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Home My WebLink About201-2391. 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 11316'feet 7891' 10570', 10612'feet true vertical 6376'feet None feet Effective Depth measured 7891'feet 10592' feet true vertical 4737'feet 6049' feet Perforation depth Measured depth 11018-11028 feet True Vertical depth 6246-6250 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 10593' MD 6049' TVD Packers and SSSV (type, measured and true vertical depth) Packer SSSV Baker 80-40 SA None 10592' MD N/A 6049' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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: Dusty Freeborn Contact Email:dusty.freeborn@conocophillips.com Authorized Title: Well Integrity Engineer Contact Phone: (907) 265-6218 N/A Sr Pet Eng: 10540 Sr Pet Geo: Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MDSize 110' Length 82' 3045' N/A N/AN/A N/A N/AN/A N/A 10160 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-239 50-103-20398-00-00 P.O. Box 100630, Anchorage, Alaska 995083. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: 16" 9.625" ADL0380049/ADL0380052 Kuparuk River Field/Kuparuk River Oil Pool KRU 2L-03 Plugs Junk measured measured measured true vertical Packer 3073' 2417' TVD Production Liner 10728' 726' Casing 6127' 3.5" 10754' 11314' 6375' 110'Conductor Surface Burst Collapse 630 3090 5410 1640 5750 7240 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 12:00 pm, 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: 2025.09.25 09:33:43-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn J.Lau 11/5/25 RBDMS JSB 100225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 24, 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 for Kuparuk River Unit 2L-03 (PTD 201-239) Commissioner Chmielowski, Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. KRU well 2L-03 (PTD 201-239). A sundry for 2L-03 plug and abandonment has been approved but not yet executed, therefor the suspended well inspection was conducted as required. The following documents are attached: - 10-404 Sundry - Suspended Well Inspection Report - Wellbore Schematic - Location Plot Plan - Photographs Please contact Dusty Freeborn at (907) 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. 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: 2025.09.25 09:34:03-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,891.0 2L-03 5/25/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: TAG 2L-03 5/28/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/8/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 27.9 3,072.5 2,416.7 40.00 L-80 BTC PRODUCTION 7 6.28 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD LINER 3 1/2 2.99 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 10,592.7 Set Depth … 6,049.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 23.2 23.2 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 511.3 511.1 3.81 NIPPLE 4.540 CAMCO DS NIPPLE NO GO CAMCO DS 2.875 3,045.6 2,404.3 62.33 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,722.6 3,695.8 60.78 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 8,116.5 4,846.5 60.87 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 9,699.8 5,620.2 61.72 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 10,487.5 5,998.9 61.29 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 10,537.1 6,022.7 61.42 SLEEVE 5.750 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 10,553.6 6,030.6 61.43 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 10,591.5 6,048.7 61.47 SEAL ASSY 5.000 BAKER 80-40 LOCATOR SEAL ASSEMBLY BAKER GBH-22 CSA 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) 10,513.0 6,011.2 61.39 TUBING PUNCH 4' TUBING PUNCH 4/24/2015 2.992 10,570.0 6,038.4 61.45 PLUG 2.69" CIBP 4/23/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,045.6 2,404.3 62.33 1 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 5,722.6 3,695.8 60.78 2 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 8,116.5 4,846.5 60.87 3 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 9,699.8 5,620.2 61.72 4 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 10,487.5 5,998.9 61.29 5 GAS LIFT DMY BK5 1 1/2 0.0 2/20/2015 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) 10,588.1 6,047.1 61.46 PACKER 5.980 BAKER ZXP LINER PACKER w/ HR PROFILE BAKER ZXP 4.408 10,606.2 6,055.7 61.48 XO THREAD 5.550 4.400 10,606.9 6,056.1 61.48 NIPPLE 5.500 BAKER RS NIPPLE BAKER RS 4.250 10,608.9 6,057.0 61.47 XO THREAD 5.550 4.400 10,638.5 6,071.2 61.30 XO THREAD 5.550 2.937 11,217.3 6,333.0 64.06 LANDING COLLAR 3.500 BAKER TYPE 1 LANDING COLLAR BAKER TYPE 1 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,018.0 11,028.0 6,245.8 6,250.2 C-4, 2L-03 3/12/2002 6.0 IPERF 2.5" HSD 2505HJ RDX Chgs, 60 deg phase 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) 11,018.0 11,028.0 1 FRAC 3/26/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,612.0 11,137.6 6,058.5 6,298.0 Cement Plug 3/30/2015 7,891.0 10,517.0 4,737.0 6,013.1 Cement Plug 5/8/2015 2L-03, 9/24/2025 5:24:28 PM Vertical schematic (actual) LINER; 10,588.1-11,314.0 IPERF; 11,018.0-11,028.0 FRAC; 11,018.0 PRODUCTION; 25.5-10,753.5 Cement Plug; 10,612.0 ftKB PLUG; 10,570.0 TUBING PUNCH; 10,513.0 GAS LIFT; 10,487.4 GAS LIFT; 9,699.8 GAS LIFT; 8,116.5 Cement Plug; 7,891.0 ftKB GAS LIFT; 5,722.6 SURFACE; 27.9-3,072.5 GAS LIFT; 3,045.6 NIPPLE; 511.3 CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 27.61 RR Date 2/26/2002 Other Elev… 2L-03 ... TD Act Btm (ftKB) 11,316.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032039800 Wellbore Status PROD Max Angle & MD Incl (°) 64.32 MD (ftKB) 11,054.04 WELLNAME WELLBORE2L-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE “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.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copyingfor any other purpose or by any other party is prohibited without the express consent ofConocoPhillips Alaska, Inc.” Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/29/2025 InspectNo:susSTS250908112717 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:2/21/2015 #315-043 Tubing:0 IA:0 OA:340 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV UNIT 2L-03 Permit Number:2012390 Wellhead Condition Well head is outside. No major corrosion, valves turned easily, disconnected from flowline Surrounding Surface Condition clean, no subsidence Condition of Cellar dry gravel in cellar, grating covering cellar in good condition Comments Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (2) attached 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_2L-03_photos_ss Page 1 of 1 Suspended Well Inspection – KRU 2L-03 PTD 2012390 AOGCC Inspection Rpt # susSTS250908112717 Photos by AOGCC Inspector S. Sullivan 9/6/2025 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: Suspension Renewal 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11316'None 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-1513 Staff P&A Engineer KRU 2L-03 6376' 7891' 4737' 10570' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Joey.Roth@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10592' MD and 6049' TVD N/A Joey Roth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380049, ADL0380052 201-239 P.O. Box 100360, Anchorage, AK 99510 50-103-20398-00-00 Kuparuk River Field Kuparuk River Oil Pool - Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool - Abandoned TVD Burst 10592' MD MD 110' 2417' 110' 3073' 6127'10754' 16" 9-5/8" 82' 3045' 11018-11028' 10728' 3-1/2" 6246-6250' 7" Perforation Depth TVD (ft): 6/15/2025 11314'726' 3-1/2" 6375' Packer: Baker 80-40 Seal Assy SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Joey Roth Date: 2025.05.22 09:01:36 -08'00' 325-319 By Grace Christianson at 9:25 am, May 22, 2025 DSR-6/3/25 X 10-407 AOGCC witness tag TOC and MIT AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut and marker plate. X SFD 8/11/2025JJL 8/11/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.11 14:33:30 -08'00'08/11/25 RBDMS JSB 081225 May 21, 2025 Final 2L-03 P&A Detailed Procedure Joey Roth (713.203.7428) May 15, 2025 Sundry # Objective: Full abandonment of Well: KRU 2L-03 (PTD 201-239). Well History: KRU 2L-03 was a Long Term Shut In (LTSI) well that was originally drilled as a C-sand producer in 2002. The well did not produce as expected and was shut in. The lease expired for the bottom hole location of 2L-03 (ADL 390680) during the LTSI. The well was approved for suspended status in August 2015 after successfully setting and testing two cement plugs (Sundry #315-043). The Ʊrst plug isolated the perforations, and the second plug isolated the TBG & TBG /IA. The 2L-03 Plug Back TD is 7891’ MD / 4737’ TVD. The well was inspected in June of 2020, and the suspension was renewed for 5 yrs. On March 31, 2025, ConocoPhillips Alaska submitted a suspension renewal request for 2L-03. This request was denied for the suspension renewal. The 2L-03 well bore has no future utility, Conoco Phillips Alaska would like to proceed with permanent plug and abandonment. Current Well Status: The producing sands in this well have been isolated from all communication with the surface in 2015 (see attached schematic and 10-403 form). The Ʊrst plug is set across the perforations which isolate the well bore from the reservoir, and the second plug isolates the TBG & TBG /IA. The plugs were tested, witnessed and passed the MIT and drawdown testing on the Tbg & IA. The TBG TOC was tagged at 7891’ MD RKB WL (wire line). This work was done in 2015 and approved (Sundry #315-043). The most recent tag on slick line was 5/25/2015. The well was circulated to seawater with a diesel freeze protect in the tubing and IA. The gas lift valves are dummied oƯ. The OA has cemented shoe. The surface casing cement job had full cement returns to surface with an FIT 16 ppg eMWT. Pressures were taken 5/17/2025: T/I/O = 0/0/270 psi (shut in pressures). OA FL at surface. No well house is over the 2L-03, and the cellar is full of snow. The conductor casing is not visible at the present time. Reservoir Information: - Last SBHP taken on 2/18/2015: Kuparuk C Reservoir pressure 3893 psi @ 6101’ ssTVD / 11018’ MD. o 0.638 gradient (12.3 ppg eMWT) - Freshwater Zones: None - Hydrocarbon Bearing Zones: o Torok: ~ 9998’ – 10,032’ MD o Seabee: ~ 8495’ – 8515’ MD & 7640’ – 7770’ MD o Schrader BluƯ: ~ 3265’ – 3280’ MD (uncemented behind production casing)* * Though the density log shows some porosity within the interval 3265' 3280' MD, the GR curve suggests it contains only about 6' MD (< 3' TVD) of sand. Corresponding deep resistivity curve that does not exceed 6.4 ohm-m. So, although there are likely some small amounts of hydrocarbons present, I wouldn't classify this thin sand or the surrounding interval as a significant hydrocarbon-bearing interval. Accordingly, I don't consider additional cementing of this interval as warranted. SFD. uncemented 12.3 ppg eMWT *The AOGCC wouldn’t classify this thin sand or the surrounding interval as a significant hydrocarbon-bearing interval and don’t believe this interval requires additional cementing. - JJL May 21, 2025 Final Useful Information from Drilling Report: a. Information: the base of the permafrost is 1746’ MD / 1652’ TVD. b. Information: This well was directionally drilled in the surface section of the well. i. KOP: 300’ MD / TVD ii. EOB: 2581’ MD / 2187’ TVD iii. Inclination: 61.8° iv. Surface Casing Cement: Cement Returns to Surface, Bumped Plug, FIT 16 ppg. Current Tubular Detail: String (OD) Top (ft) Bottom (MD / TVD) Size / Weight / Grade / Conn ID BBL / Ft Ft / BBL Volume (BBL) 3.5” (TBG) 0 7891’ / 4737’ 3.5”,9.3# / L-80 / EUE 8rnd 2.99” 0.0087 114.94 68.7 7” x 3.5” (IA) 0 7891’ / 4737’ 7”, 26# / L80 / BTC-MOD 6.28” 0.0264 37.86 208.4 9 5/8” x 7” (OA) 0 3072’ / 2416’ 9 5/8” / 40# / L80 / BTC 8.83” 0.0281 35.53 86.5 Planned P&A Program: 1. MIT-T & IA to 2500 psi to conƱrm tubing & plug back integrity. Slickline: 2. Drift TBG (min. 2.5” OD) and Tag TOC @ 7891’ MD / 4737’ TVD 3. RIH w/ TBG punch: 25’ above Tag ±7866’ MD and punch hole in the TBG. 4. RU Pump & test lines: T & IA w/ 9.0 ppg water base kill weight Ʋuid: Ѹ300 bbl. 5. Set CIBP in TBG @ 3450’ MD / 2594’ TVD 6. Pressure test CIBP to 2500 psi / 15 min. If the TBG pressure test passed. Proceed to step #11. Contingency for failed CIBP test: a. RIH w/ dump bailer, spot 1 bbl. of 15.8 ppg Class G cement on top of plug. b. POOH c. WOC – 24 hrs. d. RU and Pressure test TBG plug to 2500 psi / 15 min. e. RIH on slickline w/ 2.72 GR & chisel cutter, tag TOC @ ±3335’ MD wl. f. POOH Eline 7. RIH on eline w 2” RTG (max swell 2.19”) / 4 spf / zero phase – perforate tubing @ ± 25’ above TBG plug back depth Ѹ 3425’ MD. Displace Wellbore to Kill Ʋuid May 21, 2025 Final 8. RU Pump, Test lines and establish a circulation rate w/ 9.0 ppg water base kill weight Ʋuid. Set Intermediate Balanced Cement Plug 9. RU Cement Unit and test lines to set Intermediate abandonment plug: a. Mix and Pump cement: 30 bbl., Class G 15.8 ppg w/ gas block additive. b. Displace the cement with 9.0 ppg water base kill weight Ʋuid down TBG. Over displace cement to set a balanced plug. Planned TOC @ 2722’ MD / 2254’ TVD. c. WOC – min 12 hrs. d. If there is going to be a time gap between setting the intermediate cement plug and the surface plug, we will need to consider the time of year and freeze protection. If freezing is a concern the Ʊnal displacement for the intermediate cement job should be done with diesel. Discuss with Engineer prior to starting the job. Slickline: Test and Tag Intermediate Plug 10. RU slickline: Drift (min. 2.5”) and tag TOC. TOC is expected to be left at 2722’ MD / 2254’ TVD (State witnessed). 11. If tagged ±100’ than 2722’ MD call the Engineer or Field Superintendent. 12. RD slickline & RU to pressure test T / IA (using 9.0 ppg water base kill weight Ʋuid) 13. MIT-T/IA to 2500 psi / 30 min. (State-witnessed). E-Line: Perforate T/IA/OA and Establish Circulation: T/IA/OA: 14. RIH w/ 2” RTG-2125-402F (maximum swell is 2/19”): This gun is planned for penetrating the Tubing and the IA. a. Perforate 30’, 6 spf, 60 deg phasing, eccentered @ 500’ MD / TVD, space out in middle of a tubing joint between collars. 15. RU Pump & test lines to 2500 psi w/ 9.0 ppg KWT Ʋuid. a. Establish circulation down the tubing up the IA staging up the pump to 3bpm or 2500 psi. Circulate hole clean while maintaining <2500 psi circulating pressure: target rate 3 – 5 bpm. b. Establish circulation down the tubing up the OA at 3 bpm or 1800 psi. c. Circulate clean allowing pressures to stabilize. d. If circulation is not established at 2 bpm at the above pressures, plan to reperforate with 30’ of 2” RTG- 2125-402F, 6 spf, 60-degree phasing, at 450’ MD / TVD. e. Note any losses from 1:1 returns while pumping down the tubing and taking returns up the OA. Set Surface Cement Plug: 16. Pump the following down the tubing and up the OA: a. 5 bbl. FW spacer b. 28 bbl. of cement. (18.5 bbl. capacity from Tubing to OA surface + 50% excess). c. Check that clean cement is observed at the surface from the OA. d. If clean cement at surface is not conƱrmed from the OA, pump an additional 5 bbl. of cement for a total of 33 bbl. 17. Swap valves to take returns up the IA (on the Ʋy). 18. Continue pumping down the tubing, now taking returns up the IA: a. Pump 27 bbl. of cement (17.6 bbl. Cement to surface in IA + 50% excess). b. Check that clean cement is observed at surface from IA. c. If clean cement is not conƱrmed in returns from the IA, pump an additional 5 bbl. of cement for a total of 32 bbl. 19. Shut down pump, Shut in the well. 20. Wait on cement 48 hours. Check for trapped pressure. Open well to atmosphere. May 21, 2025 Final 21. Call out AOGCC to witness after the string cutoƯ and before any cement top job. 24-hour notice required. 22. Send the casing head stub to the materials shop. Photo document. 23. Inspect the cement job in the T/I/O with the AOGCC witness. a. Perform a cement top job if needed to ensure cement is at surface on all strings. 24. Call AOGCC to witness cap welded label (24-hour notice required). 25. Weld a ¼” thick cover plate (16” OD) over all the casing strings with the following bead welded label. AOGCC witness is required. a. Conoco Phillips b. 2l-03 c. PTD#: 201-239 d. API#: 50-103-2039800 26. Photograph cap welded label. 27. Remove the cellar and backƱll with gravel as needed to ground level. 28. Obtain site clearance approval from AOGCC. 29. Provide photo documentation to the engineer for preparation of the 10-407. Contingency Cement Top Job Post Casing Cut Procedure: 1. Install spill containment such as the Katch-Kan liner around the conductor. 2. Use a pump truck with 1” hose and nozzle for thawing out any frozen mud or ice. a. Circulate hot water down annulus and take returns into the spill containment or vac truck. Snake the hose down the annulus and thaw as far as required. 3. Run 1” schedule 80 pipe into annulus down as far as required. Hang oƯ pipe and attach crossover from 1” pipe to 2” Weco. 4. Mix on the Ʋy enough Arctic Set I or permafrost formulated Class G cement to Ʊll annulus to surface. Make sure to suck returns with vac truck until good cement is at surface. 5. Below is an example of Arctic set Cement that is acceptable for a top job: - Volume to Pump Calculated volume to Ʊll annulus to surface - Cement Type 15.7 ppg Arctic Set 1 - Rheology PV of 50-80 cp - Yield Point TY < 15 lb. / 100 ft 2 - Compressive 2000 psi ultimate - Thickening Time ~ 3 hours WARNING: Arctic Set I is a thixotropic cement and if it stops moving it may set up. Once the cement is being pumped make eƯorts to keep the cement moving via the pump. 6. Mix and pump on the Ʋy cement down line pipe taking returns up annulus and into spill containment or directly into a vac truck. 7. When clean cement returns are seen at surface, open divert valve to Ʋush extra cement and water cleanup out to dirty vac truck that has contaminant on board. 8. Monitor annulus to make sure cement does not fall. 9. Clean up cementers, the line pipe will remain in the annulus. Once the cement reaches compressive strength cut the pipe Ʋush with the casing cuts and continue with welding on marker plate. 50-103-20398-00-00 SFD May 21, 2025 Final Conductor 110’ 110’ 16” 15.062” 62.5 ppf H-40 Surface 3072.5’ 2416.7’ 9.875” 8.835” 40 ppf L-80 Production Plug Back TD 7891’ 4737’ 7” 6.276 26 ppf L-80 Liner Plug back TD 10588.1’ 6047.1’ 3.5” 2.992 9.3 ppf L-80 Tubing 7891’ 4737’ 3.5” 2.992 9.3 ppf L-80 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,891.0 2L-03 5/25/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: TAG 2L-03 5/28/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/8/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 27.9 3,072.5 2,416.7 40.00 L-80 BTC PRODUCTION 7 6.28 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD LINER 3 1/2 2.99 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 10,592.7 Set Depth … 6,049.3 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 23.2 23.2 0.00 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 511.3 511.1 3.81 NIPPLE 4.540 CAMCO DS NIPPLE NO GO CAMCO DS 2.875 3,045.6 2,404.3 62.33 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,722.6 3,695.8 60.78 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 8,116.5 4,846.5 60.87 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 9,699.8 5,620.2 61.72 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 10,487.5 5,998.9 61.29 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 10,537.1 6,022.7 61.42 SLEEVE 5.750 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 10,553.6 6,030.6 61.43 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 10,591.5 6,048.7 61.47 SEAL ASSY 5.000 BAKER 80-40 LOCATOR SEAL ASSEMBLY BAKER GBH-22 CSA 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) 10,513.0 6,011.2 61.39 TUBING PUNCH 4' TUBING PUNCH 4/24/2015 2.992 10,570.0 6,038.4 61.45 PLUG 2.69" CIBP 4/23/2015 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,045.6 2,404.3 62.33 1 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 5,722.6 3,695.8 60.78 2 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 8,116.5 4,846.5 60.87 3 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 9,699.8 5,620.2 61.72 4 GAS LIFT DMY BK5 1 0.0 2/26/2002 0.000 10,487.5 5,998.9 61.29 5 GAS LIFT DMY BK5 1 1/2 0.0 2/20/2015 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) 10,588.1 6,047.1 61.46 PACKER 5.980 BAKER ZXP LINER PACKER w/ HR PROFILE BAKER ZXP 4.408 10,606.2 6,055.7 61.48 XO THREAD 5.550 4.400 10,606.9 6,056.1 61.48 NIPPLE 5.500 BAKER RS NIPPLE BAKER RS 4.250 10,608.9 6,057.0 61.47 XO THREAD 5.550 4.400 10,638.5 6,071.2 61.30 XO THREAD 5.550 2.937 11,217.3 6,333.0 64.06 LANDING COLLAR 3.500 BAKER TYPE 1 LANDING COLLAR BAKER TYPE 1 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,018.0 11,028.0 6,245.8 6,250.2 C-4, 2L-03 3/12/2002 6.0 IPERF 2.5" HSD 2505HJ RDX Chgs, 60 deg phase 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) 11,018.0 11,028.0 1 FRAC 3/26/2002 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,612.0 11,137.6 6,058.5 6,298.0 Cement Plug 3/30/2015 7,891.0 10,517.0 4,737.0 6,013.1 Cement Plug 5/8/2015 2L-03, 5/21/2025 5:32:13 PM Vertical schematic (actual) LINER; 10,588.1-11,314.0 IPERF; 11,018.0-11,028.0 FRAC; 11,018.0 PRODUCTION; 25.5-10,753.5 Cement Plug; 10,612.0 ftKB PLUG; 10,570.0 TUBING PUNCH; 10,513.0 GAS LIFT; 10,487.4 GAS LIFT; 9,699.8 GAS LIFT; 8,116.5 Cement Plug; 7,891.0 ftKB GAS LIFT; 5,722.6 SURFACE; 27.9-3,072.5 GAS LIFT; 3,045.6 NIPPLE; 511.3 CONDUCTOR; 28.0-110.0 KUP PROD KB-Grd (ft) 27.61 RR Date 2/26/2002 Other Elev… 2L-03 ... TD Act Btm (ftKB) 11,316.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032039800 Wellbore Status PROD Max Angle & MD Incl (°) 64.32 MD (ftKB) 11,054.04 WELLNAME WELLBORE2L-03 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1 From:Lau, Jack J (OGC) Sent:Monday, August 11, 2025 10:51 AM To:Joey.Roth@conocophillips.com Subject:RE: KRU 2L-03 P&A (201-239) Joey – The AOGCC wouldn’t classify this thin sand or the surrounding interval as a signiĮcant hydrocarbon-bearing interval, so we don’t believe this interval requires addi Ɵonal cemenƟng. Let us me know if you have any thoughts or addi Ɵonal supporƟng informaƟon. Jack From: Lau, Jack J (OGC) Sent: Wednesday, August 6, 2025 4:05 PM To: Joey.Roth@conocophillips.com Subject: RE: KRU 2L-03 P&A (201-239) Joey – I would suggest taking a second look at this interval to verify it is truly a signiƱcant hydrocarbon bearing interval. Thanks, Jack From: Lau, Jack J (OGC) Sent: Tuesday, August 5, 2025 2:58 PM To: Joey.Roth@conocophillips.com Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: KRU 2L-03 P&A (201-239) Joey – I’m reviewing your sundry for 2L-03 P&A. I see the Shrader at ~3265-3280’ is hydrocarbon bearing and uncemented. Plugging must be performed in a manner that ensures that all hydrocarbons and freshwater are conƱned to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The procedure in the sundry application does not address this issue. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice 2 (907) 227-2760 Cell From:Roth, Joey To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request Date:Thursday, June 19, 2025 1:48:05 PM Attachments:2L-03 TOC calculations.xlsx Stephen, Unfortunately, I was unable to find the log. I have attached the hand calculations based on data taken from the drilling report volumes pumped. Please let me know how we should proceed. Thank you, Joey From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, June 16, 2025 7:51 AM To: Roth, Joey <Joey.Roth@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request Hello Joey, On CPAI’s application form, the Estimated Date for Commencing Operations is listed as 6/15/2025, and this date is driving my task-list priorities. The requested CBL is needed to complete my portion of AOGCC’s review. If this estimated date has changed, could you please provide a revised date so that I can prioritize my work accordingly? Thanks for your help, Steve Davies AOGCC From: Roth, Joey <Joey.Roth@conocophillips.com> Sent: Monday, June 16, 2025 7:25 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request Stephen, I have the log files for the well but am unable to open them. I am still working this issue: finding one of the petrophysics folks that can help me. The log noted on the report was Sono scope (Schlumberger) which I am unable to open. I am talking with Schlumberger about the options I have for them to produce a readable copy. What is my deadline to get this to you? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content Thanks, From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, June 13, 2025 2:00 PM To: Roth, Joey <Joey.Roth@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request Joey, Any progress with this CBL image? Thanks, Steve Davies AOGCC From: Davies, Stephen F (OGC) Sent: Wednesday, June 11, 2025 3:35 PM To: Roth, Joey <Joey.Roth@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request Thanks Joey. I appreciate your help. Steve Davies AOGCC From: Roth, Joey <Joey.Roth@conocophillips.com> Sent: Wednesday, June 11, 2025 3:33 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request is safe. Hello Steve, Just wanted to let you know that I am looking for a digitized copy of the log to send you. I will send it over as soon as I get the .tif file converted. Thank you and have a great Day, Joey From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, June 10, 2025 8:15 AM To: Roth, Joey <Joey.Roth@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]KUPARUK RIV UNIT 2L-03 (PTD 201-239, Sundry 325-319) - Information Request CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Joey, I’m reviewing CPAI’s Sundry Application for KRU 2L-03, and I noticed that the accompanying wellbore schematic drawing indicates a Soniscope log was run in this well during 2002. I would like to confirm the cement top of 3,950’, and I don’t see a copy of this log in AOGCC’s well log inventory. Could CPAI please provide a digital image of that log in .pdf format? Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 04/29/2025 InspectNo:susAGE250331131822 Well Pressures (psi): Date Inspected:3/31/2025 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:2/21/2015 #315-043 Tubing:10 IA:0 OA:271 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Bruce Richwine Date AOGCC Notified:2/26/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV UNIT 2L-03 Permit Number:2012390 Wellhead Condition Clean, in goodworking condition. Surrounding Surface Condition Snow covered , clean Condition of Cellar clean from debris other than snow Comments Location Verified by pad map / Inspection done in winter conditions due to renewal of Suspended status. Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, April 29, 2025 9 9 9 9 9 9 9 9 9 9 9 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from dusty.freeborn@conocophillips.com. Learn why this is important From:Regg, James B (OGC) To:Freeborn, Dusty Cc:Livingston, Erica J; Loepp, Victoria T (OGC); DOA AOGCC Prudhoe Bay Subject:RE: 2L-03 (PTD 201-239) Inspection for suspended well renewal question Date:Wednesday, March 26, 2025 2:46:00 PM Attachments:image001.png Your proposal is acceptable. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Wednesday, March 26, 2025 2:06 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: 2L-03 (PTD 201-239) Inspection for suspended well renewal question Hi Jim- I wanted to address an issue with an upcoming suspended well renewal. 2L-03 (PTD 201-239) was originally suspended in June of 2015 and therefor is due for renewal come June 2025. The application for suspension renewal is being submitted 60 days prior to the expiration date to meet the criteria of 25.110. However, the well currently does not have a well house allowing the surrounding area to be covered in snow which complicates meeting the requirements of Industry Guidance Bulletin 21-002A. Would it be acceptable to conduct the initial renewal inspection in the current condition and then a follow up inspection be completed once the snow has melted from the surrounding area. CPAI recognizes the criteria of 21-002A and will ensure all upcoming suspended well inspections be conducted during the summer months to ensure the surrounding areas are free from snow and ice. Thank you for the guidance on this issue and please feel free to reach out to me if additional information is needed. .58/ 37' Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 ')v 1- 2 �61: 1555 SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7T" SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: 2L-03 3093 - 11316 7 Boxes SENT BY: M. McCRACKEN DATE: June 28, 2024 AIR BILL: N/A CPAI: CPA12024062803 CHARGE CODE: N/A NAME: 2L-03 NUMBER OF BOXES: 7 Boxes UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN: MIKE McCRACKEN Mike.mccracken@conocophillips.com RECEIVED: RECEIVED JUN 2 8 2024 AOGCC CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McCracken, Mike M To:Guhl, Meredith D (OGC); Anderson, Kelsey Subject:RE: [EXTERNAL]KRU 2L-03, PTD 201-239, Samples required but not submitted Date:Wednesday, June 26, 2024 1:24:41 PM Hi Meredith, I’m not sure why DAN (I can blame him as he has retired) didn’t send these. I’ll get these together and bring them over along with the three 1H-112 wells. I’ll have these to you Friday afternoon. Cheers, Mike McCracken Data Imaging & Geological Tech Technical Data Management 9/80 ‘A’ Shift 907-265-6340 Office 907-980-0611 Cell From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, June 26, 2024 11:00 AM To: McCracken, Mike M <Mike.Mccracken@conocophillips.com>; Anderson, Kelsey <Kelsey.Anderson@conocophillips.com> Subject: [EXTERNAL]KRU 2L-03, PTD 201-239, Samples required but not submitted CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Kelsey and Mike, I’m following up on missing cuttings from KRU 2L-03, API 50-103-20398-00-00, PTD 201-239. I’m reviewing the well history file, samples were required on the approved Permit to Drill (see attached) and should’ve been submitted. I see that a mudlog was collected on this well during drilling, but no samples were submitted to the AOGCC. Unfortunately this wasn’t caught in 2002 as it should’ve been. Can you please locate these required samples and submit them as soon as possible to the AOGCC? Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. ! 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" +- "" ( . 6!3 "#$,% $& '% Suspended Well Inspection Review Report InspectNo: susBDB200517132150 g5(zow Date Inspected: 5/16/2020 Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: KUPARUK RIV UNIT 2L-03 Date AOGCC Notified: 4/27/2020 Permit Number: 2012390 Operator: ConocoPhillips Alaska, Inc. Suspension Approval: Sundry 4 315-043 - Operator Rep: Roger Winter Suspension Date: 2/21/2015 Wellbore Diagram Avail? ❑D Location Verified? ❑O Photos Taken? ❑� If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 10 BPV Installed? ❑ OA: 280 VR Plug(s) Installed? ❑ Wellhead Condition The wellhead looked to be in good condition and all the valves worked properly and had gauges on them. Condition of Cellar Full of snow Surrounding Surface Condition The surrounding areas covered in snow - no wellhouse. Comments Location Verified by as -built pad map. Supervisor Comments Photos (2). Location should be free of snow and ice for suspended well inspection. Friday, lune 5, 2020 Suspended Well Inspection — KRU 2L-03 PTD 2012390 Photos by AOGCC Inspector B. Bixby 5/16/2020 2020-0516_Suspend_KRU_2L-03�hotos_bb.doex Page I of I Well Name: 2L-03 1 API Number: 50-103-2039800-00 PTO: 201-239 Sur. Lesalion: 144' FNL, 544' FEL. Sec. 22, T10N, OiF, 0M - r STATE OF ALASKA • ALLKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casing 9 Change Approved Program Rug for Redrill Perforate New Pool Repair Well r Re-enter Susp Well "" Other:Susp Well Insp f 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IV Exploratory r 201-239 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20398-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380049/ADL0380052 KRU 2L-03 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 11316 feet Plugs(measured) None true vertical 6376 feet Junk(measured) None Effective Depth measured 7891 feet Packer(measured) 10592 true vertical 4737 feet (true vertical) 6049 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 1640 630 SURFACE 3045 9-5/8 3073 2417 5750 3090 PRODUCTION 10728 7 10754 6127 7240 5410 LINER 726 3-1/2 11314 6375 10160 10540 RECEIVED depth: Measured depth: 11018-11028 NO' EW True Vertical Depth: 6246-6250 SC�� AUG 1 2 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 10592 MD, 6049 TVD AOGC Packers&SSSV(type,MD,and TVD) PACKER= BAKER 80-40 LOCATOR SEAL ASSEMBLY @ 10592 MD and 6049 TVD SSSV=CAMCO DS NIPPLE @ 511 MD and 511 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 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 X X X X X Subsequent to operation X X X X X 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development p Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Martin Walters/MJ Loveland Email n1878(a�cop.com Printed Name Martin Walters Title Well Integrity Supervisor Signature 1° ( ‘6,t, 77 JA Phone:659-7043 Date:Aug 7, 2015 v'rL 'i/2./15 RBDMSi AUG 1 4 2015 Form 10-404 Revised 5/2015 Submit Original Only • . 11.7 ConocoPhillips Alaska REG P.O. BOX 100360 AUG 12 2015 ANCHORAGE,ALASKA 99510-0360 EIVED AOGCC August 7, 2015 Commissioner Cathy Foerster 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 2L-03 (PTD 201-239) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2L- 03 (PTD 201-239). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, 1774//7/-1-, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2L-03 Field/Pool: KUPARUK RIVER Permit#(PTD): 201-239 Sundry 315-043 API Number: 50-103-20398-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 2/21/2015 Surface Location: 143 N, 544 E Section: 22 Township: 10 N Range: 7E Nearest active pad or road: DS2L Meridian: UM Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good. Clean gravel Pad or location surface: Good Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water/fluids on pad: NA Discoloration, Sheens on pad, pits or water: NA Samples taken: None Access road condition: Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Good. Small amount of water Rat Hole: NA Wellhouse or protective barriers: Wellhouse removed for summer Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 Annulus pressures: 0/250 Wellhead Photos taken (#and description): 2 of wellhead and cellar Work Required: None �J �,,� Operator Rep (name and signature): Martin WaltersG � l G'(d ,44 AOGCC Inspector: Johnnie Hill Other Observers: Inspection Date: 7-Aug-15 AOGCC Notice Date: 3-Aug-15 Time of arrival: 9:00 AM Time of Departure: 9:15 Site access method: Passenger Truck • KUP PROD • 2L-03 CotlocoPhillipsWell Attributes Max Angle&MD TD Alaska.I;w. Wellbore APIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) crmrrmtnps 501032039800 KUPARUK RIVER UNIT PROD 64.32 11,054.04 11,316.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2L-03,5/28/20156.15.15 PM SSSV:NIPPLE Last WO: 27.61 2/26/2002 Venial schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'RKB 7,891.0 5/25/2015 Rev Reason:TAG lehallf 5/28/2015 HANGER',232 ir Casing Strings .9 'F Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED Casing Description -OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 27.9 3,072.5 2,416.7 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(L..Grade Top Thread PRODUCTION 7 6.276 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth)T/D)...WULen(I...Grade Top Thread LINER 31/2 2.992 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Liner Details .AA!CONDUCTOR;28.0-110.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl p) Item Des Com lin) NIPPLE;511.3 ;I 10,588.1 6,047.1 61.46 PACKER BAKER ZXP LINER PACKER w/HR PROFILE 4.408 10,606.9 6,056.1 61.48 NIPPLE BAKER RS NIPPLE 4.250 10,609.6 6,057.4 61.47 HANGER BAKER FLEX LOCK II DG HYD ROT LINER 4.400 HANGER 10,619.0 6,061.8 61.41 SBE SBE 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT;3,045.6 Tubing Strings I Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 23.2 10,592.7 6,049.3 9.30 LOU- EUE8RD Completion Details Nominal ID SURFACE;27.9-3,0725- . Top(ft8B) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 23.2 23.2 0.00 HANGER FMC GEN V TUBING HANGER 3.500 11 511.3 511.1 3.81 NIPPLE CAMCO DS NIPPLE NO GO 2.875 GAS LIFT;5,722.6 - 10,537.1 6,022.7 61.42 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 10,553.6 6,030.6 61.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,591.5 6,048.7 61.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,116.5 a Top(TVD) Top Incl Top(ftKB) (ftKB) I°) Des Com Run Date ID pill 10,513.0 6,011.2 61.39 TUBING 4'TUBING PUNCH 4/24/2015 2.992 s PUNCH M 10,570.0 6,038.4 61.45 PLUG 2.69"CIBP 4/23/2015 0.000 n Perforations&Slots Shot Dens GAS LIFT;9,699.8E at Top(TVD) Btm(ND) )shotslf Top(ftKB) Btm(ftKB) (NAB) (ftKB) Zone Date t) Type Corn $d 11,018.0 11,028.0 6,245.8 6,250.2 C-4,2L-03 3/12/2002 6.0 IPERF 2.5"HSD 2505HJ RDX Chgs,60 deg phase 111 Stimulations&Treatments GAS LIFT.10,48?.4 Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) a. (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com , 11,018.0 11,028.0 6.245.8 6,250.2 FRAC 3/26/2002 C-SAND FRAC NZc a Cement Squeezes TUBING PUNCH;10,5130v - L:,.. Top(ND) Btm(ND) Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Des Start Date Com 10,612.0 11,137.6 6,058.5 6,298.0 Cement Plug 3/30/2015 lay in 6bbl of 15.8 ppg class G cement 7,891.0 10,517.0 4,737.0 6,013.1 Cement Plug 5/8/2015 Fullbore 82bbls,15.8 ppg,class G,tubing and IA SLEEVE;10,537.1 1I 1 Mandrel Inserts St ati NIPPLE;10,553.6 N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Motlel OD(in) Sery Type Type (in) (psi) Run Date Com :r; 3,045.6 2,404.3 CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002PLUG;10,570.0 M 2 5,722.6 3,695.8'CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 M 3 8,116.5 4,846.5 CAMCO KBUG- M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 1 ,C r SEALASSY;10,591.5 _ 4 9,699.8 5,620.2 CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 M 11 1=1 IiG 5 10,487.5 5,998.9 CAMCO MMG 1 1/2 GAS LIFT DMY BK5 0.000 0.0 2/20/2015 Notes:General&Safety ' End Date Annotation 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;25.5-10,753.5-. FRAC;11,018.0 IPERF;11,018.0.11,028.0 I II LINER;10,588.1-11,314.0 • • CVC.1 F- z o Z W —03 o w re Lil o of z JWWI O o v O a O JtYQ W F F �o z F F Ce K I - - - w 0CI� J w w cola a w a m F iioz 31 ? W O xCD iii ,._ W 1111 = r: a. O < F--- ' M L .., a 19-41 it' CN Er IIVX f�+ •*f ff.f ff </< 0 .1 o m • 40 1'�♦ IW • ♦ o -'p .Q J Kr O O_ �. .*.f.f . ^O?i . iff' ;'f . 0 w d Q . X CN `f'f• a g. Ct In NE o L • UL C'.'i; o 0_ fff M M \ ` m o CD . c� - —' in t 2, V1 6 fl a • .f syo ■_ '1.1_�.a y t ox f O 4�� W� W Y.�. 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N ka, Inc. and This photo is copyrighted by cannot be releasedConocoPhiflipsAlasor published %7t"-.•4.:i;".t:0'.74;,.•,,::#.-t71r,-1,'A.."$,.,„.--',„',,,,•,,,.,f.'--.,.-''l''''.'4...i0.{,r''0''0r"..''4,..4,.',,*,.',',..,',('..T,'';.,,'„-.:';.'0''.'44'''''','„''.:''.;'.,„.-''.,,.,.',:,7'N',.,'...g',,"''.,'!,''...',...,..'.,,:4:''-''''::.','',,'':'11'':',,1s-,!7,•,',','i,•.,,1N,,4,„4,'o,,',.,',i'',A,P..„":4,l4i,,--1,,:,.o:p........it1,'4t'ii1'.-;:;.t',•:•',.,,.,,i'-,4'-1-',-.,'.,,-''-,''4• ',--.--,-. ...w thout express written consent „ . @ k'r'. ConocoPhilulips Alaska 0 ,mss ��"� � eye"4 • ;„ a U . C6 fi ti 0 Q' OW.111/111. . ' 0 S3 - Q , 0 _ , N O F— v O n— 0 . .. " = IMO/ 1,4., ..... '0 - — Will 1111111111111 ' ''''— ili - :1410.411,1611 MI' Aid 1.--0,4...,.........,,,,,,,,t,,,,,,,.....„.„....,„,„„...r........,...a,, Muras ...r.a .u. ILW:a.:1134* r.lEa rruru..ai.r r..aaMILMI IM Mai.as,as..„ ,, .. ' ,a„ ....2,6 aa.ra.a a:..aa.a.. BIW rEu.w4W a�..�rta.it...."r M :14-''a*4:1: ''''''"*4""'"*' Om* iCrtrra.4ar ► ► . it1��or. a.a46i.€.f.' rh e m.mo., :.: w, r- MIML...y►.ta► rld .' ''4644116411"6*""Jit"..., ...M. '1 1111.0,..""" ..rart8s:aa °. �,,.�v,r ' fia.a►at. s t +.m.eae. Alc...a.illp +al:a....ra '1`IYi.1.r +a.K 9Ya.aW.ML. r,all4 Lit w...a., #..... mt.,...... .;..> s 4. _•., r :aa . ;ham, 4 Ma''SI". .:,. �! :a► nt Iit Ra. „' • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: KRU 2L-03 Oper.Rep: Martin Walters PTD No.: 2012390 Oper. Phone: 659-7043 Location Verified? Yes Oper. Email: n1878a.conocophillips.com_ If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 02/21/15 Date AOGCC Notified: 08/03/15 Sundry No.: 315-043 Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures(psi): Tubing S/I Photos Taken? Yes IA 0 OA 250 Condition of Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: none Comments: well was verified by pad well location map SCANNED SEP 1 5 2015 Attachments: Photos(2) REVIEWED BY: ✓3 Insp.Supry j5 1Z"Ill''ic Comm PLB 06/2014 2015-0808_Suspend_KRU_2L-03jh.xlsx r • • Suspended Well Inspection—KRU 2L-03 PTD 2012390 Photos by AOGCC Inspector J. Hill 8/8/2015 IA / *4 1:II .� , , . 1 11 A � N r.. alms& di 4 � i moi + � Iwis ConocoPhillips . "" Nell Neme: 2L-03 ' '-___ . APINember: 50-103-2039800-00 PFO: 201-239 --11741 .,. ' Sur.location:144'FM.,544'FEL ,`4 1. • Sec.22.DON.NEE.UM } if l - 4 r° , -ft f < 4t, . . 9' `n ti . , _. .. .`;x r1 y tt. og.t;ri%ate.. ..1,6-7:',.. _ 4 " `F 1- _ s, r 2015-0808_Suspend_KRU_2L-03 photos_jh.docx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 11b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE! WDSPL n No. of Completions: Service Li Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips, Alaska Aband.: 2/21/2015 201-239/315-043 3.Address: 7. Date Spudded: 15.API Number: P. 0. BOX 100360,Anchorage,AK 99510-0360 2/3/2002 50-103-20398-00 ` 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 143'FNL, 544'FEL, Sec. 22,T1ON, R7E, UM 2/22/2002 KRU 2L-03 Top of Productive Interval: 9. KB(ft above MSL): 144.6' 17. Field/Pool(s): 1483'FSL, 961'FEL, Sec. 11,T1ON, R7E, UM GL(ft above MSL): 27' Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: A 1730'FSL, 796'FEL, Sec. 11,T1ON, R7E, UM 11217'MD/6333'TVD ADL 380049) Pt!k 3800.c2_ 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 461107 y- 5927702 Zone- 11316'MD/6376'TVD 4597 TPI: x- 465995 y- 5934583 Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 466161 y- 5934829 Zone- nipple @ 511'MD/511'TVD 1747'MD/1637'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No Li13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary RECEIVED none SCANNED DEC 1 4 2015 JUN 01 2015 AOGCC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM . HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 28' 110' 28' 110' 24" 9 cu yds High Early 9.625" 40# L-80 28' 3073' 28' 2417' 12.25" 485 bbls AS III Lite, 118 bbls LiteCRETE 7" 26# L-80 26' 10754' 26' 6127' 8.5" 376 sx Class G, 168 sx CI G 3.5" 9.3# L-80 10588' 11314' 6047' 6375' 6.125" 35.7 bbls Class G 24.Open to production or injection? Yes ❑ No Li 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 10593' 10588'MD/6047'TVD 11018'-11028'MD 6246'-6250'TVD -).,,.),AT.'°v�"" 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. r a Was hydraulic fracturing used during completion? Yes❑ No ❑✓ Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): suspended Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - - Form Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 } JUN - 3 2010 Submit ORIGINIAL or-r1 �� P(6 11141S- '28.CORE DATA Conventional C.): Yes ❑ No ❑ Sidewall Coreses ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑J Permafrost-Top ground surface ground surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1747' 1637' Attach separate pages to this form,if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk C 10986' 6232' Kuparuk A 11032' 6252' Formation at total depth: Kuparuk ' 31. List of Attachments: Summary of Dailiy Operations,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email: Jill.Simek@concophillips.corn Printed Name: t S SME tL Title: Staff Well Integrity Engineer 4 Signature: •►,�j SAAti(- Phone: qo. 263 q( i Date: 6-1.21'(5 INSTRUCTIONS General: ' orm and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • • NispvRECEIVED ConocoPhillips JUN 01 2015 Alaska (� P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 28 May 2015 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.performed Suspend operations on 2L-03 (PTD#:201-239),commencing work on 18 February,2015 and completing work on 25 May,2015. Operations involved laying 6 bbls of 15.8 ppg Class "G" cement in the 3-1/2" liner from approximately 11,137' RKB, across the perforations at 11,018' to 11,028' RKB, to a tagged top of cement depth of 10,612' RKB. A Cast Iron Bridge Plug was then set at 10,570' RKB and a passing State Witnessed MIT-T performed. After establishing a circulation point with tubing punch, a second cement plug was placed by pumping 82 bbls of 15.8 ppg Class "G" cement from approximately 10,517' to 7,891' RKB in tubing and IA. Top of cement was tagged at 7,891' RKB and passing mechanical integrity (MIT) and drawdown (DDT) testing was performed. Suspend operations are now complete on 2L-03 and ConocoPhillips requests that the AOGCC well status be changed to"Supsended". Operations and testing summaries are included in the attached Well Work Summary, for your reference. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, 1ff E„,L. Ji Simek ell Integrity Engineer CPAI Drilling and Wells r b KUP PROD • 2L-03 , ConoccPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl('I MD(ftKB) Act Btm(ftKB) CarmIhilaq 501032039800 KUPARUK RIVER UNIT PROD 64.32 11,054.04 11,316.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2L-03.528/20156.15'.15 PM SSSV:NIPPLE Last WO: 27.61 2/26/2002 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,891.0 5/25/2015 Rev Reason:TAG lehallf 5/28/2015 HANGER',23.2 Casing Strings Casing Description OD(in) ID(!n) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED , , ,. ,, , ,„ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 27.9 3,072.5 2,416.7 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread PRODUCTION 7 6.276 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)...WtlLen 0...Grade Top Thread LINER 31/2 2.992 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Liner Details .Ah/M CONDUCTOR;28.0-110.01..46AM/. -MM14/1, Nominal ID Top(ftKB) Top)ND)(ftKB) Top Mel('1 Item Des Com (in) NIPPLE;511.3 ri 6 10,588.1 6,047.1 61.46 PACKER BAKER ZXP LINER PACKER w/HR PROFILE 4.408 10,606.9 6,056.1 61.48 NIPPLE BAKER RS NIPPLE 4.250 10,609.6 6,057.4 61.47 HANGER BAKER FLEX LOCK II DG HYD ROT LINER 4.400 HANGER 10,619.0 6,061.8 61.41 SBE SBE 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT 30456 Tubing Strings Tubing Description I Siring Ma...'ID(in) 'Top(kKB) I Set Depth(ft..f Set Depth(ND)(...1Wt(Ib/ft) i Grade 'Top Connection 6,049.3 930 L-80 EUE8RD 1 "s Completion Details Nominal ID SURFACE;27.9-3,072.5-. ' l 1 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 23.2 23.2 0.00 HANGER FMC GEN V TUBING HANGER 3.500 511.3 511.1 3.81 NIPPLE CAMCO DS NIPPLE NO GO 2.875 GAS LIFT;5,72.6 10,537.1 6,022.7 61.42 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 10,553.6 6,030.6 61.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,591.5 6,048.7 61.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 A Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,116.5 "11111tiTop(ND) Top Incl Top(fKB) (ftKB) ('1 Des Com Run Date ID(in) A '.1` 10,513.0 6,011.2 61.39 TUBING 4'TUBING PUNCH 4/24/2015 2.992 PUNCH A % ^n v 10,570.0 6,038.4 61.45'PLUG 2.69"CIBP 4/23/2015 0.000 Perforations&Slots AA _1 Shot 1 Dens GAS LIFT;9,699.8 Top(ND) Btm(TVD) (shots/f Top(ft613) Bite(RKB) (ftKB) (ftKB) Zone Date t) Type Com ti 11,018.0 11,028.0 6,245.8 6,250.2 C-4,2L-03 3/12/2002 6.0 (PERF 2.5"HSD 2505HJ RDX AA, Chgs,60 deg phase k _ y' A ' Stimulations&Treatments 4 Min Top Max Btm GAS LIFT;10,487.4 v Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (MB) (ftKB) Type Date Corn 1 1 11,018.0 11,028.0 6,245.8 6,250.2 FRAC 3/26/2002 C-SAND FRAC ._. Cement Squeezes TUBING PUNCH;10,513.0 A' '• 'n` ::ti : Top131m(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 10,612.0 11,137.6 6,058.5 6,298.0 Cement Plug 3/30/2015 lay in 6bbl of 15.8 ppg class G cement 7,891.0 10,517.0 4,737.0 6,013.1 Cement Plug 5/8/2015 Fullbore 82bbls,15.8 ppg,class G,tubing and IA SLEEVE;10,537.1 1': Mandrel Inserts St ati NIPPLE;10.553.6 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 3,045.6 2,404.3 CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 PLUG;10,570.0 B M 2 5,722.6 3,695.8.CAMCO KBUG- 1 GAS LIFT 'DMY BK5 0.000 0.0 2/26/2002 M 3 8,116.5 4,846.5.CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 11 f M SEAL ASSY;tassls - 4 9,699.8 5,620.2 CAMCO KBUG- 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 M sl rt 5 10,487.5 5,998.9 CAMCO MMG 1 1/2 GAS LIFT 'DMY BK5 0.000 0.0 2/20/2015 Notes:General&Safety End Date Annotation 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 I IS PRODUCTION;25.5.10,753.5- - M M NA AAA FRAC;11,018.0 !PERFNA ;11,018.0-11,028.0--1 M. M M II LINER;10,588.1-11,314.0 2L-03 WELL WORK SUMMARY DATE • SUMMARY S 2/18/2015 DRIFTED TBG WITH 15'x 2.25" BAILER &TAGGED @ 11006' SLM. UNABLE TO PASS 10535' SLM WITH 10'x 2.72" DRIFT. MEASURED BHP @ 11018' RKB: 3894 PSI. BRUSH 'n FLUSHED TBG. IN PROGRESS. 2/19/2015 DRIFTED TBG WITH 10'x 2.72"TO 11006' SLM. SET 2.75" CA-2 PLUG @ 10553' RKB. SET 2.73"AVA CATCHER ON PLUG. PULLED DV @ 10487' RKB. CIRC 290 BBL INHIB SW. IN PROGRESS. 2/19/2015 ASSIST S/L WITH PREPARATION FOR CIRC-OUT. CIRCULATE 298 BBL INHIB SW FOLLOWED BY 71 BBL DSL. JUMPER AND U-TUBE AT SURFACE TO FP TBG AND IA. 2/20/2015 SET 1.5" LITE DV @ 10487' RKB. MIT IA 2000 PSI: PASSED. MIT TBG 3000 PSI: PASSED. BAILED SAND ON CATCHER f/ 10528- 10530' SLM. IN PROGRESS. **MITT pass: preTIO=325/450/150, initial=3000/550/150, 15min=2950/550/150, 30min=2940/550/150 MITIA pass: preTIO=290/100/150, initial=475/2000/250, 15min=490/1975/250, 30min=490/1965/250** 2/21/2015 BAILED SAND OFF CATCHER, PULLED SAME @ 10530' SLM. COMPLETE. 3/17/2015 BAILED SAND OFF CA-2 PLUG @ 10,554' RKB, ATTEMPTED PULL SAME. JOB SUSPENDED FOR HIGHER PRIORITY WORK. IN PROGRESS. 3/28/2015 WEEKLY BOP TEST, PERFORM MAINTENANCE ON INJECTOR, RIH AND RECOVERED CA-2 PLUG AT 10,554' RKB, ATTEMPT STEP RATE TEST, WELL PRESSURED UP TO 3000 PSI AT 0.5 BPM AFTER 29.9 BBLS OF SLICK DIESEL AWAY. CONTACT TOWN ENGINEER, SCOPE CHANGE FROM RUNNING INFLATIBLE CEMENT RETAINER TO LAYING IN CEMENT WITH BALL DROP NOZZLE. 3/30/2015 LAY IN 6 BBLS OF 15.8 PPG CLASS G CEMENT FROM 11,110' CTMD TO 10,426' CTMD WHILE MAINTAINING 1:1 RETURNS, CONTAMINATE CEMENT TOP TO 10,588' CTMD, CHASE CONtAMINATED CEMENT OOH WHILE MAINTAINING 1:1 RETURNS WITH SLICK DIESEL, READY FOR S/L TAG AFTER MINIMUM 24 HRS, JOB IN PROGRESS. 4/2/2015 OBTAINED CORRECTION FACTOR FROM GLM @ 9700' RKB. TAGGED TOC (SAMPLE OF CONTAMINATED CEMENT) @ 10,279' RKB (STATE WITNESS BOB NOBLE) ATTEMPT MITT. IN PROGRESS. INITIAL T/I/O = 1550/575/300 LRS PT TBG 2250 PSI W/ .4 BBLS DSL. START= 2250/600/300 15 MINS = 1760/590/300 30 MINS = 1660/575/300 RETEST 2250/600/300 15 MINS = 1800/590/300 FAIL. BEGIN MITT LRS PT TBG W/ .3 BBLS DSL INITIAL = 1550/575/300 START = 2250/600/300 15 MINS = 1940/590/300 30 MINS = 1860/590/300 RETEST START= 2260/600/300 15 MINS = 2160/600/300 30 MINS =2090/600/300 45 MINS = 2025/500/300 4/4/2015 PERFORMED FCO TO HARD TAG AT 10608' CTMD USING DIESEL AND DIESEL GEL. TRAPPED 1000 PSI ON SURFACE. READY FOR SLICK LINE. 4/5/2015 (AC EVAL): MITIA(Passed to 2500 psi), IA DDT (Passed). Initial T/I/O = SI 1450/68.0, IA FL @ surface. 411 Pressurized IA to 2500 psi with 2.17 bbls of diesel. T/I/O = 1625/2500/600. 15 min reading: T/I/O = 1575/2470/650. (-30) 30 min reading: T/I/O = 1560/2470/650. (0) Bled IA down to 525 psi in 9 min. T/I/O = 1450/525/425. Waited for slick line to drift tubing before doing IA DDT. Continued to bleed IA for 1 min. T/I/O = 1650/460/600. 15 min reading: T/I/O = 1650/460/600. 30 min reading: T/I/O = 1650/460/600. 45 min reading: T/I/O = 1650/450/600. (-10) 60 min reading: T/I/O = 1650/450/600. Final T/I/O = SI 1650/450/600. 4/5/2015 OBTAINED CF FROM GLM @ 10487' RKB; TAG CEMENT @ 10612' RKB (STATE WITNESS-BOB NOBLE); MITT FAILED (MULTIPLE ATTEMPTS)W/500 PSI LOSS IN 6 MIN. JOB SUSPENDED PENDING PROCEDURE. LRS RIG UP TO TREE, PRE MIT PRESSURE 1625/450/350, LRS ROLE PUMP .4 BBLS TBG @ 2500 PSI PRESSURE FALLING OFF FAST BUMP UP TBG 5 TIMES SAME. BUMP PRESSURE UP TO 2500 PSI MONITOR FOR 6 MIN PRESSURE @ 2000 PSI 1.5 BBLS PUMPED FOR TESTING. 4/23/2015 DRIFT FOR HES 2.69" CIBP, SET 2.69" CIBP @ 10,570' RKB, LRS PERFORMS PASSING MIT-T TO 2500#STATE WITNESSED BY J. HILL BOL LRS FOR MIT-T TO 2500#(STATE WITNESSED BY J. HILL) STARTING TEST PRESSURES: 2500/400/125#AFTER 15 MINS: 2450/400/125#AFTER 30 MINS: 2425/400/125#CONFER W/J. HILL, WATCH ANOTHER 15 MINS: 2425/400/125# ******PASS****** 4/24/2015 ATTEMPT TO SHIFT SLEEVE © 10, 533' RKB, SHOOT 4'TBG PUNCH @ 10,513'- 10,517' RKB...JOB DONE. 4/28/2015 Performed injectivty test establishing injectivty w/diesel thru hole punches of stable 1.85 bpm @ 2000 psi. 5/8/2015 PUMPED 82 BBLS 15.8 PPG CLASS G CEMENT DOWN TUBING TAKING RTNS FROM I/A TO TANK. 61 BBLS DIESEL IN TUBING. DSL NEXT FOR TAG. 5/25/2015 LOCATED GLM @ 5723' RKB FOR CORRECTION. TAGGED TOC @ 7891' RKB. LRS PERFORMED PASSING MITs ON TBG & IA. JOHN CRISP, AOGCC, WAIVED WITNESS. COMPLETE. **MITT pass: preTIO=50/0/200, initial=1675/50/250, 15min=1650/50/250, 30min=1650/50/250. T-DDT pass: preTIO=1650/50/250, initial=0/25/200, 15min=100/25/200, 30min=110/25/200 MITIA pass: preTIO=110/25/200, initial=210/1650/400, 15min=225/1600/400, 30min=225/1580/400, IA-DDT pass: preTIO=225/1580/400, initial=110/10/250, 15min=90/50/250, 30min=90/50/250** • • Allsup-Drake, Sharon K To: Simek,Jill Subject: RE: 2L-03 AOGCC Email 1 of 2 From: Simek,Jill Sent: Monday, March 30, 2015 9:03 AM To: Loepp, Victoria T(DOA) Cc: Senden, R. Tyler; NSK Well Integrity Proj Subject: KRU 2L-03 Update Victoria, Yesterday we performed the injectivity test on 2L-03 but were not able to establish sufficient rate for injecting cement into the perforations. The well pressured up to 3,000psi at 0.5 bpm after 29.9 bbls of slick diesel was pumped. Based on these results,we will forgo setting the cement retainer and will instead lay cement with a ball drop nozzle. The cement plug will be placed across the perforations and brought to the top of the 3-1/2" liner and into the 3-1/2" tubing. Estimated top of cement will be at 10,588 ft KB as originally planned. If you have any issues with the planned path forward, please contact me at the numbers below. Thanks, Jill Simek ConocoPhi hips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 1 • • Allsup-Drake, Sharon K To: Simek,Jill Subject: RE: 2L-03 AOGCC Email 2 of 2 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, April 07, 2015 10:19 AM To: Simek,Jill Cc: Regg,James B (DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: KRU 2L-03 Update Jill, This plan is approved as written. Please sent MITT results when obtained. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(c�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Tuesday, April 07, 2015 10:04 AM To: Loepp, Victoria T(DOA) Cc: NSK Well Integrity Proj; Regg,James B (DOA); Senden, R. Tyler Subject: RE: KRU 2L-03 Update Victoria, Per today's phone discussion, and further to yesterday's summary of recent suspend operations on 2L-03 (PTD: 201- 239),the next steps will be to set a Cast Iron Bridge Plug at approximately 10,570 ftKB. After setting the plug, a State Witnessed MIT-T and tubing drawdown test will be performed. If tests pass,we will continue with the suspend program approved by AOGCC on 10 February, 2015 (see attached). This will include shifting the sliding sleeve at 10,537 ftKB and testing for adequate circulation in preparation for pumping the second cement plug. Please reply to this email with your approval of the above steps or contact me with questions. 1 • • Thank you, Jill From: Simek,Jill Sent: Monday, April 06, 2015 11:14 AM To: 'Loepp, Victoria T(DOA)' Subject: KRU 2L-03 Update Victoria, Over the weekend, ConocoPhillips performed a Fill Clean Out to hard tag at 10,612ft on KRU 2L-03 (PTD: 201-239). The tag was witnessed by State Inspector Bob Noble. MIT-IA and IA-DDT tests passed, however the MIT-T failed. The forms for these tests are attached. I will call to discuss next steps. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 01,2015 TO: Jim Regg ( 6/41,5- P.I. l4 ,S P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-03 FROM: Johnnie Hill KUPARUK RIV UNIT 2L-03 Petroleum Inspector Src: Inspector Reviewed BYL P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2L-03API Well Number 50-103-20398-00-00 Inspector Name: Johnnie Hill Permit Number: 201-239-0 Inspection Date: 4/23/2015 Insp Num: mitJWHI50601135929 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 21,03 (Type Inj N TVD 6047 . Tubing 1600 2500 ' 2450 • 2425 . 2425 • PTD 2012390 • Type Test SPT Test psi 1512 IA 400 400 • 400 • 400 . 400 • Interval OTHER P/F P ✓ OA 125 125 125 - 125 • 125 • Notes: MIT-T as part of P&A. CYJ U 'eA i?I Z l I, 5- sEU JUL 1 32015 Monday,June 01,2015 Page 1 of 1 "9TP 2c/ -23 Loepp, Victoria T (DOA) From: Grimaldi, Louis R (DOA) Sent: Monday, May 25, 2015 6:20 AM To: charlesj.fitzpatrick@contractorconocophillips.com Cc: Loepp, Victoria T (DOA); Regg,James B (DOA); Herrera, Matthew F (DOA) Subject: RE:AOGCC Test Witness Notification Request: P &A, Kuparuk Well 2L-03 Follow Up Flag: Follow up Flag Status: Flagged Chuck I will be coming up this afternoon and relieve Mr. Crisp. What is the plan forward on this well. (Cliff notes please). Lou Grimaldi Petroleum Inspector SCANNED MAY A 9 2015 Alaska Oil and Gas Conservation Commission G ell (907)776-5402(Home) (907)252-3409(Cell) Original message From: "Crisp, John H (DOA)" Date:05/25/2015 06:11 (GMT-09:00) To: charles.I.fitzpatrick a contractor.conocophil(ips.com, DOA AOGCC Prudhoe Bay Subject: RE: AOGCC Test Witness Notification Request: P & A, Kuparuk Well 2L-03 Witness is waived for this tag and PT. From: Chuck Fitzpatrick [ nailto:noreply@formresoonse.com] Sent: Saturday, May 23, 2015 1:21 PM To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: P &A, Kuparuk Well 2L-03 Question Answer Type of Test Requested: P & A 1 Requested Time for 05-25-2015 8:00 AM Inspection Location Kuparuk Well 2L-03 Name Chuck Fitzpatrick E-mail charles.j.fitzpatrick@contractor.conocophillips.com Phone Number (907) 659-7221 Company ConocoPhillips Alaska Request is made for witness of tag&pressure test of cement Other Information: abandonment plug no. 2. Ref. Sundry No. 315-043, 10 February,2015. Submission ID: 308225244621264848 2 pT-JJ 2 —237 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 07, 2015 10:19 AM To: 'Simek,Jill' Cc: Regg,James B (DOA); Schwartz, Guy L(DOA) Subject: RE: KRU 2L-03 Updateb Jill, This plan is approved as written. Please sent MITT results when obtained. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission NNEt _ 4-�' 333 W.7th Ave,Ste 100 �� Anchorage,AK 99501 Work. (907)793-1247 Victona.Loeppalaska qov OilConservation CONFIDENTIALRY NOTICE:This e-mail message,including any attachments,contains information from the Alaska and Gas Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Simek,Jill [mailto:Jill.Simek@conocophillips.com] Sent:Tuesday, April 07, 2015 10:04 AM To: Loepp, Victoria T(DOA) Cc: NSK Well Integrity Proj; Regg, James B(DOA); Senden, R.Tyler Subject: RE: KRU 2L-03 Update Victoria, Per today's phone discussion,and further to yesterday's summary of recent suspend operations on 2L-03(PTD: 201- 239),the next steps will be to set a Cast Iron Bridge Plug at approximately 10,570 ftKB. After setting the plug,a State Witnessed MIT-T and tubing drawdown test will be performed. If tests pass,we will continue with the suspend program approved by AOGCC on 10 February,2015 (see attached). This will include shifting the sliding sleeve at 10,537 ftKB and testing for adequate circulation in preparation for pumping the second cement plug. Please reply to this email with your approval of the above steps or contact me with questions. Thank you, Jill From: Simek, Jill Sent: Monday,April 06, 2015 11:14 AM 1 To: 'Loepp, Victoria T(DOA)' Subject: KRU 2L-03 Update Victoria, Over the weekend,ConocoPhillips performed a Fill Clean Out to hard tag at 10,612ft on KRU 2L-03 (PTD: 201-239). The tag was witnessed by State Inspector Bob Noble. MIT-IA and IA-DDT tests passed, however the MIT-T failed. The forms for these tests are attached. I will call to discuss next steps. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 2 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Monday, April 06, 2015 11:18 AM To: Schwartz,Guy L(DOA) Subject: Fwd: KRU 2L-03 Updatea Attachments: MITT KRU 2L-03 04-05-15 MIfIA.xls;ATT00001.htm; MITT KRU 2L-03 04-05-15 MITT.xls; ATT00002.htm Sent from my iPhone Begin forwarded message: From:"Simek,Jill"<Jill.Simek@conocophillips.com> Date:April 6,2015 at 11:14:15 AM AKDT To:"Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov> Subject:KRU 2L-03 Update Victoria, Over the weekend,ConocoPhillips performed a Fill Clean Out to hard tag at 10,612ft on KRU 2L-03 (PTD: 201-239). The tag was witnessed by State Inspector Bob Noble. MIT-IA and IA-DDT tests passed, however the MIT-T failed. The forms for these tests are attached. I will call to discuss next steps. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone• 907-263-4131 I Cell. 907-980-7503 3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday,April 03, 2015 8:45 AM To: Schwartz, Guy L(DOA) Subject: FW: KRU 2L-03 (PTD201-239) Update Attachments: MITT KRU 2L-03 04-02-15.xls From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday,April 03, 2015 8:43 AM To: Loepp, Victoria T(DOA); Regg, James B(DOA) Cc: Senden, R.Tyler; Simek,Jill Subject: RE: KRU 2L-03 (PTD201-239) Update Victoria, The witnessed tag showed the top of cement ended up about 300' high at 10279' RKB due to suspected contaminated cement stringers. The MITT lost less than 10% in 30 minutes and marginally showed stabilization after 45 minutes however did not indicate a conclusive passing test. The next step in the approved suspension/P&A procedure is to tubing punch and circulate in an additional cement plug in the tubing and IA with a TOC 3572' . This plug will also be State Witnessed tagged and pressure tested. ConocoPhillips would like to continue the procedure as written to circulate in the final plug and have a State Witnessed MITT and tag. Please Advise MJ Loveland MJ Loveland /Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From:Simek,Jill Sent: Monday, March 30,2015 9:03 AM To: Loepp,Victoria T(DOA) Cc:Senden, R.Tyler; NSK Well Integrity Proj Subject: KRU 2L-03 Update Victoria, 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reugQIIalaska.gov AOGCC.InspectorsRlalaska.aov; phoebe.brooksealaska.nov chris.walaceR4alaska.00v OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/2L-03 DATE: 04/05/15 OPERATOR REP: Dan Riley(AES) AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L-03 Type Inj. N TVD 6,04T Tubing 1,450 1525 1575 1,560 Interval 0 P.T.D.20123900 Type test P Test psi 1511.75 Casing 680 2500 2,470 2,470 P/F F Notes: Non Witnessed MITIA as part of P&A OA 450 600 350 650 Well 2L-03 Type In]. N TVD 6,047' Tubing 1,450 1,650 1,650 1,650 1550 1,850 Interval 0 P.T.D.20123900 Type test P Test psi 1511.75 Casing 525 460 460 460 450 450 P/F F Notes: IA DDT OA 425 600 600 600 600 600 Well Type Inj. TVD Tubing Interval • P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: 1 OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey O=Other(desarbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MITT KRU 2L-03 04-05-15 MITIA.xds STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocklitalaska.slov AOGCC.Inspectorsinalaska.stov phoebe.brookstQalaska.aov chris.wallaceealaska.aov OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/2L-03 DATE: 04/05/15 OPERATOR REP: Jason Potter AOGCC REP: Robert Noble Packer Depth Pretest Initial 15 Min. 30 Min 45 Min. 60 Min. Well 2L-03 Type Inj. N TVD 6,047' Tubing 1,625 2,500 Interval 0 P.T.D.20123900 Type test P Test psi 1511.75 Casin. 150 150 P/F F Notes:Witnessed P&A MITT-pumped up to 2500 psi and 1 OA 350 350 dropped to 2000 psi in 6 min. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval' P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA , Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). ND Tubing Interval - P.T D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MITT KRU 2L-03 04-05-15 MITT.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � /1 '411*s DATE: 4/4/15 P. I. Supervisor FROM: Bob Noble SUBJECT: P&A — Plug Tag and Test Petroleum Inspector KRU 2L-03 CPAI PTD 2012390 Background: On 4/2/2015 I witnessed inconclusive tag and tests of the KRU 2L-03 abandonment plug (separate report). After review of my report, CPAI was instructed by AOGCC Engineers that they must confirm the integrity of this plug before moving uphole with the remainder of the abandonment plugging operations. 4/4/15: I traveled back out to KRU 2L-03 for the tag and pressure test. I met with CPAI rep Eddie Zemba and we went over what they had done to the well since the last time I was there. Eddie told me that they had rigged up a service coil tubing unit and cleaned the well out from - 10279 ft RKB down to 10608 ft RKB. At 10608 ft RKB they hit what they believed to be hard cement. Slick line was rigged up and they ran into the hole with 2.25" by 5 ft bailer. The top of cement was found at 10612 ft RKB. Wireline was pulled out of the hole. The bailer was found to be almost empty with a few small chip of what looked to be hard cement. Slick line was then rigged down and a Hot Oil pump was rigged up. Pretest T/I/O pressures were: 1625/450/350 psi. - I asked them to put 2500 psi on the tubing. They would pump it up and the tubing pressure would drop off with no increase on the IA pressure. I had them do this several times with the same result. It was then decided to do a leak loss rate test. They put 2500 psi on the tubing and it took 6 minutes for the pressure to drop down to 2000 psi with no increase of IA pressure. Work was suspended on the P&A of KRU 2L-03 until CPAI can review with AOGCC the plug _ integrity test results and determine steps needed to complete the P&A. SGA 2015-0404_Plug_Verification_KRU_2L-03_attempt2_bn.docx Page 1ofl • 41 C-tt 1,44. P(>t-9.4- P I u(Tug trey Regg, James B (DOA) 4(z(ts &L t1/4)0L-(e- From: oL:•(4From: Regg, James B (DOA) Sent: Friday, April 03, 2015 10:15 AM Q.44 t�I�i( To: DOA AOGCC Prudhoe Bay C Subject: FW: KRU 2L-03 (PTD201-239) Update Jim Regg Supervisor, Inspections AOGCC ,pNE© Iv1i ( 2 . 333 W.7th Ave,Suite 100 S Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday, April 03, 2015 10:01 AM To: Loepp, Victoria T(DOA); Regg, James B (DOA) Cc: Senden, R. Tyler; Simek, Jill; Kennedy, Chris; CPA Wells Supt Subject: RE: KRU 2L-03 (PTD201-239) Update Victoria, Thank you for noting the discrepancy in the procedure for the final TOC. The TOC at the end of the job will be 8200' RKB. The MITIA and both T and IA draw down tests in will be completed this weekend and I will forward you the results. Per our discussion and post MITIA& DDT's, Coil tubing will clean out down to competent cement. Slickale Witness tag and re MITT. The subsequent steps are pending the results of the FCO tag and MITT and may include a CIBP. MJ MJ Loveland /Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc Office (907) 659-7043 MJ's Cell (907) 943-1687 From: NSK Well Integrity Proj Sent: Friday, April 03, 2015 8:43 AM To: Loepp,Victoria T(DOA);jim.regg@alaska.gov Cc: Senden, R.Tyler; Simek,Jill Subject: RE: KRU 2L-03 (PTD201-239) Update 1 ' Victoria, The witnessed tag showed the top of cement ended up about 300' high at 10279' RKB due to suspected contaminated cement stringers. The MITT lost less than 10% in 30 minutes and marginally showed stabilization after 45 minutes however did not indicate a conclusive passing test. The next step in the approved suspension/P&A procedure is to tubing punch and circulate in an additional cement plug in the tubing and IA with a TOC^'8200' . This plug will also be State Witnessed tagged and pressure tested. ConocoPhillips would like to continue the procedure as written to circulate in the final plug and have a State Witnessed MITT and tag. Please Advise MJ Loveland MJ Loveland I Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc Office (907) 659-7043 MJ's Cell (907) 943-1687 From:Simek,Jill Sent: Monday, March 30, 2015 9:03 AM To: Loepp, Victoria T(DOA) Cc:Senden, R.Tyler; NSK Well Integrity Proj Subject: KRU 2L-03 Update Victoria, Yesterday we performed the injectivity test on 2L-03 but were not able to establish sufficient rate for injecting cement into the perforations. The well pressured up to 3,000psi at 0.5 bpm after 29.9 bbls of slick diesel was pumped. Based on these results, we will forgo setting the cement retainer and will instead lay cement with a ball drop nozzle. The cement plug will be placed across the perforations and brought to the top of the 3-1/2" liner and into the 3-1/2" tubing. Estimated top of cement will be at 10,588 ft KB as originally planned. If you have any issues with the planned path forward, please contact me at the numbers below. Thanks, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone 907-263-4131 I Cell: 907-980-7503 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggR� q,'2,11,5 DATE: 4/2/15 P. I. Supervisor FROM: Bob Noble SUBJECT: P&A — Plug Tag and Test Petroleum Inspector KRU 2L-03 ��N��p MP 2 2 ' 015 CPAI PTD 2012390 4/2/15: On arrival at location, I met with CPAI rep Eddie Zemba and we went over the procedure for this P&A. Eddie told me that on 3/30/15 they had pumped a 5 bbl fresh water spacer, followed by 6 bbls of 15.8 ppg of class G cement. Slick line was rigged up and pressure tested. They ran in the well with 5'x 2.5" bailer with 11' x 1.875" weight bar. Top of plug was found to be at 10279 ft RKB. The procedure called for top of cement (TOC) to be at 10,588 ft— plug was found to be 309 ft high. The bailer was pulled out of the well and found to have what looked like contaminated cement with a lot of frac sand. The sample also had a very strong diesel smell. I saw no sign of good hard cement in that sample. A MIT-T was performed with the following results: Tubing (psi) IA (psi) OA (psi) Loss (psi) Pre-Test 1550 575 300 Initial 2250 600 300 15 minutes 1940 590 300 310 30 minutes 1860 590 300 80 This test failed in the first 15 minutes (lost more than 10% of test pressure); total pressure loss was 390 psi over 30 minute test. Pressure was bumped up for retest with the following results: Tubing (psi) IA (psi) OA (psi) Loss (psi) Pre-Test 1860 590 300 Initial 2260 600 300 15 minutes 2160 600 300 100 30 minutes 2090 600 300 70 45 minutes 2025 600 300 65 This test had a 100 psi drop in the first 15 min, 70 psi drop in the second 15 minutes, and a 65 psi drop in the third 15 minutes; total pressure loss was 235 psi over 45 minute test. Summary: The plug tag/test results of KRU 2L-03 abandonment plug were inconclusive. Attachment: Email from CPAI; 4/3/15 (follow-up to inconclusive plug verification) 2015-0402_Plug_V erificati onKRU_2 L-03_bn.docx Page 1 of 1 Pro Zbi Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Thursday, March 26, 2015 10:27 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler; Kanady, Randall B Subject: RE:2L-03(PTD 201-239, Sundry 315-043) Follow Up Flag: Follow up Flag Status: Flagged Victoria, I am writing to update you on suspend operations at KRU 2L-03 (Sundry#315-043). Work is on schedule and we should be pumping the first of the two cement plugs this weekend. After state witnessed tag and testing,we plan to follow with the second plug operations on or about April 1. I will continue to update as operations progress. If you have any questions, please call or email. Thanks, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone. 907-263-4131 I Cell: 907-980-7503 S`MAKVi From: Loepp, Victoria T(DOA) [mailto:victoria.loeppPalaska.gov] Sent:Thursday, March 12, 2015 9:39 AM To: Simek, Jill Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: 2L-03 Jill, Thank you for the update. Expeditious completion of this work is expected.Your plan forward is approved. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria.Loeppt ialaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 From: Simek,Jill [mailto:Jill.Simek@conocophillips.com] Sent: Wednesday, March 11, 2015 5:00 PM To: Loepp,Victoria T(DOA) Subject: 2L-03 Victoria, On February 10,2015,Sundry Approval (Sundry#315-043)was granted to ConocoPhillips for suspension operations on KRU 2L-03(PTD#201-239). Approved procedure is to isolate perforations and suspend the well with two cement plugs, bringing top of cement to approximately 8,200 ftKB in the tubing and tubing x production casing annulus(IA). At the time of sundry approval,drilling operations were blocking access to the well. To date,Slickline has performed pre-suspend operations, including setting a 2.75"CA-2 plug in the Camco D-nipple at 10,553 ftKB to secure the well. Passing MIT-T(3000 psi)and passing MIT-IA(2000 psi)tests were obtained. Next steps will be to pull the CA-2 plug and perform a step rate injectivity test to ensure adequate rates for cementing operations. Coiled tubing and cementing operations will follow. These steps are in the original Application for Sundry Approvals procedure,attached. ConocoPhillips plans to recommence these operations on 2L-03 March 18,2015. Please reply with your approval or contact me with questions or concerns. A 10-407 will be submitted upon completion of the work. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell. 907-980-7503 2 PTO �,o1 - 23 9 Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, March 11., 2015 5:00 PM To: Loepp, Victoria T(DOA) Subject: 2L-03 Attachments: 2L-03 Approved Sundry to Suspend 10 February 2015.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, On February 10, 2015, Sundry Approval (Sundry#315-043)was granted to ConocoPhillips for suspension operations on KRU 2L-03 (PTD#201-239). Approved procedure is to isolate perforations and suspend the well with two cement plugs, bringing top of cement to approximately 8,200 ftKB in the tubing and tubing x production casing annulus(IA). At the time of sundry approval, drilling operations were blocking access to the well. To date, Slickline has performed pre-suspend operations, including setting a 2.75" CA-2 plug in the Camco D-nipple at 10,553 ftKB to secure the well. Passing MIT-T(3000 psi)and passing MIT-IA(2000 psi)tests were obtained. Next steps will be to pull the CA-2 plug and perform a step rate injectivity test to ensure adequate rates for cementing operations. Coiled tubing and cementing operations will follow. These steps are in the original Application for Sundry Approvals procedure, attached. ConocoPhillips plans to recommence these operations on 2L-03 March 18, 2015. Please reply with your approval or contact me with questions or concerns. A 10-407 will be submitted upon completion of the work. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 SCANNED MAR 1 9 2015 Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, March 10, 2015 4:57 PM To: Loepp, Victoria T (DOA) Cc: Kanady, Randall B Subject: RE: 2L-03(PTD 201-239, Sundry 315-043) Follow Up Flag: Follow up Flag Status: Flagged Victoria, We are planning to commence the suspend operations by March 31, 2015. in the meantime, per AOGCC request, we have secured the well with a CA-2 plug in the D-nipple at 10,553' KB. This was performed 2/19/2015. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 10, 2015 4:04 PM To: Simek, Jill Subject: [EXTERNAL]2L-03(PTD 201-239, Sundry 315-043) Jill, Please let me know the status on this work. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoriaioepp@alaska.gov 2 bbl - . 3c' ConocoPhillips 11551 TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender/Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7t'Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2L-03 DATE: 01/21/2015 Transmitted: I Kuparuk River Unit, Alaska 12L-03 ( oi - 1 as.hardcopy color print each 1 -/DGRiSLD/CNP/CNT(TVD) 1:600/1:240, 110-11316' and Sperry Sun SCANNED MAR 0 2015 DGR/SLD/CNP/CNT(MD) 1:600/1:240, 110-11316' and-Sperry Sun 11-7 DGR/EWR (TVD) 1:600/1:240, 110-11316' and-Sperry Sun ROP/DGR/EWR (MD) 1:600/1:240, 110-11316' and-Sperry Sun I� III Logs prints delivered to AOGCC at request of Meredith Guhl-missing from vendor distribution as required. h Please promptly sign, scan and return electronically to Sandra.D.LemkeOCOP.com CC: 21-03 transmittal folder, production well files, eSearch JAN 22 2015 Receipt: Date: AOGCC Angela K. Singh "W emposoty- ' GIS-Technical Data Management ( ConocoPhillips 'Anchorage,Alaska I Ph: 907.265.6947 7UA--C Co p'td RECEIVED r 27 2015 re ( ,AOGCC of rot Alaska Oil and Gas �w� \\�/j, s THE STATE 1 .;,-s�� , oLASIc:A Conservation Commission rd Witt=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS�� Fax: 907.276 7542 www.aogcc.alaska.gov Jill Simek SCANNED ' l Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. �3 P.O. Box 100360 01, Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2L-03 Sundry Number: 315-043 Dear Ms. Simek: 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, • 1i Daniel T. Seamount, Jr. Commissioner I4 DATED this/ day of February, 2015 Encl. Ktc;tIVtu STATE OF ALASKA JAN 2 8 2015 AL A OIL AND GAS CONSERVATION COMIV, .ON APPLICATION FOR SUNDRY APPROVALS AQGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend %_ Rug Perforations p • Ferforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing g r Other: I— 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 201-239 ' 3.Address. Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20398-00 $ 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r , KRU 2L-03 . v 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 380049 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11316 6376 11217' 6333' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 3045 9.625 3073' 2417' PRODUCTION 10728 7 10754' 6127' LINER 726 3.5 11314' 6375' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11018-11028 ' 6246-6250 3.5 L-80 10593 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER ZXP LINER PACKER , MD=10588 TVD=6047 NIPPLE-CAMCO DS NIPPLE NO GO ' MD=511 TVD=511 12.Attachments: Description Summary of Proposal F. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/31/2015 Oil r Gas r WDSPL r Suspended 417- 16.Verbal Approval: Date: WINJ r GINJ r- WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email. Jill.Simek@conocophillips.com Printed Name Jill SimekTitle: Staff Well Integrity Engineer Signature C � Phone:263-4131 Date (/2.4115' Commission Use Only Sundry Number:3) ✓ O Conditions of approval: Notify Commission so that a representative may witness Plug Integrity fr BOP Test r Mechanical Integrity Test r Location Clearance r / r7 4_z,, 'G fo W,fvi C 5_5 p I tly l' y ct fr,G1 p T a3 '� clic a �r e` - Other: NO O f17 Spacing Exception Required? Yes ❑ No Subsequent Form Required. /o -- 467- .C77- �� APPROVED BY I Approved by. /> COMMISSIONER THE COMMISSION Date: 2 1 It /15 Approved ap/ppIlicat o / yaJid tor 12 months trom the date of approval.,6 a_id is Form 10-403(Revised 10/2012) �� 4 Submit Form and Attachments in uplicate V TL 7/4-/1 n Q P I N A IP%� PIDDMS FEB 1 0 2015 . 1 r ` RECEIVELs ✓ JAN 2S 201J ConocoPhillips Alaska AOG CC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 27 January 2015 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to suspend 2L-03 (PTD#: 201-239). KRU 2L-03 is a Long Term Shut In (LTSI) well that was originally drilled as a C-sand producer in 2002. The well did not produce as expected and was shut in. Since the lease has expired for the bottom hole, location of 2L-03,_a suspend procedure is being submitted for the well. The well has 9-5/8" surface casing to 3,072.5' KB with a 7" production casing to 10,753.5' KB. There is 3-1/2"tubing stung into seal assembly at 10,591.5' KB. A 3-1/2" liner is set from 10,588.1' to 11,314.0' KB. Perforations are located from 11,018.0' KB to 11,028.0' KB. Per this procedure, suspended well operations will be performed to isolate the perforations by pumping 11 bbls of 15.8 ppg Class"G"cement through a cement retainer at approximately 10,915' KB and placing 2.8 bbls on top of the retainer, bringing cement to approximately 10,588' KB in the tubing. After waiting on cement, 81.9 bbls of 15.8 ppg Class "G" cement will then be pumped fullbore, to bring cement to approximately 8,200' KB in the IA and tubing. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, --::-— Sv1/4...,..k.".._ Ji l Si ek 1 ntegrity Engineer CPAI Drilling and Wells ConocoPhi.iips 2L-03 Suspend Procedure Permit to Drill #: 201-239 The objective of this procedure is to perform suspended well operations by placing cement plugs in the perforations, tubing, and tubing x production casing (IA) annulus. Plugging will be obtained by pumping 11 bbls of 15.8 ppg Class "G" cement through a cement retainer at approximately 10,915` KB and then placing approximately 2.8 bbls of cement on top of the retainer to bring cement in the tubing to 10,588' KB. After the first plug has hardened, 81.9 bbls of 15.8 ppg Class "G" cement will then be pumped fullbore, to bring cement to approximately 8,200' KB in the IA and tubing. Proposed Procedure: Slickline/Little Red Services: Objective: Drift and tag TD, obtain updated SBHP, dummy drift for cement retainer, set nipple plug, circulate the well over to known fluids, perform MIT testing, perform injectivity test to confirm adequate rates for cementing operations 1. Inspect pad and work area for Hazards. Complete Pre Job Safety Meeting. RU Slickline unit and support equipment. PT lubricator and surface lines as required. Open SSV that was dumped in 2006. 2. Drift and tag TD 3. Obtain static bottom hole pressure and temperature measurements. 4. Dummy drift for cement retainer. 5. Brush and Flush GLM @ 10,487' KB and D-nipple profile @ 10,554' KB. 6. Set CA-2 plug w/ catcher in D-nipple @ approx. 10,554' KB. 7. RIH and pull DMY valve from GLM @ 10,487' KB. 8. Circulate 298 bbls of inhibited SW, followed by 71 bbls of diesel freeze protect. Jumper and U-Tube at surface to freeze protect Tubing and IA. 9. Set DMY valve in GLM @ 10,487' KB. MIT-T to 3,000 psi. MIT-IA to 2,000 psi. Record Results. 10. If tests failed, plan to troubleshoot GLV's, and perform E-line (or DSL) LDL if needed. 11. Pull catcher and CA-2 plug from D-nipple @ 10,554' KB. 12. Perform step rate injectivity test with diesel to ensure adequate rates for cementing operations. Record Results. RDMO. Schlumberger Coiled Tubing/Cementing: Objective: Plug #1 - Place a cement plug across the open perforations and squeeze some cement into perforations. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. .i S Cement Volume Calculations (TOC in tubing to be at approximately 10,588' KB): • 3 1/2" liner volume from perforations to cement retainer': (11,028'-10,915') x 0.008697 bbls/ft = 1.0 bbl • 3 1/2" liner volume from cement retainer to TOC: (10,915'-10,588) x 0.008697 = 2.8 bbl • Squeeze volume: 10 bbl • Total volume: 1.0 + 2.8 + 10 = 13.8 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 7/17/2012 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 10,915' KB. 8. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations. 10. RU SLB Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 13.8 bbls of 15.8 ppg Class "G" Cement a. This calculation assumes 10 bbl of squeeze volume b. Volume could change based on injectivity test results 13. Pump 10 bbls fresh water spacer behind 14. Pump fresh water spacer ahead and 11 bbl cement through retainer, squeezing desired volume through the peas. a. This volume and rate may change based on injectvity rate 15. Shut down, un-sting from retainer 16. Lay in remaining -2.8 bbl cement above retainer. 17. POOH above TOC 18. Circulate CTU clean, watch for cement returns at surface 19. Once returns are clean, POOH and wait on cement as per SLB UCA data Slickline/ Little Red Objective: Tag TOC, State Witnessed MIT-T & MIT-IA, DDT, shift sleeve 1. WOC per Schlumberger UCA data (minimum 24 hours). Notify the AOGCC u- . Inspector of the timing of the cement plug tag and pressure testing. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. JS 4. RIH and tag TOC @ approximately 10,588' KB. Record Results. ✓ 5. RU LRS and PT Surface Equipment as require 6. Perform MIT-T to 1,500 psi. Record Results. 7. Perform MIT-IA to 1,500 psi. Record Results. 8. Perform DDT on Tubing and IA. Record Results. 9. If TOC is found at or below 10,588' KB, RIH and shift open the sliding sleeve at 10,537' KB. 10. Pump 20 bbls diesel through open sleeve to ensure adequate rate for cementing. If adequate circulation rates are achieved follow with SLB Pumping Services for Plug #2 operations. 11. If adequate circ. rate is not achievable, TOC is above sliding sleeve, or sleeve will not shift open, follow with e-line tubing punch operations. 12. RDMO E-line / Little Red (if required) 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. RIH with tubing punch and punch approximately 50' above TOC or as close to mid joint as possible. 4. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing. 5. If adequate circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 6. RDMO Schlumberger Pumping Services: Objective: Plug #2 - Fill the wellbore with cement from sliding sleeve (-10,537' KB) to approximately 8,200' KB. We will be circulating cement down the 3 1/2" tubing and up the 7" annulus. Cement Volume Calculations (TOC approximate) 40116 tubing and annulus): • Volume in 3 1/2" x 7" annulus: (10,537'-8,200') x 0.02636 bbl/ft = 61.6 bbl • Volume inside 3 1/2' tubing: (10,537'-8,200') x 0.008697 bbl/ft = 20.3 bbl • Total volume: 61.6 + 20.3 = 81.9 bbl • Displacement volume: 8,200' x 0.008697 bbl/ft = 71.3 bbl - 10 bbl spacer= 61.3 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. JS 3. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 �/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 4. PT surface equipment as required 5. Establish circulation with seawater/brine 6. Pump 10 bbls fresh water spacer 7. Pump 81.9 bbls of 15.8 ppg Class "G" Cement a. Volume could change if tubing punch required 8. Pump 10 bbls fresh water spacer 9. Displace with 61 bbls diesel to leave Top of Cement in tubing and IA at 3,572' KB. 10. Shut down SLB pumps and close in Tubing and IA. Do not overdisplace. 11. Wash up SLB cement pumps and clean up surface lines. 12. RDMO Digital Slickline / Little Red Objective: Tag TOC, State Witnessed MIT-T & MIT-IA, DDT 13. WOC per Schlumberger UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 14. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 15. RU SL and PT Equipment as required. 16. RIH and tag TOC @ approximately 3,572' KB. Record Results. ✓ 17. RU LRS and PT Surface Equipment as required. 18. Perform MIT-T to 1,500 psi. Record Results. 19. Perform MIT-IA to 1,500 psi. Record Results. 20. Perform DDT on Tubing and IA. Record Results. 21. RDMO JS . . .._....,, KUP 2L-03 CfanocoPhillips 4 ' , 11,...Aiblinlige Max Mi Jtiitle&ail ,k MAW ', d Name ,,.. yug,g4 lnd In Ifte3g1 Eign log: 6131.7.1.413126,13 1/31131g1t.t,..141+,,..,I 6.4 1.i11 D4..4 11 1111. 16.1,..10.41.1 Csinerne 43-444tAn n4 A•14 ' -Arg ert: gip betriaa Dal. ... e.3.3-.'NI:Ibt .loafi Wt., ....^..4,-.13C. .,. - o• -Be 1 mg 11,.."31 1.- . ' .te v13.'.4. _ FaillinLaaing Mbar Icing C. brAng AD-lag MINI. lot Dam.At.gm D•pp..rprm_ yrin,g ron...going..Reim T.4 Thrte CL1,41,,....:101t It It,..:3 133': 11131 C•41tAg D44ertemer Seven;CA balm C.....Tap egAll. 5433.3.444.ef-Saw Dog.ATV'S,. *Irene WI-lain_ going Top Th. 3,00 ALl. g bb g t.3, 113 g '3 b1.3e. ,41b.4 4:1AGIU 1411: Ii,.: ukaing 311.11OSIOF litrft CI Sting V..Tap little. Skrt up V.a-Swage(WD). berksp VA-Ming_ tring Tzg bleb «.. IblIket4e3IILAN 30 _,,,,,, . ...t...Z. re T. 1.,ISI,3,,.... b 1.b.9(ISO)_ 2t .uu 4.5.W. ...L._. EI IT:Z..› C. _t A.INtl, 2 131 IAD: 1.4...eel 1 11.314.0 b3/b.4 g 31.: LAN: 33.11 Liner 4$16111* tIVEY, 14,1.1 kart. Tr./14011 0...34 ri 44AnD444,44143: Camelot. 0604 155.551 5,54..'I VI AIS I....LIAO{ 11.1l(till A.'L Ile it 0.43331:1.11vt11141 A.41 ,let 44441 155.41.4 ,.....,:tb 1 51.455.1145,11 mexttt ics,NIVI•Lt .4.255 -I 1t1 ISO,5 541411 S. .A4-.1w.kt4 eJW,t13 t LEX 1.1X.:1,. _ •,I V..)1 4 hit 11 A HNA.At AA 15 tl..e. bt1:51 3 5- .5 3:3": %IL BU.4C t5 ..6,..4..!.+.,., .., .4 4.41 II 4 ARM , TUbling itnnal •.thiNg ri.Clipt., I c,I:, rriV,ii...-IT*0,ZI ISIR Deft'rf pla...10c,17,1 lierir.i rrt-1511.;.13.36.14 1-: 11.3 L g Nt.: 3'3. ..A.D. ::3..e In.3.4.1, 1 1,, ., ,i ., t-tv Completion Details 7.4.Dept {Val 7:pine tetra_ -... t.A' 11144.1 {A teat D•434peleas C.1",111.1 0.15 -51....• ...411 IL _.. :a.:' -'.-,.1',AM...LI< t kit:LIN 4,1 JULY..11.L.V.k If _1 ••1 3 511 1 1.51 SliMnL CA.4.44)1.5.hal.1.1.E NU(.:LT ' • 1 t.C12 1 51.41545±541 tfiXt le GIFU tAJLX14...;Satlit (II , ..•.. t.4..II 51.43 4115*.5 CAM-CO t:NIIIINt NA'..et' . '• 1.1.31• t At I CI 4,"1:P.Ate, eAts.I ee..-- t 1 ' - Perforattons&Slots Tap Oth1 t ben A1521 05521 'I.L Z.,1. tan. ...- Tye fggMIP 11.514.1. 11,425.5 5,4455 •.• ' .,..- • .slhll14Q t. 41145. 4i"l ' SUrout&OOtst&Thsattrients lieter1 get Top Vas lieb T41 5.44e3 1.D DKr. c.r. rrir, !Ina: 0.i 1 rrwit Ma,' TA, L‘g• A 1,31113 11, 12 1.2414)1 Is:... :4 Notes:Genial&Safety CM 5.1. ...33.41._I ' WI,,ANove tAllognotA • A.-.......: A Abi I i •I . IRK ..,,, _ ... . ..1 -, L.,. I ) i ' A A ManagigDelltBR, -144 rase CrAtt gut 55 tog. 11555 5* ltrZ Its I.-,A At lebillt OK,. n. m.... 1444.A4 An1 I., 'bp. 10p. 1,4 tr..1 14..C.r. • 45,5 4 4:4..!,....-'.1.3 1.1."*.:4.,.e.....,...2-y 1..4.. .1," UM, bt..1 4-SI, e,•..4::54.11'. 14444. •..3-ggre..MAI I . 1,51541 3 telb.1 51.1111.14.411C1-1 Ne1.1.1,31 1........1'' UV' 114,1, :21.51 ......t.TOO .3 5115.5 55455 53441e CAM..:0 A.11...t.A.M 1...A:.1: LW, bete.. 14151 4-..' . ., t,telg.21 5514.4 51.14 lAY..........te-1,33. - 1......4`. ' LAY- 5513 CX!) ...."..b..t. • • 13 IA b W4-4 t 1.3b t AV -.DN.. I 1. ....,.I- Us- 54.3.3 :410 :.:I.J1.13.•_.4. Nidelc, JS Suspend Diagram: 2L-03 Suspend PTD#: 201-239 I urr.nt CrerpIrtir.n Proposed Suspension A .f.-62.511 H-40 Conductor a 110'K8 Ai L. Mr Cameo'DS'Nipple No Go 0 511'KB illE GLM DMY g 3:048'KB A lh, P 518"4001..-E0 Ssxface Casing c 3,07:KB 4 GOA Ill —] DMY Irk 5.133'KB E1MY @ 8.117 KS OMY g 8.48T KB \ Ns Second Ptag TOC g 8.300`IBt11JIY�10.487 KB N,\I'4'.1‘ Baty CMV Sliding%leve a 10.537 KB Carrico 4"tipple No Go C 10.554'133 3-':'8.3#L-80 Tub'xrg g 10.583'KB \'ti �„ Raker ZXP Ung Packerw HR Profile 10.588'KB S' fest Plug TOC @ 10,.x98 KB Baker 80-40 Locator Seal Assembly 0 10,581'KB4 ' Baker'RS'Pipple a 10.607 KB 6aksr Flex Lock II DO HYD ROT Liner Hanger .�"�"°=r 10507 KB e1 SEF 80-4 Seal acre.Extension g+10,518'KB aa" I 7'250 L-80 Producton Casing a 10.754'KB Cement Retainer g 10.415'KZ 11,018'-e Perk. KB , All cement to be 15.E Class"u 6iGz ' 3'/7 0.3#1.-80 Liner c 11,314'103 J3 1-27-15 JS i KUP 2L-03 ConocoPhillips S Well Attributes Max Angie&MD TD AlaskaWellbore APIIUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) 501032039800 KUPARUK RIVER UNIT PROD 64.32 11,054.04 11,316.0 ConocciFhillips """ Comment•-• -•• -- H2S(ppm) Date ---Annotation End Date --- KB-Ord(ft) --- Rig Release Date • - -• -• •• Well Confg:-2L.03,7/1720121:0014 PM SSSV:NIPPLE Last WO: 27.61 2/26/2002 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 11,231.0 10/12/2006 Rev Reason:WELL REVIEW osborl 7/17/2012 CasingStrings HANGER,23- `�: III.. g Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd SRI --- ' P CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd ' SURFACE 95/8 8.835 27.9 3,072.5 2,416.8 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd PRODUCTION 7 6.276 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 31/2 2.992 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Liner Details _-- Top Depth' CONDUCTOR, (TVD) Top not Nomi... 28.110 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 10,588.1 6,047.1 61.46 PACKER BAKER ZXP LINER PACKER w/HR PROFILE 4.408 NIPPLE,511 ilL 10,606.9 6,056.1 61.48 NIPPLE BAKER RS NIPPLE 4.250 10,609.6 6,056.7 60.74 HANGER BAKER FLEX LOCK II DG HYD ROT LINER HANGER 4.400 10,619.0 6,061.3 60.76 SBE SBE 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings [_ Tubing Description IString0... I String ID...ITop(RKS) !Set DepthIf...I Set Depth(ND)...I String W0t...I String...I String Top Thrd GAS LIFT. { - TUBING 31/2 2.992 23.2 10,592.7 6,049.3 9.30 L-80 EUE8RD 3,046 Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (1 Item Description Comment ID(in) SURFACE,_ : 23.2 23.2 -0.31 HANGER FMC GEN V TUBING HANGER 3.500 20-3,072 511.3 511.1 3.81 NIPPLE CAMCO DS NIPPLE NO GO 2.875 10,537.1 6,022.7 61.42 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 GAS Ute' --- 3 10,553.6 6,030.6 61.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 5,723 10,591.5 6,048.7 61.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment GAS LI.PT• 11,018.0 11,028.0 6,246.0 6,250.3 C-4,2L-03 3/12/2002 6.0 IPERF 2.5"HSD 2505HJ RDX Chgs,60 deg em -_-- phase --- Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 11,018.0 11,028.0 6,246.0 6,250.3 FRAC 3/26/2002 C-SAND FRAC GAS LIFT. Notes:General&Safety 9700 End Date Annotation 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 10,487 a SLE10EVE,.537 i.-.1 NIPPLE.10.554 IX SEAL ASSY. 10,591 IME i PRODUCTION, A A Mandrel Details 26-10,754 Top Depth Top Port 1 (ND) Incl OD Valve Latch Sian TRO Run Stn Top(ftKB) (ftKB) (°I Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,045.6 2,404.3 62.33 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 IPERF, 11,01611.028 - 1112 5,722.6 3,695.9 61.19 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 FRAC,11.018 =- - r 3 8,116.5 4,846.5 60.87 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 4 9,699.8 5,620.4 61.91 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 5 10,487.5 5,998.9 61.38 CAMCO MMG 1 12 GAS LIFT DMY BK5 0.000 0.0 10/13/2006 LINER, 10,58611,314 TD,11.316 0 1 3 i � f Souther - --- - f ADL390681ADL390680 — / f CARAC—OL—, i I uve C CAt ACOL, 74 TP, 0 - TP, 1 AN apPi- `r Unit MUSTANG OP, MEP MEP .l °E 6/30/2012lo i E 6/30/2012 7 f • • 12 o KL iiarup BHLNE9 BASE BERMUDA ..'P` /1 I � TOP BERMUDA 8921.5' Section Line 1 1 8208'- 500'From Section Line 15 14 13 . r PAI SURFACE ` T1 ONR8 AD CAS%NG SHOE J -r---- —r9O1 DS-2L," 80052I � A �- AI, — SURF<G,E- C�rr++r--I 131 XA, ,. — '13 XA, l CHCH VRON, EXX MOBIL130 -. .1 ON , 7 EXXO MOBIL 1/3�J/2003 22 , Ta PA 23 1/3 /2003 24 19 r Kuparu River moi# 27 26 25 28 30 I s Non [ 133) If . 1ADL380054 ConocoPhillips c) CPAI, BPXA, I Kuparuk River Unit CHEVRON, 2L-03 EXXON; OBIL 34 il 35 E 1/3 : 13 33 f Originator: Paul Wharton Prepared by: J.A.Lauruhn 5 I File Ni.",., 15012002A01 I Date: 1-27-15 G.L.Alvord RECEIVEDAlaska Drilling Manager Drilling&Wells JAIV C 8 LU iJ P.O. Box 100360 Anchorage,AK 99510-0360 ConocoPhillips AOGCC Phone: 907-265-6120 January 27, 2015 Hand Delivered Commissioner Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Docket No. OTH 15-001 Non-Compliance Notice Kuparuk River Unit 2L-03 Development Well Kuparuk River Unit 2L-03 (PTD 201-239) This letter responds to the Non-Compliance Notice referenced above dated January 13, 2015. Please find enclosed ConocoPhillips Alaska, Inc.'s (CPAI) information submission in compliance with the Alaska Oil and Gas Conservation Commission's (AOGCC) request. Please let me know if you require any additional information. CPAI must immediately schedule the required well work to bring the well (2L-03) into compliance with 20 AAC25.112 Currently Doyon 25 is on 2L Pad drilling well 2L-308. At this location Doyon 25 is preventing access to 2L-03. CPAI will have to wait-until Doyon 25 has completed drilling 2L-308 and moved the rig to start work on 2L-03. CPAI will secure required approvals while waiting for the rig to move. CPA is scheduling the P&A on 2L-03 to begin no later than March 31. CPAI is also required to submit the required well data (current well sketch and flow data) for the AOGCC well file Included in Attachment 1 is a copy of the current well sketch and flow test data on 2L- 03. Failure to submit a Sundry application form (Form 10-403) outlining the procedure for plugging and abandoning KRU 2L-03 to the satisfaction of the AOGCC within fifteen days will result in issuance of a Notice of Violation. Included in Attachment 2 is a copy of the Sundry Application form 403 and 2L-03 Suspend Procedure, which was submitted separately on January 27, 2015. CPA is requesting to abandon the bottom of 2L-03 that is not on ADL 380051 and suspend the remaining portion of the wellbore. CPAI is requesting 2L-03 be suspended because it is on an active pad (DS-2L) and it is a viable candidate for redrilling. ' Docket No. OTH 15-001 January 27, 2015 Non-Compliance Notice Kuparuk River Unit 2L-03 If you have any questions regarding this matter, please contact me at 265-6120 or Randall Kanady at 243-4126. Sinc./j.reely,nn G... l2..- G. L. Alvord Alaska Drilling Manager Attachment 1: Current well sketch and flow test data on 2L-03. Attachment 2: Sundry Application form 403 and 2L-03 Suspend Procedure 2 Attachment 1 Current well sketch and flow test data on 2L-03. 1. KUP 2L-03 ConocoPI fillips 0a Well Attributes „ a � ' u ;,wMax Angle&MD TD IIX: Wellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Btm(ftKB) Alaska. 501032039800 KUPARUK RIVER UNIT PROD 64.32 11,054.04 11,316.0 UonoctiPh. daps -- -- .-- - - Comment -• - --- H2S(ppm) Date -- Annotation End Date -• KB-Grd(ft) Rig Release Date -•- ••- •-- .- .. Well cants:-2L.03,7117/2012 t:o014 PM SSSV:NIPPLE Last WO: 27.61 2/26/2002 Schemeec-Acluei Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 11,231.0 10/12/2006 Rev Reason:WELL REVIEW osborl 7/17/2012 HANGER.23 fi` Casing Strings Casing Description String 0.. String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd -11ill ' Pr CONDUCTOR 16 _ 15.062 28.0 110.0 110.0 62.50 11-40 WELDED Casing Description String 0... String ID...Top(IIKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 27.9 3,072.5 2,416.8 40.00 L-80 BTC Casing Description String 0... String ID...Top(11KB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd P PRODUCTION 7 6.276 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER31/2 2.992 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Liner Details --- Top Depth CONDUCTOR, IND) Top 1081 Nomi... 28-110 Top(ftKB) (ftKB) (1 Item Description Comment ID(in) -- 10,588.1 6,047.1 61.46 PACKER BAKER ZXP LINER PACKER w/HR PROFILE 4.408 NIPPLE.511 10,606.9 6,056.1 61.48 NIPPLE BAKER RS NIPPLE 4.250 j 10,609.6 6,056.7 60.74 HANGER BAKER FLEX LOCK II DG HYD ROT LINER HANGER 4.400 �I 10,619.0 6,061.3 60.76 SBE SBE 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd GAS;IL UFT.46_ -_- _ I !, TUBING 31/2 2.992 23.2 10,592.7 6,049.3 9.30 L-80 EUE8RD Completion Details Top Depth (ND) Top Intl Nomi... lop(ftKB) (ftKB) r) Item Description Comment ID(in) SURFACE.28-3, _ -� 23.2 23.2 -0.31 HANGER FMC GEN V TUBING HANGER 3.500 072 511.3 511.1 3.81 NIPPLE CAMCO DS NIPPLE NO GO 2.875 ___j 10,537.1 6,022.7 61.42 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 GAS UFT, - 4 10,553.6 6,030.6 61.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,723 10,591.5 6,048.7 61.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens __ Top(ftKB)Btm(ftKB)1 (RKB) (11KB) Zone Date On- Type Comment GAS UFT._ 11,018.0 11,028.0 6,246.0 6,250.3 C-4,2L-03 3/12/2002 6.0 IPERF 2.5"HSD 2505HJ RDX Chgs,60 deg 8.tn phase Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 11,018.0 11,028.0 6,246.0 6,250.3 FRAC 3/26/2002 C-SAND FRAC GAS LIFT _ { Notes:General&Safety 9.700 _- End Date Annotation 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS 10LI,487FT,_ ....../ SL10,5EEVE, 37 -. i , 0 I NIPPLE,10,55/ SEAL A0,591SSY, I !1 PRODUCTION, & Mandrel' Details 2610,754 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) r) Make Model (in) Sem Type Type (in) (Psi) Run Date Corn... 1 3,045.6 2,404.362.33 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2/26/2002 11,01&H 028 ' I 2 5,722.6 3,695.961.19 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.02262002 FRAC,11,018 -\\ r 3 8,116.5 4,846.560.87CAMCOKBUG-M 1GASLIFTDMY BK5 0.000 0.02262002 4 9,699.8 5,620.4 61.91 CAMCO KBUG-M 1 GAS LIFT DMY BK5 0.000 0.0 2262002 5 10,487.5 5,998.9 61.38 CAMCO MMG 1 12 GAS LIFT,DMY BK5 0.000 0.0 10/13/2006 LINER, 10,58611,314 TD,11,316 . , ... .. .... ... ... .... r--- 7) RS 5 cn rn it =a- 0 cu ro 1 2 L.71 0 = E fl 0 1:3 cr = < co 2 •_i o .--- o o_ f f f 14 f (Aep, ,)sled see 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U) 0 10 0 10 0 10 0 d ci o N- , „•• , , : . c4 . : o . : op-------- Y C.) CO ICV.-4. • *-------4---4---- -.14 .10 1° 0 LT. E ..r. 0 0 $ 1 co 1.. a) E 4 co 9 .----.--I-4 a)E 1 i= ...) C•1 ,4 4 .., - C, . i. • MEM'---- n . i 40•IBIM Ill IIIII ... .1. ! 1.1 ili CO CN • .' ‘.----"-• • • LIP ,•• o . , • — ------09 11 — • , ...... 3 A AIM= lk 0 C1 0 a a a a a a a a a to in c) LI-) c•i c\I .— .— (siqq) p!nbn I(isd) ssem/(Aep/siqq) Ned I!O :---- (7) a) -a 0- RI 7 N d) c CT N $ (6 731 m 11 0 D E d N O 2 D < as 0 a f .1. f II f (/cep/d3IN1/11) Neel se0 0 0 0 0 0 0 0 o O O o O o 0 o(6o ui o co (N N (f) O I I I I I 0 N- N O d' M (O • r4 3 0 O a) ca E c *-•-• * +A A D Tic a) • • 4.1"C.4. E M 4. 0 *---44 1 \111F161.. co P _J N _ 0 N f"j O N— O O O O O O O O O O O O O O O O LO M M N N r-Lo a LOO= (siqq) pinbli /(isd) ssOJd / (Asp/sigq) 0 021 HO Attachment 2 Copy of Sundry Application form 403 and 2L-03 Suspend Procedure • STATE OF ALASKA AL (A OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon I— Rug for Redrill i_ Perforate New Pool j-" Repair w ell j Change Approved Program r Suspend r� Rug Perforations r� Perforate r Pull Tubing _ lime Extension r Operational Shutdown r Re-enter Susp.Well (•-` Stimulate f Alter casing )— Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory (`-' Development )✓ 201-239 3.Address: 6.API Number: Stratigraphic ( Service (_ P. O. Box 100360,Anchorage,Alaska 99510 50-103-20398-00 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes )i No r- KRU 2L-03 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 380049 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11316 6376 11217' 6333' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 3045 9.625 3073' 2417' PRODUCTION 10728 7 10754' 6127' LINER 726 3.5 11314' 6375' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11018-11028 6246-6250 3.5 L-80 10593 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER ZXP LINER PACKER MD=10588 TVD=6047 NIPPLE-CAMCO DS NIPPLE NO GO MD=511 TVD=511 12.Attachments: Description Summary of Proposal 14.- 13. Well Class after proposed work: Detailed Operations Program ) BOP Sketch (-" Exploratory (.W Stratigraphic ). Development 14 Service 1- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2015 Oil )— Gas i " WDSPL I Suspended Fk7 16.Verbal Approval: Date: WINJ ) GINJ (- WAG P Abandoned Commission Representative: GSTOR l SPLUG I-- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email: Jill.Simek@conocophillips.com Printed Name Jill Simek Title: Staff Well Integrity Engineer Signature Phone:263-4131 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity I— BOP Test (__ Mechanical Integrity Test I-_ Location Clearance Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Approved application Is valid for 12 months trom the date of approval. Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate ConocoPhilrips 2L-03 Suspend Procedure Permit to Drill #: 201-239 The objective of this procedure is to perform suspended well operations by placing cement plugs in the perforations, tubing, and tubing x production casing (IA) annulus. Plugging will be obtained by pumping 11 bbls of 15.8 ppg Class "G" cement through a cement retainer at approximately 10,915' KB and then placing approximately 2.8 bbls of cement on top of the retainer to bring cement in the tubing to 10,588' KB. After the first plug has hardened, 81.9 bbls of 15.8 ppg Class "G" cement will then be pumped fullbore, to bring cement to approximately 8,200' KB in the IA and tubing. Proposed Procedure: Slickline/Little Red Services: Objective: Drift and tag TD, obtain updated SBHP, dummy drift for cement retainer, set nipple plug, circulate the well over to known fluids, perform MIT testing, perform injectivity test to confirm adequate rates for cementing operations 1. Inspect pad and work area for Hazards. Complete Pre Job Safety Meeting. RU Slickline unit and support equipment. PT lubricator and surface lines as required. Open SSV that was dumped in 2006. 2. Drift and tag TD 3. Obtain static bottom hole pressure and temperature measurements. 4. Dummy drift for cement retainer. 5. Brush and Flush GLM @ 10,487' KB and D-nipple profile @ 10,554' KB. 6. Set CA-2 plug w/ catcher in D-nipple @ approx. 10,554' KB. 7. RIH and pull DMY valve from GLM @ 10,487' KB. 8. Circulate 298 bbls of inhibited SW, followed by 71 bbls of diesel freeze protect. Jumper and U-Tube at surface to freeze protect Tubing and IA. 9. Set DMY valve in GLM @ 10,487' KB. MIT-T to 3,000 psi. MIT-IA to 2,000 psi. Record Results. 10. If tests failed, plan to troubleshoot GLV's, and perform E-line (or DSL) LDL if needed. 11. Pull catcher and CA-2 plug from D-nipple @ 10,554' KB. 12. Perform step rate injectivity test with diesel to ensure adequate rates for cementing operations. Record Results. RDMO. Schlumberger Coiled Tubing/Cementing: Objective: Plug #1 - Place a cement plug across the open perforations and squeeze some cement into perforations. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. JS Cement Volume Calculations (TOC in tubing to be at approximately 10,588' KB): • 3 '/2" liner volume from perforations to cement retainer': (11,028'-10,915') x 0.008697 bbls/ft = 1.0 bbl • 3 '/2" liner volume from cement retainer to TOC: (10,915'-10,588) x 0.008697 = 2.8 bbl • Squeeze volume: 10 bbl • Total volume: 1.0 + 2.8 + 10 = 13.8 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 7/17/2012 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 10,915' KB. 8. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations. 10. RU SLB Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 13.8 bbls of 15.8 ppg Class "G" Cement a. This calculation assumes 10 bbl of squeeze volume b. Volume could change based on injectivity test results 13. Pump 10 bbls fresh water spacer behind 14. Pump fresh water spacer ahead and 11 bbl cement through retainer, squeezing desired volume through the perfs. a. This volume and rate may change based on injectvity rate 15. Shut down, un-sting from retainer 16. Lay in remaining -2.8 bbl cement above retainer. 17. POOH above TOC 18. Circulate CTU clean, watch for cement returns at surface 19. Once returns are clean, POOH and wait on cement as per SLB UCA data Slickline / Little Red Objective: Tag TOC, State Witnessed MIT-T & MIT-IA, DDT, shift sleeve 1. WOC per Schlumberger UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. is 4. RIH and tag TOC @ approximately 10,588' KB. Record Results. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record Results. 7. Perform MIT-IA to 1,500 psi. Record Results. 8. Perform DDT on Tubing and IA. Record Results. 9. If TOC is found at or below 10,588' KB, RIH and shift open the sliding sleeve at 10,537' KB. 10. Pump 20 bbls diesel through open sleeve to ensure adequate rate for cementing. If adequate circulation rates are achieved follow with SLB Pumping Services for Plug #2 operations. 11. If adequate circ. rate is not achievable, TOC is above sliding sleeve, or sleeve will not shift open, follow with e-line tubing punch operations. 12. RDMO E-line / Little Red (if required) 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. RIH with tubing punch and punch approximately 50' above TOC or as close to mid joint as possible. 4. Pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing. 5. If adequate circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 6. RDMO Schlumberger Pumping Services: Objective: Plug #2 - Fill the wellbore with cement from sliding sleeve (-10,537' KB) to approximately 8,200' KB. We will be circulating cement down the 3 1/2" tubing and up the 7" annulus. Cement Volume Calculations (TOC approximately 3,572' in tubing and annulus): • Volume in 3 '/" x 7" annulus: (10,537'-8,200') x 0.02636 bbl/ft = 61.6 bbl • Volume inside 3 '/2' tubing: (10,537'-8,200') x 0.008697 bbl/ft = 20.3 bbl • Total volume: 61.6 + 20.3 = 81.9 bbl • Displacement volume: 8,200' x 0.008697 bbl/ft = 71.3 bbl - 10 bbl spacer = 61.3 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. JS 3. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 1/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 4. PT surface equipment as required 5. Establish circulation with seawater/brine 6. Pump 10 bbls fresh water spacer 7. Pump 81.9 bbls of 15.8 ppg Class "G" Cement a. Volume could change if tubing punch required 8. Pump 10 bbls fresh water spacer 9. Displace with 61 bbls diesel to leave Top of Cement in tubing and IA at 3,572' KB. 10. Shut down SLB pumps and close in Tubing and IA. Do not overdisplace, 11. Wash up SLB cement pumps and clean up surface lines. 12. RDMO Digital Slickline / Little Red Objective: Tag TOC, State Witnessed MIT-T & MIT-IA, DDT 13. WOC per Schlumberger UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 14. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 15. RU SL and PT Equipment as required. 16. RIH and tag TOC @ approximately 3,572' KB. Record Results. 17. RU LRS and PT Surface Equipment as required. 18. Perform MIT-T to 1,500 psi. Record Results. 19. Perform MIT-IA to 1,500 psi. Record Results. 20. Perform DDT on Tubing and IA. Record Results. 21. RDMO Js KUP 2L-03 ( wK)(01Iidlit)a � Wei Attributes fav _ trtaxAn easie TD 1Wdc)w+L"f2,,: IFL.'F:1.t. Vin:-,�.tet.l Inn iaa 20••, I '.4.L .. "Carom. wrs aa.l 42..,,x4 - _n.:.a. .,r., 14 terry L'r. ...w ..... .. Anna roan Vain EtK int �J n. 4 LLC YK4 Co. =01 la IG aI^i71J. 101-2.21.0t 1«.....La n VOL L_ i v1.:..A crow. Ir.i..'.P..: twang L44cripprx. 9vtK v.. 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InLY;0. !Ina GI 01 - n 1: Ila avan H_Iia Van m,:/-ISWS}V,hila-.11x41,1 T:4 1111 f ', ILION:: ' z21' .'!1 1.•+1111'.I Is411.r U:A: 414: t,.IN:: 1Oitfll6 ,TAUS 'ApireI I L TpprS1} 0.2 Lrl An^wac"CUa•. i 2ira wr 0 3Y 11 .:.11,•Ali-::kif tY4:122.N4'1 J8I I4 t}kYi214 5 t2.1 . 311.5 all 1 1.11 41Do':h (AM:UM MPI a-14W 1411 11551.1 1.11 11115'.tt4t I14t11 L'MU 1L13N'.:'1Ltt 9t 2.411 . f �� 10111 t 1.J:1111 /1.43 41'I`:t 1.2.414.11 l I".t`.I:;22 1.!!31 1u v.1.:. C!4411 11.41]::A.4051' CAY.t I,ll'-. .:::1-AStItNtLT SfStl Perhxabala&State 4» T.:.-Jtl 4-ril .a 'ap"b.:In''11611 ()•A. 1111.' Scar 0.. !n- 4t-TCwrs 11,214.0 11,101.); 1.2411 1.2^::.3;..41.111 .x!:' 1.':: 41.1 •: 02.12'LA.tap,M%cla St rrailagana&TreaSinatt a afar 0,-114. Ws le n '02 Gpr. Uupf Lan twtc (Tl, IW: }WI; Vali .11101 INS Tn. .4.11•61-s •1,:11': 11,_.'.11 t241 t1 - ..,. -. .. E totIR General&sluts 1 ' I4-. A,-..,.wr •• ':.,...�1.4......wic.rry Aw.l.n 1:c'wlrwl.s. N OF I '11QifJ 111 .:11'181 .. I 11Ya.1 in Ia n F `I I 1.1 - a re. �. M s1L7rel O104 C411,11... �..*14fTap part OW Incl it ala inn Sas 1%1 RA Mit 111)1 l'1 Y4t. IIcaN tn. Lr. T}p. TIP. 0.4 gsa</ Rn 1p Lu... . 1•x 1.4.'4.11-"'.5:1 LAMS:{i t:U24.0 1..42.1U4.B UNIT 44:1 2114/ 122 2C21:2711'.:' win • :..2011.n N ' ' . V n3+9/1.19(ASCU 1..ti.0 1,:.A tit 1 Via W11 .0A-I g.t 2+ 211:. xal . .11111 .1M . 12:1.LAW .'..,..41 1..A:.Lit 1-' L041 410 1.02U 1t?1T2bilt.. 11.1.2.41121 AIL:22*.11..,.rT. 1..:401.1 1.2%f I' 114/3 C222__21 ......!;:'±:. ... 1 20.2.1 :S.W 11.311 L _iU Let•. 1 1C 0,1224 1LOON' }.0:_t LOON' .. • F 11„;x_.I JS Suspend Diagram: 2L-03 Suspend PTD#: 201-239 Current Campletio€t Proposed Suspension Ali 16`625#11-40 Conductor g 1117 KBAlli 1 El L Camas'DS tipple No Goa 511k'B Gilt CWTYa3046'K6 C-7.; A Ill► 95,3-441#L-80 Shoe Casing g 3.077 KB A D GLAt II 7 my'a 5.723 KB DAY tjg 8.117 113 DAY g 0,700"KB k‘s4a. Ns- b PkaQ TQC B�IE4!�DAY g&10,487 KB AP SS sk, .\\,,,,„ Bakes Cfiki Stooling Sleeve a 10,537"KB Camoo'Cr ripple No Go a 10.554'KB MID 3-1r 83#L 80 Tutieg g 10,593'KB EMI Baker X.37 Lire Packer we'HR Prable g 10,5&8'KB "?'" Rest Plug TOC g 10,588 KB Jim, Baker 80-40 Locator Sea'Assembly©10,591'KB Baker RS'tipple a 10,647 KB Baker Flex Lode II DG H'YD ROT Lifer Hanger ,a tCiKB SEE 59-47 Seal Bare l:Extern=g 10,619'KB '2#L-80 Producton Casing a 10.754'KB ',' Cement Retainer,g 10,815'KB Parts: tlT All cement ' to be 15.E Class 11,018'-11,028'KB ,/ ` 31g Ole L-80 Liner ig 11,314'KB ,15 1-27-15 is 4 • 4 3 2 1 6 1 Souther -- -- - 1 ADL 90681 ADL 90680 ---- — 1 —E COL, M 11uve c.-. la P, 0 �_ I P, -M-US NG_-�--, Unit MUSTANG OP, 1 MEP MEP E 6/30/2012 C 6/30/20127 1 9 KLparujc BHL itlad BASE BERMUDA '°iP l TOP BERMUDA e>,/f/ 8921.5' Section Line 1 1 1 8208' 500'From Section Line P PA 1 15 14 13 . 16 _ _ 184 1.1 r SURFACE' e /y T10NR8E AD 80052 DS-2 . . aCA�SlNG__ASDHtOE 1i8005"t�` iiir --- - AI - ----- �y, AIRF P_AI 131 - 90 B XA, - -'`�B XA, CH RON, 130 T N � , 7E --� CH VRON, EXXO4 MOBIL I EXXO MOBIL 113 /2003 22 Ta ` PA 23 1/3 /2003 1 Kuparuk, r River UIIil \it I 27 26 25 28 30 I. — 133 f —. 1 1 ADL3 0054 ConocoPhillips C I, BP , I Kuparuk River Unit CHE RON, 2L-03 EXXON OBIL 34 E 1/3 '4013 33 ,I Orlglnelcr Paul Wharton Prepared by J.A.Lauruhn s I File Name 15012002A01 d Date: 1-27-15 1 VOF Tit 4fv, I v7;„ s?, THE STATE Alaska Oil and Gas ��,,►:"s��, ofALASKA Conservation Commission 'Witt _,_ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 ALAS*P Fax: 907.276.7542 www aogcc.alaska.gov January 13, 2015 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7012 3050 0001 4812 6853 G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Docket No. OTH 15-001 Non-Compliance Notice Kuparuk River Unit 2L-03 Development Well Dear Mr. G.L. Alvord: The Alaska Oil and Gas Conservation Commission (AOGCC) recently reviewed the well file for KRU 2L-03 (PTD 201-239) which was drilled by Phillips Alaska Inc., now ConocoPhillips Alaska Inc. (CPAI), in 2002. The bottom hole location for the well lies in expired lease ADL 380049. KRU 2L-03 is out of compliance with regulation 20 AAC 25.105(a), which requires wells to be permanently abandoned before expiration of the operator's lease. The Department of Natural Resources' records show that ADL 380049 was closed, effective September 28, 2003. Brooks Range Petroleum has since acquired the acreage under lease ADL 390680 which includes the bottom hole location of well KRU 2L-03. The AOGCC currently lists the well as shut-in, with well Class/Status listed as Development/Oil. Allowing the lease to expire without properly plugging and abandoning KRU 2L-03 is a violation of AOGCC regulations. CPAI must immediately schedule the required well work to bring the well into compliance with 20 AAC 25.112. Also, AOGCC has no records of the flow test that was conducted after the Hydraulic Fracture stimulation. The AOGCC will conduct a further review of the Form 10-407 "Well Completion Report", for any additional missing well information. Non-Compliance Notice Kuparuk River Unit 2L-03 Development Well January 15,2015 Page 2 of 2 CPAI's prompt response is required regarding a proposed schedule to plug and abandon KRU 2L-03 in a manner approved by the AOGCC. CPAI is also required to submit the required well data (current well sketch and flow data) for the AOGCC well file. Failure to submit a Sundry application form (Form 10-403) outlining the procedure for plugging and abandoning KRU 2L- 03 to the satisfaction of the AOGCC within fifteen (15) days of this letter will result in issuance of a Notice of Violation. A copy of this letter is being provided to the Department of Natural Resource, Division of Oil and Gas. If you have any questions regarding this matter, please contact Victoria Loepp at (907) 793- 1247. Sincerely, Cathy P. r oerster '`Z—� Chair, Commissioner cc: Paul Decker, Acting Director Department of Natural Resources, Division of Oil and Gas 550 W. 7th Avenue, Ste. 1100 Anchorage, AK 99501-3563 • U.S. Postal ServiceTM • CERTIFIED MAILTM RECEIPT Ln (Domestic Mail Only;No Insurance Coverage Provided) co For delivery information visit our website at www.usps.com® ra Postage $ .1" Certified Fee1-1 _■ Return Receipt Fee Postmark O (Endorsement Required) Here Restricted Delivery Fee Q (Endorsement Required) Lf j a Total Postage&Fees Sent To G.L.Alvord ,Nq Alaska Drilling Manager o Street,Apt No.; ConocoPhillipsAlaska, Inc. [ti or PO Box No. City,State,ZIP+4 Post Office Box 100360 Anchorage,AK 99510-0360 PS Form 3800.August 2006 SENDER: COMPLETE THIS SECTION COMPLETE TH.'S SECTION ON DELIVERY • Complete items 1,2,and 3.Also complete A. Signa item 4 if Restricted Delivery is desired, ,l/' " Agent • Print your name and address on the reverse X ,if ! r� Addressee so that we can return the card to you. B. Received by(P i � C. Date of Delivery I Attach this card to the back of the mailpiece, or on the front if space permits. • i API k _ D. Is delivery address different from item 1? ❑Yes 1. Article Addressed to: If YES,enter delivery address below: ❑ No G.L.Alvord Alaska Drilling Manager 3. Service Type ConocoPhillips Alaska, Inc. ❑Certified Mail® 0 Priority Mail Express" Post Office Box 100360 0 Registered 0 Return Receipt for Merchandise Anchorage,AK 99510-0360 0 Insured Mail 0 Collect on Delivery 4. Restricted Delivery?(Extra Fee) 0 Yes 2. Article Number (Transfer from service labe9 7 012 3050 0 0 01 4 812 6853 PS Form 3811,July 2013 Domestic Return Receipt KUP 2L-03 ConocoPhillips Well Attributes 'Max Angle&MD TD Alashd.Int: Wellbore APUUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) �axx��i'hilhq 501032039800 KUPARUK RIVER UNIT PROD 64.32 11,054.04 11,316.0 Comment 828(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLEWN1 ConlIg:-2L-03,7/17/2012 1:00:14 PM - 27.61 2/26/2002 Last W - Schematic-Actual ___._ Annotation Depth(RKB) End Date Annotation 'Last Mod...'End Date -- Last Tag: 11,231.0 10/12/2006 Rev Reason:WELL REVIEW I osborl 7/17/2012 HANGER,23----- :I Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f... Set Depth(TVD)... String WL. String... String Top Thrd 14 II ; P CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED Casing Description SMng 0... String ID...Top(1H(B) Set Depth(L_ Sat Depth(ND)_. String WL. String_. String Top Thrd SURFACE 95/8 8.835 27.9 3,072.5 2,416.8 40.00 L-80 BTC •Casing Description String 0... String ID�Top pub) Set Depth(L_ Sat Depth(ND)_. String WL. Stri g_ String Top Thrd PRODUCTION 7 6276 25.5 10,753.5 6,126.9 26.00 L-80 BTC-MOD Casing Description String 0... String ID_,Top(ftKB) Set Depth(L_ Set Depth(TVD)_ String WL..String... String Top T1rd LINER 31/2 2.992 10,588.1 11,314.0 6,375.2 9.30 L-80 SLHT Liner Details Top Depth CONDUCTOR. _� (ND) Top Ind NOmI... 28-110 Top(ftKB) IR(B) (1 Item DescriptionComment ID(In) 1 — 10,588.1 6,047.1 61.46 PACKER BAKER ZXP LINER PACKER w/HR PROFILE 4.408 NIPPLE,511 - )t 10,606.9 6,056.1 61.48 NIPPLE BAKER RS NIPPLE 4.250 10,609.6 6,056.7 60.74 HANGER BAKER FLEX LOCK II DG HYD ROT LINER HANGER 4.400 10,619.0 6,061.3 60.76 SBE SBE 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings ligginglINIPMF Tubing Description String 0... String ID...Top(ftKB) Set Depth(f... Set Depth(TVD)... String WL.. String... String Top Thrd GAS LIFT, it TUBING 31/2 2.992 23.2 10,592.7 6,049.3 9.30 L-80 EUE8RD 3,046 II Completion Details Top Depth (ND) Top Ind Nomi... Top(81KB) IRKB) (') hem Description Comment ID(In) SURFACE, 23.2 23.2 0.31 HANGER FMC GEN V TUBING HANGER 3.500 28-3,072 511.3 511.1 3.81 NIPPLE CAMCO DS NIPPLE NO GO 2.875 10,537.1 6,022.7 61.42 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 GAS LIFT' 5,723 10,553.6 6,030.6 61.43 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,591.5 6,048.7 61.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 Perforations&Slots - Shot Top(ND) Btn(TND) Dens Top(ftKB) Btm MKS) MKS/ 1M) Zone Date 01 Type Comment GAS LIFT, " 11,018.0 11,028.0 6,246.0 6,250.3 C-4,2L-03 3/12/2002 6.0 IPERF 2.5"HSD 2505HJ RDX Chgs,60 deg 8,117 Phase Stimulations&Treatments Bottorn Min Tap Max Bbn Top Depth Depth Depth Depth (ND) IND) ( ) fly) MIB) (ftKB) Type Date Comment 1 11,018.0 11,028.0 6,246.0 6,250.3 FRAC 3/26/2002 C-SAND FRAC GAS LIFT, g Notes:General&Safety 9,700 End Date Annotation ----- - _ 1 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 I > GAS LIFT, 10,487 II I SLEEVE, 10,537 I, NIPPLE,10,554 0., 1 a / \ III SEAL ASSY, 10,591 UNSCANNED, OVERSIZED MATERIALS AVAILABLE: o~t.~ / v~3 `1~ FILE # ~ - ~~~~ ~ ~~~ ~~~o ~~ ~. - ~ ,;~ r~t~ ~- rv To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 ~ Fax (907) 276-7542 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 10~~:~~~ ~~~ ®~ Z~~~ Anchorage, AK 99501 Dear Mr. Maunder: ati,- ~~ Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, on Arend ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Welt 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 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9!9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • • ConocoPhillips ~~ P.O. BOX 100360 AIAGE,ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~ ~l~`Lr S~ 2at~~ Dear Mr. Maunder: R,~G~ per !~'~a Ai$$ke an& ~ 4 ~ 2 p p, $sC ~'0 `4tp9 as ~- ~-3g Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, i` M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • C ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Tap-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28!2007 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 2L-803 201.239 T 7" 1.2 18" 9/9/2007 7.5 9i16J2007 2t.-309 x-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9t1Bl2tM)T 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/18/2007 2N-303 200-169 5" n/a 5" n/a 1 9/2X2047 2N-304 201-130 10" Na 10" n/a 4.5 9/2T1~7 2N-305 Z00-135 12" n!a 12" nfa 7.5 9t27/2t~7 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27>2~7 2N-309 199.021 9" n/a 9" Na 2 9/27!2007 2N-311 206.179 12" n/a 12" n/a 10 9!2712007 2N-313 t96-~1 5" Na 5" n/a 2 9/27!2007 2N-314 200-193 26" n/a 26" n/a 7 9127/27 2N-315 19&190 6" n/a 6" n/a 3 9/277 2N-3i7 188.143 5" nfa 5" n/a 1 9/27/2007 2N-318 200-1~0 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9!2712007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc RE: Status of2L-03 ) dØt-d-~S Subject: RE: Status of 2L-03 . . ",\. " fA,. ,,\. ,PIG From: "Dahlgren, Eric" <Eric.Dahlgren@conocophillips.com> ~ lM:,'\' - \ v Date: Tue, 29 Mar 2005 15 :54:43 -0900 ~ To: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com>, Thomas Maunder <tom_ maunder@admin.state.ak.us> CC: "Lowry, Scott L" <Scott.L.Lowry@conocophillips.com> ) Tom this well was never tied into the Trunk and Lateral surface piping at Tarn 2L because the post frac rates through the portable test separator were sparse and very heavy in Tar content. The plans for this well are either a sidetrack or try a surface powered jet pump to improve fluid viscosity with water heat. Both of these ideas are being studied, but there are no current plans to implement either one. (Q~~~~~y ~{S~~~ ,To þ~ s"''\~ +~(è ~t:\\.~~~Jó ~ b~~\,,~D &~~"Ð\C ~~~II\-..-\\-.¡ 'ç\-\~G.. ~. r. 1(~. ~~ ~\+~~.-\- Ù.~l.~N1-.\.-.WC\~ *-4-·cs~~ ~ ~.\ \D~A-2-' L~.. ~...~¿).' "...' -----Original Message----- From: Allsup-Drake, Sharon K Sent: Tuesday, March 29, 2005 3:45 PM To: 'Thomas Maunder' Cc: Lowry, Scott L; Dahlgren, Eric Subject: RE: Status of 2L-03 Regards, Eric W. Dahlgren 700 G Street ATO 1204 Anchorage, AK 99510 907 -265-684 7 no, we haven't sent any paperwork over since April 2002. The well had little production and has been shut-in ever since. Thanks, Sharon office phone: 263-4612 fax: 265-6224 SCANNED JUN 1. L1 2005 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 29, 2005 3:31 PM To: Allsup-Drake, Sharon K Subject: Re: Status of 2L-03 Sharon, Have you submitted any paperwork on it?? What is the problem?? Tom Allsup-Drake, Sharon K wrote: Tom- lof2 3/31/2005 12:48 PM RE: Status of 2L-03 20f2 ) ) I am asking for your advice about how to change the status of a well, 2L-03, from producer to suspended. We completed the well in March 2002 but have not flowed it. Do we need to submit paperwork to change this well's status? Thanks, Sharon office phone: 263-4612 fax: 265-6224 3/31/2005 12:48 PM RE: Status of2L-03 ) ) Subject: RE: Status of2L-03 From: "Dahlgren, Eric" <Eric.Dahlgren@conocophillips.com> Date: Mon, 04 Apr 2005 10:06:43 -0800 To: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com>, Thomas Maunder <tom_ maunder@admin.state.ak.us> Eric dO \ ~ " :-<... ~.' \ a-- ,-....1 '-Jl Sounds good . , -----Original Message----- From: Allsup-Drake, Sharon K Sent: Friday, April 01, 2005 11:32 AM To: 'Thomas Maunder' Cc: Dahlgren, Eric Subject: RE: Status of 2L-03 Tom - this sounds like an acceptable plan. .;5'CANNED APR 0 5 2.005 Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, March 31, 2005 1:20 PM To: Dahlgren, Eric Cc: Allsup-Drake, Sharon K; Lowry, Scott L Subject: Re: Status of 2L -03 Eric, Sharon and Scott, I would suggest that you keep this well as an oil production well that is S1. This takes no new paperwork and is descriptive of the wells condition. If you change it to a suspended category, then doing work on the well can become a paperwork hassle. Let me know you decision and then I will place a copy of this note in the file. Tom Maunder, PE AOGCC Dahlgren, Eric wrote: Tom this well was never tied into the Trunk and Lateral surface piping at Tarn 2L because the post frac rates through the portable test separator were sparse and very heavy in Tar content. The plans for this well are either a sidetrack or try a surface powered jet pump to improve fluid viscosity with water heat. Both of these ideas are being studied, but there are no current plans to implement either one. Regards, 10f2 4/5/2005 8:26 AM RE: Status of2L-03 20f2 ) ) i Eric W. Dahlgren 700 G Street ATO 1204 Anchorage, AK 99510 907 -265-684 7 (1,0 1- :139 -----Original Message----- From: Allsup-Drake, Sharon K Sent: Tuesday, March 29, 2005 3:45 PM To: 'Thomas Maunder' Cc: Lowry, Scott L; Dahlgren, Eric Subject: RE: Status of 2L -03 no, we haven't sent any paperwork over since April 2002. The well had little production and has been shut-in ever since. Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 29, 2005 3:31 PM To: Allsup-Drake, Sharon K Subject: Re: Status of 2L-03 Sharon, Have you submitted any paperwork on it?? What is the problem?? Tom Allsup-Drake, Sharon K wrote: Tom- I am asking for your advice about how to change the status of a well, 2L-03, from producer to suspended. We completed the well in March 2002 but have not flowed it. Do we need to submit paperwork to change this well's status? Thanks, Sharon office phone: 263-4612 fax: 265-6224 6C,ANNEO .!~PH ~.) 5 2005 4/5/2005 8:26 AM II plV')(..)~~t DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2012390 Well Name/No. KUPARUK RIV UNIT 2L-03 Operator CONOCOPHILLlPS ALASKA INC S:p ~ ¿ G f:{¿;¿ 0 (j ~ API No. 50-103-20398-00-00 MD 11316 ------ TVD 6376 '~Completion Date 3/12/2002 -- Completion Status 1-01L Current Status 1-01L UIC N ~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~/ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Data Digital J.~ 'Med/Frmt ¡ Rpt clED C U-ED D Electr Dataset Numbe~me LIS Verification U0748 See Notes Log Log Run Scale Media No 1 Interval Start Stop 55 11261 110 11316 OHI CH Received Comments Open 5/24/2002 Open 4/5/2002 final well report received digitally --- c..-+- ED C C-to855 LIS Verification vrf 551 See Notes 55 11261 Open 5/24/2002 110 11316 Case 2/28/2003 Digital Well Logging Data >---- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? @N é§)N ---' Chips Received? --y-f-N-- Formation Tops Analysis Received? . Y / N Comments: M CL 1 41 fI¡ \ ì t-;"l I/W~ fu v('~, ~ Lù l() tt^ K 0 D;Vl /, Compliance Reviewed By: \~CJ Date: I ~ A-r~' ÅU-{J 'i } ") , ó10/-;)3C¡ / /55; 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 February 27, 2003 RE: MWD Fonnation Evaluation Logs 2L-03, AI(-MW -22024 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 2lr03: Digital Log Images 50-103-20398-00 1 CD Rom ~~ RECEIVED FEB 28 2003 Alaska Oii & Gas Cons. Commi . Anchorage seton ) að/-a3, J 0 aSs WELL LOG TRA.NSMITT AL To: State of Alaska Alaska Oil and Gas Conservation C01nnl. Attn.: Lisa Weepie 333 West 7tl\ Avenue, Suite 100 Anchorage, Alaska May 14, 2002 RE: MWD Fonnation Evaluation Logs 2L-03, AK-MW-22024 1 LDWG formatted Disc with verification listing. API#: 50-103-20398-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: s¡gnd V ~ RECEIVED t,t~y' 2 ¡~. 2002 Ala8ka 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 April 9, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2L-03 (201-239) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 2L-03. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, ~-'--=l\ ~--~ R. Thomas Greater Kuparuk Team Leader P AI Drilling RT/skad RECEIVED APR 9 2002 Al8aOil&GlsCOnl.Commission An1J~& I ORt(J\~jAL ') 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 [2] Gas 2. Name of OperatDr Phillips Alaska, Inc. 3, Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location Df well at surface D Suspended D Abandoned D Service D 7. Permit Number 201-239 1 8, API Number ¡i,"'*"~" ""'.- ..', ~'. ",,. ~'~ 143' FNL, 544' FEL, Sec. 22, T10N, R7E, UM ~ iì;,T': "(ASP: 461107, 5927702) At Top Producing Interval"~ 3.Î z . () z) 1483' FSL, 961' FEL, Sec. 11, T10N, R7E, UM '~;.....'i. '.-;(j~.E:iiic!.". ... (. 4,SP: 465995, 5934583) At Total Depth~1 --.¡All,., q.-! 1730' FSL, 796' FEL, Sec. 11, T10N, R7E, UM ,q"'''\i'''''''''''''''''''.''"'~''''''(ASP: 466161, 5934829) 5. Elevation in feet (indicate KB, DF, etc.) 6, Lease Designation and Serial No. RKB 27' ADL 380049 ALK 4597 12. Date SPudded~' )'k 13, Date T.D. Reached 14. Date Comp" Susp. Or Aband':á- 15. Water Depth, if offshore , 1) fI,(d.-t':'¿J., / .z,..J "ZðC'.1- February, ,2002 February 22,2002 ret,udlY 2Gt2u02 -. N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 11316' MD 16376' TVD 11217' MD 16333' TVD YES [2] No D Landing Nipple @ 511' 22. Type Electric or Other Logs Run GR/Res, NeutlDens 23. 2l6cA't~~J jV~':, -.~SUrf.~i !~~gil 50-103-20398-00 9, Unit or Lease Name Kuparuk River Unit 10. Well Number 2L-03 11. Field and Pool Kuparuk Oil Pool Kuparuk River Field 16. No. of Completions 21. Thickness of Permafrost 1747' 16" WT. PER FT. 62.5# 40# 26# 9.3# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3072' Surface 10754' 10588' 11314' HOLE SIZE CASING SIZE 24" CEMENTING RECORD 9 cu yds High Early 485 bbl AS III Lite, 118 bbl LiteCrete 376 sx Class G, 168 sx Class G 35,7 bbls Class G AMOUNT PULLED 9.625" 12,25" 7" 8.5" 3.5" 6.125" 24. Perforations open to PrDduction (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 10585' PACKER SET (MD) 10588' & 10595' 11018' - 11028' MD 6246' - 6250' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11018' - 11028' 73290# of 16/20 proppant behind pipe with 7,3 ppa on perfs 27. Date First Production N/A Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Shut In GAS-MCF Production for OIL-BBL W A TER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Test Period> Calculated 24-Hour Rate> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. Rt:Ct:IVt:U N/A APR 9 2002 Alaska Oil &GasCOnl.CoInniIsion AndtorIge Form 10-407 Rev. 7-1-80 CONTINUEr¡(b)J., FfB. . W~R~.. - S~D~ f. .." ~ .~ t.7 I, ~ :1; '\ n ~, I \, jiJi I: H LQBDMS 8Ft Submit in duplicate \~ 'ï--' APR 2 9 2002 29. ) 30. ') GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recDvered and gravity. GOR, and time of each phase. Kuparuk C Kuparuk A 1 0986' 11 032' 6232' 6252' Annulus left open - freeze protected with diesel. RECEIVED APR "9 2002 Ala8kaOil&Gas Cons. QInmission Ancløage 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 Mark Chambers 265-1319 ~~ ' ~" . \ - Signed - \ ~ . .1 Exploration Drillinq Team Leader .~ P. Mazzolini Date '-( (e¡ (o'~ 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 ""''\ r. ~ S t, ,r f./ ~ . : , \, 1 ~ ~ \, I, ~ ~ '\ I! ~,.,,: \1 (.) \~ '\~ ".'~ ~ I, ~"F>"'" ) ~~ ~ ) PHILLIPS. ALASKA INC. . OperationsSUmm'aryRE:!port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2L-03 2L-03 ROT - DRILLING n1334@ppco.com Doyon 141 Date Sub From-To Hours Code Code Phase 2/2/2002 00:00 - 04:00 4.00 MOVE DMOB MOVE 04:00 - 00:00 20.00 MOVE MOVE MOVE 2/3/2002 00:00 - 04:00 4.00 MOVE POSN MOVE 04:00 - 08:00 4.00 MOVE OTHR SURFAC 08:00 - 22:00 14.00 DRILL OTHR SURFAC 22:00 - 00:00 2.00 WAlTON WOW SURFAC 2/4/2002 00:00 - 00:00 24.00 WAlTON WOW SURFAC 2/5/2002 00:00 - 18:00 18.00 WAlTON WOW SURFAC 18:00 - 00:00 6.00 DRILL PULD SURFAC 2/6/2002 00:00 - 08:00 8.00 DRILL PULD SURFAC 08:00 - 09:00 1.00 DRILL OTHR SURFAC 09:00 - 10:30 1.50 DRILL PULD SURFAC 10:30 - 13:00 2.50 DRILL DEQT SURFAC 13:00 - 15:30 2.50 DRILL DRLG SURFAC 15:30 - 16:30 1.00 DRILL PULD SURFAC 16:30 - 00:00 7.50 DRILL DRLG SURFAC Page 1017 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations Finish cleaning mud pits, pickup in cellar, c lean and disconnect rockwasher, blow down rig and camp and prepare for move. Rig mo ve delayed due to 16E camp move to meltwa ter blocking roads and availability of trucks Rig released @ 0400 hrs, camp started movi ng to 2L @ 0730 hr followed by truck shop, r ock washer and pits, followed by rig com pie x. All rig components on 2L location @ 193 0 hr. Weather conditions and road conditio n-rough contributed to longer than normal m ove of 8.5 miles. Finish spotting rig complexes, rockwasher a nd pipesheds. Rig Accepted @ 0400 hrs 02/0 3/2002 Prepare rig for spud, install riser and flowli ne, prepare pits for spud mud, offload spud mud fItrucks, prepare pipe shed and load w/ drillpipe, change top drive saver sub, chang e out mud bucket rubbers, change out hand Ii ng tools, finish loading pipeshed w/bha and strap same. Accumulator test, function test diverter syst em, calibrate gas detectors, witnessing waiv ed by John Spaulding-AOGCC. Phase 3 weather, suspended picking up pipe and all at risk work. Service rig & top driv e, resecure service loop rings, change out t op drive grabber, general maintenance. Waiting on phase III weather. General main tenance and inspection of equipment. Runni ng out of zerks and grease. Continue to wait on phase III weather. Gen eral maintenance, change out bottom pipe ra ms on stack. Wind abating, p/u 5" drillpipe and stand bac k in derrick. Finish picking up 5" drillpipe & HWDP, stan d back in derrick. Dig diverter line out of snowdrifts and secur e. P/U motor and bit, wash snow and ice fIcond uctor f/47-110'. P/U bha, mwd, stabilizer, h.o.s., install pro be, orient & initialize mwd, held pre-spud m eeting w/new crew, finish programing mwd to ols. Spud & drld 12-1/4" surface f/110-261', ART 2.0 HRS. Stand back 2 hwdp, p/u 1 std 8" drill clrs & 1 std hwdp. Drilled f/261'-800', KOP @300', ART 1.3 HR, Printed: 3/14/2002 2: 14:00 PM ~þ ~ ') ') Page 2 of7 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/6/2002 2/7/2002 2/8/2002 2/9/2002 2/10/2002 Date 2L-03 2L-03 ROT - DRILLING n1334@ppco.com Doyon 141 Sub From- To Hours Code Code Phase 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations 16:30 - 00:00 00:00 - 13:00 7.50 DRILL DRLG SURFAC A S T 4. 5 HR. 13,00 DRILL DRLG SURFAC Dr ill e d f 1800 - 2 007', ART 3.6 H R, AS T 4.9 H R 13:00 - 14:00 14:00 - 15:30 1.00 DRILL CIRC SURFAC 1.50 DRILL WIPR SURFAC 0.50 DRILL WIPR SURFAC 8.00 DRILL DRLG SURFAC 7.00 DRILL DRLG SURFAC 1.00 DRILL CIRC SURFAC 0.50 DRILL OBSV SURFAC 1.00 DRILL WIPR SURFAC 0.50 DRILL WIPR SURFAC 2.50 DRILL CIRC SURFAC 15:30 - 16:00 16:00 - 00:00 00:00 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 12:30 12:30 - 17:00 4.50 DRILL TRIP SURFAC 17:00 - 20:00 3.00 DRILL PULD SURFAC 20:00 - 21 :30 1.50 CASE OTHR SURFAC 21 :30 - 23:30 2.00 CASE RUNC SURFAC 23:30 - 00:00 0.50 CASE CIRC SURFAC 00:00 - 01 :00 1.00 CASE CIRC SURFAC 01 :00 - 07:00 6.00 CASE OTHR SURFAC 07:00 - 08:30 1.50 CASE OTHR SURFAC 08:30 - 09:00 0.50 DRILL WIPR SURFAC 09:00 - 10:00 1.00 DRILL TRIP SURFAC 10:00 -11:30 1.50 DRILL REAM SURFAC 11 :30 - 12:30 1.00 DRILL CIRC SURFAC 12:30 - 14:00 1.50 DRILL TRIP SURFAC 14:00 - 15:30 1.50 CASE OTHR SURFAC 15:30 - 19:00 3.50 CASE RUNC SURFAC 19:00 - 19:30 0.50 CASE CIRC SURFAC 19:30 - 20:30 1.00 CASE RUNC SURFAC 20:30 - 23:30 3.00 CASE RUNC SURFAC 23:30 - 00:00 0.50 CASE CIRC SURFAC 00:00 - 04:00 4.00 CEMENTCIRC SURFAC 04:00 - 05:00 1.00 CEMENT SEaT SURFAC 05:00 - 08:00 3.00 CEMENT PUMP SURFAC Circulate hole clean. Wiper trip to hwdp @ 1080'. hole clean, no t ight spots. RIH; wash 30' to bottom, no fill. Drilled f/2007-2600', ART 3.1, AST 3.6 HR. Drilled f/2600-3093', ART 4.0, AST 1.2 HR. Pump hi-vis weighted sweep, circulate until c lea n. Monitor well, blow down top dripe. Short trip to 2007', hole clean, no tight spot s. RIH, wash 60' to bottom, no fill. Circulate and condition, max gas 295 units @ 1400' lag depth, 160 units on bottoms up, Monitor well, no flow. Pump hi-vis sweep, finish circulating and conditioning mud. Monitor well, pump slug, POH. LID bha, download mwd, clear floor. PJSM, rig up csg equipment. Run 26 jts 9-5/8" csg, hit bridge @ 1084'. Circulate & wash on bridge. Circulate and wash on ledge/bridge to 1089' , unable to wash or rotate through. POH laying down casing. Change out pipe handling equipment, clear f 100 r. P/U drlg bha, 1 std HWDP, xo, nb stab, bit. RIH to 1089', hit bridge/ledge. Wash & ream tight spots/ledges @ 1079-108 9',1118-1122',1155-1171'. Circulate and condition hole. POH, monitor well. PJSM, rig up to run casing. Run casing to 1910'. Circulate and condition mud & hole. Continue running casing wash thru restrictio n f/2013-2045'. Continue runninjg casing f/2045-3072', wash f/2813-2890', land w/casing hanger. Establish & stage up circulation rate, condit ion mud. Circulate and condition hole and mud for ce menting. PJSM, lid Franks fill up tool, plu cementing plug head, batch up. Pump 5 bbls CW100, stopped pumping to rep lace leaking seal in cementing head xo. Cement, pump 5 bbl CW100, test lines, pum p 40 bbl CW100, drop btm plug, pump 43 bbl 10 ppg mud push wired dye, 485 bbl lead, @ 10.75 ppg, followed by 118 bbl 12.0 ppg t Printed: 3/14/2002 2:14:00 PM .) t;Hi~þ ~ ) Page 3 of 7 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2L-03 2L-03 ROT - DRILLING n1334@ppco.com Doyon 141 Sub Hours Code Code . Phase Date From - To 2/10/2002 05:00 - 08:00 3.00 CEMENT PUMP SURFAC 08:00 - 10:00 2.00 CEMENT PULD SURFAC 10:00 - 12:00 12:00 - 13:00 2.00 WELCTL NUND SURFAC 1.00 CASE OTHR SURFAC 13:00 - 15:00 2.00 CASE NUND SURFAC 15:00 - 18:00 18:00 - 22:00 3.00 WELCTL NUND SURFAC 4.00 WELCTL BOPE SURFAC 22:00 - 22:30 0.50 DRILL OTHR SURFAC 22:30 - 23:00 0.50 DRILL PULD SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 2/11/2002 00:00 - 03:30 3.50 DRILL PULD INTRM1 03:30 - 05:00 1.50 DRILL TRIP INTRM1 05:00 - 07:30 2.50 DRILL CIRC INTRM1 07:30 - 08:30 1.00 DRILL OTHR INTRM1 08:30 - 11 :00 2.50 DRILL DRLG INTRM1 11 :00 - 13:00 2.00 DRILL CIRC INTRM1 13:00 - 14:00 1.00 DRILL FIT INTRM1 14:00 - 18:00 4.00 DRILL DRLG INTRM1 18:00 - 18:30 0.50 DRILL CIRC INTRM1 18:30 - 20:00 1.50 DRILL TRIP INTRM1 20:00 - 00:00 4.00 DRILL PULD INTRM1 2/12/2002 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 02:00 1.50 DRILL TRIP INTRM1 02:00 - 02:30 0.50 DRILL CIRC INTRM1 02:30 - 03:00 0.50 DRILL DEQT INTRM1 03:00 - 00:00 21.00 DRILL DRLG INTRM1 2/13/2002 00:00 - 01 :00 1.00 DRILL DRLG INTRM1 01 :00 - 02:30 1.50 DRILL CIRC INTRM1 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations ail, kick out top plug w/5 bbl water and disp lace w/mud w/rig. bumped plugs w/1000 psi over circulating press (1500 psi), cement to surface, full returns throughout taking retu rns w/vacumn trucks thru conductor outlets. CIP @ 0750 HR. 314 BBL excess cmt. Rig down cementing equipment, lid landing j t. Nipple down diverter system. Prepare well head and rig down cementing/c asing equipment on floor. Orient, n/u Gen V well head, test packoff to 1000 psi f/10 min. N/U 13-5/8" bope. Test BOPE, 5000 hi, 250 low, annular 250/3 500#, test gas detectors, well & mud monito ring equipment, full accumulator test, witne ssing waived by Sheave-AOGCC. Install wear ring. P/U bha tools & steam thaw. Make up bha #3. BHA-m/u bit, stabs, Iwd, mwd, orient, plu Iw d, install probe, mlu xo, nm dclr, initialize mwd. RIH to 2990', thick clabbered mud plugging flowline on trip in. Condition clabbered mud. Test 9-5/8" csg to 2500 psi f/30 minutes-ok. Drill cement & float equipment & 20' new hol e to 3113'. Circulate and condition, displace hole w/new mud. Perform FIT to 16.0 ppg. E.M.W.. Drilled f/3113-3434', ART 2.6 HR. mwd failu reo Circulate bottoms up, preparing to poh for m wd. Monitor hole, pump dry job, poh, flow check @ shoe. BHA, stand back hwdp w/jars, std nm dclrs, remove radioactive sources, download mwd, change out mwd directional sub, orient moto r, load mwd. Finish making up bha. Initilize mwd, load so urces and test same. Trip in hole with bha 3344' Circulate capacity of dp and annulus. Perform PWD baseline. Directional drill 3344'-5384' Art Hrs-13.0 H rs, Ast-.5 Hrs. 5-10K wob, 540 gpm, 100 rps ,2350 psi, 7-9000 ft Ib torque. Drlg. from 5384' to 5477'. Pump 40 bbls. weighted hi vis sweep followe Printed: 3/14/2002 2: 14:00 PM ) ~. ~ ) Page 4 of 7 PHILLIPS ALASKA INC. Operations Summary 'Report Legal Well Name: 2L-03 Common Well Name: 2L-03 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From-To Hours Code Sub Phase Code 2/13/2002 01 :00 - 02:30 1.50 DRILL CIRC INTRM1 02:30 - 03:30 1.00 DRILL WIPR INTRM1 03:30 - 05:00 1.50 DRILL OTHR INTRM1 05:00 - 06:30 1.50 DRILL WIPR INTRM1 06:30 - 00:00 17.50 DRILL DRLG INTRM1 2/14/2002 00:00 - 06:00 6.00 DRILL DRLG INTRM1 06:00 - 07:30 1.50 DRILL CIRC INTRM1 07:30 - 09:30 2.00 DRILL WIPR INTRM1 09:30 - 11 :00 1.50 DRILL OTHR INTRM1 11 :00 - 12:30 1.50 DRILL WIPR INTRM1 12:30 - 13:30 1.00 DRILL REAM INTRM1 13:30 - 00:00 10.50 DRILL DRLG INTRM1 2/15/2002 00:00 - 09:00 9.00 DRILL DRLG INTRM1 09:00 - 11 :00 2.00 DRILL CIRC INTRM1 11 :00 - 13:00 2.00 DRILL WIPR INTRM1 13:00 - 14:00 1.00 DRILL OTHR INTRM1 14:00 - 00:00 10.00 DRILL DRLG INTRM1 2/16/2002 00:00 - 00:00 24.00 DRILL DRLG INTRM1 2/17/2002 00:00 - 00:30 0.50 DRILL DRLG INTRM1 00:30 - 03:30 3.00 DRILL CIRC INTRM1 03:30 - 06:30 3.00 DRILL WIPR INTRM1 06:30 - 09:30 3.00 DRILL CIRC INTRM1 09:30 - 15:00 5.50 DRILL TRIP INTRM1 15:00 - 20:00 5.00 DRILL PULD INTRM1 20:00 - 21 :30 1.50 DRILL OTHR INTRM1 21 :30 - 00:00 2.50 DRILL OTHR INTRM1 2/18/2002 00:00 - 13:00 13.00 CASE RUNC INTRM1 13:00 - 16:30 3.50 CASE CIRC INTRM1 16:30 - 19:00 2.50 CEMENT PUMP INTRM1 19:00 - 19:30 0.50 CEMENTOTHR INTRM1 19:30 - 20:30 1.00 CEMENTOTHR INTRM1 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations d by 20 bbls. hi vis sweep. Circ. till hole cl ea n. POH to shoe. Cut drlg. line & service top drive. Trip in-survey @ 3251'-wash last stand to b ottom. Drlg. & surveys from 5477 to 6685'. Drlg. & surveys from 6685' to 7150'. Pump tandem sweeps-cbu x 3-pump pill & bl ow down top drive. POH to 9 5/8" shoe. Change out & test swivel washpipe & packin g. RIH to 7059'. Causion wash & ream from 7059' to 7150'-ci rc. out thick mud. Drlg. from 7150 to 7985'. (TVD 4983') Drlg. & surveys from 7985' to 8600'. Pump 40 bbl. hi vis sweep & cbu x 3. Wiper trip to 7150' & back to 8453'.(hole in good condition-no tight spots) Mad pass from 8453' to 8600'. Drlg. & surveys from 8600' to 9180'. Drlg. & surveys from 9180' to 7128'. Drlg. & surveys from 10728' to 10773'. (TD) Formation tops:=lceburg 7469' MD.=Bermud a 9081' MD=HRZ top 10380' MD=HRZ Bottom 10685'.MD Pump tandem hi vis sweeps-cbu x 3-Monitor well pump pill & blow down top drive. Wiper trip to 8600'-tight @ 9908'. Pump sweep-cbu x 3-Maximum gas-580 units on bottoms up-spot lube pill-monitor well-bl ow down top drive. POH to run 7" csg.-flow check @ shoe-pipe pulled clean. Lay down hwdp & bha-down load & clear flo 0 r. Pull wear ring-install test plug-change top r ams to 7"-test same 250-5000#. Change bails on top drive. Run 251 jts. 7" 26# csg.-Circ. capacity of c sg. @ 9 5/8" shoe @ 3072'.-break circ. @ 55 00'-8100' & 9100'. Make up landing jt. & han 9 e r. Circ. condition mud for cementing. Test cement lines to 3500#-cement well as p er program-bump plug @ 1900 hrs. lost 12 b bls. while pumping cement. Rig down cement head & lay down landing jo in t. Set 7" packoff & test same to 5000# 10 mins Printed: 3/14/2002 2: 14:00 PM ) aHi~ìPS'~ ~ ') PHILLIPS ALASKA INC. Operations $ummary' Report Legal Well Name: 2L-03 Common Well Name: 2L-03 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From-To Hours Code Sub Phase Code 2/18/2002 20:30 - 22:30 2.00 CEMENTOTHR INTRM1 22:30 - 00:00 1.50 CEMENT OTHR INTRM1 2/19/2002 00:00 - 04:00 4.00 DRILL OTHR PROD 04:00 - 04:30 0.50 DRILL OTHR PROD 04:30 - 13:30 9.00 DRILL PULD PROD 13:30 - 15:00 1.50 DRILL PULD PROD 15:00 - 16:00 1.00 DRILL OTHR PROD 16:00 - 21 :00 5.00 DRILL PULD PROD 21 :00 - 21 :30 0.50 DRILL DEOT PROD 21 :30 - 00:00 2.50 DRILL PULD PROD 2/20/2002 00:00 - 06:00 6.00 DRILL PULD PROD 06:00 - 07:30 1.50 DRILL CIRC PROD 07:30 - 08:30 1.00 DRILL DEOT PROD 08:30 - 14:30 6.00 DRILL OTHR PROD 14:30 - 15:30 1.00 DRILL CIRC PROD 15:30 - 16:00 0.50 DRILL LOT PROD 16:00 - 17:30 1.50 DRILL CIRC PROD 17:30 - 18:30 1.00 DRILL OTHR PROD 18:30 - 00:00 5.50 DRILL DRLG PROD 2/21/2002 00:00 - 05:00 5.00 DRILL DRLG PROD 05:00 - 07:30 2.50 DRILL OTHR PROD 07:30 - 08:30 1.00 DRILL DRLG PROD 08:30 - 00:00 15.50 DRILL OTHR PROD 2/22/2002 00:00 - 07:00 7.00 DRILL OTHR PROD 07:00 - 10:30 3.50 DRILL DRLG PROD 10:30 - 00:00 13.50 DRI LL CIRC PROD 2/23/2002 00:00 - 04:30 4.50 DRILL CIRC PROD 04:30 - 06:30 2.00 DRILL WIPR PROD 06:30 - 14:30 8.00 DRILL CIRC PROD 14:30 - 16:00 1.50 DRILL TRIP PROD 16:00 - 18:30 2.50 DRILL CIRC PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 00:00 - 02:30 2.50 DRILL PULD PROD 02:30 - 05:30 3.00 CASE PULR PROD 05:30 - 15:30 10.00 CASE RUNL PROD 2/24/2002 Page50f7 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations Change out bails-saver sub & grabbers on to p drive. Change out bottom & top set of rams on bop Rig up & test bope 250-5000# OK. (witness t est waived by John Spalding Aogcc) Pull test plug & set wear ring. Lay down 5" dp out of derrick. Pick up 27 jts. 4" HT-38 dp & stand in derri ck for drlg. Cut drlg. line & service top drive. Pick up & make up BHA. Test MWD. RIH picking up 4" dp. RIH picking up 4" HT 38 dp. to 10550'. Circ. & condition mud for csg. test. Test csg. 3500# 30 mins. OK. Clean out float collar-cement -shoe & drill t 0 10800 from 10773. Circ. condition mud for lot. Perform leak off test to 15.1#. Displace hole wi 12.2# mud. Establish PWD baselines. Drlg. & surveys from 10800 to 10976'. Drlg. & surveys from 10976' to 11171'. Lost returns-pump Icm pill & reestablish ret urn s . Drlg. from 11171 to 11198'. Lost circ.-attempting to regain circ.-mixing I em & new mud-1 load mud delivered from pia nt. Attempting to stop lost circ.-cutting mud wt. to 11.4# from 11.6#. Drlg. to td @ 11316'. Circ. hole-well trying to flow-Shut in wi 150 # on choke-circ. out-raise mud wt. to 11.6#- circ.-bled off total of 105 bbls. Circ.-attempting to stabilize well 11 running & cementing liner. Wiper trip-tight hole from 11060' to 10850'. Circ.-stable well for trip. (800 units gas on bottoms up after wiper trip.) Back ream from 11316' to 7" shoe @ 10753'. Circ. bottoms up-max gas 50 units-Monitor w ell-pump pill-blow down top drive. POH for liner-hole taking right amount of ho Ie fill. Lay down bha-remove source-download mwd. Rig up & make up 21 jts. 3.5" 9.3# L-80 SLH T liner-hanger & packer & pump capacity of sam e. Run liner in hole on 4" dp to 7" csg. shoe @ 10753'-make up cement manifold. Printed: 3/14/2002 2: 14:00 PM .) ~~ ~ ) PHILLIPS ALASKA INC. Operations Sumrnary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2L-03 2L-03 ROT - DRILLING n1334@ppco.com Doyon 141 Date From -To Hours Code Sub Phase Gode 2/24/2002 15:30 - 18:00 2.50 CASE CIRC PROD 18:00 - 19:00 1.00 CASE RUNL PROD 19:00 - 21 :00 2.00 CASE CIRC PROD 21 :00 - 22:30 1.50 CEMENT PUMP PROD 22:30 - 00:00 1.50 CEMENT OTHR PROD 2/25/2002 00:00 - 00:30 0.50 CEMENTCIRC PROD 00:30 - 01 :30 1.00 CEMENT PULD PROD 01 :30 - 12:00 10.50 CEMENT OTHR PROD 12:00 - 13:00 1.00 CMPL TN OTHR PROD 13:00 - 14:00 1.00 CMPL TN OTHR PROD 14:00 - 23:00 9.00 CMPL TN RUNT PROD 23:00 - 00:00 1.00 CMPL TN DEQT PROD 00:00 - 00:30 0.50 CMPL TN DEQT CMPL TN 00:30 - 02:00 1.50 CMPL TN SOHO CMPL TN 02:00 - 05:30 3.50 CMPL TN CIRC CMPL TN 05:30 - 06:30 1.00 CMPL TN NUND CMPL TN 06:30 - 08:00 1.50 CMPL TN DEQT CMPL TN 08:00 - 08:30 0.50 CMPL TN NUND CMPL TN 08:30 - 10:00 1.50 CMPL TN NUND CMPL TN 10:00 - 12:00 2.00 CMPL TN NUND CMPL TN 12:00 - 15:00 3.00 CMPL TN FRZP CMPL TN 2/26/2002 15:00 - 16:00 1.00 CMPL TN OBSV CMPL TN 16:00 - 19:00 3.00 CMPL TN OTHR CMPL TN 19:00 - 20:00 1.00 RIGMNT RSRV CMPLTN 20:00 - 22:00 2.00 RIGMNT RGRP CMPL TN 22:00 - 00:00 2.00 RIGMNT RGRP CMPL TN 2/27/2002 00:00 - 12:00 12.00 WAlTON OTHR MOVE Page 60f 7 2/2/2002 Spud Date: 2/3/2002 End: G rou p: Start: Rig Release: Rig Number: 141 Description of Operations CBU @ 20 spm-Iost 10 bbl. mud-50S gas unit s on bottoms up. Record-torque & wt.-rih to 11316'-no hole pr obi ems. Circ. condition hole for cementing. Mix & pump 30 bbls. cw100-25 bbls. mud pus h @ 12.5# & 35.7 bbls. cement @ 15.8# & di splace same wi 120 bbls. mud-bump plug. S et hanger wI dowel I @ 4200#. Set liner top packer & reverse circ.-recover ed 10 bbls. contaminated cement-mud push & cw100. Continue circulating to clean up d p. (reverse circulated @ max 2700# no mud losses.) Reverse circ.-clean up dp. Lay down cement manifold & XO,S.I Lay down 4" dp & 4" hwdp. Cut & slip drlg. line. Perform LOT on 9 5/8" X 7" annulus. (15.8) PJSM-run 3.5" tbg. as per program. Test & chart liner & packer top 3500# 30 mi ns. 0 K Continue testing casing to 3500# and rig do wn. Space out tubing. R/U & reverse circ, displacing well to seawa t e r . Land tubing and run in lock down screws. Test tubing, annulus and shear RP valve. Pull landing joint and in stall two way check va I ve. Nipple down BOPE. Nipple up tree & test to 5000/250# & packof f to 5000#. Pull twc, freeze tbg x ann w 79 bbl diesel d own annulus, returns thru tbg, u-tube to pro tect both sides, bullhead 50 bbl down 9-5/8 x 7" annulus. Shut in well, tbg and annulus pressures zer 0, set bpv and secure well. Finish cleaning pits, rock washer, suck out sumps and cellar. Service rig and top drive, perform hazards a ssessment on top drive. Break out used HT 38 saver sub and replace , install new stab guide assembly. Change out and prepare 4" pipe handling too Is for next well. Waiting on trucks for rig move to lookout #2 Rig maintenance, finish clo saver sub, se rvice top drive, change gear oil and filters 0 n top drive, service mud pumps, agitators, c entrifuge, service skate. Prespud meeting f Printed: 3/14/2002 2: 14:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/27/2002 ) ) Page 7 of? PHILLIPS ALASKA INC. Operations Summary Report 2L-03 2L-03 ROT - DRILLING n1334@ppco.com Doyon 141 2/2/2002 Spud Date: 2/3/2002 End: Group: Start: Rig Release: Rig Number: 141 Description of Operations Sub From:.. To Hours Code Code Phase 00:00 - 12:00 12:00 - 00:00 12.00 WAlTON OTHR MOVE 12.00 WAlTON OTHR MOVE or both crews and service personnel w/Tom Brassfield. Rig released f/2L-03 @ 1200 HR 2/27/02. Continue to wait on Nabors 18E rig move an d availability of trucks. CIO torque lines an d springs on tong lines. Remove #6 pit aggi tator f/bearing for repairs. Clean out mud p ump suction headers. Work on gas detector s & gaitronics communication system. Conti nue loading out trucks wlmud, pipe & miscel laneous equipment & prepare for rig move. Printed: 3/14/2002 2: 14:00 PM Date 03/04/02 03/08/02 03/09/02 03/10102 03/11/02 03/12/02 03/13/02 03/16/02 03/21/02 03/24/02 03/25/02 03/26/02 03/27/02 03/28/02 ) 2L-03 Event History ) Comment TAGGED SOFT @ 10,605' WLM (DRILLING MUD), PULLED 1.5" SOV & SET 1.5" DV @ 10,487' RKB, PT TBG & CSG TO 3000#. [TAG, PERF, MIT] CLEANED OUT MUD TO PBTD AT 11,190' CTM WI SLICK SEAWATER USING A 1.75" VORTECH DOWN- JET NOZZLE. WELL FREEZE PROTECTED WI DIESEL TO 2500'. [FCO, VORTECH] RIH W/HEAD/SWIVEU2 WT BAR/GUN-GRITOOLSAVERISAFE-HEAD/GUN, TAGGED SOFT AND STICKY FILL AT 10606 FT, MULTIPLE ATTEMPS TO GET DOWN, UNABLE TO GET DOWN, DECIDED TO POOH. TAGGED OBSTRUCTION IN TBG @ 10632' WLM. IN PROGRESS BROACHED TBG (-2.62") TO 11200'. DRIFTED TBG WI 2.565" X 11' 3"DUMMY GUN TO 11200' WLM (TARGET PERF AREA 11028'). PERFORATED SAND INTERVAL 11018' - 11028' WI 10' OF 2-1/2" HSD, 2505 HJ RDX CHGS, 6 SPF, 60 DEG PHASING. PRESSURED UP TBG TO 3800 PSI FOR EOB. TBG PRESSURE DROPPED TO 1300 PSI UPON PERFORATING. OBTAINED SBHP OF 3768 PSI AT 11023' (MID PERF) & BHT OF 168 DEG. INSTALLED OV @ 10487' RKB. [GLV] CIO OV @ 10487' RKB. OBTAINED SAMPLE OF HEAVY DRY ASPHALTINE TYPE SUBSTANCE IN TBG. @ 10573' WLM. [GLV, TAG] TAGGED @ 11633' RKB, EST. 5' RATHOLE. TIGHT SPOT @ 10638' RKB. [TAG] PULLED 1.5" OV @ 10487' RKB.SET 2.75" CRX PLUG @ 10553' RKB. LOAD IA W/215 BBLS OF SW WI 2300' DIESEL CAP. SET 1.5" SPARTEC SIDE POCKET GAUGE @ 10487' RKB.TEST IA TO 3500 PSI. NOTE: GAUGE WILL START FAST SAMPLE @ 08003/25/02 FOR 24 HOURS. LOST SPANGS @ 8100' SLM - DROPPED CUTTER BAR & RECOVERED ALL WIRE. CUTTER BAR & TOOL STRING IN HOLE. FISHED CUTTER BAR, TOOLSTRING & LOST ROLLER FROM WELL BORE. PULLED 2.75" CRX PLUG @ 10553' RKB. [FISH, OPEN-CLOSE A SAND] PLACED 73,290 LBS OF 16/20 PROPPANT BEHIND PIPE WITH 7.3 PPA ON PERFS. ENCOUNTERED HIGH TREATING PRESSURES DURING JOB. REDUCED GEL LOADING TO 30# FROM 40# AND PUMP RATE TO 16 BPM FROM 20 BPM TO REDUCE TUBULAR FRICTION PRESSURE. SCREENED OUT WELL. FISHED 1 COMPLETE & APPROX. 1/2 OF 2ND TREE SAVER RUBBERS LOST. [FISH] SET 5/16" OV WI CK @ 9699' RKB AND TESTED. [GLV] Page 1 of 1 4/1/2002 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 2L-03 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 11,316.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ') a QJ--¿)3 ~ 15-Mar-02 RECEIVED t,~..~ D f') O. "DO? " \. \ L L ... Alaska Oil & Gas Cons. Commïssion Anchorage DEFN - VE Kuparuk River Unit North Slope, Alaska Kuparuk 2L, Slot 2L-03 2L-03 Job No. AKMW22024, Surveyed: 22 Fet,ruary, 2002 ---' SUR VE Y R E PO R T 14 March, 2002 Your Ref: 501032039800 Surface Coordinates: 5927701.73 N, 461107.21 E (10012' 48.33868 N, 15012 18' 49.19858 W) Kelly Bushing: 144.6Oft above Mean Sea Level .~ !5pE!i ... 'y..SUJ1 DRU_L'N~ SEAvac:.s A Halliburton Company Survey Ref: svy9843 Sperry-Sun Drilling Services . Survey Report for 2L-03 DEF NITIVE Your Ref: 501032039800 Job No. AKMW22024, Surveyed: 22 February, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2L Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -144.60 0.00 O.OON O.OOE 5927701.73 N 461107.21 E 0.00 MWD Magnetic 110.00 0.000 0.000 -34.60 110.00 O.OON O.OOE 5927701.73 N 461107.21 E 0.000 0.00 185.58 0.270 1.270 40.98 185.58 0.18 N 0.00 E 5927701.91 N 461107.21 E 0.357 0.15 275.63 0.790 37.330 131.03 275.63 0.88N 0.39E 5927702.61 N 461107.60 E 0.659 0.94 367.95 2.360 41.120 223.31 367.91 2.82N 2.02E 5927704.54 N 461109.25 E 1.703 3.47 .-- 456.82 3.180 43.250 312.07 456.67 6.00N 4.91 E 5927707.70 N 461112.15 E 0.930 7.73 549.54 4.250 42.150 404.60 549.20 10.42 N 8.98E 5927712.10 N 461116.24 E 1.157 13.69 641.72 5.760 42.610 496.42 641.02 16.35 N 14.41 E 5927718.01 N 461121.70 E 1.639 21.66 730.72 7.930 40.870 584.78 729.38 24.28 N 21.45 E 5927725.90 N 461128.78 E 2.449 32.20 819.60 12.000 38.150 672.30 816.90 36.19 N 31.17 E 5927737.76 N 461138.57 E 4.608 47.53 910.36 15.970 36.970 760.36 904.96 53.59 N 44.51 E 5927755.09 N 461152.00 E 4.385 69.44 1001.69 17,790 36.060 847.75 992.35 74.91 N 60.28 E 5927776.33 N 461167.88 E 2.014 95.95 1094.78 19.620 34.800 935.92 1080.52 99.24 N 77.57 E 5927800.57 N 461185.30 E 2.013 125.80 1187.44 22,390 35.370 1022.41 1167.01 126.41 N 96.67 E 5927827.64 N 461204.53 E 2.998 159.01 1280.58 26.720 35.500 1107.11 1251.71 157.94 N 119.11 E 5927859.06 N 461227.13 E 4.649 197.71 1373.23 30.370 35.710 1188.48 1333.08 193.93 N 144.89 E 5927894.91 N 461253.09 E 3.941 241.97 1466.48 31.010 35.990 1268.67 1413.27 232.50 N 172.76 E 5927933.34 N 461281.17 E 0.703 289.56 1559.09 33.990 33.020 1346.78 1491.38 273.52 N 200.89 E 5927974.22 N 461309.51 E 3.649 339.30 1652.45 39.300 30.170 1421.66 1566.26 321.00 N 230.00 E 5928021.54 N 461338.86 E 5.971 394.88 1744.64 39.510 30.020 1492.89 1637.49 371.64 N 259.34 E 5928072.03 N 461368.46 E 0.250 453.18 1838.12 39.910 32.530 1564.81 1709.41 422.67 N 290.35 E 5928122.90 N 461399.73 E 1.768 512.76 ~ 1930.83 41.210 34.690 1635.25 1779.85 472.86 N 323.72 E 5928172.92 N 461433.36 E 2.064 573.02 2024.50 43.290 35.410 1704.58 1849.18 524.41 N 359.90 E 5928224.28 N 461469.80 E 2.280 635.99 2116.97 45.640 35.370 1770.57 1915.17 577.21 N 397.41 E 5928276.89 N 461507.58 E 2.542 700.76 2209.38 48.830 35.240 1833.31 1977.91 632.57 N 436.61 E 5928332.04 N 461547.07 E 3.454 768.59 2302.26 52.110 35.380 1892.42 2037.02 691.02 N 478.01 E 5928390.28 N 461588.77 E 3.533 840.22 2395.52 55.680 36.170 1947.36 2091.96 752.14 N 522.06 E 5928451.17 N 461633.14 E 3.889 915.55 2488.50 59.850 36.880 1996.95 2141.55 815.32 N 568.87 E 5928514.11 N 461680.27 E 4.531 994.15 2581.59 61.080 36.990 2042.84 2187.44 880.05 N 617.54 E 5928578.59 N 461729.27 E 1.325 1075.10 2674.45 62.260 36.160 2086.90 2231.50 945.70 N 666.24 E 5928643.98 N 461778.31 E 1.495 1156.81 .- ---+------ --- 14 March, 2002 - 17:42 Page 20f6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 2L-03 Your Ref: 501032039800 Job No. AKMW22024, Surveyed: 22 Febroary, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2l Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (')/1 OOft) 2767.16 61.430 34.690 2130.65 2275.25 1012.30 N 713.62 E 5928710.34 N 461826.03 E 1.660 1238.55 2859.50 62.840 34.260 2173.81 2318.41 1079.59 N 759.82 E 5928777.40 N 461872.59 E 1.581 1320.17 2952.50 62.470 33.160 2216.53 2361.13 1148.31 N 805.67 E 5928845.87 N 461918.79 E 1.123 1402.76 3018.17 62.380 33.950 2246.93 2391.53 1196.82 N 837.85 E 5928894.22 N 461951.21 E 1.075 1460.94 3179.93 62.080 35.570 2322.30 2466.90 1314.40 N 919.44 E 5929011.38 N 462033.41 E 0.905 1604.06 -~ 3272.73 61.950 35.740 2365.84 2510.44 1380.99 N 967.21 E 5929077.72 N 462081.52 E 0.214 1686.01 3361.00 61.750 35.810 2407.49 2552.09 1444.13 N 1012.71 E 5929140.63 N 462127.35 E 0.237 1763.83 3454.65 61.560 35.730 2451.95 2596.55 1511.01 N 1060.89 E 5929207.25 N 462175.87 E 0.216 1846.25 3548.49 61.580 36.300 2496.63 2641.23 1577.76 N 1109.41 E 5929273.75 N 462224.73 E 0.535 1928.76 3640.20 61.510 36.150 2540.32 2684.92 1642.80 N 1157.06 E 5929338.55 N 462272.72 E 0.163 2009.37 3733.17 61.400 35.720 2584.75 2729.35 1708.93 N 1204.99 E 5929404.43 N 462320.99 E 0.423 2091.03 3825.64 61.630 35.760 2628.85 2773.45 1774.90 N 1252.46 E 5929470.15 N 462368.80 E 0.252 2172.30 3918.69 61.660 35.870 2673.04 2817.64 1841.30 N 1300.38 E 5929536.31 N 462417.06 E 0.109 2254.18 4011.90 61.840 35.700 2717.16 2861.76 1907.91 N 1348.39 E 5929602.67 N 462465.41 E 0.251 2336.28 4104.59 61.880 36.050 2760.88 2905.48 1974.14 N 1396.29 E 5929668.65 N 462513.65 E 0.336 2418.01 4197.75 61.790 35.900 2804.85 2949.45 2040.60 N 1444.54 E 5929734.86 N 462562.24 E 0.172 2500.13 4290.21 61.910 36.250 2848.47 2993.07 2106.49 N 1492.54 E 5929800.50 N 462610.58 E 0.358 2581.64 4383.24 62.060 36.030 2892.17 3036.77 2172.82 N 1540.98 E 5929866.58 N 462659.36 E 0.264 2663.76 4476.11 60.900 34.100 2936.51 3081.11 2239.60 N 1587.86 E 5929933.12 N 462706.58 E 2.212 2745.35 4569.32 60.690 34.210 2981.99 3126.59 2306.92 N 1633.54 E 5930000.21 N 462752.61 E 0.248 2826.70 4661.96 60.540 34.400 3027.45 3172.05 2373.60 N 1679.03 E 5930066.65 N 462798.45 E 0.241 2907.41 --~ 4754.58 60.240 33.760 3073.21 3217.81 2440.30 N 1724.15 E 5930133.11 N 462843.91 E 0.683 2987.92 4847.27 60.260 34.020 3119.21 3263.81 2507.10 N 1769.03 E 5930199.68 N 4628~9.13 E 0.244 3068.38 4941.04 60.250 33,900 3165.73 3310.33 2574.63 N 1814.51 E 5930266.98 N 462934.95 E 0.112 3149.78 5033.42 60.250 33,870 3211.57 3356.17 2641.21 N 1859.22 E 5930333.33 N 462980.01 E 0.028 3229.97 5125.63 60.210 33.960 3257.35 3401.95 2707.63 N 1903.88 E 5930399.52 N 463025.01 E 0.095 3309.99 5219.46 60.220 33.860 3303.96 3448.56 2775.22 N 1949.31 E 5930466.87 N 463070.79 E 0.093 3391.41 5312.25 60.630 35.090 3349.76 3494.36' 2841.74 N 1994.99 E 5930533.16 N 463116.81 E 1.235 3472.10 5404.51 60.650 34.640 3395.00 3539.60 2907.72 N 2040.96 E 5930598.90 N 463163.12 E 0.426 3552.51 5502.70 60.610 34,280 3443.16 3587.76 2978.27 N 2089.38 E 5930669.20 N 463211.90 E 0.322 3638.07 ----------.--------- - _.- -._.-- ------..--- ..-. ------ ----- 14 March, 2002 - 17:42 Page 30f6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 2L-03 Your Ref: 501032039800 Job No. AKMW22024, Surveyed: 22 February, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2L Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northing. Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5596.58 60,640 34.010 3489.21 3633.81 3045.98 N 2135.30 E 5930736.67 N 463258.17 E 0.253 3719.87 5683.63 60,340 34.020 3532.08 3676.68 3108.77 N 2177.67 E 5930799.24 N 463300.87 E 0.345 3795.62 5776.77 61.380 35.560 3577.44 3722.04 3175.58 N 2224.09 E 5930865.81 N 463347.63 E 1.825 3876.96 5869.40 61 ,700 36.420 3621.58 3766.18 3241.47 N 2271.95 E 5930931.45 N 463395.83 E 0.886 3958.39 5962.21 61.600 36.340 3665.65 3810.25 3307.22 N 2320.39 E 5930996.96 N - 463444.61 E 0.132 4040.04 6055.69 61.580 35.690 3710.13 3854.73 3373.73 N 2368.74 E 5931063.21 N 463493.30 E 0.612 4122.26 6147.97 61.460 36.040 3754.13 3898.73 3439.46 N 2416.26 E 5931128.70 N 463541.16 E 0.358 4203.36 6240.33 61.430 36.550 3798.28 3942.88 3504.85 N 2464.28 E 5931193.84 N 463589.52 E 0.486 4284.47 6333.54 61.420 35.720 3842.87 3987.47 3570.96 N 2512.55 E 5931259.70 N 463638.12 E 0.782 4366.31 6427.03 61.420 35.890 3887.59 4032.19 3637.54 N 2560.58 E 5931326.03 N 463686.50 E 0.160 4448.40 6520,12 61.350 35.900 3932.17 4076.77 3703.74 N 2608.49 E 5931391.98 N 463734.75 E 0.076 4530.11 6612.70 61.460 35.980 3976.48 4121.08 3769.55 N 2656.21 E 5931457.55 N 463782.80 E 0.141 4611.39 6705,36 61 . 180 36.000 4020.95 4165.55 3835.33 N 2703.98 E 5931523.08 N 463830.91 E 0.303 4692.67 6796.80 61.120 36.210 4065.07 4209.67 3900.04 N 2751.17 E 5931587.54 N 463878.43 E 0.212 4772.75 6891.06 61.110 36.250 4110.61 4255.21 3966.61 N 2799.95 E 5931653.87 N 463927.56 E 0.039 4855.27 6984.66 61.220 35.960 4155.75 4300.35 4032.86 N 2848.27 E 5931719.86 N 463976.21 E 0.296 4937.25 7075.85 61.420 36.4 70 4199.51 4344.11 4097.40 N 2895.53 E 5931784.16 N 464023.81 E 0.537 5017.23 7170.50 61.570 36.230 4244.68 4389.28 4164.40 N 2944.83 E 5931850.90 N 464073.46 E 0.273 5100.39 7254.62 61.110 36.380 4285.03 4429.63 4223.88 N 2988.54 E 5931910.16 N 464117.47 E 0.569 5174.19 7348.45 60.900 35.380 4330.51 4475.11 4290.38 N 3036.64 E 5931976.41 N 464165.91 E 0.959 5256.25 7444.28 60.840 35.820 4377.16 4521.76 4358.44 N 3085.37 E 5932044.22 N 464214.99 E 0.406 5339.95 ~ 7542.88 61.320 34.290 4424.85 4569.45 4429.09 N 3134.93 E 5932114.61 N 464264.92 E 1.443 5426.25 7635.94 61.430 34.490 4469.43 4614.03 4496.49 N 3181.07 E 5932181.78 N 464311.40 E 0.223 5507.93 7727.34 61.190 33.770 4513.31 4657.91 4562.86 N 3226.06 E 5932247.91 N 464356.73 E 0.739 5588.10 7820.69 61.080 33.990 4558.37 4702.97 4630.73 N 3271.63 E 5932315;55 N 464402.65 E 0.238 5669.83 7913.17 60.970 34.080 4603.17 4747.77 4697.78 N 3316.91 E 5932382.36 N 464448.28 E 0.146 5750.72 8006.07 60.990 34.300 4648.24 4792.84 4764.98 N 3362.56 E 5932449.32 N 464494.27 E 0.208 5831.95 8099.06 60.880 34.550 4693.41 4838.01 4832.02 N 3408.51 E 5932516.13 N 464540.57 E 0.263 5913.22 8191.71 60.810 34.790 4738.55 4883.15 4898.57 N 3454.54 E 5932582.44 N 464586.93 E 0.239 5994.13 8284.90 60.540 35.440 4784.19 4928.79 4965.03 N 3501.27 E 5932648.65 N 464634.01 E 0.674 6075.38 -----------.- -- - - --- ---- --- u"----- - 14 March, 2002 - 17:42 Page 4 of 6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 2L-D3 Your Ref: 501032039800 Job No. AKMW22024, Surveyed: 22 February, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2l 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) (o/100ft) 8377.93 60.050 35.330 4830.29 4974.89 5030.90 N 3548.06 E 5932714.29 N 464681.14 E 0.537 6156.18 8470.76 59.650 35.310 4876.92 5021.52 5096.40 N 3594.47 E 5932779.55 N 464727.89 E 0.431 6236.45 8563.54 60.910 34.130 4922.91 5067.51 5162.63 N 3640.36 E 5932845.54 N 464774.11 E 1.750 6317.02 8656.18 60.840 33.510 4968.00 5112.60 5229.86 N 3685.40 E 5932912.54 N 464819.50 E 0.589 6397.93 8749.42 60.740 34.250 5013.51 5158.11 5297.43 N 3730.77 E 5932979.87 N 464865.22 E 0.701 6479.30 -. 8842.37 60.680 34.030 5058.98 5203.58 5364.52 N 3776.26 E 5933046.73 N 464911.06 E 0.216 6560.35 8935.08 61.080 34.370 5104.10 5248.70 5431.51 N 3821.79 E 5933113.48 N 464956.93 E 0.537 6641.33 9028.21 60.670 33.990 5149.42 5294.02 5498.81 N 3867.49 E 5933180.55 N 465002.98 E 0.566 6722.68 9121.54 60.420 33.670 5195.32 5339.92 5566.32 N 3912.74 E 5933247.82 N 465048.57 E 0.401 6803.92 9214.06 60.220 33.800 5241.13 5385.73 5633.16 N 3957.38 E 5933314.43 N 465093.55 E 0.248 6884.28 9306.70 60,340 34.130 5287.06 5431.66 5699.89 N 4002.32 E 5933380.93 N 465138.84 E 0.335 6964.72 9399.92 61 , 170 33.930 5332.60 5477.20 5767.30 N 4047.84 E 5933448.10 N 465184.71 E 0.910 7046.05 9493.23 61.460 34.850 5377.39 5521.99 5834.85 N 4094.08 E 5933515.41 N 465231.29 E 0.919 7127.90 9586.10 61.610 34.700 5421.65 5566.25 5901.91 N 4140.64 E 5933582.23 N 465278.20 E 0.215 7209.54 9679.01 61.690 34.660 5465.77 5610.37 5969.15 N 4187.17 E 5933649.23 N 465325.07 E 0.094 7291.30 9771.83 61.830 35.110 5509.69 5654.29 6036.23 N 4233.94 E 5933716.07 N 465372.18 E 0.453 7373.07 9864.55 61.730 35.540 5553.53 5698.13 6102.88 N 4281.17 E 5933782.48 N 465419.77 E 0.423 7454.77 9956.96 61.590 35.790 5597.40 5742.00 6168.96 N 4328.60 E 5933848.31 N 465467.53 E 0.282 7536.10 10049.83 61.260 35.220 5641.82 5786.42 6235.36 N 4375.96 E 5933914.46 N 465515.23 E 0,646 7617.66 10142.76 60.990 35.070 5686.70 5831.30 6301.90 N 4422.81 E 5933980.76 N 465562.42 E 0.323 7699.03 10235.59 60.600 35.170 5731.99 5876.59 6368.17 N 4469.42 E 5934046.80 N 465609.38 E 0.431 7780.06 -- 10328.68 60.930 35.370 5777.46 5922.06 6434.50 N 4516.33 E 5934112.88 N 465656.62 E 0.401 7861.29 10421.85 61.010 35.230 5822.67 5967.27 6500.98 N 4563.40 E 5934179.12 N 465704.04 E 0.157 7942.76 10514.47 61.400 36.840 5867.28 6011.88 6566.61 N 4611.15 E 5934244.50 N 465752.13 E 1.580 8023.91 10607.19 61.480 35.750 5911.61 6056.21 6632.25 N 4659.36 E 5934309.89 N 465800.67 E 1.036 8105.33 10700.73 60.930 35.310 5956.67 6101.27 6698.96 N 4706.99 E "5934376.35 N 465848.65 E 0.718 8187.30 10766.48 61.070 35.260 5988.55 6133.15 6745.90 N 4740.21 E 5934423.12 N 465882.11 E 0.223 8244.80 10862.06 63.800 34.930 6032.77 6177.37 6815.22 N 4788.92 E 5934492.19 N 465931.17 E 2.873 8329.53 10958.27 63.970 34.680 6075.12 6219.72 6886.16 N 4838.23 E 5934562.87 N 465980.85 E 0.293 8415.91 11054.04 64.320 34.190 6116.89 6261.49 6957.24 N 4886.96 E 5934633.70 N 466029.95 E 0.588 8502.09 ----- ~---~---.. -------~----- 14 March, 2002 - 17:42 Page 50f6 DrillQuest 2.00.09.003 ... t. Sperry-Sun Drilling Services Survey Report for 2L-03 Your Ref: 501032039800 Job No. AKMW22024, Surveyed: 22 February, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11152.37 63.840 33.340 6159.87 6304.47 7030.76 N 4936.12 E 5934706.97 N 466079.48 E 11245.50 64.150 33.350 6200,70 6345.30 7100.68 N 4982.12 E 5934776.65 N 466125.85 E 11316.00 64.150 33.350 6231.44 6376.04 7153.68 N 5017.00 E 5934829.47 N 466161.00 E - All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Suñace is 25.4540 (07-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 35.0800 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11316.000., The Bottom Hole Displacement is 8737.59ft., in the Direction of 35.0430 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11316.00 Projected Survey 6376.04 7153.68 N 5017.00 E Survey tool program for 2L-03 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 6376.04 MWD Magnetic 11316.00 --- ---------.-. *- - -- - ------ - -- --.- --- --_.--- ----- - . 14 March, 2002 - 17:42 Page 60'6 Dogleg Rate (°/1 0 Oft) Vertical Section . North Slope, Alaska Kuparuk 2L Comment 0.918 8590.51 0.333 8674.17 0.000 8737.58 Projected Survey -----.-------- - --. ~ ~ DrillQlIest 2.00.09.003 ') PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie AOGCC 333 W. 7th, Suite 100 Anchorage, Alaska 99501 RE: 2L-03 PERMIT 201-239 DATE: 04/04/02 Delivery: Hand carried Transmitted herewith is the following: SL-03 (501032039800) Epoch Mud logging Data ~End of well report with color logs of Formation Log MD/Formation log TVD/ Drilling Dynamics/DML-MWD Combo ~report CD ROM containing LAS data; Final well report, morning reports, drilling and lithology remarks files LSepia paper- Formation log 2"=100' Please check off each item as received, sign and return one of the two transmittals enclosed to address below. The other copy is for your records. All data to be held confidential until State of Alaska designated AOGCC release date cc: Rick Levinson, PAl Geologist Approved for transmittal by: S. Lemke RECEIVED --Y . \ Receipt: ,/~. /\~ C..JJJl¿f j,-,-~j Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: APR 5 2002 Al8klouaGalCcaCØlllllliUn AddøIge Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases ~) j ) ) PHilliPS Alaska Inc. 2L-03 ) See 22-T10N-R7E UM North Slope Borough Alaska February 22, 2002 John Morris Sr. Logging Geologist Brady Kilmer Sr. Logging Geologist Bob Nichol Sr. Logging Geologist ~ ~JOC-------- L-I ---.J~ --- --- ) döl-d39 ) ) TABLE OF CONTENTS ) Phillips Alaska Inc. 2L-03 North Slope Borough TABLE OF CONTENTS.. ............................ .......... ... ... ......... .... .................. ...... ...... ..........2 WELL RESUME ...... ......... .......... ..... ........ ..... ........ ........... ...... ........ ..... .......... ..... ....... .... ......3 LITHOLOGY AND REMARKS ........ ...... ......... ...................... .......... ...... ..... ........ ............ ....... 4 ) RIG ACTIVITIES.............................................................................................. 18..................................................... .................................................. .26 MUD RECORD...... ................................................................................................................... 11111............................................................................... 30 SURVEY RECORD ......... .... ...... ....... ........ ....... ......... ... .... ...... ... ...... -. .,.. ...... ....... ............32 BIT RECORD............................,........................................... e.8'""""""""""", 8:................37 DAYS VS. DEPTH ......... ....,........... ...... ..... ... ... ......,....... ..... .... ...... ........ .... ... ....... ... ...8.. ...38 FINAL LOGS.. ............................. ....................... ................ ............. ....... ......APPENDIX 1 ) ~ EPOCH 2 )' ) PHILLIPS Alaska, Inc. . [Ð ) 2L-03 WELL RESUME Operator Phillips Alaska Inc. Well Name: 2L-03 Serac Location: Sec. 22 T10N R7E UM Coordinates: 143' FNL 544' FEL Sec 22 T10N R7E Elevation: Rig floor: 144.6' Pad: 117.1' AMSL County: North Slope Borough State: Alaska AFE No.: AK 0231 Spud Date: February 6, 2002 Contractor: Doyon Drilling ) Foremen: Don Presnell, Ray Springer, Dink Heim Rig: #141 - Land Logging Unit: MLOA3 Geologists: John Morris, Brady Kilmer, Bob Nichol Co. Geologist: Rick Levinson Log Interval: 110' to 11316' Dates: 2/6/2002 to 2/22/2002 Mud Types: Spud Mud to 3093' LSND to 11316' Casing Data: 16" at 110'--9 5/8" at 3093'--7" at 10753' Hole Size: 12 %" to 2422' 8 %" to 10773' 6 1/8" to 11316' ) ~ EPO(~H 3 ) ) PHilliPS Alaska, Inc. PHIlliPS m1 2l-03 LITHOLOGY AND REMARKS ) 3115' MD 2437' TVD Claystone = light to medium brownish gray; very soft to soft; irregular to sub-blocky cuttings; matte, earthy luster smooth to moderately gritty texture; non to slightly calcareous; scattered to common black specks, streaks and laminations; locally silty, grading in part to siltstone. 3160' MD 2458' TVD Sand::;: multicolored, com clear, white, light to medium gray, black, occasionally medium greenish gray, occasionally reddish orange; clasts range from fine to coarse, dominantly medium grain; angular to rounded, dominantly sub angular; moderately sorted in the medium range; composed of 600/0 quartz, 40% igneous and metamorphic lithics; scattered clusters of microcrystalline pyrite. 3220' MD 2486' TVD Claystone = light to medium brownish gray to olive gray; soft to occasionally firm; crumbly to occasionally tough; matte to chalky luster; smooth to gritty texture; non to occasionally very calcareous; thin laminations of calcite; trace to common ashy appearing blebs and streaks; trace amount clusters of microcrystalline pyrite. ) 3270' MD 2509' TVD Siltstone = light to medium gray with slight olive and brownish hues; soft to firm; crumbly to occasionally moderately tough; matte luster with common sparkles; gritty, grainy texture; non to locally moderately calcareous; common very fine sand grains; argillaceous, grading to and interbedded with claystone; common black pinpoint specks; continued common ashy streaks and white to light gray tuff blebs. 3330' MD 2537' TVD Sand = multicolored, dominantly clear, white, light to medium gray; common medium to dark greenish gray, black; clasts range from fine to very coarse; angular to well rounded; poorly sorted; 600k quartz, 40% igneous and metamorphic lithics; scattered clusters of microcrystaHine pyrite; traces of clear mica and black biotite; scattered chunks of free calcite. 3385' MD 2563' lVD Claystone = light to medium brownish gray to olive gray; soft to occasionally firm; crumbly to occasionally tough; matte to dull luster; silty to gritty texture; non to occasionally slightly calcareous; thin laminations of calcite; trace carbon inclusions; trace ashy stringers; abundant amount of microcrystaHine pyrite. ,) 3455' MD 2597' TVD Sand = varied color, dominantly transparent, white, light gray; traces of glauconite clasts; grains range from fine to very coarse; angular to well rounded; poorly sorted; [1 EPOC:H 4 ) PHilliPS Alaska, Inc. ) ) PHllUPS r!m 2L-03 60% quartz, 40% igneous and metamorphic lithics; scattered clusters of microcrystalline pyrite; traces of clear mica and black biotite; scattered chunks of free calcite; traces volcanic glass shards. 3510' MD 2623' TVD Claystone = light to medium brownish gray to olive gray; soft to occasionally firm; crumbly to occasionally tough; matte to dull luster; silty to gritty texture; non to occasionally slightly calcareous; thin laminations of calcite; trace carbon inclusions; trace ashy stringers; abundant amount of microcrystalline pyrite. 3560' MD 2647' TVD Siltstone = very light to medium gray; firm; crumbly to occasionally moderately tough; matte luster with common sparkles; gritty, grainy texture; non to locally moderately calcareous; common very fine sand grains; argillaceous, grading to and interbedded with siltstone; common black pinpoint specks; continued common ashy streaks; no hydrocarbon indicators. ) 3615' MD 2673' TVD Siltstone = light to medium gray with slight olive and brownish hues; soft to firm; crumbly to occasionally moderately tough; matte luster with common sparkles; gritty, grainy texture; non to locally moderately calcareous; common very fine sand grains; argillaceous, grading to and interbedded with 36552692claystone; common black pinpoint specks; continued common ashy streaks and white to light gray tuff blebs. 3675' MD 2702' TVD Shale = dark gray to medium dark gray; firm to moderately hard; brittle; sub-planar fracture; elongated cuttings habit; earthy to sub-sparkling luster; smooth to silty texture; thinly bedded to interbedded with siltstone. 3710' MD 2719' TVD Ash fall tuff = white, light gray, pale yellowish brown, moderate brown; soft to firm; crumbly; irregular to sub-blocky habit; chalky to resinous luster; smooth to moderately gritty texture; dominantly non calcareous, occasionally shows vigorous acid reaction; dull light yellow mineral fluorescence. 3760' MD 2743' TVD Sandstone = light gray overall with slight salt and pepper appearance; friable to firm; clasts range from very fine upper to medium upper; angular to rounded; moderately sorted in the fine to medium range; composed of 70% quartz, 30% igneous and metamorphic lithics; ashy clay matrix; dominantly matrix supported; silty; lightly calcite cemented; appears tight; no visible oil indicators. ) 3820' MD 2771' TVD Siltstone = medium olive gray to medium brownish gray; soft to firm; crumbly to occasionally moderately tough; matte luster with scattered sparkles; gritty, grainy ~ EPOCH 5 ) PHilliPS Alaska, Inc. ) PHILLIPS rD 2l-03 texture; moderately calcareous; argillaceous, grading to and interbedded with claystone; scattered to common ashy appearing blebs and streaks; scattered to common black specks and streaks. 3875' MD 2797' TVD Claystone = medium brownish gray to medium olive gray; soft to rarely firm; crumbly to mushy, rarely slightly brittle; matte luster; smooth to slightly grainy texture; 3 to 5 mm cuttings with irregular and sub-blocky habit; moderately to occasionally very calcareous; locally silty, grading in part to siltstone. 3925' MD 2821' TVD Sandstone = light gray overall with slight salt and pepper appearance; friable to firm; clasts range from very fine upper to medium lower; angular to rounded, dominantly subangular; moderately sorted in the fine to medium range; composed of 70% quartz, 300/0 igneous and metamorphic lithics; trace clusters of microcrystalline pyrite; trace of glauconite and siderite; ashy clay matrix; slightly calcareous; apparently tight; no oil indicators. ) 3990' MD 2852' TVD Claystone = medium brownish gray to medium olive gray; soft to rarely firm; crumbly to mushy, rarely moderately brittle; matte luster; smooth to slightly gritty texture; 2 to 5 mm cuttings with irregular and sub-blocky habit; moderately to occasionally very calcareous; locally silty, grading in part to siltstone. 4040' MD 2875' TVD Siltstone = medium olive gray to medium brownish gray; soft to firm; crumbly to rarely moderately tough; matte luster with scattered sparkles; gritty, grainy texture; moderately calcareous; argillaceous, grading to and interbedded with claystone; scattered to common ashy appearing blebs and streaks; scattered to common black specks and streaks. 4095' MD 2901' TVD Sandstone = light gray overall with slight salt and pepper appearance; friable to firm; clasts range from very fine upper to medium upper; angular to rounded; moderately sorted in the fine to med lower range; composed of 70% quartz, 30% igneous and metamorphic lithics; ashy clay matrix; dominantly matrix supported; silty; lightly calcite cemented; common to 100/0 of sample is clear to milky white fragments of calcite. 4160' MD 2932' TVD Claystone = medium gray with common olive and brownish hues; soft to firm; crumbly to mushy; small irregular and sub-blocky cuttings; dull, earthy luster; smooth to moderately gritty texture; locally very calcareous; scattered laminations of clear and milky white calcite; locally silty, grading to and interbedded with siltstone; common carbonaceous specks; locally common blebs and streaks of ashy appearing material. ) U EPO(~H 6 ) PHilliPS Alaska, Inc. ) ) PHILLIPS [Ð 2L-03 4225' MD 2963' TVD Shale = medium gray to dark gray with scattered olive and brownish hues; firm; moderately brittle; matte, earthy luster; smooth texture; non to locally slightly calcareous; 2 to 5 mm cuttings with platy and blocky habit; appears as thin interbéds with claystone and siltstone; poor to fair fissility. 4270' MD 2984' TVD Ash fall tuff = white, light gray, pale yellowish brown, moderate brown; soft to firm; crumbly; irregular to sub-blocky habit; chalky to resinous luster; smooth to moderately gritty texture; dominantly non calcareous, occasionally with vigorous acid reaction; dull light yellow mineral fluorescence. 4320' MD 3008' TVD Claystone = medium brownish gray to medium olive gray; soft to occasionally firm; mushy to crumbly, rarely moderately brittle; matte luster; smooth to slightly gritty texture; 3 to 5 mm cuttings with irregular and sub-blocky habit; moderately to occasionally very calcareous; locally silty, grading in part to siltstone; occasionally shows incipient fissility, grades to poor shale. ) 4380' MD 3036' TVD Sandstone = light gray overall; firm; clasts range from very fine lower to medium lower, dominantly very fine to fine; angular to subangular; moderately sorted in the very fine to fine range; composed of 70% quartz, 30%) lithics; trace clusters microcrystalline pyrite; trace possible glauconite; ashy clay matrix; matrix supported; estimated poor visual porosity and permeability; no apparent oil indicators. 4465' MD 3076' TVD Ash fall tuff = white, light gray, pale yellowish brown, moderate brown; soft to firm; crumbly; irregular to sub-blocky habit; chalky to resinous luster; smooth to moderately gritty texture; dominantly non calcareous, occasionally with vigorous acid reaction; dull light yellow mineral fluorescence. 4515' MD 3100' TVD Siltstone = medium gray with slight brownish hues; soft to firm; mushy to occasionally moderately tough; matte luster with scattered sparkles; gritty, grainy texture; non to moderately calcareous; argillaceous, grading to and interbedded with claystone; scattered to common ashy appearing blebs and streaks; scattered to common black specks and streaks; scattered very fine sand grains. ) 4575' MD 3130' TVD Sandstone = light gray overall; firm; clasts range from very fine lower to fine upper; angular to rounded, dominantly angular to subangular; moderately sorted; most grains equant; composed of 70% quartz, 30% lithics; trace clusters microcrystalline pyrite; trace possible glauconite; ashy clay matrix; matrix supported; estimated poor visual porosity and permeability; no apparent oil indicators. ~ EPO(~H 7 ) PHilliPS Alaska, Inc. PHilliPS m 2l-03 ) } 4640' MD 3162' TVD Siltstone = medium gray with slight brownish hues; soft to firm; mushy to occasionally moderately tough; matte luster with scattered sparkles; gritty, grainy texture; non to moderately calcareous; argillaceous, grading to and interbedded with claystone; scattered to common ashy appearing blabs and streaks; scattered to common black specks and streaks; scattered very fine sand grains. 4700' MD 3191' TVD Ash fall tuff = white, light gray, pale yellowish brown, moderate brown; soft to firm; crumbly; irregular to sub-blocky habit; chalky to resinous luster; smooth to moderately gritty texture; dominantly non calcareous, occasionally with vigorous acid reaction; dull light yellow mineral fluorescence. 4750' MD 3216' TVD Shale = medium gray to dark gray with scattered olive and brownish hues; firm; moderately brittle; matte, earthy luster; smooth texture; non to locally slightly calcareous; 2 to 5 mm cuttings with platy and blocky habit; appears as thin interbeds with claystone and siltstone; poor to fair fissility. ) 4795' MD 3238' TVD Siltstone = medium gray to medium dark gray and moderately brownish hues; friable to moderately firm; matte luster with scattered sparkles; gritty to granular texture; non to moderately calcareous; very argillaceous, grading in part to sandstone; scattered to common ashy appearing blebs; scattered to common black pinpoint inclusions; lesser amounts graded to claystone; no visible hydro- carbons. 4860' MD 3271' TVD Sandstone = light gray overall; firm; clasts range from very fine lower to fine upper; angular to rounded, moderately sorted; most clasts equant; composed of 70% quartz, 300/0 lithics; trace clusters microcrystalline pyrite; trace possible glauconite; ashy clay matrix; matrix supported; estimated poor visual porosity and permeability; no visible hydrocarbon indicators. 4920' MD 33001 TVD Siltstone = medium gray to medium dark gray and moderately brownish hues; friable to moderately firm; matte luster with scattered sparkles; gritty to granular texture; non to moderately calcareous; very argillaceous, grading in part to sandstone; scattered to common ashy appearing blebs; scattered to common black pinpoint inclusions; lesser amounts graded to claystone; massive bedding with interbedded shale stringers; no visible hydrocarbon indicators. ) 4990' MD 3335' TVD Sandstone = light gray to medium light gray; friable to moderately hard; very fine to fine grain; moderately sorted; most clasts equant; composed of 900/0 quartz, 100/0 lithics; I) EPOCH 8 ) ) PHILLIPS Alaska, Inc. ~ ~ 2L..03 ) traces to 10 % calcite crystals; calcareous ashy matrix; matrix supported; estimated poor visual porosity and permeability; no visible hydrocarbon indicators. 5045' MD 3362' TVD Siltstone = medium gray to medium light gray and moderately brownish hues; easily triable to moderately firm; matte luster with scattered sparkles; gritty to granular texture; moderately calcareous; very argillaceous, grading in part to sandstone; scattered to common ashy appearing blebs; scattered to common black pinpoint inclusions; lesser amounts graded to claystone; no visible hydro.. carbons. 5110' MD 3395' TVD Sand = transparent to white to very light gray; grains have traces of matrix material; grains range form very fine lower to fine to silt; angular to well rounded; poorly sorted; 90% quartz, 10% lithics; traces to 10% calcite crystals; matrix material of calcareous clay matrix; no visible hydrocarbon indicators. 5160' MD 3419' TVD Claystone = medium brownish gray to medium olive gray; very soft to soft; mushy to pasty, sectile fracture; matte to dull luster; smooth to slightly gritty texture; moderately calcareous; locally silty, grading in part to siltstone; occasionally shows incipient fissility, grades to poor shale. ) 5210' MD 3444' TVD Siltstone = medium gray to medium light gray and moderately brownish hues; easily friable to moderately firm; matte luster with scattered sparkles; gritty to granular texture; moderately calcareous; very argillaceous, grading in part to sandstone; scattered to common ashy appearing blebs; scattered to common black pinpoint inclusions; lesser amounts graded to claystone; no visible hydro- carbons. 5275' MD 3476' TVD Sandstone = very light gray to light gray to white; very fine lower to very fine upper to fine grain individual; some graded to siltstone; glauconite and carbon inclusions in clasts; calcareous ashy matrix to slightly siliceous matrix; exhibits mostly grain supporting; friable to moderately hard; angular to sub-angular; clasts are equant to mottled; thinly bedded; no visible hydrocarbon indicators. 5335' MD 3506' TVD Siltstone = medium gray to medium light gray and moderately brownish hues; easily triable to moderately firm; matte luster with scattered sparkles; gritty to granular texture; moderately calcareous; very argillaceous, grading in part to sandstone; scattered to common ashy appearing blebs; scattered to common black pinpoint inclusions; lesser amounts graded to claystone; no visible hydro- carbons. ) 5420' MD 3547' TVD U EPO(~H 9 ) PHilliPS Alaska, Inc. ) ') PHIUlPS ~ 2L-03 Sand = transparent to white to very light gray; grains have traces of matrix material; grains range form very fine lower to fine to silt; angular to well rounded; poorly sorted; 90% quartz, 10% lithics; traces to 10% calcite crystals; matrix material of calcareous clay matrix; no visible hydrocarbon indicators. 5470' MD 3572' TVD Claystone = medium brownish gray to medium olive gray; very soft to soft; mushy to pasty, sectile fracture; matte to dull luster; smooth to slightly gritty texture; moderately calcareous; locally silty, grading in part to siltstone; occasionally shows incipient fissility, grades to poor shale. 5520' MD 3596' TVD Sand/sandstone = light gray overall; friable to firm when consolidated; clasts range from very fine lower to medium lower, dominantly very fine to fine; angular to rounded, dominantly subangular to subround; moderately sorted in the very fine to fine range; composed of 60% quartz, 400/0 lithics; variable grain/matrix supported; ashy clay matrix; non to slightly calcareous; scattered free chunks of white clay mineral/devitrified ash in sample. ) 5585' MD 3628' TVD Siltstone = light to medium gray with slight olive and brown hues; soft to moderately firm; crumbly to mushy, occasionally moderately brittle; matte, luster with scattered sparkles; gritty, abrasive texture; non to locally very calc; scattered to abundant very fine sand grains; scattered blebs of ashy appearing clay mineral. 5635' MD 3653' TVD Note: 90% of cuttings are in the very fine to fine grain range. 5650' MD 3660' TVD Claystone = light to medium gray, brownish gray, occasionally olive gray; soft to occasionally firm; mushy to crumbly, occasionally moderately brittle; cuttings are very fine to fine grain size; irregular habit; matte, earthy luster; moderately gritty texture; slightly to very calcareous; locally silty, grades in part to siltstone; scattered carbonaceous specks and streaks; scattered blebs of ashy clay material; some pieces show incipient fissility. 5720' MD 3695' TVD Sand/sandstone = light gray overall; friable to firm when consolidated; clasts range from very fine lower to medium lower, dominantly very fine to fine; angular to rounded, dominantly subangular to subround; moderately sorted in the very fine to fine range; composed of 600/0 quartz, 400/0 lithics; variable grain/matrix supported; ashy clay matrix; non to slightly calcareous. ì) )' 5775' MD 3721' TVD ~ EPOCH 10 ) PHilliPS Alaska, Inc. ) ) PHilliPS I'D 2l-03 Shale = med grayish brown; firm; sub-blocky cuttings; matte luster; slightly grainy texture; scattered carbonaceous laminations; appears to be thinly interbedded with the claystones; poor to occasionally fair fissility. 5815' MD 3740' TVD Sand/sandstone = light gray overall; friable to firm when consolidated; clasts range from very fine lower to medium lower, dominantly very fine to fine; angular to rounded, dominantly subangular to subround; moderately sorted in the very fine to fine range; composed of 60°1<> quartz, 40% lithics; variable grain/matrix supported; ashy clay matrix; non to slightly calcareous; scattered free chunks of white clay mineralldevitrified ash in sample. 5900' MD 3781' TVD Tuff = light gray, white, pale yellowish brown, moderate brown; soft to firm; crumbly; small flaky and irregular cuttings; matte to chalk, occasionally resinous luster; mostly smooth texture; some pieces appear waxy when scored; scattered light gray laminations; pale yellow mineral fluorescence. ) 5945' MD 3802' TVD Claystone = light to medium gray, brownish gray, occasionally olive gray; soft to occasionally firm; mushy to crumbly, occasionally moderately brittle; cuttings are very fine to fine grain size; irregular habit; matte, earthy luster; moderately gritty texture; slightly to very calcareous; locally silty, grades in part to siltstone; scattered carbonaceous specks and streaks; scattered blebs of ashy clay material; some pieces show incipient fissility. 6015' MD 3835' TVD Sand/sandstone = light gray overall; friable to firm when consolidated; clasts range from very fine lower to medium lower, dominantly very fine to fine; angular to rounded, dominantly subangular to subround; moderately sorted in the very fine to fine range; composed of 70% quartz, 30°1<> lithics; variable grain/matrix supported; ashy clay matrix; light calcareous cement; apparent poor to fair visual porosity; no oil indicators observed. 6080' MD 3866' TVD Siltstone = light to medium gray with occasionally olive and brown hues; soft to moderately firm; mushy to crumbly, occasionally moderately brittle; earthy luster with scattered sparkles; gritty, abrasive texture; non to locally very calc; scattered to abundant very fine sand grains; scattered to common specks of ashy appearing clay mineral. ) 6130' MD 3890' TVD Tuff = light gray to white, pale yellowish brown; crumbly to firm; 2 to 3 mm cuttings with platy and sub-blocky habit; matte, chalky, occasionally slightly resinous luster; smooth to occasionally slightly grainy texture; non to occasionally very calcareous; appears as free fragments in samples and as laminations and blebs in claystones. ~ EPO(~H 11 ) PHilliPS Alaska, Inc. ) ) PHILLIPS m;J 2l-03 6180' MD 3914' TVD Sandstone = light gray; friable to firm; very fine upper to medium upper; angular to subrounded; moderately sorted in the fine range; 70°1<> quartz, 300/0 lithics; trace possible glauconite; trace clusters of microcrystalline pyrite; variable matrix/grain support; ashy appeariMg clay matrix; light calcite cement; poor estimated visual porosity; no discernible oil indicators. ' 6235' MD 3940' TVD Siltstone = light to medium gray with occasionally olive and brown hues; soft to moderately firm; mushy to crumbly, occasionally moderately brittle; earthy luster with scattered sparkles; gritty, abrasive texture; non to locally very calc; scattered to abundant very fine sand grains; scattered to common specks of ashy appearing clay mineral. 6285' MD 3964' TVD Sandstone = white to very light gray to translucent; very fine to fine grain; clasts are equant; calcareous clayey to ashy matrix; sub-angular to sub-round; 80% quartz and 20% assorted lithics; predominantly grain supported; large traces of inoceramus seashell fragments; no visible hydro- carbons. ) 6330' MD 3986' TVD Sand = clear to translucent to very light gray; fine to very fine grain; sub-angular to sub- round to angular; moderately sorted; 70% quartz and 30% calcite and other lithics; small traces of pyrite; no visible hydrocarbon indicators. 6370' MD 4005' TVD Shale = med grayish brown; firm; sub-blocky cuttings; matte luster; slightly grainy texture; scattered carbonaceous laminations; appears to be thinly interbedded with the claystones; poor to occasionally fair fissility; occasional grading to siltstone. 6415' MD 4026' TVD Claystone = light to medium gray, brownish gray, occasionally olive gray; soft to occasionally firm; mushy to crumbly, irregular habit; matte to earthy luster; moderately gritty texture; slightly to very calcareous; locally silty, grades in part to siltstone; scattered carbonaceous specks of ashy clay materials; some pieces exhibit incipient fissility . 6470' MD 4053' TVD Shale = brownish black; firm; brittle tenacity; sub-planar to blocky fracture; flaky to tabular cuttings habit; dull to earthy luster; smooth to silty texture; thick bedding with interbedded ashy clay and siltstones. ) 6505' MD 4070' TVD ~ EPOCH 12 ) PHILLIPS Alaska, Inc. ) PtllLlIPS ~ 2L-03 ) Sandstone = white to very light gray to translucent; very fine to fine grain; clasts are equant; calcareous clayey and ashy matrix; sub-angular to sub-round; 80% quartz and 20% assorted lithics; large traces of tuffaceous siltstone and inoceramus shell fragments and calcite crystals; no visible hydrocarbon indicators. 6550' MD 4091' TVD Tuffaceous siltstone = very light gray to light gray; moderately firm to firm; very calcareous; crumbly tenacity; irregular fracture; nodular cuttings habit; dull earthy luster; gritty to silty texture; thinly bedded with shales and claystones; some graded to tuffaceous and calcareous claystone, 6600'MD 4115'TVD Sand = clear to translucent to white; very fine grain; unconsolidated; poorly sorted; sub- angular to angular moderate sphericity; some frosted surface abrasion; 90% quartz, 10% inoceramus shell fragments; no visible hydrocarbon indicators. 6640' MD 4134' TVD Shale = brownish black; firm; brittle tenacity; sub-planar to blocky fracture; flaky to tabular cuttings habit; dull to earthy luster; smooth to silty texture; thick bedding with interbedded ashy clay and siltstones. ) 6695' MD 4161' TVD Calcareous tuff = very light gray to light gray; soft to moderately firm; very silty and argillaceous; crumbly tenacity; irregular fracture; equant cuttings habit; earthy to sparkling luster; silty to gritty texture; thinly interbedded with silt and free face calcite crystals; abundant inoceramus shell fragment and or calcite crystals. 6745' MD 4185' TVD Tuff = light gray to white, pale yellowish brown; crumbly to firm; irregular fracture; platy and sub-blocky cuttings habit; matte, chalky, occasionally slightly resinous luster; smooth to occasionally slightly grainy texture; calcareous to very calcareous; thick bedding with occasional thinly interbedded stringer with shale and siltstones. 6795' MD 4209' TVD Sand = clear to translucent to white; very fine grain; unconsolidated; poorly sorted; sub- angular to angular moderate sphericity; some frosted surface abrasion; 90% quartz, 10% inoceramus seashell fragments and volcanics; no hydrocarbon indicators. 6835' MD 4228' TVD Calcareous tuff = very light gray to light gray; soft to moderately firm; very silty and argillaceous; crumbly tenacity; irregular fracture; equant cuttings habit; earthy to sparkling luster; silty to gritty texture; thinly interbedded with silt and free face calcite crystals; abundant inoceramus shell fragment and or calcite crystals. ) ~ EPO(~H 13 ) PHilliPS Alaska, Inc. ) PHilLIPS m 2l-03 ) 6885' MD 4252' TVD Shale = grayish black to brownish black to medium dark gray; firm to moderately firm; dense to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding with interbedded silts and ash stringers. 6935' MD 4276' TVD Tuff = light gray to white, pale yellowish brown; crumbly to firm; irregular fracture; platy and sub-blocky cuttings habit; matte, chalky, occasionally slightly resinous luster; smooth to occasionally slightly grainy texture; calcareous to very calcareous; thick bedding with occasional thinly interbedded stringer with shale and siltstones; common inoceramus seashell fragments. 6990' MD 4303' TVD Shale = grayish black to brownish black to medium dark gray; firm to moderately firm; dense to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding with interbedded silts and ash stringers. ) 7040' MD 4327' TVD Shale = grayish black to brownish black to medium dark gray; firm to moderately firm; dense to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding with interbedded silts and ash stringers. 7090' MD 4351' TVD Claystone = light to medium gray, brownish gray, occasionally olive gray; soft to occasionally firm; mushy to crumbly, irregular habit; matte to earthy luster; moderately gritty texture; slightly to very calcareous; locally silty, grades in part to siltstone; scattered carbonaceous specks of ashy clay materials; some pieces exhibit incipient fissility . 7165' MD 4387'tvd Tuff = light gray to white, pale yellowish brown; crumbly to firm; irregular fracture; flaky and sub-blocky cuttings habit; matte, chalky, occasionally slightly resinous luster; smooth to occasionally slightly grainy texture; moderate to very calcareous; thick bedding with occasional thinly interbedded stringer with shale and siltstones; scattered to common inoceramus fragments. 7220' MD 4413' TVD Claystone = medium to occasionally dark brownish gray with some olive hues; soft to occasionally firm; crumbly to rarely slightly brittle; matte, earthy luster; smooth to moderately gritty texture; moderately calcareous; locally silty; scattered to common carbonaceous specks and streaks; grades in part to poorly fissile shale. ) ~ EPOCH 14 ) PHilliPS Alaska, Inc. PHIUIPS [D 2l-03 ) ) 7270' MD 4437' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding with interbedded silts and ash stringers. 7320' MD 4461' TVD Sand = clear, milky white, light to medium gray; clasts range from fine lower to medium upper; angular to rounded; moderately sorted; composed of 80°t'o quartz, 20% lithics; scattered clusters of microcrystalline pyrite; totally disaggregated in samples; slight acid reaction from thin calcite coating on some grains; no evidence of oil. 7375' MD 4488' TVD Claystone = medium to occasionally dark brownish gray with some olive hues; soft to occasionally firm; crumbly to rarely slightly brittle; matte, earthy luster; smooth to moderately gritty texture; moderately calcareous; locally silty; scattered to common carbonaceous specks and streaks; grades in part to poorly fissile shale. ) 7425' MD 4512' TVD Tuff = light to med gray, white, pale yellowish brown; crumbly to firm; irregular fracture; flaky and irregular cuttings habit; matte, chalky, occasionally slightly resinous luster; smooth to occasionally rarely grainy texture; moderate to very calcareous; thinly interbedded with claystones and siltstones; pale yellow mineral fluorescence; scattered inoceramus fragments. 7480' MD 4539' TVD Sand = clear, milky white, light to medium gray; unconsolidated; fine lower to medium upper; sub-angular to rounded; moderately sorted; composed of 90% quartz, 10% lithics; scattered clusters of microcrystalline pyrite; totally disaggregated in samples; slight acid reaction from thin calcite coating on some grains; no fluorescence or hydrocarbon indicators. 7540' MD 4568' TVD Sand = clear, milky white, light to medium gray; unconsolidated; fine lower to medium upper; sub-angular to rounded; moderately sorted; composed of 800/0 quartz, 200/0 lithics; abundant traces of microcrystalline pyrite; strong reaction from calcite coating of grains; no fluorescence or hydrocarbon indicators. 7590' MD 4592' TVD Sand = clear, milky white, light to medium gray; unconsolidated; fine upper to medium upper; sub-angular to sub-rounded; moderately sorted; composed of 70% quartz, 300/0 lithics; abundant traces of microcrystalline pyrite traces inoceramus fragments; strong reaction from calcite coating of grains; no fluorescence or hydrocarbon indicators. ) 7645' MD 4618' TVD ~ EPOCH 15 ) ) PHilliPS Alaska, Inc. PftILlIPS m 2l-03 Tuffaceous claystone = light medium gray to light gray to medium dark gray; tacky to stiff consistency; soft to moderately firm; malleable to sectile tenacity; irregular to no fracture; nodular cuttings habit; dull earthy luster; smooth to sHty texture; thick interbedded by and with sand; slight cohesive properties adhere sand grains to surface. 7700' MD 4645' TVD Sand = clear, milky white, light to medium gray; unconsolidated; v fine lower to medium upper; sub-angular to sub-rounded; moderately sorted; composed of 70% quartz, 30% lithics; traces of siderite and calcite crystals; non calcareous sand; slight mineral fluorescence; no hydrocarbon indicators. 7750' MD 4669' TVD Altered zone = pale yellowish orange to light brown to moderately reddish brown; moderately hard; brittle to crumbly; non calcareous; some inner crystal growth; predominantly smooth surface; possibly altered ash. 7780' MD 4683' TVD Sand = clear, milky white, light to gray unconsolidated; fine lower to fine upper to medium upper; sub-angular to angular to sub-round; moderately sorted; composed of 60% quartz, 40°/Ó lithics; consisting of biotite, calcite, and inoceramus sea shell fragments; non calcareous sand; slight mineral fluorescence from altered meta material; slight ring residual cut from dried sample. ) 7835' MO 4710' TVD Sand = clear, milky white, light to medium gray; unconsolidated; v fine lower to medium upper; sub-angular to sub-rounded; moderately sorted; composed of 700/0 quartz, 300/0 lithics of biotite, calcite crystals, and ash; non calcareous sand; traces to 10% calcareous matrix sandstone; slight mineral fluorescence; no hydrocarbon indicators. 7890' MD 4737' TVD Tuffaceous claystone = light medium gray to light gray to medium dark gray; stiff consistency; soft to moderately firm; crumbly to seetHe and dense tenacity; irregular to blocky fracture; irregular to tabular cuttings habit; dull earthy luster; smooth to silty texture; thick interbedded by and with ash tuffaceous claystone and shale; some graded to shale. 7945' MD 4763' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding. 8010' MD 4795' TVD Claystone = medium to occasionally dark brownish gray with some olive hues; soft to occasionally firm; crumbly to slightly brittle; matte to dull to earthy luster; smooth to ) ~ EPOCH 16 ) PHilliPS Alaska, Inc. ') ) PHilLIPS œJ 2l-03 moderately gritty texture; moderately calcareous; locally silty; scattered to common carbonaceous specks and streaks; grades in part to shale. 8060' MD 4819' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding. 8105' MD 4841' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to micro sparkling luster; smooth to slightly silty texture; thick to massive bedding. 8150' MD 4863' TVD Sandstone = white to very light gray to translucent; very fine to fine grain; clasts are equant; calcareous ashy matrix; matrix supported; sub-angular to sub-round; 80% quartz and 200/0 assorted lithics; large traces of tuffaceous siltstone and inoceramus fragments and calcite crystals; no visible hydrocarbon indicators. ) 8195' MD 4885' TVD Claystone = medium to occasionally dark brownish gray with some olive hues; soft to occasionally firm; crumbly to slightly brittle; matte to dull to earthy luster; smooth to moderately gritty texture; moderately calcareous; locally silty; slightly carbonaceous: large traces of pyrite; some claystone graded to shale. 8245' MD 4909' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to earthy luster; smooth to slightly gritty and silty texture; thick to massive bedding; some graded to hydrophilic claystone; large traces of pyrite. 8300' MD 4936' TVD Claystone = medium to occasionally light gray to medium brownish gray; soft to occasionally firm; pasty consist sectile tenacity; matte to dull to earthy luster; smooth to moderately gritty texture; moderately calcareous; locally silty; large traces of inoceramus sea shell fragments. 8345' MD 4958' TVD Tuff = white, light to medium gray, pale yellowish brown, moderate reddish orange; irregular, flaky and rounded cuttings; chalky and resinous luster; smooth to silty texture; non to occasionally very calcareous; appears free in samples and as streaks, blebs and laminations in claystone and shale. ) 8390' MD 4981' TVD ~ EPOCH 17 ,) PHilliPS Alaska, Inc. ) ,I ) PHILLIPS m 2l-03 Sand = light gray overall; clasts range from very fine to medium; angular to rounded, dominantly angular to subangular; moderately sorted in the fine range; composed of 80% quartz, 20% lithics; loose in samples; common chunks of tuff; slight acid reaction from surface of individual grains. 8435' MD 5003' TVD Siltstone = light to medium gray with common brownish hues; soft to firm; crumbly to rarely slightly brittle; irregular cuttings habit; matte luster with scattered sparkles; gritty, abrasive texture; slightly calcareous; argillaceous, grading in part to claystone; scattered micro fine mica; scattered to common black specks and streaks. 8490' MD 5031' TVD Tuff = white, light to medium gray, pale yellowish brown, occasionally reddish orange; soft to rarely firm; crumbly to rarely brittle; flaky and sub-blocky cuttings habit; chalky and resinous luster; smooth to moderately gritty texture; slightly to occasionally very calcareous; light yellow mineral fluorescence. ) 8540' MD 5056' TVD Sand/sandstone = light gray to grayish white overall; friable to firm when consolidated; clasts range from very fine upper to fine upper; angular to subrounded; moderately well sorted; composed of 80% quartz, 20% lithics; ashy clay matrix; variable matrix/grain support; very calcareous; up to 70% moderately bright light yellow sample fluorescence; instant diffuse pale yellow cut fluorescence followed by slow blooming bright yellow cut fluorescence; bright light yellow residual cut ring fluorescence; faint amber residual ring visible in white light. 8645' MD 5107' TVD Sand/sandstone = light gray to grayish white overall; friable to firm when consolidated; clasts range from very fine upper to medium lower; angular to subrounded; moderately sorted in the fine range; 80% quartz, 20% lithics; ashy clay matrix; variable matrix/grain support; very calcareous; up to 50% moderately bright light yellow sample fluorescence; instant diffuse pale yellow cut fluorescence followed by slow blooming moderately bright yellow cut fluorescence; moderately bright light yellow residual cut ring fluorescence; no residual ring visible in white light. 8725' MD 5146' TVD Siltstone = light to medium gray with common brownish hues; soft to firm; crumbly to rarely slightly brittle; irregular cuttings habit; matte luster with scattered sparkles; gritty, abrasive texture; slightly calcareous; argillaceous, grading in part to claystone; scattered micro fine mica; scattered to common black specks and streaks. ) 8780' MD 5173' TVD Claystone = medium to dark brownish gray; soft to firm; crumbly to rarely moderately brittle; irregular, blocky occasionally platy cuttings; matte, earthy luster; dominantly smooth to occasionally gritty texture; moderately calc; locally common ashy laminations; ~ EPOC=H 18 ') PHilliPS Alaska, Inc. ) ) PHILLIPS rÐ 2L-03 scattered to common carbonaceous specks and streaks; interbedded with and gradational to shale; commonly shows incipient fissility. 8840' MD 5202' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to sparkly luster; silty to micro- crystalline texture; thinly to lenticular interbedding with siltstone and ash. 8890' MD 5227' TVD Tuff = white, very light gray and translucent to very pale orange to pale yellowish green; firm to soft; crumbly to slightly brittle; elongated and equant cuttings habit; blocky fracture; chalky and resinous luster; smooth to slightly gritty texture; non calcareous; light mineral calcareous; light yellow mineral fluorescence. 8940' MD 5251' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; flaky to planar cuttings habit; dull to sparkly luster; moderately silty to gritty texture; thinly interbedded with siltstone; some graded to clay- stone and tuffaceous claystone. ) 8990' MD 5275' TVD Sand/sandstone = light gray to translucent very light gray; friable to firm when consolidated; grains range from very fine upper to medium lower; angular to sub- rounded; moderately sorted through out; 80% quartz, 20% lithics; very calcareous ashy clay to clean very calcareous matrix and grain supported; 30% bright gold sample fluorescence; initial burst cut followed by quick streaming cut/rivulets of bright pale yellow to bright yell white; residual ring of bright pale yell fluorescence; moderately bright light yellow dull brown residual ring in white light; traces of free calcite. 9070' MD 5314' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; fine flaky to planar cuttings habit; dull to sparkly luster; moderately silty texture; thinly interbedded with siltstone, organic material, and calcareous ashy material; some graded to tuffaceous shale. 9125' MD 5342' TVD Sand/sandstone = light gray to translucent very light gray; friable to firm when consolidated; grains range from very fine upper to medium lower; sub-angular to sub- rounded; moderately sorted; 80% quartz, 200/0 lithics; calcareous coated grains; small traces of mineral fluorescence; traces of calcite and metamorphics. ) 9195' MD 5376' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; fine flaky to planar cuttings habit; dull to [) EPO(~H 19 ) PHilliPS Alaska, Inc. ) ) PttllllPS m 2l-03 sparkly luster; moderately silty texture; thinly interbedded with siltstone, lenticular carbon inclusions and calcareous ashy material; some 20% graded to carbonaceous shale. 9250' MD 5404' TVD Calcareous tuff = very light gray to light gray to light brownish gray; firm to slightly hard; brittle to crumbly tenacity; blocky to earthy fracture; nodular to equant cuttings habit; earthy to sparkling luster; micro to cryptocrystaline; very calcareous and interbedded with calcite crystals interbedded; silty to very silty. 9300' MD 5428' TVD Shale = grayish black to brownish black to medium dark gray; moderately firm to firm; crumbly to brittle tenacity; blocky fracture; fine flaky to planar cuttings habit; dull to sparkly luster; moderately silty texture; thinly interbedded with siltstone, organic material, and calcareous ashy material; some graded to tuffaceous shale. ) 9355' MD 5455' TVD Sand = clear to translucent to very light gray; unconsolidated with slightly calcareous surface; grains range from very fine upper to medium lower; sub-angular to sub- rounded; moderately sorted; 80% quartz, 20% lithics; no hydrocarbon indicators; 93955475shale = grayish black to brownish black to medium dark gray; moderately hard to firm; crumbly to brittle tenacity; blocky fracture; fine flaky to planar cuttings habit; dull to sparkly luster; moderately silty texture; thinly interbedded with siltstone, and organic material; some graded to tuffaceous shale. 9445' MD 5499' TVD Siltstone = medium brownish gray; firm; irregular and sub-blocky cuttings; matte luster with scattered micro sparkles; abrasive, gritty texture; slightly calcareous; locally common ashy blebs and laminations; interbedded with low-grade shale. 9485' MD 5518' TVD Tuff = white, light to medium gray, moderate brown; firm to crumbly; irregular, flaky and blocky cuttings; variable matte, resinous luster; dominantly smooth to occasionally silty appearing texture; non to occasionally very calcareous; occurs as free chunks in samples and as blebs or laminations in shale and siltstone. 9535' MD 5542' TVD Shale = medium to dark brownish gray; firm; crumbly to slightly brittle; platy and blocky cuttings; matte to silky luster; smooth to moderately gritty texture; moderately to very calcareous; common carbonaceous matter; locally silty, grading in part to siltstone; poor to fair fissility. } )' 9580' MD 5563' TVD Sand = light gray overall; clasts range from very fine lower to fine upper; angular to rounded, dominantly subangular to subround; moderately well sorted; composed of 80 [:I EPOCH 20 ) PHilliPS Alaska, Inc. ) ) PHILLIPS œJ 2l-03 to 90% quartz, 10 to 200/0 lithics; common chunks of tuff inferred to be matrix material; grains are loose in samples; no apparent oil indicators. 9630' MD 5587' TVD Tuff = white, light to medium gray, moderate brown; firm to crumbly; irregular, flaky and blocky cuttings; variable matte, resinous luster; dominantly smooth to occasionally silty appearing texture; non to occasionally very calcareous; occurs as free chunks in samples and as blebs or laminations in shale and siltstone. 9680' MD 5611' TVD Note: abundant inoceramus fragments in sample at 9670'. 9695' MD 5618' TVD Sand = clear to translucent to very light gray; unconsolidated with slightly calcareous surface; grains range from very fine upper to medium lower; sub-angular to sub- rounded; moderately sorted; 800/0 quartz, 20% lithics; no hydrocarbon indicators; 97355637shale = grayish black to brownish black to medium dark gray; firm to moderately hard; crumbly to brittle; tabular and blocky fracture; fine flaky to planar cuttings habit; dull to shiny luster; moderately gritty texture; thinly interbedded with and grading to siltstone; scattered to common tuff lams. ) 9785' MD 5660' TVD Siltstone = medium brownish gray; firm; irregular and sub..blocky cuttings; matte luster with scattered micro sparkles; abrasive, gritty texture; slightly calcareous; locally common ashy blebs and laminations; interbedded with low-grade shale. 9825' MD 5679' TVD Tuff = white, light to medium gray, moderate brown; firm to crumbly; irregular, flaky and blocky cuttings; variable matte, resinous luster; dominantly smooth to occasionally silty appearing texture; non to occasionally very calcareous; occurs as free chunks in samples and as blebs or laminations in shale and siltstone. 9875' MD 5703' TVD Shale = medium to dark brownish gray; firm; crumbly to slightly brittle; platy and blocky cuttings; matte to silky luster; smooth to moderately gritty texture; moderately to very calcareous; common carbonaceous matter; locally silty, grading in part to siltstone; poor to fair fissility. 9920' MD 5724' TVD Sand = light gray to very light gray overall; unconsolidated in sample; thin calcite crust on surface; grains range from very fine upper to medium lower; sub-angular to sub- rounded; moderately sorted; 800/0 quartz, 200/0 lithics; common chunks of tuff matrix material; trace free clusters of microcrystalline pyrite. ) 9965' MD 5746' TVD U EPOCH 21 J PHILLIPS Alaska, Inc. ) PHilLIPS m 2L..;03 ) Shale = grayish black to brownish black to medium dark gray; firm to occasionally moderately hard; crumbly to brittle tenacity; blocky fracture; platy to planar cuttings habit; dull to sparkly luster; moderately gritty texture; thinly interbedded with siltstone, and organic material; common tuff laminations. 10015' MD 5770' TVD Sand = clear, white, light gray; clasts range from very fine lower to fine upper; angular to rounded, dominantly subangular to subround; moderately well sorted in the very fine to fine range; composed of 80% quartz, 20% lithics; scattered clusters of microcrystalline pyrite; grains appear loose in sample; vigorous acid reaction from most grain surfaces; estimated poor porosity; calcite cementing inferred; scattered pinpoint light yellow sample fluorescence; instant dull yellow diffuse cut fluorescence; intensity improves to moderately bright with time; no cut visible in white light. 10105' MD 5813' TVD Shale = medium to dark gray, dark brownish gray; soft to moderately firm; crumbly to moderately brittle; platy, tabular and irregular cuttings; matte to slightly shiny luster; dominantly smooth texture; non to slightly calcareous; scattered tuff lams; locally silty; appears moderately organic with scattered carbonaceous laminations; poor to fair fissility. ) 10160' MD 5840' TVD Tuff = white, pale yellowish brown, pale yellow; crumbly to occasionally firm; matte, chalky, occasionally resinous luster; dominantly smooth texture; non to occasionally very calcareous; 1 to 3 mm cuttings; platy, tabular and irregular habit; a few thin pieces appear almost translucent; rare thin shaly laminations. 10210' MD 5864' TVD Claystone = medium gray, medium brownish gray; soft to firm; crumbly to occasionally moderately tough; blocky, tabular and irregular cuttings; matte to rarely slightly shiny luster; smooth to locally very grainy texture; non to locally very calcareous; scattered thin tuff laminations; scattered to common carbonaceous specks and streaks. 10265' MD 5891' TVD Shale = medium to dark gray, dark brownish gray; soft to moderately firm; crumbly to moderately brittle; platy, tabular and irregular cuttings; matte to slightly shiny luster; dominantly smooth texture; non to slightly calcareous; scattered tuff lams; locally silty; appears moderately organic with scattered carbonaceous laminations; poor to fair fissility. ,) 10320' MD 5918' TVD Shale = medium to dark gray, dark brownish gray; soft to moderately firm; crumbly to moderately brittle; platy, tabular and irregular cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous scattered tuff laminaes; locally silty; moderately organic traces of scattered carbonaceous laminations; moderate fissility. ~ EPOCH 22 ) PHilliPS Alaska, Inc. ) ) PHilliPS m 2l-03 10375' MD 5945' TVD Shale = dark gray, grayish black; moderately firm to firm to slightly soft; crumbly to moderately brittle; platy, tabular and flaky cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous scattered tuff laminaes; locally silty; moderately organic and traces of carbonaceous laminations; high fissility assoc with carbonaceous shale. 10430' MD 5971' TVD Tuff = white, pale yellowish brown, pale yellow; crumbly to occasionally firm; matte, chalky, occasionally resinous luster; dominantly smooth texture; non to occasionally very calcareous; 1 to 3 mm cuttings; platy, tabular and irregular habit; a few thin pieces appear almost translucent; rare thin shaly laminations; some graded to tuffaceous claystone. 10485' MD 5998' TVD Shale = dark gray, grayish black; moderately firm to firm to slightly soft; crumbly to moderately brittle; platy, tabular and flaky cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous scattered tuff laminaes; locally silty; moderately organic and traces of carbonaceous laminations; high fissility assoc with carbonaceous shale. ) 10540' MD 6024' TVD Tuff = white, pale yellowish brown, pale yellow; crumbly to occasionally firm; matte, chalky, occasionally resinous luster; dominantly smooth texture; non to occasionally very calcareous; 1 to 3 mm cuttings; platy, tabular and irregular habit; a few thin pieces appear almost translucent; rare thin shaly laminations; some graded to tuffaceous claystone. 10595' MD 6050' TVD Shale = dark gray, grayish black; moderately firm to firm to slightly soft; crumbly to moderately brittle; platy, tabular and flaky cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous traces of tuff laminaes; very organic with carbon inclusions and carbonaceous laminations; high fissility assoc with carbonaceous shale. 10650' MD 6077' TVD Shale = dark gray, grayish black; moderately firm to firm to slightly soft; crumbly to moderately brittle; platy, tabular and flaky cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous scattered tuff laminaes; slightly silty; moderately organic and traces of carbonaceous laminations; high fissility assoc with carbonaceous shale. ,) 10705' MD 6103' TVD n EPO(~H 23 ) PHilliPS Alaska, Inc. ") ) PHILLIPS œ 2l-03 Shale = dark gray, med dark gray; moderately firm to firm to slightly soft; crumbly to moderately brittle; platy, tabular and flaky cuttings; matte to slightly shiny luster; dominantly smooth texture; non calcareous scattered tuff laminaes; loc moderately silty; moderately organic and traces of carbonaceous laminations; high fissility assoc with carbonaceous shale; graded to tuffaceous claystone in part. 10785' MD 6142' TVD Shale = medium to dark gray; moderately firm to firm; crumbly to moderately brittle; flaky, tabular and blocky cuttings; matte to slightly shiny luster; smooth texture; non calcareous; moderately organic; trace cut fluorescence from a few pieces. 10830' MD 6163' TVD Sand = transparent to translucent; very fine to fine grain; angular to sub.. angular; well sorted; moderate sphericity; 950/0 quartz, 5% lithics; impact surface abrasion; estimate fair porosity and good permeability; quick blue white cut fluorescence; diffuse weak yellow cut. ) 10875' MD 6183' TVD Sand = transparent to translucent to white; very fine to fine and occasional medium grained; sub-angular to sub- round to angular; moderately sorted; 900/0 quartz, 100/0 lithics, chert and pyrite; slight surface abrasion; moderate sphericity; estimate fair visual porosity and permeability; spotty yellow fluorescence; instant bluish white cut fluorescence and very pale straw cut. 10930' MD 6207' TVD Shale = dark gray to medium dark gray; firm to very firm; brittle tenacity; flaky to planar fracture; tabular to elongated and wedge like cuttings; matte to slightly shiny luster; smooth texture; non calcareous; moderately to very carbonaceous. 10970' MD 6225' TVD Altered zone = pale yellowish orange to light brown to moderate reddish brown to white; brittle to crumbly; non calcareous; some inner crystal growth; predominantly smooth surface; possible altered ash; moderately hard. 11000' MD 6238' TVD Sand = clear to translucent to moderate reddish brown due to staining; very fine lower to fine lower and occasionally lower medium; angular to sub-angular to sub-round; grains appear to be bit broken from medium sized well rounded grains; poor to moderately sorted; moderately prismoidal sphericity; abundant impact surface abrasion; 85% quartz, 15% siderite, mica, pyrite and other lithics; light gold sample fluorescence with instant bright yellow burst cut and moderately streaming cuts with free oil on surface; residual ring was bright orange and very pronounced; oil visible on sand grains. ) 11080' MD 6273' TVD U EPO(~H 24 ) PHilliPS Alaska, Inc. ) ) PHilliPS ~ 2l-03 Sand = clear to translucent to brownish red to white; very fine to fine to coarse and bit broken into angular fine grains; staining and tar present on surface; abundant oxidized glauconite; poorly sorted; very angular to angular to rounded and subrounded mature grains; impact and bit broken surface abrasion; dull gold sample fluorescence; bright yellow burst and flash cut; bright orange residual cut fluorescence. 11160' MD 6308' TVD Sand = dominantly clear and milky white; clasts range from very fine to occasionally medium grain; dominantly very fine to fine; angular to subround; poorly sorted; composed of mainly quartz with minor lithics, trace pyrite clusters, extremely calcareous; trace diffuse light yellow cut fluorescence. 11215'MD 6332'TVD Shale = medium to dark gray, grayish black to black; firm to rarely moderately hard; crumbly to brittle; flaky, blocky and tabular cuttings; matte to slightly resinous luster; dominantly smooth to locally moderately gritty texture; non calcareous; scattered carbonaceous laminations; rare streaks of ashy appearing material; moderately to occasionally very fissile. ) 11270' MD 6356' TVD Shale = dark gray to black, medium to dark gray; firm to occasionally moderately hard; crumbly to brittle; platy, blocky and tabular cuttings; dull to slightly resinous luster; dominantly smooth to occasionally moderately gritty texture; non calcareous; scattered carbonaceous laminations; rare streaks of ashy appearing material; moderately to occasionally very fissile. ) (:1 EPO(~H 25 PHILLIPS Alaska, Inc. ~ ~ 2L-03 RIG ACTIVITIES 2/04/02 Pre-spud meeting pick up 5" drill pipe (48 joints) and HWDP (29 joints) to derrick pick up 4" drill pipe and 3.5" HWDP to derrick pick up BHA (stabilizer crossover's and bit) to floor pick up motor and bit make up stabilizer LWD MWD float subscribe motor load and test MWD suspended operations at 1800 hrs due to Phase 3 weather conditions. /~/05/02 ~hase III weather risk, work suspended; general maintenance only. Phase II conditions allow work to regain: Pick up 5" drill pipe and stand back in derrick. 2/05/02 Finish picking up 5" drill pipe and heavy weight drill pipe; stand back in derrick: dig out and secure diverter line, pick up motor and bit. Wash snow and ice from conductor 47' to 110'; pick up BHA and initialize MWD. Spud well At 13:00; drilling 12 'X" surface hole from 110' to 261'. Performed short trip and stand back 8" drill collars and one stand of heavy weight drill pipe. Directionally drill from 261' to 800'. 2/06/02 Drilling from 800' to 2007', circulate hole clean and monitor well. Short trip to 1080', trip in hole washing 30' to bottom with no fill. Drill from 2007' to 2600'. ,r-"?/07/02 Drilling from 2600' to 3093', pump high viscosity weighted sweep, circulate until clean. No tight spots, trip in hole and washed 60' to bottom with no fill. Circulate bottoms up, monitor well, pump high viscosity weighted sweep and circulate until clean. Pull out of hole, pump dry job, slow through permafrost 1650' to 800', 25k on overpull from 850' to 700'. Work through and came clean, laid down BHA and rigged up CSCR. Run 9 5/8" casing, hit solid bridge at 1084'. Circulate and wash on bridge. 2/08102 Circulate and wash on bridge to 1089', laid down 9 5/8" casing. Picked up BHA and drill pipe, tripped in hole to 1079' and hit bridge. Wash and ream tight spots at 1079' to 1089', and again at 1118' to 1122', and 1155' to 1171'. Circulate bottoms up at 1288'. Circulate U EPOCH 26 /~ ..-..., ---. PHILLIPS Alaska, Inc. ~ ~ 2L-03 to clean hole. Pulled out of hole and ran 9 5/8" casing to 1990'. Circulate bottoms up and ran 9 5/8" casing. restrictions from 2013' to 2045',2813' to 2890'. Circulate and condition hole at 3072'. Washed through 2/09/02 Circulate and condition for cement. Picked up cement head and cemented as per program. Rigged down cementers and laid down landing joint, nippled down diverter system, nippled up BOP's and tested same. Installed wear ring, picked up BHA and steam thaw. Started making up BHA #3. ~ , ./10/02 Finished making up BHA #3, tripped in hole to 2990'. Cement contaminated mud plugged flowline, circulated and conditioned cement contaminated mud. Tested casing and drilled cement, float, shoe and 20' of new hole. Circulated and conditioned and displaced to new mud. Formation integrity test performed successfully. Drilled from 3113' to 3434' when MWD failed. Circulated bottoms up and monitored well. Pumped dry job and started pulling out of hole. 2/11/02 Finished pulling out of hote, make up BHA and tripped in hole to 3434'. Circulate bottoms up. Set baseline on the PWD tool and drill from 3434' to 5384'. 2/12/02 Drill from 5384' to 5477'. Circulate sweeps around till clean, performed short trip to shoe. Service top drive, trip in hole, take survey at 3251'. Wash last stand to bottom and began drilling from 5477' to 6685'. '~/13/02 Drill from 6685' to 7150', work on swivel packing and pump high viscosity pill. Raised pH to 10.5 and circulate bottoms up 3 times before performing short trip. Trip in hole to 7059', wash and ream to 7150'. Circulate out thick mud and began drilling from 7150' to 7985'. 2/14/02 Drilling from 7985' to 8600'. Circulated bottoms up 3 times and monitored well. Made short trip to 7150' and tripped to 8453' made mad pass from 8453' to 8600'. Drilled from 8600' to 9180'. (1 EPOCH 27 ....-' ~, -, PHilliPS Alaska, Inc. ~ ~ 2l-03 2/14/02 Drilled from 9180' to 10728'. 2/15/02 Drilled from 7985' to 8600', Pump sweep, circulate bottoms up three times. Pump dry job, short trip to 7150'. Run into hole to 8453', perform MAD pass from 8453' to 8600'. Drill from 8600' to 9180'. ----. /16/02 Drilled from 9180' to 10728'. 2/17/02 Drilled from 10728' to 10773', pump sweep, circulate bottoms up three times, short trip to 8600', 25k to 50k overpull from 9908' to 9750'. Run into hole, pump sweeps, circulate bottoms up three times, spot lube pill, monitor well. Pump dry job pull out of hole, lay down bottom hole assembly, pull wear ring, install test plug, change out rams in preparation for 7 inch casing. 2/18/02 Run 7 inch casing, breaking circulation periodically. Circulate and condition mud, cement casing in place, rig down cementing equipment, set pack-off and test. Change-out tools on top drive. 2/19/02 Nipple up and test BOPE. Lay down 5" drill pipe. Make up BHA. Run into hote, picking up 4" drill pipe. ,"-" 2/20/02 Run into hole. Drill out float collar and 27 feet of formation. Test formation to 15.1 ppg emu. Displace mud to 12.2 ppg mud. Drill ahead. 2/21/02 Drill to 10261'. Losing returns, short trip to shoe. Run in to 11197', circulate 11.6 ppg mud around. Totall05s of 31 barrels. 2/22102 [:I EPOCH 28 ~. ~ -.. PHilliPS Alaska, Inc. ~ ~ 2l-03 Drill to 11316'-End of well. ,-.. ,--.. ~ EPOCH 29 ~, ~\ ..........., PHILLIPS Alaska, Inc. ~ ~ 2L-03 MUD RECORD ~ ~ Phillips 2L-03 DAILY MUD REPORTS ~E DEPTH WEIGHT VIS PV YP GELS FILTRATE CAKE SOLIDS SAND pH Pm Pf/Mf CI Ca -! ~ - .,102 110 8.70 75 22 21 10/32/60 13.0 2.010.0 2.7 0.00 8.80 0.10 0.1010.40 800 80 2/06/02 155 8.70 128 28 33 14/28/36 7.0 2.0/0.0 2.7 0.65 8.80 0.10 0.1010.40 800 80 2/06/02 800 9.05 105 26 38 22/42/56 9.0 2.0/0.0 4,2 2.50 9.50 0.25 0,15/0.40 500 40 2/07/02 1915 9.70 77 28 29 15/47/57 8.0 2.0/0.0 6.8 4,50 9.60 0.30 0,20/0.50 500 40 2/07/02 2600 9.70 63 25 22 9/33/52 7.0 2.0/0.0 6.8 2.00 9.50 0.25 0.15/0.50 500 40 2/08/02 3093 9.90 63 29 20 8/30/48 5.0 2.010.0 7.8 2.00 9.50 0.30 0,15/0.50 500 40 2/08/02 3093 10.10 82 33 32 9/16/34 5.0 2.0/0.0 8.8 2.00 9.50 0.30 0,15/0,50 500 40 2/09102 3093 10.10 82 29 20 5/15/26 4.0 2.010.0 8.8 2.00 9.50 0.30 0,15/0.50 500 40 2/09/02 3093 10.10 67 32 18 5/10/17 5.5 2.010.0 8.8 2,00 9.50 0.30 0,15/0.50 500 40 2/10/02 3093 10.10 67 32 18 5/10/17 5.5 2.010.0 8.8 2.00 9.50 0.30 0,15/0.50 500 40 2/10102 3093 9.40 48 15 15 3/05/08 7.0 2.010.0 5.7 0.00 9.50 0.12 0.15/0.50 1000 40 2/11/02 3093 9.60 48 15 15 3/05/08 7.0 2.010.0 5.7 0.00 9.90 0.35 0.3010.50 800 40 2/11/02 3434 9.65 45 19 17 5/07/08 5.6 2.010.0 6.8 0.50 10.20 0.40 0.35/1.00 500 120 r -.., '/02 4410 9.65 48 16 20 7109/10 5.0 2.010.0 6.8 0.50 9.90 0.35 0,25/0.90 500 100 - 2/12/02 5384 9.70 48 15 19 6/07108 4.5 2.0/0.0 6.8 0.35 9.90 0.50 0.25/1.00 500 80 2/13/02 5880 9.60 44 14 16 5/06/07 4.6 2.0/0.0 6.8 0.10 9.80 0.45 0,25/0.80 500 80 2/13/02 6685 9.60 45 15 16 6/08/09 4.6 2.010.0 6.8 0.10 9.50 0.30 0.2010.90 400 40 2/14/02 8600 9.60 45 15 15 5/06/07 4.0 2.0/0.0 8.3 0.10 10.50 0.60 0.45/1.00 400 40 2/14/02 7985 9.60 43 14 15 5/06/07 4.4 2.0/0.0 7.8 0.10 9.90 0.40 0.30/0.80 400 40 2/15/02 8600 9.60 45 15 15 5/06/07 4.0 2.010.0 8.3 0.10 10.50 0.60 0.45/1.00 400 40 2/15/02 9180 9.60 52 17 16 5/06/08 4.2 2.0/0.0 7.8 0.10 9.70 0.40 0.20/0.80 600 40 [~ EPOCH 30 ~. ~., .~. PHILLIPS Alaska, Inc. . rÐ 2L-03 DATE DEPTH WEIGHT VIS PV YP GELS FILTRATE CAKE SOLIDS SAND pH Pm Pf/Mf CI Ca 2/16/02 10120 9.60 48 18 16 5/6/7 3.6 2.0/0.0 7.3 0.35 9.00 0.20 0.15/0,90 500 40 2/16/02 10728 9.60 44 17 14 4/6/9 3.0 2.0/4.0 6.8 0.35 10.00 0.50 0.35/1.20 500 40 2/17/02 10773 9.60 44 17 14 4/6/9 3.0 2.0/4.0 6.8 0.35 10.00 0.50 0.35/1.20 500 40 2/17/02 10773 9.60 46 18 14 4/5/5 3.2 2.0/4.0 7.3 0.35 10.40 0.60 0.40/1.20 500 40 2/18/02 10773 9.75 48 18 14 4/5/6 3.2 2.0/4.0 7.8 0.35 9.20 0.30 0.20/1.20 500 40 2/18/02 10773 10.70 49 23 19 5/6/6 3.0 2.0/4.0 9.8 0.35 9.10 0.25 0.15/1.20 500 40 .3JJSI°2 10733 9.60 46 15 18 517/9 3.0 2.0/3.0 11.8 0.00 9.70 0.25 0.15/1.10 450 40 .. ,02 10733 12.20 54 30 27 8/11/16 3.2 2.0/4.0 24.8 0.00 9.00 0.25 0.15/1,00 700 60 L - 2/20/02 10844 12.20 55 16 27 7/11/16 2.8 2.0/4.0 25.8 0.00 9.50 0.35 0.20/0.75 700 60 2/21/02 11261 11.60 45 16 18 6/8/12 3.5 2.0/4.0 20.3 0.00 9.00 0,30 0.20/1.00 500 60 2/22/02 11245 11.60 42 16 18 6/8/12 3.8 2.0/4.0 19.8 0.00 9.50 0.35 0.20/0,90 500 60 2/23/02 11316 11.60 42 18 14 5/6/12 3.5 2.0/4.0 19.8 0.00 9.40 0.40 0.30/0.90 500 60 ..-... (J EPOCH 31 ~. ~, ..-.., PHilliPS Alaska, Inc. . ~ 2l-03 SURVEY RECORD Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg feet degrees degrees feet feet feet feet degrees/100 feet 0.00 O.DO 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 110.00 0.00 0.00 110.00 0.00 N 0.00 E 0.00 0.00 185.58 0.27 1.27 185.58 0.18 N 0.00 E 0.15 0.36 275.63 0.79 37.33 275.63 0.88 N 0.39 E 0.95 0.66 ~~ 367.95 2.36 41.12 367.91 2.02 E 3.47 1.70 2.82 N 456.82 3.18 43.25 456.67 6.00N 4.92 E 7.73 0.93 549.54 4.25 42.15 549.20 10.42 N 8.99 E 13.69 1.16 641.72 5.76 42.61 641.02 16.36 N 14.41 E 21.67 1.64 730.72 7.93 40,87 729.38 24.29 N 21.45 E 32.21 2.44 819.60 12.00 38.15 816.90 36.20 N 31.17 E 47.54 4.61 910.36 15.97 36.97 904.96 53.60 N 44.52 E 69.45 4.39 1001.69 17.79 36.06 992.35 74.92 N 60.29 E 95.96 2.02 1094.78 19.62 34,80 1080.52 99.25 N 77.58 E 125.81 2.01 1187.44 22.39 35.37 1167.01 126.43 N 96.68 E 159.02 3.00 1280.58 26.72 35.50 1251.71 157.95 N 119.12 E 197.72 4.64 1373.23 30.37 35.71 1333.08 193,93 N 144.89 E 241.98 3.94 1466.48 31.01 35.99 1413.27 232.51 N 172.76 E 289.56 0.70 ---- 1559.09 33.99 33,02 1491.38 273,53 N 200.90 E 339.30 3.65 1652.45 39.30 30.17 1566.26 321.01 N 230.00 E 394.89 5.97 1744.64 39.51 30.02 1637.49 371.65 N 259.35 E 453.19 0.25 1838.12 39.91 32.53 1709.41 422.68 N 290.35 E 512.77 1.77 1930.83 41.21 34.69 1779.84 472.87 N 323.73 E 573.03 2.07 2024.50 43.29 35.41 1849.18 524.42 N 359.90 E 636.00 2.28 2116.97 45.64 35.37 1915.17 577.22 N 397.41 E 700.77 2.55 2209.38 48.83 35.24 1977.90 632.58 N 436.62 E 768.61 3.44 Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg n EPOCH 32 ~ ,.,.-... ..-..., PHILLIPS Alaska, Inc. ((I ŒJ 2L-03 feet degrees degrees feet feet feet feet degrees/100 feet 2302.26 52.11 35.38 2037.01 691.03 N 478.02 E 840.23 3,54 2395.52 55.68 36.17 2091.96 752.14 N 522.07 E 915.56 3,89 2488.50 59.85 36.88 2141.54 815.33 N 568.89 E 994.17 4.53 2581.59 61.08 36.99 2187.42 880.06 N 617.56 E 1075.12 1.33 2674.45 62.26 36.16 2231.49 945.71 N 666.26 E 1156.83 1.48 2767.16 61.43 34.69 2275.24 1012.30 N 713.64 E 1238.56 1.66 2859.50 62.84 34.26 2318.40 1079.60 N 759.84 E 1320.19 1.58 ~ 2952.50 62.47 33.16 2361.13 1148.31 N 805.69 E 1402.77 1.13 3018.17 62.38 33.95 2391.53 1196.82 N 837.86 E 1460.95 1.08 3179.93 62.08 35.57 2466.91 1314.40 N 919.46 E 1604.07 0.90 3272.73 61.95 35.74 2510.88 1380.58 N 967,42 E 1685.79 0.08 3361.00 61.75 35.81 2552.52 1443.72 N 1012.91 E 1763.61 0.23 3454.65 61.56 35.73 2596.98 1510.60 N 1061.09 E 1846.03 0.21 3548.49 61.58 36,30 2641.65 1577.35 N 1109.62 E 1928.54 0.53 3640.20 61.51 36.15 2685.35 1642.40 N 1157.26E 2009.16 0.16 3733.17 61.40 35,72 2729.78 1708.52 N 1205.19 E 2090.82 0.42 3825.64 61.63 35.76 2773.88 1774.50 N 1252.66 E 2172.09 0.26 3918.69 61.66 35.87 2818.06 1840.90 N 1300.58 E 2253.97 0.12 4011.90 61.84 35.70 2862.18 1907.51 N 1348.60 E 2336.07 0.25 4104.59 61.88 36,05 2905.89 1973.74 N 1396.49 E 2417.80 0.33 4197.75 61.79 35.90 2949.86 2040.20 N 1444.74 E 2499.92 0.17 ~- 4290.21 61.91 36.25 2993.49 2106.09 N 1492.74 E 2581.43 0.36 4383.24 62.06 36.03 3037.19 2172.42 N 1541.18 E 2663.54 0,27 4476.11 60.90 34.10 3081.53 2239.19 N 1588.06 E 2745.14 2.21 4569.32 60.69 34.21 3127.02 2306.52 N 1633.74 E 2826.49 0.24 4661.96 60.54 34.40 3172.47 2373.20 N 1679.24 E 2907.20 0.25 4754.58 60.24 33.76 3218.24 2439.89 N 1724.36 E 2987.71 0.68 Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg feet degrees degrees feet feet feet feet degrees/100 feet U EPOCH 33 ~ r--~, ----. PHilliPS Alaska, Inc. . m 2l-03 4847.27 60.26 34.02 3264.24 2506.68 N 1769.24 E 3068.16 0.25 4941.04 60.25 33.90 3310.76 2574.21 N 1814.72 E 3149.56 0.11 5033.42 60.25 33.87 3356.61 2640.79 N 1859.44 E 3229.75 0.03 5125.63 60.21 33.96 3402.39 2707.21 N 1904.10 E 3309.77 0.10 5219.46 60.22 33.86 3449.00 2774.79 N 1949.54 E 3391.19 0.09 5312.25 60.63 35.09 3494.80 2841.31 N 1995.22 E 3471.88 1.24 5404.51 60.65 34,64 3540.03 2907.29 N 2041.19 E 3552.29 0.43 5502.70 60.61 34,28 3587.76 2978.25 N 2089.42 E 3638.08 0.32 ..-- 5596.58 60.64 34,01 3633.81 3045.96 N 2135.34 E 3719.89 0.25 5683.63 60.34 34,02 3676.68 3108.76 N 2177.72 E 3795.63 0.34 5776.77 61.38 35.56 3722.03 3175.56 N 2224.14 E 3876,98 1.83 5869.40 61.70 36.42 3766.17 3241.46 N 2272.00 E 3958.41 0.88 5962.21 61.60 36.34 3810.24 3307.22 N 2320.44 E 4040.06 0.14 6055.69 61.58 35.69 3854.72 3373.72 N 2368.78 E 4122.27 0.61 6147.97 61.46 36.04 3898.73 3439.46 N 2416.30 E 4203.38 0.36 6240.33 61.43 36.55 3942.87 3504.85 N 2464.32 E 4284.48 0.49 6333.54 61.42 35.72 3987.45 3570.96 N 2512.59 E 4366.33 0.78 6427.03 61.42 35.89 4032.17 3637.54 N 2560.62 E 4448.42 0.16 6520.12 61.35 35.90 4076.75 3703.75 N 2608.53 E 4530.14 0.08 6612.70 61.46 35.98 4121.06 3769.57 N 2656.24 E 4611.42 0.14 6705.36 61.18 36.00 4165.53 3835.34 N 2704.00 E 4692.70 0.30 6796.80 61.12 36.21 4209.64 3900.06 N 2751.19E 4772.78 0.21 -- 6891.06 61.11 36.25 4255.17 3966.64 N 2799.97 E 4855.30 0.04 6984.66 61.22 35.96 4300.31 4032.89 N 2848.29 E 4937.28 0.30 7075.85 61.42 36.4 7 4344.08 4097.43 N 2895.55 E 5017.27 0.54 7170.50 61.57 36,23 4389.25 4164.42 N 2944.85 E 5100.42 0.27 Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg feet degrees degrees feet feet feet feet degrees/100 feet 7254.62 61.11 36.38 4429.60 4223.91 N 2988.55 E 5174.22 0.56 7348.45 60.90 35.38 4475.08 4290.40 N 3036.65 E 5256.28 0.95 7444.28 60.84 35.82 4521.73 4358.47 N 3085.38 E 5339.98 0.40 U EPOCH 34 ~ ".-., ~'. PHilliPS Alaska, Inc. . m 2l-03 7542.88 61.32 34.29 4569.42 4429.11 N 3134.94 E 5426.28 1.44 7635.94 61.43 34.49 4614.00 4496.52 N 3181.08 E 5507.96 0.22 7727.34 61.19 33.77 4657.88 4562.89 N 3226.06 E 5588.13 0.74 7820.69 61.08 33.99 4702.94 4630.76 N 3271.64 E 5669.86 0.23 7913.17 60.97 34.08 4747.74 4697.81 N 3316.92 E 5750.75 0,15 8006.07 60.99 34.30 4792.81 4765.01 N 3362.56 E 5831.98 0.21 8099.06 60.88 34.55 4837.99 4832.05 N 3408.51 E 5913.25 0.27 ,r- 8191.71 60.81 34.79 4883.12 4898.60 N 3454.54 E 5994.16 0.24 8284.90 60.54 35.44 4928.76 4965.06 N 3501.27 E 6075.41 0.67 8377.93 60.05 35.33 4974.85 5030.94 N 3548.06 E 6156.22 0.54 8470.76 59.65 35.31 5021.48 5096.44 N 3594.47 E 6236.49 0.44 8563.54 60.91 34.13 5067.48 5162.67 N 3640.36 E 6317.06 1.75 8656.18 60.84 33.51 5112.56 5229.90 N 3685.40 E 6397.96 0.59 8749.42 60.74 34.25 5158.06 5297.47 N 3730.77 E 6479.33 0.70 8842.37 60.68 34.03 5203.54 5364.56 N 3776.27 E 6560.39 0.22 8935.08 61.08 34.37 5248.66 5431.54 N 3821.80 E 6641.37 0.54 9028.21 60.67 33.99 5293.98 5498.85 N 3867.50 E 6722.71 0.56 9121.54 60.42 33.67 5339.88 5566.35 N 3912.75 E 6803.96 0.40 9214.06 60.22 33.80 5385.69 5633.20 N 3957.39 E 6884.32 0.25 9306.70 60.34 34.13 5431.62 5699.93 N 4002.34 E 6964.76 0.33 9399.92 61.17 33.93 5477.15 5767.34 N 4047.86 E 7046.08 0.91 9493.23 61.46 34.85 5521.94 5834.89 N 4094.09 E 7127.94 0.91 --. 9586.10 61.61 34.70 5566.20 5901.95 N 4140.65 E 7209.58 0.21 9679.01 61.69 34.66 5610.32 5969.19 N 4187.18 E 7291.34 0.09 Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dog Leg feet degrees degrees feet feet feet feet degrees/100 feet 9771.83 61.83 35.11 5654.24 6036.27 N 4233.95 E 7373.11 0.45 9864.55 61.73 35.54 5698.09 6102.92 N 4281.19 E 7454.81 0.42 9956.96 61.59 35.79 5741.96 6169.00 N 4328.61 E 7536.14 0.28 10049,83 61.26 35.22 5786.38 6235.39 N 4375.98 E 7617.70 0.65 10142.76 60.99 35.07 5831.25 6301.93 N 4422.82 E 7699.07 0.32 n EPOCH 35 ,~ /-., ~, PHILLIPS Alaska, Inc. . ~ 2L-03 10235.59 60.60 35.17 5876.55 6368.21 N 4469.44 E 7780.10 0.43 10328.68 60.93 35.37 5922.01 6434.53 N 4516.35 E 7861.33 0.40 10421.85 61.01 35.23 5967.22 6501.02 N 4563.42 E 7942.80 0.16 10514.47 61.40 36.84 6011.83 6566.65 N 4611.17 E 8023.95 1.58 10607.19 61.48 35.75 6056.16 6632.29 N 4659.37 E 8105.37 1.04 10700.73 60.93 35.31 6101.22 6699.00 N 4707.00 E 8187.34 0.72 10766.48 61.07 35.26 6133.09 6745.95 N 4740.22 E 8244.85 0.23 ,- 10862.06 63.80 34.93 6177.32 6815.27 N 4788.93 E 8329.57 2.87 10958.27 63.97 34.68 6219.66 6886.21 N 4838.23 E 8415.96 0.29 11054.04 64.32 34.19 6261.43 6957.29 N 4886.97 E 8502.14 0.59 11152.37 63.84 33.34 6304.41 7030.81 N 4936.12 E 8590.55 0.91 11245.50 64.15 33.35 6345.24 7100.73 N 4982.13 E 8674.21 0.34 11316.00 64.15 33.35 6375.98 7153.73 N 5017.01 E 8737.63 0.01 .--.... n EPOCH 36 ,---, ''--'. --, Phillips Alaska North Slope 2L-03 REPORT FOR Rick Levinson ) DATE Feb 07, 2002 TIME 05:00:00 ) DAILY WELLSITE REPORT ) ~ EPOCH DEPTH 1172 YESTERDAY 1 PRESENT OPERATION= Drilling and Sliding ahead CASING INFORMATION 15" conductor @ 110' 24 Hour Footage 1171 SURVEY DATA BIT INFORMATION NO. SIZE 1 12,25" TYPE MXC1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.70 FC 2.0/0,0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) ~H GAS _",+rING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL DEPTH 1094.78 INCLINATION AZIMUTH VERTICAL DEPTH 19,62 34.80 1080.52 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 x 14/3x22 110 SIN 5002280 VIS SOL HIGH lOW AVERAGE CURRENT AVG 254,3 @ 1132 5,3 @ 1079 108,3 186,5 fVhr 492 @ 1155 2 @ 808 60.9 39.2,3 amps 28 @ 853 0 @ 715 11.0 19,5 Klbs 67 @ 361 2 @ 619 19,9 55 RPM 1401 @ 1089 513 @ 111 835,1 1285 psi DEPTH: 110 75 PV 22 YP 21 FL Gels 10/32/60 CL~. 800 2,7 SD 0,00 OIL MBl 22,5 pH 8,80 Ca+ 80 CCI HIGH LOW AVERAGE 9 @ 1164 0 @ 1143 1.2 0 @ 1172 0 @ 1172 0,0 CHROMATOGRAPHY(ppm) 1830 @ 1164 50 @ 1143 250.4 0 @ 1172 0 @ 1172 0,0 0 @ 1172 0 @ 1172 0,0 ° @ 1172 0 @ 1172 0,0 0 @ 1172 ° @ 1172 0,0 LITHOLOGY/REMARKS . . TRIP GAS= n/a , . WIPER GAS= Ou @ 261' SURVEY= OU CONNECTION GAS HIGH=Ou AVG= Ou CURRENT OU CURRENT BACKGROUND/AVG 1,5u GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 70% Conglomeratic Gravel, 30% Claystone DAILY ACTIVITY SUMMARY Picked up Drill Pipe, Made up BHA, Drilled ice in conductor, and spudded well, drilling at report time Epoch Personel On Board= 2 Daily Cost $ 1,920.00 Report by: Brady Kilmer ,) Phillips Alaska North Slope 2l-03 REPORT FOR Rick Levinson ) DATE Feb 08,2002 TIME 05:00:00 CASING INFORMATION 15" @ 110' SURVEY DATA BIT INFORMATION NO, SIZE 1 12 1/4" TYPE MXC1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,05 FC 2,0/0,0 VIS SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) 'ÇH GAS firiNG GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY ) DAILY WELLSITE REPORT DEPTH 2860 YESTERDAY 1173 24 Hour Footage 1687 DEPTH 2767,16 INCLINATION 61.43 AZIMUTH 34.69 SIN 5002280 JETS 1 x14/3x22 INTERVAL IN OUT 110 FOOTAGE ) g EPOCH PRESENT OPERATION= Drilling Ahead VERTICAL DEPTH 2275,24 HOURS CONDITION T/B/C REASON PULLED HIGH LOW AVERAGE CURRENT AVG 367.4 @ 1474 9,9 @ 2605 153,2 120.6 fUhr 655 @ 2701 0 @ 2487 259,9 0,0 amps 29 @ 2857 0 @ 1458 16,9 28,8 Klbs 65 @ 2655 1 @ 1547 30,8 0 RPM 1728 @ 2197 469 @ 1458 1440.6 1402 psi DEPTH: 800 105 PV 26 YP 38 FL Gels 22/42/56 CL- 500 4.2 SO 2.50 OIL MBL 22.5 pH 9,50 Ca+ 40 CCI HIGH LOW AVERAGE 1400 @ 1399 ° @ 1251 132,7 0 @ 2860 0 @ 2860 0,0 CHROMATOGRAPHY(ppm) 280000 @ 1399 150 @ 2312 27879,0 146 @ 2746 1 @ 2374 18,0 21 @ 2557 1 @ 2855 1,6 ° @ 2860 0 @ 2860 0,0 0 @ 2860 ° @ 2860 0.0 LITHOLOGY/REMARKS DAILY ACTIVITY SUMMARY Drilled from 1173' to 200T and performed wiper trip; tripped dDwn to 2959' at report time Epoch Personel On Board= 2 Daily Cost $ 1920,00 Report by: Brady Kilmer ) TRIP GAS"; N/A WIPER GAS= 45u @ 200T SURVEY= N/A CONNECTION GAS HIGH= Ou AVG= Ou CURRENT Ou CURRENT BACKGROUND/AVG 293u GAS DESCRIPTION Phillips Alaska North Slope 2L-03 REPORT FOR Rick Levinson ) DATE Feb 09,2002 TIME 05:00:00 CASING INFORMATION 15" @ 110' SURVEY DATA BIT INFORMATION NO, SIZE 1 12,25" TYPE MXC1 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) "çH GAS ÅTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY ) DAILY WELLSITE REPORT DEPTH 3093 YESTERDAY 2861 ) ~ EPOCH PRESENT OPERATION= Prepare to run casing 24 Hour Footage 232 DEPTH 3093' INCLINATION 62,38 SIN 5002280 INTERVAL IN OUT 110' 3093' FOOTAGE 2983' JETS 1x14/3x22 HIGH LOW 175,8 @ 2894 20,6 @ 2957 719 @ 2904 11 @ 3031 32 @ 2895 3 @ 2937 65 @ 2902 28 @ 3030 1799 @ 2913 1345 @ 2937 DEPTH: VIS PV YP SOL SD OIL HIGH LOW AVERAGE 274 @ 3030 90 @ 3017 164,5 0 @ 3093 0 @ 3093 0,0 CHROMATOGRAPHY(ppm) 63231 @ 3030 20770 @ 3017 38102,5 24 @ 2893 8 @ 3092 15,3 0 @ 3093 0 @ 3093 0,0 0 @ 3093 0 @ 3093 0,0 0 @ 3093 0 @ 3093 0,0 LITHOLOGY/REMARKS DAILY ACTIVITY SUMMARY Trip out of hole to run casing Epoch Personel On Board= 2 Daily Cost $ 1,920,00 Report by: Brady Kilmer ) AZIMUTH 33.95 HOURS 43.40 AVERAGE 105.7 423.8 23,7 43,3 1603,5 FL MBL VERTICAL DEPTH 2426.22' CONDITION T/B/C REASON PULLED casing CURRENT AVG 75.0 448,8 3.6 61 1426 ftIh r amps Klbs RPM psi Gels pH CL- Ca+ CCI TRIP GAS= n/a WIPER GAS= n/a SU RVEY= n/a CONNECTION GAS HIGH= n/a AVG= n/a CURRENT n/a CURRENT BACKGROUND/AVG Ou GAS DESCRIPTION Phillips North Slope ) DAILY WELLSITE REPORT 2L.03 REPORT FOR Rick Levinson )oATE Feb 10, 2002 TIME 05:00:00 ') g EPOCH DEPTH 3093 YESTERDAY 3093 PRESENT OPERATION= Pulling Casing due to tight hole 24 Hour Footage 0 CASING INFORMATION 15" @ 110' SURVEY DATA DEPTH AZIMUTH INCLINATION BIT INFORMATION NO, SIZE SIN INTERVAL JETS IN OUT FOOTAGE HOURS HIGH LOW AVERAGE 75,0 @ 3093 75,0 @ 3093 0 448 @ 3093 448 @ 3093 0 3 @ 3093 3 @ 3093 0 61 @ 3093 61 @ 3093 0 1426 @ 3093 1426 @ 3093 0 DEPTH: PV YP FL SD OIL MBL TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC VIS SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS r' IjlNG GAS METHANE(C.1) ETHANE(C.2) PROPANE(C.3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL VERTICAL DEPTH CONDITION T/B/C REASON PULLED CURRENT AVG 75.0 448,8 3,6 61 1426 ftlhr amps Klbs RPM psi Gels pH CL- Ca+ CCI HIGH LOW AVERAGE 109 @ 3093 109 @ 3093 0 TRIP GAS= n/a 0 @ 3093 0 @ 3093 0 WIPER GAS= n/a CHROMATOGRAPHY(ppm) SURVEY= n/a 25226 @ 3093 25226 @ 3093 ° CONNECTION GAS HIGH= n/a 9 @ 3093 9 @ 3093 ° AVG= n/a 0 @ 3093 0 @ 3093 0 CURRENT n/a 0 @ 3093 0 @ 3093 0 CURRENT BACKGROUND/AVG n/a 0 @ 3093 0 @ 3093 0 LITHOLOGY IREMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished tripping out; ran in with casing; pull casing due to tight hole Epoch Personel On Board= 4 Daily Cost $2.480,00 Report by: Brady Kilmer ) Phillips Alaska North Slope 2L-03 REPORT FOR Rick Levinson ) DATE Feb 12, 2002 TIME 05:00:00 CASING INFORMATION 95/8" @ 3093' SURVEY DATA BIT INFORMATION NO, SIZE 2 8 1/2" TYPE DS70FNPV DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.10 FC 2,0/0,0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) \;H GAS ...kINGGAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ) DAILY WELLSITE REPORT ') g EPOCH DEPTH 3519 YESTERDAY 3095 PRESENT OPERATION= Drilling Ahead 24 Hour Footage 424 DEPTH Not Corrected INCLINATION AZIMUTH VERTICAL DEPTH SIN 24311 INTERVAL IN 3093 HOURS REASON PULLED VIS SOL CONDITION T/B/C HIGH LOW AVERAGE CURRENT AVG 413,1 @ 3179 37,7 @ 3099 160,9 86.6 672 @ 3105 510 @ 3436 598,5 562,9 10 @ 3383 1 @ 3104 6.4 5,3 86 @ 3357 33 @ 3113 82,3 83 2032 @ 3493 884 @ 3104 1861.4 1855 DEPTH: 3093' 67 PV 32 YP 18 FL Gels 5/1 0/17 8,8 SD 2,00 OIL MBl 20,0 pH 9,50 CCI JETS 3x13/3x14 OUT FOOTAGE fUhr amps Klbs RPM psi CL- 500 40 Ca+ HIGH LOW AVERAGE 62 @ 3224 ° @ 3496 20,2 ° @ 3519 ° @ 3519 0.0 CHROMA TOGRAPHY(ppm) 20595 @ 3224 273 @ 3496 5740,2 78 @ 3224 1 @ 3496 20,8 ° @ 3519 0 @ 3519 0,0 ° @ 3519 ° @ 3519 0,0 ° @ 3519 ° @ 3519 0,0 LITHOLOGY/REMARKS TRIP GAS= 47u @ 3435' WIPER GAS= n/a SURVEY= n/a CONNECTION GAS HIGH= n/a AVG= n/a CURRENT n/a CURRENT BACKGROUND/AVG 9u GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 40%, Sand 30%, Shale 10%, Siltstone 10%, Tuff 10% DAILY ACTIVITY SUMMARY Drilled to 3435', Tripped for MWD, Tripped in hole with new MWD, Drilled to 3621' at report time Epoch Personel On Board= 4 Daily Cost $ 2,480,00 Report by: Brady Kilmer ,) Phillips Alaska North Slope ) DAILY WELLSITE REPORT ) ~ EPOCH 2L-03 REPORT FOR Rick Levinson ) DATE Feb 13, 2002 TIME 05:00:00 DEPTH 5477 YESTERDAY 3520 PRESENT OPERATION= Short Tripping 24 Hour Footage 1957 CASING INFORMATION 95/8" @ 3093' SURVEY DATA DEPTH 5404,51 ' iNCLINATION 60,65 AZIMUTH 34,64 VERTICAL DEPTH 3540.03' BIT INFORMATION NO, SIZE 2 8 1/2" TYPE DS70FNPV SIN 24311 JETS 3x13/3x14 INTERVAL IN 3093' OUT FOOTAGE HOURS CONDITION T/B/C REASON PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,65 FC 2.0/0.0 HIGH LOW AVERAGE CURRENT AVG 316,7 @ 4667 24.7 @ 4737 165,5 136,0 ft/hr 9024 @ 5416 0 @ 4457 6820.8 8634,7 amps 22 @ 4481 0 @ 5204 5,2 7.3 Klbs 103 @ 4273 43 @ 3716 85,7 95 RPM 2527 @ 5425 1541 @ 3993 2106,8 2324 psi DEPTH: 3434' 45 PV 19 YP 17 FL Gels 5/7/8 CL- 500 6,8 SO 0.50 OIL MBL 7.5 pH 10,20 Ca+ 120 CCI VIS SOL MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) \:H GAS , J"hING GAS HIGH LOW AVERAGE 29 @ 3822 0 @ 3698 11.9 0 @ 5477 0 @ 5477 0,0 CHROMATOGRAPHY(ppm) 8046 @ 3715 210 @ 5156 2671.0 48 @ 5205 1 @ 5468 16,3 0 @ 5477 0 @ 5477 0,0 0 @ 5477 0 @ 5477 0,0 0 @ 5477 0 @ 5477 0,0 LITHOLOGY/REMARKS TRIP GAS= N/A WIPER GAS= N/A SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= N/A CURRENT N/A CURRENT BACKGROUND/AVG 6u M ETHAN E(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Claystone 20%, Sand 10%, Sandstone 20%, Siltstone 50% DAILY ACTIVITY SUMMARY Drilled from 3519' to 5477' to perform short trip and cut and slip drill line, Short tripping at report time. Epoch Personel On Board= 4 Daily Cost $ 2,480,00 Report by: Brady Kilmer ) ..1 Phillips Alaska North Slopé 2L-03 REPORT FOR Rick Levinson ) DATE Feb 14, 2002 TIME 05:00:00 CASING INFORMATION 95/8" @ 3093' SURVEY DATA BIT INFORMATION NO, SIZE 2 8 1/2" TYPE DS70FNPV DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.70 FC 2,0/0.0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) )H GAS '- ~"IrING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL VIS SOL ') DAILY WELLSITE REPORT DEPTH 6969 YESTERDAY 5478 24 Hour Footage 1491 DEPTH 6891.06 iNCLINATION 61,11 SIN 24311 INTERVAL IN 3093' OUT JETS 3x13/3x14 300,1 10156 23 92 2786 HIGH @ @ @ @ @ LOW 6896 9,8 @ 5557 6901 100 @ 5760 5766 0 @ 6965 5559 35 @ 5758 6867 1604 @ 6565 48 6,8 PV SO DEPTH: 5384 15 YP 0,35 OIL 19 FL MBL 49 0 HIGH LOW @ 6962 3 @ 6386 @ 6969 0 @ 6969 CHROMA TOGRAPHY(ppm) @ 6962 680 @ 5696 @ 6698 1 @ 5700 @ 6962 1 @ 6591 @ 6962 1 @ 6931 @ 6969 0 @ 6969 2830.5 81.4 13,0 0.3 0.0 AVERAGE 16,1 0.0 10377 696 143 34 0 LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY Shale 70%, Shell Fragments(ENOC) 10%, Tuff 20% DAILY ACTIVITY SUMMARY Drilled from 5478' to 7057' at report time, Epoch Personel On Board= 4 Daily Cost $ 2,540,00 Report by: Brady Kilmer ) ) [:I EPOCH PRESENT OPERATION= Drilling Ahead AZIMUTH 36,25 VERTICAL DEPTH 4255,17 FOOTAGE CONDITION T/B/C REASON PULLED HOURS AVERAGE CURRENT AVG 136,3 133.2 fUhr 8633,2 9710,6 amps 7,6 1.2 Klbs 80,2 86 RPM 2343,6 2558 psi Gels 6/7/8 CL- 500 10.0 pH 9,90 Ca+ 80 CCI TRIP GAS= n/a WIPER GAS= 105u @ 5477' SURVEY= n/a CONNECTION GAS HIGH= 18u @ 6687' AVG= 10u CURRENT 6u CURRENT BACKGROUND/AVG 23u GAS DESCRIPTION Phillips Alaska North Slope ) DAILY WELLSITE REPORT 2L-03 REPORT FOR Rick Levinson ) DATE Feb 15,2002 TIME 05:00:00 DEPTH 8250 YESTERDAY 6970 24 Hour Footage 1280 CASING INFORMATION 95/8" @ 3093' SURVEY DATA BIT INFORMATION NO, SIZE 2 8 1/2" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.60 FC 2,0/0,0 MWD SUMMARY INTERVAL TOOLS GAS SUMMARY(units) , \H GAS ,",v,IrING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 7460-7820 DEPTH 8099,06' INCLINATION 60,88 TYPE DS70FNPV INTERVAL IN 3093' OUT SIN 24311 JETS 3X13/3X14 319.4 12891 33 101 2760 HIGH @ @ @ @ @ LOW 7276 19,2 @ 7344 7686 0 @ 7529 7538 0 @ 7370 7708 39 @ 7353 7686 1148 @ 7029 VIS SOL DEPTH: 6685 15 YP 0.10 OIL 16 FL MBL PV SD 45 6,8 TO ) ~ EPOCH PRESENT OPERATION= Drilling ahead AZIMUTH 34.55 VERTICAL DEPTH 4837.99' FOOTAGE CONDITION T/B/C REASON PULLED HOURS AVERAGE CURRENT AVG 146,2 102,9 ftlhr 10904,2 0,0 amps 6,6 8.2 Klbs 81,2 83 RPM 2588,8 2563 psi Gels 6/8/9 CL- 400 15.0 pH 9,50 Ca+ 40 CCI HIGH LOW AVERAGE 136 @ 7694 4 @ 8248 22,3 TRIP GAS= n/a 0 @ 8250 0 @ 8250 0.0 WIPER GAS= 75u @ 7152' CHROMA TOGRAPHY(ppm) SURVEY= n/a 30855 @ 7694 579 @ 8248 4554,5 CONNECTION GAS HIGH= 40u @ 771O' 1357 @ 7747 26 @ 8248 174,9 AVG= 5u 1029 @ 7746 13 @ 7499 94,6 CURRENT 8u 679 @ 7749 1 @ 7248 52,7 CURRENT BACKGROUND/AVG 15u 274 @ 7749 1 @ 7622 23,7 Iceberg LITHOLOGY/REMARKS GAS See Log Max Chromo 7673'133u,30828,988,522,1 04, 166,27,25 7695'136u,25514, 141,656, 147,232,68,73 7745'119u,23487,355,1 012,247,429,141,128 DESCRIPTION See Log LITHOLOGY PRESENT LITHOLOGY Claystone 30%, Shale 40%, Siltstone 30% DAILY ACTIVITY SUMMARY Drilled from 7057' to 8345'; drilling ahead at report time, Epoch Personel On Board= 4 Daily Cost $ 2,540,00 Report by: Brady Kilmer ) Phillips Alaska North Slope 2L-03 REPORT FOR Rick LevinsDn ) DATE Feb 16, 2002 TIME 05:00:00 , / DAILY WELLSITE REPORT ) [J EPOCH DEPTH 9365 YESTERDAY 8251 PRESENT OPERATION::: Drilling Ahead CASING INFORMATION 95/8" @ 3093' 24 Hour Footage 1114 SURVEY DATA BIT INFORMATION NO, SIZE 2 8 1/2" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.60 FC 2,010,0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) )H GAS vI./rTlNG GAS METHANE(C-1} ETHANE(C-2} PROPANE(C-3} BUTANE(C-4} PENTANE(C-S} HYDROCARBON SHOWS INTERVAL 8490'-9170' TYPE DS70FNPV DEPTH 9306.70' INCliNATION 60,34 AZIMUTH 34.13 VERTICAL DEPTH 5431,62' SIN 24311 INTERVAL IN 3093' HOURS CONDITION TIBIC REASON PULLED JETS 3x13/3x14 OUT FOOTAGE VIS SOL HIGH LOW AVERAGE CURRENT AVG 195.3 @ 8394 18.5 @ 8904 92,2 81,3 ftIhr ° @ 9365 ° @ 9365 0,0 0.0 amps 37 @ 8907 0 @ 9352 5.2 1,2 Klbs 92 @ 9107 20 @ 8901 80,7 83 RPM 2772 @ 8967 1853 @ 8266 2578,3 2614 psi DEPTH: 7985' 43 PV 14 YP 15 FL Gels 5/6/7 CL- 400 7.8 SD 0,10 OIL MBL 20,0 pH 9,90 Ca+ 40 CCI HIGH LOW AVERAGE 123 @ 8726 4 @ 8994 33,0 TRIP GAS= nla 0 @ 9365 0 @ 9365 0.0 WIPER GAS= 45u @ 8600' CHROMA TOGRAPHY(ppm) SURVEY= nla 19712 @ 9239 169 @ 8978 4592,0 CONNECTION GAS HIGH= 38u @ 9105' 1564 @ 8726 16 @ 8978 345,1 AVG= 10u 1124 @ 8509 13 @ 8978 238,2 CURRENT 12u 596 @ 8509 12 @ 8978 153,3 CURRENT BACKGROUNDIAVG 19u 228 @ 8726 1 @ 8980 64.4 Bermuda LlTHOLOGYIREMARKS See log GAS 123u@8726' 18565,1564,1053,154,397,98,130 DESCRIPTION See Log LITHOLOGY SN 1 OSH40TU20TC20TT1 0 PRESENT LITHOLOGY Sand 10%, Shale 40%, Tuff 20%, Tuffaceous Claystone 20%, Tuffaceous Siltstone 10% DAILY ACTIVITY SUMMARY Drilled frDm 8345' to 9460' at report time, Epoch Personel On Board= 4 Daily Cost $ 2,540,00 Report by: Brady Kilmer ) Phillips Alaska North Slope 2L-03 REPORT FOR Rick Levinson )DATE Feb 17,2002 TIME 05:00:00 CASING INFORMATION 95/8" @ 3093' SURVEY DATA BIT INFORMATION NO. SIZE 2" 81/2" TYPE DS70FNPV DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,60 FC 2,0/0,0 MWD SUMMARY INTERVAL TOOLS TO Gf'.S SUMMARY(units) ~H GAS ",oTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C.4) PENTANE(C-S) HYDROCARBON SHOWS INTERVAL ') DAILY WELLSITE REPORT ) (j EPOCH DEPTH 10773 YESTERDAY 9366 24 Hour Footage 1407 PRESENT OPERATION= Circulating prior to Casing Run DEPTH 10700,73' INCLINATION 60,93 VERTICAL DEPTH 6010,22' AZIMUTH 35,31 SIN 24311 INTERVAL IN 3093' CONDITION T/B/C REASON PULLED FOOTAGE HOURS JETS 3X13/3X14 OUT VIS SOL HIGH LOW AVERAGE CURRENT AVG 261.9 @ 10217 13,S @ 10489 117.8 94,7 fUhr ° @ 10773 ° @ 10773 0,0 0,0 amps 42 @ 10525 ° @ 10418 8,0 12.4 Klbs 97 @ 9755 1 @ 9392 85,2 94 RPM 2974 @ 10231 1832 @ 9388 2747, ° 2924 psi DEPTH: 918O' 52 PV 17 YP 16 FL Gels 4.2 CL- 600 7.8 SD 0,10 OIL MBl 12.0 pH 9,70 Ca+ 40 CCI HIGH lOW AVERAGE 153 @ 10671 6 @ 10467 46,7 ° @ 10773 ° @ 10773 0,0 CHROMATOGRAPHY(ppm) 29786 @ 10671 907 @ 9389 8561,1 2570 @ 10671 62 @ 9389 608,2 1207 @ 10671 36 @ 9389 292,8 580 @ 10491 26 @ 9389 150,5 375 @ 10671 14 @ 10467 79.9 LITHOLOGY/REMARKS TRIP GAS= N/A WIPER GAS= N/A SURVEY= N/A CONNECTION GAS HIGH= 65u @ 10680' AVG= 25u CURRENT 65u CURRENT BACKGROUND/AVG 20u GAS DESCRIPTION LITHOLOGY AZ10RS50SH40 PRESENT LITHOLOGY 10% Metamorphic Altered Zone. 50% Carbonaceous Shale, 40% Shale Shale DAilY ACTIVITY SUMMARY Drilled from 946O' to 10773' (casing point) circulating to condition mud at report time Epoch Personel On Board= 4 Daily Cost $ 2,540,00 Report by: Brady Kilmer ) Phillips Alaska North Slope 2L-03 REPORT FOR Rick Levinson ) DATE Feb 18, 2002 TIME 05:00:00 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE 28,S" TYPE DS70FNPV DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.60 FC 2,0/4,0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) lìþTCH GAS ING GAS ) METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-S) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY AZIMUTH VERTICAL DEPTH CONDITION REASON FOOTAGE HOURS T/B/C PULLED 7680' 68,68 HIGH LOW AVERAGE CURRENT AVG 94.7 @ 10773 94,7 @ 10773 0 94,7 ftIhr 0 @ 10773 0 @ 10773 0 0,0 amps 12 @ 10773 12 @ 10773 0 12.4 Klbs 94 @ 10773 94 @ 10773 0 94 RPM 2924 @ 10773 2924 @ 10773 0 2924 psi DEPTH: 10728 44 PV 17 YP 14 FL Gels 4/6/9 CL- 500 6,8 SD 0.35 OIL MBL 13,0 pH 10,00 Ca+ 40 CCI ) DAILY WELLSITE REPORT DEPTH 10773 YESTERDAY 10773 24 Hour Footage 0 DEPTH INCLINATION ) n EPOCH PRESENT OPERATION= Running Casing TRIP GAS= n/a WIPER GAS= 580u @ 10773' SURVEY= n/a CONNECTION GAS HIGH= n/a AVG= n/a CURRENT n/a CURRENT BACKGROUND/AVG Ou GAS DESCRIPTION SIN 24311 INTERVAL IN 3093' OUT 10773' DAILY ACTIVITY SUMMARY Circulated and condition mud, pull out of hole, go in with casing at report time. Epoch Personel On Board= 4 Daily Cost $ 2,540,00 Report by: Brady Kilmer ) JETS 3X13/3X14 VIS SOL HIGH LOW AVERAGE 54 @ 10773 54 @ 10773 0 0 @ 10773 0 @ 10773 0 CHROMA TOGRAPHY(ppm) 10229 @ 10773 10229 @ 10773 0 902 @ 10773 902 @ 10773 0 432 @ 10773 432 @ 10773 0 222 @ 10773 222 @ 10773 0 115 @ 10773 115 @ 10773 0 LITHOLOGY/REMARKS Phillips Alaska North Slope 2L-03 ') REPORT FOR Rick Levinson DATE Feb 19,2002 TIME 05:00:00 CASING INFORMATION SURVEY DATA BIT INFORMATION NO. SIZE 2 8.5" TYPE DS70FNPV DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM YP PRESSURE u¡{llllNG MUD REPORT MW 9,60 VIS SOL FC 2,0/4.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENT AN E(C-5) HYDROCARBON SHOWS INTERVAL ') DAILY WELLSITE REPORT ) I [Xl EPOCH LOGO DEPTH 10773 YESTERDAY 10773 PRESENT OPERA TION= laying down pipe 24 Hour Footage 0 DEPTH !NClINATION AZIMUTH VERTICAL DEPTH SIN 24311 INTERVAL IN 3093' CONDITION T IBIC REASON PULLED JETS 3X13/3X14 OUT 10773' FOOTAGE 7680' HOURS 68.68 HIGH LOW AVERAGE CURRENT AVG 94.7 @ 10773 94,7 @ 10773 0 94.7 fVhr 0 @ 10773 0 @ 10773 0 0,0 amps 12 @ 10773 12 @ 10773 0 12.4 Klbs 94 @ 10773 94 @ 10773 0 94 RPM 2924 @ 10773 2924 @ 10773 0 2924 psi DEPTH: 10728 44 PV 17 YP 14 FL Gels 4/6/9 Cl- 500 6,8 SD 0.35 Oil MBl 13.0 pH 10,00 Ca+ 40 CCI HIGH LOW AVERAGE 54 @ 10773 54 @ 10773 0 0 @ 10773 0 @ 10773 0 CHROMA TOGRAPHY(ppm) 10229 @ 10773 10229 @ 10773 0 902 @ 10773 902 @ 10773 0 432 @ 10773 432 @ 10773 0 222 @ 10773 222 @ 10773 0 115 @ 10773 115 @ 10773 0 LITHOLOGY IRE MARKS TRIP GAS= nla WIPER GAS= nla SURVEY= n/a CONNECTION GAS HIGH= nla A VG= n/a CURRENT nla CURRENT BACKGROUNDIAVG Ou GAS DESCRIPTION LITHOLOGY 1SENT LITHOLOGY ILJÁIL Y ACTIVITY SUMMARY Cement casing and laid down pipe. Epoch Personel On Board= 4 Daily Cost $ 2,540.00 Report by: Brady Kilmer Phillips Alaska North Slope ) DAILY WELLSITE REPORT ) I R EPOCH LOGO 2L-03 ) REPORT FOR Rick Levinson . DATE Feb 20, 2002 TIME 05:00:00 DEPTH 10773 YESTERDAY 10773 PRESENT OPERATION= Picking Up 4" Drill pipe 24 Hour Footage 0 CASING INFORMATION 7" @ 10753.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T IBIC PULLED 2 8.5" DS70FNPV 24311 3X 13/3X14 3093' 10773' 7680' 68.68 4 6.125" 18946 4x13 10773' FC 2.0/4.0 HIGH LOW AVERAGE CURRENT AVG 94.7 @ 10773 94.7 @ 10773 0 94,7 fVhr 0 @ 10773 0 @ 10773 0 0.0 amps 12 @ 10773 12 @ 10773 0 12.4 Klbs 94 @ 10773 94 @ 10773 0 94 RPM 2924 @ 10773 2924 @ 10773 0 2924 psi DEPTH: 10728 VIS 49 PV 23 YP 19 FL Gels 5/6/6 CL- 500 SOL 9,8 SO 0.35 OIL MBL 15.0 pH 9,10 Ca+ 40 CCI DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM ""'iMP PRESSURE JILLlNG MUD REPORT MW 10.70 MWD SUMMARY INTERVAL TO TOOLS HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 54 @ 10773 54 @ 10773 0 0 @ 10773 0 @ 10773 0 CHROMATOGRAPHY(ppm) 10229 @ 10773 10229 @ 10773 0 902 @ 10773 902 @ 10773 0 432 @ 10773 432 @ 10773 0 222 @ 10773 222 @ 10773 0 115 @ 10773 115 @ 10773 0 LITHOLOGY IREMARKS TRIP GAS= n/a WIPER GAS= n/a SURVEY= n/a CONNECTION GAS HIGH= nla AVG= n/a CURRENT n/a CURRENTBACKGROUND~VGOu GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) GAS DESCRIPTION LITHOLOGY °RESENT LITHOLOGY I ,.lILY ACTIVITY SUMMARY Picked up 4" casing to 10521 began drilling cement. Epoch Personel On Board= 4 Daily Cost $ 2,540.00 Report by: Brady Kilmer Phillips Alaska North Slope 2L-03 , REPORT FOR Rick Levinson )DATE Feb 21,2002 TIME 05:00:00 CASING INFORMATION 7"@ 10753' SURVEY DATA BIT INFORMATION NO. SIZE 4" 8.5" TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.70 FC 2,0/4.0 MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(unlts) }H GAS \jOTTING GAS METHANE(C-1 ) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ) DAILY WELLSITE REPORT . " g EPOCH DEPTH 11117 YESTERDAY 10773 24 Hour Footage 344 PRESENT OPERATION= Trying to circ with losses DEPTH 11054,04 INCLINATION 64.32 AZIMUTH VERTICAL DEPTH 6261.43 VIS SOL INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 18946 4x13 10773' HIGH LOW AVERAGE CURRENT AVG 224.4 @ 10774 12.2 @ 10851 58.4 31,9 ftlh r 0 @ 11117 0 @ 11117 0,0 0.0 amps 19 @ 10980 0 @ 11030 7,3 8.0 Klbs 94 @ 10773 32 @ 10774 74,8 78 RPM 3076 @ 10958 1807 @ 10806 2701.4 2779 psi DEPTH: 10773 49 PV 23 YP 19 FL Gels 5/6/6 CL- 500 9,8 SD 0,35 OIL MBL 15,0 pH 9,10 Ca+ 40 CCI HIGH LOW AVERAGE 330 @ 11032 8 @ 10987 59,3 0 @ 11117 0 @ 11117 0,0 CHROMA TOGRAPHY(ppm) 73939 @ 11032 1507 @ 10801 12314,2 5568 @ 11032 87 @ 10801 783,0 1929 @ 11032 32 @ 10801 272,1 556 @ 11032 15 @ 10987 90,8 144 @ 11032 1 @ 10971 19,8 LITHOLOGY/REMARKS TRIP GAS= Ou @ 10773' WIPER GAS= n/a SURVEY= n/a CONNECTION GAS HIGH= 210u @ 10931' AVG= 20u CURRENT 19u CURRENT BACKGROUND/AVG 75u GAS DESCRIPTION LITHOLOGY RS20SN60SS20 PRESENT LITHOLOGY Carbonaceous Shale 20%, Sand 60%, Sandstone 20% DAILY ACTIVITY SUMMARY Finished picking up 4", tested casing, drilled out cement and new formation, did FIT, Began drilling, drilled to 11171' and lost returns, Epoch Personel On Board= 5 Daily Cost $ 2,540.00 Report by: Brady Kilmer ) PHILLIPS ALASKA North Slope 2L-03 . REPORT FOR Rick Levinson ) DATE Feb 22, 2002 TIME 06:00:00 CASING INFORMATION 7" @ 10753' SURVEY DATA BIT INFORMATION NO, SIZE 4 6,125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11.4 FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) '""TCH GAS );ING GAS ,.I METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ) DAILY WELLSITE REPORT ) [:I EPOCH DEPTH 11198 YESTERDAY 11118 PRESENT OPERATION= Attempt to restore circulation 24 Hour Footage 80 DEPTH VERTICAL DEPTH INCLINATION AZIMUTH TYPE INTERVAL SIN JETS IN 18946 4x13 10773' HIGH 100,9 @ 11155 0 @ 11198 8 @ 11172 82 @ 11128 2969 @ 11188 VIS 45 PV SOL SO CONDITION T/B/C REASON PULLED OUT FOOTAGE 425 HOURS LOW AVERAGE CURRENT AVG 16,0 @ 11198 52.4 16,0 0 @ 11198 0,0 0,0 0 @ 11179 4,6 0.4 23 @ 11172 77,0 24 567 @ 11198 2728,1 567 DEPTH: 11198' YP FL Gels CL- OIL MBL pH Ca+ fVhr amps Klbs RPM psi CCI HIGH LOW AVERAGE 104 @ 11155 3 @ 11132 44,9 0 @ 0 0 @ 0 0 CH ROMA TOGRAPHY(ppm) 24498 @ 11198 861 @ 11132 10197.7 1447 @ 11155 52 @ 11132 619.6 556 @ 11155 21 @ 11132 239,9 178 @ 11155 7 @ 111 32 79,6 49 @ 11155 2 @ 11133 22,6 See Log LITHOLOGY/REMARKS TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 A VG= 0 CURRENT 0 CURRENT BACKGROUND/AVG n/a GAS DESCRIPTION LITHOLOGY Kuparuk Sand PRESENT LITHOLOGY Sand 60%, Sandstone 10%, Calcareous Sand 10%, Shale 20% DAILY ACTIVITY SUMMARY Drill to 11197', lost returns, pump LCM, Circulate/monitor mud losses - spot LCM pill, circulate, Epoch Personel On Board= 4 Daily Cost 2540 Report by: Bob Nichol ,) PHilLIPS ALASKA North Slope 2L-03 " REPORT FOR Rick Levinson ) DATE Feb 23,2002 TIME 06:00:00 CASING INFORMATION 7" @ 10753 SURVEY DATA BIT INFORMATION NO, SIZE 4 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 11,6 FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) '"'ITCH GAS }nNG GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 'J DAILY WELLSITE REPORT ) [:I EPOCH PRESENT OPERATION= Circulate prep to POOH DEPTH 11316 YESTERDAY 11199 24 Hour Footage 117 DEPTH INCLINATION AZIMUTH TYPE INTERVAL SIN JETS IN OUT FOOTAGE HOURS 18946 4X13 10773 11316 543 HIGH LOW AVERAGE 75,0 @ 11256 9,2 @ 11230 43.4 0 @ 11316 0 @ 11316 0,0 13 @ 11220 0 @ 11230 3.4 54 @ 11221 22 @ 11220 52,8 2356 @ 11226 779 @ 11199 2139,2 DEPTH: 11316 VIS 41 PV YP FL SOL SD OIL MBL VERTICAL DEPTH CONDITION T/B/C REASON PULLED CURRENT AVG 31,3 0,0 4,6 54 2071 fUhr amps Klbs RPM psi Gels pH CL- Ca+ CCI HIGH LOW AVERAGE 38 @ 11246 10 @ 11199 24,9 TRIP GAS= 0 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMA TOGRAPHY(ppm) SURVEY= 0 12595 @ 11247 3674 @ 111 99 8119,3 CONNECTION GAS HIGH= 0 842 @ 11246 171 @ 11199 539,0 AVG= 0 366 @ 11246 52 @ 11199 238,0 CURRENT 0 123 @ 11246 15 @ 11199 80,9 CURRENT BACKGROUND/AVG N/A 47 @ 11246 6 @ 11200 27.8 See log LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Miluveach PRESENT LITHOLOGY Calcareous Sand 10%, Claystone 20%, Sand 10%, Shale 60% DAILY ACTIVITY SUMMARY Drill to TD, Stabilize hole, prepare to POOH & Run liner Epoch Personel On Board= 4 Daily Cost 2540 Report by: Bob Nichol )~ PHILLIPS ALASKA North Slope 2L-03 , REPORT FOR Rich Levinson ì ) DATE Feb 24,2002 TIME 06:00:00 CASING INFORMATION 7" @ 10753' SURVEY DATA BIT INFORMATION NO, SIZE 4 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) ,",ITCH GAS )~~ING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ) DAILY WELLSITE REPORT ) [:I EPOCH DEPTH 11316 YESTERDAY 11316 PRESENT OPERATION= Run into hole w/ liner 24 Hour Footage 0 TYPE VERTICAL DEPTH INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4X13 10773 11316 543 HIGH LOW AVERAGE CURRENT AVG 31,3 @ 11316 31,3 @ 11316 0 0 0 @ 11316 0 @ 11316 0 0 4 @ 11316 4 @ 11316 0 0 54 @ 11316 54 @ 11316 0 0 2071 @ 11316 2071 @ 11316 0 0 DEPTH: unavailable PV YP FL Gels CL- SD OIL MBL pH Ca+ DEPTH INCLINATION AZIMUTH SIN 18947 ft/hr amps Klbs RPM psi VIS SOL CCI HIGH LOW AVERAGE 21 @ 11316 21 @ 11316 0 TRIP GAS= 0 0 @ 0 0 @ 0 0 WIPER GAS= 799u CHROMA TOGRAPHY(ppm) SURVEY= 0 5528 @ 11316 5528 @ 11316 0 CONNECTION GAS HIGH= 0 417 @ 11316 417 @ 11316 0 AVG= 0 213 @ 11316 213 @ 11316 0 CURRENT 0 79 @ 11316 79 @ 11316 0 CURRENT BACKGROUND/AVG n/a 28 @ 11316 28 @ 11316 0 See Log LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Miluveach PRESENT LITHOLOGY Calcareous Sand 10%, Claystone 20%, Sand 10%, Shale 60% DAILY ACTIVITY SUMMARY CirclCondx mud - Back Ream to 10753' - Circ btms up, pump dry job - POOH - RIH w/ liner Epoch Personal On Board= 3 Daily Cost 2540 Report by: Bob Nichol ) PHilLIPS ALASKA North Slope Serac 2L-Ö3 REPORT FOR Rick Levinson ) DATE Feb 25,2002 TIME 06:00:00 CASING INFORMATION 7"@ 10753' SURVEY DATA BIT INFORMATION NO, SIZE TYPE DRilLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRilLING MUD REPORT MW FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS ""YING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL ') DAILY WELLSITE REPORT DEPTH 11316 YESTERDAY 11316 24 Hour Footage 0 DEPTH iNCLINATION SIN INTERVAL JETS IN OUT FOOTAGE HIGH LOW 31.3 @ 11316 31.3 @ 11316 0 @ 11316 0 @ 11316 4 @ 11316 4 @ 11316 54 @ 11316 54 @ 11316 2071 @ 11316 2071 @ 11316 DEPTH: PV YP SD OIL VIS SOL HIGH lOW AVERAGE 21 @ 11316 21 @ 11316 0 0 @ 0 0 @ 0 0 CHROMA TOGRAPHY(ppm) 5528 @ 11316 5528 @ 11316 0 417 @ 11316 417 @ 11316 0 213 @ 11316 213 @ 11316 0 79 @ 11316 79 @ 11316 0 28 @ 11316 28 @ 11316 0 See Log LITHOLOGY/REMARKS LITHOLOGY Miluveach PRESENT LITHOLOGY Calcareous Sand 10%, Claystone 20%, Sand 10%, Shale 60%. DAILY ACTIVITY SUMMARY Lay down BHA - Run Liner, Circulate - Cement Liner - POOH Epoch Personel On Board= 3 Daily Cost 2460 Report by: Bob Nichol ) ) [:I EPOCH PRESENT OPERATION= POOH AZIMUTH VERTICAL DEPTH CONDITION REASON HOURS T/B/C PULLED AVERAGE CURRENT AVG 0 0 ftlh r 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi FL Gels CL- MBl pH Ca+ CCI TRIP GAS= 500u WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION PHILLIPS ALASKA North Slope Serac 2L-03 ) REPORT FOR Rick Levinson . DATE Feb 26,2002 TIME 06:00:00 CASING INFORMATION 7" @ 10753' SURVEY DATA BIT INFORMATION NO, SIZE TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS )TTING GAS METHANE(C-1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL VIS SOL ) DAILY WELLSITE REPORT ) [:I EPOCH DEPTH 11316 YESTERDAY 11316 24 HoUr Footage 0 PRESENT OPERATION= Test Production Assembly DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SIN INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED HIGH LOW AVERAGE CURRENT AVG 31,3 @ 11316 31,3 @ 11316 0 0 fVhr 0 @ 11316 0 @ 11316 0 0 amps 4 @ 11316 4 @ 11316 0 0 Klbs 54 @ 11316 54 @ 11316 0 0 RPM 2071 @ 11316 2071 @ 11316 0 0 psi DEPTH: PV YP FL Gels CL- SO OIL MBL pH Ca+ CCI HIGH LOW AVERAGE 21 @ 11316 21 @ 11316 0 TRIP GAS= 0 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMA TOGRAPHY(ppm) SURVEY= 0 5528 @ 11316 5528 @ 11316 0 CONNECTION GAS HIGH= 0 417 @ 11316 417 @ 11316 0 AVG= 0 213 @ 11316 213 @ 11316 0 CURRENT 0 79 @ 11316 79 @ 11316 0 CURRENT BACKGROUND/AVG N/A 28 @ 11316 28 @ 11316 0 See Log LITHOLOGY IREMARKS GAS DESCRIPTION LITHOLOGY Miluveach PRESENT LITHOLOGY Calcareous Sand 10%, Claystone 20%, Sand 10%, Shale 60%, DAILY ACTIVITY SUMMARY Rev circ - UD Cmt head & XOs - UD 4" DP/3,5" HWDP - Run 3.5" Single Prod Assembly - Test @ 10515' Epoch Personel On Board= 4 Daily Cost 2570 Report by: Bob Nichol ) ~~~~E ) : F !Æ~l~~~~ ) ALASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini ExploratiölfDtillihg TeamLeader . Phillips Alaska, Inc. P.O. Box 100360 . Anchorage, Alaska 99510-0360 Re: Kuparok River Unit 2L-03 Phillips Alaska, Inc. Permit No: 201-239 Sur Loc: 143' FNL, 544' FEL, SEC. 22, TlON, R07E, UM Btmhole Loc: 1777' FSL, 757' FEL, SEC. 11, TI0N, R07E, UM Dear Mr. Mazzolini: 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 of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 2L Pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. A mud log and samples are required from base of the conductor to TD. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Diverter and blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of the diverter or BOPE 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, (UA>.~^/()u£Vj.: ~ C;~~.dèchsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 18th day of December, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ PHILLI~~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: pmazzol@ppco.com December 4, 2001 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Producer 2L-03 Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well, KRU #2L-03. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Mark Chambers at 265-1319. Sincerely, ?o.J. yr¡~ Paul Mazzolini Exploration Drilling Team Leader RECEIVED DEC 0 4 2001 Alaska 0;1 & Gas Cons. Comrrission Anchorage 01 C.' j~JA.. 9. Approximate spud date Amount January 15, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11404' MD /6429' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3131 psig At total depth (TVD) 3820 psig Setting Depth ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill b!J Aedrill U Ae-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 143' FNL, 544' FEL, Sec. 22, T10N, R07E, UM At top of productive Interval 1530' FSL, 931' FEL, Sec. 11, T10N, R07E, UM At total depth 1777' FSL, 757' FEL, Sec. 11, T10N, R07E, UM 12. Distance to nearest property line 13. Distance to nearest well 1530' @ Target 2L-305 29' @ 325' 16. To be completed for deviated wells 'Kickoff depth: 300' MD 18. Casing program size 1b. Type of well. ExploratoryU Stratigraphic Test U Service 0 Development Gas 0 Single Zone 9 it> 5. Datum elevation (OF or KB) RKB = 35 feet AMSL 6. Pr9~erty Designation .3ED°..fó[ 3'8'0049 t~LK 4597 7. Unit or property Name Kuparuk River Unit 8. Well number 2L-03 feet Maximum hole angle 61° JMH-- r1'l ì<tl 61 t-\t-II ") Development Oil b!J Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Length 80' 3089' 10882' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 35' 35' 115' 115' 9 cu yds High Early ¡ 35' \ 35' 3124' 2437' 490 sx AS Lite & 270 sx LiteCRETE ! 35' 35' 1 0917' 6194' 170 sx Class G t 10767' 6121' 11404' 6429' 170 sx Class G w/GasBLOK Hole Casing Weight 24" 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# 6.125" 3.5" 9.3# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTC L-80 SLHT 637' 19. To be completed for Aedrill, Ae-entry, and Deepen Operations. Present well condition summary Total Depth: Plugs (measured) measured true vertical feet feet Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth RECEIVED Perforation depth: measured DEC 0 4 2001 true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DAefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Chambers 265-131 ~ Signed '~ptt... M~az«"'zQOII'nl' YVI~ ~Aß:..". I ¡'Jv/o+)o I rC. , r '''''1 r-- - Title: Exploration Driffing Team Leader Date PreD::1red bv Sharon AlIsuD-nr::1k~ : \ . Î \j I See cover letter '(1"- 0 ó I for other requirements ¡ I Ei1 Yes 0 No ø Yes 0 No ~~ flI. 3 <; ~D ~~ \ ~,-rZ\ 1'^. '<) Y\. \y:::/'? ~ P;S~ 5C)dC)~\ ~CÇ~\~\.\'~\ ~~~+ IJ'IF!()/ Commission Use Onl} Permit Number. . q I API number ~7QI('~:) I Approval date :201,- 2-3 I 50- 1{)!3-- ?-C:510-CC) Conditions Df approval Samples required [jJ Yes ~ No Mud log required Hydrogen sulfide measures IRJ Yes 0 No Directional survey required AequiredworklngpressureforBOPE D2M; 0 3M; 0 5M; 0 10M;D Other: Approved by Original Signed By Cam,uy OechslJ by order of the commission Form 10-401 Rev. 12/1/85' OH/~J~ . Date Submit in triplicate ) ") Permit It - Kuparuk Well 2L-03 Application for Permit to Drill Document MoximizE Well ValUE; Table of Contents 1. Well Name....................................... .......................................................................... 2 Requirements of 20 AAC 25.005 (f)........ .................. ...... ..... ....... ........ ......................... ............ ...... .........2 2. Location Sum mary .................................. ................................................................. 2 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b).... ....... ....... ......... ............ ....................... ........ ..................... .............2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ........................................................................;......................... 3 6. Casing and Cementi ng Program .... ............ .... .......... ............... ........ .............. .... ......4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) .......... ....... .............. ............................ ......... ..... ....... ............ .......4 8. Dri II i ng FI u id Program.............................................................................................. 4 Requirements of 20 AAC 25. 005( c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 1 O. Seismic Analysis........ .............................................................................................. 6 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) '.".."'."""".'......'''.....''..''.'''.'''''''.''.........................................6 12. Evidence of Bond i ng ......................................... ......................... ............................. 6 Requirements of 20 AAC 25.005 (c)(12) ....... .... .......... ......... ............. ........ ................ .......... ... ................ 6 13. Proposed Dri II i ng Program...................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .. ............. ........ .............................. ................. ....... ................... 6 0 ~ ':1'\ '~'A lì\"t.~IJ . 2L-03 PERMIT IT. DOC Page 1 of 6 Printed: 1-Dec-01 ) ) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ......................... ............. ........ .... ........ ...... .................... ............ 7 15. Attachments............................................................................................................. 8 Attachment 1 Directional Plan' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 8 Attachment 2 BOP Schematic' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 8 Attachment 3 Drilling Hazards' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 8 Attachment 4 Diverter Schematic' , , , , , , , , , , , , , , , , , , , , , , , , , , , , ..8 Attachment 5 Mud System' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ..8 Attachment 6 Well Schematic' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , .8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by tfle operator and a unique API number B£,,1gned by the commission under 20 AAC 2S,040(Ö). For a well with multiple well branches~ each branch must sirnilarly be identified Öy a unique name and APT rlumÖer by adding a sulTix to the name designated fvr the well by ttle operatvr and tv the number as~s~qned tv tfle well by the wmmissiofl. The well for which this application is submitted will be designated as 2L-03. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill mUf/t be ¿:¡Œompanied by ead7 of'the following item:..~ excé:.pt for an item already 0/7 {¡Ie with the commis..r:;ion and Identified in the application: (2) a plat identifying the property and the propelty's owner:.:; and showing (A)the coordinates of the propos"ed location of ti7e well at the sì.Jrfacc, at the top of each ofìjective torrnationt and at total depth refr;renced to governmental s-ection lines. (8) the coordinates of the proposed location of the well at the surt.;¡ce, referenced tv the statr; plane coordinate system fvr tt7is' state as mainlained bV the National Geodetic 5ùrvey in the National Oæanic and Atmo,Spheric Admin/s'tratio/7,' (C) tile proposed depth of the well at the top of" each objective fo/matio/7 and at total (k:ptfJ; Location at Surface 1143' FNL, 544' FEL, See 22, Tl0N, R07E, UM NGS Coordinates RKB Elevation Northings: 5,927,702 Eastings: 461,107 Pad Elevation 35' AMSL 117' AMSL Location at Top of Productive Interval (Kuparuk "C4" Sand) NGS Coordinates Northings: 5,934,630 1530' FSL, 931' FEL, See 11, Tl0N, R07E, UM Eastings: 466,025 Measured Depth RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: 11059' 6262' 6110' Location at Total Depth NGS Coordinates Northings: 5,934,877 Eastings: 466,200 1777' FSL, 757' FEL, See 11, Tl0N, R07E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: 11404' 6428' 6276' And (D) other information required by 20 MC 25:0S0(b); Requirements of 20 AAC 25.050(b) If a well ifj to be If¡tentionally dev/~'1te{f, the app/ìcation for a Permit to Drill (Form 10-401) must OR Gl~A- 2L-03 PERMIT IT. DOC Page 2 of 6 Printed: 1-Dec-0 1 ') ) (1) include a pla(: drawn to a suitable seale/ ,s-!lowing tile path or the propœ-.;ë:?d wellbo('f.;'t includtilg all a(jþJCent well bores wil.hin 200 fef.?t or a/7 y portJÒf7 o( the proposed well/ Please see Attachment 1: Directional Plan And (.2) (or all well.'i Wlt.tïtfì 200 leet ol the proposed wellbore (A) list the names o( the operators of t/70S-e well.~ to the extent that thosC3 names are known or discoverable lil pub/¡(: records, and show that each named operator has been furnished a copy of tile application by cettil7edmal!; or (8) state tilat the applicant is the only affeäed owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An applicatlÒ!7 ('Or a Permit tv Drill must be accompanied by each of the fÒllowing item~~ except (or an item already on file with the commis..sion and identitìed in the application: (J) a diagram and de5"(:ription of the blowout prevention equipment (BOPE) as required by 20 AAC 25, 035~ 20 AAC 25~ 036~ or 20 AAC25.037; as applìc"able; Please see Attachment 2 - BOP Schematic for Nabors 18E. 4. Drillina Hazards Information Requirements of 20 MC 25.005 (c)(4) An application for a Pem7Ít to Drill mllst be àŒompanied by each of'the fòllowing item!;.~ except fòr an item already on fì/e wIth the (:vmmissio" and identlfiéd 117 the appliœtion: (4) li7farmation 0/7 dn/ling !7azani~ J/7c1uding (A) th(;; rnaximu1i7 downhole pressure that may be encountered, aite/ia llsed to determine it, and maximum potentia! swface pres..'iure based on a methane gradient/ Based on offset well data, the expected reservoir pressure in the Kuparuk C-Sand for the 2L-03 well is "'3800 psi at 6262/ tvd, 0.61 psi/ft or 11.7 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 2L -03 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the Kuparuk C-Sand Target at 6262/ tvd: MPSP =(6262 ft)*(0.61 - 0.11 psi/ft) = 3131 psi (8) data on potential gas zonð~' The well bore is not expected to penetrate any gas zones. And (C) data conceming potential causes of hole problems suet} as abnormally geo-pres:.c:;ured strata/ lost ckculation ZO!7es~ and zones that have a propensity for differential sticking/' Please see Attachment 3 - DrHling Hazards Summary 5. Procedure for Conductina Formation Intearitv Tests Requirements of 20 MC 25.005 (c)(5) An application tòr a PermIt to Dn/I must be accompanied by eaL"Ý7 ot" tl7e following Items, except (or an Item already on tile with the commission and identified in the application: (5) a description of the procedure for conducäng formation integrity test~ as required under 20 MC 25. OJO(f)/' Drill out surface and intermediate casing shoe and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. O.'~'~A . I \Ä . rf .. 2L-03 PERMIT IT. DOC Page 3 of 6 Printed: 1-Dec-O 1 ) ') 6. Casing and Cementing ProQram Requirements of 20 AAC 25.005(c)(6) An application (or a Pelmit to Dlill must be accompanied by each or the (ollowing item.s~ except fvr an item a/ready on l7Ie with the commission and Identitiéd in the application: (6) a complete proposed c:a5ing and cementing program as required by 20 AAC 25:030, and a desCliption a/any slotted linet"¡ pre- perforated linet"¡ or screen to be Installed; Casing and Cementing Program Hole Top 8tm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (In) (In) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 80' 35'/35' 115'/115' 260 sx 15.8 ppg ASl 9-5/8 12-1/4 40.0 L-80 BTC 3089' 35'/35' 3124'/2437' Lead: 490 sx 10.7 ppg AS Lite Tail: 270 sx 12.0 ppg LiteCRETE Planned TOC=Surface 7 8-1/2 26.0 L-80 BTC 10882' 35'/35' 10917'/6194' 170 sx 15.8 ppg 'G' w/ add. Planned TOC=10,117' 3-1/2 6-1/8 9.3 L-80 SLHT 637' 10767'/ 11404'/6429' 170 sx 15.8 ppg 6121' GASBLOK w / add. Planned TOC=10,767' 3-1/2 9.3 L-80 EUE 8rd 10732' 35'/35' 10767'/6121' Tubing Mod 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application f'Or a Permit' to Dnll must be accompanied by each of the (0110 wing Jtem5~ except (or an item already on file with tfle commis..s'ÍCJf1 and Identified in the application: (1) a diagram and desaiption of ti7e dlverter system as required by 20 AAC 25, 03~ unless this reqUlI"{;~ment Is waived by the CO/TIITli5'5iol7 under 20 AAC 25, 035(17)(2); Please see Attachment 4 - Diverter Schematic for Nabors 18E. 8. Drilling Fluid Program Requirements of 20 MC 25.005(c)(B) An application for a Permit to Dr7l1 must be accompanied by each of'the following Item5¡ except for an item already on file with the comml<islon and Identifìed in the application: (8) a drilling fluid program, 1i7c1uding a d;~Jgram and deSï.7iption of the drilltl7g flllld system, as required by 20 AAC 25:033/ Drilling will be done using mud systems having the following properties: OR Gl^A. 2L-03 PERMIT IT. DOC Page 4 of 6 Printed: 1-Dec-01 ) ) Surface Hole: Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 9.6 9.6* 9.6* Funnel ViscosIty 100-150 100-150 100 75 (seconds) Yield Point 25-45 25-45 20- 30 18-30 (cP) Plastic Viscostiy 8-15 11- 22 15-25 15-25 (lb/l00 sf) 10 second Gel 10- 30 10-25 10-25 10-25 Strength (lb/l00 sf) 10 minute Gel 25-55 25-55 20-40 20-40 Strength (lb/l00 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 8-15 6 <6 <6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Intermediate Hole: Initial Value Final Value Density (ppg) 9.3 9.6 Funnel Viscosity 40-55 40-55 (seconds) Yield Point 5-8 20-27 (cP) Plastic Viscostiy 6-13 11-19 (Ib/l 00 sf) 10 second gel 3-7 4-7 10 minute gel 6-13 pH 9-10 8-9 API filtrate <6 <6 HTHP filtrate NC <10 Solids % 4-10 6-11 Production Hole: Initial Value Anal Value Density (ppg) 12.2 12.2 Funnel Viscosity 50-65 50-65 (seconds) Yield Point 25-35 25- 35 (cP) Plastic Viscostiy 25- 35 25- 35 (Ib/l 00 sf) 10 second gel 9-14 9-14 10 minute gel 16-26 16-26 pH 9-10 8-9 API filtrate <6 <6 HTHP filtrate <10 <10 Solids % 16-22 16- 22 Please see Attachment 5 - Mud System for Nabors 18E. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Of GI~ A- 2L-03 PERMIT IT. DOC Page 5 of 6 Printed: 1-Dec-01 ) ') 9. Abnormally Pressured Formation Information Requirements of 20 MC 25.005 (c)(9) An application f'or a PermIt to Dnl/ must be accompanied by each of'the fbI/owing itern'i¡ except fÒr an item already on fHe with the commission and identified 117 t/70 application: (9) for an exploratory or stratigmphic test well, a tabulation setting out the depths of predicted abnormally geopresslJred strata a8 required by 20 AAC 25: 033(0; N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicatkJn fòr a Permit to Dnll must be accompanied by each of the following item~ except for an item already on file with the commis.sion and identitìed in the application: (10) for an exploratory or.s"iraligraphic te.ST well, a seignic refraction or reflection analysis as required by 20 AAC25~06.1(a); N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005 (c)(ll) An application f'or a PermIt to Dnll mU:"7: be accompanied by each of'the following Item5~ except for an item already on file with tile commi53ion and identified in the application: (11) for a well drilled from an offshore platform, mobile bottofi7..fÒunded structure, jack.up rig, or floating drill1i7g vessel, an analysir; of ~"eabed condItions as required by 20 AAC 25.061(b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005 (c)(12) An applk:ation for a Permit to Drill must be accompanied by each of the fiJllowing Items, except for an item already 0/7 file with the commf':;'siol7 and identified Ii? the application: (12) evidence showing that the requirements of20 AAC 25:025" {Bonding}have been met/ Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed DrillinQ Program Requirements of 20 MC 25.005 (c)(13) An applk-aiion tÖr a Permit to Dlill must be accompanied by each or the following items~ except for an item already on tlIe with the commission and idenUf1ed Ji"} the application: The proposed drilling program is listed below. Also, Please refer to Attachment 6, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 115' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 18E. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/ 3124 MD') as per attached directional plan. Run MWD / LWD loggin9 tools in drill strin,Q. as required for directional monitoring and formation data gathering. 4 ~/ /êE.5/~/JD (ðf'-h~d/ ) .J$ 4. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job or stage job if needed. Note: 9 5/8" port collar to be installed at +/- 1000 MD'. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. OR! G/^'A- 2L-03 PERMIT IT. DOC Page 6 of 6 Printed: 1-Dec-01 ") ) 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 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). 8. Directionally drill 8-1/2" hole to 10,917' MD as per attached directional plan (Well is currently planned as a Top Set above the Kuparuk formation). Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Circulate al'1d condition hole. POOH 4Æ:./ 1Ct!'~ / Pld b 9. Run 7" 26.0# L-80 BTCM casing and cement. ,)1> Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 MC 25.030 10. Nipple up BOPE and test to 5000 psi. Record results. 11. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 12. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 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). 13. Drill 6-1/8" hole to well total depth (+/- 11,404' MD) as per attached directional plan. Run MWD / LWD logging tools in drill string as required ~r di;'7ë°nal;nonito~1l9 and formation data gathering. Circulate and condition hole. POOH (!>K/A3f:.:y .Dz5<J/AJI?t'¿/IZu'þ )1 . L , 9.P-~A ~k I~:h 14. Run open hole e-line or drill pipe conveyed logs as needed. (N~ ¡>fð.".hJ1&,J . 15. Run and cement 3-1/2" 9.3# L-80 SLHT liner and Baker ZXP hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 16. Run and land 3-1/2" completion tubing string. 17. 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. 18. Freeze protect well with diesel. Set BPV. Release rig and turn well over to production. 19. 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 Pelmit to Drill mu~tc be accompanied by each of tfle Ibllowing items~ except tor an item a/ready on file with the commission and identlfìed in tile application: (14) a general desaiption of how the operator plans to dispose ot'drilling mud and cutbi7gS" and a statement of whether the operator intends to request authorization under 20 AAC 25, 080 for an annular disposal operr.":¡tion i/7 the well./' Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2L pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 2L pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2L-03 for annular pumping of fluids occurring as a result of future drilling operations on 2L pad. OR G NA- 2L-03 PERMIT IT. DOC Page 7 of 6 Printed: 1-Dec-0 1 ) 15. Attachments Attachment 1 Directional Plan Attachment 2 BOP Schematic Attachment 3 Drilling Hazards Summary Attachment 4 Diverter Schematic Attachment 5 Mud System Attachment 6 Well Schematic 0: G VA. ) 2L-03 PERMIT IT. DOC Page 8 of 6 Printed: 1-Dec-01 -6 ~ ~ ~ 3" Choke Line ~ ~ [ ~ ~ )-5/8" 5000 psi BOP S~tk Nabors Rig 18e c:L 4 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid, 2, Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3, Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report, The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure, ~ 3 þ þ 2" Kill Line 2 Man Hyd ~ BOP Stack Test 1, Fill BOP stack and manifold with water. 2, Check that all hold-down screws are fully retracted, Predetermine L, depth that test plug will seat and seat in wellhead. Run in lock-down I screws in head, ~ 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5, Open annular preventer and manual kill and choke line valves, 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes, Continue testing all valves, lines, and chokes with a 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8, Open top pipe rams and close bottom pipe rams, Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 7 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1 r 1. 13-5/8" 5000 psi SGL Gate (pipe rams) 2. 24" Cameron Drilling Spool wI 13-5/8" 5000 psi Flanged Connections and 4" 5000 psi Flanged Side Outlets with Choke and Kill Lines, 2 Choke valves One 4" 5000 psi Cameron type FC HCR Hydraulic Gate One 4" 5000 psi Cameron type F Manual Gate 2 Kill valves One 3" 5000 psi Cameron type FC HCR Hydraulic Gate One 3" 5000 psi Cameron type F Manual Gate 3. 13-5/8" 5000 psi DBL Gate (pipe rams on top, blind on bottom) 4, 13-5/8" 5000 psi Hydril Annular Preventer D':, GNA~ MAC Rev 12/01/01 ) .. ) 2L-03 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Event I Risk Level I Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Drilltreat. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gravel/Sand Sloughing Low Increase mud weight / viscosity, High density sweeps. Hole Swabbing on Trips Moderate Slow trip speed, Proper hole fill (use of trip sheets), Pumping out of hole. Abnormal Reservoir Pressure Low Diverter drills, Increased mud weight. Lost Circulation Low Reduced pump rates, Mud rheology, LCM 8-1/2" Hole / 7" Casina Interval I Risk Level Moderate Event Shale stability in HRZ High ECD and swabbing if higher MW is required Hole cleaning in long, high angle tangent Shale stability across K-l interval Abnormal Reservoir Pressure Lost Circulation Moderate Moderate Moderate Moderate Moderate I Mitigation Strategy Control with higher MW and proper drilling practices. Pumping and rotating out on all trips to reduce swab and barite sag potential. Good drilling practices. Control with higher MW and proper drilling practices. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight. Reduced pump rates, Mud rheology, LCM 6-1/8" Hole / 3 1/2" Liner Interval I Risk Level I Mitigation Strategy Moderate Pumping and rotating out on all trips to reduce swab and barite sag potential. Good drilling practices. Event High ECD and swabbing if higher MW is required Hole cleaning in long, high angle tangent Shale stability across Miluveach Abnormal Reservoir Pressure Lost Circulation Moderate Moderate High Moderate Control with higher MW and proper drilling practices. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight. Reduced pump rates, Mud rheology, LCM 2L-03 Drilling Hazards Summary. doc prepared by Mark A. Chambers 12/03/01 0 i. GNA- Page 1 of 1 -1 ? [ ) ) 21-1/4" DIVERTER SCHEMATIC Nabors Drilling Rig 18e 5 L Open -----------~ I I ~--------... To Accumulator I I Closed ,'i'\ S ~--------- ¡ L.- t I I I I I I :: From : ~----- Accumulator I I I I I I Closed: : I I I I - I I .---"1 I [[ .----L-j ~ ... Open ~ 7~ Maintenance & Operation 4 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately ] 2. Close annular preventer/open the valve in the event that an influx of wellbore fluids or gas is detected. 3 J 2 1 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES .c-/ 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 21-1/4" 2000 psi Flanged Diverter Spool 5. 21-1/4" Hydril MSP 2000 psi Annular Preventer 6. 16" Hydraulically Actuated Knife Valve 7. 16" Diverter Line (Straight) 0 ~'GNA~ MAC, Rev. 12/01/01 ') ) . RIG 18-E MUD SYSTEM ITEM DESCRIPTION QUANTITY Main Mud Pumps Continental Emsco, FI000, 140 SPM, 3,010 maximum 2 psi with 6" liners, 514 gpm with 6'~' liners Annular Injection Pump K & T triplex, model 160, powered by a Toshiba 60 1 hp motor Pulsation Dampener Continental Emsco model PD-5-5000 lb, 7,500 psi 1 Strainers Discharge -Continental Emsco flanged, ~ischarge 2 assembly with 5" outlet Suction - 8" Mueller model 758 "Y" strainer 2 Shock Hose 3 1/2" x 8'6" grade D, S 5000 Goodall 1 Charge Pump Mission Magnum 6 x 5 x 11, driven by 60 hp motor 2" Cement Hose 2" x 21' FC273-32 Airquip hose with XXH weld stub 1 . ends. 5,000 psi working, 10,000 test Mix Pump Mission, Magnum 6 x 5 x 11, driven by 60 hp motor 2 Mud Cleaner Pump 'Gallagher 6 x 8, driven by 75 hp 575 V motor 1 ) Hole Fill Pump 'Mission, 1 7/8" pedestal powered by 1,755 rpm 1 Toshiba motor Shale Shaker Derrick model 58 2 Centrifuge Swaco, model 518, 200 gpm 1 Desilter Derrick model L48, sixteen 4" cones, 800 gpm 1 Desander . Brandt SR-l, two 12" cones rated for 1,000 gallons at 1 15 feet of head Mud Hopper Demco 6" figure 612B mud hoppers 2 Mud Degasser Pyramid Steel primary degasser 1 . Brandt DG-l 0 vacuum degasser, 5 hp, 1,000 gpm 1 O~'G,NA- ') ) Agitators Brandt powered by 5 hp Toshiba motor 2 . Pits ~ orking pits, 400 bbls capacity each 3 Trip tank, with monitor, 66 bbls 1 Pill pit, 50 bbls 1 Tanks Water storage, 1 71 bbls 1 Diesel storage, 156 bbls '. 1 Fuel tank, 500 bbls, double walled, skid mounted 1 Cuttip.gs Removal System Auger system 2 Cuttings Box (N one) 0 Bulk Mud Trailers Barite and gel 1 each . . OR'G NA~ STANDPIPE ~IFOLD CEMENT rI-1 ~-s0 STANDPIPE,! '! CHOKE ~IFOLD J - 5000~ ~.... . . I 1'1>----- ~~ -rÞ< ~ - e ~ ."RJÆ~ ~J~ ~L<Pî 2 L L .~D IR!. F\IXR -T ~ """,,,,,,,,,,,,,,r,,,,,,,,,,,,,,,,,,,, ;:TT7"T'TT'T'T ~ 7777 ^ . I ".... , r IQ£ R1. L!::::. I I '2" I«Ð - BOP STACK ~ 13-5/8" 5000# ---. ~ ~ . ." QØŒ ~ IVV'lI IrvvI~ ~----------------------~ ~.lEGEND I"'-"Ii ~ GATE V&VE . .. ""¡¡¡r- BUTTERFlY V&VE H,P. MUD PUMP #2 ~ CHECKV&VE ~<P ~ IW.1 V&VE () I ::: V&VE I . 12x6/ ur II COMPARTMENT CAPACllY CAPACITY BBlS 2" & COUPARTMENT Q) SUCTION TN« 200 ill IIUO TANK 175 ill WOO TN« 100 @ WUO TN« 100 @ WUO a.rAHER TANK 140 @ ŒGASSER TANK 140 ø PR.L TANK JO @ TRIP TNt< 75 @ HOlDING TANK JO ~~P.IWP9\18E.MUD_SCHEM,DWG.11/2810111:32:41 AM 12110 II 10.& 1r ~rO S~~~~ fR() atOIŒ IW8'OlD . 8x6 WATER TANK I 7\1 11r+,2. D:I ---11 I. r t 6. . r Crn:M~GE '" ~~~~r\~~_~ INJECTION PUMP I NJ r-u:::G' ,:..: ~ ~ ~4L1 I . vntV\ E PUMP ~ (AS REQ\HD) T L -+ -J/~/~/~ """ /'/' -QP~PSQ- 6" 6. !l8x6 2.8:1.6 " " . T T. 11 n- I I I I I . . ~ DEGASSER PUMP 6x5 \ I ------- ---I ~--a.VI I I tA\ @ 0 ill f1\ :) ~ .?1\h ~ \.Y ~/f-ri/~~/I I I 'f1 I 'f1 f lfJ r/~I MIxHOPPERs " MUD CLEANER 1 I 'Ã' I. I I 1\iE\ 0 0 I PUMP : ~ I.:;) [S] I . @ ~ 6x5 r4£~~.- '!Uf~: rID ~ ul~.T Øll~ ~ ø I. I I I I:) rn rn 11 I ~~ II : " 1\f-CjH/r-- I' --1\1EI' 7- t- œu - -I-;.~ rn: ~-~ ':rn- ~ WATER PUMP tA\ <\ 1 /' " - -{j) Jx2 ~ ~ ~ ~(!) (!) I I A @ -~_._--- L ~ \~/I 1 ill"'" 00 _o_~' ŒJ _ŒJŒJ- æ I~ PU~PS - I~ ~i0~ ~ TI/~-<H/I ~ @ I I I I ~ . @ .V8x6 I.' '-"' HOLE FILL PUMP CENTRIFUGE PUMP Jx2 7 M~ 11/~/H/H0-<H/' . T I'TJ-eJ-l/I ~.. ~ 4L1 I VM~ ..-V~ -"'+ I CENTRIFUGE. .. 4 ~ T ~-----_==:r-- / T/ ~ - TI/-.--------J -J/~ 58 I ", 1'1' I MUD CLEANER I I I I I T ~ SCREEN!IIÐERfl.OW «t I CUTTINGS .. CONVEYOR '-...-/ ~è~&ift~~~~Œ ... NøbotsNaslar =-a = DrII""'9 no. .... .---- Anchoroge. - 99503 907--561-#40 ~ RIG 1 BE MUD SYSTEM FLOWSHEET 11/28/01 C .u.. D.H. YOOIFIED BOP STACK IXItIFIGœA1IOH 5/01Je5 B CHI as Ii.£C1JON LI£ IOOED NÐ HCR VM.VES REPO œ/01/83 A roE lA - 11) CAD 00\1E ~. ~ 'W" 0fSCIFID 1TII.E - fff aIECIŒD fff /- fff IREV. TOE C ~ 00\1E ~~ ~ NTS SEPT 93 18EOOO1C 1 of 1 ':"..C_,., . ~-,. . . Material List Item Description ' '. A 3-1/8" 5000# Remote Hydraulic Operated Choke . . . - .'. ... .. .."...... .,.:... .. B,C 3-1/8" 5000# Adjustable Choke ..:.... '. . 1,5,6,7,10,15 4-1/16" 5000# Manual Gate Valve> . '... 2-5,8,9,11-14 3-1/8" 5000# Manual Gate Valve 16 2-1/16" 5000# Manual Gate Valve . I..' ...~. ;, ;ø~~ ~ . . .....".r Legend ffi White Handle Valves W Normally Open CD Red Handle Valves Normally Closed '. - . r ~ ,.'0', '."., - ¿.L-03 Planned Completion Schematic (Sheet 1 of 2) Prod ucer , , , , . , ~ ~ , , . , , , ~ ~ , , . , . , . , ~ ~ ~ ~ , , , , , , , , , , ~ ~ , , , , . , ~~ '~ Conductor: 16", 62.58# Set @ +1- 115' MO I I I I ~ I I I ~ I I I I I I ~ I ~ I I I I ....J ~ I I I I i I ~ I I ~ I I I I I I I I I- TD 12-1/4" Hole @ 3124' MD I 2437' TVD I (100' TVO Above theTop of the C-80) I I I I I I. I I I I I I I. 9-5/8" TAM Port Collar BTC Box x Pin Set @ +1- 1000' MO Surface Casing 9-5/8", 40#, L-80, BTC Float Collar to Surface Weatherford Single Valve Float Collar 9-5/8",32-53#, BTC Box x Pin 9-5/8", 40#, L-80, BTC Casing (2-Joints) Weatherford Single Valve Float Shoe 9-5/8",32-53#, BTC Box Up Production Casing 7",26#, L-80, BTC Float Collar to Surface Weatherford Single Valve Float Collar 7", 20-35#, BTC Box x Pin 7", 26#, L-80, BTC Casing (2-Joints) Weatherford Single Valve Float Shoe 7", 20-35#, BTC Box Up TD 8-1/2" Hole @ 10917' MD /6194' TVD (45' MD below K-1 Marker) .. I I I I ~ ~ I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ I ~ I I I I ~ I ~ I Jj I-- I I I ~ I I I I I. I I. I I I ~ I I I L --- (Ph.__~ PHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY FMC Gen V Tubing Hanger wI 3-1/2" L-80 EUE 8rd Mod pup joint installed 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing (1-Joint) installed below tubing hanger 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing Spacout Pups (as required). 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing as required from 'OS' Nipple to surface 3-1/2" Camco 'DS' Landing Nipple wi 2,875" No-Go Profile, Plan to locate nipple @ +1- 500' MD 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing with 3-1/2" x 1" Camco 'KBUG' GLM's wi dummy valves and latches. 6-foot handling pups should be installed on top and bottom of each GLM. Plan to spaceout GLM's as follows: GLM# TVD-RKB MD-RKB 1 TBD TBD 2 TBD TBD 3 TBO TBD 4 TBD TBO 3-1/2" X 1-1/2" Camco 'MMG' GLM wI dummy valves and latches. 6-foot handling pups should be installed on top and bottom. 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing (1-Joint). 3-1/2" Baker 'CMU' Sliding Sleeve wi Cameo 2,813"'DS' Profile 3-1/2",9,3#, L-80, EUE 8rd Mod Tubing (1-Joint). 3-1/2" Camco 'D' Landing Nipple wI 2.750" No-Go Profile. 3-1/2",9.3#, L-80, EUE 8rd Mod Handling Pup Joint (6 foot length) 3-1/2" Baker 'GBH-22' Seal Assembly wI 17' of seals and locator, Packer Assembly by Baker Oil Tools: Top of Packer set @ +1-10767' MD 16121' TVD (150' MO above 7" Casing Shoe) See Sheet 2 for Lower Completion (Packer Assembly and Below) O~ 'G NA- 2L-03 Schematic v2A prepared by Mark Chambers 11/30/01 .!L03 Planned Completion Schematic (Sheet 2 of 2) Prod ucer Production Casing 7",26#, L-80, BTC Float Collar to Surface TD 8-1/2" Hole @ 10917' MD I 6194' TVD (45' MD below K-1 Marker) Future Kuparuk Perforations TD 6-1/8" Hole @ 11,404' MD I 6,429' TVD (200' MD Below the Base of the Kuparuk) (Ph..:.ìs\ PHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Liner Top Packer Assembly, by Baker Oil Tools, consisting of the following: Top of Packer to be set @ +1- 10767' MD 16121' TVD (150' MD above 7" Casing Shoe) 1, Baker 5" x 7" 'ZXP HR' Liner Top Isolation Packer (Plan to utilize Baker rotating packer setting dog sub) 2. Baker 5" x 7" 'Flexlock' Hydraulic Liner Hanger. Flexlock Hanger should be pinned for +1-2600 psi and the 'HR' Setting Tool pinned for +1-3300 psi. Baker to verify pressure settings. I I I I I I I ~ 3. Baker '80-40' Seal Bore Extension (SBE) 20' Length wi 4.00" Min ID. 4. Crossover Sub as required 3-1/2",9.3#, L-80, SLHT Tubing from Landing Collar to SBE 3-1/2", Baker Landing Collar wi SLHT Box x Pin 3-1/2",9.3#, L-80, SLHT Tubing (1-Joint) 3-1/2", Baker Float Collar wI SLHT Box x Pin 3-1/2",9.3#, L-80, SLHT Tubing (2-Joints) 3-1/2", Baker Float Shoe wI SLHT Box Up PBTD (Top of Landing Collar) +1- 11,308' MD, 6,382' TVD 0. =, 'G,NA ~ 2L-03 Schematic v2A prepared by Mark Chambers 11/30/01 <=>E -'~~ c.. -~Q) --...° ~o ----~ ~t: =--- Q) ~> r--~ L. .- I v 500 - 0 - 500 - 1000 - 1500 - ,.-..... - ~ 2000 - I+- '-"" 2500 - 3000 - 3500 - 4000 - 4500 - 5000 - 5500 - 6000 - 6500 - 7000 500 i RKB ELEVATION: 152' KOP 2.00 6.00 OLS: 2.00 deg per 100 ft 12.00 18.00 24,00 30.00 OLS: 3.00 deg per 36 00 T I.. West Sok ~2.oo BI Permofrosl 48.00 54.00 60.00 EOB MAXIMUM ANGLE 61.18 DEG 0 500 1000 1500 2000 2500 Phillips Alaska, Inc. Structure: Tarn Drill Site 2L Well: 3 Location: Norlh Slope, Alaska /PHilliPS ... \tïm 0 800 1600 East (feet) -> 4000 35.08 AZIMUTH 8497' (TO TARGET) TD LOCATTION: 1776' FSL, 757' FEL SEC. 11, T10N, R7E, UM 100 ft KUPARUK C Target LOCATION: 1529' FSL. 931' FEL SEC. 11, T10N, R7E, UM C-BO(K-10) C-50 C-4O C-37 Bose Iceberg 9 5/8 2400 4800 5600 8000 3200 Míluveoch LCU I Kup A TGT - Kup C 7 Csg pt Bose HRZ TI HRZ(K-2) - 5600 ^ - 4800 I Z - 4000 0 ., -+- :r ,.-..... - 3200 -+> m m -+- '-"" - 2400 - 1 600 - 800 ---, - 0 C-35 SURFACE LOCATION: 143' FNL, 544' FEL SEC. 22, T1 ON, R7E, UM C-30 TI HRZ(K-2) Bose HRZ C-2O TGT - Kup C 7 Csg pt ~ K-1 2L-03 Kup C TGT Rvsd 29 Npv 01 ~ LCU / M~l£,e~ch ~ TO 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 Vertical Section (feet) -> Azimuth 35.08 with reference 0.00 N, 0.00 E from slot #3 Created by janes For:M Chambers! Dole plotted: 3-Dec-2DDI Plot Reference is 2L -3 Version #3.A. Coordinotes ore in feet reference slot 13, True Vertical Depths ore reference RKB (Nabors1 BE).j BillI ¡ BAKER HUGHES _._._.J~TEQ -..-----. _n_. \ Cr""ted by ¡ones For: M Chambers I Dote plotted: 3-Dec-2oo1 i Plot Ref.rence is 2L-3 Version '3A ¡ Coord in ollIS orfl in feel referencfI :;101 13. ¡True Verticol Depths or. reference RKB (Nobors18E). ¡ 14.. ¡ -=- INTF.Q Phillips Alaska, Inc. Structure: Tarn Drill Site 2L Well: 3 Location: North Slope, Alaska /fHI~LIPS ~ ~ ,lD r-'-'~'-----"--- ....------------------ ------ - ----------'-------'--'~.~-.--_._--'---"----'----~-'-----...--------'-- ---- PROF~LE COMMENT DATA ~-=====a::::OI-==-O:::::==::::::: .----- Point ----- MD Inc Dir TVD No rt h East V. Sect Deg/1 001 KOP 300.00 0.00 35.08 300.00 0.00 0.00 0.00 O.OO! IT / West Sak 1 622.04 34.66 35.08 1552.00 289.26 203.12 353.45 3.001 IS/ Permafrost 1746.51 38.40 35.08 1652.00 349.88 245.69 427.52"01 ~ 1 ¡E08 2506.00 61.18 35.08 2139.12 821 .4 1 576.80 1003.70 3.001 19 5/8 Csg pt 3123.93 61.18 35.08 2437.00 1264.47 887.93 1545.09 0.001 dC-80(K-10) 3331 .37 61.18 35.08 2537.00 1413.21 992.37 1726.84 0.00\ :dC-50 6080.00 61.18 35.08 3862.00 3384.03 2376.30 4135.02 0.001 ~C-40 6806.06 61.18 35.08 4212.00 3904.62 2741.87 4771.15 O.OO! ~C-37 7220.94 61.18 35.08 4412.00 4202.10 2950.76 5134.65 0.001 ==:::T op Iceberg 7283.18 61.18 35.08 4442.00 4246.72 2982.09 5189.17 0.001 riBose Iceberg 7407.64 61.18 35.08 4502.00 4335.96 3044.76 5298.22 0.001 IC-35 8942.73 61.18 35.08 5242.00 5436.64 3817.67 6643.17 O.OO! IC-3O 10125.16 61.18 35.08 5812.00 6284.47 4413.02 7679.14 0.001 IT/ HRZ(K-2) 10423.88 61.18 35.08 5956.00 6498.65 4563.42 7940.86 ~ '10! ¡C-20 10602.28 61.18 35.08 6042.00 6626.57 4653.25 8097.17 lrÔO! I ¡Bose HRZ 10699.78 61.18 35.08 6089.00 6696.48 4702.34 8182.59 0.001 ¡K-1 10871.96 61.18 35.08 6172.00 6819.93 4789.03 8333.44 0.001 17 C59 pt 10916.96 61.18 35.08 6193.69 6852.20 4811.69 8372.87 0.001 iTGT - Kup C 11058.64 61.18 35.08 6261 .99 6953.79 4883.03 8497.00 0.001 ¡LCU / Kup A 11120.89 61.18 35.08 6292.00 6998.42 4914.37 8551 .54 0.001 Mìluveach 11 203.87 61.18 35.08 6332.00 7057.92 4956.15 8624.24 0.001 ! T D -------------- ....----_____--.l1 403.87 61.18 35.08 6428.41 7201 .32 5056.85 ___JiZ9 9~_____----J)~0! ) Phillips Alaska, Inc. Tarn Drill Site 2L 3 slot #3 Tarn Development Field North Slope, Alaska ) SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 2L-3 Version #3.A Our ref: prop4758 License: Date printed: 3-Dec-2001 Date created: 11-Jun-2001 Last revised: 3-Dec-2001 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 48.339,w150 18 49.199 Slot Grid coordinates are N 5927701.776, E 461107.193 Slot local coordinates are 142.63 S 543.74 W Reference North is True North Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath Closest approach with 3-D Last revised Distance 15-Dec-1998 29.0 14-Dec-2000 199.0 10-Jan-2001 199.0 29-Dec-1998 299.3 11-Jan-1999 268.6 19-Nov-1998 329,9 18-Mar-1999 149.7 4-Apr-1999 50.7 14-Mar-2000 388.5 16-Nov-1998 388.5 29-Dec-1998 180.1 PMSS <0-9210'>, ,305,Tarn Drill Site 2L PMSS <0-14161'>,,317,Tarn Drill Site 2L PMSS 9455'-12655'MD,,317A,Tarn Drill Site 2L 323 PMSS <0-10400'>,,323,Tarn Drill Site 2L PMSS <0-12403'>,,321,Tarn Drill Site 2L PMSS <0-9200'>,,325,Tarn Drill Site 2L PMSS <0-11140'>, ,313,Tarn Drill Site 2L PMSS <0-9727'>,,307,Tarn Drill Site 2L PMSS <0-6864'>"Arete,Tarn Drill Site 2L 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 315 PMSS <0-8236'>,,315,Tarn Drill Site 2L JR!G NA- Minimum Distance method M.D. Diverging from M.D. 325.0 325.0 637.5 637.5 637.5 637.5 312.5 312.5 325.0 325.0 100.0 100.0 180.0 180.0 650,0 650.0 337.5 337.5 337.5 337.5 20.0 20.0 l--J?i~-i-¡ lip-~---Ai~~-k-~-:-----f~-~)~-~-- I.............'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''",,,,,''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.............................................................,............................,.............,...,..........,.....,..........., ¡ structure: Tarn Drill Site 2L Well: 3 !.......n......n...n.......nn.............nn............nn.........~.?n?..?..!.~..?~.......~.....n~.?..~!.~......~..~.?..P..~.~n....~.~..~..=.~.?....................................................................................., ~HI~LIPS ~ r!lm "ë~;;~ï;;;¡"ï,ÿj~~~;......._".....n.nF;;~';''''~;¡:-''ëh-~~'b';r; Dote plotted: J-Dec-2001 Plot Reterence Is 2L-3 Version 13.A. CoordInate. ore In teet reterence .Iot ((3, True Vertical Depths ore rMWKB (Nabor.18E). BAKER HUGHES I Nr.E.Q....._.....-...--.....,---......- TRUE NORTH ~ c:J 0 10 350 340 20 330 280 30 300 310 50 320 40 .60 290 70 280 80 270 90 260 250 18 I ¡ 900 240 @ 230 100 110 120 130 12000 220 1210 13001 \ \ \ I¡ 1300 \ \ 1100 200 \ 19\180 ~1400 ~ \9 ~ 280 @ \ \ ~ 1200 \ \ ~ 170 '\ 140 " ~2300 \~400 "\ 1 30 16~~ 1500 ~~ ~ Normal Plane Travelling Cylinder - Feet All depths shown ore Measured depths an Reference Well O=,'G'NA- "''''''''''''''''''''.........................................."...............................""''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''""'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.'''''''.''''''''''''''''''''''................ l.-~.~.!_~.i:_iJe_~__..~-~._~-~_~_~.l__.__~.~l~.:_._. ! structure: Tarn Drill Site 2L Well: 3 ~HI~LIPS ~ ~~~..~ .....1............................... 'C;;~ïed"'b'Ÿ"JÖ~;';''''''.'' "è~';';".'M".'ëh~m bers Date plotted: .3-Dec-2D01 Plot Reference i. 2L-.3 Ver5;an #3.A. Coordinate. ore in feet reference .Iot #3. True Vertical Depth. are ~~ce RKB (NobarsI8E). r&ii!!1I Bf¡I!I.s Location: North Slope, Alaska .""""''''''''''''.''''''''''''''''''''.'' ...",."",,,,,,,,,,,,,,.,,,.,,..,,.,,,..,., .................................................. ..".""."..""",.",.".",..,.,.".,..".,...,..... """"''''''''''''''''''................., --_.._-_.._.......J~]]:..Q-_...._...._......__.__..__..._.__........ East (feet) -> 160 520 120 80 40 0 40 80 120 160 200 240 280 320 360 400 400 - - 400 //./..{;O;s$J: 360 1 600 e"'/' - 320 /' 1 800 "."." ..../' ..../' /"/1700 1500 //' ...../ 1600 / 520 480 - - 480 440 - - 440 360 - 320 - 280 - - 280 240 - - 240 160 - -~ 200 - ~ """"''0 1 600 '-\ ',- 240: ~ ~ I //1400 1 500)""" ..../ 1400// 1300 / / 137 1200 1270 1100 1000 1100 ""I 900 1000/ 800 900 J 700 800/ 500 500' ~Õo"'-'7ÕÒ-"-'---'"'-'-''' /i};e.... 800 gõõ""--'-'-,--" 40 - -'-"'0. 1 000 1000"'-'-'-"'--,."-",,,--,-- ~ "'-0 1100 11 00 -........-.-....-.-. ~ 1100 """""...,1200 1200 13ÕÕ-o-"-,-""-",,,,,,,,,,,,,,,.-,,,,,,,,-,-,-,-,,-,, 80 ~ "''',,1200 ""-"',),300 1400 -;-SÕõ'.'-'-''''-'@§D.- 80 """, ".... 1300 "" 1 400 .. 90Ò"'" "-........ 1400 e"" 120 - '"""" -""":"""" 1 500 "'-0, 1500 1000'8,. "-" "" --""'" "--..-...~ 600 '-........,-~OO 1100-e.............. '-""- 1 700 -......... ,"-...-... -"""""'''' 1700 """"........ "',1800 -'-........ 1200~.... -...-..., '" ...., ''0,2 900 -',1800 ....................... '......., '-" 1300' """',,2000 -""', ...." ~ ""''O..A~OO ~ ~ ~ 160 - - 160 ^ I z 0 -. - ::J'" 200 - - 200 ^ I ...--.. - Q) Q) - '--" 120 - - 120 ...c - L 0 Z 80 - - 80 ...--.. - CD CD - '--" 40 - - 40 0 - - 0 - 40 - 120 - 160 - 200 - 240 160 120 80 40 0 40 80 120 160 200 240 280 320 360 400 East (feet) -> O=G NA- --pi~~\ii-p-~ ........,..,.......,.............,...................."""""""""""""""""""""""""""'"...............................,...., Alaska, ') InC~ ..-....-..-------..-.----------.-..-.-......-,..---....--..-.-....-..-..-.-. Created by Jones For: M Chambers Date plotted: 3-Deo-2001 Plot Relerence Is 2L-3 VersIon #3.A. Coordinate. ore in feet reference ,'ot #3. True Vertical Oepths ore refere,nce RKB (NaborsIBE), ßiím Location: North Slope, Alaska ,..."................."._.._.....l~::~.~............................................;...---..--...'.-.-..-.-..--........"..-..-...........-......-..'.'.""-'-la"s'fTf'e'ëlT'-=">""-'--'- 0 350 700 1050 1400 1750 2100 2450 2800 3150 7350 - 7000 - 6650 - 6300 ... 5950 - 5600 - 5250 - 4900 ... 4550 - ^ I 4200 - ............ -+- Q) 3850 - Q) '+- '-- ..c:: 3500 - -+- I.... 0 Z 3150- 2800 - 2450 ... 2100 - 1750 - 1400 - 1050... 700 - 350 - 0 '"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''..........................."...,.................,.."."....,................"..........""'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''................................. Structure: Tarn Drill Site 2L Well: 3 -'."''''.''''''.'---'''-'''''''''''''''-'''''' 3500 3850 4200 Target - 6262.00 Tvd, 6953.80 N, 4883.03 E ,_."......;._:~~ 3700 ,,~.,......,.o-J..t '-"'-0...--....... 3900 .0,/ V" -.......... ..~,-,,/ J';: v ~41 00 ...-,...'-.2 00 '-... ...".-".-- .9Q '" 4300 ----,..-:-- ~.>. V \ ~..- ~ 00 _0'---::- \5'0" '\ 4500 ~ ~ v \ 1 700 /""'~7 Vo \ ,/'" " Q , 1500 ~".>. .900 V \ 4700 ~Oo ~ ~ ~ I I 0 350 700 4200 1050 1750 1400 2100 2450 2800 3150 3500 3850 East (feet) -> 01i'G ^A. ~HILLIPS ~ rÐ 4550 4900 5250 - 7350 4550 - 6650 - 6300 - 5950 - 5600 - 5250 - 4900 - 4550 ^ - 4200 I Z - 3850 0 :::¡. :r ............ - 3500 - CD CD - '-- - 3150 - 2800 - 2450 - 2100 - 1750 - 1400 - 1050 - 700 - 350 0 4900 5250 ') ) Phillips Alaska, Inc. Tarn Drill Site 2L 3 slot #3 Tarn Development Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2L-3 Version #3.A Our ref: prop4758 License: Date printed: 3-Dec-2001 Date created: 11-Jun-2001 Last revised: 3-Dec-2001 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 48.339,w150 18 49.199 Slot Grid coordinates are N 5927701.776, E 461107.193 Slot local coordinates are 142.63 S 543.74 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North OR, G, NA. ~) Phillips Alaska, Inc. Tarn Drill Site 2L,3 Tarn Development Field/North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 300.00 400.00 500.00 600.00 700.00 800.00 866.67 966.67 1066.67 1166.67 1266.67 1366.67 1466.67 1566.67 1622.04 1666.67 1746.51 1766.67 1866.67 1966.67 2066.67 2166.67 2266,67 2366.67 2466.67 2506.00 3000.00 3123.93 3331.37 3500.00 4000.00 4500.00 5000.00 5500.00 6000.00 6080.00 6500.00 6806.06 7000.00 7220.94 7283.18 7407.64 7500.00 8000.00 8500.00 8942.73 9000.00 9500.00 10000.00 8.00 10.00 12.00 15.00 18.00 21. 00 24.00 27,00 30.00 33.00 34.66 36.00 38.40 39.00 42.00 45.00 48.00 51. 00 54.00 57.00 60.00 61.18 61.18 61.18 61. 18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61,18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 0.00 0.00 2.00 4.00 6.00 35.08 35.08 35.08 35.08 35.08 0.00 300.00 399.98 499.84 599.45 698.70 797.47 862.90 960.13 1056.00 1150.25 1242.63 1332.88 1420.75 1506.01 1552.00 1588.41 1652.00 1667.74 1743.77 1816.30 1885.12 1950.06 2010.93 2067.56 2119.81 2139.12 2377.26 2437.00 2537.00 2618.29 2859.32 3100.35 3341. 38 3582.41 3823.43 3862.00 4064.46 4212.00 4305.49 4412.00 4442.00 4502.00 4546.52 4787.55 5028.58 5242.00 5269.61 5510.64 5751.67 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 1. 43 N 5.71 N 12,84 N 22.82 N 35.62 N 46.03 N 65.13 N 88.37 N 115.69 N 147.00 N 182,23 N 221. 27 N 264.03 N 289.26 N 310.38 N 349.88 N 360.19 N 413.34 N 469.66 N 529.02 N 591. 24 N 656.16 N 723.60 N 793.37 N 821. 41 N 1175.62 N 1264.47 N 1413,21 N 1534.12 N 1892.63 N 2251.14 N 2609.65 N 2968.15 N 3326.66 N 3384.03 N 3685.17 N 3904.62 N 4043.68 N 4202.10 N 4246,72 N 4335.96 N 4402.19 N 4760.69 N 5119.20 N 5436.64 N 5477.71 N 5836.22 N 6194.73 N 0.00 E 0.00 E 1.00 E 4.01 E 9.02 E 16.02 E 25.01 E 32.32 E 45.74 E 62.06 E 81.24 E 103.23 E 127.96 E 155,38 E 185.40 E 203.12 E 217.95 E 245.69 E 252.93 E 290,25 E 329.80 E 371.48 E 415.18 E 460.76 E 508.12 E 557.11 E 576.80 E 825.53 E 887.93 E 992.37 E 1077.28 E 1329.03 E 1580.77 E 1832.52 E 2084.27 E 2336.02 E 2376.30 E 2587.77 E 2741. 87 E 2839.52 E 2950.76 E 2982.09 E 3044.76 E 3091. 26 E 3343.01 E 3594.76 E 3817.67 E 3846.51 E 4098.26 E 4350.00 E Dogleg Degl100ft ') PROPOSAL LISTING Page 1 Your ref: 2L-3 Version #3.A Last revised: 3-Dec-2001 Vert Sect 0.00 0.00 2.00 2.00 2.00 0.00 0.00 KOP 1. 75 6.98 15.69 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35,08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 2.00 2.00 3.00 3.00 3.00 27.88 43.52 56.24 79.58 107.98 3.00 3.00 3.00 3.00 3.00 141.36 179.62 222.67 270.38 322.62 3.00 3.00 3.00 3.00 3.00 353.45 TI West Sak 379.26 427,52 BI Permafrost 440.13 505.06 3.00 3.00 3.00 3.00 3.00 573.89 646.42 722,45 801. 78 884.18 3.00 3.00 0.00 0.00 0.00 969.44 1003.70 EOB 1436.51 1545.09 9 5/8" Csg pt 1726,84 C-80(K-10) 0.00 0.00 0.00 0.00 0.00 1874.58 2312.65 2750.72 3188.79 3626.86 0.00 0.00 0.00 0.00 0.00 4064.93 4135.02 C-50 4503.00 4771,15 C-40 4941. 07 0.00 0.00 0.00 0.00 0.00 5134.65 5189.17 5298.22 5379.14 5817.21 C-37 Top Iceberg Base Iceberg 0.00 0.00 0.00 0.00 0.00 6255.28 6643.17 C-35 6693.35 7131.42 7569.49 All data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from RKB (Nabors18E) (152.00 Ft above mean sea Bottom hole distance is 8799.47 on azimuth 35.08 degrees from wellhead. Total Dogleg for wellpath is 61.18 degrees. Vertical section is from wellhead on azimuth 35.08 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 0: G NA- level) . ) Phillips Alaska, Inc. Tarn Drill Site 2L,3 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 10125.16 10423.88 10500.00 10602.28 10699.78 10871. 96 10916.96 11000.00 11058.64 11058.66 11120.89 11203.87 11403 .87 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 61.18 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 35.08 5812.00 5956.00 5992.70 6042.00 6089.00 6172 . 00 6193,69 6233.72 6261. 99 6262.00 6292.00 6332.00 6428.41 R E C TAN G U L A R COO R DIN ATE S 6284.47 N 6498.65 N 6553.23 N 6626.57 N 6696.48 N 6819.93 N 6852.20 N 6911.74 N 6953.79 N 6953.80 N 6998.42 N 7057.92 N 7201. 32 N 4413.02 E 4563.42 E 4601.75 E 4653.25 E 4702.34 E 4789.03 E 4811.69 E 4853.50 E 4883.03 E 4883.03 E 4914.37 E 4956.15 E 5056.85 E Dogleg DegllOOft ) PROPOSAL LISTING Page 2 Your ref: 2L-3 Version #3.A Last revised: 3-Dec-2001 Vert Sect 0.00 0.00 0.00 0.00 0,00 7679.14 C-30 7940.86 T/ HRZ(K-2) 8007.56 8097.17 C-20 8182.59 Base HRZ 0.00 0.00 0.00 0.00 0.00 8333.44 8372.87 8445.63 8497.00 8497 . 02 K-1 7" Csg pt TGT - Kup C 2L-03 Kup C TGT Rvsd 29 Nov 01 0.00 0,00 0.00 8551.54 LCU / Kup A 8624.24 Miluveach 8799.47 TD All data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from RKB (Nabors18E) (152.00 Ft above mean sea Bottom hole distance is 8799.47 on azimuth 35.08 degrees from wellhead, Total Dogleg for wellpath is 61.18 degrees. Vertical section is from wellhead on azimuth 35.08 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 0 :.GNA~ level) . ') ) Phillips Alaska, Inc. Tarn Drill Site 2L,3 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2L-3 Version #3.A Last revised: 3-Dec-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 1622.04 1552.00 289.26 N 203.12 E TI West Sak 1746.51 1652.00 349.88 N 245.69 E BI Permafrost 2506.00 2139.12 821. 41 N 576.80 E EOB 3123.93 2437.00 1264.47 N 887.93 E 9 5/8" Csg pt 3331.37 2537.00 1413.21 N 992.37 E C-80(K-10) 6080.00 3862.00 3384.03 N 2376.30 E C-50 6806.06 4212.00 3904.62 N 2741.87 E C-40 7220.94 4412.00 4202.10 N 2950.76 E C-37 7283.18 4442.00 4246.72 N 2982.09 E Top Iceberg 7407.64 4502.00 4335.96 N 3044.76 E Base Iceberg 8942.73 5242.00 5436.64 N 3817.67 E C-35 10125.16 5812.00 6284.47 N 4413.02 E C-30 10423.88 5956.00 6498.65 N 4563.42 E TI HRZ(K-2) 10602.28 6042.00 6626.57 N 4653.25 E C-20 10699.78 6089.00 6696.48 N 4702.34 E Base HRZ 10871.96 6172.00 6819.93 N 4789.03 E K-1 10916.96 6193.69 6852.20 N 4811.69 E 7" Csg pt 11058.64 6261. 99 6953.79 N 4883.03 E TGT - Kup C 11058.66 6262.00 6953.80 N 4883.03 E 2L-03 Kup C TGTRvsd 29 Nov 01 11120.89 6292.00 6998.42 N 4914.37 E LCU I Kup A 11203.87 6332.00 7057.92 N 4956.15 E Miluveach 11403.87 6428.41 7201. 32 N 5056.85 E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot '¡'VD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE 3123.93 2437.00 O.OOE 10917.00 6193.71 O.OOE 11403.87 6428.41 1264.47N 6852.23N 7201.32N 887.93E 9 5/8" CSG 4811.71E 7" CSG 5056.85E 3 1/2" CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2L-03 Kup C TGT Rvsd 466025.000,5934630.000,0.0000 6262.00 6953.80N 4883.03E 1-Jun-200l 0 1 G,NA.. ) ) Phillips Alaska, Inc. Tarn Drill Site 2L 3 slot #3 Tarn Development Field North Slope, Alaska PRO P 0 S ALL 1 S TIN G by Baker Hughes INTEQ Your ref: 2L-3 Version #3.A Our ref: prop4758 License: Date printed: 3-Dec-2001 Date created: 11-Jun-2001 Last revised: 3-Dec-2001 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 48.339,w150 18 49.199 Slot Grid coordinates are N 5927701.776, E 461107.193 Slot local coordinates are 142.63 S 543.74 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 0. ?,'G,", vA!~ ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Tarn Drill Site 2L,3 Your ref: 2L-3 Version #3.A Tarn Development Field,North Slope, Alaska Last revised: 3-Dec-2001 Measured Inclin Azimuth True Vert R E eTA N G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R D I N ATE S Easting Northing COO R DIN A T E S 0.00 0.00 35.08 0.00 O.OON O.OOE 461107.19 5927701.78 n70 12 48.34 w150 18 49.20 300.00 0.00 35.08 300.00 O.OON O.OOE 461107,19 5927701.78 n70 12 48.34 w150 18 49.20 400.00 2.00 35.08 399.98 1.43N 1.00E 461108.20 5927703.20 n70 12 48.35 w150 18 49.17 500.00 4.00 35.08 499.84 5.71N 4.01E 461111.23 5927707.47 n70 12 48.40 w150 18 49.08 600.00 6.00 35.08 599.45 12.84N 9.02E 461116.28 5927714.57 n70 12 48.47 w150 18 48.94 700.00 8.00 35.08 698.70 22.82N 16.02E 461123.33 5927724.51 n70 12 48.56 w150 18 48.73 800.00 10.00 35.08 797.47 35, 62N 25.01E 461132.38 5927737.26 n70 12 48.69 w150 18 48.47 866.67 12.00 35.08 862.90 46.03N 32.32E 461139.74 5927747.63 n70 12 48.79 w150 18 48.26 966.67 15.00 35.08 960.13 65.13N 45.74E 461153,25 5927766.67 n70 12 48,98 w150 18 47.87 1066.67 18.00 35,08 1056.00 88.37N 62.06E 461169.69 5927789,82 n70 12 49.21 w150 18 47.40 1166,67 21.00 35.08 1150.25 115. 69N 81. 24E 461189.01 5927817.04 n70 12 49.48 w150 18 46.84 1266,67 24.00 35.08 1242.63 147.00N 103.23E 461211.15 5927848.24 n70 12 49.78 w150 18 46.20 1366.67 27.00 35.08 1332.88 182.23N 127.96E 461236.07 5927883.33 n70 12 50.13 w150 18 45.48 1466.67 30.00 35.08 1420.75 221.27N 155,38E 461263.68 5927922.24 n70 12 50.52 w150 18 44,69 1566.67 33.00 35.08 1506.01 264.03N 185.40E 461293.92 5927964.83 n70 12 50.94 w150 18 43.82 1622.04 34,66 35,08 1552.00 289.26N 203.12E 461311.76 5927989.97 n70 12 51.18 w150 18 43.30 1666.67 36.00 35.08 1588.41 310,38N 217.95E 461326.70 5928011,01 n70 12 51. 39 w150 18 42.87 1746.51 38.40 35.08 1652.00 349.88N 245.69E 461354.63 5928050.37 n70 12 51.78 w150 18 42.07 1766.67 39.00 35.08 1667.74 360.19N 252,93E 461361. 93 5928060.64 n70 12 51.88 w150 18 41.86 1866.67 42.00 35.08 1743.77 413.34N 290.25E 461399.51 5928113.59 n70 12 52.40 w150 18 40,77 1966,67 45.00 35.08 1816.30 469.66N 329.80E 461439.34 5928169.71 n70 12 52.96 w150 18 39,63 2066.67 48.00 35.08 1885.12 529. 02N 371.48E 461481.32 5928228.85 n70 12 53.54 w150 18 38,41 2166.67 51. 00 35.08 1950.06 591. 24N 415,18E 461525.33 5928290.84 n70 12 54.15 w150 18 37.15 2266.67 54.00 35.08 2010.93 656.16N 460.76E 461571.24 5928355.52 n70 12 54.79 w150 18 35.82 2366.67 57.00 35.08 2067.56 723. 60N 508.12E 461618.93 5928422.71 n70 12 55.46 w150 18 34.45 2466.67 60.00 35.08 2119.81 793.37N 557.11E 461668.27 5928492.23 n70 12 56.14 w150 18 33.03 2506,00 61.18 35.08 2139.12 821.41N 576. 80E 461688.11 5928520.17 n70 12 56,42 w150 18 32.45 3000.00 61.18 35.08 2377.26 1175.62N 825.53E 461938.60 5928873.07 n70 12 59.90 w150 18 25.23 3123.93 61,18 35.08 2437.00 1264.47N 887.93E 462001. 44 5928961.60 n70 13 00.78 w150 18 23.42 3331. 37 61.18 35.08 2537.00 1413.21N 992.37E 462106.63 5929109.79 n70 13 02.24 w150 18 20.39 3500.00 61.18 35.08 2618.29 1534.12N 1077.28E 462192.14 5929230.26 n70 13 03.43 w150 18 17.92 4000.00 61.18 35.08 2859.32 1892.63N 1329.03E 462445.68 5929587.45 n70 13 06,95 w150 18 10.61 4500.00 61.18 35.08 3100.35 2251.14N 1580.77E 462699.23 5929944.64 n70 13 10.48 w150 18 03.30 5000.00 61.18 35.08 3341.38 2609.65N 1832.52E 462952.77 5930301.83 n70 13 14.00 w150 17 55.99 5500.00 61.18 35.08 3582.41 2968.15N 2084.27E 463206.31 5930659.01 n70 13 17.53 w150 17 48.67 6000.00 61.18 35.08 3823.43 3326.66N 2336.02E 463459.85 5931016.20 n70 13 21.05 w150 17 41.36 6080.00 61.18 35.08 3862,00 3384.03N 2376.30E 463500.42 5931073.36 n70 13 21. 62 w150 17 40.19 6500.00 61.18 35.08 4064.46 3685.17N 2587.77E 463713.39 5931373.39 n70 13 24.58 w150 17 34.05 6806,06 61.18 35.08 4212.00 3904.62N 2741.87E 463868.58 5931592.03 n70 13 26.74 w150 17 29.57 7000.00 61.18 35.08 4305.49 4043.68N 2839.52E 463966.93 5931730.58 n70 13 28.11 w150 17 26.73 7220.94 61.18 35.08 4412.00 4202.10N 2950.76E 464078.97 5931888.42 n70 13 29.66 w150 17 23.50 7283,18 61.18 35.08 4442.00 4246. 72N 2982.09E 464110.52 5931932.88 n70 13 30.10 w150 17 22.59 7407,64 61.18 35.08 4502.00 4335.96N 3044,76E 464173.64 5932021.79 n70 13 30.98 w150 17 20.77 7500.00 61.18 35.08 4546.52 4402.19N 3091. 26E 464220.47 5932087.77 n70 13 31.63 w150 17 19.41 8000.00 61.18 35.08 4787.55 4760.69N 3343.01E 464474.01 5932444.96 n70 13 35.16 w150 17 12.10 8500.00 61.18 35.08 5028.58 5119. 20N 3594.76E 464727.55 5932802.15 n70 13 38.68 w150 17 04.78 8942.73 61.18 35.08 5242.00 5436.64N 3817,67E 464952.05 5933118.43 n70 13 41.80 w150 16 58.30 9000.00 61.18 35.08 5269.61 5477.71N 3846.51E 464981.09 5933159.34 n70 13 42.21 w150 16 57.46 9500.00 61.18 35.08 5510.64 5836.22N 4098.26E 465234.63 5933516.53 n70 13 45.73 w150 16 50.14 10000.00 61.18 35.08 5751.67 6194.73N 4350,OOE 465488.18 5933873.72 n70 13 49.26 w150 16 42.83 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from RKB (Nabors18E) (152.00 Ft above mean sea level). Bottom hole distance is 8799.47 on azimuth 35.08 degrees from wellhead. Total Dogleg for wellpath is 61.18 degrees. Vertical section is from wellhead on azimuth 35,08 degrees, Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ C ,iG"NA~ ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Tarn Drill Site 2L,3 Your ref : 2L-3 Version #3.A Tarn Development Field,North Slope, Alaska Last revised : 3-Dec-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G R A PHI C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R D I N ATE S 10125.16 61.18 35.08 5812.00 6284.47N 4413.02E 465551. 64 5933963.13 n70 13 50.14 w150 16 40.99 10423.88 61.18 35.08 5956.00 6498.65N 4563.42E 465703.12 5934176.53 n70 13 52.24 w150 16 36,62 10500.00 61.18 35.08 5992.70 6553.23N 4601.75E 465741.72 5934230.91 n70 13 52.78 w150 16 35.51 10602.28 61.18 35.08 6042.00 6626.57N 4653.25E 465793.58 5934303.97 n70 13 53.50 w150 16 34.01 10699.78 61.18 35.08 6089.00 6696.48N 4702.34E 465843.02 5934373.63 n70 13 54.19 w150 16 32.58 10871. 96 61.18 35.08 6172.00 6819.93N 4789.03E 465930.33 5934496.63 n70 13 55.40 w150 16 30.06 10916.96 61.18 35.08 6193.69 6852.20N 4811.69E 465953.15 5934528.78 n70 13 55.72 w150 16 29.40 11000.00 61.18 35.08 6233.72 6911.74N 4853.50E 465995.26 5934588.10 n70 13 56.30 w150 16 28.18 11058.64 61.18 35.08 6261. 99 6953.79N 4883.03E 466024.99 5934629.99 n70 13 56.72 w150 16 27.33 11058.66 61.18 35.08 6262.00 6953.80N 4883.03E 466025.00 5934630.00 n70 13 56.72 w150 16 27.33 11120.89 61.18 35.08 6292.00 6998.42N 4914.37E 466056.56 5934674.46 n70 13 57.16 w150 16 26.41 11203.87 61.18 35.08 6332.00 7057.92N 4956.15E 466098.63 5934733.74 n70 13 57.74 w150 16 25.20 11403.87 61.18 35.08 6428,41 7201.32N 5056.85E 466200.05 5934876.61 n70 13 59.15 w150 16 22.27 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from RKB (Nabors18E) (152.00 Ft above mean sea level). Bottom hole distance is 8799.47 on azimuth 35.08 degrees from wellhead. Total Dogleg for wellpath is 61.18 degrees. Vertical section is from wellhead on azimuth 35.08 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ O~.'G,Nt~ ) ') Phillips Alaska, Inc. Tarn Drill Site 2L,3 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2L-3 Version #3.A Last revised: 3-Dec-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300,00 300.00 O.OON O.OOE KOP 1622.04 1552.00 289.26N 203.12E TI West Sak 1746.51 1652.00 349.88N 245.69E BI Permafrost 2506.00 2139.12 821.41N 576.80E EOB 3123.93 2437.00 1264.47N 887.93E 9 5/8" Csg pt 3331. 37 2537.00 1413.21N 992,37E C-80(K-10) 6080.00 3862.00 3384.03N 2376.30E C-50 6806.06 4212.00 3904.62N 2741.87E C-40 7220.94 4412.00 4202.10N 2950.76E C-37 7283.18 4442.00 4246, 72N 2982.09E Top Iceberg 7407.64 4502.00 4335.96N 3044.76E Base Iceberg 8942.73 5242.00 5436.64N 3817.67E C-35 10125.16 5812,00 6284.47N 4413.02E C-30 10423.88 5956.00 6498.65N 4563.42E TI HRZ(K-2) 10602.28 6042.00 6626.57N 4653.25E C-20 10699.78 6089.00 6696. 48N 4702.34E Base HRZ 10871.96 6172 .00 6819.93N 4789.03E K-1 10916.96 6193.69 6852.20N 4811.69E 7" Csg pt 11058.64 6261. 99 6953.79N 4883.03E TGT - Kup C 11058.66 6262,00 6953.80N 4883,03E 2L-03 Kup C TGT Rvsd 29 Nov 01 11120.89 6292.00 6998.42N 4914.37E LCU I Kup A 11203.87 6332.00 7057.92N 4956.15E Miluveach 11403.87 6428.41 7201.32N 5056.85E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE 3123.93 2437.00 O.OOE 10917.00 6193.71 O.OOE 11403.87 6428.41 1264.47N 6852,23N 7201.32N 887.93E 9 5/8" CSG 4811.71E 7" CSG 5056.85E 3 1/2" CSG Targets associated with this we11path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------'------------------------- 2L-03 Kup C TGT Rvsd 466025.000,5934630.000,0.0000 6262.00 6953,80N 4883.03E 1-Jun-2001 0 :' ~ 'NA I I I :4. - 2L-Q3 Permit Information ) ) Subject: 2L..o3 Permit Information Date: Fri, 14 Dec 2001 16:41 :38..0900 From: "Mark A Chambers" <mchambe2@ppco.com> To: tom_maunder@admin.state.ak.us Tom: Per our discussion this afternoon, the following items will be incorporated into the plan for drilling 2L-03: 1. A Mud log will be required on 2L-03' (1 st Kuparuk We1l from the 2L..Pad) 30' sampling from surface to TD increasing to 10' sampling across the Kuparuk Interval. 2. A Surface Gyro will be utilized as required to handle any close crossing issues. 3. The current planned Intermediate cement job will be revised to cover the Ice Berg if it is determined to be Hydrocarbon Bearing. For your review, I have attached a Cement Summary for the current plan and a proposed Contengency Cement Summary to cover the Ice Berg if it is found to be Hydrocarbon Bearing. If you require any further information please feel free to give me a call. Thanks. Mark Chambers 265-1319 Wk 240-5868 Celt (See attached file: 2L-03 Dowell Cmt Sum Intermediate.doc)(See attached file: 2L-03 Dowell Cmt Sum Intermediate Contingency. doc) Name: 2L-03 Dowell Cmt Sum Intermediate.doc ŒrJ2L-03 Dowell Cmt Sum Intermediate.doc Type: WINWORD File (application/msword) Encoding: base64 Name: 2L-03 Dowell Cmt Sum Intermediate R~2L 03 D II C t S I t d" t C t" d Contingency.doc bj - owe m urn n erme la e on InÇlency. oc Type: WINWORD File (application/msword) Encoding: base64 1 of 1 12/17/0111:51 AM Rig: Nabors 245E Location: Exploration Client: Phillips Alaska, Inc. Revision Date: 12/14/2001 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (901) 223-8808 email: CAvant@slb.com I I I Previous Csg. < 9-5/81, 36 #/ft csg at 3,124' MD < Top of Lead 7083' MD < Top of Tail at 10,117' MD < 7",26.0# casing in 8 1/2" OH TO at 10,917' MD (6,194'TVD) * Mark of Schlumberger . Cer II ACE 'ÞreliminaryJobDesign . 7")nterm~diateGOnti~Qency \'. Preliminary Job Design based on limited input data, For estimate purposes only. Schlumbepgep Volume Calculations and .Cement Systems Volumes are based on 300% excess in the permafrost and 75% excess below the permafrost. The top of the tail slurry is designed to be at 10,117' MD. Lead Slurry Minimum pump time: 190 min. (pump time plus 90 min.) 13.0 ppg Class G + 0.04% 0800 + 0.2% 0046 + 0.3% 0065 + 8.0% 0020 + 0.6% 0167 - 1.99 ft3/sk 0.1668 fe/ft x (0') x 1.00 (no excess) = 0.1268 ft3/ft x ( , - 3124') x 4.00 (300% excess) = 0.1268 ft3/ft x (3034] x 1.75 (75% excess) = 0 fe + 0 ft3+ 673.2 ft = 673.2 fe /1.99 fe/sk = Round up to 340 sks Ofe Ofe 673.2 ft3 673.2 fe 338.3 sks Have 250 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 170 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.5%S1, 0.2%046, 0.3%065, 0.4%0167 -1,17 ft3/sk 0.1268 ft3/ft x (10917' -10117') x 1.75 (75% excess) = 0.2148 ft3/ft x 80' (Shoe Joint) = 177.5 fe + 17.2 ft3 = 194.7 fe/1.17 fe/sk = Round up to 170 sks BHST = 139°F, Estimated BHCT = 118 of. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Stage Pump Rate Volume (bpm) (bbl) 6 50 CW100 Drop Bottom Plug MudPUSH Xl Lead Slurry . Tail Slurry Drop Top Plug Displacement Slow Rate 6 6 6 50 121 35 6 3 395 20 MUD REMOVAL 177.5 fe 17.2 fe 194.7 fe 166.4 sks Stage Time Cumulative (min) Ti,!,e (mm) 8.3 8.3 3.0 11.3 8.3 19.6 20.2 39.8 5.8 45.6 3.0 48.6 65.8 114.4 6.7 121.1 Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-21, Ty ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placem ent. Schlumbepgep . Cetr1CADEPreliminaryJob Design \. 7" .lntèrmediateCasina . " Preliminary Job Design based on limited input data, For estimate purposes only. Rig: Nabors 245E Location: Exploration Client: Phillips Alaska, Inc. Revision Date: 12/14/2001 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 223-8808 email: CAvant@slb.com Volume Calculations and. Cement SV$tem$ Volumes are based on 75% excess. Tail slurry is designed for 800' shoe tack. Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%065, 0.1%0800 - 1.17 ft3/sk (adjust retarder to give desired thickening time) 0.1268 fe/ft x 800' x 1.75 (75% excess) = 0.2148 ft3/ft x 80' (Shoe Joint) = 177.5 fe + 17.2 ft3 = 194.7 fe /1. 17 ft3/sk = Round up to 170 sks 177.5 fe 17.2 ft3 194.7 fe 166.4 sks Previous Csg. < 95/8",36.0# casing at 3,124' MD BHST = 139°F, Estimated BHCT = 118°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SC~EDULE Pump Rate Stage Sta e Time Cumulative Stage Volume 9 . Time (bpm) (bbl) (mm) (min) CW100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 35 5.8 23.8 Drop To~ Plug, 3.0 26.8 Displacement 6 395 65.8 92.6 Slow Rate 3 20 6.7 99.3 < Top of Tail at 10,117'MD MUD REMOVAL < 7",26.0# casing in 8 1/2" OH Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv ~ 19-22, Ty ~ 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. TO at 10,917' MD (6,194' TVD) . Mark of Schlumberger ') ) ..: I ¡.:ti"l.. ._~ il] ~ I ~_1.1 ::f~'I] a.: I =lIIIIeiIIM~:¡ .el: '-l~[~~~~;~:~~:~~,~~ç ~.~~~,I:.~~'l ~;.~~;~ ~..~~]~'~ I[._~,~~ ~r[~- ~.~t'~~\. ~~¿~~::~~,~~; ;,1 ~~~~I~:~'~ :~,~~~:..~~l~~ .~I'~ .,ll~" ~-- ~-;]¡II()!I!f",I'!!&¿!lf:,'~~nf~~:~!ijrr;.,.Ik, E;: ' ~r I '~i 1M ~Inl t\.Iallt)~a'U\~o~'~tt,i~~~J71}~>:' 0,,1:\, ,Ii, "' ~) .} .'~', J. , k:.,)~I[ '" '. W,. ,',". O\l:ll~~, 1II1nc.l(.,. Arcounl (19.1)(I1{)(I , A ~ fhllllro:. Ali:r:.\.;a. 111(, , ',II ,I,," ' rmt'lt 1t,n:~JVI '. ' , ß.311"...~hflt>~"IU(. K[r('i~13'¡ <1 Ä ~n~l~~r~;el, ~2~9 51 0-2776 '\;}:'~::~¡~jJ ~,:f) , ..J ~;j 12-04-01 III 000 0 ,¡. 0 . 3 L, L, 118 I: 0 H j 90 L, 2 b 2 I: 0 9 90000111 ¡; 'èj::[:.ô:'] 3:4' :4:" *.*************100.00* Amount : Void after 90 days ~~~~~i~ru J <f9rilmOu!Jt.Spver,$:25~OOO,OO . :., .. ..' ....'.- -." ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME \'--~\J ë) '-- CJ ~ CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) / DEVELOPMENT REDRILL PILOT. HOLE (PH) EXPLORATION ANNULAR DISPOSAL . L-) NO INJECTION WELL ANNULAR DISPOSAL L-) YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore 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(t), 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. . . ANNULU~ L:..J YES + SPACING EXCEPTION 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 perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ~u.0 ,,-.)~\o~ * ~~\<t~ 1>k~t'Ni:.V\..~ ~'" 4.."t\O~~ð,\ ~Q..l \ \((~ '. Templates are located m drive\jody\templates ~¿. , WELL PERMIT CHECKLIST COMPANY ¡JÁ-i//t'!- WELL NAME 2L -03 PROGRAM: exp - dev ,/ redrll- serv - wellbore seg _ann. disposal para req - FIELD & POOL i.fl°/L;{) INITCLASS ~l/ ¡niL- GEOLAREA t;Jf'lD UNIT# ~.J/ ¡lot) ON/OFF SHORE G~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . .IM . . . . . . . . . ~', N h -4' , 2. Le~se number appropriate?¥: ~. ~4c. ''-+:~/. I;'.-7'f::1. N ~ ;:f'-'-vf-~~- .~4 ,~e~_.. HL:>¿ ~gOé62-) ,ft~-?~ ~l~ vJ ~ 3. Unique well name and number... . . . . . . . . . . . . . . , N (. D r ¿t<... T/L/C 3~~~, Þ 4. W ell located in a defined pool.. . . . . . . . . . . . . . . , . N ., . /l ' ,. L> I( I . I / I / 1/,' ~ 5. Well located proper distance from drilling unit boundary. . . . .' N ¿L-ö3 tot I! ÞtL -/-i.L. t-/r.:;1- 4X-I C1 Y'-II(,¿,¿ 10 -(-t...L./'-L~rulL. ~ 67. Ws effi"l?catted properdi~ltabnlce.fr°d~ll~ther~tells.. . . . . . . . . :NN ;:¿L.-P&d. .4OC-;é.c- d!c>¿S A~ ~«-- a- fftudlD;{ ktrwL ~J ~( . U Clen acreage aval a e' In n ang Un! .. . . . . . . . . . . . I ' / / () . " 8. Ifdeviated,iswellbóreplatinduded.. . . . . . . . . . . . . . N OA.-f/;J6¡pCt<i (A!.-<::~¿»-Y'¡L0'-tV ,tL ~-:k... ~ ~ßÞlns ~,~ê.~'~n'-¿ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . . N d~ ~ J.-5.¿5 A..-~'¡ c.b~ Ií~LJ-~ i':r:'Þ7IÞ/ t.0u( ~r-/)? ,-h; oM.. --.;k. t.vU( , 10. Ope,,;,tor has ~ppropria!e bond in force.. . . . . . . . . . . . . N .j:,(e';) . - I<k, "-<-,0 [/ ~.!I .M<-9! ,é..I:kd ~.b +~ r,§ 5 ..f'r"""," 2£.-- 32-'7 ~~ '-'( 11. Permit can be Issued without conservation order. ....... ',N..fYÞ'nL z::/4.'O Iv (;,g(Ç{ ;"11p(;tJr;f-ÆC:<!:.- CÆ5¡"'lr!¡{O~ -f{r--¡..t....-!0 ffi-.--/J(¿.{J~ ",° APPR DATE 12. Permit ca~'be issued without administrativ~ approval.. . . . .N ..t.L-ò3 kr,'(( 6c.- 4¡1'..lf~ "'-jlC()1 7"Vþ ßt~r -{-t~ :z.L- 3~C¡. /~ ft'> /2. ,¡I.O I 13. Can permit be approved before 15-day walt.. . . . . . . . .. . Y N "'¿V16v r-e- -- ccú?\..f'(.¿j'{L ¡-¿c&-lrd'/ a... P11..L.d/ð<? ~ ..:5eLF""r~ tvl/( ~ . . f-<:-4. U 11~ P'?'L- '2 c- 0 3. 4,þ ¿1 . ENGINEERING 14. Conductor stnngproVlded . . . . . . . . .. . . . . . . . . . ~ N . {.) . 15. Surface casing protects all known USDWs. . .. . . . . . .. . Y N ~ \,) ~ '\) ~ ~ . 16. CMT vol adequate to drculate on conductor & suñ csg. . . . . N' "" . 17. CMTvoladequateto.tie-inlongstringtosurfcsg. . . . . . . . Y Œ) C>.~~'-.\\~~~\~~~c::.~\ 0\-\-\~Ct.\'I ~\~~,,~ù \::\ 18. CMT will COver all known productive horizons. . . . .'. . . .. '~ N ~C?LN-fr.......~ ~o\-..)~<è:. ~c)...'i "'~lt.~ ~c ~Q- 'r-..t:...~tL..~~ ~ <:'C~«~\C,),t""~ ~NJ~ 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N Q:..~'\~~\.......~ ~~ \ "Ù ~c:.~~ s?\~ . 21. If a re-drill, has a 1Q-403 for abandonment been approved. . . ~ N~ ...:> ~ ~ - ~ ~ 22. Adequate well bore separation proposed.. . . . . . . . . . . . N <-\('\':>Q:: Q..~,,~\N:::.~ \.C")Q:,~~\~,\<?,c.) ( ~\ ~" + ~~è:) C' '-\ ~ . 23. If diverter required, does it meet regulations. . . . . . . . . . N ~ ~ ~ 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ~\~-\ ~~ \.\ ~ç'--\\-.-.~ ~S. S COO ~~\ , 26. BOPE press rating appropriate; test to ~ (SOOt) psig. N '""'~ '::> 'Q <t..c:..\ ~ ~\ ~ \ ~\ , \"""~~~\ ~~~ C>..\>~ro\>\\Q~ " 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. . N ' , 28. Work will occur without operation shutdbwn. . . . . . . . . . . N '''"' " ~' <\ (' ~ \ ~ 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y <ID ""'.vC) ~\-..Ð0\c.J ~\1!:~\~cJtè 'v-\::>~~t'-~~. \l..,~~ (tCy'-.)"t~\>~d v-) 'S~,,~,,>+G),O~ 3D. Pennit can be issued w/o hydrogeri sulfide measures. . . .. Y1Ñ! r:,ff;¿-/ ú.><./I z m - 3:;' ¡",.,ied 2. "'-'-~ N£/ ~.:5 u,,¿J' 35 ~ hf s <2..64. 31. Data presented on potential overpressure zones. . . . . . . (Ÿ;,~ ~ J-e-"5ÇJ~r-IA-~¡r-,'j,.e.,s-:;.w,,~ ~ K...,~.,.dc.. C,..$a-J"'¿ ¡::,; //.. 7 í1(Jé.m4..r 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . . . . A~ .- APP,ß DATE. 33. Seabed condition survey [If off-shore). . . . . . . . . . . . . A Y N Æ() /z 'I/'D! 34. Contact name/phone for weekly progress reports [exploratpt'Ý only] Y N .; 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 AAC 25.252 or 20 MC 25.412. Y N GEO~Y: ENGINEERING: UIC~Annular COMMISSION: .. Comments/Instructions: ~Þfrl'.tr ~RW J, ./G "-'J\, WM 8?s I"'J ({ 101. .d~'D~ ( ~./-Þ,.r fVt.u..:7/ Óf?e~Lj ~/ ¿¿ IU ud /öð ~- ./.21 TEMPEl r~ IV I \";) ( (~ JMH ?jI1\\'l:" "(J1~ltì\ q r-[/r6¿¿l¡'L.¡{Jk~ {£)7'// ßL . ut æ¿ &-Ÿl --/.fM ~//, , ,'(j , .' ~ ~. DATE KJ;Y' rt.. 'J-{ \ ~ GEOLOGY APPR DATE Y N Y N ~~ 0\\"'I""-\..~~\'i \>\~~~~~~\~ \).JQ:\\.. ~~~ ~c...\~~~TI: 0\ ~\>\C~~~ ~~"<".~\~~C)\'d-L- . . . , -, .,,_.. c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z ( 0 -t ~ ::0 -t m Z -t :I: en » ( ::0 m » ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chrono'ogicaUy . ' organize this category of information. ) Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 16 10:31:32 2002 Reel Header Service name...I.......... LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS ) ð,o/-a3 (~ /0'655 Writing Library. Scientific Technical Services Tape Header Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name....... ........ . UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN C omme n t s . . . . . . . . . . . . . . . . . S T S LIS Physical EOF Comment Record TAPE 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: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: Writing Library. Scientific Technical Services MWD RUN 1 AK-MW-22024 B. ZIEMKE R. SPRINGER MWD RUN 4 AK-MW-22024 J. STRAHAN D. HEIM MSL 0) OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 2L-03 501032039800 Phillips Alaska, Inc. Sperry-Sun Drilling Services 16-MAY-02 MWD RUN 2 AK-MW-22024 J. STRAHAN R. SPRINGER 22 ION 7E 143 544 .00 144.60 117.10 CASING SIZE (IN) 16.000 9.625 7.000 MWD RUN 3 AK-MW-22024 J. STRAHAN R. SPRINGER DRILLERS DEPTH (FT) 110.0 3072.0 10753.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE ) ) NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4) . 4. MWD RUNS 2 AND 3 COMPRISED COMPENSTATED NEUTRON POROSITY (CNP), STABILIZED PRESSURE WHILE DRILLING (PWD) . DIRECTIONAL, DGR, EWR4, LITHO-DENSITY (SLD), AND 5. MWD RUN 4 COMPRISED DIRECTIONAL, DGR, EWR4, SLD, AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. DUE TO INITIAL PHILLIPS CONCERN FOR SOME OF THE RUN 4 POROSITY VALUES, THE CTN DATA WERE REPROCESSED USING THE SLD QUALITATIVE CALIPER DATA, INSTEAD OF THE NORMAL FIXED-HOLE-SIZE VALUE. ALTHOUGH SOME DIFFERENCES WERE OBSERVED IN REPROCESSED DATA, NO OBVIOUS PROBLEMS WERE DISCOVERED. BECAUSE THESE REPROCESSED VALUES ARE PROBABLY SOMEWHAT MORE ACCURATE, THEY ARE THE VALUES PRESENTED. 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 4/16/02, QUOTING AUTHORIZATION FROM GKA GROUP. 8. MWD RUNS 1, 2, 3, AND 4 REPRESENT WELL 2L-03 WITH API# 50-103-20398-00. THIS WELL REACHED A TOTAL DEPTH OF 11316'MD / 6376'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, SLD CALIPER) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECT OR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. ) ) PARAMETERS USED IN PROCESSING POROSITY LOGS: FIXED HOLE SIZE(CNP) : HOLE SIZE (CTN) : VALUES(6.125" BIT SIZE) MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX: MATRIX DENSITY: $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/05/16 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 RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 8.5" SLD CALIPER 9.6 - 12.2 PPG 400 - 800 PPM CHLORIDES 15000 PPM CHLORIDES 1.0 G/CM3 SANDSTONE 2.65 G/CM3 clipped curves; all bit runs merged. .5000 START DEPTH 55.5 100.5 100.5 100.5 100.5 100.5 110.5 2999.5 2999.5 2999.5 3072.0 3077.0 3077.0 STOP DEPTH 11261.5 11268.5 11268.5 11268.5 11268.5 11268.5 11316.0 11214.0 11214.5 11214.0 11228.5 11228.5 11228.5 # 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 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 55.5 3093.0 3434.0 10773.0 MERGE BASE 3093.0 3434.0 10773.0 11316.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction..... ..... .......Down Optical log depth units......... ..Feet Data Reference Point........... ...Undefined Frame Spacing................... ..60 .lIN Max frames per record........... ..Undefined Absent value...... ............. ...-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) ) Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 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 OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 55.5 11316 5685.75 22522 55.5 11316 ROP MWD FT/H 1.11 700.25 126.554 22412 110.5 11316 GR MWD API 12.92 439.86 113.966 22413 55.5 11261.5 RPX MWD OHMM 1. 05 2000 8.58085 22331 100.5 11268.5 RPS MWD OHMM 1. 02 2000 11.2563 22331 100.5 11268.5 RPM MWD OHMM 0.88 2000 19.4616 22331 100.5 11268.5 RPD MWD OHMM 0.92 2000 27.1422 22331 100.5 11268.5 FET MWD HOUR 0.21 91. 35 1. 66264 22331 100.5 11268.5 NPHI MWD PU-S 13.24 71.76 44.243 16430 2999.5 11214 FCNT MWD CNTS 104.4 1291 575.592 16431 2999.5 11214.5 NCNT MWD CNTS 2120 31931. 6 3780.05 16430 2999.5 11214 RHOB MWD G/CM 1. 823 3.241 2.35583 16171 3077 11228.5 DRHO MWD G/CM -0.102 0.935 0.045757 16171 3077 11228.5 PEF MWD BARN 0.57 19.35 2.72362 16181 3072 11228.5 First Reading For Entire File.. ... .... .55.5 Last Reading For Entire File...... .... .11316 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/16 Maximum 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 SUMMARY VENDOR TOOL CODE GR RPX RPS 2 header data for each bit run in separate files. 1 .5000 START DEPTH 55.5 100.5 100.5 STOP DEPTH 3039.0 3049.0 3049.0 ) RPD FET RPM ROP $ 100.5 100.5 100.5 110.5 3049.0 3049.0 3049.0 3093.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 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: # 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 TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ... ... ..........0 Data Specification Block Type. ....0 Logging Direction....... ......... . Down Optical log depth units......... ..Feet Data Reference Point..... ....... ..Undefined Frame Spacing.... ....... ...... ... .60 .1IN Max frames per record.. .......... .Undefined Absent value................. ... ..-999 Depth Units....................... Datum Specification Block sUb-type...O ,) 08-FEB-02 Insite 66.37 Memory 3093.0 110.0 3093.0 .3 62.8 TOOL NUMBER PB02440HGR8 PB02440HGR8 12.250 110.0 LSND 9.70 63.0 9.5 500 7.0 5.000 4.400 9.000 3.700 67.0 77.0 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 55.5 3093 1574.25 6076 55.5 3093 ROP MWDOI0 FT/H 1.11 298.28 129.61 5966 110.5 3093 GR MWDOI0 API 12.92 139.88 78.3647 5968 55.5 3039 RPX MWDOI0 OHMM 1. 05 597.04 19.151 5898 100.5 3049 RPS MWDOI0 OHMM 1. 02 269.7 28.72 5898 100.5 3049 RPM MWDOI0 OHMM 0.88 1905.3 48.8635 5898 100.5 3049 RPD MWDOI0 OHMM 0.92 2000 63.4785 5898 100.5 3049 FET MWDOI0 HOUR 0.21 3.51 0.620965 5898 100.5 3049 First Reading For Entire File......... .55.5 Last Reading For Entire File.......... .3093 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ....02/05/16 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name......... ... .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.. ... ..02/05/16 Maximum Physical Record..65535 File Type.. ............ ..LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2999.5 2999.5 2999.5 3039.5 3044.0 3044.0 3044.0 3044.0 3044.0 3071.0 3076.0 3076.0 3093.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 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 STOP DEPTH 3339.0 3339.0 3339.0 3391.5 3384.0 3384.0 3384.0 3384.0 3384.0 3348.5 3348.5 3348.5 3434.0 11-FEB-02 Insite 66.37 Memory 3434.0 3093.0 3434.0 ) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................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 Units....................... Datum Specification Block sub-type...O .J 61. 8 62.1 TOOL NUMBER PB02446HWRG6 PB02446HWRG6 PB02446HWRG6 PB02446HWRG6 8.500 3072.0 LSND 9.60 48.0 9.9 800 7.0 5.000 3.520 4.500 3.500 60.0 88.0 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2999.5 3434 3216.75 870 2999.5 3434 ROP MWD020 FT/H 5.95 320.15 156.372 682 3093.5 3434 GR MWD020 API 56.77 140.31 102.319 705 3039.5 3391.5 RPX MWD020 OHMM 2.43 2000 10.6531 680 3044 3384 RPS MWD020 OHMM 2.5 2000 12.7358 680 3044 3384 " ) RPM MWD020 OHMM 2.63 2000 22.424 680 3044 3384 RPD MWD020 OHMM 1. 51 2000 127.547 680 3044 3384 FET MWD020 HOUR 0.21 79.82 12.4128 680 3044 3384 NPHI MWD020 PU-S 27.14 64.54 50.3171 680 2999.5 3339 FCNT MWD020 CNTS 402 694 502.406 680 2999.5 3339 NCNT MWD020 CNTS 2192 3026 2435.93 680 2999.5 3339 RHOB MWD020 G/CM 1. 946 2.456 2.15068 546 3076 3348.5 DRHO MWD020 G/CM -0.008 0.117 0.0371722 546 3076 3348.5 PEF MWD020 BARN 1. 81 9.42 3.30223 556 3071 3348.5 First Reading For Entire File......... .2999.5 Last Reading For Entire File.......... .3434 File Trailet Service name............ .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/05/16 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name... ."'."" .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...02/05/16 Maximum Physical Record..65535 File Type........ ....... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF DRHO RHOB RPD RPX RPS RPM FET GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 3339.5 3339.5 3339.5 3349.0 3349.0 3349.0 3384.5 3384.5 3384.5 3384.5 3384.5 3392.0 3434.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 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: # STOP DEPTH 10678.0 10678.0 10678.0 10687.0 10687.0 10687.0 10723.0 10723.0 10723.0 10723.0 10723.0 10730.0 10773.0 17-FEB-02 Insite 66.37 Memory 10773.0 3434.0 10773.0 59.7 62.1 ,) TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type.. ...0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point....... ..... ..Undefined Frame Spacing............. ..... ...60 .1IN Max frames per record..... ....... .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER PB02446HWRG6 PB02446HWRG6 PB02446HWRG6 PB02446HWRG6 8.500 3072.0 LSND 9.60 44.0 10.0 500 3.0 3.750 1.760 4.500 3.100 62.0 140.0 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3339.5 10773 7056.25 14868 3339.5 10773 ROP MWD030 FT/H 2.68 700.25 129.466 14678 3434.5 10773 GR MWD030 API 39.88 439.86 128.943 14677 3392 10730 RPX MWD030 OHMM 1.18 37.18 4.09738 14678 3384.5 10723 RPS MWD030 OHMM 1. 21 32.05 4.16047 14678 3384.5 10723 RPM MWD030 OHMM 1. 28 28.47 4.35418 14678 3384.5 10723 RPD MWD030 OHMM 1.3 26.89 4.50501 14678 3384.5 10723 FET MWD030 HOUR 0.24 9.83 0.866911 14678 3384.5 10723 ) , NPHI MWD030 PU-S 13.24 71.76 44.3247 14678 3339.5 10678 FCNT MWD030 CNTS 433 1291 601.921 14678 3339.5 10678 NCNT MWD030 CNTS 2120 3942 2645.94 14678 3339.5 10678 RHOB MWD030 G/CM 1. 823 3.241 2.35575 14677 3349 10687 DRHO MWD030 G/CM -0.042 0.935 0.0451988 14677 3349 10687 PEF MWD030 BARN 0.57 6.64 2.40337 14677 3349 10687 First Reading For Entire File.. ....... .3339.5 Last Reading For Entire File.......... .10773 File Trailer Service name....... ..... .STSLIB.004 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .02/05/16 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT RPM RPS RPD FET RPX GR PEF RHOB DRHO ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10678.5 10678.5 10678.5 10726.5 10726.5 10726.5 10726.5 10726.5 10730.5 10754.0 10754.0 10754.0 10773.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 11214.0 11214.5 11214.0 11268.5 11268.5 11268.5 11268.5 11268.5 11261. 5 11229.5 11229.5 11229.5 11316.0 22-FEB-02 Insite 66.37 Memory 11316.0 10773.0 11316.0 61.1 64.2 TOOL NUMBER PB02466HAGR4 ) EWR4 SLD CTN $ ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ....... .... ..0 Data Specification Block Type.....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 Specification Block sUb-type...O ) PB02466HAGR4 PB02466HAGR4 PB02466HAGR4 6.125 10753.0 LSND 12.20 55.0 9.5 700 2.8 3.100 1. 530 3.250 4.000 72.0 152.6 72 .0 73.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 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 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10678.5 11316 10997.3 1276 10678.5 11316 ROP MWD040 FT/H 1.12 350.59 51.6862 1086 10773.5 11316 GR MWD040 API 56.88 212.75 114.763 1063 10730.5 11261. 5 RPX MWD040 OHMM 1. 73 133.55 10.4749 1085 10726.5 11268.5 RPS MWD040 OHMM 1.96 350.98 11.426 1085 10726.5 11268.5 RPM MWD040 OHMM 2.34 2000 62.6428 1085 10726.5 11268.5 RPD MWD040 OHMM 2.4 2000 85.6525 1085 10726.5 11268.5 FET MWD040 HOUR 0.56 91. 35 12.0379 1085 10726.5 11268.5 NPHI MWD040 PU-S 17.63 60.83 39.2722 1072 10678.5 11214 FCNT MWD040 CNTS 103.98 792.26 261. 822 1073 10678.5 11214.5 NCNT MWD040 CNTS 13499.2 31939.8 20161. 5 1072 10678.5 11214 ) ') RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN 1. 999 -0.102 4.84 3.163 0.493 19.35 2.47417 0.0585672 7.31654 952 952 952 10754 10754 10754 11229.5 11229.5 11229.5 First Reading For Entire File........ ..10678.5 Last Reading For Entire File........ ...11316 File Trailer Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/16 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name..... ....... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number. .... .01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File