ft, EUE-8rd Tubing w/(20' of BLAST Rings) 3-112" CMU SS (2.750" 10) 3-112", 9.3#/ft, EUE-8rd Tubing Cameo 0 Nipple (2.250" 10) 3-112", 9.3#/ft, EUE-8rd Tubing (tit) 3-112 x 7" ZXP liner HGR PKR 8893' 6464' 3-112", 9.3#/ft, EUE-8rd Tubing 3-112", 9.3#/ft, Slotted liner (RIM special clearance coupling) 23' 500' 500' to be determined 10399' 6429' Baker CMU Sliding -2.813" ID 14.28" DS Profile , 26#, L80, BTM. Intermediate Casing Top Set @ 9043' MD/6474' TVD - 100' from fault Well TD @ 10399' MO / 6429' TVD Baker CMU Sliding Sleeves -2.75" ID I 4.28" OD DS Profile 3.5",9.3#, LaO, WE 8rd. Tubing ZXP-HMC LinerTop Packer Set @ 8893' MD ---------- ---------- ---------- ---------- ---------- ---------- ---------- CHECK 1 STANDARD LETTER DEVELOPMENT j DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL { TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME KR{~ 3¡J'--lr CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNUL~SAL ANNULA~OSAL -dfj YES ANNULAR DISPOSAL THIS WELL (' "CLUE" The permit is for a new well bore segment of existing well ---'---' Permit No, API No. ' Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved.. . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS I ~YES+ SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. DATE 11 ~ tJ - 'LOOt ~~YD:~:Pj;¿¡Jiti: ~~ö ~: ( American Express~ Cash Advance Draft Issued by Integrated Payment System, Inc. Englewood. Colorado Payable at NOlWest Bank of Grand Junction - Downtown. NA PERIOD ENDING GrandJunction.Colorado ~,J...\D\ 181 1:12..40/1 n') I I $ [iqQ 00 --] DO L LARS WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION COMPANY , () INIT CLASS 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Wellloeated in a defined pool.. . . . . . . . . . . . . . . . . 5. Wellloeated proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . - - . . - . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . '.' . . I.' . . 10. Operator has appropriate bond in force~ 5~~. (P~i~fl.(n).., )'/.0-'1"';' 11. Permit ean be issued without conservation order. . . . . . . . APPR DATE 12. Permit ean.be issued without administrative approval.. . . . . Þ II, 2/, 01 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided . . . . . . . . .. . . . . . . . . . 15. Surface easing protects all known USDWs. . . . . . . . . . 16. CMT vol adequate to drculate 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. 8 & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore 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 ~ S-o U psig. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Pennit can be issued w/o hydrogen sulfide measures. . . . ,. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APP,~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Ai~ 11.2/. D)' 34. Contact name/phone for weekly progress reports [explora . ANNULAR DISPOSAL35. 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 pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GE~ ENGINEERING:. .UICfAnnular COMMISSION: ~~ ' WM ~ ,895 JM &i/~~~ PROGRAM: exp - dev - redrll- serv - wellbore seg _ann. disposal para req - GEOL AREA T37'C) UNIT# ON/OFF SHORE (')Þ) " N N , N N. )N N ~ ßr berxd Þtt.'~Þu-- t4 Sq s-z /'8¿).~ N ./N ~~ . ~ <w ~\D'<k'2, \'\ "-<L."l\h~S) (j)N . (y) N <L"'s.~';~~ ~ ~ ~ ~C) \CCSCL~~ D\.-\-- -¥-N-- "-J ~ .:::> .:> "'\ ~ ~ V-~S~ r¿ <-.\- <2- d'ò, \ \ ",,>'¡ ?\> c.c, \\ ~\ 't ~ ~">-\-~ Çð~a ~N. . ~ ~~~1:~0~\-\\c.Q\ Of' ~~ ~~ \'=..~~'-.)"\'~~ ~(~~u--s.~~ ~ CJ.~~~* Y ND - ¿. (, - /8' 'y '., S (;~ '_7 G> ..e..- 4-¡.û ~Â-<¿ $ / !;.c.U>s4Ô#-1- / P'.3 N . Y N only) Y N c 0 Z ( 0 {, -I :E :xl -I m Z -I :r: , 2C.;C:D. en ¿D :Þ :xl ( m > DATE \.l( ~ S; GEOLOGY APPR DATE Y N Y N Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/011100) f 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 simpHfy finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special 'effort has been made to chronologicaHy , . organize this category of information. (' ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 04 09:03:21 2002 Reel Header Service name..... ........LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/04/ 04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Nunmer......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOr Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # 1\7ELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # eTOB DATA ,TOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-11209 T. MCGUIRE E. EOSS # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DEEfUCK FLOOE: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STFUNG 12.250 8.500 # REMARKS: Writing Library. Scientific Technical Services Writ.ing Library. Scientific Technical Services 3N-19PB1 500292305670 PHILLIPS Alaska, Inc. Sperry Sun 02-APR-02 MWD RUN 2 AK-MM-11209 P. SMPrH F. HERBERT MWD RUN 3 AK-MM-11209 P. SMITH F. HERBERT 28 13N 9E 1561 70 .00 29.66 32.90 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 118.0 3640.0 8754.0 1. ALL DEPTHS ARE JVIEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2 ~ MfAìD RUN 1 IS DIRECTIONAL WITH NATUR1\L GAJlIIMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. a OJ -dd5 /0,67 ( ( 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMW\. RAY (SGRC) IS LOGGED BEHIND CASING FROM 3613' MD, 3586' TVD TO 3640' MD, 3612' TVD. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 8713' MD, 6458' TVD TO 8754' MD, 6461' TVD. 5. THE GAP IN GAMMA RAY (SGRC) FROM 8516' MD, 6457' TVD TO 8713' MD, 6458' TVD IS DUE TO A GAMMA RAY TOOL FAILURE. 6. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. DATED 02/18/0::::. ALL JVIWD LOG HEI-\.DER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL 3N-19PB1 WITH API # 50-103-20378-70. THIS WELL REACHED A TOTAL DEPTH OF 10483' MD, 6456' TVD. SROP = SMOO'l'HED RATE OF PENETRATION SGRD "'" SMOO'I'HED GAMMA RAY SGRC = SMOOTHED GAMMA RAY COMB:LNED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALl,OW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORIVIATION EXPOSURE TIME $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number.... ....,..1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ clipped curves; all bit runs merged. .5000 START DEPTH 89.0 151. 0 3630.0 3630.0 3630.0 3630.0 3630.0 STOP DEPTH 10431. 0 10482.0 10438.0 10438.0 10438.0 10438.0 10438.0 H BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) -~------- EQUIV1\I.,E',NT UNm:!I F':rE~.D DE P'rF1 --------- BASELINE DEPTH ( ( $ # HERGED PBU MWD HWD MWD DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 89.0 ~ 3663.0 3 8765.0 MERGE BASE 3662.0 8764.5 10482.0 $ 1+ REHARKS: HERGED HAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units....... ....Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...ü Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 Ü 1 ROP HWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMH 4 1 68 16 5 RPM MVlìD OHMJv] 4 1 68 20 6 RPD HWD OHMM 4 1 68 24 7 FET M!AjD HR 4 1 68 28 8 First Last Name Service Unit Min Max ]VIe an Nsarn Reading Reading DE PT FT 89 10482 5285.5 20787 89 10482 ROP MWD FT/H 0.27 672.86 128.066 20663 151 10482 GR MWD API 16.36 441.23 100.273 20291 89 10431 RPX H~ÎìD OHH~I[ 0.53 1399.73 8.10199 13617 3630 10438 RPS HWD OHNH 0.53 2000 10.2115 13617 3630 10438 RPM MWD OHMM 0.51 2000 22.,1988 13617 3630 10438 RPD MWD OHMM 0.22 2000 19.H337 13617 3630 10438 FET HWD HR 0.21 113.13 2.53992 13617 3630 10438 First Reading For Entire Fi18..........89 Last Reading For Entire F11e...........10482 File Trail,,;r Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/04 Haximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... """" ..STSLIB.002 Service Sub l,evel Name... Version Number...........1.ü.O Date of Generation.......02/04/04 Haximum Physical Record..65535 File 'Type................ LO Previous File Name...... .STSLIB.001 Comment Record (' FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUHHARY VENDOR TOOL CODE GR ROP $ L ( header data for each bit run in separate files. 1 .5000 START DEPTH 89.0 151. 0 STOP DEPTH 3613.0 3662.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTíl'JARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE 'TOOL TYPE NGP NA'rURAL GAMIvIA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (1'1'1'): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MU D CAKE NT' M'I': # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ II Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point.. .......... ..Undefined Frame Spacing.....................60 .1IN Max frames per record.... .........Undefined Absent value.................... ..-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specificat:Lon Block sub-type... 0 13-DEC-01 Insj.te 4.05.5 3.30 Memory 3662.0 .3 13.5 TOOL NUMBER TLG033 12.250 3640.0 Spud Mud 9.60 154.0 9.0 500 4.6 .000 91. 000 .000 .000 .0 91. 0 .0 .0 Name Service Order Un:Lts S:Lze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOIO FT/H 4 1 68 4 2': ( (' GR MWDOI0 API 68 8 3 first Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 89 3662 1875.5 7147 89 366:? ROP M~\)DOI0 FT/H 0.:27 672.86 14~3.463 7023 151 366:: GR M~"I1DO 10 API 16.36 139.79 77.9615 7049 89 3613 First Reading For Entire File..........89 Last Reading For Entire File.... .......3662 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... V~rsion Number...........1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO2 Comment Record FILE HEADER FILE NUMBER: RATÑ MTÑD Curves and log header data for each bit run in separate files. BIT .RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ 3 ,~ ¿ .5000 START DEPTH 3613.5 3630.0 3630.0 3630.0 3630.0 3630.0 3662.5 STOP DEPTH 8516.0 8722.5 8722.5 8722.5 8722.5 8722.5 8764.5 II LOG HEADER DAT.A DATE LOGGKD: SOFTWARE SURFACE SOFTWI\RE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (fT): BOTTOM LOG INTERVAL, (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 24-DEC-01 Insite 4.05.5 66.16 Memory 8765.0 15.2 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE 'TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB02345HWRG6 PB02345HV\ìRG6 (' ( BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 8754.0 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 l\T MEASURED TEHPERATURE (HT): HUD AT HAX CIRCULA'I'ING TERHPERATURE: HUD FILTRATE AT HT: HUD CAKE AT HT: LSND 12.20 59.0 8.8 450 2.2 2.000 .908 2.400 2.400 68.0 158.0 68.0 68.0 NEUTRON TOOL HATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REHARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specif:Lcation Block Type.....O Logging Direction.................Down Optical log depth un.its........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined .Absent value...................... -999 Depth Units....................... Datum Specification Block: sub-typE::... 0 Name Service Or'del' Un:Lts Si.ze Nsam Rep Code Offset Channel DEPT F"l' 4 1 68 0 1 ROP HWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS HWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD Mír.JD020 OHMM 4 1 68 24 7 FET HWD020 HR 4 1 68 28 8 Fi.rst Last Name Service Unit Min Max Hean .Nsam Reading Reading DEPT FT 3613.5 8764.5 6189 10303 3613.5 8764.5 ROP MWD020 FT/H 0.4 552.17 128.306 10205 3662.5 8764.5 GR MWD020 ¡\PI 36.34 441.23 115.081 9806 3613.5 8516 RPX MWD020 OHMM 0.53 13'70.06 5.50956 10186 3630 8722.5 RPS MWD020 OHMM 0.53 :2000 6.5137 10186 3630 8722.5 RPM MWD020 Ol-IMM 0.5] 2000 8.95655 101B6 3630 8722.5 RPD MWD020 OHMM (L~22 2000 10.3918 10186 3630 8722.5 FET MWD020 HR 0.21 109.33 1.92622 10186 3630 8722.5 First Reading For Entire File...........3613.5 Last Reading For 8ntire File...........8764.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.. .....02/04/04 Maximum Physical Record..65535 ~' Fil e Type........ - . . . . . . . LO Next File Name.. ... .... ..8T8LI8.004 Physical EOF File Header Service name.. ...... .....8TSLIB.004 Service 8ub Level Name... Version Number.......... .1.0.0 Date of Generation. ......02/04/04 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE [\lUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ ( header data for each bit run in separate files. 3 .5000 START DEPTH 8713.5 8723.0 8723.0 8723.0 8723.0 8723.0 8765.0 jj LOG HEADER DATA DATE LOGGED: SOFTWARE SURfACE SOE"I'WARE VERSION: DOWNHOLE SOFTli'Jl\RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILl,ER (FT): TOP LOG INTERVAL (F'r): BOTTOM LOG INTERVJ.\L (1:"1'): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DE PTI-[ 10431. 0 10438.0 10438.0 10438.0 10438.0 10438.0 10482.0 BOTTOM) TOOL TYPE DUJ\L GAMMJ\ RJ\Y ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (F'T'): # BOREHOLE CONDI'I'IONS MUD TYPE: MUD DENSITY (LB/G): HUD VISCOSITY (S): HUD PH: MUD CHLORIDES (PPM): FLUID 1.,OS8 (C3): RESIS'l'IVITY (OHMM) 1.I.T 'J'EMPERNTURE (DEGF) MUD AT MEASURED 'I'E:MPERATURE (1'1'r): MUD 1\'1' Mf\X CIH.CULJ\TING TEEMPERJ\TURE: MUD FILT.RATE AT M'l': MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 30-DEC-01 Insit.e 4.05.5 66.16 Memory 10483.0 81. 5 103.1 TOOL NUMBER PB02367HAG.R4 PB02367HAG.R4 6.125 Drill-N 9.80 49.0 8.5 450 4.0 .060 .034 .040 .060 74.0 136.4 74.0 74.0 ( ( HOLE CORRECTION (IN): TOOL STANDOFF (IN:: EWR FREQUENCY (HZ;: REMARKS: $ # Data Format Specification Record Data Record Type.................. (I Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specificati.on Block sub-type... () Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'T 4 1. 68 () 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1. 68 1.2 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MvW030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET M1riJD030 HR 4 1 68 28 8 F.i rat Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8713.5 10482 9597.75 3538 8713.5 10482 ROP MWD030 FT/H 1.92 398.77 85.6489 3435 8765 10482 GR MWD030 l\21 37.71 161. V5 103.785 3436 8713.5 10431 RPX MWD030 OHMM 2,.38 1399.73 15.7984 3431 8723 10438 RPS MT^1D030 OHMM 2.01 846.65 :21.1898 3431 8723 10438 RPM MWD030 OHMM 4.05 2000 62.7031 3431 8723 10438 RPD MWDü30 OHMM 1. .17 200ü 45.n49 3431 8723 10438 FET MWD030 HR 0.42 113.13 4.36188 3431 8723 10438 First Reading For Entire File....... ...8713.5 Last Reading For Entire File...........10482 File Trailer" Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..... ..02/04/04 Maximum Physical Record..65535 File Type................ LO Next File NamB. ..........STSLIB.005 Phys:Lcal EOr Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing LibL.ary. Scientific Technical Services Reel Trailer Service name..... ..... ...LI8TPE Date.....................0:2/04/04 Origin. . . . . . . . . . . . . . . . . . . 81'S Reel Name................UNKNOWN (' Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ( Scientific Technical Services ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 04 08:29:01 2002 Reel Header Service name... ..........LISTPE Date.....................02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS ( aO/-aas I071o~ Writing Library. Tape Header Service name.............LISTPE Date.....................02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNK.NOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Scientific Technical Services Wei ting Library. Physical EOF Comment Record 'rAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 A.K-MM-11209 'I'. MCGUIRE R. ROSS ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD !\UN 4 AK-MM-11209 T. MCGUIRE G. RIZEK fI SURFACE LOCATION SECTION: TO\i\TNSHI P: RANGE;: FNL: FSL: FEL: FWL: ELEVA'l'ION (FT FROM MSL 0) KELLY BUSHING: DERRI CK FLOO!\: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 8.500 # REMARKS: Scientific Technical Services 3N-19 500292305600 PHILLIPS Alaska, Inc. Sperry Sun 04-APR-02 MWD RUN 2 AI{-MM-1l209 P. SMITH F. HERBERT 28 13N 9E 1561 .00 29.66 32.90 CASING SIZE (IN) 16.000 9.625 7.000 MWD RUN 3 AK-MM-11209 P. SMITH F. HERBERT 70 DRILLERS DEPTH (FT) 118.0 3640.0 8754.0 ( ( 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. "- . MWD RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. 1'1~'JD RUNS 2 - 4 .A.RE DIRECTIONAL WITH DUAL GANMA RAY (DGR) UTILIZING GEIGER NUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 3613' MD, 3586' TVD TO 3640' MD, 3612' TVD. GAMJltIA RAY (SC;RC) IS LOGGED BEHIND CASING FROM 8713' NO, 6458' TVD TO 8754' MD, 6461' TVD. 5. THE GAP IN GAMNA RAY (SGRC) FRON ~3516' MD, 6457' TVD TO 8713' MD, 6458' TVD IS DUE TO A GAMMA. RAY TOOL FAILURE. 6. 3N-19 IS TIED INTO 3N-19PBl AT THE KICKOFF POINT. 'T'HIS WELL KICKS OFF FROM 3N-19PBl AT 9475' MD, 6472' TVD. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. DATED 02/18/02. ALl, MWD LOG HEADER DATA RET.AINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1. - 4 REPRESENT' WELL 3N-19 WITH API # 50-103-20378-00. THIS WELL REACHED A TOTAL DEPTH OF 10515' MD, 6445' TVD. SROP ,= SMOoTHED RATE OF PENETRATION SGRD "" SMOOTHED GAMMI\ RAY 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 SPACINC;; ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM clipped curves; all bit runs merged. .5000 S'I'J\R'I' DE P'I'H 89.0 151. 0 3630.0 3630.0 3630.0 STOP DEP'I'H 10464.0 10515.0 10471.0 10471.0 10471.0 ( { RPS RPX $ 3630.0 3630.0 10471.0 10471.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 MERGE TOP 89.0 3663.0 8765.0 9475.5 1'1ERGE BASE 3662.0 8764.5 9475.0 10515.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1. 68 0 ROP MWD FT/J¡ I.[ 1 68 I~ GR MWD l\PI 4 1 68 8 RPX MT!I7D OHMM 4 :I 68 12 RPS MWD OHMM 4 1 68 16 RPIVI MWD OHMM 4 1 68 20 RPD MWD OHMM 4 1 68 24 FET MWD HR 4 1 68 28 Channel 1 2 3 5 6 7 8 F.:Lrst Last Name Service Unit Min Max Mean N,sam Reading Reading DEPT FT 89 10515 5302 20853 89 10515 ROP MltW FT/H 0.04 672.86 12tL 278 20729 151 10515 GR MWD API 16.36 441. 23 98.061.1 20357 89 10464 RPX MWD OHMM 0.53 1625.72 10.6658 13683 3630 10471 RPS MWD OHMM 0.53 2000 14.6333 13683 3630 10471 RPM MWD OHMM 0.51 2000 28.0734 13683 3630 10471 RPD MWD Ol-IMM 0.22 2000 2~~.662E) 13683 3630 10471 FET MTAìD HR 0.21 113.13 2.58075 13683 3630 10471 First Reading For Entire File..........89 Last Reading For Entire File........ ...10515 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO2 Physical EOr File Header Comment Record FILE HEADER FILE NUt-mER: RA!I'J M!I'JD Curves and log header data Ear each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 89.0 ROP 151.0 ( Service name.. ...........STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation...... .02/04/04 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl ., 1 .5000 STOP DEPTH 3613.0 3662.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE, VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-'I'IME:) : TD DRILLER (FT): TOP LOG INTERVA.L (F'I'): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGl,E: # TOOL STRING ('rOp TO BO'r'I' OM ) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING Dl-\'I'A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEP'rH (FT): # BOREHOLE CONDITIONS MUD 'TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT ME.ASURED TEMPERATUI\E (MT): MUD AT MAX CUZCULATTNC, 'rERMPERA'rURE: MUD FILTRATE AT M'I': MUD CAKE AT MT: NEUTRON TOOL MATRIX: MA'rRIX DENSI'I'¥: HOLE CORRECTION (IN): TOOL S'rJ\NDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specifi.cat:Lon Block Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefinéd (( 13-DEC-01 Insite 4.05.5 3.03 Memol:y 3662.0 .3 13.5 TOOL NUMBER TLG033 12.250 3640.0 Spud Mud 9.60 154.0 9.0 500 4.6 .000 91.000 .000 .000 .0 91.0 .0 .0 ( ( Frame Spacing.....................60 .1IN Max frames per record.............Undefined ,!\bsent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE E'T FT 1 68 0 1 ROP MWD010 FT/H 1 68 4 :2 GR MWD010 API 1 68 8 -:' First Last Name Service Unit Min Max Mean Nsam Reading Reading DE E'T FT 89 3662 1875.5 7147 89 3662 ROP [v[WD010 FT/H 0.27 672.86 148.463 7023 151 3662 GR MWD010 API 16.36 U9.79 77.9615 7049 89 3613 First Reading For Entire File..........89 Last Reading For Entire File...........3662 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 Fil e Type................ La Next File Name......... ..STSLIB.003 Physical EOF File Header Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 Fi 1 e Type................ La Previous File Name.......STSLIB.OO2 Comment Record FILE HEAD.ER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMA.RY VENDOR TOOL CODE GR RPM RPD RPS RPX FET Rap $ 3 header data for each bit run in separate files. 2 .5000 s'rART DEPTH 3613.5 3630.0 3630.0 3630.0 3630.0 3630.0 3662.5 STOP DE prrI-J 8516.0 8722.5 8722.5 8722.5 8722.5 8722.5 8764.5 JI LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTli1IARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLEE (FT): TOP LOG INTEEVAL (FT'): BOTTOM LOG INTERVAL (E"I'): BIT ROTATING SPEED (RPM): 24-DEC-Ol Insite 4.05.5 66.16 Memory 8765.0 !( HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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 'I'EMPERl-\'I'URE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT M'I': 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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Un1 ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 ROP MWD020 FT/II 4 1 68 4 GR MWD020 API 4 1 68 8 RPX MWD020 OHMM 4 1 68 12 RPS MWD020 OHMM 4 1 68 16 RPM HWD020 OHMM 4 1 68 20 RPD MWD020 OHMM 4 1 68 24 FET MWD020 HR 4 1 68 2 ~3 ( 15.::: 92.8 TOOL NUMBER PB02345HWRG6 PB02345HWRG6 8.500 8754.0 LSND 12.20 59.0 8.8 450 ~. ~ 2.000 .908 2.400 2.400 68.0 158.0 68.0 68.0 Channel 1 2 .3 5 6 '7 8 F:Lrst Last Name Service Uni t Mì.n Max Mean Nsam Reading Reading DEPT FT 3613.5 8'764.5 6189 10303 3613.5 8764.5 ROP Hwb020 F'r/H 0.4 552.17 128.306 1020!5 3662.5 8764.5 GR MWD020 API 36.34 441.;?3 115.081 9806 3613.5 8516 RPX HWD020 OHMM 0.53 1370.06 5.50956 10186 3630 8722.5 RPS IV¡WD020 OHMM 0.53 2000 6.5137 10186 3630 8722.5 RPM MWD020 OHMM 0.51 2000 B.95655 10186 3630 8722.5 RPD HWD020 OHHH 0.22 2000 10.3918 10186 3630 8722.5 FET HTÑD020 HR 0.21 109.33 1.92622 10186 3630 8722.5 First Reading For Entire File..........3613.5 (' Last Reading For Entire File... ........8764.5 File Trailer Service name..... ........8T8LI8.003 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation..... ..02/04/04 Maximum Physical Record..65535 Fi 1 e Type................ 1.,0 Next File Name. ........ ..8T8LI8.004 Physical EOF File Header Service name. ......... ...STSLI8.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation... ....02/04/04 Maximum Physical Record..65535 File Type................LO Previous File Name.. .....STSLIB.003 Comment Record FILE HEADER FILE NUI'1BER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE: GR FET RPD RPM RPS RPX ROP ( header data for each bit run in separate files. :3 .5000 START DEPTH 871:3.5 8723.0 8723.0 8723.0 8723.0 8723.0 8765.0 $ jl LOG HEADER DATA DATE LOGGED: SOFTWARE SURF.AGE SOFTWARE VER.3ION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERV1\L (FT): BIT ROTATING 8PEED (RPM): HOIÆ INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 9475.0 9475.0 947 5.0 9475.0 9475.0 9475.0 9475.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMt'\G. RESIS. 4 BOREI.¡OI.,.E AND C.AsING DlVrJ.\ OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DEN8ITY (L8/G): MUD VI8COSITY (8): MUD PH: HUD CHLORIDES (PPH): FLUID LOS8 (C3): 30-DEC-01 Insite 4.05.5 66.16 Hemory 9475.0 81. 5 103.1 TOOL NUMBER PB02367HAGRA PB02367HAGR4 6.125 Drill-N 9.80 49.0 8.5 450 4.0 \( (C RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .060 .034 .040 .060 74.0 136.4 74.0 74.0 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.....O Logging Direction..... ............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing....... ..............60 .1IN Max frames per record....... ......Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR ~1WD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 6 C5 1:2 RPS MWD030 OHMM 4 1 68 16 5 RPIv¡ IvIWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 F:L rst Last Name Service Unit M:Ln Max ME~an Nsam Reading Reading DEPT FT 8713.5 9475 9094.25 1524 8713.5 9475 ROP MíÑD030 FT/I-J 1. 92 194.66 86.251 1421 8765 9475 GR MWD030 API 37.71 119.87 90.3671 1524 8'713.5 947S RPX MWD030 OHMM 2.38 1399.73 18.9035 1505 8723 9475 RPS MWD030 OHMM 2.01 846.65 23.7035 1505 8723 9475 RPM MWD030 OHMM 6.46 2000 114.89 1505 8723 9475 RPD MWD030 OHMM 1.17 2000 72.7142 l~~Ot) 8723 9475 FET MíÑD030 HR 0.44 113.13 8.85616 1505 8723 9475 First Reading For Entire File..........8713.5 Last Reading For Entire File...........9475 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.... ...02/04/04 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF Fj.le Header Service name.............STSLIB.OO5 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.......02/04/04 Comment Record FILE HEADER FILE NUMBER: RAir.] MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ ( Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.004 5 4 .5000 START DEPTH 9475.5 9475.5 9475.5 9475.5 9475.5 9475.5 9475.5 STOP DEPTH 10471.0 10471.0 10471.0 10471.0 10464.0 10515.0 10471.0 # LOG HEADER DA.TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOF'l'WARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 'I'D DRILLER (F"r): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEl~ MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GJ-\JIllMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): Ii BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD V~SCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUEE (MT): MUD AT MAX CIECULATING TERMPERATURE: MUD FILT.RA'I'E AT M'T': MUD CAKE AT M'r: tI 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.....O Logging Direction. ................Down ( 02-JAN-02 Insite 4.05.5 66.16 Memory 10515.0 82.4 98.0 TOOL NUMBEE PB02367HAGE4 PB02367HAGE4 6.125 BARADEIL 10.20 48.0 8.5 81000 2.0 1.300 .671 2.000 2.200 70.0 142.0 70.0 70.0 ( ,1' ( Optical log depth units...........feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IK Max frames per record. .... ........Undefined Ab s en t val u e. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Uni t.s Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP I'fWD040 FT/H 4 1 68 4 GR MWD040 API 4 1 68 8 ~ RPX MlÑD040 OHMM 4 1 68 12 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 "7 fET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9475.5 10515 9995.25 2080 9475.5 10515 ROP tvlWDO 4 0 FT/H 0.04 269.91 813.7034 20BO 9475.5 10515 GR MWD040 API 52.5 157.58 91. 2435 1978 9475.5 10464 RPX MWD040 OHMM 1.9 1625.72 30.8086 1992 9475.5 10471 RPS MWD040 OHMM 3.02 1265.15 49.2994 1992 9475.5 10471 RPM MWD040 OHMM 3.75 992.4 60.2349 1992 9475.5 10471 RPD MWD040 OHMM 4 . O~~ 13[-)1.9tj 68.1995 1992 947 5.5 10471 FET 1'1TÑD040 HR 0.4 43.34 1.18648 1992 9475.5 10471 First Reading For Entire Fi1e..........9475.5 Last Reading For Entire File...........10515 F.11e Trailer Service name.............8T8LI8.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/04 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.... .........LISTPE Date.....................02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......Ol Next Tape Name........... TJNKNOW.N Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments. . . . .. . . . . . . . . . . . STS LIS 1i\1ri t:Lng LibJ.:'ary. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ( j: \