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Home My WebLink About202-043David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/27/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL T20260127 WELL: KTU-32-07H PTD: 202-043 API: 50-133-220511-00-00 SFTP – Folder Name: SFTP - Data Files: Please include current contact information if different from above. 202-043 T41291 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.27 14:09:32 -09'00' 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: CTCO, N2 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): 11,857' N/A Casing Collapse Structural Conductor Surface 2.260psi Intermediate 3,090psi Production 5,410psi Liner N/A (Slotted 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 stefan.reed@hilcorp.com 206-518-0400 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Stefan Reed, Operations Engineer AOGCC USE ONLY N/A (Slotted Liner) Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 202-043 50-133-20511-00-00 Hilcorp Alaska, LLC Proposed Pools: 139' 139' 6.4# / L-80 TVD Burst 7,383' 7,240psi 1,517'1,517' Size 9-5/8"6,526' 1,517' MD Perforation Depth MD (ft): 6,526' 4-1/2" See Attached Schematic 5,750psi 5,020psi 6,503' 9,329' Length February 4, 2026 11,764'2,160' 2-7/8" 8,740' 139' 20" 9,435' Kenai Beluga/Up Tyonek Gas 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Tyonek Unit (KTU) 32-07HCO 510C Same 8,678' 7" ZXP, 6,279' MD / 6,272' TVD, Baker Premier & Baker FH Pkrs; N/A 9,295' MD / 8,610' & 7,317' MD / 7,098' TVD; N/A 8,742' 9,319' 8,622' 7" ~1,908psi 3,136' m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:54 pm, Jan 23, 2026 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2026.01.23 12:26:17 - 09'00' Noel Nocas (4361) 326-047 DSR-1/27/26TS 1/26/26 X CT BOP test to 3500 psi BJM 1/27/26 10-404 JLC 1/28/2026 01/28/26 CTCO/PERF CTCO/PERF Well: KTU 32-07H Well Name: KTU 32-07H API Number: 50-133-20511-00-00 Current Status: Producing Gas Well Permit to Drill Number: 202-043 First Call Engineer: Stefan Reed (907) 777-8433 (O) (206) 518-0400 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Max Expected BHP: ~2,750psi @ 8,425 TVD (from PT Survey) Max Potential Surface Pressure: ~1,908psi (0.1psi/ft gas gradient) Applicable Frac gradient: 0.71 psi/ft using LOT from 4/3/2002 Shallowest Perf Depth: 1,908psi/(0.71-0.1) = 3,218 TVD Top of Pools per CO 510C: Top of Beluga/Upper Tyonek is 4,674 MD (4,673 TVD) Brief Well Summary KTU 32-07H was drilled in 2002 as a Tyonek D-1 horizontal producer. Unlike the offset horizontal D-1 producer, KTU 24-06H, KTU 32-07H never flowed to the D-1 potential. Never flowing above 0.3 MMSCFD. In 2014 the D-1 was plugged off and a RWO executed to complete the well to its current 2-7/8 tubing/packer configuration. Perforations were added in the Upper Tyonek sands and the well has remained on as a steady producer with a ~10% decline. Recently rate has declined significantly, and the well is currently producing ~ 400MSCFD. The purpose of this work/sundry is to perform a coil tubing clean out and add perforations/reperforate sands in the Beluga/Upper Tyonek Gas Pool. Notes Regarding Wellbore Condition 11/20/2025: Slickline flowing PT Survey to 8,985 12/10/2025: Slickline drift w/ 2x 20 to 8,989. 2 bailer to 8,991 thick mud. Coil Clean Out Procedure 1. MIRU Coil Tubing 2. Test BOPs to 250psi low/3,500psi high a. Provide 24-hour notice to AOGCC for witness 3. MU/RIH with clean out nozzle assembly 4. Clean out well as deep as possible using N2/foam. a. If unable to get returns to surface, discuss with OE 5. Circulate out fluid w/ N2 6. Pressure up well to ~2,000psi w/ N2 7. RDMO Eline Procedure 8. MIRU Eline 9. PT PCE 250psi low /2,500psi high 10. Ops bleed N2 from well as directed by OE/RE for desired perforating pressure by zone (typically targeting 20% underbalance) 11. Perforate proposed intervals bottoms up per table below: CTCO/PERF CTCO/PERF Well: KTU 32-07H Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sands Top MD Btm MD Top TVD Btm TVD FT TY 72-8 ± 7,500 ±7,510 ±7,229 ±7,237 ±10 TY 73_2 ±7,587 ±7,596 ±7,292 ±7,299 ±9 UT 1A ±7,615 ±7,627 ±7,313 ±7,321 ±12 UT 1B ±7,752 ±7,781 ±7,417 ±7,440 ±29 TY 75-8 ±7,878 ±7,907 ±7,518 ±7,542 ±29 TY 78-2 ±8,215 ±8,244 ±7,806 ±7,831 ±29 TY 84-6 ±8,989 ±9,031 ±8,426 ±8,454 ±42 12. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Record initial and 5/10/15 minute tubing pressures after firing b. Reperf any zones per RE/GEO discretion. c. Pending well production, all perf intervals may not be completed d. If necessary, use nitrogen to pressure up well during perforating e. Above perfs will be shot in the Beluga/Upper Tyonek governed by CO 510C 13. RD E-Line Unit and turn well over to operations for production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil BOP Schematic 4. Standard Nitrogen Procedure All existing perfs and existing horizontal liner are in the Bel/Upper Tyo Gas pool per email from Stefan Reed 1/27/26. -bjm Perforation Detail (Proposed Perforation Depths are Open Hole) Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status 7,470' 7,504' 7,208' 7,232' 34 09/28/14 Open 7,690' 7,730' 7,369' 7,400' 40 09/28/14 Open 7,834' 7,852' 7,483' 7,497' 18 09/28/14 Open 7,908' 7,922' 7,543' 7,555' 14 09/27/14 Open 8,008' 8,046' 7,628' 7,660' 38 09/27/14 Open 8,150' 8,180' 7,750' 7,776' 30 09/27/14 Open 8,993' 9,033' 8,429' 8,456' 40 09/27/14 Open 9,945' 9,975' 8,725' 8,726' 30 03/24/03 Closed 11,545' 11,575' 8,734' 8,735' 30 03/21/03 Closed State/Prov:Alaska Country:USA 66.0' 9/22/2014 Date Completed:9/21/2014 Ground Level (above MSL):RKB (above GL):21' Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date:10/16/2014 Angle @KOP and Depth:0.5º @ 5,800'Angle/Perfs:30º to 50ºMaximum Deviation:92.5º @ 10,676' Tyonek 75-8 Tyonek UP1D Tyonek UP1C Lease:A - 028142 County or Parish:Kenai Peninsula Borough Sand Tyonek D-1 Tyonek D-1 Well Name & Number:Kenai Tyonek Unit 32-07H Tyonek 72-8 Tyonek 84-6 Tyonek 78-2 Tyonek 76-7 Drive Pipe 20" K-55 133 ppf 139' MD Surface Casing 13-3/8" L-80 68 ppf BTC @ 1,517' Cmt w/ 614 sks Casing 9-5/8" L-80 40 ppf BTC @ 6,526' Cmt w/ 625 sks 7" ZXP liner top packer @ 6,279' 7" HMC liner hanger @ 6,299' ID = 6.187" TD: (6-1/8" open hole) 9,435' - 11,857' Tubing: 2-7/8", 6.4 ppf, L-80, EUE-8RD 1 - Chemical Injection @ 2,058' Live Valve installed 9/22/14 Splice @ 64' (32 bands on 1/4" line) 2 - Gaslift Mandrel @ 7,237' Dummy Valve installed 9/21/14 3 - FH Packer @ 7,317' (30K shear) 4 - X Profile @ 7,338'. 2.313" ID 5 - WLEG @ 7,383' 6 - Baker Premier packer @ 9,295' 7 - Composite BP @ 9,329' Dumped 10' of cement on top 8 - X-nipple @ 9,350' ID = 3.813" 4-1/2" Slotted Liner, 9,604' - 11,764' 12.6 ppf, L-80, IBT-M w/ 1/4" vertical slots Packoff bushing @ 11,764' ID = 2.375" API: 50-133-20511-00 AOGCC: 202-043 RT-GL: 21.00' RT-THF: 20.15' Surface: 79' FNL, 4325' FWL Sec. 7, T4N, R11W, S.M. Tree cxn: 4-3/4" Otis Lift Thds: 4.909" MCA Directional Data KOP: 5,850' Hole angle at 7" shoe = 61 deg Max. Doglegs: 9,489' - 9,583', 26.7 deg/100 ft 6,683' - 6,746', 8.1 deg/100 ft 8,443' - 8,506', 7.0 deg/100 ft Note:Frequently have excess drag in the severe dogleg area at 9,500'. See Kenai Tyonek Unit 32-7H Pad 41-7 79' FNL, 4,325' FEL, Sec. 7, T4N, R11W, S.M. Liner 7" L-80 26 ppf BTC @ 6,299' - 9,435' Cmt with 1300 sks SCHEMATIC 1 UP1C 3 4 5 72-8 UP1D 75-8 76-7 78-2 84-6 2 76 8 Perforation Detail (Proposed Perforation Depths are Open Hole) Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status 7,470' 7,504' 7,208' 7,232' 34 09/28/14 Open ± 7,500 ±7,510 ±7,229 ±7,237 ±10 TBD Proposed ±7,587 ±7,596 ±7,292 ±7,299 ±9 TBD Proposed ±7,615 ±7,627 ±7,313 ±7,321 ±12 TBD Proposed 7,690' 7,730' 7,369' 7,400' 40 09/28/14 Open ±7,752 ±7,781 ±7,417 ±7,440 ±29 TBD Proposed 7,834' 7,852' 7,483' 7,497' 18 09/28/14 Open ±7,878 ±7,907 ±7,518 ±7,542 ±29 TBD Proposed 7,908' 7,922' 7,543' 7,555' 14 09/27/14 Open 8,008' 8,046' 7,628' 7,660' 38 09/27/14 Open 8,150' 8,180' 7,750' 7,776' 30 09/27/14 Open ±8,215 ±8,244 ±7,806 ±7,831 ±29 TBD Proposed ±8,989 ±9,031 ±8,426 ±8,454 ±42 TBD Proposed 8,993' 9,033' 8,429' 8,456' 40 09/27/14 Open 9,945' 9,975' 8,725' 8,726' 30 03/24/03 Closed 11,545' 11,575' 8,734' 8,735' 30 03/21/03 Closed State/Prov:Alaska Country:USA 66.0' 9/22/2014 Tyonek 78-2 Tyonek 72-8 Tyonek 73-2 UT 1A Date Completed:9/21/2014 Ground Level (above MSL):RKB (above GL):21' Revised By:S. Reed Downhole Revision Date:Schematic Revision Date:1/19/2026 Angle @KOP and Depth:0.5º @ 5,800'Angle/Perfs:30º to 50ºMaximum Deviation:92.5º @ 10,676' Tyonek 75-8 Tyonek UP1D Tyonek UP1C Lease:A - 028142 County or Parish:Kenai Peninsula Borough Tyonek 84-6 UT 1B Tyonek 75-8 Sand Tyonek D-1 Tyonek D-1 Well Name & Number:Kenai Tyonek Unit 32-07H Tyonek 72-8 Tyonek 84-6 Tyonek 78-2 Tyonek 76-7 Drive Pipe 20" K-55 133 ppf 139' MD Surface Casing 13-3/8" L-80 68 ppf BTC @ 1,517' Cmt w/ 614 sks Casing 9-5/8" L-80 40 ppf BTC @ 6,526' Cmt w/ 625 sks 7" ZXP liner top packer @ 6,279' 7" HMC liner hanger @ 6,299' ID = 6.187" TD: (6-1/8" open hole) 9,435' - 11,857' Tubing: 2-7/8", 6.4 ppf, L-80, EUE-8RD 1 - Chemical Injection @ 2,058' Live Valve installed 9/22/14 Splice @ 64' (32 bands on 1/4" line) 2 - Gaslift Mandrel @ 7,237' Dummy Valve installed 9/21/14 3 - FH Packer @ 7,317' (30K shear) 4 - X Profile @ 7,338'. 2.313" ID 5 - WLEG @ 7,383' 6 - Baker Premier packer @ 9,295' 7 - Composite BP @ 9,329' Dumped 10' of cement on top 8 - X-nipple @ 9,350' ID = 3.813" 4-1/2" Slotted Liner, 9,604' - 11,764' 12.6 ppf, L-80, IBT-M w/ 1/4" vertical slots Packoff bushing @ 11,764' ID = 2.375" API: 50-133-20511-00 AOGCC: 202-043 RT-GL: 21.00' RT-THF: 20.15' Surface: 79' FNL, 4325' FWL Sec. 7, T4N, R11W, S.M. Tree cxn: 4-3/4" Otis Lift Thds: 4.909" MCA Directional Data KOP: 5,850' Hole angle at 7" shoe = 61 deg Max. Doglegs: 9,489' - 9,583', 26.7 deg/100 ft 6,683' - 6,746', 8.1 deg/100 ft 8,443' - 8,506', 7.0 deg/100 ft Note:Frequently have excess drag in the severe dogleg area at 9,500'. See Kenai Tyonek Unit 32-7H Pad 41-7 79' FNL, 4,325' FEL, Sec. 7, T4N, R11W, S.M. Liner 7" L-80 26 ppf BTC @ 6,299' - 9,435' Cmt with 1300 sks PROPOSED 1 UP1C 3 4 5 72-8 UP1D 75-8 76-7 78-2 84-6 2 76 8 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 McLellan, Bryan J (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, January 27, 2026 3:39 PM To:'Stefan Reed' Cc:Starns, Ted C (OGC); McKensie Neely Subject:RE: [EXTERNAL] KTU 32-07H (PTD 202-043) pools Stefan, Just checking to see if multiple pools would be open in this well. No need to estimate depth of Tyo Gas Pool 1 top since its below this well and cant comingle. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Tuesday, January 27, 2026 3:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; McKensie Neely <mckensie.neely@hilcorp.com> Subject: Re: [EXTERNAL] KTU 32-07H (PTD 202-043) pools Bryan, All perforations will be in the Beluga/Upper Tyonek Gas Pool, no commingled production. Top of pool is 4,674 MD/4,673 TVD. The D1 lateral that is plugged off is also in the Beluga/Upper Tyonek Gas Pool. This well did not go below the D1 when drilled so we don't have an exact top for the Tyonek Gas Pool 1, but can estimate if needed. Thank you. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC 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. 2 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, January 27, 2026 3:15 PM To: Stefan Reed <stefan.reed@hilcorp.com> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL] KTU 32-07H (PTD 202-043) pools Stefan, After the cleanout and re-perf, will multiple pools be open to comingled production? What is the TVD depth of the base of the Beluga/Upper Tyonek Gas pool in this well? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/14/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240314 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL BRU 221-35 50283201930000 223077 11/18/2023 AK E-LINE Perf HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL IRU 41-01 50283200880000 192109 11/16/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 1/16/2024 AK E-LINE GPT/Perf KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF KU 3-06A 50133207160000 223112 1/12/2024 AK E-LINE CBL KU 21X-32 50133202040000 169100 12/8/2023 AK E-LINE JetCut MPU CFP-02 50029212580000 184242 3/9/2024 READ CaliperSurvey NCI A-18 50883201890000 223033 12/8/2023 AK E-LINE Perf/GPT NIA NK-18 50029224210000 193177 12/13/2023 AK E-LINE IPROF PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf TBU M-15 50733204220000 190109 2/7/2024 AK E-LINE GPT/Perf Please include current contact information if different from above. T38615 T38615 T38616 T38617 T38618 T38619 T38620 T38621 T38622 T38623 T38624 T38625 T38626 T38627 T38628 KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -08'00' • Kra_ 32-c?t4 • PthZOZ0430 Regg, James B (DOA) From: Christopher Walgenbach <cwalgenbach@hilcor om> Sent: Wednesday, April 18, 2018 9:51 AM '( 4/i€:f re To: Regg,James B (DOA) l 1 Subject: Re: Kenai Gas Field The function test is complete. Thank You Jim Chris Sent from my iPhone On Apr 18, 2018, at 9:42 AM, Regg,James B (DOA) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov»wrote: With a function test of all components on KTU 32-07H; I will grant a waiver for the required performance test since the semi-annual pad tests will occur in a week. This should not be construed to be a blanket approval for future similar situations. Jim Regg Supervisor, Inspections AOGCC SCANNED 333 W.7th Ave, Suite 100 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<mailto:jim.regg@alaska.gov>. From: Christopher Walgenbach <cwalgenbach@hilcorp.com<mailto:cwalgenbach@hilcorp.com» Sent:Tuesday,April 17, 2018 11:00 AM To: Regg,James B (DOA) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov» Cc: Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov<mailto:phoebe.brooks@alaska.gov»; Chad Johnson <chjohnson@hilcorp.com<mailto:chjohnson@hilcorp.com»; Larry Greenstein <Igreenstein@hilcorp.com<mailto:Igreenstein@hilcorp.com» Subject: Kenai Gas Field Jim, We changed out the SSV and wing valve on KTU 32-07H yesterday. In the next few days we will formally submit for the semi-annual AOGCC witness testing on dates April 25th and 26th. Would you prefer we include the KTU 32-07H SSV in that testcycle rather than submit for it now? 1 • Thanks, Chris Walgenbach Production Foreman South Kenai Asset Team Hilcorp Alaska LLC Office 907-283-1382 Cell 907-690-1727 2 • Marathon MARATHON Oil Company May 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7~h Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List ~ ~ ~~~, _~ ~. ,~ ~ 5-'' } ~ ~ ~`~~ ~ ~ `~ ~ ~ ~ ~ ;~~~ ' ` ';~ A ~~' ~ A,~ ~ ~ 2008 ~arathon Oil Company Aiaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Co~s. C~~~is~~~~ ~~I~s~a Oi1 ~ ~chor~~ ~e~- a ~h~SE~c ~~. ~v ~~+r~ t~~ S~c~ ~ , ~ ~- ~ ~ ~ ~ ~ ~~ `~ e~~~ ~ ~ 5 ~~ ~ ~~~5~ ~~`? ~~~~s~~j~F ~v ~°~- ~r~S~~'T Cs.~C..OreJe~ ~.~ ~e Dear Mr. Maunder. ~~~~~ `~~ ~~ ~C1 ~` ~ e~J ~~- ~ Marathon and the AOGCC have had discussions on the follow-up reporting needed to close out 10-403 Sundry approved well work activities. Work has been ongoing to ~/~~a'~~ identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, .~~ ~Q~~ Kevin J. Skiba Engineering Technician , r. .>~:~~~~~~~~~k~' ~+~~:r ~~ '~ ~~~~ Enc(osures: 10-404 Sundry Submittai List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon MARATHON Oil Company January 23, 2008 ~~~~1~~ MAY ~ ~ Zn08 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Al~ska Oif & Gas C~~~, ~;~mmissioi~ Anchora~e Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KTU 32-7H Dear Mr. Maunder: Attached for your records is the 10-404 sundry report for well KTU 32-7H. This sundry covers the acid stimulation of the horizontal section of well KTU 32-7H. The work was completed under sundry #303-044. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~ Wayne . Cissell Well Work Over Supervisor - Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File KJS KDW STATE OF ALASKA y~~ ALAS~IL AND GAS CONSERVATION COMMI~N " 'MAY 1.01 V C U T 6 2008 REPORT OF SUNDRY WELL OPERATIONSA~~~~ ~~~ ~ ~as Cons. Comrnission Anchoraae 1. Operations Abandon Repair Well Plug PerForations Stimulate ~- Other PerFormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ^ PerForate ^ Re-enter Suspended Well ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development Q Exploratory^ 202-043 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20511-00 7. KB Elevation (ft): 9. Well Name and Number: 8T KTU 32-7H ~ 8. Property Designation: 10. Field/Pool(s): _ ~"ED A-028142 Kenai Gas Field/ Tyonek 11. Present Well Condition Summary: Acid Stimulate horizontal section Total Depth measured 11857 - feet Plugs (measured) N/A true vertical g~42 - feet Junk (measured) N/A Effective Depth measured 11,807' feet true vertical g,74~' feet Casing Length Size MD TVD Burst Collapse Structural 139' 20" 139' 139' Conductor Surface 1517' 73-3/8" 1577' 1577' 3090 psi 1540 psi Intermediate Production 6526' 9-5/8" 6526' 6503' S750 psi 3090 psi Liner 3136' 7" 9435' 8677' 6340 psi 3830 psi Perforation depth: Measured depth: No aerforations. Slotted liner in open hole 9604' -11.764' True Vertical depth: No perforations. Slotted liner in open hole 8717' - 8740' Tubing: (size, grade, and measured depth) 4-1/2" L-80 9604' -11,764' Packers and SSSV (type and measured depth) Baker Premier Packer 9295' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Horizontal section treated at depth 9604' - 11,764' Treatment descriptions including volumes used and final pressure: 179 bbl 7.5% HCL, Well head pressure 0 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 150 0 0 psi 700 psi Subsequent to operation: 0 N/A 0 0 psi 0 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: ' 303-044 j Contact Kevin Skiba (907) 283-1371 Printed Name ayne E. Cissell G Title W~II Work Over Supervisor Signature \ Phone (907) 283-1308 Date 01I23/2008 Form 10-404 Revised 04/2006 ~ ~" ~~~ JLI~ ~+~ 200q ~,~~ SubmitOriginal Only U Operational Details for WeIL• KENAI TYONEK UNIT 32-7H Report Rept # From To Hours Phase Activity Sub Status Date Activity 02/19/03 12 08:00 16:00 8.00 STIM CLTBG RURD AF 02/20/03 13 08:00 16:00 8.00 STIM CLTBG RURD AF 02/21/03 14 07:00 07:30 0.50 STIM SAFETY SMTG AF 02/21/03 14 07:30 13:00 5.50 STIM CLTBG RURD AF ~ T Type Operations 02/21/03 14 13:00 16:30 3.50 STIM CLTBG RICT TA FLDS 02/21/03 14 16:30 19:45 3.25 STIM CLTBG JETw AF 02/21/03 14 19:45 21:15 1.50 STIM CLTBG JET AF ~ 02/21/03 14 21:15 22:45 1.50 STIM CL~BG JET MIRU 1-3/4" coil tubing unit and nitrogen pump. RU flowback iron. Also MIRU acid tanks and KCI tank. SDFN. Finish RU coil tubing and nitrogen unit. Test BOPE and flowback iron to 250/4000 psi. Blend 179 bbl of 7.5% HCI acid in poly tanks. Blend 300 bbl of 6% KCI. Conduct prejob operations and safety meeting at KGF office. NU injector head. Pickle coil tubing with 7 bbl of 7.5% HCI and displace with 17 bbl of 6% KCI and nitrogen. Return lines froze off - thaw return lines. ND injector head, MU Rotojet tool. Rotojet is equipped with 45-deg upward noules and set for low-impact washing. NU injector head, test to 4000 psi. RIH. SITP = 2245 psi. Reach 11,700' with no difficulty. CDT (1 hr), thought we were pumping acid but pump never caught prime. Began pumping acid down coii tubing at 1.0 bpm. Pump pressure = 2150 psi, wellhead = 2350 psi. Once acid turned the corner, POOH at 15 fpm while circulating acid at 1.0 bpm through Rotojet nozzle. Reduce wellhead pressure at surFace while laying in acid, but wellbore pressure is building continually while laying in acid (squeeze pressure). Getting neglible increase in drag while circulating acid. Pump pressure = 3200 psi, wellhead = 3200 psi after pumping 179 bbl of acid. Displace acid with 3 bbl of 6% KCI and nitrogen at 1000 scfm. Once all liquid was displaced from the ~il, reduce nitrogen rate to 750 scfm and RIH jetting at 25 fpm. Get first liquid returns shortly after displacing acid. Return pH is 0, adding soda ash to neutralize the return fluid. AF Reach 11,700' without any difficulty. Catch several flowback samples, showing minimal solids content. No indications of washing or tagging fill with RIH. Pump pressure = 2300 psi and falling continuously. Wellhead pressure steady at 700 psi. POOH jetting with coil at 750 scfm. ~ 02/21/03 14 22:45 00:30 1.75 STIM CLTBG POCT AF 02/21/03 14 00:30 01:30 1.00 STIM CLTBG RURD AF 02/21/03 14 01:30 06:00 4.50 STIM FLOW WELL AF 02/22/03 15 06:00 10:00 4.00 STIM FLOW WELL AF 02/22/03 15 10:00 14:00 4.00 STIM FLOW WELL AF ~ Reach 9600', and pump pressure has leveled off at 1525 psi, and volume of returns roughly equals volume pumped. Cease pumping nitrogen. POOH allowing well to continue to unload. Wellhead pressure = 575 psi. ND and stand back injector head. Well flowing with less than 100 psi wellhead pressure. Not carrying any fluid independently. Produce well overnight. Wellhead pressure = 25 psi, not carrying any fluid to surface. Flow well to open-top tank. FTP = 25 psi, has not brought up any fluid independently. Shut-in to allow pressure to build. Release flowback hands. Pad operator will produce to system afterpressure builds. Haul off neutralized acid for disposal. Clean solids out of diffuser tank. e e ~\ ..., . ..........u;'..... ". ,~. <', '. ... ,.,', MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~serFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) , ) Alaska Asset Team Northern Business Unit , , M MARATHON ~ Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-296-3397 May 9, 2005 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7tb Avenue, Suite 100 Anchorage, AK 99501 CERTIFIED MAIL RE: Marathon Oil Company KTU 32-7H CONFIDENTIAL Dear Mr. Oakland: Confidential digital data for the above referenced well is enclosed. ,/' , \""')~) ~, J The CD contents are listed below: ~ Combined.PDS ~Combined .zip lm KTU #32-7HLIS.dlis l!) KTU 32-7H.LAS ~ Main Log_USI_CBT _017LUP.DLIS ~ USI_CBT _017LUP .Ias ~USI_ CBT _017LUP .zip ~ Marathon Enhanced processing.dpk Directional Survey directory: l!) ktu_32-7h_tvd_dir _sur .Ias S~NEI) NO\) \) ß 2005 Mud Log\Database directory: ¡g¡ Ktu327h. dbf ¡g¡ KTU327H.hdr it KTU327H.mdx ~ KTU327H_SCL.DBF ~ KTU327H_SCL.MDX ~ KTU327H_TVD.DBF ~ KTU327H_TVD.MDX ~ KTU327HR.DBF ~ KTU327HR.MDX ~ MFCC321. TMP ~ MFCC3B2.TMP ~ MFCD032. TMP ~ MFCDOF4. TMP Mud Log\LAS Data directory: ~ KTU32-7H.las 1'~tJ?--e'1) Fv1~ t, .... - -- ) Marathon KTU 32-7H Data Transmittal May 9, 2005-05-11 Page 2 ) Mud Log/Moming Reports directory: ;f)20020322.htm i}20020323.htm :t)20020324.htm f20020325.htm 4)20020326.htm 4120020327.htm ;f)20020329.htm .¡) 20020403. htm 4120020404.htm i:!20020405.htm ;,f]20020407.htm ;f)2002040B.htm i)20020409.htm ~20020411.htm -I'!20020413.htm i')20020414.htm i)20020415.htm 4)20020416.htm i}20020417.htm ij2002041B.htm 4'j20020419.htm i!20020420.htm >Í.120020421.htm <t)20020422.htm j)20020423.htm i)20020424.htm <l)20020425.htm :l)20020426.htm ~ 20020427 .htm <l)2002042B.htm i!20020430.htm i'!20020501.htm .t)20020503.htm i 20020504 ,htm ;@)20020506.htm 4120020507,htm iÏ)2002050B.htm 4'J 20020509, htm 4120020510.htm <t)20020511,htm ci) 20020512, htm :t)20020513.htm ;f) 20020514, htm Mud Log/Remarks directory: g KTU32-7H Remðrks.txt Mud Log/W ell Report directory: l@:}KTU32-7H Finðl Report. doc Please sign and return confirming you have received this data. Thank you, ;(~~ Kaynell Zeman Geological Technician Enclosure "-o~' Î~r- /;2... t~ \~ \J""~"'" DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 .Sf7(.)J Ie; f1A.~Ö~Á API No. 50-133-20511-00-00 Permit to Drill 2020430 Well Name/No. KENAI TYONEK UNIT 32-07H Operator MARATHON OIL CO MD 11857.......·· TVD 8742 ./:.. Completion Date 5/20/2002 ,....-. Completion Status 1-GAS _'~~_'__"_".__"___"" ____.,,_,. _·________·__,·___~_R___·______·_·_··_·__·,_··_···_'_·,'_.~_.__,_..~.___.____~..__.__..___"___,________ __~_____.___._._.."_.M______._.__.,._"...._._ M..__R_..____·_···____·_____M__...._ REQUIRED INFORMATION Mud Log No Samples No _._._.._.__..~-_._._'.,-~.,.,._--~-~_._-,.---.-._--------_.,- _,,__._. ___....____.__n...____. _.._-,.,.,~~..__.__..._._.,_.._-,-_.._.__.'._-,--,-,_.-"--" --~.._,-,_.__._-----,,--_._~.._..._,_..-_.'....-._.,_.-..--.,--" ..~._,.,._,..,-_._-_.,----_.._-_._.._._....._.__._.__.-..--.-.,-. ""~._~- . . - -. -,-",-,.,..-...,. -..,-.....--...-.. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? "r-t-M-- Current Status 1-GAS UIC N ---.--.--. -~---_._---.-~-- ----_.~_._-_.._.,---_.__.__._.__. -.-.. ..~.,_._"',.. .__._.._..._-~_._~_.- ... .__________.____"'·_..M...·__·__.."_.....___,_.~·___·_ ¡1 (~ \ /;v\..... V"". Directional Survey Yes j) lIef M ....._...-._._.._--===.::::::::.:::.:.::::=:::::::=.-.:::-.=:::::::::::.::::::=:.::~l.~:::~.·:.:::: ~ .._-----_...._~----_.,---_._-_..._----- (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments Received Sample Set Number Comments Formation Tops Daily History Received? ØiN t!JN Analysis 'Yï-rïf' Received? _._------_._,,_._.._.._-_._-----~----------_._- _._~._------..__.. ----...--..-.- .- --...-....- ---.------..,------ ----..-- ---. -'-"'--'-'-'- -..-----------.--- ..~,----, .---.---..-.------..-------...-----. -.-- ... . . - -.,-.-..--" -.-..,-. ._--_...._--_.---".._---_._---_._-,----,~-_._---_._._.-----.---.. .--.. -.-..- --.-'.'--- ' . Comments: ~ ~ ~~"'-\ ._.._--_.._.._----~---- -----.--'----.---------,..------ .-.-.,.-.- C::!...I fc; (~ '::,-=.) t.... ~ t- . c.. \3 (,... U ~ I: i- f I 'f E:- l .-.-------.------- --- .__._----_._-----~.~---_.- .--- -.. ".. -~~:;:~:~:~::~~:~::~;=-~~~~~~:~::_~)~---~~~~~~:.=~=~-~--_....._.~~-_.=:===-~---~~_._-- ---- --- -~. --_.._---_._._~----------_._-'"--- Date: ') ~ J rvv--. i ÒG ~.- -..-------. __--2___.___..______,,,__,,,.__ __. ..____ /Vttd. " 'f:, \,.- { r f K ¿ ,( r" \ ~ ~<J ~d E... ~~~ f E..,x. I J..' (7J... rt)~; c. 'Q ,,'1 d) ~ 'I E ^ / ..L: r.I,- 5c ",i < (" ~ L- ¿ us ( r 1J,')IL "\ \ð!h¿dr ~"J )UVJtj f~- ~ \..;> '>--:' "-,,....,' ~.., t~_·.. .... -." ~ ....... <ill:' . ""' ,~ MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool , field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBD 23X-06 200-023 KTU 32-07 181-153 KBD 31-07 168-049 KDD2 195-055 KBD 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBD 33-06 178-055 KDD5 195-054 KTU 43-06XRD 177-029 KBD13-08 203-066 KEU 43-07X 185-181 KED 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KED 41-07 169-012 KDU4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KED 33-06 199-025 KEU 42-07 200-188 KED 24-06 202-025 KBD 41-07X 200-179 KEU 44-06 ~ g:\cm~~\kgf\weS\kU43-6al\AOGCC Vstring subsequent.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull Tubing 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 79'FNL,4325'FWL,Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1440'FNL,4083'FWL,Sec. 7, T4N,R11W, S.M. At Effective Depth At Total Depth 1428' FNL, 1811' FWL, Sec. 7, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 139' 1517' Stimulate Alter Casing 5. Type of Well: Development X Exploratory Stratigraphic Service Plugging Repair Well Perforate Other X 6. Datum Elevation (OF or KB) 21.00' OF feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 32-7h 9. Permit Number 202-043 10. API Number 50-133-20511-00 11. Field/Pool Kenai Gas Field/ Tyonek Installed Velocity String 11857 feet Plugs (measured) N/A 8742 feet feet Junk (measured) N/A feet Size Cemented Measured Depth 20" driven 139' 13-3/8" 614 sacks 1517' True Vertical Depth 139' 1517' 6526' 9-5/8" 625 sacks 6526' 3136' 7" 1300 sacks 9435' measured no perforations. Slotted liner in open hole, 9604' - 11,764' MD 6503' 8677' true vertical no perforations. Slotted liner in open hole, 8717' - 8740' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) N/A 4-1/2", 12.6 ppf, L-80, IBT-Mod to 9604' & 1-1/2" CT, 0.125-0.156" wall thickness to 9610' Baker Premier packer @ 9295' RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage Treatment Description Including Volumes Used and Final Pressure 14. Oil-Bbl Prior to Well Operation o Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby ce~fy that the foregoin Signed ~ :' I 1 o X is true and correct to the best of my knowledge. Form 10-404 Rev. 06/15/88 Representative Daily Averaqe Production or Injection Data Casing Pressure Gas-Mcf Water-Bbl 500 0 550 0 Tubing Pressure o 700 o 700 16. Status of Well Classification as: Oil Gas X Suspended Service Denise M. Titus Title Production Engineer Date 12/31/03 OFçlG\NAL ~Bfl Submit in Duplicate JAN U ¿J.:>' ",-c ~c~ Marathon Oil Company Operations Summary Report Page 1 of 1 Legal Well Name: KENAI TYONEK UNIT 32-7H Common Well Name: KENAI TYONEK UNIT 32-7H Event Name: RECOMPLETION Contractor Name: Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 11/21/2003 12:00 - 18:30 6.50 CL TBG RURD CSGPRO 18:30 - 19:15 0.75 CLTBG RURD CSGPRO 19:15 - 20:30 1.25 CL TBG CSGPRO 20:30 - 20:45 0.25 CLTBG CSGPRO 20:45 - 21 :00 0.25 CL TBG CSGPRO 21 :00 - 22:00 1.00 CL TBG CSGPRO 11/22/2003 06:30 - 07:30 1.00 CL TBG RCMP 07:30 - 08:00 0.50 CL TBG RCMP 08:00 - 09:30 1.50 CL TBG RCMP 09:30 - 13:45 4.25 CL TBG RCMP 13:45 - 14:15 0.50 CL TBG RCMP 14:15 - 15:00 0.75 CL TBG RCMP 15:00 - 15:25 0.42 CL TBG RCMP 15:25 - 17:30 2.08 CL TBG RCMP 17:30 - 18:00 0.50 CL TBG RCMP 18:00 - 18:30 0.50 CL TBG RCMP 18:30 - 20:00 1.50 CL TBG RCMP 20:00 - 00:00 4.00 CL TBG RCMP 11/24/2003 08:30 - 11 :30 3.00 WL TRT RCMP 11 :30 - 13:00 1.50 FLOW RCMP 13:00 - 15:00 2.00 RCMP Start: 11/15/2003 Rig Release: Rig Number: 1 Spud Date: 3/18/2002 End: 11/23/2003 Group: Description of Operations Obtain work permit. Hold safety meeting. Spot equipment and RU. Finish rigging up flowback and function test BOPs. (complete BOP ftn/pressure test completed in the shop) Load CT w/ 50/50 methanol while pumping pig, taking returns to flowback tank. Once returns clean up, take clean methanol back to source tank. Once total CT volume is displaced, shut in returns and pressure test BOP and CT string to 500/3000psi. Blow CT down with N2 to tank to purge 50/50 methanol. Blow pressure off of string and break injector head from WHo Prepare to install roll-on BHA. Roll-on is mis-sized. Elect to SO for night. Secure location and have roll-on machined to proper size. Arrive, obtain permit, warm up equipment and conduct safety meeting. Roll-on machined BHA including pump off plug and profile for pump down latch. NU injector head and attempt to RIH. Tag up in tree several times. Close master valve and bleed off lubricator. Break Bowen connection and attempt to guide CT into hanger below BOPs, crossovers, and 2nd master valve. Unable to guide. PU CT to investigate. Plug missing from bottom of roll-on nipple. Cut off BHA and rig back injector head to machine alternative BHA. MU new BHA and stab injector. Open wellhead pressure to Assy and watch pump pressure to test new BHA. Pressure test good. Break WHA above 2nd master valve. Guid CT through hanger by hand. MU WHA. Correct KB to 17.6'. Open master valve and inspect flange for isolation. Test good. RIH w/ 1-1/2" velocity string and pump off BHA. Encounter friction at -9350'. PU and run through carefully suspect deviation effects. Run pipe to 9650' and PUH to 9610' hangoff depth. Engage True turn hanger. Slack off pipe and run in lock screws and gland nuts to energize packoff. Bleed pressure off from above packoff and observe for 10 minutes to verify pressure integrity of CT hanger spool. Test good. Rough cut pipe using BOP shears and begin RD of BOP stack. Dress CT stub and install G&G wireline reentry guide (grapple style) about 8-1/2" stickup left above CT hanger. Replace 2nd master valve and flange and RD BJ Services. RU and pump N2 down tubing string via tree cap to pump plug off of CT. Re-rig line from tree cap to flow N2 off of tubing prior to turning well over to production. Demob flowlines and scaffolding. Clean location and replace wellhouse. Printed: 12/31/2003 10:21 :51 AM Tubina: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1" dummy valve installed - 1/4" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' ID = 3.813" 4-1/2" Slotted Liner, 9604' -11,764' 12.6 ppf, L-80, IBT-M w/ 1/4" vertical slots Packoff bushing @ 11,764' ID = 2.375" Guide shoe @ 11,807 Well KTU 32-7h ~ ~ Tubing & Slotted Liner Detail Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. DOQleQs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506',7.0 deg/100 ft Directional Survey Well Name & Number Prepaired By: M MARATlO. . 120", 133 ppf, K-55 drive pipe @ 139' API: 50-133-20511-00 AOGCC: 202-043 ~ 13-3/8",68 ppf, L-80, BTC Surface Casing @ 1517' Cmt w/ 614 sks RT-GL: 21.00' RT-THF: 20.15' Surface:79'FNL,4325'FVVL Sec. 7, T4N, R11W, S.M. ) 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt w/ 625 sks Tree cxn: 4-3/4" Otis Lift Thds: 4.909" MCA 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' ID = 6.187" 7",26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks Tree drawing 1-1/2" CT Velocity String to 9610' MD 0.125"-0.156" wall thickness Weatherford BHA w/ profile for 0.87" Pump down dart ITD: 6-1/8" open hole, 9435' - 11,857' .~ Note: Frequently have excess drag in the severe dogleg area at 9500'. See reports of Jan - March 2003. Perforations in Slotted Liner (2.5",6 spf 60-deg phase) 9945' - 9975' (3/24/03) 11,545' - 11,575' (3/21/03) KTU 32-7h Gary Eller Lease \ Pad 41-7, Kenai Gas Field Date Completed \ 05/19/02 County or Parish Last Revision Date: Kenai Peninsula 04/03/03\ I State/Prov. Alaska --., --, r ' Nt MARATHON ~ Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 31 , 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KTU 32-7h Dear Mr. Aubert: Enclosed is the 10-404 Report of Sundry Well Operations form for Marathon well KTU 32- 7h. A velocity string was installed to facilitate the lifting of produced water. The well rate was too low to unload 4-1/2" pipe. A 1-1/2" CT velocity string was installed which will improve the lift velocity in the well to allow produced water to flow to surface. This work was completed 11/25/03. An operations summary and updated well bore diagram are enclosed for your review. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at d mtitus@marathonoil.com. Sincerely, r\ A~ tW- V;yv Denise M. Titus Production Engineer RECEIVED JAN 0 5 2004 0·, & Gas Cons Commission A\aska , . Anchorage Enclosures ORtGINAL .-.... G:\CMN\DRLG\KGF\WELLS\KU13-6L \AOGCCO V-string Sundry.xls _, vJGA- III F-I/2..()() ~ fJ?JS IIII fß STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 11857 feet Plugs (measured) NIA 8742 feet NI A feet Junk (measured) NIA NI A feet Size Cemented Measured Depth 20" driven 139' 13-3/8" 614 sacks 1517' 1. Type of Request: Operation Shutdown Plugging Suspend Repair Well Pull Tubing 5. Type of Well: Development X Exploratory Stratigraphic Service Abandon Alter Casing Change Approved Program Variance 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 79' FNL, 4325' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1440'FNL,4083'FVVL,Sec. 7,T4N, R11W,S.M. At Effective Depth Install Velocity String At Total Depth 1428' FNL, 1811' FWL, Sec. 7, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 139' 1517' 6526' 9-5/8" 625 sacks 6526' 3136' 7" 1300 sacks 9435' measured no perforations. Slotted liner in open hole, 9604' - 11,764' MD true vertical no perforations. Slotted liner in open hole, 8717' - 8740' TVD Tubing (size, grade, and measured depth) 4-1/2", 12.6 ppf, L-80, IBT-Mod to 9604' Packers and SSSV (type and measured depth) Baker Premier packer @ 9295' 13. Attachments Description Summary of Proposal Re-enter Suspended Well Time Extension Stimulate Perforate Other X 6. Datum Elevation (OF or KB) 21.00' OF feet 7, Unit or Property Name Kenai Tyonek Unit 8, Well Number KTU 32-7h ,/ 9. Permit Numb~ 202-043 10. API Number ,/ 50-133-20511-00 11. FieldlPool Kenai Gas Fieldl Tyonek True Vertical Depth 139' 1517' 6503' 8677' - . 15. Status of Well Classification as: Detailed Operations Program ..25.. BOP Sketch 14. Estimated Date for Commencing Operation 14-Nov-03 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby ~rt ~h~tt~~Yß:eg: is true and correct to the best of my knowledge. Signed \ \\.Yv.... II:; r Denise Titus Title Production Engineer J " FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location Clearance Mechanical Integrity Test Form Required 10- 4 {/ c.{ __fJfl J ~ Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Suspended Date 11/12/2003 APproval No. "3 ð ~-1/}? Commissioner (( If iL (j) Submit in Triplicate -- M MARATHON ~ f Marathon Oil Company Alaska Region KTU 32-7h Kenai Gas Field, Pad 41-7 Velocity String Hang-off Procedure WBS # WO.03.09591.EXP History: KTU 32- 7h is a horizontal Tyonek well. This well has not flowed as expected since its completion. The well is currently producing to the high pressure system at 500mscfpd. The rate is well below unload rate for the 4-1/2" tubing and shows evidence of loading up. This well may benefit from the ability to steadily lift the water it produces. ~ Objective: Install a velocity string facilitate continuous water lifting. The wellhead configuration should permit the well to flow via tubing, annulus, or both. Procedure: 1) Shut in well and remove flowlines. NU and test TrueTum CT hanger with integral slips above bottom master valve. Pipefitters will advise as to orientation of side outlet on CT hanger. NU and test remaining tree. 2) Reconfigure surface flowlines to permit the well to flow via tubing, annulus, or both. /' This will entail a tee installation upstream of the wing valve SSV. Side outlet flow from the CT spool will be protected by the existing SSV. 3) Prep and weld 1-1/2" hangoff string as needed to get at least 9760' string length. X-ray welds. Pressure and fuction test BOPs in the shop prior to arriving on location. 4) MIRU BJ CT wI 1-1/2" hangoffstring (wall thickness varies). NU BOPs on 4-1118" 5M flanged CT hanger. (Do we need an additional valve to get off of the well?). RU MaC flowback setup including chicksans, choke, and a tame Venting and flowback are not anticipated. The flowback tank will only be needed briefly to release pressure test fluid. 5) MU Weatherford roll-on BRA profile and pumpoffplug. Ensure CT is as straight as possible to prevent tagging up in chemical injection mandrel at 1973'. Close rams on test bar and fill kill line with freeze protected fluid (6% KCl). Test bottom connection to 250/3500psi against test bar. Relieve pressure and NU injector head. Shell test against CT plug to 250/l00Opsi. /' 6) Hold pre-job discussion. Ensure hanger slips are fully retracted. Rill at a slow rate +1- 50'/min with 1-1/2" velocity string watching weight indicator closely (*note--hanger ---- ID= 1-11/16"). Keep an eye on wellhead pressure. This is expect to come up due to pipe displacement. If pressure must be bled down to Rill, check area for adj acent operations and coordinate as needed. 7) Run string to approximate depth of 9610'. Ensure R T -GL measurement of 21' is included in depth. / 8) Once on depth, turn operating screw on CT hanger about ~ turn to position marked on hanger to engage the slips. Lower tubing until weight indicator reads zero and hanger is supporting the tubing. Set down string weight to test hanger. Tighten the gland nut on the operating screw to support the slips. 9) Energize the packoff assembly by tightening the four packoff screws one half turn each, equally repeating until all four are tight. Tighten all four gland nuts on the packoff screws. 10) Pressure test the CT hanger seal once packoff is thoroughly engaged. Install gauge on / annular side outlet and bleed down pressure from the flowcross to the tame Block in at the flowcross and monitor WHP to ensure no pressure buildup. 11) Once packoff is verified holding, prepare to cut pipe. Close BOP rams on the pipe and rough cut with BOP shears. 12) Ensure Pwh=O and rig injector head and BOPs back from the CT spool. Make final cut on the CT above the tubing head assembly. Dress cut and install wireline entry guide. RDMO BJ CT. 13) NU remaining tree valves and test. Complete surface flowline tie-in. 14) MIRU BJ N2 to top of tree. Reconfigure flowback as needed to blow well down to ~ atmosphere (for venting N2) prior to gas sales. 15) Pressure up on tubing until pump off plug releases. RD BJ N2 and bleed N2 pressure off of well. 16) Turn well to system and monitor for water/solids. Produce to high pressure system and ~ compare to previous rates. Turn to low pressure system if necessary. I final objective is sustained water production. Record rate where water is lifted and produce at unload rate. Tubinq: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1" dummy valve installed - 1/4" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' ID = 3.813" 4-1/2" Slotted Liner, 9604' -11,764' 12.6 ppf, L-80, IBT-M wi 1/4" vertical slots Packott bushing @ 11,764' 10 = 2.375" Guide shoe @ 11,807 Well KTU 32-7h M .AUTHO. ~ . 120", 133 ppf, K-55 drive pipe @ 139' AP I: 50-133-20511-00 AOGCC: 202-043 ~ 13-3/8", 68 ppf, L-80, BTC Surface Casing @ 1517' Cmt wi 614 sks RT-GL: 21.00' RT-THF: 20.15' ~ Surface:79'FNL,4325'FVVL Sec. 7, T4N, R11VV, S.M. Tree cxn: 4-3/4" Otis Lift Thds: 4.909" MCA 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt wi 625 sks Tree drawinÇ1 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' 10 = 6.187" 7", 26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks Tubing & Slotted Liner Detail ( Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. Doqleqs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506',7.0 deg/100 ft Directional Survey VVell Name & Number Prepaired By: ) Proposed 1-1/2" Velocity String to 9610' MD I TD: 6-1/8" open hole, 9435' - 11,857' Note: Frequently have excess drag in the severe dogleg area at 9500'. See reports of .I Jan - March 2003. Perforations in Slotted Liner (2.5",6 spf 60-deg phase) 9945' - 9975' (3/24/03) 11,545' - 11 ,~75' (3/21/03) KTU 32-7h Gary Eller Lease I Pad 41-7, Kenai Gas Field Date Completed 1 05/19/02 Alaska 1 State/Prov. County or Parish Last Revision Date: Kenai Peninsula 04/03/031 .^, ---- ..-.- .. ' M MARATHON } f Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 12, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 'i-~_ 'io 9 Ql Reference: KTU 32-7h Dear Mr. Aubert: Enclosed is the 10-403 Application For Sundry Approvals form for Marathon well KTU 32-7h. The proposed work is to install a coiled tubing velocity string to facilitate the lifting of ~ produced water. The well is currently at a rate inadequate to unload 4-1/2" pipe. This work is expected to begin 1 ~ A detailed procedure and a well bore diagram are also enclosed for your revie~2fr;~ need any additional information, I can be reached at 907-283-1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, [\ d I' , J LL,... ,.. /f-, ro;. j~;;r Denise M. Titus Production Engineer Enclosures ¡A, , If.\ ~ RE: KT.LJ 32-7h PTD 202-043 - -- Subject: RE: KTU 32-7h PTD 202-043 Date: Fri, 14 Mar 2003 09:01 :57 -0900 From: "Eller, John G." <JGEller@MarathonOil.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Yes, Tom, our BOP test procedure will be the same. We'll have the well drawn down to near atmospheric pressure to maximize underbalance, and we'll fire the guns via internal coil tubing pressure. And thanks for the reminder, I will get you 404s for the previous operations. -----Original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday/ March 14/ 2003 8:54 AM To: Eller, John G. Subject: Re: KTU 32-7h PTD 202-043 Hi Gary, I checked the file and you guys have attempted a number of operations to coax the well to flow. Since you indicate that you plan to use coil, is the BOP test the same as for the previous operations (4000 psi)?? Please let me know that part of the process. Based on what you have performed previously on this well, a sundry will not be necessary for this activity. Good luck. Tom Maunder, PE AOGCC "Eller, John G." wrote: Tom Attached is a wellbore schematic diagram for well KTU 32-7h in the Kenai Gas Field. It is a horizontal completion in the Upper Tyonek Unit, completed with a slotted liner in an open hole. Production has been very disappointing, and has not been improved by bacteria or acid treatments. Next week we are planning on perforating select portions of the slotted liner (desperation move). This will not change the interval that this well is completed in, but is strictly an attmept to bypass damage in the existing completion interval. Somewhat analagous to a reperf operation without any change in interval. Do you need a formal sundry for this work, or can this notofication suffice? I do not know yet the specific perforation intervals. We will convey the guns on coil tubing. Thanks, and call if you have any questions. «KTU32-7h.ZIP» J. Gary Eller Operations Engineer Alaska Region, Marathon Oil Company 907-564-6315 1 of 1 3/14/20039:47 AM Tubina: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1" dummy valve installed - 1/4" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' ID = 3.813" 4-1/2" Slotted Liner, 9604' - 11,764' 12.6 ppf, L-80, IBT-M wi 1/4" vertical slots Packoff bushing @ 11,764' 10 = 2.375" Guide shoe @ 11,807 Well KTU 32-7h ~ M .ARATHO. . 120", 133 ppf, K-55 drive pipe @ 139' I' I I t. I API: 50-133-20511-00 AOGCC: 202-043 ~ Tree drawing RT-GL: 21.00' RT - THF: 20.15' 13-3/8",68 ppf, L-80, BTC Surface Casing @ 1517' Cmt wi 614 sks ~ )- Surface: 79'FNL,4325'FVVL Sec. 7, T4N, R11VV, S.M. Tree cxn: 4-3/4" Otis 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' ID = 6.187" 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt w/ 625 sks Tubing & Slotted Liner Detail Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. Doqleqs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506',7.0 deg/100 ft Directional Survey VVell Name & Number Prepaired By: ITD: 6-1/8" open hole, 9435' - 1 ~ ,857' ) 7",26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks 14-1/2" Slotted Liner, 9604' - 11,764' KTU 32-7h Gary Eller Lease I Pad 41-7, Kenai Gas Field Date Completed I 05/19/02 I State/Prov. I Alaska County or Parish Kenai Peninsula RE: KTU 32-7H --- ,~---....... Subject: RE: KTU 32-7H Date: Thu, 13 Feb 2003 10:39:00 -0900 From: "Eller, John G." <JGEller@MarathonOil.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Probably a bit of a mistake on my part, Tom. The second test is strictly to test the Bowen connection that is broken when we install our wash tool on the end of the coil. There's no reason we can't do a 4000 psi test again. -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Wednesday, February 12, 2003 6:33 PM To: Eller, John G. Subject: KTU 32-7H Gary, Just a quick question. In step 1 of the proposed procedure, you test the BOP to 4000 psi. In step 4, you NU the injector head and test the lubricator to 2500 psi with N2. The 2500 psi exceeds your 81 pressure, but is there a disconnect here in the two test pressures?? Thanks. Tom 1 of 1 2/13/2003 6:25 PM -.........-...- - g:\cmn\drlg\kgf\wells\ku43-6al\AOGCC01 A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull Tubing Stimulate X Alter Casing 5. Type of Well: Development X Exploratory Stratigraphic Service Plugging Repair Well Perforate Other 6. Datum Elevation (OF or KB) 21.00' OF feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 32-7h 9. Permit Number 202-043 10. API Number 50-133-20511-00 11. Field/Pool 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 79' FNL, 4325' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1440'FNL,4083'FWL,Sec. 7, T4N,R11W,S.M. At Effective Depth I Bacterial Treatment At Total Depth 1428' FNL, 1811' FWL, Sec. 7, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 11857 feet 8742 feet Plugs (measured) NIA Effective Depth: measured true vertical feet feet Junk (measured) NIA Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 139' Size 20" Cemented driven Measured Depth 139' True Vertical Depth 139' 1517' 13-3/8" 614 sacks 1517' 1517' measured 6526' 9-5/8" 625 sacks 6526' 3136' 7" 1300 sacks 9435' no perforations. Slotted liner in open hole, 9604' - 11,764' MD 6503' 8677' true vertical no perforations. Slotted liner in open hole, 8717' - 8740' TVD -:¡:-¿,... Ii Tubing (size, grade, and measured depth) 4-1/2", 12.6 ppf, L-80, IBT-Mod to 9604' I ··I·,I~; ~ . ..L> ~ Packers and SSSV (type and measured depth) Baker Premier packer @ 9295' j-\1aBk(J~ iJÜ B~ \_1(.: 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Entire open hole interval, 9604'-11,764' MD Treatment Description Including Volumes Used and Final Pressure Spotted 230 bbl of bacteria along the slotted liner trom 9604'-11,764'. bacteria to consume mud products tor 10 days before jetting out with coil. No immediate improvement in production. 14. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation o 400 o o 700 Subsequent to Operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operatio X Oil Gas X Suspended o 150 0 16. Status of Well Classification as: o 700 Service Signed J. Gary Eller Title Production Engineer () h} ~ ¡,,:~ ~. ¡Ô, I l,.J \ \ t \~j ~ ¡ \ k Dnnuc DCI ÆB I 2 ?nn.i Date 10-Feb-03 Submit in DUPlicat~ ~ MARATHON OIL COMPANY Daily Workover Report Increase Production Page 1 of 1 21.0 RIG NAME & NO. IGL 66.00 124 HR PROG TMD AUTH MD TVD DFSO IDO~ I RPT# DATE 8 09-Jan-2003 SAPIWBS COST 650,000 I CUM WELL COST 149,145.78 I LEAKOFF WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Wayne Cissell FIELD NAME KENAI STATElPROV Alaska CURRENT STATUS / MTS KB WBS RIG PHONE WO.02.07775.EXP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 21,813.00 I NEXT CASING o (ft) (in) @ 0 (ft) COUNTY/OTHER Kenai Borough I LAST CASING (in) @ 124 HR FORECAST OPERATION COMMENTS Bien and heat 292 bbl of 6% KCI water in insulated tank. MIRU coil tubing. Test BOPE. SAFETY SUMMARY BOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 0.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 07:00 22:00 15.00 FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL DESCRIPTION AF MIRU CL TBG MIRU coil tubing and nitrogen. Pressure test BOPE to 250/4000 psi using methanol water. MI 400 bbl insulated tank. Bien 292 bbl of 6% KC!. MIRU hot oil truck. Heat KCI water to 90 deg F. ROMO hot oil truck LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 9.625 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 0 TVO (ft) o NEXT BOP TEST: WT (lblft) GRADE BURST (psi) Printed: 1/23/2003 6:28:35 PM ~- -.. MARATHON OIL COMPANY Daily Workover Report Increase Production Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gary Eller FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS/ MTS KB IGL 66.00 124 HR PROG TMD AUTH MD TVD \DFSO I DOLO IRPT#9 DATE 10-Jan-2003 SAPIWBS COST 650,000 I CUM WELL COST 248,889.78 I LEAKOFF 21.0 RIG NAME & NO. WBS RIG PHONE WO.02.07775.EXP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 99,744.00 I NEXT CASING o (ft) (in) cæ 0 (ft) COUNTY/OTHER Kenai Borough I LAST CASING (in) @ 124 HR FORECAST OPERATION COMMENTS RIH with coil tubing to 11,700'. Circulate bacteria water. Unexpectedly getting liquid returns to surface. Continue pumping all available bacteria water. Secure well. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 0.00 ACCIDENT DESCRIPTION: SAFETY SUMMARY BOP PSI TEST I LAST STOP CARD AUDIT ~EGULATORY INSP? I LAST RIG INSPECTION SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 09:00 11:00 2.00 AF MIRU CLTBG NU coil tubing injector head. Pressure test lubricator to 4000 psi. 11:00 12:45 1.75 AF STIM CL TBG RIH with coil tubing. SITP = 1490 psi. 12:45 13:45 1.00 TA STIM CL TBG Tag at 6679', unable to work past. PU 100' and attempt to RIH, but tagging up immediately. Open well to flow, RIH with coil to 6715' before tagging. Pump nitrogen at 500 scfm while continuing to bleed tubing pressure. Able to get past. Shut down nitrogen. SITP = 980 psi. 13:45 14:45 1.00 AF STIM CLTBG RIH to 11,700'. 14:45 17:15 2.50 AF STIM CL TBG Blend 15 drums of bacteria into 292 bbls of 6% KCI water. Product is 12 drums of B-Clean DFg and 3 drums of B-Chem 6c, both from Drilling Specialties. Roll tank to mix bacteria in KCI water. 17:15 19:00 1.75 AF STIM CLTBG POOH with coil tubing at 15 fpm while pumping bacteria water at 1.5 bpm. Not taking returns at surface, and wellhead pressure ar d pump pressure building. 19:00 19:30 0.50 TA STIM CLTBG Suspect filter at inlet to coil tubing reel is plugging. Investigate and determine that it is not plugged. Apparently building significant hydrostatic pressure in annulus with only half of treatment pumped away. 19:30 20:00 0.50 TA STIM CL TBG Resume circulating at 1.5 bpm. Getting liquid returns (condensat9) at surface after having pumped 178 bbl of bacteria water. Shut down again 20:00 20:45 0.75 AF STIM CL TBG Resume circulating bacteria while bleeding off surface pressure. Getting strictly gas returns now. POOH with coil tubing. 20:45 22:15 1.50 AF STIM CLTBG Getting 100% liquid returns at surface. Fluids are carrying a large amount of formation sand. Not obvious whetehr bacteria are present in return water, so caught a sample for lab verification. Continue to POOH circulating bacteria water. Pumped a total of 315 bbl of bacteria water. 22:15 00:00 1.75 AF STIM CLTBG Finish POOH with coil tubing. Shut in well, and blow reel dry with nitrogen. Secure well, SDFN. Printed: 1/23/2003 6:26:26 PM --- WELL NAME KENAI TYONEK UNIT 32-7H LAST BOP TEST: SIZE (in) 10 (in) SHOE TEST (ppg) 9.625 MARATHON OIL COMPANY Daily Workover Report Increase Production KB 21.0 124 HR PROGTMD GL 66.00 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 0 0 .- TVD I DFSO I DOLO NEXT BOP TEST: WT (Ibltt) GRADE Page 2 of 2 RPT#9 ¡DATE 10-Jan-2003 BURST (psi) Printed: 1/23/2003 6:28:26 PM .---- -. MARATHON OIL COMPANY Daily Workover Report Increase Production Page 1 of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Wayne Cissell FIELD NAME KENAI STATElPROV Alaska CURRENTSTATUS/MTS KB GL 66.00 124 HR PROG TMD AUTH MD TVD IDFSO I DOLO RPT# DATE 10 19-Jan-2003 SAPIWBS COST 650,000 I CUM WELL COST 260,518.78 I LëAKOFF 21.0 RIG NAME & NO. WBS RIG PHONE WO.02.07775.EXP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 11,629.00 I NEXT CASING o (ft) (in) @ 0 (ft) COUNTY/OTHER Kenai Borough I LAST CASING (in) @ 124 HR FORECAST OPERATION COMMENTS MIRU coil tubing. Test BOPE. Blend 350 bbl of 6% KC!, heat to 100 deg F. SAFETY SUr1MARY ~~HRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT ~EGULATORY INSP? I LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 10:00 15:30 5.50 FROM TO SUB AF OPERATIONS SUMMARY PHASE OP TRBL STIM CLTBG DESCRIPTION MIRU 1.75" coil tubing and nitrogen. Pressure test BOPE to 250/4000 psi. Test pumping iron to 5000 psi. Blend 350 bbbl of 6% KCI and heat to 100 deg F. LAST BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg) 9.625 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 0 TVD (ft) o NEXT BOP TEST: WT (lblft) GRADE BURST (psi) Printed: 1/23/2003 6:28:53 PM ~ - MARATHON OIL COMPANY Daily Workover Report Increase Production Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gary Eller FIELD NAME KENAI STATElPROV Alaska CURRENT STATUS / MTS KB IGL 66.00 124 HR PROG TMD AUTH MD TVD DFSO I DOLO I RPT # DATE 11 20-Jan-2003 SAPIWBS COST 650,000 I CUM WELL COST 314,274.78 I LEAKOFF 21.0 RIG NAME & NO. WBS RIG PHONE WO.02.07775.EXP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 53,756.00 I NEXT CASING o (ft) (in) (á2 0 (ft) COUNTY/OTHER Kenai Borough I LAST CASING (in) @ 124 HR FORECAST OPERATION COMMENTS RIH with coil. Wash sand/fill along length of horizontal section. Jet well with nitrogen, recover 250 bbl from wellbore. RD coil tubing. Turn well over to Production. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 0.00 None ACCIDENT DESCRIPTION: SAFETY SUr1MARY BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 07:30 09:30 2.00 AF STIM CL TBG Held prejob safety meeting. PU coil tubing injector head. Pressu'e test lubricator to 4000 psi. Empty reel with nitrogen. 09:30 11 :15 1.75 AF STIM CL TBG RIH with coil tubing. SITP = 100 psi. Tag up at 9278'. PU30', begin circulating 6% KCI at 2.5 bpm and nitrogen at 600 scfm. RIH, easily get past obstruction. 11:15 14:30 3.25 AF STIM CL TBG Get fluid returns at surface. Wash sand/fill while RIH at 30 fpm tc 11.700'. Pump pressure = 2550 psi, wellhead = 200 psi. Getting a decent amount of sand in the returns. 14:30 15:00 0.50 AF STIM CL TBG Circulate at 11,700' at 2.5 bpm and 600 scfm nitrogen.Pump pressure increased to 2850 psi, wellhead = 600 psi. 15:00 15:30 0.50 AF STIM CL TBG POOH washing sand to 11,100'. Returns cleaner, but still occasional sand. 15:30 16:00 0.50 AF STIM CL TBG Cease sand washing. Shut-down fluid pump, RIH to 11,700' circulating nitrogen at 600 scfm. 16:00 17:45 1.75 AF STIM CL TBG POOH to 9550' jetting with nitrogen at 600 scfm. At 9550', continue jetting until volume of liquid returns is diminishing. Have recovered approximately 200 bbl from wellbore. Pump = 1280 psi, wellhead = 920 psi. 17:45 18:45 1.00 AF STIM CL TBG RIH with coil tubing to 11,700' while continuing to jet at 600 scfm. Circulate at 11,700' for 15 minutes. Getting strong liquid returns again. 18:45 19:30 0.75 AF STIM CL TBG POOH to 10,050' jetting at 600 scfm with nitrogen. Pump = 860 psi, wellhead = 270 psi. Recovery = 230 bbl from wellbore. 19:30 20:30 1.00 AF STIM CL TBG Reduce nitrogen rate to 350 scfm (minimum rate). RIH to 11,700. Jet at 11,700' for 15 minutes at 350 scfm nitrogen. Pump = 520 psi, wellhead = 150 psi. Minimal fluid returns. 20:30 22:15 1.75 AF STIM CL TBG POOH to 6600' jetting with nitrogen at 350 scfm. Pump = 300 ps', wellhead = 120 psi. Total recovery from well bore = 250 bbl. 22:15 23:30 1.25 AF STIM CLTBG Shut down nitrogen. POOH with coil tubing, allowing well to continue to vent. Printed: 1/23/2003 6:28:44 PM ~ -- MARATHON OIL COMPANY Daily Workover Report Increase Production Page 2 of 2 WELL NAME KENAI TYONEK UNIT 32-7H IKB 21.0 GL 66.00 124 HR PROGTMD ITVD IDFSO I DOLO RPT# I DATE 11 20-Jan-2003 FROM TO HRS FROM 23:30 00:30 1.00 OPERATIONS SUMMARY TO SUB PHASE OP TRBL DESCRIPTION AF STIM CL TBG RD coil tubing injector head. Turn well over to Production Dept. to produce to sales. LAST BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg) 9.625 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 0 0 NEXT BOP TEST: WT (lblft) GRADE BURST (psi) Printed: 1/23/2003 6:28:44 PM ~ _ GOICMNlDRlGIKGFlWEllSIKU13.6lIAOGCþ :Ll\3> ,lWLb ~ø.1 1?C7) 2-/ /4-/::5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend Repair Well Pull Tubing 5. Type of Well: Development X Exploratory Stratigraphic Service 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface // / 79'FNL,4325'FWL,Sec. 7, T4N,R11VV,S.M. At top of Productive Interval 1440'FNL,4083'FVVL,Sec. 7,T4N,R11W, S.M. At Effective Depth ACid Stimulation At Total Depth 1428'FNL, 1811'FVVL,Sec. 7, T4N,R11W,S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Operation Shutdown Plugging Variance 11857 feet ':/ Plugs (measured) 8742 feet Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 139' 1517' 13-3/8" NI A feet N/A feet Junk (measured) Re-enter Suspended Well Time Extension Stimulate X Perforate Other 6. Datum Elevation (DF or KB) 21.00' DF feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 32-7h 9. Permit Numbev 202-043 10. API Number 50-133-20511-00 11. FieldlPool 'V N/A N/A Size 20" Cemented driven Measured Depth 139' True Vertical Depth 139' true vertical 4-1/2", 12.6 ppf, L-80, IBT-Mod to 9604' 614 sacks Packers and SSSV (type and measured depth) Baker Premier packer @ 9295' 1517' 1517' measured 6526' 9-5/8" 625 sacks 6526' 3136' 7" 1300 sacks 9435' no perforations. Slotted liner in open hole, 9604' - 11,764' MD 6503' 8677' no perforations. Slotted liner in open hole, 8717' - 8740' TVD r Tubing (size, grade, and measured depth) 13. Attachments Description Summary of Proposal 14. Estimated Date for Commencing Operation 19-Feb-03 16. If Proposal was Verbally Approved Name Date Approved rue and correct to the best of my knowledge. Service ¡-! ' ?UO,j \or~;·~¡·l( j,;ø 15. Status of Well Classification as: Detailed Operations Program X BOP Sketch Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIONm fft MLBI Oil Gas X Suspended Signed ~ Gary Eller Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: . tify C mmission so re~,;entative may wit~ess 4QOO "S.' \SQ ~ ~~\-- Plug Integnty BOP Test Ã.. Location Clearance Mechanical Integrity Test Subsequent Form Required 10- -4«)'-\ ~ 1 Date 2/10/2003 Approval No. 3¿-·" 3 - L-:~11f Commissioner Date a2//ø63 -; Submit in Triplicate RBDMS 8Fl FEF3 19 ~ --- Well KTU 32-7h WBS WO.02.07775.EXP Kenai Gas Field Acidizing Procedure Ob_iective: Acidize the horizontal section of well KTU 32-7h using 7.5% HCland BJ's Rotojet wash tool in order to improve productivity. Procedure: 1. MIRU 1 %" BJ coil tubing unit and nitrogen pump. Well KW32:-7hsþouldbe-shl1t:.in and built to full surface pressure (approximately 2200 psi). R.Ilscaffolding as needed. NU BOPE and 30' of lubricator. RU flowlines~~~t~fiºJçe måfûfold:to:clean returns-tank. Pressure test BOPE to 250/4000 psi using fra1i;&v:~.erÖrKClwater.Pressuretestpump discharge lines to 6000 psi. ~~~~,~~~~- >- 2. 19b co(llwJ:!ir1g to pic~epipe. DispJace:acid -ith sQtlã;~h\as needed.· Jet reel dl)'usirig -~ u - --- ---- - - - - - --- --- ---- - - - - - ---- - -- - >{require ª'~~c£~~;fof1*()I'Ì)er barrelOfwater) in suction nd 179 b~.5%N§EWìth additives (5% ammonium 1 + 3 gp + lk~~--~=-118 + 1 gpt Inflo-15 0 + 5 pptg nns shoif'QpWith~the KGF operator and BJ include¡l:ón,gloves, face shield, and half-mask air acid to v {~r concentration. Collect samples of acid injector head. Pressure test lubricator with 2500 psi reo _ KTU 32-7h shut-in and the reel full of nitrogen. Tool string ofRo~~,~ wash tool (OD = 1 %"), inline filter, hydraulic disconnect, check il conneètor. Rill to toe of well at 11,750'. Check PU and drag weight A simulation. ___ ~OOH at 15 fpm with 7.5% HCl at 1.2 bpm through the Rotojet nozzle. Continue to sh OOH, pumping a total of 178 bbl of HCI. Continue to POOH while displacing acid - with one reel volume (i.e. 29 bbl) of 6% KCI. 6. When finished displacing reel with KCl, begin circulating nitrogen at 500 scEm while Rill. Take returns to the clean return tank, adding soda ash as needed to neutralize acid. Capture several samples of acid returns during flowback, upstream of where acid is being .. Well KTU 32-7h Acidizing Procedure Page 2 ,"""---..... -. neutralized. Be prepared to wash fill if returns indicate a large amount of fonnation fines has been released during the acidizing. Continue jetting to 11,700'. 7. POOH jetting with nitrogen to ±6000'. SD nitrogen, POOH. Flow well long enough to purge nitrogen and access flow. Produce well to system. RDMO coil tubing and nitrogen. JGE - February 10,2003 Tubinq: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1" dummy valve installed - 1 14" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' 10 = 3.813" 4-1/2" Slotted Liner, 9604' - 11,764' 12.6 ppf, L-80, IBT-M wi 1/4" vertical slots Packoff bushing @ 11,764' 10 = 2.375" Guide shoe @ 11,807 .., Well KTU 32-7h ,,~. ~ !I I' ~ I,·!' I' Ii t 1·,'.' :i M, MARATH:OI ì ..,. ,- . 120",133 ppf, K-55 drive pipe @ 139' AP I: 50-133-20511-00 AOGCC: 202-043 . ) ~ 13-3/8", 68 ppf, L-80, BTC Surface Casing @ 1517' Cmt wi 614 sks RT-GL: 21.00' RT-THF: 20.15' Surface:79'FNL,4325'FVVL Sec. 7, T4N, R11VV, S.M. 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' 10 = 6.187" Tree cxn: 4-3/4" Otis Tree drawinq 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt wi 625 sks Tubinq & Slotted Liner Detail Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. Ooqleqs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506', 7.0 deg/1 00 ft Directional Survey VVell Name & Number Prepaired By: TO: 6-1/8" open hole, 9435' - 11,857' I .,.. ;td~J..·'.!..'¿""..,I'.'u.,,~.tl_~;IIi\1oili..II...II'~' , , ,,~-,~~ ... ~~ 7",26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks 14-1/2" Slotted Liner, 9604' -11,764' KTU 32-7h Gary Eller Lease I Pad 41-7, Kenai Gas Field Date Completed I 05/19/02 Kenai Peninsula I State/Prov. I Alaska County or Parish /~- _ G:\CMNIDRLGIKGFIWELLS\KU1306L\AOGCCk- '\( G q.,,?tð ,/"/O'L !Y7S Of /0 (,/03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Repair Well Operation Shutdown Plugging Re-enter Suspended Well Time Extension Stimulate X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 9j9-6168 4. Location of Well at Surface .J V . 79'FNL,4325'FWL,Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1440'FNL,4083'FWL,Sec. 7, T4N, R11W, S.M. At Effective Depth Pull Tubing 5. Type of Well: Development X Exploratory Stratigraphic Service Variance Perforate Other At Total Depth 1428'FNL, 1811'FWL, Sec. 7, T4N,R11W,S.M. 12. Present Well Condition Summary Total Depth: measured true vertical I Bacterial Treatment 6. Datum Elevation (DF or KB) 21.00' DF feet 7, Unit or Property Name Kenai Tyonek Unit 8, Well Number KTU 32-7h 9. Permit Number / 202-043 :../ 10. API Number ./ 50-133-20511-00 11. FieldlPool 1517' 11857 feet Ý Plugs (measured) NIA 8742 feet NI A feet Junk (measured) NIA NIA feet Size Cemented Measured Depth 20" driven 139' 13-318" 614 sacks 1517' True Vertical Depth 139' Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 139' 1517' 6526' 9-5/8" 625 sacks 6526' 3136' 7" 1300 sacks 9435' measured no perforations. Slotted liner in open hole, 9604' - 11,764' MD 6503' 8677' true vertical no perforations. Slotted liner in open hole, 8717' - 8740' TVD RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6 ppf, L-80, IBT-Mod to 9604' Packers and SSSV (type and measured depth) Baker Premier packer @ 9295' JAN 0 6 200J Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 9-Jan-03 16. If Proposal was Verbally Approved 15. Status of Well Classification as: Oil Gas X Suspended Name of Approver Date Approved Service 17. I he~fy that the forego ~s true and correct 10 the best of my knowledge. Signed~ ~~~~ Gary Eller Title Production Engineer FOR COMMISSION USE ONLY Conditions of ApprovaL Notify ommission so rep~1entative may witness 4tJ:jJ\>o;; \ ~\) ~-\-t:.s ~ Plug Integrity BOP Test ~ Location Clearance Mechanical Integrity Test Subsequent Form Required 10- ~\)"-\ Date 1 13/2003 Approval No. 3D_--? -- óZ5-_::'f Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED BY M L. Bm Commissioner Date I It, h ~;7 Su6mit!¡n Triplicate RBOMS 8Fl JÞ,N ,~n o ?nO-1 ~;c--' -.I _U '\_i ~ \ lr-~ ~~J p\ L.. /-, -. Well KTU 32-7h WBS WO.02.07775.EXP Kenai Gas Field Bacterial Treatment for Mud Damage Ob.iective: Place specific bacteria in the horizontal section of well KTU 32-7h in order to remove xanthan polymer drilling mud damage and improve productivity. Remove the bacteria after allowing sufficient time for them to consume the polymer. Procedure: 1. Take delivery of 12 drums ofB-Clean DFG and 3 drums ofB-Chem 6C bacteria from Drilling Specialties. This is sufficient to blend 262 bbl of bacteria water. Drums should be transported and stored in a heated environment until they are needed. Do not allow drums of bacteria to freeze. Upon taking delivery of the bacteria, capture three small, random samples ofB-Clean DFG and onesample ofB-Chem 6C. Appropriate PPE while handling the bacteria incll!des glQve, rubber apron, and face shield. Have these sample~-s~I1t via courier to Whit~'EnvitönmentaIServices (Anchorage) for testing to en~~~~;~~iª,1!íltty· - -- -- ---- ----- - -- -- - -- ..-J~t--:~Wit~~_ª~«¥i~~two Q~.h~þroþosed job, blend 262 bbl of 6% KCI (22 lbs per bbl) in a --J--7:-¥s~lt~~ï~j~~le waf~jgl!zl~nded, MIRU hot oil truck. Heat the KCI water to a ~~i~i~h~~iiiliiimumt~~~~~po F. ~1\IDN1Ø hot oil tnick~ -- - - - - - - - - --- -- -- - -- -- - - - - - - - - - - - - - -- - - - -- --- -- ---- --- - ~--~-=;~~~~çapture~-~~Rle ofttle~~(.m water thatistobe mixed with the 15 drums of bacteria. ._-u--·---~:-t~hip thisf~~mgl~ of~~13W:ªter to White Environmental Services to verify that the water is ~-=-:-~c~---~~suitable f9f-~Æo1\veying:t11~lPacteria. - - -- - --- -- -- - . - - ---- ----- ._--~~<-~pnce W!'!!te~~nvir0l11Jl~€rit~1-has approved use of the KCI water, prepare to blend the -'_~~-:~-~:-drums Q.f!I~$!~ria. Iftli~~(a.i1k ofKCI water has cooled too much, reheat the tank ofKCI _ _ u_~_~--f;-;Wate~ ~ti~If!~blending-the drums of bacteria. It is important that the bacteria do not _~--~-_Ui~ft-~c~~'y-=~t\'al1ytime, nor is it advisable to reheat the tank of KCI water once the drums have - ;:-'-~--~~~~iJ.~[ð;ª't(E Therefore, time the addition of the bacteria to closely coincide with the c~--<~E~~a-djlIe~s-of coil tubing to operate. -- ---5;.~ MIRU 1 %" BJ coil tubing unit and nitrogen pump. Well KTU 32-7h should be shut-in - and built to full surface pressure (approximately 2200 psi). RU scaffolding as needed. NU BOPE. RU flowlines and choke manifold to clean returns tank. MU standard wash nozzle onto coil tubing. Wash nozzle should have large ports for minimal pressure drop. Pressure test BOPE to 250/4000 psi using methanol water. Jet reel dry using nitrogen after pressure testing. ----- -- Well KTU 32-7h Bacteria Procedure Page 2 6. Use a clean vac truck to pick up 40 bbl of heated KCI water. Use this same vac truck to suck out the content of the 15 drums of bacteria into the heat KCI water bath. Appropriate PPE while handling the bacteria includes glove, rubber apron, and face shield. Transport the bacteria-laden KCI water back to the KCI source tank, and empty the contents of the vac truck into the heated KCI source tank. Capture final bacteria samples for post-job analysis, if needed. 7. Rill with empty coil tubing to ±11,700'. If necessary to circulate, attempt to use nitrogen to circulate instead of liquid. Lay in 262 bbl of bacteria water at 1.5 bpm while POOH at 15 fpm. Do not open well up to take returns - simply lay in the bacteria along the horizontal section. Displace the bacteria water with nitrogen while continuing to POOH. Continue to pressure up the wellbore with nitrogen until a surface pressure of ±3000 psi is achieved. 8. POOH, stand back coil tubing. Secure well, and install SPIR gauge to monitor wellhead pressure. Allow 7 days for bacteria to consume polymer. - - - - -- - 9.:M1~1";0'iØ!y~~attempttQ-flº'Y-w~nto tTowbacktank. Ifunable to flow independently, RU u-m:;t~tr~tül)w:g.;2!3'~ssure--t~st--=JlØPEto 250/4000 psi using methanol water. MU standard _-c__-----~'%alh[ti?~~I~~QJ1-10 coiFÌ1.llJIDg. Jet reel dl}'using nitrogen after pressure testing. - - - - - - - _n _ _ _ _ __ _ __ _ _ . _ _ __ _ _ _ _ - - - - - - - - - - ~---~~1~;<;KJmI wit1í-~grp~reel(ffcÓjl'tubing to±11;700'. Jet with nitrogen at 500 scfm while -- - 'C-ÞOOH.~'!:rJjiJjf~returlfsåE?-ples and analyze for polymer content to help determine '-_-\~--effective!1~[~~filhe oacte~a, treatment. Itisalso possible that the samples could be ~\~~--=(lnalyzedf~ot}~ã.$teria;if~tl!ey survived beìng removed from the wellbore. Continue jetting _-until wel[ís-JJ1Ï1oading(ltíIìt' s own or liquid returns have ceased. - - - - - -- -,-_--ill\Flow w~11~f§3gas bustetl0¥1g enough to purge nitrogen and assess flow. Produce well to >~=Lsystem'~@:N10 coil~tlibìrlg and nitrogen. -J9:e__~Jåniujry 3, 2003 Tubina: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1" dummy valve installed - 1 14" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' ID = 3.813" 4-1/2" Slotted Liner, 9604' - 11,764' 12.6 ppf, L-80, IBT-M wi 1/4" vertical slots Packoff bushing @ 11,764' ID = 2.375" Guide shoe @ 11 ,807 Well KTU 32-7h ~ M MARAtHON , ~ 120", 133 ppf, K-55 drive pipe @ 139' API: 50-133-20511-00 AOGCC: 202-043 RT-GL: 21.00' RT-THF: 20.15' 13-3/8",68 ppf, L-80, BTC Surface Casing @ 1517' Cmt wi 614 sks ) . ~ Surface: 79'FNL,4325'FVVL Sec. 7, T4N, R11VV, S.M. Tree cxn: 4-3/4" Otis 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' ID = 6.187" Tree drawing 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt wi 625 sks Tubing & Slotted Liner Detail Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. Doqleqs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506',7.0 deg/100 ft Directional Survey VVell Name & Number Prepaired By: ITD: 6-1/8" open hole, 9435' - 11,857' ) 7",26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks 14-1/2" Slotted Liner, 9604'-11,764' KTU 32-7h Gary Eller Lease I Pad 41-7, Kenai Gas Field Date Completed I 05/19/02 I State/Prov. I Alaska County or Parish Kenai Peninsula ) STATE OF ALASKA ) ALA~r<..A. OIL AND GAS CONSERVATION COMMISSION VVE~L COMPLETION OR RECOMPLETION REPORT AND LOG .-- 1. Status of Well OILD GAS[8] SUSPENDEDD 2. Name of Operator MARATHON OIL COMPANY ABANDONEDD SERVICED Classification of Service Well (~~, '¡,.~.... -. ~'~ . .. : . __. . I. . ,.,... .t ,. .. i "s.. '". r'·. ~. ,,---1'-;''-.' " '" ,'..,. .1..... .~~. Lease Designation and Serial No. A-028142 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions ;¡~ $', z"'·t.yt.. .41> N/A feet MSL one 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost YeS~NO D N/A feet MD N/A 3. Address P. O. Box 196168, Anchorage,AK 99519-6168 4. Location of Well at Surface 79' FNL, 4325' FWL, Sec. 7, T4N, R11W, S.M. At top of Producing Interval 1440' FNL, 4083' FWL, Sec. 7, T4N, R11W, S.M. At Total Depth 1428' FNL, 1811' FWL, Sec. 7, T4N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. 21.00' DF-GL 12. Date Sfiudded 3/~2002'ÅÞ COMPlÚíON I_DATE : ~- lb· D2-f ¡'... .1, I ~l" ~~D. ~ "'.1";;¡« .. .~--,- ~ 13. Date TD. Reached 5/12/2002 17. Total Depth (MD+TVD) 11857' MD, 8742' TVD 18. Plug Back Depth (MD+TVD) N/A 22. Type Electric or Other Logs Run PEX, dipole sonic, CBL, USIT 7. Permit Number 202-043 8. API Number 50-133-20511-00 9. Unit or Lease Name Kenai Tyonek Unit 10. Well Number KTU 32-7h 11. Field and Pool Kenai Tyonek Pool Kenai Gas Field 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. GRADE 20" 133 K-55 0 139 13-3/8" 68 L-80 0 1517 9-5/8" 40 L-80 0 6526 7" 26 L-80 6299 9435 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) - no perforations - 6-1/8" open hole from 9435' - 11857' MD (8677'-8742' TVD) - 4-1/2" slotted liner 9604' - 11764' Driven 17-1/2" 12-1/4" 8-1/2" 25. SIZE 4-1/2",12.6 ppf Driven N/ A 614 sks (to surface) N/A 625 sks N/A 1300 sks N/A TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 9604' 9295' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production 3-Jul-02 Date of Test 7/5/2002 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) flowing PRODUCTION FOR TEST PERIOD ---. CALCULATED 24-HOUR RATE---, Flow Tubing Pres. 140 Hours Tested 24 Casing Pressure o OIL-BBL o OIL-BBL o GAS-MCF 350 GAS-MCF 350 WATER-BBL CHOKE SIZE GAS-OIL RATIO o N~ WATER-BBL OIL GRAVITY-API (corr) o N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal On ~ ('\ \\1 ^L ,i'\ \ (:¡ ~ i\J/-\ Form 10-407 Rev. 7-1-80 N :\drlg\kgf\wells\KBU33-6\AOGCOMPL.xls CONTINUED ON REVERSE SIDE R. E (~ F , \1 f [) JUL 2 9 2002 Alaska Oil & lias Cons. L;omrìllssîon - Anchorage r'JqnMS 8Fl Submit in Triplicate AUG I 3 2002 ') ) 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Sterling D1 Coal 3517 3516 N/A 4560 4559 7437 7184 9400 8662 9608 8716 Top Beluga Top Tyonek D1 Sand RECF~"l"'~' JUL 2 9 2002 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey I hereby cert~t the toreg~g~ true and correct to the best at my knowtedge Signed ~ ~ Gary Eller Title lUaska Oil &. üas b01'l5. l"OmffiiSSion Anchorage 32. Production Engineer Date 7/26/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 N :\drlg\sterl ing\su32-9\AOGCOMPL.xls ('-~~ 1 Ii \,; f( ~ ) \ ï. ~"'. L t ~ ; Tubina: 4-1/2", 12.6 ppf, L-80, IBT-M Chemical injection mandrel @ 1973' - 1 H dummy valve installed - 1/4" SS, 0.049" wall control line Baker Premier packer @ 9295' 10' of 5.25" seals X-nipple @ 9350' 10 = 3.813" 4-1/2" Slotted Liner, 9604' - 11,764' 12.6 ppf, L-80, IBT-M w/ 1/4" vertical slots Packoff bushing @ 11,764' ID = 2.375" Guide shoe @ 11,807 Well KTU 32-7h ~ M MAUTlO. 1 . 120", 133 ppf, K-55 drive pipe @ 139' API: 50-133-20511-00 AOGCC: 202-043 ~ -_ I RT-GL: 21.00' RT-THF: 20.15' ~ 13-3/8",68 ppf, L-80, BTC Surface Casing @ 1517' Cmt w/ 614 sks Surface: 79'FNL,4325'FVVL Sec. 7, T4N, R11VV, S.M. 7" ZXP liner top packer @ 6279' 7" HMC liner hanger @ 6299' ID = 6.187" Tree cxn: 4-3/4" Otis 9-5/8",40 ppf, L-80, BTC Casing @ 6526' Cmt w/ 625 sks Tubinq & Slotted Liner Detail Directional Data KOP: 5850' Hole angle at 7" shoe = 61 deg Max. DoqleQs: 9489' - 9583', 26.7 deg/100 ft 6683' - 6746', 8.1 deg/100 ft 8443' - 8506', 7.0 deg/100 ft Directional Survey VVell Name & Number Prepaired By: TD: 6-1/8" open hole, 9435' - 11,857' .~\~ --' 7", 26 ppf, L-80, BTC Liner @ 6299' - 9435' Cmt with 1300 sks 14-1/2" Slotted Liner, 9604' -11,764' KTU 32-7h Gary Eller Lease I Pad 41-7, Kenai Gas Field Date Completed I 05/19/02 Kenai Peninsula I State/Prov. I Alaska County or Parish Well KTU 32-7h, Kenai gas Field Final Directional Surveys MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 194.00 1.40 174.70 193.98 -2.36 0.22 -0.22 0.72 0.72 0.00 254.00 1.50 174.70 253.96 -3.87 0.36 -0.36 0.17 0.17 0.00 315.00 1.00 180.60 314.95 -5.20 0.43 -0.43 0.85 -0.82 9.67 376.00 1.20 183.40 375.94 -6.37 0.38 -0.38 0.34 0.33 4.59 437.00 1.40 158.80 436.92 -7.70 0.62 -0.62 0.96 0.33 -40.33 498.00 1.50 179.90 497.90 -9.19 0.89 -0.89 0.89 0.16 34.59 559.00 1.30 148.60 558.88 -10.58 1.25 -1.25 1.28 -0.33 -51.31 619.00 1.10 164.10 618.87 -11 .72 1.76 -1.76 0.63 -0.33 25.83 680.00 1.10 160.20 679.86 -12.83 2.12 -2.12 0.12 0.00 -6.39 740.00 0.80 197.20 739.85 -13.77 2.19 -2.19 1.11 -0.50 61.67 800.00 0.90 159.50 799.85 -14.62 2.23 -2.23 0.93 0.17 -62.83 866.00 0.70 212.30 865.84 -15.44 2.20 -2.20 1.11 -0.30 80.00 928.00 0.70 288.20 927.84 -15.64 1.64 -1.64 1.39 0.00 122.42 989.00 0.90 277.30 988.83 -15.47 0.81 -0.81 0.41 0.33 -17.87 1,051.00 0.80 304.70 1,050.82 -15.16 -0.03 0.03 0.67 -0.16 44.19 1,113.00 1.10 298.40 1,112.82 -14.63 -0.91 0.91 0.51 0.48 -10.16 1,175.00 0.90 257.30 1,174.81 -14.45 -1.91 1.91 1.17 -0.32 -66.29 1,238.00 1.10 285.40 1 ,237.80 -14.40 -2.98 2.98 0.83 0.32 44.60 1,301.00 1.00 256.20 1,300.79 -14.37 -4.09 4.09 0.85 -0.16 -46.35 1,364.00 1.10 272.70 1,363.78 -14.47 -5.23 5.23 0.50 0.16 26.19 1 ,427.00 1.30 290.00 1,426.76 -14.20 -6.51 6.51 0.65 0.32 27.46 1 ,467.00 1.80 274.90 1,466.75 -13.99 -7.56 7.56 1.60 1.25 -37.75 1,553.00 1.60 280.80 1,552.71 -13.65 -10.08 10.08 0.31 -0.23 6.86 1,616.00 1.40 283.10 1,615.69 -13.31 -11 .70 11.70 0.33 -0.32 3.65 1,679.00 1.50 281.60 1,678.67 -12.97 -13.25 13.25 0.17 0.16 -2.38 1,741.00 1.00 254.00 1,740.65 -12.96 -14.57 14.57 1.24 -0.81 -44.52 1,802.00 0.60 231.60 1,801.65 -13.30 -15.33 15.33 0.82 -0.66 -36.72 1,865.00 0.70 236.80 1 ,864.64 -13.72 -15.91 15.91 0.18 0.16 8.25 1,927.00 0.60 308.40 1,926.64 -13.73 -16.48 16.48 1.23 -0.16 115.48 1,989.00 0.30 231.90 1,988.64 -13.62 -16.87 16.87 0.98 -0.48 -123.39 2,052.00 0.70 298.30 2,051.64 -13.54 -17.33 17.33 1.02 0.63 105.40 2,116.00 1.00 344.70 2,115.63 -12.82 -17.83 17.83 1.13 0.47 72.50 2,179.00 1.30 1.90 2,178.62 -11.57 -17.95 17.95 0.72 0.48 27.30 2,243.00 1.10 31.30 2,242.61 -10.32 -17.60 17.60 1.00 -0.31 45.94 2,306.00 1.70 28.40 2,305.59 -8.99 -16.85 16.85 0.96 0.95 -4.60 2,368.00 1.80 50.60 2,367.56 -7.56 -15.66 15.66 1.10 0.16 35.81 2,431.00 1.60 25.40 2,430.53 -6.14 -14.51 14.51 1.22 -0.32 -40.00 2,494.00 1.50 23.50 2,493.51 -4.58 -13.81 13.81 0.18 -0.16 -3.02 2,557.00 1.60 23.50 2,556.49 -3.02 -13.13 13.13 0.16 0.16 0.00 2,620.00 1.40 21.00 2,619.46 -1.50 -12.50 12.50 0.33 -0.32 -3.97 2,684.00 1.50 63.80 2,683.44 -0.40 -11.47 11.47 1.66 0.16 66.87 2,748.00 1.80 48.50 2,747.42 0.64 -9.97 9.97 0.83 0.47 -23.91 2,811.00 2.00 58.60 2,810.38 1.87 -8.29 8.29 0.62 0.32 16.03 2,874.00 1.80 73.80 2,873.35 2.72 -6.40 6.40 0.86 -0.32 24.13 2,937.00 0.80 82.00 2,936.33 3.05 -5.01 5.01 1.61 -1.59 13.02 2,999.00 0.50 16.70 2,998.33 3.37 -4.51 4.51 1.20 -0.48 -105.32 ) ) Well KTU 32-7h, Kenai gas Field Final Directional Surveys MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 3,063.00 0.10 193.50 3,062.33 3.59 -4.44 4.44 0.94 -0.62 276.25 3,124.00 0.70 45.00 3,123.33 3.80 -4.19 4.19 1.29 0.98 -243.44 3,186.00 0.60 24.20 3,185.32 4.36 -3.79 3.79 0.41 -0.16 -33.55 3,248.00 0.60 50.90 3,247.32 4.86 -3.40 3.40 0.45 0.00 43.06 3,311.00 0.60 19.40 3,310.32 5.38 -3.04 3.04 0.52 0.00 -50.00 3,374.00 0.40 114.20 3,373.32 5.60 -2.73 2.73 1.19 -0.32 150.48 3,435.00 0.20 167.30 3,434.31 5.41 -2.51 2.51 0.53 -0.33 87.05 3,498.00 0.30 133.50 3,497.31 5.19 -2.36 2.36 0.28 0.16 -53.65 3,561.00 0.30 144.00 3,560.31 4.94 -2.15 2.15 0.09 0.00 16.67 3,624.00 0.50 74.60 3,623.31 4.88 -1.79 1.79 0.77 0.32 -110.16 3,687.00 0.40 119.40 3,686.31 4.85 -1.33 1.33 0.56 -0.16 71.11 3,749.00 0.50 45.90 3,748.31 4.93 -0.95 0.95 0.88 0.16 -118.55 3,813.00 0.20 151 .20 3,812.31 5.03 -0.69 0.69 0.91 -0.4 7 164.53 3,876.00 0.30 214.90 3,875.31 4.79 -0.73 0.73 0.44 0.16 101.11 3,941.00 0.40 37.00 3,940.31 4.84 -0.69 0.69 1.08 0.15 -273.69 4,004.00 0.30 230.90 4,003.31 4.91 -0.69 0.69 1.10 -0.16 -263.65 4,066.00 0.50 312.80 4,065.31 4.99 -1.01 1.01 0.88 0.32 132.10 4,129.00 0.40 250.10 4,128.30 5.10 -1 .42 1.42 0.76 -0.16 -99.52 4,193.00 0.40 244.00 4,192.30 4.93 -1.83 1.83 0.07 0.00 -9.53 4,256.00 0.40 287.60 4,255.30 4.90 -2.24 2.24 0.47 0.00 69.21 4,319.00 0.50 12.80 4,318.30 5.23 -2.39 2.39 0.97 0.16 135.24 4,382.00 0.20 207.40 4,381.30 5.40 -2.38 2.38 1.10 -0.48 -262.54 4,446.00 0.50 312.50 4,445.30 5.49 -2.64 2.64 0.91 0.47 164.22 4,509.00 0.60 8.60 4,508.30 6.00 -2.79 2.79 0.83 0.16 89.05 4,572.00 0.50 356.30 4,571.29 6.60 -2.76 2.76 0.24 ~0.16 -19.52 4,635.00 0.10 188.90 4,634.29 6.82 -2.78 2.78 0.95 -0.63 -265.71 4,698.00 0.50 354.50 4,697.29 7.04 -2.82 2.82 0.95 0.63 262.86 4,762.00 0.50 359.20 4,761.29 7.60 -2.85 2.85 0.06 0.00 7.34 4,828.00 0.20 56.80 4,827.29 7.95 -2.76 2.76 0.65 -0.45 87.27 4,888.00 0.60 323.20 4,887.29 8.26 -2.86 2.86 1.07 0.67 -156.00 4,950.00 0.50 15.20 4,949.28 8.78 -2.98 2.98 0.79 -0.16 83.87 5,012.00 0.50 18.70 5,011.28 9.30 -2.82 2.82 0.05 0.00 5.65 5,075.00 0.10 179.20 5,074.28 9.50 -2.73 2.73 0.94 -0.63 254.76 5,138.00 0.60 352.90 5,137.28 9.78 -2.77 2.77 1.11 0.79 275.71 5,201.00 0.00 270.00 5,200.28 10.10 -2.82 2.82 0.95 -0.95 0.00 5,263.00 0.40 278.30 5,262.28 10.14 -3.03 3.03 0.65 0.65 0.00 5,327.00 0.20 253.20 5,326.28 10.14 -3.36 3.36 0.37 -0.31 -39.22 5,390.00 0.60 316.10 5,389.28 10.34 -3.69 3.69 0.86 0.63 99.84 5,452.00 0.40 350.10 5,451.27 10.79 -3.95 3.95 0.56 -0.32 54.84 5,515.00 0.30 211 .40 5,514.27 10.86 -4.08 4.08 1.04 -0.16 -220.16 5,578.00 0.20 194.70 5,577.27 10.62 -4.19 4.19 0.19 -0.16 -26.51 5,641.00 0.40 241.60 5,640.27 10.41 -4.41 4.41 0.48 0.32 74.44 5,704.00 0.50 289.00 5,703.27 10.39 -4.87 4.87 0.59 0.16 75.24 5,767.00 0.20 78.70 5,766.27 10.50 -5.02 5.02 1.08 -0.48 237.62 5,831.00 0.80 145.90 5,830.27 10.15 -4.66 4.66 1.17 0.94 105.00 5,894.00 3.00 148.20 5,893.23 8.39 -3.54 3.54 3.49 3.49 3.65 5,957.00 5.30 143.20 5,956.06 4.66 -0.93 0.93 3.69 3.65 -7.94 ) ) Well KTU 32-7h, Kenai gas Field Final Directional Surveys MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 6,022.00 7.20 146.00 6,020.67 -1.12 3.15 -3.15 2.96 2.92 4.31 6,080.00 9.40 143.80 6,078.06 -7.96 7.98 -7.98 3.83 3.79 -3.79 6,143.00 11.10 144.70 6,140.05 -17.06 14.52 -14.52 2.71 2.70 1.43 6,206.00 13.00 144.00 6,201.66 -27.75 22.19 -22.19 3.02 3.02 -1.11 6,269.00 14.70 145.40 6,262.83 -40.06 30.89 -30.89 2.75 2.70 2.22 6,332.00 16.80 146.80 6,323.46 -54.26 40.42 -40.42 3.39 3.33 2.22 6,395.00 19.60 147.30 6,383.30 -70.77 51.12 -51 .12 4.45 4.44 0.79 6,459.00 23.10 146.20 6,442.90 -90.24 63.90 -63.90 5.50 5.47 -1.72 6,480.00 24.40 146.00 6,462.12 -97.26 68.62 -68.62 6.20 6.19 -0.95 6,557.00 28.50 146.00 6,531.05 -125.69 87.79 -87.79 5.32 5.32 0.00 6,620.00 31.50 145.90 6,585.60 -151.79 105.43 -105.43 4.76 4.76 -0.16 6,683.00 35.90 147.10 6,638.00 -180.94 124.70 -124.70 7.06 6.98 1.90 6,746.00 40.90 148.60 6,687.36 -214.07 145.49 -145.49 8.07 7.94 2.38 6,809.00 41.10 148.30 6,734.90 -249.29 167.12 -167.12 0.45 0.32 -0.48 6,872.00 44.10 147.00 6,781.27 -285.31 189.95 -189.95 4.96 4.76 -2.06 6,935.00 45.10 146.30 6,826.13 -322.26 214.27 -214.27 1.77 1.59 -1.11 6,999.00 44.80 146.50 6,871.43 -359.92 239.29 -239.29 0.52 -0.47 0.31 7,063.00 44.80 145.90 6,916.84 -397.39 264.37 -264.37 0.66 0.00 -0.94 7,126.00 44.50 146.40 6,961.66 -434.16 289.04 -289.04 0.73 -0.48 0.79 7,189.00 44.40 146.30 7,006.63 -470.89 313.48 -313.48 0.19 -0.16 -0.16 7,252.00 44.50 145.60 7,051.60 -507.44 338.19 -338.19 0.79 0.16 -1.11 7,316.00 44.30 145.70 7,097.33 -544.41 363.45 -363.45 0.33 -0.31 0.16 7,379.00 44.20 145.40 7,142.46 -580.66 388.32 -388.32 0.37 -0.16 -0.48 7,440.00 44.00 145.10 7,186.26 -615.54 412.52 -412.52 0.47 -0.33 -0.49 7,501.00 44.10 144.50 7,230.11 -650.20 436.96 -436.96 0.70 0.16 -0.98 7,567.00 43.80 143.70 7,277.62 -687.30 463.82 -463.82 0.96 -0.45 -1.21 7,627.00 42.30 145.80 7,321.47 -720.74 487.47 -487.47 3.46 -2.50 3.50 7,690.00 39.80 148.40 7,368.98 -755.45 509.95 -509.95 4.80 -3.97 4.13 7,755.00 38.00 151.00 7,419.57 -790.68 530.56 -530.56 3.74 -2.77 4.00 7,817.00 37.00 152.70 7,468.76 -823.95 548.37 -548.37 2.32 -1.61 2.74 7,880.00 35.00 155.50 7,519.73 -857.24 564.56 -564.56 4.11 -3.17 4.44 7,943.00 32.20 159.50 7,572.20 -889.42 577.93 -577.93 5.66 -4.44 6.35 8,006.00 30.60 165.20 7,625.98 -920.65 587.91 -587.91 5.35 -2.54 9.05 8,071.00 30.90 174.30 7,681.88 -953.27 593.80 -593.80 7.17 0.46 14.00 8,132.00 30.40 181 .30 7,734.37 -984.30 595.00 -595.00 5.90 -0.82 11 .48 8,194.00 29.80 188.80 7,788.03 -1,015.22 592.29 -592.29 6.14 -0.97 12.10 8,253.00 30.20 194.30 7,839.14 -1,044.09 586.38 -586.38 4.71 0.68 9.32 8,316.00 31.70 200.90 7,893.18 -1,074.92 576.56 -576.56 5.89 2.38 10.48 8,380.00 32.60 206.30 7,947.38 -1,106.09 562.92 -562.92 4.70 1.41 8.44 8,443.00 33.40 214.30 8,000.24 -1,135.64 545.62 -545.62 7.03 1.27 12.70 8,506.00 33.70 221 .20 8,052.76 -1,163.13 524.33 -524.33 6.07 0.48 10.95 8,569.00 34.30 225.70 8,105.00 -1,188.68 500.11 -500.11 4.11 0.95 7.14 8,631.00 35.00 231 .20 8,156.01 -1,212.03 473.74 -473.74 5.17 1.13 8.87 8,694.00 37.00 237.50 8,207.00 -1,233.55 443.66 -443.66 6.68 3.17 10.00 8,757.00 39.00 242.30 8,256.65 -1,252.95 410.10 -410.10 5.66 3.17 7.62 8,819.00 41.40 246.90 8,304.01 -1,270.07 373.96 -373.96 6.16 3.87 7.42 8,882.00 42.80 251.00 8,350.77 -1,285.22 334.55 -334.55 4.90 2.22 6.51 ') Well KTU 32-7h, Kenai gas Field Final Directional Surveys MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 8,945.00 45.70 254.80 8,395.90 -1,298.10 292.55 -292.55 6.24 4.60 6.03 9,007.00 47.20 256.00 8,438.61 -1,309.42 249.06 -249.06 2.80 2.42 1.94 9,070.00 50.30 258.00 8,480.15 -1,320.05 202.92 -202.92 5.47 4.92 3.17 9,131.00 53.30 261.10 8,517.87 -1,328.72 155.78 -155.78 6.33 4.92 5.08 9,196.00 55.30 262.60 8,555.80 -1,336.19 103.54 -103.54 3.60 3.08 2.31 9,260.00 57.10 263.70 8,591.41 -1,342.53 50.74 -50.74 3.15 2.81 1.72 9,323.00 59.50 264.20 8,624.51 -1,348.18 -2.56 2.56 3.87 3.81 0.79 9,345.00 60.50 263.60 8,635.51 -1,350.20 -21.51 21.51 5.12 4.55 -2.73 9,386.00 61.10 264.90 8,655.51 -1,353.79 -57.12 57.12 3.13 1.46 3.17 9,396.00 60.60 264.80 8,660.38 -1,354.57 -65.81 65.81 5.08 -5.00 -1.00 9,489.00 69.20 268.90 8,699.81 -1,359.09 -149.81 149.81 10.07 9.25 4.41 9,524.00 76.80 268.90 8,710.03 -1,359.73 -183.25 183.25 21.71 21.71 0.00 9,550.00 83.70 268.20 8,714.43 -1,360.38 -208.85 208.85 26.67 26.54 -2.69 9,583.00 88.20 269.20 8,716.76 -1,361.12 -241.75 241.75 13.97 13.64 3.03 9,614.00 89.50 269.60 8,717.39 -1,361.45 -272.74 272.74 4.39 4.19 1.29 9,649.00 89.70 269.20 8,717.63 -1,361.81 -307.74 307.74 1.28 0.57 -1.14 9,680.00 89.70 269.20 8,717.79 -1,362.25 -338.73 338.73 0.00 0.00 0.00 9,712.00 89.80 268.90 8,717.93 -1,362.78 -370.73 370.73 0.99 0.31 -0.94 9,7 42.00 89.10 269.60 8,718.22 -1,363.17 -400.72 400.72 3.30 -2.33 2.33 9,776.00 88.50 269.60 8,718.93 -1,363.41 -434.72 434.72 1.76 -1.76 0.00 9,801.00 88.70 269.60 8,719.54 -1,363.58 -459.71 459.71 0.80 0.80 0.00 9,865.00 87.40 269.20 8,721.72 -1,364.25 -523.67 523.67 2.13 -2.03 -0.62 9,926.00 88.20 268.90 8,724.06 -1,365.26 -584.61 584.61 1.40 1.31 -0.49 9,961.00 88.60 268.90 8,725.04 -1,365.93 -619.59 619.59 1.14 1.14 0.00 9,992.00 87.40 269.60 8,726.12 -1,366.34 -650.57 650.57 4.48 -3.87 2.26 10,023.00 86.00 269.20 8,727.91 -1,366.66 -681.52 681 .52 4.70 -4.52 -1.29 10,056.00 86.50 269.20 8,730.07 -1,367.12 -714.44 714.44 1.52 1.52 0.00 10,087.00 87.20 268.50 8,731.77 -1,367.74 -745.39 745.39 3.19 2.26 -2.26 10,120.00 87.50 268.50 8,733.29 -1,368.61 -778.34 778.34 0.91 0.91 0.00 10,151.00 87.80 268.20 8,734.57 -1,369.50 -809.30 809.30 1.37 0.97 -0.97 10,181.00 89.50 267.50 8,735.27 -1,370.62 -839.27 839.27 6.13 5.67 -2.33 10,226.00 89.20 267.80 8,735.78 -1,372.47 -884.23 884.23 0.94 -0.67 0.67 10,275.00 92.30 268.50 8,735.14 -1,374.05 -933.19 933.19 6.49 6.33 1.43 10,305.00 90.40 268.90 8,734.43 -1,374.73 -963.18 963.18 6.47 -6.33 1.33 10,337.00 88.50 268.90 8,734.74 -1,375.35 -995.17 995.17 5.94 -5.94 0.00 10,366.00 89.00 268.50 8,735.37 -1,376.00 -1,024.15 1,024.15 2.21 1.72 -1.38 10,398.00 89.40 268.50 8,735.82 -1,376.84 -1,056.14 1,056.14 1.25 1.25 0.00 10,429.00 89.00 268.90 8,736.25 -1,377.54 -1,087.13 1,087.13 1.82 -1.29 1.29 10,459.00 89.10 268.90 8,736.75 -1,378.12 -1,117.12 1,117.12 0.33 0.33 0.00 10,489.00 89.80 269.20 8,737.04 -1,378.62 -1,147.11 1,147.11 2.54 2.33 1.00 10,521.00 90.10 269.20 8,737.07 -1,379.06 -1,179.11 1,179.11 0.94 0.94 0.00 10,534.00 90.30 269.20 8,737.02 -1,379.25 -1,192.11 1,192.11 1.54 1.54 0.00 10,553.00 90.40 269.60 8,736.91 -1,379.45 -1,211.11 1,211.11 2.17 0.53 2.11 10,586.00 91.00 269.20 8,736.50 -1,379.79 -1,244.10 1,244.10 2.19 1.82 -1.21 10,615.00 91.80 269.90 8,735.79 -1,380.02 -1,273.09 1,273.09 3.67 2.76 2.41 10,646.00 91.80 270.30 8,734.82 -1,379.96 -1,304.08 1,304.08 1.29 0.00 1.29 10,676.00 92.50 270.60 8,733.70 -1,379.73 -1,334.05 1,334.05 2.54 2.33 1.00 ') ') Well KTU 32-7h, Kenai gas Field Final Directional Surveys MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 10,709.00 90.50 271.00 8,732.83 -1,379.27 -1,367.04 1,367.04 6.18 -6.06 1.21 10,739.00 88.90 271.00 8,732.99 -1,378.74 -1,397.03 1,397.03 5.33 -5.33 0.00 10,771.00 89.20 271.00 8,733.52 -1,378.19 -1,429.02 1,429.02 0.94 0.94 0.00 10,800.00 89.90 271.00 8,733.75 -1,377.68 -1,458.02 1 ,458.02 2.41 2.41 0.00 10,833.00 90.60 271.00 8,733.60 -1,377.10 -1,491.01 1,491.01 2.12 2.12 0.00 10,865.00 89.30 271.30 8,733.63 -1,376.46 -1,523.01 1,523.01 4.17 -4.06 0.94 10,897.00 89.20 271.00 8,734.05 -1,375.82 -1,555.00 1 ,555.00 0.99 -0.31 -0.94 10,928.00 89.30 271.00 8,734.46 -1,375.28 -1,585.99 1 ,585.99 0.32 0.32 0.00 10,959.00 89.00 271.00 8,734.92 -1,374.74 -1,616.98 1,616.98 0.97 -0.97 0.00 10,986.00 89.00 271.00 8,735.39 -1,374.27 -1,643.97 1,643.97 0.00 0.00 0.00 11,020.00 89.30 271.00 8,735.89 -1,373.67 -1,677.96 1 ,677.96 0.88 0.88 0.00 11 ,051.00 90.30 271.70 8,736.00 -1,372.94 -1,708.95 1,708.95 3.94 3.23 2.26 11,082.00 90.30 271.70 8,735.84 -1,372.02 -1,739.94 1,739.94 0.00 0.00 0.00 11 ,111.00 91.10 271.70 8,735.48 -1,371.16 -1,768.92 1,768.92 2.76 2.76 0.00 11,143.00 91.10 271.70 8,734.87 -1,370.21 -1,800.90 1,800.90 0.00 0.00 0.00 11,173.00 89.90 272.00 8,734.61 -1,369.25 -1,830.89 1,830.89 4.12 -4.00 1.00 11,206.00 89.90 271.30 8,734.66 -1,368.30 -1,863.87 1,863.87 2.12 0.00 -2.12 11,234.00 90.30 271.70 8,734.62 -1,367.56 -1,891.86 1,891.86 2.02 1.43 1.43 11 ,267.00 90.60 271.70 8,734.36 -1,366.58 -1,924.85 1,924.85 0.91 0.91 0.00 11,298.00 90.00 271.70 8,734.19 -1,365.66 -1,955.83 1,955.83 1.94 -1.94 0.00 11,329.00 89.10 272.00 8,734.44 -1,364.66 -1,986.82 1,986.82 3.06 -2.90 0.97 11,359.00 89.10 271.70 8,734.91 -1,363.69 -2,016.80 2,016.80 1.00 0.00 -1.00 11 ,390.00 89.70 271.30 8,735.23 -1,362.88 -2,047.78 2,047.78 2.33 1.94 -1.29 11,422.00 90.30 271.70 8,735.23 -1,362.05 -2,079.77 2,079.77 2.25 1.87 1.25 11,452.00 91.00 271 .70 8,734.89 -1,361.16 -2,109.76 2,109.76 2.33 2.33 0.00 11,483.00 89.90 272.00 8,734.65 -1,360.16 -2,140.74 2,140.74 3.68 -3.55 0.97 11,514.00 90.20 272.00 8,734.62 -1,359.07 -2,171.72 2,171.72 0.97 0.97 0.00 11 ,545.00 90.40 272.00 8,734.46 -1,357.99 -2,202.70 2,202.70 0.65 0.65 0.00 11,577.00 89.20 273.10 8,734.57 -1,356.57 -2,234.67 2,234.67 5.09 -3.75 3.44 11 ,607.00 89.00 272.40 8,735.04 -1,355.13 -2,264.63 2,264.63 2.43 -0.67 -2.33 11,639.00 89.10 272.70 8,735.57 -1,353.71 -2,296.59 2,296.59 0.99 0.31 0.94 11 ,667.00 88.00 272.40 8,736.28 -1,352.46 -2,324.56 2,324.56 4.07 -3.93 -1.07 11,698.00 87.70 271.00 8,737.44 -1,351.54 -2,355.52 2,355.52 4.62 -0.97 -4.52 11,729.00 88.00 271.00 8,738.61 -1,351.00 -2,386.49 2,386.49 0.97 0.97 0.00 11,761.00 88.10 271.00 8,739.70 -1,350.44 -2,418.47 2,418.47 0;31 0.31 0.00 11,791.00 88.40 271.00 8,740.61 -1,349.92 -2,448.45 2,448.45 1.00 1.00 0.00 11,857.00 88.40 271.00 8,742.46 -1,348.77 -2,514.42 2,514.42 0.00 0.00 0.00 ) ') ') ) MARÄTHON'OIL COMP,ANY Page 1 of,' t. WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R.C. Lawson CURRENT STATUS Prepare to move rig. 24 HR FORECAST Move and begin R/U rig. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 , DÇiily'Drilling Repprt GL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 1 3/16/20 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00(%) 92.20(%) 14,121.50 14,121.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST NON E 3/14/2002 I NEXT CASING 139.0 (ft) 13.375 (in) @ 1,500.0 (ft) LEAKOFF PPG STATElPROV Alaska I COUNTY/OTHER I LAST CASING Kenai Borough 20.000 (in) @ OP COMMENTS: RID rig. " ,OP~F=I~TIºNS~LlI\II,M'(\F1Y, FROM· '"TO::' '.. :H'RS'" PEPT,",,'FM· DEPTH TO . ':·BUB =PH'I\SE. . DËs6RipT.lq~.,.. 12:00 00:00 12.00 MIRU, Accept rig FIKBU 23X-6 @ 12:00hrs 03/15/2002. 00:00 06:00 6.00 UD top drive and torque tube, rotary motor, beaver slide, back wind walls. Blow down water and steam. RID rig air. UD liner and matting boards. MIRU Remove back landing, scope down derrick, layover derrick and prepare to move. Pull electric lines. RID outriggers, carrier tie down turnbuckles" stairs for sub and pits, flowline and panick line. Split pits from pump room. Raise carrier skirts. . . .. ,;' 'COMPANY Marathon Inlet Drilling Alaska ,:':SERVICE ',' , PE,RSONNELDATA':" , ~O.: HOURS' , , COIV!P~NY: ':' 1 18.00 Alaska Petroleum Contra 17 156.00 Weaver Brothers .. ': :: SE~VICE , NO. ", H'OORS;', 3 21.00 1 6.00 ":. , Printed: 3/18/2002 7:21 :31 AM ·." 'SUB' FRP~, ' TO ,HRS DEP1:H FM DEPTH TO 06:00 12:00 6.00 12:00 1'8:00 6.00 18:00 00:00 6.00 00:00 06:00 6.00 ), WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R.C. Lawson CURRENT STATUS RlU rig. 24 HR FORECAST Complete R/U rig. Prepare to spud. FIELD NAME ] STATElPROV Kenai Alaska OP COMMENTS: Move and R/U rig. , '.. CO~PANY" Marathon Inlet Drilling Alaska Alaska Petroleum Contra SERVICE' ') MARATHON Oll,COMPANY Pa.ge'1 ,of 1 Daily Drilling Report IGL 66,,00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 2 3/17/21 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI ! NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 19,890.00 34,011.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/14/2002 I NEXT CASING 139.0 (ft) 13.375 (in) @ 1,500.0 (ft) I COUNTY/OTHER I LAST CASING Kenai Borough 20.000 (in) @ LEAKOFF PPG OPERATIONS SUMMARY . , .. , . . . ... . '.' . . , .. ..".,. ,., , , . , . ' , .. " , , ,. . , ,PHASE MIRU MIRU .. DESCRIPTION '" Load out fuel tank, water tank, boiler, generator, pits, pump room, dog house, carrier, scope down sub and move to KBU 32-7H. Spot sub base, bring in mud boat and spot. Pull pit room and pump room together and stab dresser sleeves. Raise and pin off sub base. Install outriggers. Spot carrier and level. Raise derrick. Set drillers doghouse, choke house, flowline, stairs and landings, back floor plate and back wind walls. Raise and pin front windwalls. R/U steam, air and water lines. RlU stand pipe, cement line and shock hose. Pull electric lines. RlU guide lines. RlU derrick tarpes and carrier skirts. R/U rig hydraulics. lay water lines and fill water tanks. Scope up derrick. R/U lights and geronimo line. Set in trip tank. Sopt in catwalk and beaver slide. MIRU MIRU , ,P,ERSONNELDATA NO..', 1 17 2 , HOURS" 18.00 156.00 24.00 COMPANY, Weaver Brothers Vecco , SERViCe, , , NO.'" ': HOURS: ' 3 25.00 1 12.00 Printed: 3/18/2002 7: 19:41 AM ') ') 'MARATHON:OILCOMPANY' . . . . , "Pag~ i of 1- WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R.C. Lawson CURRENT STATUS N/U diverter. 24 HR FORECAST Spud well. Drill ahead. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling Rep()rt GL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 3 3/18/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 1 MOC WI 1 NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 27,915.00 61,926.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 I NEXT CASING 139.0 (ft) 13.37,5 (in) @ 1,500.0 (ft) LEAKOFF PPG 1 STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 20.000 (in) @ OP COMMENTS: R/U rig. N/U diverter. C/O liners. : FROM Tp...." HRS, 06:00 12:00 6.00 , , .. , . . ., . DEPTH FM:DEPTH TO , "'OPE~AT~().N$':§UMMA~Y: ,.,..".."." , ,. :,SUB, ,:~t1ASE," "!:.,, '~ESCRIPTION" MIRU R/U drillers console, snubbing post, carrier frame and tarps, carrier mufflers. Install rotary motor. R/U brake linkage. P/U and M/U torque tube. Hang torque tube and install turnbuckles and adjust. P/U and R/U top drive. Weld on head to conductor for diverter. Place diverter near sub. R/U rig floor. Hang tongs and spinners. R/U geolograph line. Install choke and kill line. N/U diverter. CIO liners in pumps to 5.5". 12:00 17:00 5.00 MIRU 17:00 18:00 1.00 18:00 00:00 6.00 MIRU MIRU 00:00 06:00 6.00 MIRU ... , 'PER$ONNE~'I?'ÄtA. ~'NÓ. tïoLJI~s:' ":':.' COMPANy:' 1 18.00 Weaver Brothers 17 156.00 Vecco 2 20.00 , , . " ''':,':, ÇOM~ANY:: "<, 'SERVICE:''- Marathon Inlet Drilling Alaska Alaska Petroleum Contra 'SERVicE ,... ;',' iNO;,:: ,:: : .H:ÖURS,,' 1 4.00 1 12.00 Printed: 3/18/2002 7:01 :04 AM .. .."... .... ... '" .. .... ..... ...... . .... . .... ... . . .... .. . . .. . . . .. . . . ..... . . ... "' .... .. ...... .. . .' ,". .... . . . .......... ... .... ....... . . . ........",... ..... ...."... .. .. .... ",.>.[:j~¡ Iy.. t.>r¡ IO:r]:~iRep9rt: ST I KB I GL 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE OH 87.00 66.00 494.0 551 551 4 3/19/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO.' I AFE COST GLACIER DRILLING 1 907-283-1312 11,6300 01.G0338.CAP.rPRL3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%~ 34,567.00 96,493.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 I NEXT CASING 139 (ft) 13.375 (in) @ 1,500 (ft) ') ) . .. ... .. ". . ... ..... .. . . .... ... .. ... ...... .. . .. ... . . . . ... . . . ... . .. . .",. '. .."...... ... . . .. '. ... .. . . .. ... ". . .... .. .. . .. ,".. .... . '. ..", . ... .. .", .. .. ..... .." .. . . ..... .... .... . .. ,·MARATHoN OILêo.MPANY' WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R.C. Lawson CURRENT STATUS Drillinç¡ ahead @ 551'. 24 HR FORECAST Drill ahead to 1500'. Condition hole. Run 13 3/8" CSG. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borouç¡h 20.000 (in) @ LEAKOFF PPG OP COMMENTS: Test diverter. P/U DP. Mix mud. P/U BHA. Cleanout conductor F/5T to 139'. Drill new hole F/139' to 551'. :"'::.1,,",:..:·: . ....... ..... ...... )iØB..~~r:'~N~§;:i$!O:M:·NI'J\RY T9' ,.H~{$;t)l;prH,FM ',Q~PfHt9 .SUa :pHÄ$~' 06:00 09:00 3.00 AF MIRU R/U kill line to conductor. R/U derrick windwalls. Set mouse hole. Function test mud pumps. Test diverter. Perform accumulator test. Repair air leak on drawworks. P/U 4" DP drift M/U and rack back. CIO shaker screens. Mix mud. MIRU Cont. mix mud. Spot cement silos. MIRU Cont. P/U and rack back DP(total 50jnts). MIRU Drift and M/U 5" HWDP(25jnts) and 1-61/2" drilling jars. Rack back in derrick. MIRU M/U 17.5" bit and 8" mud motor BHA. DRLSUR Clean out conductor F/5T to 139'. Drill new hole F/139' to 152'. Circ. hole clear. - DRLSUR Rack back 4 jnts 5" HWDP. M/U and scribe collar MWD tool. DRLSUR Drill F/152' to 551 '(totals ART=4.87hrs AST=.13hrs). 09:00 09:30 0.50 09:30 12:00 2.50 AF 12:00 14:00 2.00 AF 14:00 16:00 2.00 AF 16:00 20:00 4.00 AF 20:00 21:30 1.50 AF 21 :30 23:30 2.00 57 152 AF 23:30 00:30 1.00 AF 00:30 06:00 5.50 152 551 AF MIRU MIRU T~';N$,tY~~~g)1 8.80Ip~:1 ,.."lëþQI" JIVIUD DATAl DAILY COST I '·>Þ\l ':PŸfYP:;<3~~Š. .VV'-fHT~~ .. ·pcrr.$ÓL . þlLIWAt 'ill{~$~ri~'MBT Ph/pM 74 18/28 24/37 18.01 3.014.0 961 0.25/20.0 1010.3 625.00 Pf/Mf 0.3/0.8 CUM COST 1,875.00 CI Ca H2S LIME ES 200 1 Ii 17.500 Smith MSDGHQC BIT / RUN 1 I 1 WOB RPM 45 I 70 GPM 550 LK 1029 12/18/18/1811 57.0 3/1812002 O-O----~- PRESS 850 P BIT 335 HRS 5.00 24Hr DIST 494.0 24Hr ROP 98.80 CUM HRS CUM DEPTH CUM ROP 5.00 494.0 98.80 BHA~Ö. ···I~EŠ~~::9: BHA DESCRIPTION »'i;'BHA ~/;. .'..' '., . '. :».. /"':'···>u ..,.. ....... , lEFF~'-; PICK46P '1$4A~6ÞF1RÓT4~T,::ITQRi%~6~~X:~~) .... '·IB8A;R$IJAR8~6S'IMWb9HR$'IMJ"R~~S:'IS$ 8:~ Bit, 8" M1C MOTOR 1.2AKO W/17 1/4" UBS ,17" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP, 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub, 4" 14 PPF S-135 HT-38 PUMP I HYDRAULIC DATA NO. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 1 OILWELL 8.000 5.500 110 255.23 850 510.46 2 OILWELL 8.000 5.500 110 255.23 850 510.46 SURVEY DATA MD INCL AZIMUTH TVD VS N/SCUM E/W CUM DOGLEG MD INCL AZIMUTH TVD VS N/SCUM EIW CUM DOGLEG 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 315 1.00 180.60 314.95 -0.43 -5.20 0.43 0.85 194 1.40 174.70 193.98 -0.22 -2.36 0.22 0.72 376 1.20 183.40 375.94 -0.38 -6.37 0.38 0.34 254 1.50 174.70 253.96 -0.36 -3.87 0.36 0.17 437 1.40 158.80 436.92 -0.62 -7.70 0.62 0.96 COMPANY Marathon Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Weaver Brothers 17 156.00 Baker Hughes Inteq SERVICE POB @ 06:00: NO. HOURS 1 6.00 2 48.00 Printed: 3/19/2002 10:09:54 AM ) ) WELL NAME KENAI TYONEK UNIT 32-7H . .... . ...... .. ... .......... . ..... .. . ". . . . . .. . .. .. . . "' . . .. .. . . ..... ... .·,Ø,éiiIY:ºriniHg:·~~·pqrf.., ' GL 124 HRS PROG ITMD 66.00 494.0 551 TVD 551 DFS 1 REPT NO. I DATE 4 3/19/2002 POB @ 06:00: NO. HOURS 1ST IKB OH 87.00 COMPANY M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 24.00 SERVICE . .. ,". ....... ...."",.. " 'cASING SUMMARY LAST CASING TEST: MD (ft) TVD (ft) WT (Ib/ft) 139 139 133 LAST BOP TEST: SiZEOh) 20.000 ID (in) LOT (ppg) 18.730 NEXT BOP TEST: GRADE K-55 BURST (psi) 3,060 Printed: 3/19/2002 10:09:54 AM ) MARATHON :OlL COMPANY , , , , , , ,Daily :Dr~Uirlg :Reþor,t ' IGL 66.00 ') Page'1 of; 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS P.O.H. to run casing 24 HR FORECAST Run and cement casing /nipple up I test BOP s FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 20.000 (in) @ 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 969.0 1,520 1,520 2 5 3/20/2002 1 RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 1 MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 64,568.00 162,742.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 I NEXT CASING 139.0 (ft) 13.375 (in) @ 1,500.0 (ft) ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: Drilling to casing point @ 1520 I P.O.H. to run pipe 'i~ROIY': 06:00 10:00 11:00 00:00 01:00 03:30 04:30 , ,to" ':' HFi$ 10:00 4.00 11:00 1.00 00:00 13.00 01 :00 1.00 03:30 2.50 04:30 1.00 06:00 1.50 , bEPTH'FM, 551 853 853 1,520 1,520 1,520 1,520 LEAKOFF PPG ... . . .. , ' .. . , . H"':'" ';1:1"'" DEPTH TO 853 853 1,520 1,520 1,520 1,520 1,520 , ,OÞER-A110NS,'"SÜMMARY " ':.:' ::PHAse:'·""",··,',·,",·,·,·,' 'I , ' "" ,PESCÄIIJ'fI'ON'::' , DRLSUR Drilling from 551' to 853' DRLSUR C.B.U. I Change out saver sub DRLSUR Drill from 853' to 1520' DRLSUR Circulate and Condition Hole DRLSUR Short trip to jars I S.L.M. (no correction) DRLSUR Circulate and Condition Hole for casing DRLSUR P.O.H. to run casing ::: '::SUB . ,., :<D~~S.:IJ)'t~'P~),.I 9.20 !:;ÞP:' ,IEte IMU'IJ.':;~AtÂI,p"I'Lv:CqST::1 2,191.00 1'~LJJlAçó~-r:'l 5,747.00 ,<:'.'F-V:: ~¡, ",~,vri.~ "J.';ELS" 'V!LJ.tIT:H.P, , .:FCrr.;SOL ,..OIUWA T' ,:"%~¡:aod!M~'T:;,' ::.::' '~Ji/pM ,;': : pt/Mf'::', Çl "Ca:<'::':' ,H2$::: ,LIMe:' ,E$) 50 13/21 22/25 10.61 2.0n.0 96/ 0.25/17.5 10.00/0.2 0.1/0.6 200 40 I.:: I \/..';: : ;\ I g ,;,Si,"'i :F.I'~N '; :} ,Size; :'.. 1 /1 17.500 BIT I RUN 1 / 1 :', "I ::~~~U,f"'·;': ' Smith WOB 10/20 ,'J~YP~'.', "',:' se~I'þ'~ ~b."~1:0~ :'j;ËT:::Ò~~~A' ,: MSDGHQC LK 1029 12/18/18/18// "I, " ' r:..1 . .1'· . .. , ':/ Ö~¡)TÚ:IN .,~ D~"E J'~':',::'" ,':,:',:. i-9~O~'L~B~G~~,~R; ':'" 57.0 3/18/2002 0-0------ RPM 70 /75 GPM 557 PRESS 1,270 HRS 17.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 969.0 57.00 22.00 1,463.0 66.50 ^, :;" " 'i ,'; ", ":, , ,,' : :: ,':,', ' ,', ,:..:.: :', '<~ ::~i:: "!,:,T~BA":, >: ': ,\' :, :"',"1' ;: ~ ::> :' : ::,:,,; <":' '; ,": :.. ',','" '~'-:¡;¡',::::, .6H~:~o.. IL~~~:~, leFF~. ':IPlq~6F,:' S~~60~tß~T~':/:" T0f1¡,~6~¡~~~~):' :,>EJHA~RS, ,,\~A~~6~" ,1~WD,HRS.':-]MTR;'HRS'ls~ HRS,: BHA DESCRIPTION Bit, 8" M1 C MOTOR 1.2AKO W/17 1/4" UBS , 17" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP ,6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP, Cross-Over Sub, 4" 14 PPF S-135 HT-38 , " .¡" -:.".. PBIT 359 ::.. NO~::; :,; , ',fv'lAKE,OFPUMP' , 1 OILWELL 2 OIL WELL ';: :'PUMP.j HYDRAULIC' DÄTA: '," " , STROKE '(in) '~INER{o)", ;' S~M, ': ,'Q"(gp~) , PRESS. (~~i) , 8.000 5.500 120 278.43 1,270 8.000 5.500 120 278.43 1,270 T~TAL,Q, :,KILL.~PM I PR,ESSURE 556.86 556.86 'M.D., 498 559 619 680 740 800 866 928 989 COMPANY Marathon INCL. , 1.50 1.30 1.10 1.10 0.80 0.90 0.70 0.70 0.90 , AZI 179.90 148.60 164.10 160.20 197.20 159.50 212.30 288.20 27.30 ~ c .:' . , " , ' S,URVEY, DATA TN.D. N/S CUM EIW.CUM SECTI"ON "M.D. 497.90 -9.19 0.89 -0.89 1,051 558.88 -10.58 1.25 -1.25 1,113 618.87 -11.72 1.76 -1.76 1,175 679.86 -12.83 2.12 -2.12 1,238 739.85 -13.77 2.19 -2.19 1,301 799:85 -14.62 2.23 -2.23 1,364 865.84 -15.44 2.20 -2.20 1,427 927.84 -15.64 1.64 -1.64 1,467 988.83 -15.10 1.50 -1.50 1,520 'INCL. 0.80 1.10 0.90 1.10 1.00 1.10 1.30 1.80 1.80 SERVICE PERSONNEL DATA NO. HOURS COMPANY 18.00 Inlet Drilling Alaska AZI 304.70 298.40 257.30 285.40 256.20 272.70 290.00 274.90 274.90 T.V.D. 'N/S cullil E/W CUM SECTION: 1,050.83 -14.42 1.37 -1.37 1,112.82 -13.89 0.49 -0.49 1,174.81 -13.72 -0.51 0.51 1,237.80 -13.67 -1.57 1.57 1,300.79 -13.64 -2.69 2.69 1,363.78 -13.74 -3.83 3.83 1,426.77 -13.47 -5.11 5.11 1,466.75 -13.26 -6.16 6.16 1,519.73 -13.11 -7.82 7.82 SERVICE NO. HOURS 17 156.00 Printed: 3/20/2002 6:54:50 AM WELL NAME KENAI TYONEK UNIT 32-7H " COMPANY,:,'" Baker Hughes Inteq M-I Drilling Fluids 0) 1ST IKB OH 87.00 S'ËiWICE ,,'MARATHON, OI'L COMPANY 'Qally Drilling 'Report GL 124 HRS PROG ITMD 66.00 969.0 1,520 ,'PI:RSº~~E:L DA"TA' : ,..,., NO. HOURS' , COMPANY 2 48.00 Weatheriord Completion 1 24.00 ) ITVD IDFS 1 ,520 2 , 'SERVICE' P~ge '2 of, 2, I REPT ~o. Printed: 3/20/2002 6:54:50 AM JDATE 3/20/2002 NO., 2 HOURS, 8.00 ') ) , " MARATHON OILCOMPÀNY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS W.O.C Iclean pits I nipple down diverter 24 HR FORECAST Nipple up stack I test BOP s Imix mud / drill FIELD NAME I STATElPROV Kenai Alaska Daily Drillirl~ Re:port ST I KB I GL 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE OH 87.00 66.00 1,520 1,520 3 6 3/21/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11,63VD 01.G0338.CAP.~RL3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%' 105,393.00 268,135.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 I NEXT CASING 139 (ft) 13.375 (in) @ 1,500 (ft) I COUNTY/OTHER I LAST CASING Kenai Borouç¡h 20.000 (in) @ LEAKOFF PPG OP COMMENTS: Ran and cemented casing I WOC I nippling down diverter '. ' , 'þPE;RATIÇ>N'S SUMMARY, DEPTH,FM DEPTH TO "'SUB, "PHAsE' ", 1,520 1,520 AF DRLSUR P.O.H. to run 133/8" casing 1,520 1,520 AF CSGSUR Rig up tongs; spider; Weatherford tools to run pipe 1,520 1,520 AF CSGSUR PJSM I Run 37 Jts. 133/8" - 68# L80 casing (Shoe @1517 I stab in @ 1471) 1,520 1,520 AF CSGSUR Make up head pin and circulate well 1,520 1,520 AF CSGSUR Make up seal nipple on 4" drill pipe I R.I.H I space-out and stab in @ 1471 1,520 1,520 AF CSGSUR Circulate and Condition Hole 1,520 1,520 AF CSGSUR PJSM I Test lines to 2000 psi I OIK -- Pump 40 bbls. Mud Clean 2 @ 8.4 ppg; followed by 614 sks. (274 bbls.) Class "G" cement @ 12.0 ppg. with 20% MPA-1; 20% LW-6; .3% CD-32;1 % SMS; 1.5% calcium chloride and 19hs FP-6L I good cement @ pits @274 bbls.;displaced w/15 bbls. drilling mud to 15' above stab-in /Floats held I C.I.P @ 0130 CSGSUR P.O.H. w/ drill pipe I Lay down seal nipple CSGSUR WO Cement / Wash cement from diverter assembly and flowline / Lay down all casing tools I centralize casing / cleaning pits FROM 06:00 08:00 12:00 16:30 19:30 22:30 00:00 TO. 08:00 12:00 16:30 19:30 22:30 00:00 01:30 'HR$,' 2.00 4.00 4.50 3.00 3.00 1.50 1.50 01:30 02:30 1.00 02:30 06:00 3.50 1,520 1,520 .. " . " ", .: c· ,DESCRIPTioN', ',' ' 1,520 AF 1,520 AF D,ENSITY(ppg) 9.20 :pp:1 ,IECDIIMUDDATAI'DAI~YC()STI "¡;V' ,PVlVP ):~EL;S ' 'WLlHTHP:' 'FciT.SOL. c;>1L./WAT' %Si"nd/MB't,: '~h/pM.' 45 16/14 8123 9.61 2.0/6.0 961 0.25/15.0 10/0.1 . BITIRUN' '<SIZE:::;, 1/1 17.500 BIT I RUN 1 I 1 'MAN~F. Smith WOB 1 0 I 20 RPM 70 I 75 1,455.00 Pf(Mf' ' 0.1/0.7 I,CU~"C9STJ 7,202.00 , ,cr' Ca:: H2S:, L.IME' e5 200 40 , TYPE MSDGHQC 'BITS' :':SERIA'L. ~q. ':JËTS"O~'TFA::" ,": : DEPJ'tHN ;'[jÄTE;IN ,,::' , 57.0 3/18/2002 , ",: i~Ó~D~L.·B~G~Ö.R; , 2-2-EC-A-E- 1-NO-TD .T. ,T· I LK 1029 12/18/18/18// GPM 557 24Hr ROP 57.00 CUM HRS CUM DEPTH CUM RQP 22.00 1,463.0 66.50 PBIT 359 HRS 24Hr DIST PRESS 1,270 BHA NO. "I LI:NGTH " 1 858.49 BHA DESCRIPTION EFF WT. PICK UP SLACKOF1 ROT WT. 'ITO~~~(maX/min)' "I BHAHRS :IJAR~~S: 'Mw6'8RS.MTR ~RS' JSS'H~S o 60 60 60 4,500/1,500 17.00 I Bit, 8" M1C MOTOR 1.2AKO W/17 1/4" UBS, 17" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP, 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub. 4" 14 PPF S-135 HT-38 NO. 1 2 OILWELL OILWELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids MAKE OF PUMP PUMP" HYDRAULlC,DATA STROKE (in)L.INER (in) ',SPM Q(gpm) 8.000 5.500 75 174.02 8.000 5.500 75 174.02 PRESS. (psi) ,TOTAL Q 695 348.04 695 348.04 KIL.L. SPM I PRESSURE SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Weatherford Completion 17 156.00 Epoch Well Services 2 48.00 BJ Services 1 24.00 POB @ 06:00: NO. HOURS SERVICE 2 2 4 8.00 8.00 32.00 Printed: 3/21/2002 10:00:14 AM ) ) , 'MARATHON OIL COMPANY' Page,'2 öf2! , Daily' DriUing R~'port,' I GL 124 HRS PROG I TMD 66.00 1,520 WELL NAME KENAI TYONEK UNIT 32-7H 1ST IKB OH 87.00 LAST BOP TEST: SIZE (in) 20.000 '10 (in) LOT (ppg) . ' 18.730 MD (ft) 139 CASING SUMMARY LAST CASING TEST: TVD (ft) 139 WT (Iblft) 133 TVD IDFS 1,520 3 NEXT BOP TEST: GRADE, K-55 1 REPT ~o. ¡DATE 3/21/2002 ,. BURST (psi)', ' 3,060 J Printed: 3/21/2002 10:00:14 AM ....... . . ..... ... ..... . .... ... . . .... . . .. .... ... .' .. . . ... .. ... .... . ........ . ... . . ........ . .. . ... . . . ... ... ... ... ... .. .. ... .. . . .. ... . . . ... . .. .... ...... . . .. ...... .. .. ... .. .. ... ... ... ..... .. ... ..... . ..... ... .... . .... . ..... . ....... . .. '. ... .... .. . . . .... .. . .. ..... ........ .. . ';¡'IVIARÄTHONOILÖt>MPANY ) ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Testing BOP, s I Wait on Vetco rep. 24 HR FORECAST Pick up drillpipe I test csg. / drill out FIELD NAME I STATElPROV Kenai Alaska . .. ... .................. .. . . ", ... ... .. ......... . .. .... ....... ... ........ ....... . ... . . . ....... ... ....... ... .... ..................... ... ... ................. ...... . . . . ..... ... .... ..... .... .... .. . .......... ...... ....... . ..... .. .. .......... ..... ...... ......... ... .. ....... ..... ...... ... ....... . ....... ... . . ....... . ...... .... . ....... . .. ..... ...... ...... .... . .. ...... .............. .......... ........... ... .. ... ,'...... ·D~,iI5f[)rilïin9¡a~.pqrf, ..' . GL 66.00 TMD TVD I DFS 4 REPT NO. I DATE 1,520 1,520 7 3/22/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 26,457.00 294,592.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING Kenai Borough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) \24 HRS PROG ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 LEAKOFF PPG OP COMMENTS: Nipple down diverter / nipple up stack OPERATIONS SUMMARY , ' , FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 12:00 6.00 1,520 1,520 DRLlN 1 Nipple down diverter pipe and diverter I Rough cut 13 3/8" I Nipple down and load out diverter 12:00 16:00 4.00 1,520 1,520 DRLlN 1 Cut 20" and 13 3/8" at elevation and dress for casing hanger I Set in slip -on hanger,run in screws and test to 1860 psi/15 min 16:00 02:30 10.50 1,520 1,520 DRLlN 1 Set in 13 3/8" stack I Hook up all lines and controls / Function test BOP s; pick up test jt. and fill stack wI water 02:30 06:00 3.50 1,520 1,520 DRLlN 1 Test BOP s I ( Found crack in btm. flange of tubing spool) "Þ¡;f\J~ïTy(þþg) 9.20 I PP I :,',FY, ' 'FWNp ;'qE:~$¡, :WLltiTHP,¡F:Crr.soL 43 14/16 9121 I 2.0/6.0 I ECD I I MUD DATAl DAILY COST I OIUWAT %Sand/MBT Ph/pM 961 0.25115.0 9.00/0.1 1,007.00 Pf/Mf 0.1/0.8 I,Cù,MþC)~t:1 8,209.00 CI Ca H2S LIME 200 80 ES COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 17 228.00 Epoch Well Services 2 48.00 SERVICE NO. 1 2 HOURS 24.00 24.00 Printed: 3/22/2002 7:27: 16 AM ) ) 'MARATHON OIL COMPANY " ",Page t.9f.2':" WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Drilling 24 HR FORECAST Drill w/ surveys FIELD NAME Kenai , ' , " , , , DC:¡ily,DriUing Report ST I KB I GL 124 HRS PROG' TMD TVD I DFS 5 REPT NO. I DATE OH 87.00 66.00 1,520 1,520 8 3/23/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 65,208.00 359,800.50 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska KenaiBorough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 OP COMMENTS: Test Bops / repair tbg. spool and load shoulder Idrill to 1540' and changeover mud , , OPERATIONS SUMMARY 1:':":'':-- ' , FROM, . I 'I'''·. "I' ""'." , " ... ""..". ".,,, . ""1',1 .. 'I', " 'TO,,: , HRS,:,: 'DEPTH FM, DI;PTH TO SUB ',' : PHASE: DESCRIPTION 06:00 13:30 7.50 1,520 1,520 DRLlN1 Bottom flange of tubing spool leaked during BOP test / Inspection revealed improperly drilled lock-down had been plugged and welded I Weldor brought to location by Vetco and leak was repaired I Service rig / Run HWDP into hole / Pick up and stand back 15 stds. drillpipewhile wellhead was being repaired 13:30 14:00 0.50 1,520 1,520 DRUN 1 P.O.H. wI HWDP to test repaired lock-down hole 14:00 15:00 1.00 1,520 1,520 DRUN1 Install test plug / Test repairs -OK 15:00 18:00' 3.00 1,520 1,520 DRUN 1 Finish testing BOP s I Koomey performance test -OK 18:00 22:00 4.00 1,520 1,520 DRUN1 Nipple down stack below tubing spool to repair scratch on load shoulder caused by running test plug improperly I Nipple up stack 22:00 00:00 2.00 1,520 1,520 DRUN 1 Test btm. flange of tubing spool and kill line I OK 00:00 01:00 1.00 1,520 1,520 DRLlN 1 Make up BHA and test MWD 01:00 02:00 1.00 1,520 1,520 DRUN 1 R.I.H. to firm cement @ 1469' 02:00 02:30 0.50 1,520 1,520 DRUN1 Test casing to 1500 psi I OK 02:30 03:30 1.00 1,520 1,540 DRlIN1 Drill Cement; float collars , shoe , and open hole to 1540' for leak - off test 03:30 04:00 0.50 1,540 1,540 DRlIN 1 Circulate and Condition Hole 04:00 05:00 1.00 1,540 1,540 DRlIN1 Perform leak - off test (270 psi; 1540' ; 9.35 MW ) = 12.7 EMW 05:00 06:00 1.00 1,540 1,540 DRlIN 1 Change over mud to 8.8 ppg Flo - Pro :,..'q~~$I:rv(ppg{!1 8.85 1,:p~'1 I ECD, , ,IMU,D:DATAI,PA,I~V'COSt:1 11,399.00 I,GUMGøs~1\:1 19,608.00 ':..,,:'fY',;:.::,::p:vriþ,' ::::GELS' "WUHTH'p, :,;i=çff.SbL." :: OIUWAT:' '::'%~~ndlivlBt,' "\:Jpt'l/p~,:,: ':,~/,Mf.;:: I 'CI;' '.':: ::':,':Ca: :H~S;)" ':LIME .."ES.:' 58 8/24 12/17 14.01 1.013.0 961 I 8.8010.1 0.110.8 19,000 20 . ;, ,'BIT" RUN' 2/1 SIZE 12.250 "'..MANúF. Hughes 'TY.PE· MXC-1 BITS:: ' :',:SERIAL~JO: 'JETSORrF~,': , , ' , .. .'. \' 6000038 15/18/18/1811 C'E'PTtÙN D,A TejN 1,520.0 3/23/2002 ..'. ' .',.. ,'i~6-D~L.B~G~9'!R : 0-0------ BIT I RUN 2 11 WOB 5 I 10 RPM 70 1 75 GPM 600 PRESS 1,200 PBIT 348 HRS 0.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 20.0 40.00 0.50 20.0 40.00 8,HA NQ. LENGTH 2 859.23 BHA DESCRIPTION BHA EFF wT. 'I PICK LIP SLACK OF~,ROT WT. TORQU~ (maximin) BHA HRS I JAR HRS MWD HRS MTR MRS SS HRS o 1 I 500 I 1 ' 1 1 1 Tri-Cone Bit, Bent Sub Motor, Intergral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 8.000 5.500 75 174.02 600 348.04 8.000 5.500 75 174.02 600 348.04 COMPANY Marathon Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Baker Hughes Inteq 16 216.00 M-I Drilling Fluids SERVICE NO. HOURS 2 48.00 1 24.00 Printed: 3/23/2002 9:46:08 AM WELL NAME KENAI TYONEK UNIT 32-7H COMPANY ,..' Epoch Well Services 1sT KB OH 87.00 SERVICE MARATHON OIL COMPANY OaUy Drilling Report I GL 124 HRS PROG 66.00 TMD 1,520 , ' :PI:B$q~NEL 'DATA' Nb~ .., HO.URS COMPANY 2 24.00 R&K Industrial ) ITVD 1,520 IDFS 5 SERVICE" ' Pag~ 2 'of. 2, I REPT ~o. I DATE 3/23/2002 NO. 'HOURS 2 18.00 Printed: 3/23/2002 9:46:08 AM ') ) ... .. . . ... ",.. . . ,.. .... . "'" . . .... .... . ... ... ... . .... ... . .... ...... .... ... .. . . . .... ..", .. . . . .... . .. ... .. . ... . .... ... '" ... . .. . . ". .. .... . . .. ... .... ,',.··.IV1~;~~~~.QN.~.I~.:G:(l);M;~·~.;~.~:·· · , ¡p~iIYl:>rilllng:ftêpqtr" ' GL 66.00 ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Drilling @ 3450' 24 HR FORECAST Drill FIELD NAME Kenai 124 HRS PROG TMD TVD 1,930.0 3,450 3,450 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 49,257.00 409,057.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 OP COMMENTS: Drill I Short trip I drill to 3450' FROM 06:00 21:30 22:30 00:00 00:30 01:30 TO HRS 21 :30 15.50 22:30 1.00 00:00 1.50 00:30 0.50 01 :30 1.00 06:00 4.50 DENSITY(ppg) I 9.15 FV PVNP GELS 46 8/21 10/14 DEPTH FM DEPTH TO 1,540 2,990 2,990 2,990 2,990 2,990 2,990 2,990 2,990 2,990 2,990 3,450 OPERATIONS SUMMARY PHASE SUB DESCRIPTION Drill Open Hole (Directional) from 1540' to 2990' C.B.U. I Check for flow Short trip to shoe @ 1517' Service Rig R.I.H. Drill from 2990' to 3450' DRLlN1 DRLlN1 DRLlN 1 DRLlN1 DRLlN 1 DRLlN1 I PP I WUHTHP 9,01 I CUM COST I 31,229.00 CI Ca, H2S LIME 22,000 60 I ECD I ¡MUD DATAl DAILY COST I FCrr.SOl OIUWAT %SandlMBT Ph/pM 1.0/5.0 961 0.25/4.0 9.0010.2 11,621.00 Pf/Mf 0.2/0.9 ES BITS BIT / RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B7G-O-R 2/1 12.250 Hughes MXC-1 6000038 15/18/18/18// 1,520.0 3/23/2002 0-0------ BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/1 5 I 20 70 /75 418 775 174 13.00 1,910.0 146.92 13.50 1,930.0 142.96 PUMP I HYDRAULIC DATA NO. MAKE OF PUM" STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 1 OILWELL 8.000 5.500 90 208.83 775 417.66 60 180 2 OILWELL 8.000 5.500 90 208.83 775 417.66 60 180 , ... ;SlJRVËY[)ÄTA . .. ..... . M.D.' All T.V:D; . rWS cUMEi'NëuMSECTï()N M;D; All· T.V;D.. , N/SCm,IIElWCUM ·SECrJON 1,553 1.60 280.80 1,552.71 -13.65 -10.08 10.08 2,431 1.60 25.40 2,430.53 -6.14 -14.51 14.51 1,616 1.40 283.10 1,615.69 -13.31 -11.70 11.70 2,494 1.50 23.50 2,493.51 -4.58 -13.81 13.81 1,679 1.50 281.60 1,678.67 -12.97 -13.25 13.25 2,557 1.60 23.50 2,556.49 -3.02 -13.13 13.13 1,741 1.00 254.00 1,740.65 -12.96 -14.57 14.57 2,620 1.40 21.00 2,619.46 -1.50 -12.50 12.50 1,802 0.60 231.60 1,801.65 -13.30 -15.33 15.33 2,684 1.50 63.80 2,683.44 -0.40 -11.47 11.47 1,865 0.70 236.80 1,864.64 -13.72 -15.91 15.91 2,748 1.80 48.50 2,747.42 0.64 -9.97 9.97 1,927 0.60 308.40 1,926.64 -13.73 -16.48 16.48 2,811 2.00 58.60 2,810.38 1.87 -8.29 8.29 1,989 0.30 231.90 1 ,988.64 -13.62 -16.87 16.87 2,874 1.80 73.80 2,873.35 2.72 -6.40 6.40 2,052 0.70 298.30 2,051 .64 -13.54 -17.33 17.33 2,937 0.80 82.00 2,936.33 3.05 -5.01 5.01 2,116 1.00 344.70 2,115.63 -12.82 -17.83 17.83 2,999 0.50 16.70 2,998.33 3.37 -4.51 4.51 2,179 1.30 1.90 2,178.62 -11.57 -17.95 17.95 3,063 0.10 193.50 3,062.33 3.59 -4.44 4.44 2,243 1.10 31.30 2,242.61 -10.32 -17.60 17.60 3,124 0.70 45.00 3,123.33 3.80 -4.19 4.19 2,306 1.70 28.40 2,305.59 -8.99 -16.85 16.85 3,186 0.60 24.20 3,185.32 4.36 -3.79 3.79 2,368 1.80 50.60 2,367.56 -7.56 -15.66 15,66 3,248 0.60 50.90 3,247.32 4.86 -3.40 3.40 Printed: 3/24/2002 11 :23:35 AM BHA NO. I LENGTH 2 859.23 BHA DESCRIPTION , ... .ÐHA I EFF WT. I PICK UP I SLACK OF~ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS 1 MWD HRS I MTR HRS I SS HRS o 83 83 I 83 1,500 14,000 28.50 1 Tri-Cone Bit, Bent Sub Motor, Intergral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over ) WELL NAME KENAI TYONEK UNIT 32-7H .. . . . ...... . . ... ... .... . . ... . .... . .. ",' . . .. .. .. . ..... . . .... .", . . . ..... ..... . .. .... ... .", . . .. .. . . '" . . . '" . . . . . ... .. . ·::·...,·.·.."i~~~ðW~ON·,9IL:.9·~·~·~~:~.~··.·,·'·,·'· ¡·.LQ~Uyprillirig·R.~p<?r~<: .. ,..' IGL 66.00 124 HRS PROG 1,930.0 ITMD 3,450 . . .. . ..... . ............. .. . . ... .. ..... . . 0"" ". ... '" ..... ..", .... ... . .... . . .. ...", .. . . "... ...... .. . . ... . .. .... ..... .. .. .. . . .. .. . . ...:::............:....;.;.::.;:.::.:.:.. ... T,v;D. ,,"¥$ ÞlJrvlE!'ttçÞNI :S,ªþ;r19N·. 114.20 3,373.32 5.60 -2.73 2.73 1ST \KB OH 87.00 3,311 . ... ..... .", . ........ ......... .... . ..... . , ....... "i: '(, .....:. .sq~V~'{[))XTA T.y;P;.·NI~þLJMËIW,Ç(~$ECtIØN ':. ·'.I\IIIj;: .< INc;L/. 19.40 3,310.32 5.38 -3.04 3.04 3,374 0.40 0.60 Marathon Inlet Drilling Alaska Baker Hughes Inteq '.:þE~SO·NNEt[).ATJ¥· ' , 'No;··.,. " ·.HÞµ8$.· '¢qMÞANY' ..... .., 1 18.00 M-I Drilling Fluids 16 216.00 Epoch Well Services 2 48.00 R&K Industrial ,'·,i'.: . SERVICE .....,.' . "' . . ....... ....... 1 2 2 24.00 24.00 24.00 Printed: 3/24/2002 11 :23:35 AM ) ') .. . .....", "' .. . .. . . . .. ...... . . . . . ..... .... .... ... ...", . ...... . .. ..... .. .... ... .... 0"·. . . . . .. . ... '·DallDrÏlÏin<Rè ·Orf., ,:... ,. .::.. ...¥ .:' ::. :".. .... S;l. .,: ,:. ... :. p.. .. '..: .: . , ST I KB I GL \24 HRS PROG I TMD TVD DFS I REPT NO. I DATE OH 87.00 66.00 1,300.0 4,750 4,749 7 10 3/25/2002 RIG NAME & NO. I RIG PHONE AUTH MC AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11 ,63~D 01.G0338.CAP.d>RL3,284,000 I MOC WI I NRI CAlLY WELL COST CUM WELL COST 100.00 (%) 92.20 (%' 55,231.00 464,288.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I NEXT CASING LEAKOFF PPG 1,517 (ft) 9.625 (in) @ 6,527 (ft) 12.73 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Short trip 24 HR FORECAST Drill FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borouç¡h 13.375 (in) @ OP COMMENTS: Drilling 3450' to 4750' / Short trip - ream tight spot @3420' :F~óM: '::¡rp:' 'HRS· 06:00 01 :00 19.00 01 :00 02:30 1.50 02:30 06:00 3.50 " .,' )).) ,....:: ::'" ....:.... ' :::;,...'; : '·'<()eI?R~tl(:)f\j:ª¡:¡$:~MM'*'~'«: DèpTH:FMPf;pi~TÒ: '". ;·.SÚB·, .,: :e~A$~: 3,450 4,750 AF DRLlN1 4,750 4,750 AF DRLlN1 4,750 4,750 AF DRLlN1 .. '" ..... .... .... .. . '" . . . . . . . .... . . ... .. ., .. .. .., .... ...... ....... ..... "... .", .. ... .", ... . . .. ... , . ... . '. ·:;::PE$ÞR¡é~IÞN:' Drill Open Hole (Directional) from 3450' to 4750' Circulate and Condition Hole Short trip (5) stds. into old hole I Tight @ 3420' pulling out I Reaming; working thru same spot running back in DENSITY(ppg) FV PVNP 46 10/22 9.30 GELS 11/16 I PP I WLlHTHP 9.41 IECDI IMUD DATAl DAILY COST I FC/T.SOL OILIWAT %Sand/MBT Ph/pM 1.0/7.0 96/ 0.25/5.0 9/ 16,467.00 Pf/Mf 0.1/1.3 I CUM COST I CI Ca 18,500 60 47,696.00 H2S LIME ES 2/1 12.250 Hughes MXC-1 6000038 15/18/18/18// 1,520.0 3/23/2002 0-0------ BIT I RUN 2/1 WOB 25 I 25 RPM 70 I 75 GPM 418 PRESS 1,050 PBIT 177 HRS 17.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 1,300.0 74.29 31.00 3,230.0 104.19 o 103 100 103 8,000 11,500 36.50 3 3 Tri-Cone Bit, Bent Sub Motor, Intergral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over ':~9. :' 1 2 . .. ..... .. . ... . ... ... ... ..... ... ........ ... .. ...... .... . .... ...... .. .... ..... .... ......: r .. ... ........ .......... .... .. ."""",,,,,,..,,,,,,, '" """" . '''''' " MAKEOF.PUfv'!P· . ' ,. ..... ..,pqlVï~l:fI~p~Q~lþ,g~TA ... 'STROKE(iri) 'LINER!I") ..' :SPM '. ·.<Hgpm) ... 8.000 5.500 90 208.83 8.000 5.500 90 208.83 .. . ...... . .... . ... ... .... ... .. ....... .... . ..... .. ...... ..'"""", . ,'. ' ". .,,'. Þ~~S$.Jþsi) 1,050 1,050 .'", '" ,.', .', ".." ",. . TOTÂLq.· .' 417.66 417.66 ... ........ ...... ::.':':'::: :.:..':'.:' :.'::.::.::"': ''':':.:'. ..:..:..... .:: . ....... .. ..... ................ ... . .. .... .......... .... .............. . ... ..... .. . .... ...."... ... .. ........ . . .... ... . . ....... ......... .... ........ .......... .... .... .......... .. .. . . . . . . . . . . . .. ... . .. ... ... .... ........ . ." ",,,".,,,,,,,,,,,,,,,,,,,,,,,,,,,, """'" " . ""'''' ".". ,·.KILLSpMq )~REš5URÊ: ..' 60 310 60 31 0 OILWELL OILWELL <sURVeYPArÂ ' MD INCL AZIMUTH TVD VS N/SëUM EIWC:UMDOGLEG MD 'INCL·· AZIMUTH TVD VS N/scOry1eÎWC:ûM DOGLEG 3,435 0.20 167.30 3,434.31 2.51 5.41 -2.51 0.53 4,129 0.40 250.10 4,128.30 1.42 5.10 -1.42 0.76 3,498 0.30 133.50 3,497.31 2.36 5.19 -2.36 0.28 4,193 0.40 244.00 4,192.30 1.83 4.93 -1.83 0.07 3,561 0.30 144.00 3,560.31 2.15 4.94 -2.15 0.09 4,256 0.40 287.60 4,255.30 2.24 4.90 -2.24 0.47 3,624 0.50 74.60 3,623.31 1.79 4.88 -1.79 0.77 4,319 0.50 12.80 4,318.30 2.39 5.23 -2.39 0.97 3,687 0.40 119.40 3,686.31 1.33 4.85 -1.33 0.56 4,382 0.20 207.40 4,381.30 2.38 5.40 -2.38 1.10 3,749 0.50 45.90 3,748.31 0.95 4.93 -0.95 0.88 4,446 0.50 312.50 4,445.30 2.64 5.49 -2.64 0.91 3,813 0.20 151.20 3,812.31 0.69 5.03 -0.69 0.91 4,509 0.60 8.60 4,508.30 2.79 6.00 -2.79 0.83 3,876 0.30 214.90 3,875.31 0.73 4.79 -0.73 0.44 4,572 0.50 356.30 4,571.29 2.76 6.60 -2.76 0.24 3,941 0.40 37.00 3,940.31 0.69 4.84 -0.69 1.08 4,635 0.10 188.90 4,634.29 2.78 6.82 -2.78 0.95 4,004 0.30 230.90 4,003.31 0.69 4.91 -0.69 1.10 4,698 0.50 354.50 4,697.29 2.82 7.04 -2.82 0.95 4,066 0.50 312.80 4,065.31 1.01 4.99 -1.01 0.88 COMPANY Marathon Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Baker Hughes Inteq 17 228.00 M-I Drilling Fluids SERVICE POB @ 06:00: NO. HOURS 2 48.00 1 24.00 Printed: 3/25/2002 9:39:29 AM ) ) .... .. .. . ... . . '" .. . ... ... o ,.. ... ... .... . . .. . .... . . '" .. ... o . . .. '" .... . . . .. . .. . . . . . .. .. . ..... ... . ... .... .. ....... . . .. .... . . . ... .. . . . ,. , . .., . .··MA~~[.fi (1~OIL9()M·ÞANY··· , >.p~lly¡'ºri IJirt5J. R~:~øl"t, ' I GL 124 HRS PROG I TMD 66.00 1,300.0 4,750 WELL NAME KENAI TYONEK UNIT 32-7H 1ST IKB OH 87.00 ITVD DFS 4,749 7 :PËRSONNELDAiÄ: NP.' .HC>U.~S , .. :. .,CC>fY1pÄf,iv 2 24.00 R&K Industrial '··ª~RVlëE · I REPT NO. I DATE 10 3/25/2002 POB @ 06:00: :·,·N9.' '·HÇlIJR§::· 2 24.00 MD (ft) 139 1,517 . ... ....... ......... .... " . CASING·SÜMMÂRY< ' LAST CASING TEST: 3/22/2002 TVD (ft) WT (lb/ft) 139 133 1,517 68 LAST BOP TEST: 3/22/2002 SIZE (in) ID (in) LOT (ppg) 20.000 18.730 13.375 12.415 12.73 NEXT BOP TEST: GRADE K-55 L-80 3/29/2002 BURST (psi) 3,060 5,380 Printed: 312512002 9:39:29 AM ) ) . . . .. .",.. ... . .. ... .... . . .. .. · . 0""· ... ... . . ... . . .. . ... ... . ,".. ... .. "' , , ... .. . . ..... . . ....... .. .... ..... .. ........... ,".... .. . ... . ... . ... ... ...",............. . ...... . . . """ ....... . . . . ..... .. . .. .... ..... .. ... .. . .... . .. . .. . . . . .............. .......... ..... . . ;<. M'ARATHOf\JQIL.:C0IV1p:ANY' WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Drilling @ 5630' 24 HR FORECAST Drill FI ELD NAME Kenai 1ST A TElPROV Alaska .. . .......... .... ....... ..... ..... ..... ..... .. . .... ......... .... ........ · . . . . . . . . . . . . . . . . .... . . .. .. .. .. . . ... . . . . ... . ...,. . . . . .... ... . . .. . . . .. .. ... .... ...... ....... . .... . . ............... .. ....... .. . '" . . .. . .. . ...... ......... ..... "' . ...", ......... ..... ........ .... ...... .... .... ....... ... . ..... ............. · .. ........... .. ..... .... ... ..... ... ......... .. .. . ",... . ....... ......... ............ ..... .... .. ... .. . ... . . . . .. . .. . .. . .. ...... . . .. . . . . , . . .. . .. . ... .... . .' . .. . . . . . . .. . .. . ... . .. . . .. , .... . .. ... . ... . ·.Dªily[)tiIHJ"Ïg ¡fi~p~t~f.>·' ST \KB IGL 124HRSPROG TMD TVD OH 87.00 66.00 880.0 5,630 5,629 8 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11 ,63ØD.01.G0338.CAP.~RL.3,284,OOO I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 51,519.00 515,807.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I NEXT CASING LEAKOFF PPG 1,517 (ft) 9.625 (in) @ 6,527 (ft) 12.73 I COUNTY/OTHER I LAST CASING Kenai Borough 13.375 (in) @ OP COMMENTS: Drilling @ 5630 ";, .. "" , " '" ., ····'..!q~~~J\"TI()NŠ¡$,J..MM,t\~V':¡¡··· ' PEPT¡:fTQ ,..··SU¡:j> )F>t:iAsE" · ".. "·'··.Tj$S~¡:¡I~TIÖN· 4,750 AF DRLlN1 Wash/Ream from 4587' to 4750' 5,630 AF DRLlN1 Drill Open Hole (Directional) from 4750' to 5630' (880') ·FROrvt· 06:00 07:30 . .. . . .. . ...... . ,. . .. . . .. . . . . ........ .... ........... . ............... . ... . ... . ,rÖ·'¡j-lRS¡· ¡b~ptH'FM 07:30 1.50 4,750 06:00 22.50 4,750 DENSITY(ppg) FV PVNP 45 10/22 9.15 I PP I GELS WLJHTHP 11/18 9.21 Fcrr.SOL 1.0/6.0 IECD ¡MUD DATAl DAILY COST I OIUWAT %SandlMBT Ph/pM 961 0.50/6.0 9.0010.1 10,104.00 Pf/Mf 0.1/2.1 I CUM COST I 57,800.00 CI Ca H2S LIME 18,500 80 ES BIT I RUN 2/1 BITS MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L..B-G-O-R Hughes MXC-1 6000038 15/18/18/18// 1,520.0 3/23/2002 0-0------ WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 15 I 25 70 I 75 510 1,850 260 20.50 880.0 42.93 51.50 4,110.0 79.81 BIT I RUN SIZE 2 11 12.250 BHA NO. I LENGTH 2 859.23 BHA DESCRIPTION BHA IEFF WT. I PICK UP SLACK OFFROT WT. I TORQUE (m.:I.xImin) BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS o 118 113 115 3,000/8,000 58 58 1 Tri-Cone Bit, Bent Sub Motor, Intergral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over PUMP I HYDRAULIC DATA NO. MAKE OF PUMP STROKE (In) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILLSPM I PRESSURE 1 OILWELL 8.000 5.500 110 255.23 1,850 510.46 60 350 2 OILWELL 8.000 5.500 110 255.23 1,850 510.46 60 360 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 4,762 0.50 359.20 4,761.29 2.85 7.60 -2.85 0.06 5,201 0.00 270.00 5,200.28 2.82 10.10 -2.82 0.95 4,828 0.20 56.80 4,827.29 2.76 7.95 -2.76 0.65 5,263 0.40 278.30 5,262.28 3.03 10.14 -3.03 0.65 4,888 0.60 323.20 4,887.29 2.86 8.26 -2.86 1.07 5,327 0.20 253.20 5,326.28 3.36 10.14 -3.36 0.37 4,950 0.50 15.20 4,949.28 2.98 8.78 -2.98 0.79 5,390 0.60 316.10 5,389.28 3.69 10.34 -3.69 0.86 5,012 0.50 18.70 5,011.28 2.82 9.30 -2.82 0.05 5,452 0.40 350.10 5,451.27 3.95 10.79 -3.95 0.56 5,075 0.10 179.20 5,074.28 2.73 9.50 -2.73 0.94 5,515 0.30 211.40 5,514.27 4.08 10.86 -4.08 1.04 5,138 0.60 352.90 5,137.28 2.77 9.78 -2.77 1.11 SERVICE PERSONNELDATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 17 228.00 Epoch Well Services 2 48.00 R&K Industrial POB @06:00: NO. HOURS 3 48.00 2 24.00 2 24.00 Printed: 3/26/2002 1 :29:38 PM ) ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Sliding 1 building angle 24 HR FORECAST Drill 1 build angle FIELD NAME Kenai "MARA T.HON~OIL 'COrylP,ANY . .... . , ' , " ' , ,',Daily :Drilling Report: , ST I KB I GL 124 HRS PROG TMD TVD I DFS REPT NO. I DATE OH 87.00 66.00 295.0 5,925 5,923 9 12 3/27/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 11,637 DD.01.G0338.CAP.DR _ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 173,312.00 689,119.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 · P(lge,,1-'of, 1', " ' , " ',:OPERATIQNS, SOMMAR'Y:;' , .. , , .: ,"r .. I',: '::F~QN.t :'TO',,'. ,::,HR$,:', D~PTH FM ,DEPTH TO ':, SU\3 ' ,'~HAS~', .. '. ' J:;' :': PJ;SQRIPTION:,:, 06:00 10:30 4.50 5,630 5,820 CSGIN1 Drill Open Hole (Directional) from 5630' to 5820' 10:30 12:00 1.50 5,820 5,820 CSGIN1 Circulate and Condition Hole 12:00 19:00 7.00 5,820 5,820 CSGIN1 P.O.H.I Backream from 5820' to 4200' I Pull to 3960' wlo pump or rotary 19:00 20:30 1.50 5,820 5,820 CSGIN1 Circulate and Condition Hole 1 Sevice rig 20:30 22:30 2.00 5,820 5,820 CSGIN1 R.I.H. to 5740' 1 Wash to btm. @ 5820' 22:30 06:00 7.50 5,820 5,925 CSGIN1 Sliding / Building angle ART = 4 hrs. / AST = 6 hrs. DENSITY(ppg) . 915 I PP I I.E.C...DI.,. "I.M. 'UD, .:,.D.'.A.',T.'.',\A.:,,'.'I·:'DÁ,iL,:v:.c.,O.,.S.·,T..:,'; :,·.·.:,·,:',·.'",·,',',·:F','v" :..,,:,;.., ',,:,',',,:p..,,·:v:,'IY',;~ .p.,',,:' ,: ,G' .. EL',: S·: , "'. ,·w· U.. 'H::-T:',H":P:,. .,' " ,,;,þCJt~S.ÖL ,',' OIUW~T~:" ":/'D/~~~rid/rillêl'::: '::~':! ~~/prlil, . ", 52 10/31 13/18 9.2/ 1.0/6.0 961 0.15/5.0 8.50/0.1 9,846.00 , p.f~M(:.' 0.1/2.3 1,'C,4M',CÞS,T ,I 67,646.00 CI ".',,,,.::·,':è~>:·" ,H2S, 'LIME, ':. ES,::" 19,000 160 ,.,' ',·,'BI1S, ,:..:'::,',;',' 1 ,.'::,:;'" ,,' '.. ,.' " I sEaiÅi..~ê>':::::':':: ":~,Êtá'cjij'tFA,( :",:':D~l?tH:i~ DATe:IN " 1:,,1, 6000038 15/18/18/1811 1,520.0 3/23/2002 ·'1,:,1.' ';BITf~ÜN:" '::~iZE:: 2 /1 12.250 :i:.b~D~L~ß;;èiTQ~~:'::' ,'.' 0-0------ BIT I RUN 2 11 WOB 20 I 35 RPM 70 I 75 GPM 510 PRESS 1,750 PBIT 260 HRS 10.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 295.0 29.50 61.50 4,405.0 71.63 ":"':' " "::\,·,!""'BHÀ::::':", '.' , I ~f",t ...·PIC{2'i· ·····1 $~i~ OF1~qi rJ"I\O~~~o~~&66 ".> I BHA ~RB "I~I\ÂHR$ ··MWDIiRS. ~R~~$IB.$;lif~·· '. Tri-Cone Bit, Bent Sub Motor, Intergral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over "1"':',' ;.:, ,', ~' '.1 .., .; 'I!' . ,B.8~~O.,,:! L~~~~;, BHA DESCRIPTION ...',·:c '.' \" . , :::':: .': "": ,'PUMP:l, HYDRAÚLIC ,DATA ",:SjROK:E,:(lri) ::: H~é~:'(~~F/: s~rJI'.:, :;d:('gpm):,: 8.000 5.500 110 255.23 8.000 5.500 110 255.23 :-'. ;. '. ~; . ;" ,": i: ' ! .... ~ ':.': 'I; :' ,;, :: ~ . : ¡"" ¡ ... .. '. ~ :; '. I ¡"' +: .' ¡ I ¡ " ': I . ' '., ~RESS~:.(~$I) "T.OT~L~ ,: '::':(ILLSP~(I::'p'R,ESSU~E,:) 1,750 510.46 60 350 1,750 510.46 60 360 ::::.)~p:: 1 2 . : ,>,.;. " ;,: ,;::,.'..' : 1\ I, " )'; . ;,:, :;,:..: ,~4.IÇE;PF=',:I:'UMP:: ,,:'.' ': OILWELL OILWELL , , , " , ': ,SURVEY: DATA ,:' 'T,V,D.:' ,:WS CUM ~ CUM 'sEctioN: :,',":I\'i:D~" 5,577.27 10.62 -4.19 4.19 5,767 5,640.27 10.41 -4.41 4.41 5,831 5,703.27 10.39 -4.87 4.87 :~NCi...:' '~I ':" 0.20 78.70 0.80 145.90 'T~V..D'. :: ,N1s C~~ ~'CtjM' $E'Crlb~ ' 5,766.27 10.50 -5.02 5.02 5,830.27 10.15 -4.66 4.66 :-'M.P.,,"'" 5,578 5,641 5,704 iNCL., ' 0.20 0.40 0.50 "" All,:, 194.70 241.60 289.00 CQri/lPANY , Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE , ' PE~SONNEL;DATA NO. 'HOURS' , -COMPANY 1 18.00 M-I Drilling Fluids 17 228.00 Epoch Well Services 2 48.00 R&K Industrial SERVICE' NO. HOURS, 3 48.00 3 36.00 2 24.00 Printed: 3/27/2002 6:45:25 AM ) . . ......... ...... ...... ..... . '" ... .... . . ... .. . .. .. .... . .. . . . .. . . . , .. . .. . . .. . .. .. .... . . . . .."... . ... . . . . . . ... .. ... .", . .... "'""0· .. ,MARATHON¡ OIL ··COI\,1PANY ) .. ' ... . ... ....... .. ........ ",........".", .. ." .................. . . .... . .... . '" .. .. . ... ...... ...... . '" .... '" . ... .," ... .. ... .. ... .. . ... 'Qilil,y :[)rllli~9::R~.:Hºr1; ,. ¡', ., ST I KB I GL 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE OH 87.00 66.00 105.0 6,030 5,956 10 13 3/28/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907 -283-1312 11 ,63VD ,01.G0338.CAP.~RL3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%' 61,761.00 750,880.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I NEXT CASING LEAKOFF PPG 1,517 (ft) 9.625 (in) Cã2 6,527 (ft) 12.73 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS DrillinQ Cã2 6030 24 HR FORECAST Drill 1 build anQle FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai BorouQh 13.375 (in) @ OP COMMENTS: Drill to 6017' 1 Trip for bit and motor IDrilling @ 6030' FROM 06:00 10:30 12:00 19:00 20:00 21:00 22:00 00:00 00:30 03:30 05:30 DENSITY(ppg) FV PV/YP 53 12/31 BIT / RUN 211 3/RR BIT / RUN 2/1 3/RR . .. .... .". . .~.... .". . ......... ......... ..., '" .".. .... ..... ...... ..... . .", '" .. .. .. B8f.~Ö·ILE8¿~:~ BHA DESCRIPTION TO 10:30 12:00 19:00 20:00 21:00 22:00 00:00 00:30 03:30 05:30 06:00 SIZE 12.250 12.250 HRS 4.50 1.50 7.00 1.00 1.00 1.00 2.00 0.50 3.00 2.00 0.50 DEPTH FM DePTH TO SUB 5,925 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,017 AF 6,017 6,030 AF OPERATIONS SUMMARY PHASE DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DRLlN1 DESCRIPTION Drill Open Hole (Directional) to 6017' (Stalling out wI 100 psi differential) Circulate and Condition Hole P.O.H. Lay down motor and bit and top stabilizer Pick up new mud motor; bit #3 and orient tool R.I.H. with HWDP I Test MWD Slip and cut drilling line Service Rig R.I.H.I (tight @ 5904') 1 Ream 5900' to 6017' Trouble shoot; repair pump #2 rod wash electric motor Drill Open Hole (Directional) to 6030' 9.00 GELS 13/21 I PP I WUHTHP 8.11 IECD IMUD DATAl DAILY COST I FC/T.SOL OIL/WAT %Sand/MBT Ph/pM 1.0/5.0 961 0.20/4.3 9/0.1 20,200.00 Pf/Mf 0.1/2.3 I CUM COST·' CI Ca 20,000 80 87,846.00 H2S LIME ES MANUF. TYPE Hughes MXC-1 Hughes MXC1 WOB RPM GPM 20 I 30 70 I 75 510 1 0 I 20 70 I 75 510 BITS SERIAL NO. JETS OR TFA 6000038 15/18/18/1811 G19JP 15/18/18/1811 PRESS 1,900 1,900 PBIT 256 256 HRS 3.50 0.50 24Hr DIST 92.0 13.0 DEPTH IN DATE IN 1,520.0 3/23/2002 6,017.0 3/27/2002 , -O-D-L-B-G-O-R 3-3-CT-H-E- 2-EC-PR 0-0------ 24Hr ROP 26.29 26.00 CUM HRS CUM DEPTH CUM ROP 65.00 4,497.0 69.18 0.50 13.0 26.00 .'" ,,,.. ". '" . . " .. " :;, ' .. ..,.... ." ....,' .., ' ,. F> ..:: ..,.> ; ··,éHA>···' IEFF~T.Y~iC~~; ISLÅ1~~ÖF1Rb~~T.1 TOR~~66(j~~6t6 57.50 1 Tri-Cone Bit, MWD Tool, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar , Heav~ Weight Drill Pipe (21), Cross Over PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.500 110 255.23 1,900 510.46 8.000 5.500 110 255.23 1,900 510.46 KILL SPM / PRESSURE 60 440 60 440 SURVEY DATA vs N/SCUM EtW CUM DOGLEG MD 3.54 8.39 -3.54 3.49 5,957 SERVICE PERSONNELDAT A NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 17 228.00 Epoch Well Services 2 48.00 R&K Industrial SERVICE POB @06:00: NO. HOURS 3 48.00 3 36.00 2 24.00 NO. MAKE OF PUMP 1 OILWELL 2 OIL WELL MD ,NCL AZIMUTH TVD 5,894 3.00 148.20 5,893.23 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq Printed: 3/28/2002 10:09:26 AM ') I) ···MD:(ft) 139 1,517 .. .. .. . . ... . .. ... .. . CASINGSUIVIMÄRY · LAST CASING TEST: 3/22/2002 TVD (fir: .. :wr(II:>)ft) . :. 139 133 1,517 68 .. .. . ......... . ..... .. "."",. ...... . .... ....... ..". . .... . ........... . ........... . ... .".. .. . .. ....... .. . ""' 0.....·· .. .. .. .. "' '" . . . .. .... ...... ..... .. .. . ........ .. ..... ...... . . .. . .. . . . ... . ,. . . . . . . . . .. .. . '" ..... . .. . . . . ..... . . ":" . ..... . . '. . .... .... ..", ...... .... .... .. ... .... ·MARAtHdt~føll. COMPANY WELL NAME KENAI TYONEK UNIT 32-7H ,". ",. ....... .. . .... . .....", . ....... ..... ..... "' · .... . . . . '" . . . · . .",. .. · . .. .. . ... .. ...... ... . ... . . .. .. .. ............. ... .... .. .·.þªily: pl":in¡ ~gR~p()tt ::::. . 1ST I KB IGL \24 HRS PROG ITMD OH 87.00 66.00 105.0 6,030 LAST BOP TEST: 3/22/2002 . , , ' , . . . .. .. SIZE (in) . ID(iIi) ··LOT(ppg) 20.000 18.730 13.375 12.415 12.73 NEXT BOP TEST: <:GRÀbË . K-55 L-80 3/29/2002 BURs·r(þ~i} ....... 3,060 5,380 Printed: 3/28/2002 10:09:26 AM ) ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Short trip to shoe 24 HR FORECAST Clean hole / Run and cement casing FIELD NAME I STATE/PROV Kenai Alaska MARATHON OIL COMPANY . C·aily DriHing Report GL 66.00 Page 1 of 1 ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD IDFS REPT NO. ¡DATE 500.0 6,530 6,507 11 14 3/29/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 43,608.00 794,488.50 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 OP COMMENTS: Drill to casing point @ 6530' / Circulate to short trip 1':.'"'''0''' ... ,.. DEPIH'Tq FROM: ·Tp· .. IiRS. DEpTH·FM . .sµa. 06:00 04:00 22.00 6,030 6,530 04:00 06:00 2.00 6,530 6,530 q,f'E.~ATiºN$;SlJMMAFtx· . . ·PHASE ' DRLlN1 'I 1"1' I DESCRIPTlqN· Drill Open Hole (Directional) from 6030' to 6530' (500') AST= 12.5 hrs.) Circulate and Condition Hole ( ART = 5.5hrs. / DRLlN1 .;DÊN~rö'(p·pg)/1 9.15. I. pP:I. .. .I~çbl IMUD·bATAI·:DAILV:CO$T. ·'.:FV .. PV~P: . G.!:LS··: WU~THP::· ;iFCrr.SOL OIUWAT,'· ,,!oSand/~B~··', :·p:I:I!pM' 48 12/25 10/18 7.8/ 1.0/6.0 96/ 0.15/4.5 9.50/0.2 4,649.00 ·..cUNrCqST" 92,495.00 , . P:f/Mf:·· .,: :,:.CI . :>::9a;: ,;·H~$ .1':IME ::··E,S:,. 0.2/2.4 19,000 80 :BIT1·RUN· :'size· 3/RR 12.250 MANIJ F. . Hughes :, ' ··.T·YPS·. MXC1 :' . ;",BITS ....... ·SE.RIALN(j;':', . :J~iSQR "(¡;:A. G19JP 15/18/18/18// .', ". . ".." .1,~O~D~L~E3~G·~Ö~R , 2-2-NO-A-E- 2-NO-TD OEp,THJI',I:;Q~TE I~ 6,017.0 3/27/2002 BIT I RUN 3/RR WOB 20 / 30 RPM 70 / 70 GPM 464 PRESS 1,500 PBIT 215 HRS 18.00 24Hr DIST 500.0 24Hr ROP 27.78 CUM HRS CUM DEPTH CUM ROP 18.50 513.0 27.73 ,~HA~~O. .. L~NqTH 3 853.93 BHA DESCRIPTION ':.;, ,. .. ,. 'BHÄ:'.... ." . ",.' .. '" I ' .:'EFF:r· ~;I PIC~~:::' I,$~~ C>F·fR.9~,~. ....: Tçj~~66rii~~~~)'·· ,ßHA HR'~··;;:IJþ"~::~ '. :',M'ND HR$:l ~TR~R~: ¡·sp· rI~,~ . ' Tri-Cone Bit MWD Tool, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over ·:,'NO:·'·· 1 2 ',',!. ,::. ", , ').:'PUMPJ'HYDRAULlC'DATA· , . I.'':" . . OILWELL OIL WELL .:: STRoj(e:(lt'Ú:· ~IN'¡;;R(iiïL(,SPM, :::Q(gpm»). PflESS;,(p~l) ·iqTAL:Q. . :KI~L.:$PM,I. P.R·ES$URI;;.::, 8.000 5.500 100 232.03 1,500 464.06 60 380 8.000 5.500 100 232.03 1,500 464.06 60 380 :.M:D. 6,022 6,080 6,143 6,206 6,269 :·INCL;. 7.20 9.40 11.10 13.00 14.70 ·..·AZI 146.00 143.80 144.70 144.00 145.40 ·SORVEY DATA T.V.D. NlS CU.M EIW CUM SECTION : . <M.D. 6,020.67 -1.12 3.15 -3.15 6,332 6,078.06 -7.96 7.98 -7.98 6,395 6,140.05 -17.06 14.52 -14.52 6,459 6,201.66 -27.75 22.19 -22.19 6,480 6,262.83 -40.06 30.89 -30.89 6,530 :: T It'JCL. 16.80 19.60 23.10 24.40 27.00 ·,AZI 146.80 147.30 146.20 146.00 146.00 ·T.V.D; NlS,CUM: ElW CUM SECTION. 6,323.46 -54.26 40.42 -40.42 6,383.30 -70.77 51.12 -51.12 6,442.90 -90.24 63.90 -63.90 6,462.12 -97.26 68.62 -68.62 6,507.17 -115.24 80.74 -80.74 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq . SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00. M- Drilling Fluids 17 228.00 Epoch Well Services 2 48.00 R&K Industrial SERVICE NO.· 3 3 2 HOURS 48.00 36.00 24.00 Printed: 3/30/2002 11: 11 :44 AM ) ) : MARATHON. OIL COMPANY ·Pa.ge 1·0(t·. ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily·Drilling Report IGL 66.00 124 HRS PROG WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Changing rams 24 HR FORECAST Run and cement casing / nipple up BOP S FIELD NAME I STATElPROV Kenai Alaska TMD TVD I DFS REPT NO. IDA. TE 6,530 6,507 12 15 3/30/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 45,233.00 839,721.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST One 3/18/2002 3/22/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 13.375 (in) @ 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 OP COMMENTS: Short trip 1 Backreaming ; cleaning hole to run casing :' . OPERATIONS ·SÚMMARY·:· 'FROM.: ... '. . .'... o , .";':1'" "":""".. ··"ÒES:CRIPTION: u TO.· HRS·:. DEPTH ¡::JI/\ DEPTI-:HQ .. .S!.)B . PtiASE : : , . 06:00 12:30 6.50 6,530 6,530 DRLlN 1 P.O.H.I Back -ream to 5970' / P.O.H. -SLM 12:30 13:30 1.00 6,530 6,530 DRLlN1 Service Rig 13:30 16:00 2.50 6,530 6,530 DRLlN1 R.I.H. to 6394' / Drilling bridge 6394' to 6400' 16:00 16:30 0.50 6,530 6,530 DRLlN1 Wash/Ream to 6530' (15' of fill on bottom) 16:30 20:00 3.50 6,530 6,530 DRLlN1 Circulate and Condition Hole 20:00 21:30 1.50 6,530 6,530 DRLlN1 Attempt to P.O.H. / Backream to 5598' 21:30 22:00 0.50 6,530 6,530 DRLlN1 Run back to bottom @ 6530' 22:00 00:00 2.00 6,530 6,530 DRLlN1 Circulate and Cqndition Hole 00:00 05:00 5.00 6,530 6,530 DRLlN1 P.O.H. Lay down BHA 05:00 05:30 0.50 6,530 6,530 DRLlN1 Clear floor 05:30 06:00 0.50 6,530 6,530 DRLlN1 Change rams to 9 5/8" :".DE;~$rtv(pp~rl. .9..35 ,:pp'l eçDI IMÚb:DATAII[)~IL.y;ços:r·1 5,388.00 I:C~'I/U~bST·1 97,883.00 ·.·FV··::· ·ÞVlYp· '·GEI.S. .';, WLMit·!p: ·FÓrr~sOL ::'::'p'LJwAf.:' .>:%SânWM'~r:·' ·'Pti/pll/l'·.'· ':PI/MI'·· ':'~"bL:" ,. Ca '.;:, ·H2S· LiME :::,·ES: 54 13/28 11/20 7.4/ 1.0/8.0 96/ 0.10/5.0 8.50/0.1 0.1/2.3 18,500 60 BIT / RUN .: ;.," . . ,'.'.;. ;:::',!.MANÙ~;¡·!,:. '.' '.; :,. Hughes WOB RPM : " .. ,·1· .. .. ''.', .,'.'BITS:·:! ":11,,".. ., 1m, ::,TvPE:. Se.RIALNO,,:;,:~i!TS'OR:T~~ :. Di:~t{IN':[)ATe'·IN"I:, '.: ';I~O~j,;,l~B~~;Þ~R .. MXC1 G19JP 15/18/18/18/1 6,017.0 3/27/2002 2-2-NO-A-E- 2-NO-TD GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP :srt t~UN. 3/RR BHÀ~Ô' 'ILt:~"I~FF WTi 1 PICK 8P, ',' ili~bk6~1RO~~';I~O~~~(~rtiirij "'I BHA HR~ pARHRS ·.I~WD'~~SI~R H~'ISSH{S ,', BHA DESCRIPTION Tri-Cone Bit, MWD Tool, Non-Mag Drill Collar, Hang-Off Sub, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE. . PERSONNEL DATA .NO; HOURS . COMPANY 1 18.00 M-I Drilling Fluids 16 214.00 Epoch Well Services 2 48.00 Weatherford Completion SERVICE:' . NO. .. HOURS 3 48.00 3 36.00 2 6.00 Printed: 3/30/2002 11 :26:24 AM ) ) MARATHON· O.ILCOMPANY Page '1.: at 1· WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Circulating 24 HR FORECAST Cement casing / Change out spool/nipple U:J and test BOP s FIELD NAME I STATElPROV COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 13.375 (in) @ ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 D~ily Drilling Report GL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 6,530 6,507 13 16 3/31/2002 ¡RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR _ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 45,349.00 885,070.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/18/2002 3/22/2002 I NEXT CASING LEAKOFF PPG 1,517.0 (ft) 9.625 (in) @ 6,527.0 (ft) 12.73 OP COMMENTS: Ran 158 jts. 9 5/8 -40# -L80 buttress / Shoe @ 6526' / F-C @ 6440' . . .. . ~ OPE:RATIÓN·S SUMMARY. ":":'::":1':'1'. .... t.>:: . ;"". " "I I'" ...". '. ",' .' '''''''' "'" . . ,,,. 'I' '" "". DE.S'CRI·PTION . ."'''' FROM· ·TO. :HRS: DEPTH f=M DEPTH·TO . SUB .,: . .·PHA.8E 06:00 06:30 0.50 6,530 6,530 CSGIN1 Install 9 5/8" pipe ràms 06:30 07:30 1.00 6,530 6,530 CSGIN1 Pull wear ring / Test door seals to 250 - 1500 psi 07:30 10:00 2.50 6,530 6,530 CSGIN1 Change to long bales / Rig up to run casing 10:00 14:30 4.50 6,530 6,530 CSGIN1 Run 9 5/8" 40# - L80 butress casing to shoe @ 1517 / CBU 14:30 21:30 7.00 6,530 6,530 CSGIN1 Run casing 21:30 22:30 1.00 6,530 6,530 CSGIN1 Make up mandrel hanger and landing jt. / Work thru ram cavities and land casing 22:30 02:00 3.50 6,530 6,530 CSGIN1 Circulate and condition hole / Discuss method of installing tubing spool wI 1500' of open annulus with drilling engr. 02:00 04:00 2.00 6,530 6,530 CSGIN1 Pump (1 ) gallon red dye around system to determine actual T.O.C. in 95/8" X 12 1/4" annulus (no visible returns) 04:00 06:00 2.00 6,530 6,530 CSGIN1 Pump (1 ) gallon methanol thru mud to determine excess hole volume and T.O.C. (no visible returns) . .DE;~SITV(ppg) :1 9.35 l~p,1 I'~CD I I MUDPATAI~::DA.,LY:'C()STI 4,991.00 1·':cuft!1ëÒ~n:,1 102,874.00 ..>.=v, ,.!þvi'i~ \.'~ELS,.. :"WµfiTH,P.; '!FcttSOL: ··';·:.OIl.JWÄT,I,'..'%.SalÎd/MBr" :,'P,h!pM,I. '·~:,":~/Mf:' ·':::·"'!CI,:· :<·~'C~¡:'·:· .: .:!-I~$; ·'ÜMËf .ES:' 57 12/28 11/18 7.5/ 1.0/8.0 96/ 0.10/5.0 8.50/0.1 0.1/2.3 18,000 60 . .', '.P·ERSONNEL .[)ÄTJ.\. N, o. '·HduRg:: '>.:·CbiV!PANy:: . . . , .. I " \ ,I, 1 18.00 Epoch Well Services 17 226.00 Weatherford Completion 2 48.00 BJ Services 3 48.00 ¡ ., ' . 'I"·" "". ", . <... > CQM.~ANY,:: . Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids . . . SER\ilèE. . ::: I1PURS· '.. 36.00 36.00 40.00 Printed: 4/1/2002 6:38:40 AM ) ) MARATHON OIL COMPANY Page 1 of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Nipple up BOP S and mix mud 24 HR FORECAST Test BOP S / Pick up BHA / Drill out FIELD NAME I STATElPROV Kenai Alaska ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 ··1?aUy DrUllng Report IGL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 6,530 6,507 14 17 4/1/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 161,555.00 1,046,625.50 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/24/2002 3/22/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 12.73 I COUNTY/OTHER I LAST CASING Kenai Borough 9.625 (in) @ OP COMMENTS: Cement 9 5/8" casing / WOC / Change out tbg. spool and nipple up BOP s O·PERATION5.SUMMARY·· I "'''''I'' "'"'''' ,."". , " "",,,,,. DESCRIPTION:.·. . . FRO 1\1I ,TO HRS· .. . DEPTH. F~ DEPTH.TO SUB : PHASg 06:00 08:00 2.00 6,530 6,530 CSGIN1 Circulate Carbide (returns @ 14500 strokes-15660 calculated) 08:00 11:00 3.00 6,530 6,530 CSGIN1 PJSM / Pump (2) bbls. water and test to 3000 psi / Pump (30) bbls. MCS4D sweep @(10) ppg.; followed by 474 sks. Class "G" @ 12 ppg w/ 18% LW6; .4% CD32; .1% ASA301 ; 20% M P A-1 ; .1% static free ; 5# per sk. Kol Seal; 1/4Ib./sk. Cello=Flake; .2% R3; 19hsFP _6L then followed by151 sks. Class "G" tail cement @ 12.76 ppg. w/.9%BA-10A; .2% R3; .6% CD32 ; .15%A-2; 22%LW-6; 5% MPA-1 ; .1% static-free; 2% KCL(bwow) ; and 1 ghs FP-6L / Pump out plug w/5 bbls. water and displace with 483 bbls.mud· with rig pumps; bumped plug @ calculated displacement @ 1500psi / Floats held C.I.P. @ 1045 11:00 21:30 10.50 6,530 6,530 CSGIN1 WO Cement / Clean pits and refill w/ water / Start mixing mud for 81/2" hole 21:30 22:00 0.50 6,530 6,530 CSGIN1 Test 9 5/8" casing to 1500 psi / 30 minutes /OK 22:00 23:00 1.00 6,530 6,530 DRLlN2 Rig down test lines / Back out and lay down landing joint 23:00 23:30 0.50 6,530 6,530 DRLlN2 Monitor annulus w/ bubble bucket 23:30 01:30 2.00 6,530 6,530 DRLlN2 Nipple down BOP s 01:30 04:00 2.50 6,530 6,530 DRLlN2 Change out tubing spool 04:00 06:00 2.00 6,530 6,530 DRLlN2 Set and test 9 5/8" packott to 3000psi /10 minutes / OK / Nipple up SOP s COMÞÁNY:, 'Marathon Inlet Drilling Alaska Baker Hughes Inteq ·:D~~~,TY(iiPg)::·1 9.35 I' ~pl I Ecp.1 II\fIUO'DATAI;;:DAI~Y'C(;)~T.1 . :'j:y :.:.. ,jJV'r,(P, ':Gl~LS'· : vvLm~Hp,. . FCft;$O(" OIUWA T : '. ~oSånc:l!MBr', .::.::' ::Ph/pM.' .~ . 57 12/28 11/18 7.5/ 1.0/8.0 96/ 0.10/5.0 8.50/0.1 IpERSONNE,L;DATA·:,.' '··:NO. HÒURS ' ': ·COMPANY 1 18.00 M-I Drilling Fluids 17 226.00 Epoch Well Services 2 48.00 ABS Vetco Gray 3,276.00 I: :Ç~M;.¢Q~T: I 106,150.00 'F'f!M( ,;., . ·.:.Cr··"!' ':.,(:a ,,:: :, H2S" .. L!ME' l~S, 0.1/2.3 18,000 60 .' , on I 'SERVICE· SERVICE ., . . NO.. 1 2 1 , H:OURS 24.00 24.00 12.00 Printed: 4/1/2002 6:55:18 AM ') WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Jerry Lorenzen CURRENT STATUS Drilling float collar 24 HR FORECAST Drill out of shoe; perform UO test; drill FIELD NAME I STATE/PROV Kenai Alaska MARATHON· OIL COMPANY . Daily DrUling ·Report IGL 66.00 Page j of :1 I COUNTY/OTHER I LAST CASING Kenai Borough 9.625 (in) @ 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 6,530 6,507 15 18 4/2/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00(%} 92.20(%} 55,791.00 1,102,416.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/1/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 12.73 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: Nipple up stack / Test BOP S /Pick up BHA and drill float collar .opr;rt~rIÔNS:·~UrJIMARY·· . .,. . , . .. . ",. , ... 'F'ROM: ':'TÖ: HRS . DE'PTH: ·FI\f DEPTH· TO; :.. :éue :.::,: PHA$.f% . DESCRIPTION: . . 'T'· I 06:00 09:00 3.00 6,530 6,530 DRLlN2 Nipple up BOP S 09:00 12:00 3.00 6,530 6,530 DRLlN2 Test BOP S / Unable to test bottom pipe rams with test plug-test joint configuration 12:00 14:30 2.50 6,530 6,530 DRLlN2 Nipple down BOP S 14:30 17:00 2.50 6,530 6,530 DRLlN2 Nipple up with 24" spool under stack 17:00 19:30 2.50 6,530 6,530 DRLlN2 Install test plug / Finish BOP test 19:30 21:00 1.50 6,530 6,530 DRLlN2 Make up bit #4 / Change motor setting, orientate; and load MWD 21:00 22:30 1.50 6,530 6,530 DRLlN2 R.I.H. to drillpipe 22:30 23:00 0.50 6,530 6,530 DRLlN2 Test MWD (tool failed) 23:00 00:30 1.50 6,530 6,530 DRLlN2 P,O.H. to check MWD 00:30 01:30 1.00 6,530 6,530 DRLlN2 Change out MWD and test 01:30 04:30 3.00 6,530 6,530 DRLlN2 R.I.H. / Tag float collar @ 6440' 04:30 05:30 1.00 6,530 6,530 DRLlN2 Test casing to 2500psi / 30 minutes OK 05:30 06:00 0.50 6,530 6,530 DRLlN2 Drilling on float collar and cement ··.qENSITY(ppg) I 8.75 1F.'p··1 , . ¡EeD I MUD·:'CÃïAI 'cAlLY COST 1 . -:':Al: :pvIŸP: ·.GELS· 'W'LIHTtiP FplTJSOL', OIL/WAT: ,. O(~andlMEI'r:Þ",/p.ivI 45 5/20 10/12 / /4.0 96/ 8.80/ 18,915.00 Pf/Mf / rCIJM,ëQ~"",1 125,065.00 ,.CI. " ,,' ,Ca·: . U H:2S" '.Üivlë::; jis'::> 37,000 60 , , .,; I· BITS'",...::., '''... . '" , I .' :' ''''. : I SgRIALNO:.;: . ·JETS;OR'TFA: MXRS18DD V49DF 18/18/18/// !'.o. I '"'r ·',;1<:1· ". DEPTH ,IN. ' DATE IN 1 ;, 6,530.0 4/1/2002 ";1": . ... :~rr/RÜN . :.812E 4 /1 8.500 .". .,. . : . ,:I·I.O~[)o.L-B;';G~o;.R: 0-0------ BIT I RUN 4/1 WOB / RPM / GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 'B.MA NO., I LENGTH· 4 884.78 BHA DESCRIPTION IEFF :. PICKUPSLACK OFtAi:U WI. T~~~ (';"'xlmin) I BHAHAS I JAA H~S MWD HAS MTA HASISS HAS Tri-Cone Bit, Bent Sub Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Drill Collar Hang-Off Sub, Drill Pipe, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over COMPANY 'Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HPURS COMPANY 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 SERVICE ·NO. 1 2 HOURS 24.00 24.00 Printed: 4/2/2002 6:47:12 AM ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Drilling ahead @6825'. 24 HR FORECAST Drill ahead. FI ELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) @ . .. ... ...... ",. ........ ... "'" .. .. . .... .. . .. ....... ... ... .. .. . . .. .. '" . . . . ... . . .. ... .. ... .. . pªiIY· ..p"illi'~g·.lJêport ST IKB IGL 24HRSPROG ITMD TVD DFS OH 87.00 66.00 295.0 6,825 6,747 16 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11 ,631iJD 01.G0338.CAP.~RL3,284,OOO I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 46,654.00 1,347,942.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/1/2002 I NEXT CASING LEAKOFF PPG 6,526 (ft) 7.000 (in) @ 9,428 (ft) 13.66 OP COMMENTS: Drill float equipment and shoe. Clean old hole to 6530'. Drill F/6530' to 6550'. CBU. Perform LOT. Displace well to 9.0ppg mud. Clean rig while repair generator#1 engine. Drill f/6550' to 6825' OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 07:00 1.00 AF DRLlN2 Cont. drill float collar and shoe tract to 6526'. Clean old hole to 6530'. 07:00 08:00 1.00 AF DRLlN2 Drill new hole F/6530' to 6550'(ART=Ohrs, AST=.75hrs). 08:00 09:30 1.50 AF DRLlN2 CBU. 09:30 10:30 1.00 AF DRLlN2 Perform LOT(13.7 EMW). 10:30 13:00 2.50 AF DRLlN2 Displace well to 9.0ppg flopro mud. 13:00 18:00 5.00 AF DRLlN2 While PIU and rack back 94 joints of 4.0" HT-38 DP mix mud. 18:00 22:00 4.00 TA DRLlN2 While repair engine #1 generator clean rig. 22:00 02:00 4.00 6,550 6,690 AF DRLlN2 Dir drill and survey F/6550 to 6690'(ART =1.00hrs AST =2.5hrs) (max gas 1307 units @ 6663'). 02:00 03:00 1.00 AF DRLlN2 Circ. out gas and begin to increase MW to 9.3ppg. 03:00 06:00 3.00 6,690 6,825 AF DRLlN2 Dir drill and survey F/6690' to 6825'(ART =1.25hrs AST =1.5hrs) increase MW to 9.3ppg. DENSITY(ppg) 8.95 .I¡ppl. . l~q[)1 .... r MUb.¡ØA"AI:p~I~YÇqSTI :FV ... pVNi=' .. .·GI;~$··· · WLIH"rHP .. ·FCrt~SÞL. ::·.OÎIJWÂT ··:%S~rlë:ljl\lléT' .. :Pij!þrv,· 40 7/21 11/13 8.01 1.0/3.0 197 1.0010.8 11,919.00.......... ...!cuM:cÓštl 136,984.00 &t/l\ll{ ·"0.1 .'.·.C.i1 .. ..·H2S. ·~ïM.Ê..·· é:S':¡ 0.4/1.3 25,000 20 4/1 8.500 Baker Hughes MXRS18DD V49DF 18/18/18111 6,530.0 4/1/2002 BIT I RUN 4/1 WOB 30 I 35 RPM 80180 GPM 400 PRESS 1,500 PBIT 247 HRS 6.15 24Hr DIST 295.0 24Hr ROP CUM HRS CUM DEPTH CUM ROP 47.97 6.15 295.0 47.97 . .BHA . I EFF WT. I SL.AGK OF~ROt WT. ··jtöRÔUE(ma.xïrri¡r1) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SSHRS 39 130 120 I 125 10 I 4 Tri-Cone Bit, Mach1X 11.4AKO 18 3/8UBHS , Non-Mag Integral Blade Stabilizer, Non-Mag Drill Collar, Hang-Off Sub, Drill Pipe, Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over, 4" 14PPF S-35 HT-38DP BHA NO. I LENGTH 4 884.78 BHA DESCRIPTION OILWELL OILWELL PUMPIHYDRAULlCDATA STROKE (in) LlNER(iri) SPM Q(gpm) 8.000 5.000 108 207.10 8.000 5.000 108 207.10 PRESS.(psi) TOTAL Q 1 ,500 414.20 1,500 414.20 KILL SPM lPRESSURE 50 360 50 360 SURVEY·DATA MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM E/W CUM DOGLEG 6,557 28.50 146.00 6,531.05 -87.79 -125.69 87.79 5.32 6,683 35.90 147.10 6,638.00 -124.70 -180.94 124.70 7.06 6,620 31.50 145.90 6,585.60 -105.43 -1 51 .79 105.43 4.76 6,746 40.90 148.60 6,687.36 -145.49 -214.07 145.49 8.07 COMPANY Marathon SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Inlet Drilling Alaska SERVICE POB@ 06:00: NO. HOURS 18 238.00 Printed: 4/3/2002 6:06:34 AM ) . . ... '. .' "' .. . . .. ....."... .... .... .. . :MÄR~rffl~N~]L.q9~ PANY . .P~·~ ly.·prIJJiI"Î9RØþqrt· . IGL 124 HRS PROG ITMD 66.00 295.0 6,825 WELL NAME KENAI TYONEK UNIT 32-7H 1ST IKB OH 87.00 ÇqMPANy·· · Baker Hughes Inteq M- Drilling Fluids $ERVlce . . ...... .PEFlSÖN~EL.[)Ärl\· ...... ....... <NQ;. .·!joÜÄS .···CQMÞANY'·. 3 48.00 Epoch Well Services 1 24.00 R&K Industrial . ... . I REPT NO. I DATE 19 4/3/2002 . .. >PQË3@þ6:pÖ; ... ·.·SERVlce·; .... .. NO~. HÖU.R$:· 2 24.00 2 24.00 ITVD IDFS 6,747 16 Printed: 4/3/2002 8:06:34 AM ) ) MARATHONOI.L.COMPANY· . Page 1 of.1 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 . . ... . .. Dai'y ·Drilling Report IGL 66.00 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Service rig @ CSG shoe. 24 HR FORECAST RIH and drill ahead. FIELD NAME Kenai 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 786.0 7,611 7,309 17 20 4/4/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 67,937.00 1,415,879.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/1/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 9.625 (in) @ 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 . I .. OP COMMENTS: Drill f/6825' to 6856'. C/O saver sub. Drill f/6856' to 7611 '. Cire. hole clean. POOH to CSG shoe. ::"::':.;: ::... :... .....:.: ··.·:;.:ÓPERA Tro~S:~.~MMARY.i: .:: . ,DEPTH TO : <::Sµ~ ;. :::'P-IASE, .; ,... .:....: DE$q~ipjION 6,856 DRLlN2 Dir drill and survey F/6825' to 6856'(ART =.8hrs AST =Ohrs). DRLlN2 C/O saver sub to TDS. DRLlN2 Dir drill and survey F/6856' to 7611'(ART=16.00hrs AST=.7hrs). DRLlN2 Cire. hole elean(CBUX2). Completed repairs to #1 generator engine @ 02:00hrs. 05:00 06:00 1.00 DRLlN2 POOH wet to 6526'(tight @ 7510' to 7486') :':ÖËNSIT)'(p'pgrl 9.60 ,·pj:i·I. :ecÞI... IMlJ[fDA"~I::þA1b'cPST:1 12,183.00 I'CµM:COSr.1 149,167.00 ::>f\i:.; i.PV/YP::· G.ËLS.: ·Wj.!tiTMP;: ':.Ftrt:~ÖV:·:· .oi, UVVAr :.:.:Di~â~dIMBt .:':ph¡pM",; ; Pf/Mt '::;:·C'·"": ·<;:a'· :H2S L.IME:·>', ES..... 43 9/29 16/20 7.4/ 1.0/8.0 /92 0.25/6.0 1.00/0.2 0.1/1.0 28,000 40 :FRON( 06:00 07:00 07:30 03:30 , ""II.. :", .:::TO:·. . :: . HB~··:· . DEPTH: F~ 07:00 1.00 6,825 07:30 0.50 03:30 20.00 05:00 1.50 01,". . ::811/ ~Uf.{ .'. SIZE·:·' 4 /1 8.500 BIT J RUN 4/1 MANUi='. :,: Baker Hughes WOB 30/30 6,856 7,611 .. .., ..:. Blr~<:,..... .. ,.. ..SEBI~LNO.: :. :"JETSqR.T:FA' V49DF 1&1&18H/ PRESS 1,600 PBIT 267 HRS 17.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 786.0 44.91 23.65 1,081.0 45.71 .",,,. T· ." '. ... ~,,' .1 .. .. . ';.. :.:.:..,,; !::":.......""".,, " .'" ·.DEPTH.IN:·DATEJN: ., 6,530.0 4/1/2002 ,. .., . . , , , . . I:"O~D-t~B~G~O-R·. 0-0------ ::;'TYPE:: MXR818DD RPM 85/85 GPM 410 ¡I '. C "aHA :0:. ../ L~~~~~ BHA DESCRIPTION " _I ÊFF=_-:I~IC~¿'I~~~ Þft~P~~, ·1;!~~~7:';~;IBHAHRS IJAA8R~ IM~íiHi1S'1 M1i1 H~S 185 HRS Tri-Cone Bit, Maeh1 X /1.4AKO /8 3/8UBHS , Non-mag 83/8" stab, Non-Mag Drill Collar, Hang-Off Sub, Non-mag C8DP , Cross Over, 5" HWDP (4), 6 1/2" hydro/meeh jars, 5" HWDP (21), Cross Over, 4" 14PPF 8-35 HT-38DP , . .. . .:M.A.KE:OF PQMÞ .;: ... PUNIP IHYDRAÜLlCCATA:;'," .1:> ··.:·ST~ÖK¡;:.(I~) ; LlNÊR(ln) . .SPM: Q(gpm): .PRESS.(ps~) .;10TI\I..; Q 8.000 5.000 108 207.10 1,600 414.20 8.000 5.000 108 207.10 1,600 414.20 KILL SPM:/ PRES$URE.· 50 400 50 400 ; NO.·: 1 2 OILWELL OILWELL :.M.D. 6,809 6,872 6,935 6,999 7,063 7,126 7,189 INCL. 41.10 44.10 45.10 44.80 44.80 44.50 44.40 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq AZI· 148.30 147.00 146.30 146.50 145.90 146.40 146.30 1''' ' : SURVEY DATA T.V.D.' NlS CUM·E/W'CUM SECrlON M.D. 6,734.90 -249.29 167.12 -167.12 7,252 6,781.27 -285.31 189.95 -189.95 7,316 6,826.13 -322.26 214.27 -214.27 7,379 6,871.43 -359.92 239.29 -239.29 7,440 6,916.84 -397.39 264.37 -264.37 7,501 6,961.66 -434.16 289.04 -289.04 7,567 7,006.63 -470.89 313.48 -313.48 SERVICE . INCL. 44.50 44.30 44.20 44.00 44.10 43.80 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial , . .. . ., . . . . . . . . . . . :. ,T.V.D., NJSCUM EIW CUM SECTION· 7,051.60 -507.44 338.19 -338.19 7,097.33 -544.41 363.45 -363.45 7,142.46 -580.66 388.32 -388.32 7,186.26 -615.54 412.52 -412.52 7,230.11 -650.20 436.96 -436.96 7,277.62 -687.30 463.82 -463.82 AZI 145.60 145.70 145.40 145.10 144.50 143.70 SERVICE NO. 1 2 1 HOURS 24.00 24.00 10.00 Printed: 4/4/2002 6:51: 18 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Circ. out to lower gas. 24 HR FORECAST Weight up and drill ahead. FIELD NAME Kenai )) MARATHON: OIL COMPANY Page 1·of.·2 . Daily Drilling Report GL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 589.0 8,200 7,793 18 21 4/5/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 70,621.00 1,486,500.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/112002, I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (tt) 13.66 ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 I STATElPROV I COUNTY/OTHER ILASTCASING Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: Service rig. Drill:Fn611' to 7832'. Circ. out gas and increase MW to 10.0ppg. drill Fn832' to 8048'. Circ. and increase MW to 10.5ppg. Drill F/8048' to 8200'. Circ. out gas. . ., .. ....""."".""...."".. . . : .:' . :, .... ., .. :, ), ,.. ·F~()M . ·to:,::. HRS,: DE~H"FM DEPTH T() 06:00 06:30 0.50 06:30 13:30 7.00 7,611 7,832 13:30 14:30 1.00 14:30 20:30 6.00 7,832 8,048 20:30 23:00 2.50 8,048 8,048 23:00 00:00 1.00 8,048 8,048 00:00 05:00 5.00 8,048 8,200 05:00 06:00 1.00 8,200 8,200 . ,.,.,.. ··ÓP,ERATIONS·SUMMAR't : .; .: :'SUB::,'·p~Ãse'. . ..; i . DRLlN2 Service rig. DRLlN2 Dir drill and survey Fn611' to 7832'(ART =2hrs AST =3.2hrs). DRLlN2 Circ. out gas (background gas 500units) increase MW to 10.0ppg. DRLlN2 Dir drill and survey Fn832' to 8048'(ART =2.3hrs AST~3.2hrs). DRLlN2 Circ. out gas(max gas 1600units) while increase MW to 10.5ppg. DRLlN2 W/R tight spot F/8020' to 8048'. DRLlN2 Dir drill and survey F/8048' to 8200'(ART=1.3hrs AST=3.2hrs). DRLlN2 Circ. out excessive gas(max gas 1763 units). Background gas staying above 250units. :'PE~SI1'Y(ppg).1 10.50 ¡.pp. I'ECD. J MUDDATAlDAI,L¥,.cosr.l ::':::':f.V .-: :·pvtv:P :: G:LS :VVIJHTHP . FC/T.SOL': 'bIlJWAT::;,:,1:Þ/I>Séi'h~MB:r::': 'Ph/pM, 42 11131 14/21 7.61 1.0/13.0 187 0.25/6.0 9.20/0.1 ·BIT(RUN: "·S.IZE'· 4 /1 8.500 . '".". BIT' RUN 4 11 WOB 25/30 , RPM 80/80 "". I" '·,<.::BrrS 'il:.,: , .:. TYPE·: . " .SERIAL.:,;m:··' : JETS' oatFA ' MXRS18DD V49DF 18/18/18/11 GPM 412 PRESS 1,850 HRS 13.35 24Hr DIST 589.0 .,. .. DESCf:iIPTI()N;.:: y.. :,: PBIT 296 . ,. 9,290.00 ::PUM;PPST:, 158,457.00 : ·pflrlilf'::'< .:.:,: ,CI . :Ca· ':,: ':~ H2S ,~:l.l~E' ES' 0.1/0.8 28,000 20 'I'. :1::::'<::;,,;:1 ",,:1; :·DEPTH IN:'DATE'IN·.,' 6,530.0 4/1/2002 : ..I~o~b~t.;,B~G~6~R:' :. .. 0-0--00-- 24Hr ROP CUM HRS CUM DEPTH CUM ROP 44.12 37.00 1,670.0 45.14 :SHA40..,·, L:~~7~: . BHA DESCRIPTION I~F:' '·1 PiC~6~'I~~~OF1S0~~: ··IT6~~~:min¡'..' 'IBHAHRSIJAA HAsIMW6HSS ~HRS I SsHss' Tri-Cone Bit, Mach1X 11.4AKO 18 3/8UBHS , Non-mag 8 3/8" stab, Non-Mag Drill Collar I Hang-Off Sub, Non-mag CSDP ,Cross Over, 5" HWDP (4), 61/2" hydro/mechjars, 5" HWDP (21), Cross Over, 4" 14PPF S-35 HT-38DP ....' . NO. 1 2 MAKE OF PUMP OILWELL OILWELL PUMP/HYDRAULIC DATA STROKE (in) LlNEfI (in) SPM· Q (gpm) 8.000 5.000 107 205.18 8.000 5.000 108 207.10 M.D. . 7,627 7,690 7,755 7,817 7,880 INCL 42.30 39.80 38.00 37.00 35.00 AZI 145.80 148.40 151.00 152.70 155.50 SURVEY DATA T.V.D. NlS CUM EfW CUM SECTION ·M.D. 7,321.47 -720.74 487.47 -487.47 7,943 7,368.98 -755.45 509.95 -509.95 8,006 7,419.57 -790.68 530.56 -530.56 8,071 7,468.76 -823.95 548.37 -548.37 8,132 7,519.73 -857.24 564.56 -564.56 INCL 32.20 30.60 30.90 30.40 COMPANY Marathon Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Baker Hughes Inteq 18 238.00 M-I Drilling Fluids PRESS. (psi) TOTAL Q 1 ,850 412.28 1,850 412.28 KILL SPM:' PRESSURE 60 520 60 530 AZI 159.50 165.20 174.30 181.30 T.V.D. NlS CUM EfW CUM SECTION 7,572.20 -889.42 577.93 -577.93 7,625.98 -920.65 587.91 -587.91 7,681.88 -953.27 593.80 -593.80 7,734.37 -984.30 595.00 -595.00 SERVICE NO. 3 1 HOURS 48.00 24.00 Printed: 4/5/2002 8: 10: 19 AM WELL NAME KENAI TYONEK UNIT 32-7H . :COMpANY . Epoch Well Services ') 1sT IKB OH 87.00 SERVICE MARATHON OIL. COMPANY Daily Drilling Report . IGL 66.00 124 HRS PROG 589.0 TMD 8,200 . PERSONNEL DAtA ... . .. . " . , . NO. . HQURS .:COMPANY 2 24.00 R&K Industrial ) ITVD I DFS 7,793 18 SE~VIC~ ~åg~2 of 2 . . I REPT NO. 21 Printed: 4/5/2002 8:10:19 AM I DATE 4/5/2002 NO. .. HOURS ,:. 2 14.00 ) ') · . .. .... . . ... .. .. . ,... . ...." '. ...... .. . ... . . . . ... ... ... . . .. ..... . . .. ... "' ...... ..... . . . ... ... .. ..... .. .... ... ..... ..... '" ..... . . ....... ...... . . .. . . . . .. . .. ..... .. .... . ... ... "' ... .... .... .. ... .. . .. . ...", .... .", . . . . . .. ·····I\IIÄRAìHON: OIL. CO:MPANY· WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS RIH @ 5500'. 24 HR FORECAST RIH. Drill ahead. FIELD NAME Kenai ... ............. .... .. .... .... . ... .... ......... .. "' '" ..... . ... o ......... .. .... 0"" ...... . . .. . . . ,".. . .... ......... ..", . . '" .., .. .... · ..,. . ... .. .... . . . .. ...... ... .... . . . .. . .... . ... ....... ....... ... .... .. . ..... . . ..... .. ·~~nY[)rilli[1g¡f-tep()rt···· . . GL 66.00 . ... . . . ·RaQ~1dt2 ... ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 24HRSPROG TMD TVD DFS REPTNO. ¡DATE 57.0 8,257 7,842 19 22 4/6/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 100,734.00 1,587,234.50 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/1/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: Circ. out gas and increase MW to 10.8ppg. Drill F/8200' to 8257'. Work stuck pipe free. Circ. and condition mud. POOH. C/O jars and bit. C/O MWD battery. RIH. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 08:00 2.00 DRLlN2 Circ. out gas and increase MW to 10.8ppg. 08:00 11:00 3.00 8,200 8,257 DRLlN2 Dir drill and survey F/8200'to 8257'(ART =.8hrs AST =2hrs). 11:00 11 :30 0.50 8,257 8,257 DRLlN2 Work stuck pipe @ 8257'. Pipe came free(max overpull 70K) Jars would not fire. 11:30 13:30 2.00 8,257 8,257 DRLlN2 Bleed in 3% Lubtex. 13:30 16:00 2.50 8,257 8,257 DRLlN2 Increase MW to 11.0ppg. 16:00 20:00 4.00 8,257 8,257 DRLlN2 POOH. Wash and ream tight spots @ 7985',7535',7295',7108',6971', 6896'. 20:00 21:30 1.50 8,257 8,257 DRLlN2 Circ. shakers clean(CBU X2) @ 6526'. Pump slug. Blow down lines. 21:30 03:00 5.50 8,257 8,257 DRLlN2 POOH. UD jars and C/O bit. 03:00 03:30 0.50 8,257 8,257 DRLlN2 C/O batery for MWD. 03:30 04:30 1.00 8,257 8,257 DRLlN2 RIH W/BHA and test MWD. 04:30 06:00 1.50 8,257 8,257 DRLlN2 Cont. RIH fill pipe @ 3638'. DENSITY(ppg) 11.05 I PP I IECDI I MUD DATAl DAILY COST 31,878.00 I CUM COST I 190,335.00 FV PVIYP GELS WUHTHP FCIT.SOL OIUWAT %SandlMBT Ph/pM Pf/Mf CI Ca H2S LIME ES 48 17/39 16/21 6.6/ 2.0/15.0 3/82 0.25/10.0 9.00/0.1 0.1/1.0 27,500 40 BIT / RUN 4/1 5/1 SIZE 8.500 8.500 MANUF. Baker Hughes Baker Hughes TYPE MXRS18DD MXRS18DD BITS SERIAL NO. JETS OR TFA V49DF V52DF 18/18/18/// 20/20/20/// DEPTH IN DATE IN 6,530.0 4/1/2002 8,257.0 4/6/2002 I-O-D-L-B-G-O-R 2-3-CT-G-E- 1-EC-DTF 0-0------ BIT / RUN 4/1 WOB 30 / 35 RPM 80 / 85 GPM 368 PRESS 2,000 PBIT 248 HRS 2.80 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 57.0 20.36 39.80 1,727.0 43.39 · ~HA . I EFFWT! I SI..ACKOFî ROTWT. ITORÖUE(I?~X/ri1in) I BHAHRS ¡JAR HRS I MVVD HRS MTR HRS I SS HRS Tri-Cone Bit, Mach1 X /1.4AKO /8 3/8UBHS , Non-mag 83/8" stab, Non-Mag Drill Collar, Hang-Off Sub, Non-mag CSDP , Cross Over, 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), Cross Over, 4" 14PPF S-35 HT-38DP I?HANO, .... ·:1 LENGTH 5 882.51 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM a (gpm) PRESS. (psi) 8.000 5.000 98 187.92 2,000 8.000 5.000 98 187.92 2,000 TOTAL a 375.84 375.84 KILL SPM / PRESSURE 60 600 60 600 OILWELL OILWELL M.D. 8,194 INCL. 29.80 AZI 188.80 SURVEY DATA T.V.D. N/S CUM ElW CUM SECTION M.D. 7,788.03 -1,015.2 592.29 -592.29 INCL. AZI T.V.D. N/S CUM ElW CUM SECTION Printed: 4/8/2002 6:46:47 AM WELL NAME KENAI TYONEK UNIT 32-7H . . . .... '" .. . . "' . '" . · .... · ÇOMpÄNV . Marathon Inlet Drilling Alaska Baker Hughes Inteq ) I~H ~;.oo ") . .. . . . . ... . . . . . . . . .... . .., . .. .. .. . . . . . ... .. ... .. .. . .. . . ... ...."..... ....... .. "... .. .. . .. .... .. ... . . . ... . .. . ·.·..·IV1ÄFt·~,.1-I9N:plh..·.~9M:P?\NY:· ... .. : ... ··PéliIY·ØI"~ IlilÎglTlépÔ~f·· ... GL 66.00 124 HRS PROG 57.0 ITMD 8,257 ··ÞERSONNEL,·0t\l'Þ\.. .... ..... .. NO, ... ··.HÇllJR$ . .. ···CC>MPANY ... 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial .. HÓUR$ · 1 24.00 2 24.00 2 14.00 Printed: 4/8/2002 6:46:47 AM ) ) · . ... .. . . .. ... . ...... .. · . .. . . .....". ...... ... · .. .. ,". . . . . . . . .. . . . .. . .. . .. . · . .. ... . . . . . ... . ... .. . . ... 0"" '" ... ..... ·""0 .... ...... . .. . ··<IVIARATHONOIL..:ÔQI\II:PANv· . .... ..... .... ,.. . ..", ....... ... .... ..... ...... ..... . .. .. ............... .... . . ....... .. ...", · ....... ..... ... ... .... . .... .. . ....", . . .. .... ... .......", . . ...... ... ....... .", . ... . . .... ... ....... ........." . . . .. .. ... ,".. ....", ........ .... · . .. . . .. .... . ... .. . . . [j ·~·I··ltf ~II··~···.···· ··.·R·· ..... ... .·Y. ····.t· .... .. .;;uy<rl..ll"lg>~.pqL· ..... GL 66.00 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Drilling ahead. 24 HR FORECAST Drill ahead. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 24HRSPROG TMD TVD IDFS REPTNO. I DATE 343.0 8,600 8,131 20 23 4/7/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 47,870.35 1,635,104.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/112002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 I STATE/PROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: Service rig. RIH to 8257'. Drill f/8257' to 8600'. DRLlN2 Service rig. DRLlN2 Cont. RIH to 8257'. DRLlN2 Dir drill and survey F/8257' to 8600'(ART = 4.4hrsAST =1 0.3hrs)(lost 1 hr to clock change for Daylight Savings Time)(lncrease MW to 11.3ppg @0500hrs). .Þ¢.NsrtY.(~,~Q) 11.15 :pp'i¡ I:·~ÞDI I:MÛ()::DÄj"ÄI¡·PAIWY:ë()~TI 11,330.35....... 1::êu~:q?$T:·::1 201,665.35 ..... PI·:. ·F='VI:YP; ... ·ØELS: ·WllI-{THfi:F¢tTlé61L :ÒÎL/WAT:: ·.··%$~rI~iMËrr ...... :F?h/pM ... . .x Pf/M1 .. ::::.0.1. . .. .:: t!â. "H2S :. ¡:LIMj; : .: ES·· 52 19/40 19/26 7.2/ 2.0/17.0 3/80 0.50/7.5 9.0010.1 0.110.9 29,000 80 FROM TO HRS 06:00 07:00 1.00 07:00 10:00 3.00 10:00 06:00 20.00 DEPTH FM DEPTH TO SUB OPERATIONS SUMMARY PHASE DESCRIPTION 8,257 8,600 5/1 8.500 Baker Hughes MXRS18DD V52DF 20/20/20111 8,257.0 4/6/2002 0-0------ BIT I RUN 5 I 1 WOB 25 I 35 RPM 78 I 82 GPM 400 PRESS 2,200 PBIT 194 HRS 14.60 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 343.0 23.49 14.60 343.0 23.49 ~þ;. 1 2 ·rv1AK~C)FPIj.MP: . ::'.:.... . .".. ....... .............. .. ......... .. .. .. .. ... ... ....:.:: ....:.. :' . .. .... ..... . ...... .... .........: <i : ..·...·.·.··.i( ::::: ..·...·....··.···.·"BH~,:·>i.. ..... ¡.. .... ..¡ ..... <:: :<: ::·<·,¡:f:>· "E;Ff;:: .·PiÞ1 ~i ..., ~~~ØFF~~ ;::·I..røi;!9Ì'J$~~~ini'Í)lii~A~RS' JAFâUJ$ ··IMWb'!1R$. M~~'~Å$' Tri-Cone Bit, Mach1X 11.4AKO 18 3/8UBHS , Non-mag 8 3/8" stab, Non-Mag Drill Collar, Hang-Off Sub, Non-mag CSDP , Cross Over, 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), Cross Over, 4" 14PPF S-35 HT-38DP ···Pl.JMP·jHV[)RÂl.U"IÖDATA .. .... $r~pl<¢(i~)UNEFfWî) ..:. ŠPM· '9(91)01) 8.000 5.000 103 197.51 8.000 5.000 103 197.51 . ........ ....... .. . "' . .......... ....... ......... .. . .... . ... . ... . . ..... ... ... ... .... ...",.. ......... .. ....... . ....... .. . ...........",... ß8A:t>J(?··I,ÜÚ~êtH 5 882.51 BHA DESCRIPTION OILWELL OILWELL 395.02 395.02 ··>KILLsPM/PRËSSURE : 60 520 60 520 SURVEY DATA . T.V.D. NlS CUM ElWCUM SECTION M.D; 7,839.14 -1,044.0 586.38 -586.38 8,443 7,893.18 -1,074.9 576.56 -576.56 8,506 7,947.38 -1,106.0 562.92 -562.92 T~V;D. NIS CUM E/WCUMSËCTION 8,000.24 -1,135.6 545.62 -545.62 8,052.76 -1,163.1 524.33 -524.33 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial SERVICE NO. 1 2 1 HOURS 24.00 24.00 14.00 Printed: 4/8/2002 6:44:32 AM ) ) .. . . ... .. . .... . .. · ....... .. .. ...... . . .. .. ... . .. . . . . ... . . .. · . .... . ... . .. . ... .. ... ... . .. . .. . .. . . . ........ ..." . ..... ... . . . ...... ..... ... .. ....... ..... .... ..... . "' .... ... . . . . .... ... "' ... . .." .... ". .. .. ... .. ........ . ... ....... .... .. .... . . .. .... . .", . . ........ ..... .. .. ...... .... . . ............. . ... . .. .. . .. . ... ..... ..... .... ........ .. .. ., .. ·MARÄTHONÖILct>MPANY ...... . . .. . ... . . . ... . . . .. .. . . . . . . . . .' ... "' .. "' .. . . ... .. . . . ",. . ... . .. ",".. . ..... .. . ....... "' . · · · ........ . ·;····p~9èr()f:1. WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R Clawson CURRENT STATUS RIH @ 8800' 06:00hrs. 24 HR FORECAST Drill ahead. FIELD NAME Kenai 124 HRS PROG TMD rvD IDFS REPTNO. I DATE 267.0 8,867 8,340 21 24 4/8/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 43,591.00 1,678,695.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/112002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 9.625 (in) @ 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 .."...... ."' '" .... ...... . . ..... ". ......... . ....... ...... .. . . "' .. ...... .. ....... ... .. ... . .. . ..... ....... ......... · ... ..... ...... .. ....... ..... ..' ..... . .... .... ... ...... . ... . . ... ..... ... . . . .... ... ..... .......... ... ... .. .................. ....... .... ...... ..... . . . . ... . .. . . . .. .. ,. . . .'. . .. . . . . .. ... .. . .... ..... . ...... .... ........ ... ... . . ... ..... .......... ·.·····....··..··..Q~iiy·::t:>til.li.Q.g::R~p:()t(i..····· . ..... . . . ...... ...... . .... . .... ... ............ .. ... ........... .... ............ .............. IGL 66.00 ST KB OH 87.00 RIG NAME & NO. GLACIER DRilLING 1 OP COMMENTS: Drill f/8600' to 8867'. Circ. shakers clean. POOH to CSG shoe @ 6526'. Service rig. RIH. OPERATIONS SUMMARY "" " I' ' '"'''' FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 00:30 18.50 8,600 8,867 DRLlN2 Dir drill and survey F/8600' to 8867' 00:30 02:30 2.00 8,867 8,867 DRLlN2 Circ. shakers clean(CBUX2). 02:30 04:30 2.00 8,867 8,867 DRLlN2 POOH(wet) to CSG shoe @ 6526'. 04:30 05:00 0.50 8,867 8,867 DRLlN2 Service rig. 05:00 06:00 1.00 8,867 8,867 DRLlN2 RIH. ,;~:~I~~~~ . 'iG~~~~J;:r~'~,.fÇIT;SÓll~7~!ÎJWA+~~~~t~~¡·rt¡it:~~þ~;I, ¡;~;::.~O;;..cìl¡,1~~;:~~'!;ij~~6~~~3~E$ 46 15/34 14/22 6.81 2.0/15.0 4/81 0.25/5.0 8.5010.1 0.1/1.1 29,000 60 8.500 Baker Hughes MXRS18DD V52DF 20/20/20111 8,257.0 4/6/2002 0-0------ BIT I RUN 5/1 WOB 30/35 RPM 78 I 80 GPM 383 PRESS 2,100 PBIT 180 HRS 13.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 267.0 19.78 28.10 610.0 21.71 BHA NO. I LENGTH 5 882.51 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF1ROT WT. I TORQUE (maximin) I BHA HRS JAR HRS I MWD HRS I MTR HRS I SS HRS 39 160 125 140 8 112 Tri-Cone Bit, Mach1X 11.4AKO 18 3/8UBHS , Non-mag 83/8" stab, Non-Mag Drill Collar, Hang-Off Sub, Non-mag CSDP , Cross Over, 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), Cross Over, 4" 14PPF S-35 HT-38DP . .. ... ..... ·..···ÞOMÞIHv.CRAUt..IÖDÅTA··· Np. .... . <. .··.MAKeOFPU~p> >.... ... ... ···..·STRO~E.(¡r1j ... LïNEFf(hl).SPJiij< ·Q·(gpm) . PRgS$: (pSI) 1 Oil WEll 8.000 5.000 100 191.76 2,100 2 OILWELl 8.000 5.000 100 191.76 2,100 . fÞtALC} ·.·.KllL SPM1PRESSUfÏË 383.52 60 540 383.52 60 545 SUR\fEYDATA··. T.V.D. NlS CUM E/W CUMSECTIONM.D; 8,105.00 -1,188.6 500.11 -500.11 8,757 8,156.01 -1,212.0 473.74 -473.74 8,819 8,207.00 -1,233.5 443.66 -443.66 T,V.D. NlS CUM EIW CUM SECTION 8,256.65 -1,252.9 410.10 -410.10 8,304.01 -1,270.0 373.96 -373.96 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial Printed: 4/8/2002 6:42:08 AM } ) . MARATHON OIL CO.MPANY ·Pag~.1·of.1 ., WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Drill ahead. 24 HR FORECAST Drill ahead. FIELD NAME Kenai · .. · .. " . . . . . . · .; .·.Dªilÿ:·DriHing Report ST I KB I GL 124 HRS PROG TMD TVD I DFS REPT NO. I DATE OH 87.00 66.00 213.0 9,080 8,487 22 25 4/9/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI INRI DAIL V WELL COST CUM WELL COST 100.00(%) 92.20(%) 57,579.00 1,736,274.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/112002 I STATElPROV I COUNTY/OTHER ILASTCASING NEXTCASING LEAKOFFPPG Alaska Kenai Borough 9.625 (in) @ 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 OP COMMENTS: Drill f/~867' to 9034'. Circ. and increase MW to 11.8ppg. Drill f/9034' to 9080'. . .. ,... : .:ÒRç~t\TIONS··SUMI\II~,RY'··;·: :. ... ........ . . 'DEPTH·FM: DEPTH Ï'öi . SUB..·:·I:JHA.~E·:·. .. .... .... . DEsCRIPTIoN>·"·" . 8,867 9,034 DRLlN2 Dir drill and survey F/8867' to 9034'(ART =2.6hrs AST =4.8hrs). 9,034 9,034 DRLlN2 1200 units gas to surface mud spraying up to rotary table. Shut in well. CSG and DP pressure Opsi. Circulate through choke 2.7BPM while increase MW to 11.6PPG. Open annular circulate and work DP(background gas 500units). DRLlN2 Circulate out @ 9BPM(background gas 350-600units). DRLlN2 Circulate and increase MW to 11.8PPG. DRLlN2 Dir drill and survey F/9034' to 9080' (ART =1.0hrs AST = 2.3hrs) ., F~9ì1ir;. T~i <.. : :HF.(Š: 06:00 17:00 11.00 17:00 22:00 5.00 22:00 23:00 1.00 23:00 01 :00 2.00 01 :00 06:00 5.00 9,034 9,034 9,034 9,034 9,034 9,034 DE~ŠllJ(ppg·) ·111.60 .I,I='~,·I .1 :EG[) I . I MÜï:>"PÀTA:!::' pAI!Ä,rCOS1< I .' :¡d=V,,·· pW'iP.::; i,GEL$:: :WUH~i;tP·, ·.:.Fcrr~SOL.. ,::.()njw~t::· .:¡·~kß~~~MBt. .:. . "::, PIJ!p~:: 44 14/34 12/21 6.51 2.0/16.0 3/81 0.25/5.0 9.00/0.2 " , 11,844.00 .R'I,Mf·. .. 0.1/1.2 1··c~M;CO$l'·1 218,509.35 :'ci,:: ,·:):::'çël . :::'H2S·,: ,L.j~~:" ;·ES::· 30,000 40 n~~":1 MXRS18DD f ;,..~.·:\I:;, .'.:SE~.IÀ~~~.;:~·I·'!:";~.:JeTè:6.R'T,iA,.",.\:' . V52DF 20/20/2011I .,r,,!',: I," · .·Dè~iH ,iN/ÓÂ,.ÈI,N ;:::: ..:, 8,257.0 4/6/2002 ,. .,'c t .' ,. .1 " . . ~ I . .. . -,. A ^ . :·:BI'T / R~N \:. :: :~SI~·E, ,; :. 5 /1 8.500 I" ;:"'1,·" ,.., . ,'. ,,::,'~AN,UF~"·· Baker Hughes :.)-O~6~(.~~ri~d~R 0-0------ BIT I RUN 5 11 WOB 30 / 35 RPM 78 I 80 GPM 364 PRESS 2,250 PBIT 170 HRS 10.70 24Hr DIST 213.0 24Hr ROP 19.91 CUM HRS CUM DEPTH CUM ROP 38.80 823.0 21.21 . ·1·' . . !" : ','.'.: ,,:'1 r. : '.! . BHA~Ó;: ':·I'L~~~~5~. BHA DESCRIPTION .:~:.»:::.. ";... :,...:. ..:'..;' ·,.'·.:·;:;":':"6HA::':::· ,.::., ..,.,. .,., :··,i.:\.::··....... . .:;.,.."! . 'I'EFI':: ~lç~~t'l S~~aff;Rq~:f; ·lrQì'ié!U~¿"7:inilÌ)~HAHf!~1 jÌ\ÌIHRS,'~D~RS. iJlTR HRs:ISS:fJ~S: Tri-Cone Bit. Mach1X 11.4AKO 18 3/8UBHS . Non-mag 8 3/8" stab, Non-Mag Drill Collar. Hang-Off Sub, Non-mag CSDP ,Cross Over, 5" HWDP (4), 61/4" hydraulic jars . 5" HWDP (21), Cross Over, 4"14PPF S-35 HT-38DP . :PUMPJ.H'lDRAULlC:DATA: , . . ::NO;' 1 2 . .: NlÁKE OF PUMp··, :. . OILWELL OILWELL ·ÇOMP~NY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE . StRO~E· (in) ;l:.lNEfI.:,(i·nh,' ~p.r~f:' <;) (gpmr' PRESS; (psi), , TOTAL cf 8.000 5.000 95 182.17 2,250 364.34 8.000 5.000 95 182.17 2,250 364.34 PERSONNEL, CAT A No.· ·HOURS: . C()MPÄN'( 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial KilL: S~M .'·PRESSÜRE 60 640 60 640 SERVICE , NO. ··i-IOURS· 1 24.00 2· 24.00 1 6.00 Printed: 4/9/2002 9:12:28 AM ) ') . . ·I\ßARATHON OIL. COMPANY . . . . Daily DrUHng, Repcu1: . ST I KB I GL 124 HRS PROG TMD TVD I DFS REPT NO. I DATE OH 87.00 66.00 113.0 9,193 8,554 23 26 4/10/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 60,922.00 1,797,196.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 3/31/2002 4/1/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 Page J. of 1· WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Testing BOPE. 24 HR FORECAST Test BOP. C/O BHA and Bit. RIH. Drill ahead. FIELD NAME I STATElPROV I COUNTY/OTHER.' LAST CASING Kenai Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: Drill F/9080' to 9194'. Circ. hole clean. POOH. Service rig. Test BOPE. : .,' ,"; . : OPERATIONŠ::SUIVIMARY. "".;¡: : I",""' 'ï .. .. .. ,:'.;:.... . , ., : ". ..,. \....,,,..:, '; '," ...",¡::';" : bEPT~ t9 ';>PHAšE!: . ·11":·""..".... ....,"".."...."". ., , F~c)~ ..:1:0 .: ...: H.~s:., OE~TI:i' FlY! SUB: : [)E·SCRIPTloN. ::<.. . ,. ,.. .. < 'CJ 06:00 17:00 11.00, 9,080 9,193 DRLlN2 Dir drill and survey F/9080' to 9193'(ART=2.8hrs AST=4.0hrs). 17:00 20:00 3.00 9,193 9,193 DRLlN2 Circ. hole clean and bump MW up to 11.8ppg. 20:00 21:00 1.00 9,193 9,193 DRLlN2 POOH to 8574'. 21:00 03:00 6.00 9,193 9,193 DRLlN2 Pump slug and POOH. 03:00 03:30 0.50 9,193 9,193 DRLlN2 Service rig. 03:30 05:00 1.50 9,193 9,193 DRLlN2 Pull wear bushing. Run test plug. 05:00 06:00 1.00 9,193 9,193 DRLlN2 Test BOPE. ';.PE~SITY(þpghl 11.85 I :'p:p: I I ECD IMUp:·PATAlp~'LiY·9qSTj 14,774.00 I: CUN/,:ÇCl~T: I 233,283.35 :i·:'.FV>·: ,.P\I!J.,:P:· ':··~E:LS:, W~.JIÙI:Ü:) ·:·Fcrr~$Ç)L:·. ·.OU,/WAT:·¡, :·;,%Sàl1~Ml3r.', Ph/pJ\II :u.",..<pf/Nlf,; . 01", :ça: : ·,H2$.·, (·:LlrinE', ,ES. 47 17/35 14/22 6.8/ 2.0/17.0 5n8 0.25/6.0 8.50/0.1 0.1/1.2 29,000 40 ;;$ITÚmN: ,; '·siZE.'· 5 /1 8.500 MANUÞ.' : '. Baker Hughes BIT I RUN 5/1 WOB 30/40 RPM 80/85 .,,' '../ :, ::, .:, :·!:·,',;,B~T~,<,:, ';::...: ;TY~E. .' . ,~.I:R.I~L NC;>.:, .<. . "E'n:; ÇU:¡,TfA¡ MXRS18DD V52DF 20/20/20/// /c: I 'I'· .. P" , ; ¡' .; D!=PTH fN,.DATe i~:';, ; 8,257.0 4/6/2002 'H:>~~L~B~G-O-~ ". 2-2-WT-A-E- 1-SD-BHA I'; GPM 374 PRESS 2,400 HRS 6.80 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 113.0 16.62 45.60 936.0 20.53 PBIT 180 · ~tiÄfÒ::ll~:!5~ ... BHA DESCRIPTION IEF~ ~'\·IPIC~~: .1 s~~ OF1RQ;:·· ~O~~~ ~:rTÎn)" B~ HRSI"~ HRS'" M~Þ~~~:IMr~~R~ ~1¡>$;Ä~s: Tri-Cone Bit, Mach1X /1.4AKO /8 3/8UBHS , Non-mag 8 3/8" stab, Non-Mag Drill Collar, Hang-Off Sub I Non-mag CSDP Cross Over, 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), Cross Over, 4" 14PPF S-35 HT-38DP .. NO. 1 2 . . .~AKE OF.PUMp· OILWELL OILWELL : . . ~ PUMP1 HYDRAULlC:DA T A"· , . SrROKE:On) . LINE'R (In) .': SPM·· Q (gprr.) PRESS; (psi) . 8.000 5.000 97 186.01 2,400 8.000 5.000 98 187.92 2,400 TOTAL Q 373.93 373.93 .: KILLSPr\If., PRE;S$U,RE 60 600 60 600 M.D.· . 9,070 INCL. 50.30 . ·AZI 258.00 ,SURVEY DATA T.V.D. NIS CUM8w CUM SECTION.. . M.D; .. 8,480.15 -1,320.0 202.92 -202.92 9,131 AZI 261.10 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq INCL. 53.30 . T.V.D. . NlS.tUM E/W CUM SECTION 8,517.87 -1,328.7 155.78 -155.78 SERVICE ·PERSONNEL' DATA NO. HOURS : COMPANY· 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 48.00 R&K Industrial HOURS 24.00 24.00 20.00 SERVICE NO. 1 2 2 Printed: 4/10/2002 7:13:28 AM ) ) ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) @ WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Drilling ahead @9220'. 24 HR FORECAST Drill ahead. FIELD NAME Kenai .MARAiHON OIL,COMPANY ·:pag·e lof.2·. .. . . . .. ... . :DaUy.C·rilling:Repo·i-t IGL 66.00 24HRSPROG TMD TVD IDFS REPTNO. DATE 27.0 9,220 8,568 24 27 4/11/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 37,955.00 1,835,151.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/10/2002 4/10/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 OP COMMENTS: Test BOPE. C/O mud pump liners and repair koomey. Repair finger board. P/U new bit and motor. M/U BHA. RIH to CSG shoe. Circ. out gas. RIH to 9162'. Circ. out gas. Drill f/9193' to 9220'. F¡:¡ÖN( ::to! H·RS. .. .DEPTH FM: :PE;~Tti:TÇt ...;'·SUB· 06:00 10:00 4.00 10:00 12:00 2.00 12:00 13:30 1.50 13:30 16:30 3.00 16:30 21 :30 5.00 21 :30 22:30 1.00 22:30 00:00 1.50 00:00 02:30 2.50 02:30 06:00 3.50 9,193 9,220 ,,,. ,,,,,,,,,,....,.., """"""" . ... "' ."" ."....." . . ....... ........ ,....."............. Cn~E:RAT.19N·S:SUMMARY¡,.,. . .. .::;..;.:.:::. .. .,. :¿. ·.I~~ASE ,. . I' l' DE'SCR(~J.io~:·:::-; ;/:" ..... .. . DRLlN2 Test annular, upper variable rams, blind rams, lower pipe rams, IBOP, TIW valve, choke and kill line valves, upper and lower kelly valves, 1-12 choke manifold valves to 250/3000psi 5min. Perform accumulator test. UD test plug. Install wear bushing. Blow down choke. C/O pump liners to 4.5". DRLlN2 Repair triplex pump on koomey unit while C/O mud pump liners to 4.5" . DRLlN2 Cont. C/O mud pump liners. DRLlN2 Begin UD used mud motor. Tugger line caught monkey board. Inside finger on off drillers side board gave way and the first row of HWDP shifted to the driller side fingers. Latch HWDP and RIH to clear fisrt row of pipe on off driller side board. Repair finger. POOH and rack back first row. DRLlN2 P/U new bit and motor. M/U BHA. RIH fill pipe @ 3300'. Cont. RIH to CSG shoe @ 6526'. Circ out gas(CBU X 1.5) @ shoe(max gas 1650 units). RIH to 9162'. Circ. out gas(CBUX2 max gas 1280 units). Dir drill and survey F/9193' to 9220'(ART = .4hrs AST=2hrs). .' .:~ .\. DRLlN2 DRLlN2 DRLlN2 DRLlN2 j~'FNSjTY(PP.9) I 11.80 I·pp· 'ECD IMÚDDATAlhjAi,lrY,CQST, 8,263.00 :.:: fV: ' . ·.pvt'{p·\· GELS: :'WuHTHp·:Fcrr.soÇ on:,JWAT~!; :'·.:o¡oSa,nd/M.BT .'::. :·:PtiJplVf-:..: "PI/Nif'.' 49 16/32 11/18 6.41 2.0/17.0 4/80 0.25/6.0 9.0010.1 0.1/1.3 .qu.M:.c.osrl 241 ,546.35 ·.Çl.' ·:.::'iba:'.;: H2~"': ·lJM~: ::.ES::' 29,000 40 .. . .'BITfRur·,f ;. SIZE· 6 /1 8.500 . . MANUF; Baker Hughes ·TYPE MXRS18DD BIT I RUN 6 11 WOB 30/40 RPM 78 I 80 GPM 383 .. ;. . . BITS:::,' . . 'sE~i.ALNO..:··: ··JEis.ORtFA :.:,:.. V48DF 20/20/20111 ' DEPTHIN'·DATE IN 9,193.0 4/10/2002 ., , . ·:I~q-D-L::'B,;;G~cP.~R 0-0------ PRESS 2,660 HRS 2.40 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 27.0 11.25 2.40 27.0 11.25 PBIT 188 BHA· EFF WT. I PICK UP I SLACK OF~ROT WT. TORQUE (maximin) BHA HRS JAR HRS I MWD HRS MTR HRS . S$ HRS 48 158 123 I 138 10 I 6 Tri-Cone Bit, MACH1X/1.2AKO/8 3/8UBHS, NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP, X/O 4 1/2" H90-P X 4" HT-38P ,4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 41/2" IF-B , 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), X/O 41/2" IF-P X HT-38-B ,4" 14PPF 5-35 HT-38DP BHA NQ. LENGTH 6 1,756.21 BHA DESCRIPTION ·NO. 1 2 MAKE OF PUMP OILWELL OILWELL COMPANY Marathon Inlet Drilling Alaska SERVICE PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM a (gpm) PRESS. (psi) 8.000 4.500 125 194.16 2,660 8.000 4.500 125 194.16 2,660 TOTAL a 388.32 388.32 KILL SPM I PRESSURE 60 580 60 580 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Baker Hughes Inteq 18 238.00 M-I Drilling Fluids SERVICE NO. HOURS 2 48.00 1 24.00 Printed: 4/13/2002 12:03:46 PM WELL NAME KENAI TYONEK UNIT 32-7H '. "'" "'" .".. ,. : COMPANY· Epoch Well Services ) 1sT IKB OH 87.00 SERVICE .MARATHON OIL COMPANY Daily .Drilling :Repor~ IGL 124 HRS PROG ITMD 66.00 27.0 9,220 .......:... P:ERSPN~ÈL DATA . . ·NO.:· HOURS.tqJYIP~NY· . 4 48.00 ") Page 2 Qf ·2.· . ITVD DFS I REPT NO. I DATE 8,568 24 27 4/11/2002 : . . ... SERVICE· . NO':.··· HOU~S . ~ Printed: 4/13/2002 12:03:46 PM I STATE/PROV I COUNTY/OTHER LASTCÁSING Alaska Kenai Borough 9.625 (in) @ WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Drilling ahead @ 9320'. 24 HR FORECAST Drill ahead. FIELD NAME Kenai )) MARATHON OIL CO.MPANY .. Page ,t·oC1.. , .. ·.·DéiUy Drilling· Report IGL 66.00 ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 100.0 9,320 8,623 25 28 4/12/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 60,323.00 1,895,474.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/10/2002 4/10/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 OP COMMENTS: Drill F/9220' to 9304'. Trouble shoot mud pump#1. POOH to CSG shoe. C/O hydraulic motor and slip and cut drill line. Test run pump#1. RIH. CBU. Drill F/9304' to 9320'. Oþ'ER~TIONS:SÚMM:ARY.·;,·.: .. " :: .' ...:' .. ·~UB"',:.J:)HA,~·E'· ... ,DES.c:R.IPTIÓt·(' DRLlN2 Dir drill and survey' F/9220' to 9304(ART =2.4hrs AST =2.4hrs). DRLlN2 Circ. with pump#2 while trouble shoot pump#1. DRLlN2 Pull 5 stands to 8994'. Pump slug. C/O Haagland hydraulic motor while POOH to CSG shoe. DRLlN2 Service rig. Cont. C/O Haagland hydraulic motor on pump#1. DRLlN2 Slip and cut drill line. DRLlN2 Cont. C/O Haagland motor. Test run mud pump#1. DRLlN2 RIH. DRLlN2 CBU(max gas 670units). Trouble shoot hydraulics #1 pump. DRLlN2 Dir drill and survey F/9304' to 9320'(ART =Ohrs AST =1.2hrs). LiFCD I ,I M.oD,'~PA T ~,P:D~ILY:cos{1 13,182.00 1:::çurw,(cOsr:· 254,728.35 ·F;ctr;$QL:.('·9IUW~T: ,; ,·::·.%S~nd/IÌllFn:·.·:. .'··:·Ph/pM'.:, . .):JflMt:::,:· .. cf·'·'·:: :.:. :c¡f: ..: 't12S . ,LIME :. ES>. 2.0/17.0 5/78 0.15/6.0 8.50/0.1 0.1/1.3 29,000 40 , ·:f:jAS:" ;, FR()M. :; 10· . 06:00 14:30 8.50 14:30 15:30 1.00 15:30 18:00 2.50 18:00 18:30 0.50 18:30 20:00 1.50 20:00 22:30 2.50 22:30 00:00 1.50 00:00 03:00 3.00 03:00 06:00 3.00 . PEPrH F.M 'QE~TH T;O 9,220 9,304 9,304 9,304 9,304 9,304 .. .,:..:.':.:,:. ....;...: . ···BHA .... . ".: .....; .'. ,. .....,. ,::. i3HA:O'IL;'~~~.~1IÈFF: IPIC~6~ IS~~~Ò~1~OÙVT. '1qRaU~~n) . 'IBHAHRSIJAFi'HFiSIMWbHR~IMTR HRS' S$HRS .... SHA DESCRIPTION Tri-Cone Bit, MACH1X/1.2AKO/8 3/8UBHS , NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP , X/O 4 1/2" H90-P X 4" HT-38P , 4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 4 1/2" IF-B , 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), X/O 41/2" IF-P X HT-38-B , 4" 14PPF S-35 HT-38DP POMP I HYDRAULIC .DATA· . STROKE (in) LiNER (in) . SPM Q (gpm) PRESS. (psi) 8.000 4.500 125 194.16 2,600 8.000 4.500 125 194.16 2,600 9,304 9,304 9,304 9,304 9,304 9,304 DEf':I~ITY(P'~g) ·,1 .11.85 I PP: I ..: FV :. ,;·.ÞV,N'F{; . GELS· . WL/HTHÞ. 46 16/32 11/17 6.2/ "I T . \rl'· )jlT (f¡Ur{ . ::.:51z.e 6 /1 8.500 ,MAt-.lUF.· .. Baker Hughes BIT I RUN 6/1 WOB 30/40 NO. 1 2 MAKE OF PUMP OILWELL OILWELL RPM 78 / 80 9,304 9,304 9,304 9,304 9,304 9,304 ; . ·,':~BITS: . . .'., _ ,:". .TYPE ..;,' . '·;SERIAC.NO..',:'···· ..iET$.QFfTfA,' MXRS18DD V48DF 20/20/20/// .., .:·:DEPTHIN þAT~:I~ ..: 9,193.0 4/10/2002 ..', .1-b.~o.-l~~~f3'::Ö~R: 0-0------ GPM 372 PRESS 2,600 HRS 6.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 100.0 16.67 8.40 127.0 15.12 PBIT 178 ·TOTAL Q 388.32 388.32 KILL SPM I PRESSlIRE 60 600 60 580 M.D. 9,196 INCL 55.30 AZI 262.60 SURVEY DATA T.V.D. N/S CUM EJW CUM SECTION M.D. 8,555.80 -1,336.1 103.54 -103.54 9,260 AZI 263.70 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE INCL. 57.10 T.V.D. N/S CUM E/W CUM SECTION . . 8,591.41 -1,342.5 50.74 -50.74 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 2 48.00 Rand K SERVICE 1 4 1 24.00 48.00 10.00 Printed: 4/13/2002 12:00:59 PM ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Circ. shakers clean. 24 HR FORECAST POOH. Run Logs. Wiper trip for liner. FIELD NAME I STATElPROV Kenai Alaska ') IViARATH.ON OIL COMPANY ..Daily Drilling Report IGL 66.00 . Page l of 2.: . : 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 119.0 9,439 8,682 26 29 4/13/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 67,127.00 1,962,601.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/10/2002 4/10/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 9.625 (in) @ 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 OP COMMENTS: Drill F/9320' to 9439'. Circulate and increase MW to 12.0ppg. POOH to 6526'. Service rig. RIH to 9439'. Circ. shakers clean. <::. .' ... ...:.. ·:,:"BHA·,· .. .. ... ,.. . I ~FF:. : I PIC~ 6~:·lS~~~ OF1RO~~. . ;. TORdUEi¡:min) . BHA HRS ·:1 JAR HRS: . MWD HRS 1 MT~· HRà I 5S· HRS ... Tri-Cone Bit, MACH1X/1.2AKO/8 3/8UBHS, NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP , X/O 4 1/2" H90-P X 4" HT-38P ,4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 41/2" IF-B ,5" HWDP (4), 61/4" hydraulic jars,S" HWDP (21), X/O 41/2" IF-P X HT-38-B, 4" 14PPF S-35 HT-38DP ·PUMP I HYDRAULIC DATA STROKE (in) l~INER (in) . . SPM Q (gpm) PRESS. (psi) 8.000 4.500 125 194.16 2,600 8.000 4.500 125 194.16 2,600 . . I ; .~. ., FROIVL ·TO· ·.HRS' : .DEPTti. FM DEPTi(TÒ.., 06:00 14:00 8.00 9,320 9,402 14:00 15:00 1.00 9,402 9,402 15:00 15:30 0.50 9,402 9,430 15:30 17:00 1.50 9,430 9,430 17:00 17:30 0.50 9,430 9,439 17:30 19:00 1.50 9,439 9,439 19:00 22:30 3.50 9,439 9,439 22:30 23:30 1.00 9,439 9,439 23:30 00:30 1.00 9,439 9,439 00:30 02:00 1.50 9,439 9,439 02:00 03:30 1.50 9,439 9,439 03:30 06:00 2.50 9,439 9,439 '··DENSIi"Ý(pp9j· :1 12.00 I~p,. ···.FV,·· ".pvjy'p·: :. G.Ë~$', ,:,wtiï-Ù·â;:¡·p,·: : ,'Fcrr;sot! 49 18/39 14/24 6.4/ 2.0/18.0 . ,. .'BITI AU,N :':".$.IZe" 6 /1 8.500 .. :···.TYPE:· MXRS18DD BIT / RUN 6/1 RPM 80/85 GPM 383 WOB 35 1 45 . . .. ,. $HA NO. . :1 L¡:NGTH. 6 1,756.21 BHA DESCRIPTION ·NO. 1 2 MAKE OF PUMP OILWELL OILWELL , . .';:..,>. '.'QPERATIÔNSSÚ.MMARy:"· . ,! \ ." " ' I. \.. '\ SUB .. ·:PHASE:··· ..:: :.··p£S·CRIPTIÖN· DRLlN2 Dir drill and survey F/9320' to 9402(ART =3.9hrs AST =1.3hrs). DRLlN2 Circ. up samples. DRLlN2 Dir drill and survey F/9402' to 9430'(ART =.2 hrs). DRLlN2 Circ. up samples. DRLlN2 Dir drill and survey F/9430' to 9439'(ART =.2hrs) DRLlN2 Circ. up samples. DRLlN2 Circ. and increase MW to 12.0ppg. Cont. circ. shakers clean. DRLlN2 POOH wet to 8956. Pump slug. DRLlN2 POOH to 6526'(tight spot @ 8500'). DRLlN2 Service rig. C/O swab and liner #1 cylinder pump#1. DRLlN2 RIH(no fill). DRLlN2 Circ. shakers clean(CBUX3)(max gas 406units). ECD I ,MOD: CAT A I:DAI~Y· COST I 6,603.00 ':. ;,OIUWAT:. ;' ··'·o/~S:~ndJMBì',:: ... .. .'. ~lì/plVl .. '·':·::pt'Mf: " 5n7 0.25/6.3 9.50/0.2 0.1/1.6 I' ~urill COST':, 261,331 .35 ·:·'.CI· ::·;::;:;";"·'cà.; .: <':'H2S..·"·'LlM~': . ES:·· 28,000 40 .~ ,. : :,.:.'; ·::BITS:o: ., . . ': :.. SE~IAL~O'. .';:. .. . ,::.:' J·ETSOfl1F:Á: . V48DF 20/20/201// :11 '. I I" (": . :, I, ':. H;>-:t>.~L~B-G~Ö~R. :::.. . . 0-0------ );>ÊPTH·I~ DÁT¢IN; . 9,193.0 4/10/2002 PRESS 2,600 PBIT 191 HRS 5.60 24Hr DIST 119.0 24Hr ROP 21.25 CUM HRS CUM DEPTH CUM ROP 14.00 246.0 17.57 TOTAL Q . 388.32 388.32 KILL SPM I PRESSURE 60 580 60 560 SURVEY DATA M.D. INCL. þ.Z1 T.V.D. NlS CUM EIW CUM SECTION M.D. INCL. AZI T.V.D. NlS CUM EIW CUM SECTION 9,323 59.50 264.20 8,624.51 -1,348.1 -2.56 2.56 9,386 61.10 264.90 8,655.51 -1,353.7 -57.12 57.12 9,345 60.50 263.60 8,635.51 -1,350.2 -21.51 21.51 9,396 60.60 264.80 8,660.38 -1,354.5 -65.81 65.81 · ..··..CO!'v'1PANY Marathon SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Inlet Drilling Alaska SERVICE NO. 18 HOURS 238.00 Printed: 4/13/2002 11 :58:56 AM WELL NAME KENAI TYONEK UNIT 32-7H . .. .' ",,,. """."....". :...>. CO.MPÄN\; . . Baker Hughes Inteq M-I Drilling Fluids ) ) . MARAtHON OIL COMPANY· pa,ge:2 dt2.·· . 1sT IKB OH 87.00 SERVICE . .. . . . . ·D.aily Drilling Rep()rt GL 124 HRS PROG TMD 66.00 119.0 9,439 . . ··P'ERSONNEL DATA· NO. HQURS·· . ..... ... COMpANY. 2 48.00 Epoch Well Services 1 24.00 Rand K ITVD I DFS 8,682 26 . . .. SERVICE·. . I REPT NO. 29 I DATE 4/13/2002 .,. " . ..,. ..,. .,. ·NO. . . .;HdU~S . 4 48.00 1 10.00 Printed: 4/13/2002 11 :58:56 AM ) ) MARATHONO··IL COMÞ·AN·Y Pag~ lofT WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS POOH logging w/Reeves. 24 HR FORECAST POOH w/logs. RIH w/Bit. POOH. Run liner. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 9.625 (in) @ ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 ·Daily ::C·rill h~"9·:Report GL 66.00 124 HAS PROG TMD TVD I DFS REPT NO. I DATE 9,439 8,682 27 30 4/14/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 46,493.00 2,009,094.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/14/2002 4/10/2002 I NEXT CASING LEAKOFF PPG 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 OP COMMENTS: Cont. Circ. POOH(SLM). Run Schlumberger. Could not pass 7680' with logs. RID Schlumberger. RlU Reeves DP conveyed logs. RIH w/DP. Girc. and deploy Reeves tools below DP. , . . .:,jjPERÄTIONS::·$UMMARY..::·: ,:, b~PTl-n:MbEPÌ"t:t10 ,SUB .·ÞH.A~·E" .. ..... .: .... , .1 DRLlN2 Cont. circ(total CBUX3). DRLlN2 POOH(SLM)(tight spot@ 7244'}. DRLlN2 RlU Schlumberger. PJSM prior to logging. RIH w/PEX. Could not pass 7680'. POOH. RID Schlumberger. DRLlN2 RlU to run Reeves DP conveyed memory logs. PJSM prior to running Reeves logs. M/U Reeves logging tool assy. Test circ. w/tools in string. RIH(drift all pipe and subs}. Wash down last 7' to 9439'. Circ. @ 3.3BPM one DP volume. Pull DP up to 9332'. Drop Reeves messenger. Pump down DP(positive indication that tool was deployed}. . . ·FRO,rJi:: ·::r;o··· :·;IofRS > 06:00, 06:30 0.50 06:30 14:00 7.50 14:00 17:30 3.50 . DESC~IPTION :, .. . , 17:30 19:30 2.00 19:30 21:00 1.50 21:00 04:00 7.00 04:00 05:00 1.00 05:00 06:00 1.00 . DRLlN2 DRLlN2 DRLlN2 DRLlN2 :,b~NSITY,(P.pg)" 12.00 I<pf)·' . .. J ECD, ¡'MUD ·DÀTAI:¡·QAIL~rcO$TI 6,603.00 I :cm~fçq~:t:j ,267,934.35 ::F=¥'> . "Pvrv.:p . : GEL$:, ,·WLMTHP: ··.fcrr.SOL; .. OIUWAT.· ·:;P(~:á~~MB:r ,\·::<gh/pM :.<.. .:Pf/Mf,: . ,CI . ..;... :':ca.:I::· ,t-i~S:::: ·I..IMÊ : ,··ES:' 48 18/38 13/20 6.7/ 2.0/18.0 5/78 0.25/6.3 9.50/0.2 0.1/1.6 30,000 40 ... , ··,BITS .,.. ., ,". ,. ... .:.....1·. : I 'T'{:)E,: ..: S.l§BI.AL:.r\lO. : ..;; . ~:~T$ OR +fA. .. :.:. :::::~E~;n{If:·.I·; D~rE:!I.N',' .:: .:;.,:::I~ò~~L~B~G~C)~R .:::: ' MXRS18DD V48DF 20/20/20/// 9,193.0 4/10/2002 1-1-WT-A-E- 1-SD-TD MXRS18DD V48DF 20/20/2011/ 9,439.0 4/14/2002 0-0------ RPM GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP ::8111 RUf".!' '! ':SíZE:¡':: : 6/1 8.500 7RR /1 8.500 BIT 1 RUN WOB BHA ~o 1\~~:.17IËF~:. PIC~: IS~~~OF1RO~ t· t~~~ ;~xIrrun)BHA H~S I JAAHRS I M~() H~~IMr(l H~ IS~'HRS BHA DESCRIPTION Mule Shoe, Landing Circ. Sub, 3 1/2" 13ppf S-135 DP (3), Lower Latch Sub, Upper Latch Sub, Float Sub, 3 1/2" 13PPF 8-135 DP , Float Sub, X/O 31/2" IF-P X HT-38 ,4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 41/2"IF-B, 5" HWDP (25), X/O 41/2" IF-P X HT-38-B , 4" 14PPF 8-35 HT-38DP .PUMP I HYD·RAULlC DATA STROKE (in) LINER (in) . . SPM Q (gpm) 8.000 4.500 125 194.16 8.000 4.500 125 194.16 NO._ 1 2 . MAKE OF PUMP PRESS. (psi) TOTAL Q 2,600 388.32 2,600 388.32 KILL SPM {PRESSURE OILWELL OILWELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Epoch Well Services 18 238.00 Rand K 2 48.00 Schlumberger 1 24.00 Reeves SERVICE NO. 4 1 4 2 HOURS 48.00 10.00 48.00 48.00 Printed: 4/15/2002 6:54:23 AM ) ). WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS POOH. 24 HR FORECAST POOH. Run CSG. FIELD NAME Kenai 124 HRS PROG TMD TVD IDFS REPT NO. I DATE 3.0 9,442 8,684 28 31 4/15/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 83,942.00 2,093,036.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/14/2002 4/10/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 9.625 (in) @ 6,526.0 (ft) 7.000 (in) @ 9,428.0 (ft) 13.66 MARA THON·,OILCOM·P ANY Daily Drilling R~port. IGL 66.00 :. : Pag~1 of 1 ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: Log on DP 9428' to 6474'. Circ. B/U @ CSG shoe. Cont.logging to 3500'. POOH UD logging tools and assy. RIH. Drill F/9439' to 9442'. CBU. POOH. .. .. ' , ·::·OP'ERATI:ONS':SÚMMARY:· . . ; .r.,.. .. . on. . ',. I'· . , ." :P:¡()M: :TÒ·:"·:· .,.ftRS:.·. . [:)E:FITI'i· FM . :DEPTH ,"0 ·:···SUB .: ,·ptiÁ~È·' ;¡" . ,: DE$CRÞT!9N· . . " 06:00 09:00 3.00 EV AL 2 Log on DP 9428' to 6474'. 09:00 10:00 1.00 EVAL 2 Circ. BU @ 6474'(max gas 150units). 10:00 12:30 2.50 EVAL 2 Cont. POOH logging to 3500'. 12:30 14:30 2.00 EV AL 2 Cont. POOH. 14:30 16:30 2.00 EV AL 2 UD logging tool and assy. 16:30 21:30 5.00 EV AL 2 RIH w/ 8.5" bit and BHA. Tag 5' fill on bottom. Wash down to 9339'. 21:30 22:00 0.50 9,439 9,442 EV AL 2 Drill F/9439' to 9442'. 22:00 01:30 3.50 9,442 9,442 EV AL 2 Circ shakers clean(CBUX4). Work bottom 15' tight spots. (max gas 250units). 01:30 03:30 2.00 9,442 9,442 EVAL 2 Pump slug and POOH to CSG shoe. 03:30 04:00 0.50 9,442 9,442 EV AL 2 Fill trip tank. Mix and pump slug. 04:00 06:00 2.00 9,442 9,442 EVAL 2 POOH. :JJENSiTY(ppg,;;· 12.15 IPfJ·: I.,ECD: IMUli,DATAIDAILYCQ~r I :':·''':'Å(::pvN~ . :::'(;EL$>.:Wln1T~'p'·· :Fprr~SOL: . "·'þiL(WA(::·· :;'·;a)~Såf1diM~t;·; ..'·:::Pb/pM': 51 17/37 13/19 7.3/ 2.0/18.0 5n7 0.25/6.3 9.00/0.2 1,952.00 : ":Pf/~f 0.1/1.6 1··.C4M 9,9$r·:1 269,886.35 'cr<'.; !;: . cå:· ::.:: 112S·· "LlM,~: ::' . ES: 30,000 40 .;:1,. .',' , '. ,. .. : ,~þ'Nl)f:;,/ Baker Hughes .. . ü:: '·1· ;': :: :"''':,'ryPE::, . MXRS18DD I::'>, ,·Brt~ ,. .:.., ..;, ;SER!ÄU~p;·:::·: ·~,ET~. pR IFA'· . V48DF 20/20/20/// "I"t i'" I, :". ". I' );';r': ;.:"' . i ;.)3ITf.~UN: , .. <·siZJ;'>: 7RR /1 8.500 '. .~:, : I: ;',,': .. \ , , DEPTH IN DATE IN I '~, ' 9,439.0 4/14/2002 " ' ¡ I. .:I~ö.~n2L~B~G~~.;R·,' 0-0------ BIT I RUN 7RR / 1 WOB 20 / 30 RPM 80/85 GPM 385 PRESS 2,650 PBIT 196 HRS 0.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 3.0 6.00 0.50 3.0 6.00 NO. 1 2 MAKE, OF PUMp . .....,:. .'.,. ·ÞIiA :.:. . '\ ,. .. EFF:. PIC~ 6': '. .. s~~ OFtFiÒ~ .:,!qÁCiUEI~j:min) .. BH¡>.HRS JARHRSIMliVÖHRS MTRHRSSS, HRS Tri-Cone Bit, MACH1X/1.2AKO/8 3/8UBHS , NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP , X/O 4 1/2" H90-P X 4" HT-38P ,4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 41/2" IF-B , 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), X/O 41/2" IF-P X HT-38-B , 4" 14PPF S-35 HT-38DP .'UMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM·· Q (gjJm) PRESS. (psi) 8.000 4.500 125 194.16 2,650 8.000 4.500 125 194.16 2,650 rOT AL Q 388.32 388.32 KILL SPMI PRES$URE . .' . . . . I B.HA:NO. : ·LENGTH .:.. 8 1,756.21 BHA DESCRIPTION OILWELL OILWELL PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HQURS Marathon 1 18.00 Epoch Well Services 4 48.00 Inlet Drilling Alaska 18 238.00 Rand K 1 10.00 Baker Hughes Inteq 2 48.00 Reeves 2 32.00 M-I Drilling Fluids 1 24.00 Printed: 4/15/2002 6:51 :36 AM ) ) ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS RIH wIT' liner on 4" DP. 24 HR FORECAST Run 7" liner and cement. POOH w/running tool. FIELD NAME 1ST ATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 9.625 (in) ~ GL 66.00 124 HRS PROG ITMD TVD DFS REPT NO. ¡DATE 9,442 8,684 29 32 4/16/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 11 ,63ØD 01.G0338.CAP.~RL3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%) 48,082.00 2,141,118.85 IACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/15/2002 4/10/2002 I NEXT CASING LEAKOFF PPG 6,526 (ft) 7.000 (in) ~ 9,428 (ft) 13.66 OP COMMENTS: POOH. LID BHA. C/O bottom rams to 7" and test door seals. RlU and run 7" liner. Circ. one CSG volume. M/U hanger assy and RIH w/T' liner on 4"DP. FRþliit' ;:ïÖ;:"HRS ..... 06:00 06:30 0.50 06:30 09:30 3.00 09:30 11:00 1.50 11 :00 13:30 2.50 13:30 15:30 2.00 15:30 01 :30 10.00 01 :30 04:30 3.00 ... .. ..... . ""0 ...", ..... . . ... .... ... .. ........ ...... .... . '" . .. .. .... .. , . .. ... .. . . ... . . ...", ......... ............. '" '"' ..... . ..... .. . . .... ..... ... b~PTii::FM(bE~THTO· ..: :S.IJB AF AF AF AF AF AF AF 04:30 06:00 1.50 AF DENSITY(ppg) FV PVNP 52 18/36 12.15 I PP I GELS WL/HTHP 13/18 7.6/ FCIT .SOL 2.0/18.0 IECDI ¡MUD DATAl DAILYCOST I OILIWAT %Sand/MBT Ph/pM 7/75 0.25/7.0 9/0.2 271,505.35 H2S LIME ES oí!r~'~~lôNs<SUMIVIÄRyL" · . /::PHAsE' DRLlN1 POOH. DRLlN1 LID 5" HWDP and 6 1/4" Jars. DRLlN1 Cont. POOH w/4" DP. LID BHA. CSGIN2 C/O lower rams to to 7". Test door seals to 250/3000psi 5min. CSGIN2 RlU to run 7" liner. CSGIN2 Run 7" liner(total 76 joints). CSGIN2 Whi'le circulate 1 CSG voulme. C/O bales and elevators. M/U hanger assy. RID Weatherford, RlU rig tongs and M/U and torque Baker plug dropping assy and layout on cat walk. CSGIN2 RIH w/T' liner on 4" DP(4600' @ 06:00hrs). 1,619.00 PflMf I CUM COST I CI Ca 0.2/1.6 29,000 40 7RR /1 8.500 Baker Hughes MXRS18DD GPM I PRESS I P BIT BIT / RUN WOB RPM V48DF 20/20/201// 9,439.0 4/14/2002 1-1-WT-A-E- 1-SD-TD HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP :. ... .........: .... ¡....::,..:.. ..........: ..:. .... ......, ...""::, :... ........ .. .iT·: :SHA" ....:.... .:........ '.:/ . ...... ....' ......:'.: ¡'<.. ···.::f. ... .:'. 8HA:O.' "IL~~~~~ 11 ~FF \Jr " 1 P'tkUP jSLAtK6Fî ~OTWf, "I ibRQOE (~k;';iñ)' 'IBHAHRSIJi\R fiRS ":IM,.vP~!\S"1 r.rt~HRsl ~s' H!1S, BHA DESCRIPTION Tri-Cone Bit, MACH1X/1.2AKO/8 3/8UBHS, NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP ,X/O 41/2" H90-P X4" HT-38P, 4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X41/2" IF-B. 5" HWDP (4), 61/4" hydraulic jars ,5" HWDP (21), X/O 41/2" IF-P X HT-38-B ,4" 14PPF S-35 HT-38DP COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVice LAST BOP TEST: SIZE (in) 20.000 13.375 9.625 4/10/2002 ID(in) LOT (ppg) 18.730 12.415 8.835 12.73 13.66 PERSONNEL DATA NO. HOURS COMPANY 1 18.00 RandK 18 238.00 Weatherford 3 72.00 Baker Oil Tools 1 24.00 BJ Services 4 48.00 . POB.@06:00: NO. HOURS 1 10.00 2 40.00 2 36.00 3 24.00 SERVICE MD (ft) 139 1,517 6,526 CASING SUMMARY LAST CASING TEST: 4/2/2002 TVD (ft) WT (Ib/ft) 139 133 1,517 ,68 6,503 40 4/17/2002 BURST (psi) 3,060 5,380 5,750 NEXT BOP TEST: GRADE K-55 L-80 L-80 Printed: 4/16/2002 9:54:30 AM ) ) MARATHON OIL·CO·MPANY ... :"Pag·e 15)f).· WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R C Lawson, Gene Anderson CURRENT STATUS Change out lower 7" rams to 4" rams. 24 HR FORECAST Clean out to top of 7" liner and PT. FIELD NAME I STATElPROV Kenai Alaska . . . . . . , . . . . . . . . . ... . . . .. . . . . ·.CaUy Drilling Report·.· . GL 66.00 ., I . I COUNTY/OTHER 1 LAST CASING Kenai Borough 7.000 (in) @ , . 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 30 33 4/17/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 84,882.00 2,223,369.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/16/2002 4/10/2002 I NEXT CASING LEAKOFF PPG 9,442.0 (ft) 4.500 (in) @ 11,637.0 (ft) ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: Finish run & cement 7" liner. .1:., 'J: ' . .... ., ··:OPERATI.ONS· SUMMÄRY, :' '. '. . , :. I'" I ::''1.~S . "I' 'I·.·.. . . .. . . I :.. ::·P~A.SE::· ,'. .."....... .'1"" .. I ..... '.F~QNi ., ·:,TÖ;:', DEPTH .FM· DEPTH.TQ . ::SUB .-.¡', . . . .:,.. '.DESCRIPTIÖt:·r :c . :! . ·06:00 08:00 2.00 9,442 9,442 CSGIN2 RIH wI 4" liner on 4" DP to 9-5/8" casing shoe @ 6526' MD. 08:00 09:00 1.00 9,442 9,442 CSGIN2 Circulate casing and DP volume @ 100 SPM & 500 psi. 09:00 12:00 3.00 9,442 9,442 CSGIN2 Finish RIH with 7" liner to 9319' MD. 12:00 12:30 0.50 9,442 9,442 CSGIN2 Wash to bottom fl 9319' to 9442' MD. 12:30 15:30 3.00 9,442 9,442 CSGIN2 Circulate and condition mud for cementing. 15:30 16:30 1.00 9,442 9,442 CSGIN2 RU cementing head. Held safety meeting. Set liner hanger wI TaL @ 6307' MD. 16:30 18:00 1.50 :9,442 9,442 CSGIN2 Circulate and condition mud for cementing. 18:00 20:00 2.00 9,442 9,442 CSGIN2 Hold safety meeting. Cement 7" liner as follows.: pump 5 bbls water ahead, 30 bbls 13 ppg spacer, mix & pump 291 bbls (1300 sx) class 'G' cement + 2% KCI + 9% BA-10A + 2% FL-63 + 0.6% CD-32 + 0.15% SMS + 0.25% R-3 + 1 gal/100sx FP-6L mixed @ 15.7 ppg, 1.19 cf/sk. Release dart, displace wI 182 bbls of 12.1 ppg mud. Bump plug with 2800 psi, 500 psi over late PP. CIP @ 20:00 hours, 4/16/02. 20:00 21:00 1.00 9,442 9,442 CSGIN2 Bleed pressure. Pull 10 stands. 21:00 00:00 3.00 9,442 9,442 CSGIN2 Circulate hole. Recovered spacer and +1-20 bbls cement. 00:00 04:00 4.00 9,442 9,442 CSGIN2 POOH. LD liner hanger setting tool. 04:00 06:00 2.00 9,442 9,442 DRLPRO Flush pumps, top drive,mud Iines,BOP stack and flow line with fresh water, blow down same. Check swabs in #1 pump, clean suction screens, clean mud pits, trip tank. Change out lower rams to 4" while WOC. ': ,ÐENsrry(ppg) ::1,. 12.20 ··~p'l , ¡Ecn 112.5IMuD:DAtA:I)~U.:ÿ,qOSTI . : :fV<· ': PYIYP ',·GELS, '.'.WUHTHP; . ;FCIT~S)OL· .: .. QI!..IWAT:: . :'Ÿ9s'an~~år:,·..<pti/~!V'" 45 24/17 10/14 7.2/ 2.0/19.0 5n7 0.2Sn.0 9.001 2,472.00 . Pf/Mf· 11.5 I :CqM;·ÇO,ST': 273,977.35 , . ··CI Cà.:· ..: Ii~S. .. Urv'l~' ;,;. gs/ 26,800 80 . . . . ·'COMPANY:: Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVICE . .··PERSONNELDAT'A NO..· ..HOURS COMPANY 2 40.00 Rand K 18 238.00 Weatherford 3 72.00 Baker Oil Tools 1 24.00 BJ Services 4 48.00 ,. . SERVICE . ... . ~ . NO.· . HdüRS· . 1 10.00 2 40.00 2 36.00 6 72.00 Printed: 4/17/2002 7:48:02 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Repair #1 pump. 24 HR FORECAST Finish drilling cement, test liner lap. FIELD NAME I STATE/PROV Kenai Alaska ) ) ., , . .. u· MARATHON OIL:COMPÄNY :. Page.·l:of 1 .. . ',. . . . .. . .' . . ... . .. .. . .. . . ; ·PaHY . Dr.illing Fleport . GL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 31 34 4/18/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 30,665.00 2,254,034.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/17/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ OP COMMENTS: PU clean out BHA & TIH. Drill cement fl 5665' to 5898'. Rpr. #1 pump. . .'.:.' .,.. .,. .,·OPERAT~·ON·S:'SUMMARY::· .:......,,.....::;:,.::>/::. ,...; : t=l3pnil . : ·l(l ' .: .H,R$:: .DEfrfHFM,: DEPTHfÓ' :.. Sl)B: : ¡ ;:,P.HA$~ . :/: '::-;, ::\ .. .'. ',::. .; DEiSCRIPTION I' : " . . !,. 06:00 10:00 4.00 9,442 9,442 DRLPRO Continue clean pits, pair dwks adjustment cylinder, adjust brakes, grease choke manifold & stack valves. Inspect dwks clutch & brake linkage. Inspect derrick and repair derrick finger. Repair DSDH heater. DRLPRO Test annular, upper pipe rams, upper & lower kelly cocks, floor valve, check valve, inside & outside kill valves, HCR & inside choke valves, choke manifold valves 1-12, lower pipe rams, blind rams & dart valve to 250.psi low/3000 psi high. Function test Koomey unit, check N2 bladders. DRLPRO Service Rig DRLPRO Caliper & PU 8-1/2" clean out BHA. DRLPRO TIH with 4" DP to 5665' MD. DRLPRO Tag hard cement @ 5665' MD. Drill cement f/5665' to 5898' MD. DRLPRO Circulate contaminated mud. DRLPRO Repair #1 pump hydraulic drive. 10:00 14:30 4.50 9,442 14:30 15:00 16:30 20:00 01:30 03:30 15:00 16:30 20:00 01:30 03:30 06:00 9,442 9,442 9,442 9,442 9,442 9,442 0.50 1.50 3.50 5.50 2.00 2.50 9,442 9,442 9,442 9,442 9,442 9,442 9,442 ·PEN$ITY(PP9)' 11.50 I , PP: I I EeD I I MuO: DA TAl-DAILY. ~oST·1 :..., t=y.',:. ,·ÞYr{Þ,: ·::.G.EÜ( I wÒt11JiÞ: 'j:¢rr.SOL·.; ;:/ :OIlJY./ Á"·:: . ·:(:~~.SàndJrJ¡Bt·· 1··~h'/pM:, ':: 49 7/16 5/8 30.0/ 3.0115.0 4/81 0.25/7.0 10.90/5.8 989.00 I CUM,COST.! 274,966.35 . PfiMt .:·:::\:.C(·:,:·:· .:;':':<::a',,; :·'·H2S:,: ·tlM,S~ :ËS.( 1.0/3.3 22,000 440 :¡. ¡: [".,j.:: ,':." , . ·.:.1 :. :,r;. .. ërtiß~N' > SIZE 8RR 11 8.500 :41 . .,:;, MANÙp'~ :·1:,:· Hughes BIT I RUN 8RR I 1 WOB 5/10 :::,.yPE'·; MG1 RPM 30 I 40 I,':, S'E;~I~L~~.:-:a~T~·'~:E-r~p~'r¡::A';.O:: I: ... D~'~iHiIN:DÄt.e;,NC'· T49BW 24/24/24111 5,665.0 4/17/2002 ... I::· .,,' .j,'. I:' " I· , II· .~. ·1~Q~~L~~~G~QlR .., 0-0------, .. :,.'. GPM 259 PRESS 700 HRS 5.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 233.0 42.36 5.50 233.0 42.36 PBIT 40 . . . . . ..~ ..,' , ...,. aHA· . BHA ~boILi'~~~ 00' eFF ¡.¡f,o PICK UP 0\ sLÀ~~QF1~ÓT~0 0 TóâaUE(';"xlminj I SHAHRS IjAR ~éls BHA DESCRIPTION Tri-Cone Bit, Float Sub, Casing Scraper, Drill Collar (2), Cross Over NQ MAKEO~PUMP 1 OILWELL 2 OILWELL . .., ' . ... ... MWD HRSMTéloHRS ISS:,HÀS ' PUMP tHYDRAULlCDATA· STROKE (h'l) . LINER (in) 'SPM Q (gpm) PRESS. (psi) TOTAL a· KILL SP~ I PRESSURE. 8.000 4.500 80 129.55 700 259.10 8.000 4.500 80 129.55 700 259.10 PERSONNEL DATA COMPANY SERVICE NO. t:l0URS CQMPANY SERVICE NO. HOURS Marathon 1 24.00 Weaver Bros 1 6.50 Inlet Drilling Alaska 18 238.00 S&R 1 1.00 Baker Hughes Inteq 3 72.00 Frac Tank Delivery 2 4.00 M-I Drilling Fluids 1 24.00 Vacuum Trucks 2 12.00 Epoch Well Services 4 48.00 Printed: 4/18/2002 7:19:06 AM ... WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Repair #1 pump. 24 HR FORECAST Clean ouVtest 7" liner. Mix new mud. FIELD NAME I STATElPROV Kenai Alaska ') ) . I ... . . . ." . . '·MARA TH:QN. :O·IL;·C·O·MPANY· .. Cåily .DI"iHing R~port·.: . . IGL 66.00 . . Pag~ 1 of 1.' . , ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 32 35 4/19/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 79,789.00 2,333,823.85 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/17/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ OP COMMENTS: Drill cement f/ 5898' to 6285' MD. Wash to TOL @ 6307' MD. Test casing to 16.3 ppg EMW. POOH. TIH w/ 7"liner clean out BHA. Continue #1 pump repair. · .. .;..::. ..!':'..t' .. . . : .. . :;10:/· :::,~;~s . .. ."'. ·.FROM·; ·u, DEPTH ~r;.,. .DEPTHTO 06:00 14:00 8.00 9,442 9,442 14:00 14:30 0.50 9,442 9,442 14:30 15:30 1.00 9,442 9,442 15:30 16:30 1.00 9,442 9,442 16:30 20:30 4.00 9,442 9,442 20:30 22:30 2.00 9,442 9,442 22:30 02:30 4.00 9,442 9,442 02:30 06:00 3.50 9,442 9,442 .>...·rOp·eRATIONS'SUMMARy·· .¡. .. , ..... : ::.: ·$~'B:· '.:PH.~S.E·.... ,. .':.'. ... ' '... . .< .... ::PES(:RpriqN:: '.., ... CSGIN2 Continue drilling cement f/ 5898' to 6285' MD. Drilled out of cement. CSGIN2 W/R f/ 6285' to top of 7" liner @ 6307' MD. No cement on TOL. CSGIN2 Circulate hole clean. MW in/out 9.3 ppg. CSGIN2 Prepare to test casing. Close pipe rams & pressure test casing to 16.3 ppg EMW w/ 2300 psi & 9.3 ppg MW for 30 minutes OK. CSGIN2 Calibrate Baker depth track. POOH. CSGIN2 LD 6-1/2" DC's, 9-5/8" scraper & 8-1/2" bit. Caliper tools, PU 6-1/8" bit & 7" scraper. PU 25 jts 3-1/2" HWDP. CSGIN2 TIH w/7" liner clean out BHA. Tag fill at 6301' MD. PU to 6232' MD. CSGIN2 Continue #1 pump repair, Denison pump. Clean & flush system. Service carrier, top drive, blocks & crown. Clean top drive, pump room. Change oil in #1 carrier, clean pill pit. .; b.~NSir\f.(ppg)..1 9.25 I, p~.1 . . I¡:Ç.9·1.. I MUD: ·DA'TAl! þAI~Y\Gqs:r::'1 · .FY;'. pVlYp·.,; ·.ßI;:LŠ;,. WUHTH~.. 'fÇrt~SdL:I:: qUJWAT' :;:; :; . :a!~SanCiJMB:r,:' :::.., Ph/pM:.: 59 21/34 3/4 30.0/ 3.0n.0 3/90 0.50/5.0 11.00/5.6 5,397.00 . .1··.?·,8M...·ç9S...rJ... 2,80,363.35 ~/~f':.:·::.· ·CI:,: ¡ '; 'I, . :;.ç~ '.;' '·';.H2S;·.' : UiVI.E'."~$· 1.1/3.2 11,000 400 .. ŠrriB.ÚN ¡:: :.sIZe¡ 8RR /1 8.500 9 /1 6.125 :: ... ::::\::;::.:.. ~~~¿~:>\~:,::.< ¡ .:..::':"·:·:::.:TYpe· :,:<:..'i:;:/': :;S~~·IA~.~O} :~~.T~'·:~iEtS;Ö~'TPA . , :. ::·DI:PTH;ï~:·i6~ TE(IN .. ,.. ;~Ó~Q~L-~~~~¿~R.:'::" Hughes MG1 T49BW 24/24/24/// 5,665.0 4/17/2002 0-0------ Hughes ATJ4 M67JD 24/24/24/// 6,307.0 4/18/2002 0-0------ WOB RPM GPM PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP .j. ',:' ',Itl BIT / RUN . " " . · . .. aHA1~o. ·.1 L:;;~~~ BHA DESCRIPTION ,.::':' r·l. . ,.','~ , ", .,"SHA.- ", :1 EFF wt . .PICK Up.: . ·SLACkOFFROTIWr: ·.\tORQUE'(7'Xlmfn) rBHAH~S :.JAR·rtRS: Tri-Cone Bit, 7" scraper, Bit Sub, Float Sub, Heavy Weight Drill Pipe (25), Cross Over 1 ¡¡¡We HRS¡MTRHÄ$.. SSHRS COMPANY· . Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids SERVICE . ···.PERSONNELDATA· NO.: HOURS:. . COMPANY 1 24.00 Epoch Well Services 18 238.00 Vacuum Trucks 3 72.00 Baker Oil Tools 1 24.00 NO. 4 3 1 . . HOURS 48.00 24.00 2.00 . SERVICE· Printed: 4/20/2002 6:02:34 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Circluate hole while mixing new mud system. 24 HR FORECAST Mix & displace hole wI new mud. Trip for new BHA. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ST OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 REPT NO. 36 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 41,570.00 2,375,393.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST YES 4/19/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) OP COMMENTS: Clean out 7" liner to beneath float shoe. Circulate hole while mix new mud. FROM 06:00 07:00 09:30 10:00 10:30 15:30 16:30 TO 07:00 09:30 10:00 10:30 15:30 16:30 18:30 18:30 19:00 0.50 19:00 00:00 5.00 00:00 02:30 2.50 02:30 03:30 1.00 03:30 06:00 2.50 DENSITY(ppg) FV PVNP 47 22/28 HRS 1.00 2.50 0.50 0.50 5.00 1.00 2.00 DEPTH FM 9,442 9,442 9,442 9,442 9,442 9,442 9,442 DEPTH TO 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 Fcrr.SOL 3.0/8.0 SUB OPERATIONS SUMMARY ."" "'" " PHASE CSGIN2 CSGIN2 CSGIN2 CSGIN2 CSGIN2 CSGIN2 CSGIN2 DESCRIPTION 9,442 9,442 9,442 9,442 9,442 9.50 I PP I GELS WUHTHP 10/14 30.01 CSGIN2 CSGIN2 Test run mud pumps. Wash 6' of soft fill on TaL & 10' of fill inside TOL. TIH to 9111' MD. WIR fl 9111' to 9131' MD. Circulate hole due to excess cement cuttings over shaker. Clean up hole. WIR fl 9131' to float collar @ 9350' MD. Circulate hole prior to casing test. Prepare to test casing. Close pipe rams & pressure test casing to 16.3 ppg EMW wI 2200 psi & 9.6 ppg MW for 15 minutes OK. (Note: Bled 60 psi of pressure from 13-3/8" x 9-518" annulus in 30 minutes. Install gauge to monitor pressure.) Readjust compensator on #1 Denison pump. Float collar, landing collar & float shoe & cement fl 9350' to 9435' MD. DP strap indicates all float equipment 7' higher than expected. Circulate hole while mixing new mud system. BGG 1500 units. Flow check well. Well flowing slightly. Shut in & monitor pressure. No pressure build up. Circulate well through choke & poor-boy degasser at reduced rate. BGG at report time 800 units. CSGIN2 CSGIN2 CSGIN2 IECDI IMUD DATAl DAILY COST I OILlWAT %SandlMBT Ph/pM 4/88 0.50/6.0 10.90/4.8 I CUM COST I 282,792.35 CI Ca· H2S LIME 15,000 460 2,429.00 Pf/Mf 1.7/3.3 ES 9/1 BIT I RUN 9 I 1 6.125 Hughes WOB 5 115 RPM 50 I 65 ATJ4 GPM 355 M67JD 24/24/24/// 6,307.0 4/18/2002 0-0------ PRESS 1,770 HRS 5.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 85.0 17.00 5.00 85.0 17.00 PBIT 63 BHA BHA NO. LENGTH I EFF WT.· I PICK UP I SLACK OF~ROT WT. I TORQUE (maximin) BHA HRS I JAR HRS I MWD HRS I MTR HRS SS HRS 10 770.79 0 150 115 I 125 6,000 I 500 BHA DESCRIPTION Tri-Cone Bit, 7" scraper, Bit Sub, Float Sub, Heavy Weight Drill Pipe (25), Cross Over NO.· 1 2 OILWELL OILWELL A VG. CONN: MAX. CONN: PUMPIHYDRAUI..ICDA TA STRQKE(in) · LINER (in) SPM Q(9pm) PRESS. (psi) 8.000 4.500 50 80.97 1,770 8.000 4.500 50 80.97 1,770 TOTALQ 161.94 161.94 KILLSPM t PRESSURE MUD GAS UNITS AVG. TRIP: MAX. TRIP: A VG. SKGRD: MAX. DRL: 900 1,500 260 Printed: 4/20/2002 7:30:26 AM COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 72.00 Vacuum Trucks SERVICE NO. 1 4 2 HOURS 24.00 48.00 18.00 Printed: 4/20/2002 7:30:26 AM ) ) MARATHON O,IL. COMPANY· Page 1 :of 2: . . . ,. ... ..Daily DriUingReport.. :.. IGL 66.00 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Circulate & mix mud. 24 HR FORECAST Finish displacement. Trip for directional BHA. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ TMD TVD I DFS REPT NO. I DATE 9,442 8,684 34 37 4/21/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00(%) 92.20(%) 36,310.00 2,411,703.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/19/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: Circulate hole while build new mud system. Circulate out gas bubble. FIT to 14 ppg EMW. Circulate & mix mud. Displace hole to 9.6 ppg new mud. Mix 12 ppg NaBr fluid. OPERAT.I.ÒN'S:SÜMMARY:·· ,.... . -~.. : IY, :..~~Å.~:E:: : ::: .. I . . ;.:;;' '~:.p,E$ÇR,IPTtqN: ::. ¡\: ::...::~R,$:.. '·:·$ØB: :~~OJI.II:: ·:to DEPTH .f:M : [)E:P;TH TO 06:00 13:30 7.50 9,442 9,442 13:30 16:30 3.00 9,442 9,442 16:30 20:00 3.50 9,442 9,442 20:00 20:30 0.50 9,442 9,442 20:30 01:00 4.50 9,442 9,442 01:00 05:00 4.00 9,442 9,442 05:00 06:00 1.00 9,442 9,442 \24 HRS PROG CSGIN2 Circulate hole while mix new mud system. Circulate through choke & degasser holding 400 psi back pressure. CSGIN2 Shut well in while work on electrical bulkhead to pump room. SIDPP - 780 psi, SICP - 700 psi. CSGIN2 Kill well using Drillers Method. 60 spm, 1050 psi DP pressure & 800 psi casing pressure through choke & degasser. Circulate out bubble. Well will stil flow. CSGlN2 Perform preliminary F.I.T. to 14 ppg EMW, 2050 psi w/ 9.5 ppg MW, OK. CSGIN2 Circulate hole while mixing new mud system through choke & degasser holding 400 psi back pressure. CSGIN2 Displace 9.5 ppg old mud w/ 9.6 ppg new ProFlo mud system holding 750 psi back pressure on choke. Max BGG - 800 units. CSGIN2 Shut well in w/750 psi back pressure while building 12 ppg NaBr fluid. Casing pressure ressure build up to 825 psi in 45 minutes. Prepare to circulate hole. ::D~fj$.ITX(pP9J,1 9.65,..I··PP. eCQj10.2MUD.:I:>ATÄlt.cAI.tvþOST: 986.00 I·Cµ~.bost·1 283,778.35 :;:::,:ï=V:i> >·PVN~,·(¡EI,.~ '::;vi~THP: i.FCIT;S;9~·.· ::.ol0v~r;F·:'¡:::y!>S:ål1dJ~"~i:· ,'··::,':F~h'jpM:'·\" .. :.Pf'M~<:·;· :;. I . ·ql .:',.:'.:",>¢~<.:. H2S'.·· ·tIME ':·ES;:' 46 10/25 11/14 8.0/ 2.0/9.0 /91 / 10.00/1.0 1.7/3.3 132,000 . . .'. ." ..1",· . ,"; .. . '~Il) ~U~~ :. ~.:: sái:·· :.. . 9 /1 6.125 BIT' RUN ' I : ,. :., ::'MÅNUF~ Hughes RPM . TYPE'·:·· ATJ4 WOB GPM .,::'.. :;.. BITS::·::.·' .... .. I·· .. .. : s~RïAL N.å..· . .. /, \J.ETS ql:r:rFA':,: '.. . DEPjH IN. QA TEIN:, '.::I~o~o.;L.~~~G~6~R· ...: M67JD 24/24/24/// 6,307.0 4/18/2002 O-O-__m PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP . .... :..' .:::.::.'. : :.. . ' .. , , ... . . . ··:aHA· .:.:. .. ': . BHÄ1~O'1 LE;~~'EFFWT PICK UP 'I SLACKOF1 ROTWr:1 TOF¡QUE <';'"x/m1n) 1 BHA HRS 1 JAR HRS 1 MWDH~S MTR HRS 1 SS HRS BHA DESCRIPTION Tri-Cone Bit, 7" scraper, Bit Sub, Float Sub, Heavy Weight Drill Pipe (25), Cross Over ·;·NO. . 1 2 MAKE OF·PUMP OILWELL OILWELL A VG. CONN: MAX. CONN: COMPANY Marathon SERVICE PUMP {HYDRAULIC DATA STROKE (in) . LINER (in). SPM Q (gpm) . 8.000 4.500 50 80.97 8.000 4.500 50 80.97 PRESS. (psi) TOTALq 1,435 161.94 1,435 161.94 KILL SPM ,. PRESSURE MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: 700 1,000 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Inlet Drilling Alaska 18 238.00 Printed: 4/22/2002 6:41 :04 AM WELL NAME KENAI TYONEK UNIT 32-7H COMp,ANY· Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services ) ) . MARATHON OIL. COMPANY· . .Pag·e 2··o(~ 1sT /KB OH 87.00 . SERVJCE· . . .' .. . DaUy·D.r¡ning..·R~port :: ' I GL /24 HRS PROG I TMD 66.00 9,442 IJER~ºNNEL.·DATA· : ..... . NO.. HQl,IR$ COMPANY: . 3 72.00 Vacuum Trucks 1 24.00 M-I Delivery Truck 4 48.00 ITVD IDFS 8,684 34 . .. . SERVICE I REPT NO. 37 ¡DATE 4/21/2002 .. .. . . ... . N,Ô: .. ::~6Ü.RS ::. 3 36.00 1 2.00 Printed: 4/22/2002 6:41 :04 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Kill well w/12 ppg mud. 24 HR FORECAST Finish displacement. Trip for directional BHA. FIELD NAME I STATE/PROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ) ) MARATHONQIL COMPANY· pag·e J :(jf:t ·Dailv Drilling Report· IGL 66.00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 TMD TVD I DFS REPT NO. I DATE 9,442 8,684 35 38 4/22/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) . 92.20 (%) 166,642.00 2,578,345.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/19/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 124 HRS PROG OP COMMENTS: Increase MW to 10 ppg. Displace hole to 10 ppg. Well still flowing. Increase MW to 12 ppg. Pumping kill weight mud at rpt time. .." '..'. .. . ' ~' . I".. .:. ¡:::RqM:, :T,O·>: ::::':IiRS .... CEPTHFM·· DEPTH TO . . . . . 06:00 08:30 2.50 9,442 9,442 08:30 15:00 6.50 9,442 9,442 15:00 18:30 3.50 9,442 9,442 18:30 19:00 0.50 9,442 9,442 19:00 22:30 3.50 9,442 9,442 22:30 00:00 1.50 9,442 9,442 00:00 03:30 3.50 9,442 9,442 03:30 06:00 2.50 9,442 9,442 .·'(j:PE.RATIO,NS·SUMMARY··' :'1. '.'... . ,. SUB· , :::.p¡HAsE,u .> ;,1· .., ·,;u :.: . ..,DESC~iPtiO.N: CSGIN2 Circulate hole while mix new mud system. Max BGG 935 units. CSGIN2 Well shut in while mix new 10 ppg mud. SIDPP 950 psi, SICP 1000 psi. CSGIN2 Kill well using Wait & Weight Method. Displace hole fl 9.6 ppg to 10 ppg kill mud. CSGIN2 Flow check well. Well still flowing. CSGIN2 Well shut in while increasing MW to 11.0 ppg. SIDDP 650 psi, SICP 695 psi. Increase MW to 12 ppg. CSGIN2 Pump 200 bbls 40 vis spacer to make room to build 12.0 ppg mud volume. CSGIN2 Well shut in while increasing MW to 12.0 ppg. SIDPP 640 psi, SICP 680 psi. CSGIN2 Kill well using Wait & Weight method. Displace hole from 10 ppg to 12 ppg kill mud. COMMENTS Daily cost includes $123,702 mud cost for changeover. :;.·:bE~~I1~Y(P'~g):[ . 10.05 , I' PP I "',.'" J·~CD'11~~~ I:,M. t)p:,DArAJ:·~(IL~:Ço~!:l, ,123~7?2.00 .CIJ:.·r;.":U.;··~"..'C.·.:c::ba:'S.,..T...;':J..H.. 2S~0..7.: ::4"I.M~.OE' .:,3, "".5...'...E' $:.. ;. i=v:. '.,. PVtYP: '. GELS WLtHTHP FCn;.SQL ", ;OIlJw~ T '.,' .,.., :%SäncJ1M~T,,: .:, ..;. ~h!~M ,..,. . ..::.. ~IMf·. ,: .', ... . L.; 42 9/25 10/12 6.8/ 1.0/10.0 3/88 / 10.10/0.6 0.5/1.4 126,000 20 "; .c.\ I," :BTl~UN' :«SIZE:.: 9 /1 6.125 , MANÚF~: ;.. Hughes . ,: BIT I RUN WOB RPM . , . . . ·>:SJTS" ¡ '.;.::. :,.TYPE:· ., ·',:,:,SERIAL:, NO.:··: .. :'·":JE.TS Ç>R·TFA· DEPTHjN:·.DATE':IN:'· .' :r~o~.(j~(..a~~.å~R, AT J4 M67 JD 24/24/24//1 6,307.0 4/18/2002 0-0------ GPM PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BfiA1 ~o~ I L~6:7~ 'Iwivr.. I PICK UP ,"1 SLACK~tOTWr'IT~~~{7'ml~) IBHA HFlS "1 JARHFlSIMWO ~FlS 1 MTFlHRS "1 SS:HFlS ' BHA DESCRIPTION Tri-Cone Bit, 7" scraper, Bit Sub I Float Sub Heavy Weight Drill Pipe (25), Cross Over NO.: . . . MAKE OF PUMP 1 OILWELL A VG. CONN: MAX. CONN: " PUMP I HYDRAULIC DATA' . . STROKE (in) ,LINER SPM Q . PRESS. 8.000 TOTALQ 0.00 KILL SPM I PRESSURE 40 410 MUD GAS AVG. TRIP: MAX. TRIP: 'I UNITS A VG. BKGRD: MAX. DRL: 438 935 PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Marathon 1 24.00 Epoch Well Services 4 48.00 Inlet Drilling Alaska 18 238.00 Vacuum Trucks 2 24.00 Baker Hughes Inteq 3 72.00 M-I Delivery Truck 1 2.00 M-I Drilling Fluids 1 24.00 Printed: 4/22/2002 6:38:18 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS TIH w/ directional BHA. 24 HR FORECAST Drill out & perform LOT, Drill ahead building curve. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: Kill well. Check btm @ 9439'. Condition mud. POOH. Change BHA. TIH. ., ..... ::"::·ÖP'ERA110NS·S'UfJUVI.ÄRY·;: ::. . . . . ,'" :", .. Â: .. ." . , '~ ".: .'"'' . " , , . . . " . ": ... . p . : " ":., .... . ';:$o.B.:. ... ·PHAS.E: .,.' . :":J:)ESÇRIPTIOI'\f CSGIN2 Kill well using Wait & Weight method. Displace hole to 12 ppg mud. CSGIN2 MW in/out 12.0 ppg. BGG 10 units. Flow check well. NO FLOW. Circulate & wash to bottom below float shoe to 9439' MD. Pull one stand. CSGIN2 Slip and Cut Drill Line CSGIN2 Circulate & add viscosifier to suspend barite prior to TOOH. 1 unit BGG. CSGIN2 Stop circulation & mix viscosifier in surface pits. Well dead. CSGIN2 Circulate & add viscosifier prior to TOOH. 0 units BGG. CSGIN2 Slug pipe & POOH to change BHA. SLM out of hole. No correction. CSGIN2 LD bit & 7" scraper. MU directional BHA. CSGIN2 TIH w/ new BHA. .. :. ,.. .,.' I.'. 'I''''',' ", ...,,:": FI:r.O~,. . TO:· . ..::I-~!:1:...' ,PE.,TH FM. DEPTHt9 06:00 12:00 6.00 9,442 9,442 12:00 12:30 0.50 9,442 9,442 12:30 13:30 1.00 13:30 14:00 0.50 14:00 16:00 2.00 16:00 19:00 3.00 19:00 02:00 7.00 02:00 04:00 2.00 04:00 06:00 2.00 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 9,442 ) } . . . ···MARATHONOIL COMPANY Page 1 of.1 . . . . , . . . paUy Drilling ~E!·port· GL 66.00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 36 39 4/23/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 71,749.00 2,650,094.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/19/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 : ::: c :iDEN~lty(P.P9) :·1 12.05 l>p·p·:I.. ..... liE¢·p) 13.0 IMU[).bATAlþ~.'LYco~:t:·1 ,·Fv:i: ::fjvIYP:. :G'el..,S',.. WLlHTtt:) ~bi,T.soL>· oiUWAr 1 ···O¡oSs¡'dïMBt;··· '."·!",Ph/þ"¡L.. 56 14/41 19/24 6.8/ 1.0/17.0 3/80 / 9.50/0.4 18,234.00 I '¢IJ~.Ü::PST ~I 425,714.35 .J~1/Mr·::· CI: :::..:.<::":..'q~('. ;. ·:.H2S'·: ::LIME: ;es' 0.3/1.3 124,000 40 ;:ISp"(RUN ... ,;SI~·E>:.:·· 9/1 6.125 10 /1 6.125 I":' ':1;':. 1'~C?~~~.7~~G-9~,R ,. 2-3-NO-A-E-O-N O-BHA 0-0------ BIT I RUN 9/1 WOB /2 RPM 10 / 20 .¡:··BITS·:: ~:'.,:,:. .< J SERIALNO.·;: . '. :JETS!oFi;'TFA.'· ....:. M67 JD 24/24/24/11 5010956 15/15/15/11 .: :"'::;"'.';':",'1 .l·. ;:¡ .. . :DE~T~·,~. :'DATEIN ,'. 6,307.0 4/18/2002 9,439.0 4/23/2002 GPM 355 CUM HRS CUM DEPTH CUM ROP 5.00 89.0 17.80 PRESS 700 24Hr DIST 4.0 24Hr ROP 17.00 PBIT 80 HRS .,..::. .... .. . .'...:. ¡. ./.:... .. ..... . .... :<.,::.: '<.:..'.:....:. . .: ······aHA.·;·: ::. . : ... .... ßi:IÎ;·1~6. l1~~~~~/rEFI<Wr'1 PIC~LJP ISLACKOF1ROT '/iT; ITORaUE(j"",,,.¡n>· SH:o.HRS JAR HRS MW{)HR$ MTR,HRS 155'HRS; BHA DESCRIPTION STXR20 Tricone Bit, M1 X Motor w/ 2.5 AKa, MWD Tool, Hang-Off Sub, NM DP (2), Cross Over, Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. MAKE OF PUMP 1 OILWELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids SERVICE PUMP rHYDRAULlCDATA STROKE (in) . LINER (in). SPM Q (gpm)· PRESS..(psi) TOTAL Q ::KILL SPM I PRESSURE 8.000 4.500 100 161.93 700 161.93 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch Well Services 18 238.00 Vacuum Trucks 3 72.00 M- Delivery Truck 1 24.00 SERVICE. NO. HOURS 4 48.00 1 4.00 3 6.00 Printed: 4/23/2002 7:16:10 AM ) ) MARATHON OIL COMPANY .page r·of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Repair mud pump. Monitor well. 24 HR FORECAST TOOH. Test BOPE. TIH w/ directional BHA. Finish repairs. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 ·Daily Drilling Report IGL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 37 40 4/24/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 40,258.00 2,690,352.85 ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/19/2002 4/17/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 OP COMMENTS: FTIH. Tag btm @ 9439' MD. Circulate B/U. Pump repair. FROM TO HRS DEPTH FM· DEPTH TO . . SUB 06:00 08:00 2.00 9,442 9,442 08:00 11 :00 3.00 9,442 9,442 11:00 06:00 19.00 9,442 9,442 qPER~ TIPN·$ SlJMMARY . PHASE. CSGIN2 CSGIN2 CSGIN2 DESCRIPTION;:· . TIH w/ directional BHA. Tag bottom at 9439' MD. Circulate bottoms up. TG 12 units. #1 pump down. Wait on new Denison pump. Complete removal of Denison pump, flush all lines, drain & fiter hydraulic fluid, change filters. Repair hydraulic line supports. Inspect hoses, clamps, etc. Investigate failure. Fill mud pump hydraulic tank. Purge #2 pump hydraulic system. Change pump liners to 4". COMMENTS Tag TOL @ 6305' MD. Shoe @ 9435' MD. AOGCC & BLM notified of BOP test. .·OEt;JSITY(ppg) FV" 'ÞVNP 54 13/39 12.00 I ppl GELS WUHTHP 17/21 5.6/ I ECD 12.9:MUD ;CATAI:'DAILYCOST' FCIT.SOL ·OIL/WAT %SandlMBT Ph/pM. 1.0/17.0 3/80 9.50/0.4 5,933.00 Pf/Mf 0.3/1.3 I CUMC.0ST I 431,647.35 CI.· . Ca· 'H2S· LIME· ·E~: 124,000 40 BIT / RUN 10/1 . SIZE' 6.125 MANUF. Hughes . BITS TYPE 'SERIA~NO.' JETS OR TFA· OEP;rH IN·: DATE IN· H)~o.:L~6~G-d-R STXR20DX2 5010956 15/15/15/// 9,439.0 4/23/2002 0-0--00-- GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BIT / RUN WOB RPM BHA ~o. , I LENGTH 11 1,784.31 BHA DESCRIPTION ',SHA jEFF·.wr. ./ PICK UP I SLACK OF1ROTWT. <ITORQUE(~axlmin) BHA HRS ¡JÁR HRS /MWD HRS I MTRHRS S·äHRS.: STXR20 Tricone Bit, M1 X Motor w/2.5 AKO , MWD Tool, Hang-Off Sub, NM DP (2), Cross Over, Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. . MAKE OF PUMP 2 OILWELL PUMPl HYDRAULIC DATA STROKE (in) LlNER(in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 4.500 120 194.32 2,400 194.32 KILL SPM / PRESSURE COMPANY· Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Vacuum Trucks 18 238.00 R&K Industrial 3 72.00 Veco Alaska 1 24.00 InsurancelWorkmans Co 4 48.00 Alaska Pipe & Supply SERVICE NO. HOURS 1 4.00 3 6.00 1 2.00 2 6.00 1 1.00 Printed: 4/24/2002 7: 11 :07 AM ) ). . MARATHON OIL COMPANY '. Page 1 of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Circulate hole. Rig repair. 24 HR FORECAST Rig repair. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling 'Report IGL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 38 41 4/25/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 44,200.00 2,734,552.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/24/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: POOH. Test BOPE. TIH. Rig repair. ÖP'EAATIONS SUMMAAV .., "'. FROM TO HRS DEPTH FM 'DEPTH ,Ta- SUB· . PHASE"; DESCRIPTION, 06:00 13:00 7.00 9,442 9,442 CSGIN2 Pump slug. POOH to test BOP's. Stand back directional BHA. 13:00 18:30 5.50 9,442 9,442 CSGIN2 Test BOPE. Test annular, upper pipe rams, upper & lower kelly cocks, floor valve, check valve, inside & outside kill valves, HCR & inside choke valves, choke manifold valves 1-12, lower pipe rams, blind rams & dart valve to 250 psi low/ 3000 psi high. Function test Koomey unit, check N2 bladders. 18:30 01:00 6.50 9,442 9,442 CSGIN2 TIH wI directional BHA. 01:00 06:00 5.00 9,442 9,442 CSGIN2 Circulate bottoms up. TG 0 units. COMMENTS Expect Denison pump delivery +/-08:00 hrs. 'DENSITY(ppg) :·1 12.05 I::PP. FV·:· PVIYP.' GELS WUHTHP 53 13/39 17/21 5.6/ I Ecö·13.1[MUD DATA] PAI'LV COST I FC/T~SOL' I' OIUWAT o/OSaJ;ldlMBT Ph/pM 1.0/18.0 3/79 9.5010.4 5,933.00 "Pr/Mf ' 0.3/1.3 I CUM:C?ST' 437,580.35 cl " . Ca:" t12S LI!\IIE : ' ES:' 240,000 40 BIT l RUN 10/1 SIZE 6.125 MANUF; Hughes WOB RPM :BITS TYPE': ' SERIAL,NO. JETS dR Ti=A' DEPTH IN' DATE IN I-O~:D-L-B~G-Ö-.R·: STXR20DX2 5010956 15/15/15/1/ 9,439.0 4/23/2002 0-0------ GPM I PRESS I P BIT HRS I 24Hr DIST 24Hr ROP CUM HRS I CUM DEPTH I CUM ROP BIT I RUN . '. . , ':'. ." '.' . . aHA '. . ~ , . . . ..'... .' . . . BHA1 ~o.· 1\~~~;.~1 I EFF wr. I PICKUP . I SLACK (jF1ROT, WT:. TÖRQl.JE (jaximin)' IBHA HRS I JAR HRS MWD HRS I MTR HRS I SS' HRS BHA DESCRIPTION STXR20 Tricone Bit, M1X Motor w/ 2.5 AKa, MWD Tool, Hang-Off Sub, NM DP (2), Cross Over, Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar I Heavy Weight Drill Pipe (21), Cross Over . NO. MAKE OF PUMP 2 OILWELL PUMP I HYDRAULIC DATA STROKE,(in) LINER (i'n) SPM Q (gpm) PRESS.(psi) TOTAL Q 8.000 4.000 60 75.99 1,345 75.99 KILL SPM I PRESSURE COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 BJ Services 18 238.00 Carlile 3 72.00 R&K Industrial 1 24.00 S & R Enterprises 4 48.00 Alaska Bolt & Chain SERVICE NO. 1 1 1 1 1 HOURS 1.00 1.00 1.00 1.00 1.00 Printed: 4/25/2002 6:53: 19 AM ') ) MARATHON OIL COMPANY Page. 1 of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Repair rig. 24 HR FORECAST Repair rig. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 . Daily Drilling Report IGL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 9,442 8,684 39 42 4/26/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI INRI ' DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 36,385.00 2,770,937.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/24/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,441.0 (ft) 4.500 (in) @ 11,640.0 (ft) 14.00 ST A TElPROV Alaska I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ OP COMMENTS: Repair rig. FROM. :TO' HRS' DEPTH FM· DEPTH'TO '. Sl)B 06:00 06:00 24.00 9,442 9,442 ()PI::R\TIONS·~µM\JAR,{. . : "":' "", PHASE: . 'DESCRIPTION . CSGIN2 Repair Rig. Remove existing Denison pump. Replace water valve, steam valve, paint rotary table, pick up felt & pit liners, paint new generator house. New Denison pump arrived location 16:30 hrs. Install new pump. Den ¡son engineer arrived location 23:30 hrs. Modify mud pump hydraulics per Denison engineer. '. DENSITY(ppg) ·1 12.05 I·pp IECD I MUD DATA·DAILY:ÇOST I 2,474.00 I CUM COST I 440,054.35 -::: FV·; PVIYP :.GELS WUHTHP. FCIT.SOL ' OIUWAT: %Sa.I1d1M aT I . ,: Pb/pM ' , PflMf " :. . C.I: 'Ca" H~S LIME. ES 55 14/38 17/21 5.6/ 1.0/17.0 3/80 9.50/0.4 0.3/1.3 124,000 40 '. ßIT I RUN ., SIZE'" 10/1 6.125 , MANÜF.: " Hughes BITS· ". .' I . . TYPE SERI~L NO; JETS OR TFA . DEPTH IN QAT'EIN "1-O~D-L~B:-G-b~R STXR20DX2 5010956 15/15/15/// 9,439.0 4/23/2002 0-0------ GPM I PRESS I P BIT HRS 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP ': I. BIT I RUN WOB RPM BHA1~· IL~~~;.~1IÊFF wr; I PICK UP I SLACK~;tROT""; 1~6~~~ (~min; I BHA HRSlJAR HRSI MWDHRs I MTRHRS I SS HRS BHA DESCRIPTION STXR20 Tricone Bit, M1 X Motor w/ 2.5 AKO , MWD Tool, Hang-Off Sub, NM DP (2), Cross Over, Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over : COMPANY. Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services Fastenal Delivery SERVICE . PERSONNEL DATA . NO., HOUR~ 'COMPANY 2 28.00 Lynden Transport 18 238.00 S&R Enterprises 3 72.00 Vetco Wellhead 1 24.00 Weaver Brothers 4 48.00 Denison Engineer 2 1.00 S~RVICE NO. 2 1 1 2 1 Hc::>URS 3.00 1.00 1.00 3.00 6.50 Printed: 4/26/2002 7:21:03 A.M ) ) . ...... . .. ",.... .. . .. ... ... .... ... .. ... ..... . ... '" .. ... .... . . ........",.. .... o ... ... . . ... ... . . ... . .. . . . . .. . . . .. . . "' ..... ... . . . .. .. .., ..... ... '" . .. ,". ... ... . .. . ""' o . . ..... ..... ... ... . . . . . . .. .. . . .... ·'·rv1ARATHONQILCQMPÄNY.·,,· ....... .. .. .... .." ",. ,".. . ....", ......""0 ....0"" .... .... .... .. . ..... ..... . .." ........ ..... .......... .... ......... . .. . ... ",. ..... .., ... ... . ..... .... "....... ..... . .. ....... .. ..... . . ..... ... .. . . . . .,... .. ... ... . . ... ... . . . . . .. ....... . ... . ..... . . ... ... '"' . .. ",.. .... ...... . '" ,". .. . .. . ..',.',. LP~Hy:Órih.[~9.;ffl~·P9tf:.·'.· ,..'. ... ST IKB IGL \24 HRS PROG TMD OH 87.00 66.00 9,442 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11,63ú)D,01.G0338.CAP.r!>RL3,284,OOO' I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 33,157.00 2,804,094.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/24/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,441(ft) 4.500 (in) @ 11,640 (ft) 14.00 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Repair rig. 24 HR FORECAST Repair rig. Drill 20'. Perform LOT. Drill curve. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: Repair rig. Cirulate to test pumps. Repair rig. OPERATIONS SUMMARY . '" .",,, ''''''. PHASE FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 13:30 7.50 9,442 9,442 TA 13:30 14:30 1.00 9,442 9,442 TA 14:30 06:00 15.50 9,442 9,442 TA DENSITY(ppg) FV PVIYP 57 14/41 12.00 I PP I GELS WUHTHP 19/24 5.8/ BIT I RUN. II SIZE 10/1 6.125 MANU F. Hughes WOB RPM BIT I RUN CSGIN2 CSGIN2 CSGIN2 DESCRIPTION Repair Rig. Modify mud pump hydraulic system per Denison engineer. Circulate to test pumps & hydraulic system. Repair Rig. Drain hydraulic oil tank. Modify hydraulic tank. Refill wI oil. IECDI13.1MUD DATAl DAILY COST I FCIT.SOL OIUWAT %Sand/MBT Ph/pM 1.0/17.0 3/80 9.50/0.4 I CUM COST I 442,528.35 CI Ca H2S LIME 240,000 40 ES 2,474.00 , pf/Mf 0.3/1.3 BITS TYPE SERIAL NO. JETS ORTFA DEPTH IN DATE IN I~O-D-L-B-G-O-R STXR20DX2 5010956' 15/15/15/1/ 9,439.0 4/23/2002 0-0------ GPM I PRESS I P BIT I. HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP -BHA NO. ILENGTH 11 1,784.31 BHA DESCRIPTION aHA I EFF WT. I PICK UP I SLACK OF1ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS STXR20 Tricone Bit, M1 X Motor w/ 2.5 AKa, MWD Tool, Hang-Off Sub, NM DP (2), Cross Over, Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 30.00 Epoch Well Services 19 240.00 Denison Engineer 3 72.00 Oilfield Hotshot 1 24.00 Veco Alaska POB @ 06:00: N.O. HOURS 4 48.00 1 24.00 1 2.00 1 1.00 SERVICE Printed: 4/27/2002 8:12:39 AM ' ') ) . .... ... .. .. .. ... .. .... ... ...... . . ... "' . , ' , ....... . .... .. . . ...... ....... "... .... o .... ",. .. ... . . ,.... .. ... .... ., .... . . ... . ....... .... .... . .... ... .. . ... .... .. .... ......... . .. . '"' . .... . .. ... .. ..", . .. . .. . . ... .... ". . .., . .. .. . . .. ... . . . .. .. ...... ... . ...... ... ..... . . . . . . .. ,".... . . . .. . . ... .. , ,<, .','MÄR~ÆHê)~i9IL8~MPANV ..'... '. ,'. '>< i'...·.' ~'~ ily',Þti Uii"1gRèpôrt', " ST IKB GL 24HRSPROG ITMD TVD DFS IREPTNO. I DATE OH 87.00 66.00 128.0 9,570 8,717 41 44 4/28/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 11,63(7)D,01.G0338.CAP.~Rl3,284,OOO I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 62,676.00 2,866,770.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/24/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS POOH for flow test. 24 HR FORECAST FPOOH. Run test tools on DP. Flow test well. POOH. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: Finish pump repair. Drill to 9458' MD. Perform LOT to 15.27 ppg EMW. Decrease MW to 11.3 ppg while sliding. Slide & build curve to 9570' MD. Flow check. POOH. OPERATIONS SUMMARY PHASE DESCRIPTION CSGIN2 Test run mud pumps wI new hydraulic system. Circulate B/U. DRLPRO Slide drill fl 9442' to 9458' MD. (AST- 0.48 hrs) DRLPRO Circulate B/U. DRLPRO Perform L.O.T. to 15.27 ppg EMW wI 1477 psi surface pressure & 12.0 ppg MW. DRLPRO Slide drill fl 9458' to 9491' MD. (AST - 0.50 hrs) DRLPRO Repair rig. Replace liner gasket in #1 pump. DRLPRO Re-Iog previous interval wI MWD/GR for formation tops. DRLPRO Slide drill fl 9491' to 9550' MD. (AST - 1.66 hrs) DRLPRO Circulate for samples & WT. DRLPRO Pull 2-1/2 stands to 7" liner shoe at 9435' MD. TIH. DRLPRO Slide drill fl 9550' to 9555' MD. (AST - 0.17 hrs) DRLPRO Pull 2-1/2 stands to 7" liner shoe at 9435' MD. TIH. DRLPRO Slide drill fl 9555' to 9570' MD. (AST - 0.53 hrs) DRLPRO Circulate B/U. BGG 15 units. Monitor well 1/2 hr, no flow. DRLPRO Pump slug. TOOH. CENSITY(ppg) 11.30 I PP I I ~CC 1~~.~..I~~,E,.,~~I~J",.~~',~~~.~~~,1 4,939.00 .. ",.,.I·.~U~9~~~·JH'.'.,.~47,467.35 ::;1;" i :···~wyp:; ::~El.$/ "WLlHTHP lFC/T;SQL . ... 'QILlWÂT:: '<Ö¡o'$~n~J.Ml3r:. ,:.'.f'~lpl\II¡:'i""H··'Pf¡tJif;: ""Ti'c::;r'" 'C8'" Hl,"H2Sll'Ï-:IME 51 13/44 21/26 5.31 1.0/14.0 3/80 10.6 10.5010.3 0.2/1.4 107,000 40 FROM .TO HRS DEPTH FM DEPTH TO SUB 06:00 08:30 2.50 9,442 9,442 TA 08:30 09:00 0.50 9,442 9,458 AF 09:00 10:30 1.50 9,458 9,458 AF 10:30 12:00 1.50 9,458 9,458 AF 12:00 12:30 0.50 9,458 9,491 AF 12:30 13:30 1.00 9,491 9,491 TA 13:30 19:00 5.50 9,491 9,491 AF 19:00 21:00 2.00 9,491 9,550 AF 21:00 22:00 1.00 9,550 9,550 AF 22:00 22:30 0.50 9,550 9,550 AF 22:30 23:30 1.00 9,550 9,555 AF 23:30 00:00 0.50 9,555 9,555 AF 00:00 01:00 1.00 9,555 9,570 AF 01:00 03:00 2.00 9,570 9,570 AF 03:00 06:00 3.00 9,570 9,570 AF 10/1 6.125 Hughes STXR20DX2 BIT I RUN 10 I 1 RPM GPM 284 WOB 10 I 30 ...... ..BITS ..........' .. ;'":;;; ::'::: ':. -::'. ::.:'::::::.::::' ::::.::.:! . --. .. . . "SERIÁ(iNO;, .., ¡'JETsoFi'TFÄ :; 5010956 15/15/15/// , ' " , ",.", . · ... ". .... ... ..... .......... ..... · . .......... .......... ....... ..... . . ...... . ............. .......... . ... ... ............... ....... . ... ........ ... · ... .. .. ..... . .. ... .... . . ......... ... . .. .. , DEPTH IN bATE IN 9,439.0 4/23/2002 0-0------ PRESS 2,300 HRS 5.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 131.0 26.20 5.00 131.0 26.20 PBIT 312 BHA BHA NO. I LENGTH I EFF WT. I PICK UP SLACK OF1ROT WT. I TORQUE (maximin) I BHA HRS JAR HRS I MWD HRS I MTR HRS I SS HRS 11 1,784.31 0 150 110 125 I BHA DESCRIPTION STXR20 Tricone Bit, M1 X Motor wI 2.5 AKO , MWD Tool Hang-Off Sub, NM DP (2), Cross Over Drill Pipe (28), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over OILWELL OILWELL A VG. CONN: MAX. CONN: PUMPIHYDRAULICDATA STROKE (in) LlNER(in) SPMQ (gpm) PRESS: (psi) 8.000 4.000 112 141.84 2,300 8.000 4.000 112 141.84 2,300 TOTALQ 283.68 283.68 KILLSPM I PRESSURE 60 860 60 900 MUD GAS AVG. TRIP: MAX. TRIP: UNITS A VG. BKGRD: MAX. DRL: 2 79 Printed: 4/28/2002 7:58:16 AM " .... ."'.""0··· . .... ..... .. ... .... ... . . . .. ..",..", . . .......... ..... .. . ,". . ... .... . .. ...... .",. . .. .. .... . ... .... .. . ... .. .. .. . · . . ... . . .. ..... ... .. ... .. . ..... .. . ... "' · . . . . . ... . .... .. . .. . .. ..... . . .. .. . · .. .. ..·....""0··..·..·· ... .. ....... .. ......... .... . '. ,'I\IIÅRATHQN Cnb'COfVIp:Þ¡Nv,' .. ... .. ......", .......... .. ............ ...... . .... .... .... .. .. .. ..... ... .. .... ....... .. .. ",... .... ....... . ",.. . .. ...", .. ....", ........ ... ...... .. .. ... '" .. . ....... . . .. . .... . '" ...... .... . ,.. . .. ...... .. . ,". . ... . ... . . ... .", ..... . ,".. ..... .. ... .. ...... .' . '" . . . ....... ..........",... ......... .... ." , .' ,,' ,;p~HY:ºtJlliP9¡:¡ffl~p9r~):'·' ',' ' IGL 66.00 \24 HRS PROG 128.0 ITMD 9,570 MD 9,489 INCL 70.10 AZIMUTH 277.00 SURVEY DATA TVD VS N/S CUM E/WCUMDOGLEG MD 8,699.25 150.01 -1,352.90 -150.01 15.68 9,524 INCL 76.60 AZIMUTH 276.60 ':<. ..' H'COIVIPÄNY ,.,'" ........ ...... Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services . ... ... ...... .... .... . . . ... ......... ......... ...... ........ ...... .. . .. ... . . .. . . . . . .. . .. ... . . . . . . , . . . .. . .. ..................... ...... ............... . . . ..... ....,. ... .. ......:.:......:....... . . ... ... .... .. .......... ...... .. ...... ........ .............. . ..... .. . .. ....... ... . ...... ...... . .... . . . .. . , . >"·/:::·/SÊÅVICE ,'. <. '. ' .. ... ...... . iPERSÖNNEIlDÄtíV¡ , . . . . .. ... ...... ......... .... ... '. .,.: 'Nä>',HØUf¡$¡ ;.'. "çQlVipÄ~N.; '" 2 42.00 Denison Engineer 18 238.00 MI Centrifuge Personnel 3 72.00 Lynden Transport 1 24.00 Alaska Oil Sales 4 48.00 R&K Industrial ) ITVD 8,717 IDFS 41 TVD VS N/S CUM E/W CUM DOGLEG 8,709.27 183.29 -1,348.94 -183.29 18.60 , , .'; ..'.;.,' .,;< . .. .;. ······.¡pQs.(§¡oä:QQ:; ,. ;, · .,;, '/SE:RvïCE .'.,.'.... ... ·>NO.' .·"HOUA$,· 1 24.00 2 31.00 1 1.00 1 1.00 1 2.00 Printed: 4/28/2002 7:58:16 AM ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS POOH wI test tools. 24 HR FORECAST TIH open ended. Perform Form-A-Set squeeze. POOH. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ST OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 \24 HRS PROG REPT NO. 9,570 45 I RIG PHONE AUTH MD AFE COST 907-283-1312 11,637 DD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 50,567.00 2,917,337.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/24/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435.0 (ft) 4.500 (in) @ 11,640.0 (ft) 15.27 OP COMMENTS: POOH. LD BHA. PU test tools. TIH. Set packer, open bypass. Displace DP to 10.0 ppg mud. Monitor SIDPP. Reverse 10 ppg mud to 11.3 ppg mud. Circulate & POOH. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 09:00 3.00 9,570 9,570 DRLPRO FPOOH. 09:00 09:30 0.50 9,570 9,570 DRLPRO Service Rig. 09:30 10:00 0.50 9,570 9,570 DRLPRO LD 2.5 AKO motor & BHA. MU test tools. 10:00 16:00 6.00 9,570 9,570 DRLPRO TIH wI test tools. 16:00 17:00 1.00 9,570 9,570 DRLPRO RU test head. Set packer at 9324' MD. RU chicksan to to choke. Open by-pass valve. 17:00 18:00 1.00 9,570 9,570 DRLPRO Displace DP wI 98 bbls 10 ppg mud. 18:00 19:30 1.50 9,570 9,570 DRLPRO Close by-pass & monitor DP pressure. SI with 760 psi on DP. Final SIDPP 935 psi. 19:30 22:00 2.50 9,570 9,570 DRLPRO Open by-pass. Reverse 10 ppg mud fl drill pipe. 22:00 01 :00 3.00 9,570 9,570 DRLPRO Release packer. Circulate full circulation to 11.3 ppg MW in/out. Flow check. Slug pipe. 01:00 05:30 4.50 9,570 9,570 DRLPRO POOH wI test tools. 05:30 06:00 0.50 9,570 9,570 DRLPRO LD test tools. DENSITY(ppg) FV PVIYP 55 13/41 11 .35 I PP I GELS WUHTHP 19/24 5.41 I ECD 112.71 MUD DATAl DAILY COST I FCIT.SOL OIUWAT "IoSandlMBT Ph/pM 1.0/15.0 2/83 10.6 10.50/0.3 2,856.00 Pf/Mf 0.2/1.3 I CUM COST 1 450,323.35 CI Ca H2S LIME 110,000 40 ES BIT I RUN 10/1 SIZE 6.125 MANUF. Hughes TYPE STXR20DX2 BITS SERIAL NO. JETS OR TFA 5010956 15/15/15111 DEPTH IN DATE IN 9,439.0 4/23/2002 I-O-D-L-B-G-O-R 2-3-WT-H-E- I-WT-BHA BIT I RUN 10 I 1 WOB 10 I 30 RPM GPM 284 PRESS 2,300 PBIT 312 HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 5.00 131.0 26.20 ,'.' '. ,',,·,,···'SHA' EFF~. 'lpIC~~: IS~~~o¡=1R()~~. >TÓRåÜE(jaxlrnin) SHAHRS IJARHRS IM'NDHRS MTR HRS Champ III Test Packer, VR Safety Joint, John Jars, OMNI Valve, Drain Valve, RD Safety Valve, Cross Over $HA NO. ", .'\ LENGTH 12 51.22 BHA DESCRIPTION PUMÞIHYDRAUI..IC'DATA STRQ(E(hl) LlNER(ín) SÞM Q(gpm) 8.000 4.000 62 78.52 8.000 4.000 62 78.52 'NO. 1 2 MAKEOFPUMP PRESS.(psi) TOTALQ 850 157.04 850 157.04 KILLSÞMI.PRESSUFŒ OILWELL OIL WELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Denison Engineer 18 238.00 Halliburton Test Enginee 3 72.00 Weaver Brothers 1 24.00 R&K Industrial 4 48.00 SERVICE NO. HOURS 24.00 22.00 1.00 11.00 Printed: 4/29/2002 6:57:22 AM ) ) MARATHON OIL COMPANY Page 1 of 2 sT IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling Report IGL 66.00 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS POOH wI open ended DP. 24 HR FORECAST FPOOH. TIH w/ biUBHA. Drill plug. POOH. TIH w/ test tools. FIELD NAME I sTATElPROV I COUNTY/OTHER ¡LAST CASING Kenai Alaska Kenai Borough 7.000 (in) (éQ 24HRSPROtMD ITVD IDFS IDOL REPTNO. DATE 9,570 8,717 43 44.00 46 30-Apr-2002 I RIG PHONE AUTH MD ¡WBS SAPIWBS cos- 907-283-1312 11 ,637 ~D.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 60,694.00 2,978,031.85 ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/29/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) (éQ 11,640 (ft) 15.27 OP COMMENTS: TIH open-ended. Circulate. Pump flush & polymer squeeze. Pull 18 stds. Squeeze formation. Bleed pressure. Circulate. POOH. FROM 06:00 06:30 10:30 12:00 TO 06:30 10:30 12:00 15:30 HRS 0.50 4.00 1.50 3.50 DEPTH FM DEPTH TO SUB 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 15:30 16:00 0.50 16:00 17:00 1.00 17:00 17:30 0.50 17:30 00:00 6.50 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 00:00 02:30 2.50 9,570 9,570 AF 02:30 06:00 3.50 9,570 9,570 AF DENSITY(ppg) FV PVNP 55 13/45 11.35 I PP I GELS WUHTHP 19/24 5.4/ I ECD112.701 MUD DATAl DAILY COST I Fcrr.SOL OILlWAT %Sand/MBT Ph/pM 1.0/17.0 2/81 0.30/0.8 10/0.2 18,575.00 Pf/Mf I CUM COST 468,898.35 CI/Ca H2S LIME ES 6RPM OPERATIONS SUMMARY PHASE OP DRLPRO BBHD DRLPRO TRIP DRLPRO CAN DC DRLPRO SOCP DRLPRO SOCP DRLPRO SOCP DRLPRO SOCP DRLPRO SOCP DRLPRO CANDC DRLPRO TRIP DESCRIPTION LD test tools. TIH w/ open ended 4" DP to TD at 9570' MD. Circulate B/U. TG 21 units. Hold pre-job safety & procedures meeting. Remove screens f/ mud pumps. Mix & pump 25 bbls Safe-Klean flush. SD, clean pill pit. Mix 25 bbls Form-A-Set pill. Pump Form-A-Set pill. Displace w/95 bbls 11.3 ppg mud. Pull 18 stds DP to 8454' MD. Flush pumps & lines. SI & pressure up to 1800 psi. Bump pressure to 1800 psi every 25 minute-so Squeeze total of 6.6 bbls. SI at 21 :30 hrs. Pressure decreased to 1550 psi at 00:00 hrs. Bleed pressure. Bled back +/-1 bbl. Circulate B/U. BGG 0 units. Pump slug. POOH w/ DP. 0.2/1.3 110,000 /40 NO. 1 2 OILWELL OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 120 147.27 1,000 8.000 4.000 120 147.27 1,000 TOTAL Q 294.54 294.54 KILL SPM / PRESSURE MAKE OF PUMP AVG. CONN: MAX. CONN: COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services Denison Engineer Halliburton Test Engineer SERVICE LAST BOP TEST: 4/24/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 12.73 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 21 A VG. BKGRD: MAX. DRL: 2 POB @ 06:00: NO. HOURS 1 1.00 1 1.00 1 1.00 1 11.00 1 1.00 1 6.00 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Weaver Brothers 18 238.00 M-I Drilling Fluids 3 72.00 S&R Enterprises 2 30.00 R&K Industrial 4 48.00 Peninsula Sanitation 1 12.00 Veco Alaska 1 2.00 SERVICE CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018(psi)@ (ppg) 1,517 1,517 NEXT BOP TEST: WT (Ib/tt) GRADE 133.00 K-55 68.00 L-80 5/1/2002 BURST (psi) 3,060 5,380 Printed: 4/30/2002 10: 15:29 AM WELL NAME KENAI TYONEK UNIT 32-7H LAST BOP TEST: 4/24/2002 SIZE (in) 10 (in) SHOE TEST (ppg) 9.625 8.835 13.66 7.000 6.276 15.27 ) MARATHON OIL COMPANY Daily Drilling Report I GL 124 HRS PROtTMD 66.00 9,570 1ST IKB OH 87.00 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MO (ft) TVD (ft) 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,477 (psi) @ 11.30 (ppg) 9,435 8,679 TVD 8,717 ) Page 2 of 2 I DFS I DOL I REPT NO. I DATE 43 44.00 46 30-Apr-2002 NEXT BOP TEST: WT (lb/ft) GRADE 40.00 L-80 26.00 L-80 5/1/2002 BURST (psi) 5,750 7,240 Printed: 4/30/2002 10:15:29 AM ) ) MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS TIH w/ test tools. 24 HR FORECAST TIH. Perform neÇ)ative test. POOH. Test BOPE. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling Report IGL 66.00 124 HRS PROtTMD TVD IDFS IDOL REPT NO. DATE 9,570 8,717 44 45.00 47 01-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11,637 ~D.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 34,019.00 3,012,050.85 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/29/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) ~ 11,640 (ft) 15.27 OP COMMENTS: TIH w/ biUBHA. W/R polymer plug f/9270' to 9570' MD. Circulate B/U. TOOH. TIH w/ test tools. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP DESCRIPTION 06:00 06:30 0.50 9,570 9,570 AF DRLPRO SRIG Service Rig 06:30 07:30 1.00 9,570 9,570 AF DRLPRO BBHD PU directional BHA. 07:30 12:00 4.50 9,570 9,570 AF DRLPRO TRIP TIH. 12:00 12:30 0.50 9,570 9,570 AF DRLPRO WASHR Wash polymer plug f/ 9270' to 9437' MD. (Calculated top of plug at 9086' MD) 12:30 13:30 1.00 9,570 9,570 AF DRLPRO CANDC Circulate B/U. 13:30 14:00 0.50 9,570 9,570 AF DRLPRO WASHR Wash polymer plug f/ 9437' to TD at 9570' MD. 14:00 16:00 2.00 9,570 9,570 AF DRLPRO CANDC Circulate B/U. Slug pipe. Flow check. 16:00 19:00 3.00 9,570 9,570 AF DRLPRO TRIP POOH to 4657' MD. Hole not taking proper hole fill. Flow check. Small amount of flow. Decision to go back to bottom. 19:00 21:00 2.00 9,570 9,570 AF DRLPRO TRIP TIH to 7" shoe at 9435' MD. 21:00 22:30 1.50 9,570 9,570 AF DRLPRO CANDC Circulate B/U. Slug pipe. Flow check. 22:30 04:00 5.50 9,570 9,570 AF DRLPRO TRIP POOH. Stand back directional tools. 04:00 04:30 0.50 9,570 9,570 AF DRLPRO SRIG Service Rig, clean floor. 04:30 05:00 0.50 9,570 9,570 AF DRLPRO BBHD PU test tools for negative test. 05:00 06:00 1.00 9,570 9,570 AF DRLPRO TRIP TIH w/ test tools. DENSITY(ppg) FV PVIYP 53 14/45 11.45 I PP I GELS WUHTHP 16/21 5.8/ I ECO 112.701 MUD DATAl DAILY COST I FCIT.SOL OIUWAT %Sand/MBT Ph/pM 1.0/17.0 2/81 0.30/10.0 10/0.2 3,126.00 Pf/Mf I CUM COST 472,024.35 CI/Ca H2S LIME ES 6RPM 0.2/1.1 105,000/80 BIT / RUN SIZE MANUF. 11 /2 6.125 Hughes TYPE STXR20DX2 BITS SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 5010956 24/24/2411I 9,570.0 4/30/2002 0-0------ HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BIT / RUN WOB RPM GPM I PRESS I P BIT BHA BHA1~O' I LE~~~~ I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~ax/min) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS BHA DESCRIPTION Champ III Test Packer, VR Safety Joint, John Jars, OMNI Valve, Drain Valve, RD Safety Valve, Cross Over NO. 1 2 MAKE OF PUMP PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 122 149.73 1,950 8.000 4.000 122 149.73 1,950 TOTAL Q 299.46 299.46 KILL SPM / PRESSURE OILWELL OILWELL MUD GAS UNITS AVG. CONN: MAX. CONN: AVG. TRIP: MAX. TRIP: 32 AVG. BKGRD: MAX. DRL: COMPANY Marathon SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 25.00 Inlet Drilling Alaska SERVICE PCB @ 06:00: NO. HOURS 18 238.00 Printed: 5/1/2002 4:14:55 PM WELL NAME KENAI TYONEK UNIT 32-7H COMPANY Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services ) MARATHON OIL COMPANY 1sT IKB OH 87.00 Daily Drilling Report GL 66.00 124 HRS PROtTMD 9,570 SERVICE PERSONNEL DATA NO. HOURS COMPANY 3 72.00 Denison Engineer 2 30.00 R&K Industrial 4 48.00 Maintainer Driver LAST BOP TEST: 4/24/2002 SIZE (in) 10 (in) SHOE TEST (ppç¡) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,477 (psi) @ 11.30 (ppg) 9,435 8,679 12.73 13.66 15.27 ) Page 2 of 2 I DFS I DOL I REPT NO. I DATE 44 45.00 47 ~1-May-2002 POB @ 06:00: NO. HOURS 1 12.00 1 10.00 1 12.00 ITVD 8,717 SERVICE NEXT BOP TEST: WT (lblft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 5/1/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/1/2002 4:14:55 PM ) ) .. MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Well SI for pressure build up. 24 HR FORECAST Reverse DP w/11.5 ppg mud. POOH. LD test tools. Run CBL. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) cæ Daily Drilling Report ST IKB IGL 124HRSPROtTMD ITVD IDFS IDOL REPTNO. DATE OH 87.00 66.00 9,570 8,717 45 46.00 48 02-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 PD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 52,288.00 3,064,338.85 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/29/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) cæ 11,640 (ft) 15.27 OP COMMENTS: TIH wI test tools. Set packer at 9320'. Displ DP w/9 ppg brine. Cycle SI periods. Flow well until gas to sfc. Reverse 9 ppg brine & gas to sfc. Displ DP wI 9 ppg brine. Start pressure build up. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP DESCRIPTION 06:00 09:00 3.00 9,570 9,570 AF DRLPRO TRIP Trip in hole wI test tools. 09:00 10:30 1.50 9,570 9,570 AF DRLPRO SCDL Slip and Cut Drill Line. 10:30 12:30 2.00 9,570 9,570 AF DRLPRO DSTF RU test head. Set packer at 9320' MD. RU chicksan to choke manifold. Open by-pass valve. 12:30 13:30 1.00 9,570 9,570 AF DRLPRO DSTF Displace DP w/ 98 bbls 9.0 ppg brine. 13:30 16:00 2.50 9,570 9,570 AF DRLPRO DSTF Close by-pass & monitor DP pressure. SI wI 1160 psi on DP. 1 hour SIDDP 1345 psi. Cycle DP pressure every 30 minutes, bleed pressure to 0 psi & SI, record 30 min SIDPP. (1) SIDDP 570 psi. (2) SIDDP 400 psi. (3) SIDDP 300 psi. 16:00 18:00 2.00 9,570 9,570 AF DRLPRO DSTF Bleed pressure off DP to 0 psi & open well through choke to pill pit. Well flowing slightly. Monitor flow. Flow rate at end of flow period +1-15 gal/hr. 18:00 23:30 5.50 9,570 9,570 AF DRLPRO DSTF Cycle DP pressure every 30 minutes, bleed pressure to 0 psi & SI, record 30 min SIDPP. (4) SIDDP 300 psi. (5) SIDDP 350 psi. (6) SIDDP 350 psi. (7) SIDDP 370 psi. (8) SIDDP 330 psi. (9) SIDDP 280 psi. (10) SIDDP 270 psi. (11) SIDPP 300 psi. After bleeding pressure fl cycle 11, well started to flow. 23:30 00:00 0.50 9,570 9,570 AF DRLPRO DSTF Flow well through choke & degasser, choke 1/2 open & 100 psi FDPP. Gas to surface at end of flow period. 00:00 01:00 1.00 9,570 9,570 AF DRLPRO DSTF Shut well in. Bleed DP pressure to 0 psi. 60 minute SIDDP 145 psi. 01:00 02:00 1.00 9,570 9,570 AF DRLPRO DSTF Open by-pass. Reverse 9.0 ppg brine & gas fl drill pipe w/11.5 ppg mud. BU gas 400 units. 02:00 03:30 1.50 9,570 9,570 AF DRLPRO DSTF Displace DP wI 98 bbls of 9.0 ppg brine. 03:30 06:00 2.50 9,570 9,570 AF DRLPRO DSTF Start pressure build up. Record SIDDP every 15 minutes. Initial SIDPP 520 psi at 03:40 hrs. SIDPP 880 psi at report time. DENSITY(ppg) FV PVIYP 52 14/41 11.45 I PP I GELS WUHTHP 17/22 6.2/ I ECD 112.601 MUD DATAl DAILY COST I FCIT.SOL OIUWAT %Sand/MBT Ph/pM 1.0/17.0 2/81 0.30/1.0 1010.2 2,809.00 Pf/Mf I CUM COST 474,833.35 CI/Ca H2S LIME ES 6RPM 0.211.3 108,000/80 BHA NO, I LENGTH I EFF WT. I PICK UP 14 51.22 BHA I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS Printed: 5/212002 9:47:53 AM ) ) WELL NAME KENAI TYONEK UNIT 32-7H MARATHON OIL COMPANY Daily Drilling Report GL 124 HRS PRotTMD 66.00 9,570 Page 2 of 2 1ST IKB OH 87.00 ITVD IDFS IDOL REPT NO.DATE 8,717 45 46.00 48 02-May-2002 BHA BHA DESCRIPTION Champ III Test Packer, VR Safety Joint, John Jars, OMNI Valve, Drain Valve, RD Safety Valve, Cross Over NO. MAKE OF PUMP OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM I PRESSURE 8.000 4.000 130 159.54 800 159.54 PERSONNEL DATA POB @ 06:00: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Marathon 2 26.00 Veco Alaska 1 8.00 Inlet Drilling Alaska 18 238.00 Maintainer Operator 1 10.00 Baker Hughes Inteq 3 72.00 Halliburton Tester 1 24.00 M-I Drilling Fluids 2 30.00 R&K Industrial 2 15.00 Epoch Well Services 4 48.00 LAST BOP TEST: 4/24/2002 SIZE (in) 10 (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 12.73 13.66 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1.517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,477 (psi) @ 11.30 (ppg) 9,435 8,679 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 5/1/2002 BURST (psi) 3,060 5,380 5,750 7,240 , Printed: 5/212002 9:47:53 AM I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Run CBT-USIT log. 24 HR FORECAST Finish log. Test BOPE. FIELD NAME Kenai ) ) ST OH RIG NAME & NO. GLACIER DRILLING 1 REPT NO. DATE 8,717 46 47.00 49 )3-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11,637 Q>D.01.G0338.CAP.DR _ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.2000 46,347.00 3,110,685.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 4/29/2002 4/24/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: Well SI, pressure build up. Bleed well to 0 psi.. Shut in well, pressure build up. Reverse DP to 11.5 ppg mud. Rls pkr. Circulate hole to 11.5 ppg mud. POOH wI test tools. RU & run CBT/USIT log. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP DESCRIPTION 06:00 07:00 1.00 9,570 9,570 AF DRLPRO DSTF Well shut in. Pressure at 06:00 hrs 880 psi. Pressure at 07:00 hrs 910 psi 07:00 08:30 1.50 9,570 9,570 AF DRLPRO DSTF Bleed pressure to 0 psi. Shut well in for pressure build up. 90 minute build up 645 psi. 08:30 09:30 1.00 9,570 9,570 AF DRLPRO DSTF Open by-pass. Reverse 9.0 ppg brine to 11.5 ppg mud. 09:30 12:30 3.00 9,570 9,570 AF DRLPRO CANDC Release packer. Circulate full circulation to 11.5 ppg MW inlout. 12:30 13:00 0.50 9,570 9,570 AF DRLPRO PULD LD test head. Slug pipe. 13:00 15:00 2.00 9,570 9,570 AF DRLPRO TRIP POOH wI test tools. 15:00 15:30 0.50 9,570 9,570 AF DRLPRO TRIP Mix & pump 2nd dry job. 15:30 18:00 2.50 9,570 9,570 AF DRLPRO TRIP POOH wI test tools. 18:00 18:30 0.50 9,570 9,570 AF DRLPRO TRIP Open by-pass & pump 3rd dry job. 18:30 22:00 3.50 9,570 9,570 AF DRLPRO TRIP FPOOH. 22:00 23:00 1.00 9,570 9,570 AF DRLPRO BBHD LD test tools. 23:00 06:00 7.00 9,570 9,570 AF DRLPRO LOGOTR Pre-job safety meeting. RU wireline unit & run CBT/USIT log. RD wireline unit. COMMENTS Held weekly safety meeting. DENSITY(ppg) FV PVIYP 51 14/37 11.45 I PP I GELS WLJHTHP 16/20 6.41 ECD12.40IMUD DATAl DAILY COST l FC/T.SOL OIUWAT ·%Sand/MBT Ph/pM 1.0/16.0 2/82 0.30/1.0 9.501 3,278.00 Pf/Mf 0.1/1.3 CUM COST, 478,111.35 CVCa H2S LIME ES 6RPM 96,000 180 BHA BHA1~O. ILE~~~~ EFFWT. ¡PICKUP I SLACK OF1ROT WT. ITORQUE(~xImin) BHAHRS IJARHRS IMWDHRS IMTRHRS ISSHRS BHA DESCRIPTION Champ III Test Packer, VR Safety Joint, John Jars, OMNI Valve, Drain Valve, RD Safety Valve, Cross Over OILWELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services SERVICE LAST BOP TEST: 4/24/2002 SIZE (ìn) ID(in).·. SHOE TEST (ppg) 20.000 18.730 13.375 12.415 12.73 PUMP I HYDRAULIC DATA STROKE (In) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 4.000 130 159.54 800 159.54 KILL SPM I PRESSURE PERSONNEL DATA NO. HOURS COMPANY 2 28.00 Maintainer Operator 18 238.00 Halliburton Tester 3 72.00 R&K Industrial 1 24.00 OSHA 4 48.00 Schlumberger POB @ 06:00: NO. HOURS 1 10.00 1 18.00 1 4.00 1 4.00 4 40.00 SERVICE CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 K-55 68.00 L-80 5/1/2002 BURST(psi) 3,060 5,380 Printed: 5/312002 10:53:22 AM ..... .. ........ '....... ...... ......... .. . ...... .. ·'··'!:'éAsIN'(~SUMMAR~i,· ' LAST CASING TEST: 4/19/2002 . . . . . .... .. . .. . . . . . . . . . .. .. . . . . . . . .. .. ,. . . . .. . . ... .. . . . .... . , MAX,SICp.::·."'· ·/H ¡:··MP(ft)¡'¡< ·Wb¡(ft) 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,477 (psi) @ 11.30 (ppg) 9,435 8,679 LAST BOP TEST: 4/24/2002 .. . ............. ... ... .... ... . ". .. .... . ... . . . SIZ·Ê:{lri) ,...'., ·...IÓ'(iO) ¡S!4ÓË>TE$T(ppg) 9.625 8.835 13.66 7.000 6.276 15.27 NEXT BOP TEST: 5/1/2002 . " .. ........ ..... ,... .... ,... ... . . .... . .. . "·,VVTOb/hj· ",. ·¡··:GFÙXÖÊ/· BURST (pŠij. 40.00 L-80 5,750 26.00 L-80 7,240 Printed: 5/3/2002 10:53:22 AM ) ) MARATHON OIL COMPANY Page. 1 of· 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Prepare to circulate B/U. 24 HR FORECAST POOH/TIH. Reduce MW. Clean out polymer ¡lug. Triplchg BHA. FIELD NAME I STATElPROV COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 . Daily Drilling Report' IGL 66.00 \24 HRS PR04TMD I TVD I DFS I DOL I REPT NO. DATe I 9,570 8,717 47 48.00 50 )4-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11,637 d>D.01.G0338.CAP.DR _ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 77,914.00 3,188,599.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: Test BOPE. TIH wI OE DP. Circ B/U. Mix & pump polymer pill. Squeeze formation. Monitor pressure. ",.,. ,. , .,. .".",Öp·t;RArl.QNS'SUMMARY 'FROM T.o . !-iRS . ,DEPTH FM DEPTH TO SUB .' PHASE . OP 06:00 08:30 2.50 9,570 9,570 AF DRLPRO PLOT .1·" ',. 08:30 09:00 0.50 9,570 9,570 AF DRLPRO WEARB 09:00 09:30 0.50 9,570 9,570 AF DRLPRO SRIG 09:30 11:00 1.50 9,570 9,570 AF DRLPRO WOO 11:00 15:00 4.00 9,570 9,570 AF DRLPRO SOCP 15:00 17:00 2.00 9,570 9,570 AF DRLPRO SOCP 17:00 18:30 1.50 9,570 9,570 AF DRLPRO SOCP 18:30 19:00 0.50 9,570 9,570 AF DRLPRO SOCP 19:00 20:00 1.00 9,570 9,570 AF DRLPRO SOCP 20:00 20:30 0.50 9,570 9,570 AF DRLPRO SOCP 20:30 06:00 9.50 9,570 9,570 AF DRLPRO SOCP .... .. ,...."""... , DE;Sc.RIPTION Test BOPE. Test annular, upper pipe rams, upper & lower kelly cocks, floor valves, check valve, inside & outside kill line valves, HCR & inside choke valves, choke manifold valves 1-12, lower pipe rams, blind rams & dart valve to 250 psi 10wI 3000 psi high. Function test Koomey unit, check N2 bladders. Test & calibrate gas alarms. Test witnessed by AOGCC rep Lou Grimaldi. Install wear bushing. Service Rig WO Orders TIH wI open ended 4" DP to TD @ 9570' MD. Circulate B/U. TG 340 units. Hold pre-job safety & procedures meeting. Remove screens fl mud pu~ps. Mix & pump 25 bbls Safe-Klean flush. SD, clean pill pit. Mix 25 bbls Form-A-Set pill. Spot polymer pill on bottom wI 95 bbls 11.5 ppg mud. Pull 18 stds DP to 8488' MD. Flush pumps & lines. SI & squeeze polymer at 0.25 bpm at 15 minute intervals to 1700 psi. Squeeze total of 4.82 bbls. SI at 02:30 hrs. Pressure decreased to 1635 psi at report time (6 hr squeeze, 3.5 hour SI). COMMENTS BOP test witnessed by AOGCC rep Lou Grimaldi. DENSITY(ppg) FV PV/YP 52 15/38 I 11 .45 I PP I GELS WLJHTHP 15/19 6.61 I ~CD 112.401 MUD DATADAILY.COST I Fcrr.SOL OIUWAT ' %Sand/MBT Ph/pM 1.0/17.0 2/81 0.30/1.0 9.501 18,259.00 I CUM COST 496,370.35 'Pf/Mf . . CUCa H2S LIME· ES 6RPM 0.1/1.5 98,000 180 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M- Drilling Fluids SERVICE PERSONNEL DATA N.o. H.oURS COMPANY 1 24.00 Epoch Well Services 18 238.00 AOGCC Rep 3 72.00 Weaver Brothers 1 24.00 SERVICE' . POS'@ 06:00: NO. HOURS 4 48.00 1 3.00 1 1.00 LAST BOP TEST: 5/3/2002 ,,'SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 12.73 13.66 15.27 LAST CASING TEST: 4/19/2002 MAxsfcp MD(ft) TVD(ftf' (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 NEXT BOP TEST: WT(lb/ft) . GRÄDE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 5/10/2002 Bl.JRST(pSi) 3,060 5,380 5,750 7,240 Printed: 5/6/2002 6:30:18 Atv1 ) ) MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS POOH wI C/O BHA. 24 HR FORECAST TIH wI lateral section BHA. Drill ahead. FIELD NAME I STATElPROV Kenai Alaska ST \KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily þrilling Report IGL 66.00 \24 HRS PROqTMD TVD IDFS IDOL REPT NO. DATE I 9,570 8,717 48 49.00 51 05-May-2002 I RIG PHONE AUTH MD I was SAPIWBS COS- 907-283-1312 11,637 Q>D.01.G0338.CAP.DR_3,284,OOO IMOC WI INRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 35,831.00 3,224,430.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ OP COMMENTS: Circ B/U. POOH. TIH. Circ & reduce MW to 10 ppg. W/R polymer pill to TD @ 9570'. Pull to shoe. Circ B/U. POOH. Öþ'ERAfIONs SUMMARY "," ""'; , "" . 'I'" ". ' .. FROM ' Tp HRS: DEPTH FM DEPTH TO . SUB PHASE:.' OP . DESCRIPTION . 06:00 08:00 2.00 9,570 9,570 AF DRLPRO CANDC Circulate B/U. B/U 25 units. Flow check. Pump dry job. 08:00 12:30 4.50 9,570 9,570 AF DRLPRO TRIP POOH wI 4" DP. 12:30 18:00 5.50 9,570 9,570 AF DRLPRO TRIP TIH wI 2.5 AKO motor BHA to 9100' MD. 18:00 22:30 4.50 9,570 9,570 AF DRLPRO CANDC Circulate & condition mud. Trip gas 26 units. Decrease MW fl 11 .5 ppg to 10.0 ppg. BGG 0 units at end of MW reduction. 22:30 23:30 1.00 9,570 9,570 AF DRLPRO WASHR W/R polymer plug fl 9100' to 9455' MD. Flow check well. 23:30 01:00 1.50 9,570 9,570 AF DRLPRO WASHR W/R polymer plug fl 9455' to TD at 9570' MD. Pull to shoe at 9435' MD. 01:00 02:30 1.50 9,570 9,570 AF DRLPRO CANDC Circulate B/U. BU gas 25 units. Flow check well. Pump dry job. 02:30 06:00 3.50 9,570 9,570 AF DRLPRO TRI P POOH. DENSrN(ppg) 10.00 I pp I FV PVtY~,·· GEL.$ WµHTHI' 48 9/29 13/17 6.81 I fCD \10.60\ MUD:oAtAI DAILY COST I Fcrr~SOL' OII,JWAT' .' %$a",,(jfMi3T Phlp!'v1' 1.0/12.0 1/87 0.25/1.0 9.501 2,923.00 Pf/Mf " 0.1/1.2 I:CUMêOST 499,293.35 'CIIÇa". H2S LIME" I ES :6RPI\iI. 96,000 180 BIT.l RUN 12/3 . SIZE, 6.125 MANUF. Hughes . 'BITS ," . '''I I" . TYPE SERIAL NO.·, JETS'ÖR TFA DEPTH IN DÄTE>lN I.;,O-D-L~B~()~O-R STXR20DX2 5010956 24/24/24111 9,570.0 5/4/2002 2-3-WT-A-E- I-SD-BHA GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BIT I RUN WOB RPM NO. 1 2 MAKE OF PUMP '. " '.. BHA .. I EFF wr: I PICK UP I SLA~kO~1ROTwi-'ITOROUE (,;,,,,¡minj ¡BHA HRS I JAR HRS I M~D HRS MTRHRS 'I SS 'HR~ Tri-Cone Bit, MACH 1 X/1.2AKO/8 3/8UBHS , NON MAG CSDP W/MWD , Hang-Off Sub, NON-MAG CSDP , X/O 4 1/2" H90-P X 4" HT-38P ,4" 14PPF S-135 HT-38 DP (28), X/O HT-38-P X 41/2" IF-B , 5" HWDP (4), 6 1/4" hydraulic jars, 5" HWDP (21), X/O 41/2" IF-P X HT-38-B , 4" 14PPF S-35 HT-38DP PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 8.000 4.000 122 149.73 8.000 4.000 122 149.73 PRESS. (psi) TOTAL Q 1,550 299.46 1,550 299.46 KILL SPM I PRES$URE .SHA NO. . . ! LENárH 15 1,756.21 BHA DESCRIPTION OILWELL OILWELL COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 72.00 R&K Industrial SERVICE POB @ 06:00: NO. HOURS 3 32.00 5 52.00 1 10.00 12.73 13.66 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAXSICP MD(ft} TVD(ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 LAST BOP TEST: 5/3/2002 SIZE(in) ID(iri) SHOE TEST(pþg) 20.000 18.730 13.375 12.415 9.625 8.835 NEXT BOP TEST: .WF(lbift} GRADE 133.00 K-55 68.00 L-80 40.00 L-80 5/10/2002 ··BURST(psi) 3,060 5,380 5,750 Printed: 5/6/2002 6:32: 1 0 AM ) ) MARATHON O,IL COMPANY: '. Paga.2 of 2 WELL NAME KENAI TYONEK UNIT 32-7H 1ST KB OH 87.00 Daily. Drilling ·Report. IGL 66.00 124 HRS PRO~TMD I 9,570 LAST BOP TEST: 5/3/2002 SIZE (in) ID (in) SHOE TEST (ppg) 7.000 6.276 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAx SICP MD (ft) TVD (ft) 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 ITVD 8,717 I DFS I DOL I REPT NO. I DATe 48 49.00 51 þ5-May-2002 NEXT BOP TEST: 'WT (lb/ft) . 'GRADE . . 26.00 L-80 5/10/2002 BÜRST '(psi) 7,240 Printed: 5/6/2002 6:32:10 AM ) ) MARATHON OIL COMPANY Page.l·:af 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Drilling ahead. 24 HR FORECAST Drill ahead. FIELD NAME Kenai Daily Drilling. Report ST I KB I GL 124 HRS PRO~TMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 410.0 I 9,980 8,726 49 50.00 52)6-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 rPD.01.G0338.CAP.DR_3,284,OOO I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 91,710.00 3,316,140.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: POOH. Chg BHA. TIH. Orient tools. Drill fl 9570' to 9980' MD. . FROM. 06:00 07:00 08:00 12:00 12:30 13:30 '14:30 .: DEPTH i=M DEPTH.TO SUB 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,570 AF 9,570 9,980 AF , TO. ..HRS 07:00 1.00 08:00 1.00 12:00 4.00 12:30 0.50 13:30 1.00 14:30 1.00 06:00 15.50 .DENSITY(ppg) 9.90 I :pp I FV . PV/VP.··· GE~S WUHTHP 52 12/31 15/17 5.41 '' I" . . . BIT J.RUN SIZE· MANUE. TYP~ ' 13/1 6.125 Hughes DP0702 BIT I RUN WOB RPM GPM 13 11 5 I 20 60 I 70 307 ::.OP·Ef.1.t\ TIOf\JS SUMMARY . PHA$E' op· DRLPRO TRIP DRLPRO BBHD DRLPRO TRIP DRLPRO SRIG DRLPRO TRIP DRLPRO SURV DRLPRO DOHS , . DESC.RIPTION .... 29,458.00 CQM ·COST· 528,751.35 . 'Pf/Mf .' CIICa ,. H~S LIME,' ES!: '6RP~: 0.2/1.5 88,000/60 ·B.ITS '.'SERIALNO.·' . JETS OR'TFA 7000087 12/12/12/12/12/ PRESS 2,130 , DEPTH. IN DATE IN 9,570.0 5/5/2002 I I . ';. .. .,' . . . ,. . 170~[)'L"B~G~O~Ft 0-0------ PBIT 281 24Hr ROP 26.45 CUM HRS CUM DEPTH CUM ROP 15.50 410.0 26.45 FPOOH. LD 2.5 AKO motor BHA. PU PDC bit & 1.0 AKa motor lateral BHA. TIH wI new BHA. Test motor & MWD. Service Rig FTIH to 7" shoe at 9435' MD. Orient wI MWD & wash to bottom at 9570' MD. Directional drill & survey fl 9570' to 9980' MD (AST 5.25 hrs, ART 6.32 hrs). I ECO1 0.80'MUD:DAT A I'D~ILY COST' .FCIT,SOL . OluWÂT:. " %SandlMBT' PM/pM 1.0/10.0 3/87 0.25/2.0 9.5010.2 HRS 15.50 24Hr DIST 410.0 BHA1~Ø rL:~~;.~ol EFF:' IPIC~~: ""' S~~~ OF1RÖ;:: "I T~~~¿~~~) "IBHÄ HRS 1 JAÄ HRS '>AWD HRS IMfR HRS I SSfiRS BHA DESCRIPTION HTC DP0702 PDC Bit, M1XL 1.0 AKa Motor, 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. 1 2 PUMP I HYDRAULIC DATA STROKE (in) LINER (¡n) SPM O,(gpm) PRESS. (p$i) 8.000 4.000 125 153.41 2,130 8.000 4.000 125 153.41 2,130 TOTAL 0 306.82 306.82 KILL SPM I PRESSURE, 60 620 60 600 MAKE OF PUMP . OILWELL OILWELL A VG. CONN: MAX. CONN: 40 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 18 20 172 A VG. BKGRD: MAX. DRL: 7 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EIW CUM DOGLEG 9,550 83.70 268.20 8,714.43 208.85 -1,360.38 -208.85 26.67 9,742 89.10 269.60 8,718.22 400.72 -1,363.17 -400.72 3.30 9,583 88.20 269.20 8,716.76 241 .75 -1,361.12 -241.75 13.97 9,776 88.50 269.60 8,718.93 434.72 -1,363.41 -434.72 1.76 9,614 89.50 269.60 8,717.39 272.74 -1,361.45 -272.74 4.39 9,801 88.70 269.60 8,719.54 459.71 -1,363.58 -459.71 0.80 9,649 89.70 269.20 8,717.63 307.74 ~1 ,361.81 -307,74 1.28 9,865 87.40 269.20 8,721.72 523.67 -1,364.25 -523.67 2.13 9,680 89.70 269.20 8,717.79 338.73 -1,362.25 -338.73 0.00 9,926 88.20 268.90 8,724.06 584.61 -1,365.26 -584,61 1.40 9,712 89.80 268.90 8,717.93 370.73 -1,362.78 -370.73 0.99 Printed: 5/6/2002 6:33:48 AM WELL NAME KENAI TYONEK UNIT 32-7H ': COMPA[\jY . Marathon Inlet Drilling Alaska Baker Hughes Inteq .. ) ) MARATHON OIL C·OMPANY. Page 2· of .2 Daily Drilling Report. GL \24 HRS PR04TMD 66.00 410.0 I 9,980 1ST IKB OH 87.00 SERVICE PERSONNEL DATA ., "" '" "'" .,,,, . ,NO.. . HOURS COMPANY 2 42.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 1 72.00 R&K Industrial LAST BOP TEST: 5/3/2002 SIZE (in) . ID .(In)'" SHOE TEST(ppg) . 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 .' CASiNG SUMMARY LAST CASING TEST: 4/19/2002 . MAX. slCP '. , . MD (ft) . 'TVD' (ft) (psi) @ (ppg) ,139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 12.73 13.66 15.27 TVD 8,726 I DFS I DOL I REPT NO. I DATE 49 50.00 52 þ6-May-2002 . $ERVICE . . . NEXT BOP TEST: WTOb/ft) .: . . .GRADE· 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 POB@ 06:00: NO.. HOURS'" 2 42.00 1 48.00 1 4.00 5/10/2002 BURST (psi) , 3,060 5,380 5,750 7,240 Printed: 5/6/2002 6:33:48 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR Gene Anderson CURRENT STATUS Circulate B/U for trip. 24 HR FORECAST TFNB. Change BHA. TIH. Drill ahead. FIELD NAME I STATElPROV Kenai Alaska ) MARATHON OIL COMPANY Page 1 of 2 Daily Drilling Report ST KB GL 124 HRS PROtTMD ITVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 270.0 10,250 8,735 50 51.00 53 07-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD IWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 ¡þD.01.G0338.CAP.DR_ 3,284,000 MOCWI INRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 57,158.00 3,365,723.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) ~ 11,640 (ft) 15.27 I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) ~ OP COMMENTS: Drill fl 9980' to 10176' MD. Wiper trip. Drill f/1 0176' to 10250'. Circ for trip. 10,176 AF 10,176 AF 10,176 AF 10,238 AF OPERATIONS SUMMARY PHASE OP DESCRIPTION DRLPRO DOHD Directional drill & survey f/9980' to 10,176' MD. Pump 10 bbllow vis sweep at 10,000' MD. (AST 1.5 hrs, ART 4.03 hrs) Wiper trip. Back ream to 7" casing shoe. Service Rig Orient tools & TIH to TD. Directional drill & survey f/1 0,176' to 10,238' MD. (AST 0.5 hrs, ART 2.4 hrs) DRLPRO RRCO Work on #1 mud pump cooling fan motor. DRLPRO DOHD Directional drill & survey f/1 0,238' to 10,250' MD. (AST 0.5 hrs, ART 1.5 hrs) DRLPRO CANDC Circulate B/U for trip. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 15:00 9.00 9,980 10,176 AF 15:00 16:00 1.00 16:00 17:00 1.00 17:00 18:00 1.00 18:00 00:00 6.00 10,176 10,176 10,176 10,176 00:00 01 :00 1.00 01 :00 05:00 4.00 10,238 10,238 05:00 06:00 1.00 10,250 DENSITY(ppg) FV PVIYP 51 10/35 9.85 PP I GELS WUHTHP 16/21 5.01 DRLPRO WTRP DRLPRO SRIG DRLPRO WTRP DRLPRO DOHD 10,238 TA 10,250 AF 10,250 AF ECD11.00MUD DATAl DAILY COST I FCIT.SOL OILIWAT %Sand/MBT Ph/pM 1.0/10.0 3/89 0.25/1.3 9/0.1 I CUM COST 532,594.35 CI/Ca H2S LIME ES 6RPM 89,000/40 3,843.00 Pf/Mf 0.1/1.8 BITS BIT / RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O·D·L·B-G-O-R 13/1 6.125 Hughes DP0702 7000087 12/12/12/12/121 9,570.0 5/5/2002 8-8-WT-A-D- 2-NO-PR BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 13/1 5/20 70 I 70 307 2,000 280 10.43 270.0 25.89 25.93 680.0 26.22 BHA BHA NO. I LENGTH I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 16 3,003.30 0 150 115 125 6,000/8,000 BHA DESCRIPTION HTC DP0702 PDC Bit, M1XL 1.0 AKO Motor, 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar. Heavy Weight Drill Pipe (21), Cross Over NO. 1 2 MAKE OF PUMP OILWELL OILWELL AVG. CONN: MAX. CONN: PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 125 153.41 2.000 8.000 4.000 125 153.41 2,000 TOTAL Q 306.82 306.82 KILL SPM / PRESSURE 60 620 60 610 40 80 MUD GAS AVG. TRIP: MAX. TRIP: 287 AVG. BKGRD: MAX. DRL: UNITS 70 11 25 SURVEY DATA MD INCL AZIMUTH TVD VS N/S CUM EJW CUM DOGLEG MD INCL AZIMUTH TVD VS N/S CUM EJW CUM DOGLEG 9,961 88.60 268.90 8.725.04 619.59 -1,365.93 -619.59 1.14 10,087 87.20 268.50 8,731.77 745.39 -1,367.74 -745.39 3.19 9.992 87.40 269.60 8,726.12 650.57 -1,366.34 -650.57 4.48 10,120 87.50 268.50 8,733.29 778.34 -1,368.61 -778.34 0.91 10,023 86.00 269.20 8,727.91 681.52 -1,366.66 -681.52 4.70 10,151 87.80 268.20 8,734.57 809.30 -1,369.50 -809.30 1.37 10,056 86.50 269.20 8,730.07 714.44 -1,367.12 -714.44 1.52 10,181 89.50 267.50 8,735.27 839.27 -1,370.62 -839.27 6.13 Printed: 5/8/2002 9:59:45 AM WELL NAME _KENAI TYONEK UNIT 32-7H COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids ) MARATHON OIL COMPANY Daily Drilling Report IGL 124 HRS PROtTMD ITVD 66.00 270.0 10,250 8,735 1ST IKB OH 87.00 Page 2 of 2 I DFS I DOL I REPT NO. I DATE 50 51.00 53 þ7-May-2002 PERSONNEL DATA POB @ 06:00: SERVICE NO. HOURS COMPANY SERVICE NO. HOURS 2 48.00 Epoch Well Services 48.00 18 238.00 R&K Industrial 4.00 4 84.00 , Lynden Transport 1.00 3 48.00 Carlile Trucking 1.00 12.73 13.66 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 NEXT BOP TEST: wr (Iblft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-BO LAST BOP TEST: 5/3/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 5/10/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/8/2002 9:59:45 AM ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS Drilling ahead @ 10465. 24 HR FORECAST Drill ahead. Bit trip @ 30hrs. FIELD NAME I Kenai ) ) .. ............. . . .. .... .... .. .. ... . ........ .. . ..... .. .., . . .... .. .... . .... . . .. . ..... . .. .... . . . . . ... .. . .. . .. ... ... . . .. ",". .... . .. .. .. . ... . . . . ,.. .. .. . . .... . .... .",. ..... .... . . . . . ..' . . ".. .' , .. .. . . ,". . . . . . . . ... ...... . .. .. . . . ..... .. . .. . ...... .. . .. . . . .. . . . 'M~~~]~C)'N91~;:O~N1.Pt\N'l. " , '¡·@~nYþrilÏlf1$.R~pq"J .', IGL 66.00 124 HRS PR04TMD I TVD 215.0 I 10,465 8,736 51 52.00 54 )8-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11,637 rPD.01.G0338.CAPDR _3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 48,072.00 3,413,795.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: POOH change bit and motor. RIH. Drill f/10250' to FROM 06:00 12:00 13:00, 17:30 18:00 18:30 19:00 DEPTH FM DEPTH TO SUB AF AF AF AF AF AF AF TO HRS 12:00 6.00 13:00 1.00 17:30 4.50 18:00 0.50 18:30 0.50 19:00 0.50 06:00 11.00 DENSITY(ppg) FV PV/yP 49 10/33 9.75 I PP I GELS WUHTHP 15/20 5.11 FCIT.SOL 1.0/10.0 OPERATIONS SUMMARY PHASE OP DRLPRO TRIP DRLPRO BSHD DRLPRO TRIP DRLPRO SRIG DRLPRO TRIP DRLPRO WASHR DRLPRO DOHD DESCRIPTION POOH. UD bit and 1.0deg motor. M/U 1.2deg motor and new bit. RIH to 9434'. Service rig. Orient assy and RIH to 10106'. W/R F/10106' to 10250'. Dir drill and survey F/10250' to 1 0465'(TG=303units)(AST =2.7hrs ART =5.0hrs). I ECDI I MUD DATAl DAILY COST I OIUWAT %SandlMBT Ph/pM 2/88 0.25/1.3 8.5010.1 14,500.00 I CUM COST 547,094.35 Pf/Mf CIICa H2S LIME ES 6RPM 0.1/1.8 89,000/40 15 BITS BIT I RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D~L-B-G-O-R 13/1 6.125 Hughes DP0702 7000087 12/12/12/12/12/ 9,570.0 5/5/2002 8-8-WT-A-D- 2-NO-PR 14 ION E 6.125 HTC STX-R20DX2 5010955 16/16/16111 10,250.0 5/7/2002 0-0------ BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 14 lONE 5 115 70 I 70 270 1,900 189 7.70 215.0 27.92 7.70 215.0 27.92 BHA BHANO. ¡LENGTH EFFWT. PICKUP I SLACK OF1ROT WT. ¡TORQUE (maximin) IBHAHRS I JAR HRS MWDHRS IMTR HRS ISS HRS 17 2,994.51 0 148 115 128 6 I 8 BHA DESCRIPTION STXR20DX2, M1X W/1.2AKO W/6"UBHS , 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over OILWELL OIL WELL PUMP lHYDRAULlCDAT A . STROKE(in) LlNEi=t (in) , SPM '. Q(gprn) 8.000 4.000 110 135.00 8.000 4.000 110 135.00 KILL SPMI PFtESSURE 60 640 60 1,900 MUD GAS AVG. TRIP: MAX. TRIP: UNITS ·1 22 A VG. CONN: MAX. CONN: 20 15 A VG. BKGRD: MAX. DRL: 20 303 SURVEY DATA MD INCL AZIMUTH TVD VS NIS CUME/W CUM DOGLEG MD INCL AZIMUTH TVD VS NIS CUM E/W CUM DOGLEG 10,226 89.20 267.80 8,735.78 884.23 -1,372.47 -884.23 0.94 10,337 88.50 268.90 8,734.74 995.17 -1,375.35 -995.17 5.94 10,275 92.30 268.50 8,735.14 933.19 -1,374.05 -933.19 6.49 10,366 89.00 268.50 8,735.37 1,024.15 -1,376.00 -1,024.15 2.21 10,305 90.40 268.90 8,734.43 963.18 -1,374.73 -963.18 6.47 10,398 89.40 268.50 8,735.82 1,056.14 -1,376.84 -1,056.14 1.25 Printed: 5/8/2002 7:10:11 AM ) WELL NAME KENAI TYONEK UNIT 32-7H 1ST IKB OH 87.00 Marathon Inlet Drilling Alaska Baker Hughes Inteq M- Drilling Fluids . ........ ...... . . .. . "' .. '" . . . .. . .... .............. . .......... . . . . . . . .. .... . .. . ... .. . . . . "' .. . . . ... "'" .. ... ........ ..", .. .... . .. .... ... ....... . ... ... ... .......... .. ".. . ... .. .. .. ... . .... '" ". ........... ..... . . . .. ""' o . . . . .. . . . . . . , . . . . . .. .. .... . .. . . . ..., .. . .. .. . . .. .. . . , MABATfqQNfOILCOMPAN'( · .. ..... . '""' ..... ..... ......... . . ...... .",",.... ..... . .. .. . . ..... ......... .. .. ..,. ," . ". . .. . .. .... ......... . . . . . . .. ........ .. . ... . ... . . . . . ...... . , .. .. . . . .. .. ....... . ..... . "' . "' ,... ;i[¡)ªilý..·.~~illiÔ:g:6~P9 rl IGL 66.00 124 HRS PR04™D 215.0 I 10,465 ) .... .... .... ... ....... .... ..... .. ,". . . .. ... . . ... . . . ...". .. ..... .... .. ... . .. .... .... ... . ...... "' . ......... ,". ... ....... . ... . .." . . .. ........ .... . . ., ,. ......., .... ......, .., ".. ..... ..., , .. ".. ..... ., · :::P?gø ?qf?).} , .... .. , , ITVD 8,736 DFS 51 I DOL I REPT NO. I DATE 52.00 54 þ8-May-2002 POS·@06:0Ö: PEASÖNNELDATA' , NO. HOURS COMPANY 2 38.00 Epoch Well Services 18 238.00 R&K Industrial 4 48.00 Veco Alaska 5 60.00 LAST BOP TEST: 5/3/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD(ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11 .30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) , 9,435 8,679 12.73 13.66 15.27 SERVICE NEXT BOP TEST: WT (lb/ft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 NO. HOURS 4 48.00 1 4.00 1 4.00 5/10/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/8/2002 7: 1 0:11 AM WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS Drilling ahead @ 10793'. 24 HR FORECAST Drill ahead. Bit trip @ 30hrs. FIELD NAME I Kenai 124 HRS 328.0 10,793 8,736 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11,637 Q>D.01.G0338.CAP.DR _ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000Q 92.2000 46,254.00 3,460,049.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/2/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 87.00 RIG NAME & NO. GLACIER DRILLING 1 STATElPROV Alaska I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ OP COMMENTS: Drill f/10465' to 10584'. Circ. Drill f/10584' to 10793'. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 10:00 4.00 10,465 10,584 AF 10:00 12:00 2.00 10,584 10,584 AF 12:00 16:30 4.50 10,584 10,584 AF OPERATIONS SUMMARY PHASE OP DRLPRO DOHD DRLPRO CANDC DRLPRO CANDC 16:30 06:00 13.50 DENSITY(ppg) FV : . PV/yP 53 12/36 BIT I RUN 14/1 BIT I RUN 14 I 1 BHA NO. I LENGTH 17 2,994.51 BHA DESCRIPTION DESCRIPTION Dir drill and survey F/10465' to 1 0584'(ART =3.8hrs AST =Ohrs). Circ. for samples. Pump low vis sweep. Survey. Circ. and condition mud while waiting for decision to drill ahead(Conn. gas 240units from survey. Gas came up early). Dir drill and survey F/10584' to 1 0793'(ART =6.8hrs AST =2.8hrs) (Max conn gas380 units). 10,584 10,793 AF DRLPRO DOHD 9.65 I PP I GELS WUHTHP 18/24 5.2/ I ECD 110.901 MUD DATAl DAILY COST I FCIT.SOL OIUWAT %SandlMBT Ph/pM 1.0/9.0 2/89 0.20/1.9 10.0010.3 SIZE 6.125 TYPE STX-R20DX2 BITS SERIAL NO. JETS OR TFA 5010955 16/16/16111 MANUF. HTC WOB 10 I 20 GPM 270 PBIT 187 PRESS 1,900 RPM 70 I 70 HRS 13.20 6,849.00 Pf/Mf 0.2/2.0 I CUM COST 553,943.35 CIICa H2S LIME ES 6RPM 80,000/40 18 DEPTH IN DATE IN 10,250.0 5/7/2002 I-O-D-L-B-G-O-R 0-0------ 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 328.0 24.85 20.90 543.0 25.98 ÐHA . ' I EFF WT. I PICK UP I SLACK OF1ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS 1 MWD HRS I MTR HRS I SS HRS o 152 115 130 1 0 I 6 STXR20DX2 , M1X W/1.2AKO W/6"UBHS , 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over 'I ,puMÞ1HYÐRAÜLIC¡[)A'TÄ: . ~T¡:¡()I5EO")i.lNEFt'<.") ¡'. $¡:)M · ,"q(gprnf 8.000 4.000 110 135.00 8.000 4.000 110 135.00 KILL SPM iPRÊSSÙRE .' ... .... . ............. 60 660 60 660 OILWELL OIL WELL A VG. CONN: MAX. CONN: 260 380 MUD GAS AVG. TRIP: MAX. TRIP: MD 10,429 10,459 10,489 10,521 10,534 10,553 COMPANY Marathon INCL 89.00 89.10 89.80 90.10 90.30 90.40 SURVEY DATA TVD VS NlS CUM EJW CUM DOGLEG MD 8,736.25 1,087.13 -1,377.54 -1,087.13 1.82 10,586 8,736.75 1,117.12 -1,378.12 -1,117.12 0.33 10,615 8,737.041,147.11-1,378.62-1,147.11 2.54 10,646 8,737.07 1,179.11 -1,379.06 -1,179.11 0.94 10,676 8,737.021,192.11-1,379.25-1,192.11 1,54 10,709 8,736.91 1,211.11 -1,379.45 -1,211.11 2.17 10,739 AZIMUTH 268.90 268.90 269.20 269.20 269.20 269.60 INCL 91.00 91.80 91.80 92.50 90.50 88.90 UNITS o 45 76 AVG. BKGRD: MAX. DRL: AZIMUTH 269.20 269.90 270.30 270.60 271.00 271.00 TVD VS NlS CUM EJW CUM DOGLEG 8.736.50 1,244.10 -1,379.79 -1,244.10 2.19 8,735.79 1,273.09 -1,380.02 -1,273.09 3.67 8,734.82 1,304.08 -1,379.96 -1,304.08 1.29 8,733.70 1,334.05 -1,379.73 -1,334.05 2.54 8,732.83 1,367.04 -1,379.27 -1,367.04 6.18 8,732,99 1,397.03 -1,378.74 -1,397.03 5.33 SERVICE PERSONNEL ' DATA NO. HOURS COMPANY 2 38.00 Inlet Drilling Alaska SERVICE POB @ 06:00: NO. HOURS 18 238.00 Printed: 5/9/2002 7:30:31 AM ) . ..... .. . ....... .. '.. '. ": ":". ...; . ,".:; .. ", . . :. :.' .... "., .......:.."".."."::" ...... :: .:.:. :. . .. . . .... .. . .. .. . . . . . .. ..... . ... .......... .......... '" ... ,".. ... ..... ,".. . . .... . ... ", .. ...... ..... ... ........ . ..... ...... . ..... . .. . ........ ........ .. . .... ·r4~¡¡t~J~~~J~!~·.~~~~~NK· '.,'.... · 'D·· '··;,·m"ll" '·.0' "'I i: ··,.<~l¥::><~I,.,I.n9~~ppr".." 1GL 66.00 124 HRS PROqTMD 328.0 I 10,793 COMPANY Baker Hughes Inteq M-I Drilling Fluids Epoch Well Services PERSONNEL DATA NO. HOURS COMPANY 4 48.00 R&K Industrial 5 60.00 Veco Alaska 4 48.00 SERVICE LAST BOP TEST: 5/3/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) , 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11 .30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 12.73 13.66 15.27 ..' ... .. .. . .. . .. '.. " ".':"..... .. ..... ":: . ." : . ... . . ..... .. . .. . . · . .... . .. ... . . . . .. . .. . · . . "... . .. . ...... . · .... ..... .. ... , '.. ...' ,'·'··,·'.·j?~9êg;þf? ..;. ITVD 8,736 I DFS I DOL I REPT NO. I DATE 52 53.00 55 þ9-May-2002 POB @ 06:00: SERVICE NEXT BOP TEST: WT(lb/ft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 NO. HOURS 4.00 4.00 5/10/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 519/2002 7:30:31 AM ) ) MARATHON OIL COMPANY.: Page'1 of 2. ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling ·Repo.rt IGL 66.00 I COUNTY/OTHER I LAST CASING Kenai Borough 7.000 (in) @ WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS POOH. Bit on surface 06:00hrs. 24 HR FORECAST Perform BOPE test. RIH. Drill ahead. RELD NAME I STATElPROV Kenai Alaska 24HRSPR04TMD ITVD DFS IDOL REPTNO. DATE I 11 ,004 8,736 53 54.00 56 10-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS COS- 907-283-1312 11,637 ~D.01.G0338.CAP.DR_3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 74,437.00 3,547,403.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/3/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11 ,640 (ft) 15.27 ... c c :'.. ·r·. .. OP COMMENTS: Drill F/10793' to 11004'. CBU. POOH to 10067' wet. BIR F/10100' to 9435', CBU increase MW. CBU. POOH. .' ", ·.FROM' 06:00 12:30 13:00 17:00 19:00 20:00 21:30 ·H,RS··:. 6.50 0.50 4.00 2.00 1.00 1.50 2.00 ., .,., . ,. D~PTH·FM DEPTH TO '. SUB- . 10,793 10,927 AF 10,927 10,927 TA 10,927 11,004 AF 11 ,004 11 ,004 AF 11,004 11,004 AF 1-1,004 11,004 AF 11,004 11,004 AF . TP 12:30 13:00 17:00 19:00 20:00 21:30 23:30 23:30 00:00 0.50 00:00 02:00 2.00 02:00 06:00 4.00 11,004 11,004 11,004 11:004 AF 11,004 AF 11,004 AF 'ÖPE:AATIØNS·.SUMMA~Y: .. . . .. PHA5.E'· . op·.·· ", ",' DESCRIPTION DRLPRO DOHD Dir drill and survey F/10793' to 10927'(ART=5hrs AST=.5hrs). DRLPRO RRCO cIa cap gaskets #1 pump. DRLPRO DOHD Dir drill and survey F/10927' to 11 004'(ART =2.4 AST =Ohrs). DRLPRO CANDC Flow check. CBU(230 units conn gas). DRLPRO TRIP POOH to 10067' wet(tight @ 10570',10206', and 10067'). DRLPRO WASHR BIR F/10100' to 9435'(tight @ 10002',9958',9840',9530',9500'). DRLPRO CANDC CBUX2@ 9435'(Max gas 720units. Large quantity of cutting across shakers @B/U mainly sand). Increase MW to 9.8ppg w/NaBr. DRLPRO FLOWCK Observe well. No flow. DRLPRO FLOWCK CBU(no conn gas). Pump Dry Job. Fill trip tank. DRLPRO FLOWCK POOH. . ., ::':DEN,$Il~Y(pp'g) ,I 9.80 f,RP;1 l'Ecp 111.001:MÜb·DÄT~LÓAILY90ST:.1 >.::: Fy. ¡. ,':. PVI'JP : GËLS WLlHTHP' I7cir~SQL, , OIUWAT . ; %Sand/MB"( . Ph/pM' 48 10/34 15/21 5.01 1.0/9.5 2/89 0.25/2.5 10.0010.3 22,365.00 l:cUr.,1 COST' 576,308.35 :.pf/Mf. ·CVCa ..', :; . H2~ LIME:' .ES.· 6RPM· 0.2/1.9 83,000/40 15 ; ~~::::: I. : .·Blíl:R~N· . '$I~e,' 14/1 6.125 MANUF.'.· . ' HTC ..·TYPE''':'· STX-R20DX2 BIT I RUN 14/1 RPM 70 I 70 GPM 270 WOB 12 I 40 ". :··,BITS',·.:..' '. . SEFUAL~O. ·.JE1"~:ORJF~, ' 5010955 16/16/16/11 .'. .. . ^,' ../ ;: DEPTH IN ',DATE ,IN ' 10,250.0 5/7/2002 "I-O~D~kB-G-()~R . 0-0------ PRESS 1,900 HRS 8.50 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 211.0 24.82 29.40 754.0 25.65 PBIT 187 .1 .... . ',,,, " .",.... 1 .;.' . aHA '::.":'.':'.' ,;., "I"',: ":". ..' " :BJ-:lÄNO. ,:lEj\iGTI-i '.':EFF":wr.' PICKUP ·SLACKOF1ROTWT. TOROl.JE-(rOaXll11in)··' SHAHAS'JÄRHRS "!MWDHRS MTRHRS.SS HRS .: 17 2,994.51 . 0 165 115 130 10,000 I 6,000 BHA DESCRIPTION STXR20DX2 , M1X W/1.2AKO W/6"UBHS , 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. 1 2 MAKE OF PUMP OILWELL OILWELL AVG. CONN: MAX. CONN: 125 230 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids SERVICE PUMP. I HYDRAULIC DATA STROKE (In) LINER (In) SPM Q' (gpm) PRESS. (psi) 8.000 4.000 110 135.00 1,900 8.000 4.000 110 135.00 1,900 TOTAL Q 270.00 270.00 KILL SPM I PRESSURE 60 660 60 660 MUD GAS· AVG. TRIP: MAX. TRIP: UNITS A VG. BKGRD: MAX. DRL: o 50 196 POB @ 06:00: NO. HOURS 4 48.00 1 12.00 1 4.00 2 8.00 PERSONNEL DATA NO. HOURS COMPANY 2 36.00 Epoch Well Services 18 238.00 R&K Industrial 4 48.00 Weaver 5 60.00 Rand K trucking SERVICE Printed: 5/10/2002 7:16:14 AM ) ) ·MARATHON··OIL C.ÖMPANY Page 2·of·2 . WELL NAME KENAI TYONEK UNIT 32-7H 1ST KB OH 87.00 Daily Drilling Report' IGL 66.00 124 HRS PRO~TMD I 11 ,004 TVD 8,736 I DFS I DOL I REPT NO. I DATE 53 54.00 56 ~ 0-May-2002 LAST BOP TEST: 5/3/2002 SIZE (in)" 'ID (in):"SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 CASING SUMMARY. LAST CASING TEST: 4/19/2002 NEXT BOP TEST: MAX SICP MD (ft) TVD (ft) WT(lbift)· ·GRADE (psi) @ (ppg) 139 139 133.00 K-55 1,018 (psi) @ (ppg) 1,517 1,517 68.00 L-80 798 (psi) @ 11.30 (ppg) 6,526 6,503 40.00 L-80 ~.,703 (p~i),~ 11.50(pp~) ,,', . .9,4~5 8,679 26.00 L-80....,...... .. .... ........ .." ,..., ".."."",.." .. . REQUIREMENTS' '.' WI 9.65 MW connection gas was present. W/9.8 MW to csg shoe connection gas was not present. Connection gas was coming up well early and correlates to the liner top depth. 12.73 13.66 15.27 5/10/2002 BU RST (psi): 3,060 5,380 5,750 7,240 Printed: 5/10/2002 7: 16: 14 AM .) ) MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS Drillinç¡ ahead @ 11,200'. 24 HR FORECAST Drill ahead. FIELD NAME Kenai Daily Drilling Report ST IKB IGL \24 HRS PRotTMD ITVD IDFS IDOL REPT NO. DATE OH 87.00 66.00 196.0 11,200 8,736 54 55.00 57 11-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 JþD.01.G0338.CAP.DR. 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 47,130.00 3,594,533.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 STATElPROV I COUNTY/OTHER ¡LAST CASING Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: Test BOP. Repair rig and service. M/U new bit and RIH to csg shoe. Slip and cut drill line. RIH to 11004'. Drill F/11004' to 11200'. OPERATIONS SU MMARY PHASE OP DESCRIPTION DRLPRO PLOT Pull wear bushing. Run test plug. Test annular, bottom 4" pipe rams, upper 27/8" X 51/2" variable pipe rams w/4" test joint to 250/3000psi 5min. Tes~ blind rams to 250/3000psi 5min. inside and outside kill line valves, check valve, inside choke line valve, HCR valve, upper and lower kelly cock valves, TIW and IBOP valves, 1-12 CMV valves to 250/3000psi 5min. Perform accumulator test. Pull test plug. Install wear bushing. CIO joy stick on drillers console. Change oil and filter on #2 carrier motor. Service carrier, top drive, blocks and crown. Blow down choke. Adjust crown-o-matic. M/U new bit and orient MWD. Test MWD. RIH to CSG shoe @ 9435'. Slip and cut 730' of drill line. Orient tools and RIH to 10913'(tight spot @ 9460-9530). W/R F/10913' to 11004'. Dir drill and survey Drill F/11 004' to 11 ,200'(ART=5.6 AST=.5hrs)(max trip gas 520units) FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 09:00 3.00 AF 09:00 11 :00 2.00 AF DRLPRO RRCO 11:00 12:00 1.00 AF DRLPRO BBHD 12:00 16:30 4.50 AF DRLPRO TRIP 16:30 19:00 2.50 AF DRLPRO SCDL 19:00 21:00 2.00 AF DRLPRO TRIP 21:00 06:00 9.00 11,004 11,200 AF DRLPRO DOHD DENSITY(ppg) FV PVNP 48 10/32 9.80 I PP I GELS WUHTHP 14/19 5.11 I ECD 110.901 MUD DATAl DAILY COST I FCIT.SOL OIUWAT %Sand/MBT Ph/pM 1.0/9.5 2/89 0.25/2.5 10/0.2 10,251.00 I CUM COST 586,559.35 Pf/Mf ' CI/Ca H2S LIME ES 6RPM 0.2/1.8 81,000/40 14 BITS BIT I RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 14/1 6.125 HTC STX-R20DX2 5010955 16/16/16//1 10,250.0 5/7/2002 6-6-CR-N-F- I-SD-HR 15/1 6.125 HTC STX-R20DX2 5011345 15/15/15//1 11,004.0 5/11/2002 0-0------ BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 15/1 15 I 25 70 I 70 282 2,200 268 6.10 196.0 32.13 6.10 196.0 32.13 BHA BHA NO. I LENGTH I EFF WT. I PICK UP I SLACK OF~ ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 18 2,994.51 0 155 110 I 130 10,00017,000 BHA DESCRIPTION STXR20DX2, M1X W/1.2AKO W/6"UBHS, 6" UG NM String Stab, NMCS DP, MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. 1 2 PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 115 141.14 2,200 8.000 4.000 115 141.14 2,200 TOTAL Q 282.28 282.28 KILL SPM / PRESSURE 60 680 60 670 MAKE OF PUMP OILWELL OILWELL UNITS AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: 520 AVG. BKGRD: MAX. DRL: 398 30 Printed: 5/11/2002 10:20:20 AM WELL NAME KENAI TYONEK UNIT 32-7H MD 10,959 10,986 11,020 11,051 INCL 89.00 89.00 89.30 90.30 AZIMUTH 271.00 271.00 271.00 271.70 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq MARATHON OIL COMPANY Daily Drilling Report IGL 24HRSPRotTMD TVD IDFS 66.00 196.0 11,200 8,736 54 ) 1ST IKB OH 87.00 SURVEY DATA TVD VS N/S CUM EIW CUM DOGLEG MD INCL 8,734.92 1,616.98 -1,374.74 -1,616.98 0.97 11,082 90.30 8,735.39 1,643.97 -1,374.27 -1,643.97 0.00 11,111 91.10 8,735.89 1,677.96 -1,373.67 -1,677.96 0.88 11,143 91.10 8,736.00 1,708.95 -1,372.94 -1,708.95 3.94 AZIMUTH 271.70 271.70 271.70 SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 34.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 36.00 R&K Industrial 12.73 13.66 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 LAST BOP TEST: 5/10/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 ') Page 2 of 2 IDOL I REPT NO. DATE 55.00 57 11-May-2002 TVD VS N/S CUM EIW CUM DOGLEG 8,735.84 1,739.94 -1,372.02 -1,739.94 0.00 8,735.48 1,768.92 -1,371.16 -1,768.92 2.76 8,734.87 1,800.90 -1,370.21 -1,800.90 0.00 SERVICE POB @ 06:00: NO. HOURS 5 60.00 4 48.00 1 5.00 NEXT BOP TEST: WT (lb/ft) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 5/17/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/11/2002 10:20:20 AM .~ ,~ j' ) MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS Drilling ahead @ 8736'. 24 HR FORECAST Drill ahead. FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ Daily Drilling Report ST IKB IGL 24HRSPROtTMD ITVD DFS IDOL REPTNO. DATE OH 87.00 66.00 365.0 11,565 8,736 55 56.00 58 12-May-2002 RIG NAME & NO. ¡RIG PHONE AUTH MD IWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 ~D.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 56,763.00 3,651,296.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: Drill f/11 ,200' to 11,389'. CBU. POOH. CBU @ CSG shoe. C/O kelly valves and test. Orient tools RIH. Drill f/11389' to 11565', OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP DESCRIPTION 06:00 13:00 7.00 11,200 11,389 AF DRLPRO DOHD Dir drill F/11 ,200' to 11 ,389'(ART=5hrs AST=.3hrs). Lower kelly valve began to leak. 13:00 14:30 1.50 11,389 11,389 TA DRLPRO CANDC CBU. 14:30 17:30 3.00 11 ,~89 11,389 TA DRLPRO WASHR B/R F/11389' to 9608'(tight spots @ 10,850', 10,764', 10,515', 10,077', and 9,865'). 17:30 18:00 0.50 11,389 11,389 TA DRLPRO TRIP High side motor and POOH to CSG shoe. 18:00 20:00 2.00 11,389 11,389 TA DRLPRO CANDC CBUX2 @ CSG shoe (large quantity of cutting across shakers)(330 units gas). 20:00 21:00 1.00 11,389 11,389 TA DRLPRO RRCO CIO upper and lower kelly valves. 21:00 22:30 1.50 11,389 11,389 TA DRLPRO PLOT Test upper and lower kelly valves to 250/3000psi 5min. 22:30 00:00 1.50 11,389 11,389 TA DRLPRO TRIP Orient tools and RIH wash last 100' to 11 ,389'(tight spotlledge@9460'). 00:00 06:00 6.00 11,389 11 ,565 AF DRLPRO DOHD Dir drill and survey F/11389' to 11565'(ART=3.1 hrs AST=.3hrs)(Wiper gas=656units, Conn gas =40units). DENSITY(ppg) FV PVlYP 49 11/35 9.75 I PP I GELS WUHTHP 16/21 4.91 I ECD 111.101 MUD DATAl DAILY COST I Fcrr.SOL OILIWAT %Sand/MBT Ph/pM 1.0/9.5 3/88 0.20/3.0 9/0.1 17,015.00 Pf/Mf 0.1/1.5 85,000/40 I CUM COST 603,574.35 CI/Ca H2S LIME ES 6RPM 16 BIT / RUN 15/1 SIZE 6.125 MANUF. HTC TYPE STX-R20DX2 BITS SERIAL NO. JETS OR TFA 5011345 15/15/15/11 DEPTH IN DATEIN 11,004.0 5/11/2002 I-O-D-L-B-G-O-R 0-0------ BIT / RUN 15/1 WOB 1 0 I 25 RPM 70 I 70 GPM 270 PRESS 2,400 PBIT 244 HRS 8.63 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 365.0 42.29 14.73 561.0 38.09 BHA BHA NO. I LENGTH I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 18 2,994.51 0 150 110 130 8,000/6,000 BHA DESCRIPTION STXR20DX2, M1X W/1.2AKO W/6"UBHS ,6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. 1 2 MAKE OF PUMP PUMP J HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 4.000 110 135.00 2,400 8.000 4.000 110 135.00 2,400 TOTAL Q 270.00 270.00 KILL SPM / PRESSURE 60 780 60 780 OILWELL OILWELL AVG. CONN: MAX. CONN: 20 40 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 656 45 656 AVG. BKGRD: MAX. DRL: MD 11,173 11,206 INCL 89.90 89.90 AZIMUTH 272.00 271.30 SURVEY DATA TVD VS N/S CUM EfW CUM DOGLEG MD 8,734.61 1,830.89 -1.369.24 -1,830.89 4.12 11,234 8,734.66 1,863.87 -1,368.29 -1,863.87 2.12 11,267 INCL 90.30 90.60 AZIMUTH 271.70 271.70 TVD VS N/S CUM EfW CUM DOGLEG 8,734.61 1,891.86 -1,367.56 -1,891.86 2.02 8,734.35 1,924.85 -1,366.58 -1,924.85 0.91 Printed: 5/12/2002 11:25:50 AM WELL NAME KENAI TYONEK UNIT 32-7H MD 11,298 11,329 11,359 11,390 INCL 90.00 89.10 89.10 89.70 AZIMUTH 271.70 272.00 271.70 271.30 COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq ) -------- -------,- MARATHON OIL COMPANY ) Page 2 of 2 1sT IKB OH 87.00 Daily Drilling Report I GL 124 HRS PROtTMD I TVD I DFS IDOL I REPT NO. DATE 66.00 365.0 11,565 8,736 55 56.00 58 12-May-2002 SURVEY DATA TVD VS N/S CUM E/W CUM DOGLEG MD 8,734.19 1,955.83 -1,365.66 -1,955.83 1.94 11,422 8,734.44 1,986.82 -1,364.66 -1,986.82 3.06 11,452 8,734.91 2,016.80 -1,363.69 -2,016.80 1.00 11,483 8,735.23 2,047.78 -1,362.88 -2,047.78 2.33 11,514 INCL 90.30 91.00 89.90 90.20 AZIMUTH 271.30 271.70 272.00 272.00 SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 40.00 M-I Drilling Fluids 18 238.00 Epoch Well Services 3 36.00 R&K Industrial 12.73 13.66 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,01B(psi)@ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 LAST BOP TEST: 5/10/2002 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 TVD VS N/S CUM E/W CUM DOGLEG 8,735.23 2,079.78 -1,362.16 -2,079.78 1.88 8,734.89 2,109.76 -1,361.37 -2,109.76 2.69 8,734.65 2,140.75 -1,360.37 -2,140.75 3.68 8,734.62 2,171.73 -1,359.29 -2,171.73 0.97 SERVICE POB @ 06:00: NO. HOURS , 5 60.00 4 48.00 1 8.00 NEXT BOP TEST: WT (lb/ft) GRADE 133.00 K~55 68.00 L-80 40.00 L-BO 26.00 L-80 5/17/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/12/2002 11 :25:50 AM ') ) MARATHON OIL COMPANY Page 1 of 2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS CBU @ CSQ shoe. 24 HR FORECAST POOH. RIH w/polish mill. POOH. RIH Set liner top packer. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai BorouQh 7.000 (in) @ Daily Drilling Report ST I KB I GL 124 HRS PROtTMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 292.0 11,857 8,743 56 57.00 59 13-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS COS- GLACIER DRILLING 1 907-283-1312 11,637 pD.01.G0338.CAP.DR_ 3,284,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 62,194.00 3,729,490.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: Drill F/11 ,565' to 11,857'. B/R to 9700' POOH to the CSG shoe. CBU @ shoe. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP DESCRIPTION 06:00 09:30 3.50 11,565 11,637 AF DRLPRO DOHD Dir drilll and survey F/11 ,565' to 11.637'(ART=3.3hrs AST=.25hrs). 09:30 17:00 7.50 11,637 11,833 CS DRLPRO DOHD Dir drilll and survey F/11,637 to 11,833'(ART=4.27hrs AST=.38hrs). 17:00 18:30 1.50 11,833 11,833 TS DRLPRO RRCO C/O gasket #1 pump suction. 18:30 21:00 2.50 11,833 11,857 CS DRLPRO DOHD Dir drill and survey F/11 ,833' to 11,857'(motor stalling and increase in rotary torque)(ART=.56hrs AST=.88hrs). 21:00 00:00 3.00 11,857 11,857 AF DRLPRO CANDC CBU X2. 00:00 05:00 5.00 11,857 11,857 AF DRLPRO WASHR B/R F/11,857' to 9700'(tight spots @ 10,510',10,220', 10,200'). High side motor and POOH to CSG shoe(max gas 793 units). 05:00 06:00 1.00 11,857 11,857 AF DRLPRO CANDC CBU @ 9424'(max gas 440units). DENSITY(ppg) FV PVNP 48 12/34 9.80 I PP I GELS WL/HTHP 16/20 4.71 IECDI ¡MUD DATAl DAILY COST I FCIT.SOL OILIWAT %Sand/MBT Ph/pM 1.0/9.5 3/88 0.15/4.4 1010.3 5,670.00 I CUM COST 609,244.35 Pf/Mf CI/Ca H2S LIME ES 6RPM 0.2/1.6 85,000 140 16 BIT I RUN SIZE MANUF. TYPE 15/1 6.125 HTC STX-R20DX2 BIT I RUN WOB RPM GPM 15/1 1 0 I 25 70 I 70 270 BITS SERIAL NO. JETS OR TFA 5011345 15/15/15/1/ DEPTH IN DATE IN 11,004.0 5/11/2002 I·O·D·L·B·G·O·R 0-0------ PRESS 2,200 P BIT 245 HRS 9.64 ,24Hr DIST 292.0 24Hr ROP 30.29 CUM HRS CUM DEPTH CUM ROP 24.37 853.0 35.00 BHA BHA NO. I LENGTH I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TOR.a. UE (max/min) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I S5 HRS 18 2,994.51 0 150 110 128., 9,00017,000 . BHA DESCRIPTION STXR20DX2 , M 1 X W/1.2AKO W/6"UBHS , 6" UG NM String Stab, NMCS DP , MWD Tool, Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 4.000 110 135.00 2,200 270.00 8.000 4.000 110 135.00 2,200 270.00 KILL SPM / PRESSURE 60 760 60 760 AVG. CONN: MAX. CONN: 55 214 MUD GAS AVG. TRIP: MAX. TRIP: UNITS 236 55 AVG. BKGRD: MAX. DRL: MD 11,545 11 ,577 11,607 11 ,639 11 ,667 INCL 90.40 89.20 89.00 89.10 88,00 AZIMUTH 272.00 273.10 272.40 272.70 272.40 SURVEY DATA TVD VS N/S CUM EIW CUM DOGLEG ~ MD INCL 8,734.46 2,202.71 -1.358.21 -2,202.71 0.65 11,698 87.70 8,734.57 2,234.67 -1.356.78 -2,234.67 5.09 11,729 88.00 8,735.04 2,264.64 -1,355.34 -2,264.64 2.43 11,761 88.10 8,735.57 2,296.60 -1,353.92 -2,296.60 0,99 11.791 88.40 8,736.28 2,324.56 -1,352.68 -2,324.56 4.07 AZIMUTH 271.00 271.00 271.00 271.00 TVD VS N/S CUM E/W CUM DOGLEG 8,737.44 2.355.53 -1,351.76 -2.355.53 4.62 8,738.61 2,386.50 -1,351.22 -2,386.50 0.97 8,739.70 2.418.48 -1,350.66 -2,418.48 0.31 8.740.61 2,448.46 -1,350.13 -2,448.46 1.00 Printed: 5/13/2002 9:56:27 AM WELL NAME KENAI TYONEK UNIT 32-7H COMPANY Marathon Inlet Drilling Alaska Baker Hughes Inteq ) ) MARATHON OIL COMPANY Daily Drilling Report I GL 124 HRS PRotTMD I TVD 66.00 292.0 11,857 8,743 Page 2 of 2 1ST IKB OH 87.00 I DFS IDOL I REPT NO'1 DATE 56 57.00 59 13-May-2002 PERSONNEL DATA POB @ 06:00: SERVICE NO. HOURS COMPANY SERVICE NO. HOURS 2 40.00 M-I Drilling Fluids 3 48.00 18 238.00 Epoch Well Services 4 48.00 3 36.00 R&K Industrial 9 8.00 12.73 13.66 15.27 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (tt) TVD (tt) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 NEXT BOP TEST: WT (Ib/tt) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 LAST BOP TEST: 5/10/2002 SIZE (in) ID (in) SHOE TEST (ppç¡) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 5/17/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/13/2002 9:56:27 AM ) ) MARATHON OIL COMPANY .page 1 of"1, WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS RIH W/ZXP liner top packer assy @ 3800'. 24 HR FORECAST Set liner top packer. RIH and displace to brine. FIELD NAME I STATElPROV I COUNTY/OTHER / LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ Daily Completion Report ST I KB I GL 124 HRS PRO~TMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 I 11,857 8,743 1 14-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD JWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 D.01.G0338.CAP.CM:J 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 19,871.00 19,871.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: RIH w/polish mill. Dress top of liner. CBU. POOH. UD polish mill. PIU and RIH w/ZXP liner top packer. . ,OPERATIONS SUMMARY . .' ..",,,,,., . . """.. ......... " p.,""""" ,¡,,, . ""'''. FRÖM' .' TO" :H~S. D~PTi-"FM D~'pti-l TO . SUB' PHAsE::'·. ·.:.OP· .. . DE$C'RIPTION'" 14:00 14:30 0.50 TA CSGPR BBHD PIU 7 3/8" X 8 1/8" Polish mill. 14:30 19:00 4.50 TA CSGPR TRIP RIH w/polish mill(SLM). Circulate down to top of 7" liner. Dress top of liner. CBU. POOH. Inspect polish mill and UD(marks on upper dress mill). P/U ZXP packer. RIH w/ZXP assy (rabbit pipe). . , . . . 19:00 20:00 1.00 TA CSGPR CANDC 20:00 00:30 4.50 TA CSGPR TRIP 00:30 01:30 1.00 TA CSGPR MISC 01:30 02:00 0.50 TA CSGPR PACOP 02:00 06:00 4.00 TA CSGPR TRIP DENSITY(ppg): I 9.85 I pi=':1 IECDI11.20IMUDDATAI-:.D~!L¥Co.ST.1 ¡." FV. ..·PVNP:::: aE($WUHTHP' .Fqrr.SOL 9ILJWAT.· ~/oSandlMBTPh/PM' 47 13/30 15/18 5.2/ 1.0/9.5 3/88 /4.5 9.50/0.2 0.00 , PI/MI', 0.2/1.5 . I CµM C,OST 0.00 . , 'C1I9a ':::' ',H2S LIME:.. E~..;: 6RPM 80,000/60 15 BHA2~O"1 Œ:':i:EFF WT'IPlc~upl SLACK O;1~OT Wr'I"O~~~(~~~in) I B~ HRS IJAÂHR;;I~W~HÂS I Mi~HRSI SS:H~S . ". BHA DESCRIPTION 95/8" X 7" ZXP Packer Assy , 4 1/2" IF-P X 3 1/2"IF-B , Baker running tool. . :' , . ..,. PERSONNEL DATA : CONip~NY'. ,.' Marathon Baker Hughes Inteq Baker Oil Tools , 'S,ERVICE . NO· ..":: H()UR~' 3 24.00 3 24.00 1 16.00 ·cOMPANY: . .. ~ '.. Epoch Well Services M-I Drilling Fluids Inlet Drilling Alaska :: S.E~VIÇE '. PQa @06:QO: :., : :", NO; . .; Ho,uR~:r·· 2 16.00 1 16.00 19 140.00 LAST BOP TEST: 5/10/2002 SIZF(in) : 'ID (in)" SHOE TEST (ppg) 7.000 6.276 15.27 'CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) 1,703 (psi) @ 11.50 (ppg) 9,435 TVD (ft) 8,679 NEXT BOP TEST: WT (lb/ft)· GRADE 26.00 L-80 5/17/2002 BURST (psi). 7,240 Printed: 5/14/2002 7:13:41 AM ) ) MARATHON OIL'COMPANY . Paget.o(1.·:: \24 HRS PRO~TMD I rvD I DFS I DOL I REPT NO. DATE I 11,857 8,743 57 58.00 60 14-May-2002 I RIG PHONE AUTH MD I WBS SAPIWBS cos- 907-283-1312 11 ,637 ~D.01.G0338.CAP.DR_ 3,284,000 , MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000Q 92.2000 62,194.00 3,791,684.85 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11 ;640 (ft) 15.27 ··DailY·Drilling·Report· , . GL 66.00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR RC Lawson CURRENT STATUS Change to completion operations @ 14:00hrs 05/13/02. 24 HR FORECAST FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 7.000 (in) @ OP COMMENTS: POOH. UD directional tools. PIU polish mill assy_ RIH. .' ...,. ,. ,...., ,,'..,.,., ::::ºpeRJ.\TIONS'~PMI'.IIA~Y;·' .. .. .>"., .... ,FROM: ~!O.: HRS " DEþTH'FMQEPTtfTO:' sua:.. :,PHASE.· ·.:::·:op· :':": ',: ',: :.".:: ...: . ·D·¡;:SCFüp'nöi'J··· ' 06:00 14:00 8.00 AF DRLPRO TRIP POOH w/8.5" bit and directional assy. UD directional tools(two cones from bit lost in hole). . pENSITY(ppg) .·1 9.85 I. PP I ..... :1=',( 'PVNP.·· .GE~S '. WUHTHp, 48 13/31 15/19 5.01 . ECDI MUD DATAl DA'ILYCOST I FCIT;SOL 'dILJWAT';'" '%$andlMBT ': phipM. 1.0/9.5 3/88 14.5 9.5010.2 10,091.00 I. ·:~UM:C.OST 619,335.35 ::Pf/Mf, ';CII98:;':' H2S' ::LIMÉ' ·:::t;~.:::'~RÞM 0.2/1.5 82,000/60 15 '..,: ',. . ",' BitS.·.!. ..' . . . ;81'1' l~~N, :';:'::SiZE: ," ,MANÚF.,' ··'TYPE. :'SERIAh.~,9..:'J~ts;'6R:TFA!:: DÊpn.fïN"DATEI~'. . ':;:"'::'I~O~·[},t~:B~Ô~Ô~.R·:~:::<::· 15/1 6.125 HTC STX-R20DX2 5011345 15/15/15111 11,004.0 5/11/2002 8-8-LC-A-F- 8-SD-PR BIT I RUN WOB RPM I GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP . ..", ~: ,:' ,,".; ";1>':,,:' ·:·I·\.··~:·':ra·HA !"', ",;',' .':',: , "'," ~...,:.:..,;. "':,: . ~HA1~:!IL:'~~~; . E!* wI PICK UP', SLACkC>F1RÒT\'iT:}1TORQ0Et~';'¡n) . ..! ~HJ\HI\S dM HRS ·1 t<1WOHR~IMTiìt:iÌ'S I $siHÄà ( BHA DESCRIPTION STXR20DX2 , M1X W/1.2AKO W/6"UBHS , 6" UG NM String Stab, NMCS DP MWD Tool. Hang-Off Sub, NMCS DP (2), Cross Over, Drill Pipe (66), Cross Over, Heavy Weight Drill Pipe (4), Drilling Jar, Heavy Weight Drill Pipe (21), Cross Over A VG. CONN: MAX. CONN: "" ~::MÜD::GAS" '.' AVG. TRIP: MAX. TRIP: , . PISRSÖNNELtlAT A ·f':IO. . HÖUR~', .: :·.>C()rv'\PANY . 2 16.00 Epoch Well Services 18 72.00 R&K Industrial 3 24.00 Tomco 3 24.00 . . 'CÖMP~NY' . Marathon Inlet Drilling Alaska Baker Hughes Inteq M-I Drilling Fluids . . 'SERVICE :' LAST BOP TEST: 5/10/2002 SIZE (in) 10 (in) . SHOE TEST (ppg) 20.000 18.730 13.375 12.415 9.625 8.835 7.000 6.276 CASING SUMMARY LAST CASING TEST: 4/19/2002 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 139 139 1,018 (psi) @ (ppg) 1,517 1,517 798 (psi) @ 11.30 (ppg) 6,526 6,503 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 12.73 13.66 15.27 .. . ':I:' :~NITS:., ·1 AVG. BKGRD: MAX. DRL: o , ' . '. SERVIC.E·· .' ' POB @ .QI?:ØO.:, NO... HOURS:: 2 16.00 1 6.00 1 1.00 NEXT BOP TEST: WT (Ib/tt) GRADE 133.00 K-55 68.00 L-80 40.00 L-80 26.00 L-80 5/17/2002 BURST (psi) 3,060 5,380 5,750 7,240 Printed: 5/14/2002 7: 11 :43 AM ) ) MARATHON OIL.CO.MPANY Page.1of·2 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Prepare to displace hole to 9.8ppg brine. 24 HR FORECAST Displace hole to 9.8ppg brine. Short trip. POOH. Run liner. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ PaUy Completion Report ST I KB I GL 124 HRS PR04TMD 1 TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 I 11,857 8,743 1 1.00 2 15-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD JWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 D.01.G0338.CAP.CM;) 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000Q 92.2000 66,668.00 86,539.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: RIH w/ZXP Packer. Test seals and set packer. CBU. POOH. UD setting tool. M/U BHA. RIH to CSG shoe. CBU. RIH to TD. CBU mix brine. I . '.' .::' OP'EFÙ\TIONS SUMMARY:" . FROM .. TO ' . :HR.S· : [)EPTi.F,M DEPTH·TO.:·f:jUB PHÄSE . .. 'oP' DESC'RIPTIÒN, . 06:00 08:30 2.50 TA CSGPR TRIP Cont. RIH w/9 5/8" X7" ZXP liner top packer(rabbit all pipe). 08:30 09:30 1.00 TA CSGPR PACOP PIU 15' DP pup. M/U last DP stand. Circ. while RIH to top of liner. Seals engaged TaL @ 6299'. Sting 6' of seals into seal bore. Test seals to 500psi. 09:30 10:00 0.50 TA CSGPR PACOP Drop setting ball. 10:00 10:30 0.50 TA CSGPR PACOP Set packer w/3000psi. Ball seat blew early @3000psi. Release from packer w/12rt hand turns(new TOL@6279') 10:30 12:00 1.50 TA CSGPR CANDC CBU. 12:00 16:30 4.50 TA CSGPR TRIP POOH wet. Break UD Baker setting tool(positive indication that packer set). 16:30 17:00 0.50 AF CSGPR BBHD Measure Icaliper BHA tools. 17:00 17:30 0.50 AF CSGPR BBHD M/U BHA. 17:30 22:30 5.00 AF CSGPR TRIP RIH to CSG shoe. 22:30 00:00 1.50 AF CSGPR CANDC CBU @ CSG shoe(134units). 00:00 01:00 1.00 AF CSGPR TRIP RIH to 11,762'. Wash F/11 ,762' to 11,859'. 01:00 03:00 2.00 AF CSGPR CANDC CBU(max trip gas 1179units). 03:00 06:00 3.00 AF CSGPR CANDC Cont. circ. while mix 9.8ppg NaBr brine in pits. DENSITY(ppg) I 9.85 Fv' : 'PV/yP GEI..S 46 14/29 14/17 I PP. .ECDI11.lOl.MU[) .DATAI :DAILYCÖST 40,801.00 I CUNf,COS:: 40,801.00 WUHTHP'" ·FC/T;SOLOIIJWAT.:' :%SandlMBT· Ph/pN!.·· <Pf/Mf :CI/Ca" H2$ LIME'. ES . 6RPM 5.41 1.0/9.5 3/88 14.5 9.30/0.2 0.1/1.6 80,000/40 14 BIT I RUN MANUF. Hughes WOB RPM TYPE ATJ4 'BITS . SERIAL NO. JETS OR TFA . DEPTH IN DATEIN I-O-[)"'(-B~G-b-R M67 JD 15/15/15111 11,857.0 5/1412002 0-0------ PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BIT I RUN' SIZE 16RR9/1 6.125 GPM BHA BHA NO. I LENGTH EFF WT. ' PICK UP I SLACK OFFROT WT. I TORQUE (maximin) BHA HRS JAR HRS MWD HRS I MTR HRS I SS HRS 21 3,301.64 0 160 115 . I BHA DESCRIPTION 6 1/8" Mill tooth bit, 3 1/2"IF X 3 1/2" REG Bit sub w/float , HT-38-B X 3 1/2"IF-P , 4" 14PPF S-135 HT-38 DP (40), 3 1/2" IF-B X 3 1/2"IF-P, 3 1/2" HWDP (3), 4 3/4" Daily Jars, 31/2" HWDP (21), 31/2"IF-P X HT-38-B, 4" 14PPF S-135 HT-38 DP AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS COMPANY Marathon Baker Hughes Inteq SERVICE PERSONNEL'DATA NO. HOURS COMPANY 2 48.00 Baker Oil Tools 2 24.00 Epoch Well Services SERVICE 50 50 POB @ 06:00: NO. HOURS 1 17.00 2 16.00 1,175 A VG. BKGRD: MAX. DRL: Printed: 5/15/2002 6:52:47 AM ) ) MARATHON OIL COMPANY .Page.2·of2. CØM.PANV M-I Drilling Fluids ·Da.ily Conipletion·Report 1ST KB GL 24HRSPROtTMD OH 87.00 66.00 11 ,857 . ÞE~SONNEL DATA 'No:. . HOURS' COMPANY 16.00 Inlet Drilling Alaska . . . WELL NAME KENAI TYONEK UNIT 32-7H TVD 8,743 DFS1 I DOL I REPT NO. I DATE 1.00 2 ~ 5-May-2002 SERVICE : POB @ 06:00:' " ......".', ~ERVIC·E. .' .. .' .' NO. ,: . .HOUl~S . 20 240.00 LAST BOP TEST: 5/10/2002 .. ... . 'SIZE(in) '. 10 (in)': SHOE TEST (ppg) . 7.000 6.276 15.27 ·CASING. SUMMARY LAST CASING TEST: MAX. sicp . . .fV1D (ft)· . 1,703 (psi) @ 11.50 (ppg) 9,435 TVD (ft) 8,679 NEXT BOP TEST: 5/17/2002 WT (lb/ft)' :. :·GRADE· .' î3URs't(psi) 26.00 L-80 7,240 Printed: 5/15/2002 6:52:47 AM ) ) WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Circ. @ CSG shoe and cIa Kelly valves on TD. 24 HR FORECAST POOH run 4.5" Slotted liner. RELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ MARATHON OILCO.MPANY Daily. Completion Report·' ST KB IGL 24HRSPR04TMD ITVD IDFS IDOL REPTNO. DATe OH 87.00 66.00 I 11,857 8,743 2 2.00 3 16-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD JWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 D.01.G0338.CAP.CM=> 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 88,712.00 175,251.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/10/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 . Pa~e 1 of 2·. .... . OP COMMENTS: Circ. condo hole. Clean pits. Displace hole to 9.8ppg KCUNaBr brine. Short trip. Circ. @ CSG shoe. 08:30 12:00 3.50 AF CSGPR CANDC 12:00 14:00 2.00 AF CSGPR TRIP 14:00 16:30 2.50 AF CSGPR CANDC 16:30 18:00 1.50 AF CSGPR TRIP 18:00 21:00 3.00 AF CSGPR CANDC 21:00 01:00 4.00 AF CSGPR CANDC 01:00 03:30 2.50 AF CSGPR TRIP 03:30 06:00 2.50 TA CSGPR CANDC . ()P~RA'TIQN~,,~~MMA~Y . . , : ": pHASE: . : OP. ' . . '. ., '. <.DESêRIPTION:: .. . CSGPR CANDC Circ. and condition hole. Clean pits. CSGPR CANDC Displace hole to 9.8PPG KCUNaBr brine(calculated washout 300%)(max wiper gas 650units). Circ. hole w/9.8ppg brine(max gas 11 OOunits). Flow check. POOH to CSG shoe @ 9435'(tight spots 10,935',10,658', 10,580'-10570',10,260'). CBU @ CSG shoe. Pump 40bbl high vis sweep(max gas 450 units). RIH to 11 ,857'(tight spots 9839', 10,578', 10957', 11,080', 11,110', 11,400', 11,426'). CBU(max gas 970units). Cont. circ. and wt up brine to to 10.0ppg. Repair leaking gasket cylinder#2 pump#2. Upper kelly cock leaking. Can not get gas to come down below 100units and stay there. Flow check well. Well not flowing. POOH to CSG shoe(tight @ 11,490',9830',9489'). Circ. @ CSG shoe with reduced rate while cIa upper and lower kelly cock assy on top drive(upper kelly failed test after C/O)(max gas 493units but came down @ BIU to 30 units) .. ..' \'". . . . i. . FROM :·TO·· HRS ;"DEPTH ¡:riIIDE.PT~TO·SUB· 06:00 06:30 0.50 AF 06:30 08:30 2.00 AF ':.DF~~ITY(ppØ): I . . 10.05 1":flP I .:: fy:.pV(YP : GELS: "WLlHTHP 27 1/1 / I I·ECP. I MUD:.DATAI·ï)AI~Y~CÓsT·1 i=Cff;SOL.:. ',. ,"OIUWAT::;' %SançliMBT,:" :1 ,. .Ph/p;",: /13.0 188 7.001 25,000.00 '1. pf/Mf:' I I.CµM gOST " 65,801.00 C~¢"ä::.::;': 'H2S:LlM~ :':E$:: 6ÂPM 122,000 160 1 BIT1RUN. . ~ SIZE MANUÞ; :TY·P·E.·: ' 9RR 11 6.125 Hughes ATJ4 BIT I RUN WOB RPM GPM BiTS ," . .....:' . , . : ':SERIAL NO.: 'JETS OR TFA . :'DEPTH ,N' DATE IN., ·1-O-()~l'..B":G-O~R M67JD 15/15/15111 11,857.0 5/14/2002 2-3-WT-A-E- I-NO-TD PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP '. . BHA' . I;3HAN6."LENC3TH ËFFWT. PiCKuP SLAC.KOF1ROTW;. ,/TORQUE(maxlmin) BHAHRS JARHRS IMWDHRS'/MTRHRS SS HRS 21 3,301.64 0 175 110 I BHA DESCRIPTION 61/8" Mill tooth bit, 3 1/2"IF X 31/2" REG Bit sub w/float , HT-38-B X 3 1/2"IF-P , 4" 14PPF S-135 HT-38 DP (40), 3 1/2" IF-B X 3 1/2"IF-P , 3 1/2" HWDP (3), 4 3/4" Daily Jars, 31/2" HWDP (21), 3 1/2"IF-P X HT-38-B ,4" 14PPF S-135 HT-38 DP COMPANY Marathon Epoch Well Services M-I Drilling Fluids Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. . HOURS COMPANY 2 48.00 Baker Oil Tools 2 48.00 Rand K industrial 1 24.00 Swacco 20 240.00 SERVICE POB @ 06:00: NO. HOURS 1 2.00 3 30.00 1 12.00 Printed: 5/17/2002 2:01 :25 PM ) ) MARATHON OIL COMPANY Page·2Óf:·2 - WELL NAME KENAI TYONEK UNIT 32-7H . Daily' Com pletion Report- 1ST IKB IGL OH 87.00 66.00 124 HRS PRO~TMD ITVD DFS2 I 11,857 8,743 I DOL I REPT NO. I DATE 2.00 3 ~ 6-May-2002 LAST BOP TEST: 5/10/2002 . ·SIZE.(in) . .ID (in)'.' SHOE TEST (ppg) 7.000 6.276 15.27 CASING· SUMMARY· LAST CASING TEST: NEXT BOP TEST: 5/17/2002 . MAX SICP MD' (ft) . 1VD (tt) . 'WT' (Ib/tt) ·GRADE:··· BURST (psi):' 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 26.00 L-80 7,240 REQOtREME:NTS' Could not get gas to go below 1 OOunits while circulating horizontal section. The higher the pump rate the more gas seemed to come to the surface. Raised mud wt with no better results. Flow checked well. Well was not flowing. Pulled to shoe with well taking proper fill. Easily circulated gas out on first bottoms up. Printed: 5/17/2002 2:01 :25 PM .) ) MARATHON OIL COMPANY . ',. .' Page.1·0f. ( WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Run 4 1/2" Slotted liner @ 9500' @ 06:00hrs. 24 HR FORECAST Run 4.5" slotted liner. Set packer. POOH UD DP. Run TBG. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 7.000 (in) @ . Daily Completion Repott ST KB GL 24HRSPR04TMD ITVD IDFS IDOL REPTNO. DATE OH 87.00 66.00 I 11,857 8,743 3 3.00 4 17-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD JWBS SAPIWBS COS- GLACIER DRILLING 1 907-283-1312 11,637 D.01.G0338.CAP.CM:) 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 40,609.00 215,860.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/16/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 9,435 (ft) 4.500 (in) @ 11,640 (ft) 15.27 OP COMMENTS: CBU @ CSG shoe. POOH to 5300'. CIO TD kelly cock assy. Cont. POOH and BIO 61/8" bit. RlU and run 41/2" slotted liner assy. . . .FROM 10' 06:00 07:30 07:30 10:30 10:30 13:00 13:00 16:00 16:00 18:30 18:30 19:00 19:00 23:00 23:00 00:30 00:30 01 :30 01 :30 06:00 H~S 1.50 3.00 2.50 3.00 2.50 0.50 4.00 1.50 1.00 4.50 Á ' OPER~TI:ONŠ S~I'v1MARX':::':' ; DEPTH F'MDE·PTHTO. ~UB:.. .': PHASE·: ,OP " AF CSGPR CANDC AF CSGPR TRIP TA CSGPR RRCO AF CSGPR TRIP AF CSGPR RSCL AF CSGPR SAFE AF CSGPR RSCL AF CSGPR RSCL AF CSGPR RSCL AF CSGPR RSCL : .1 " ...·DESCRIPTION ..' ' CBU @ CSG shoe. POOH to 5300'. C/O TD kelly cock assy and test 250/3000psi 5min. Cont. POOH. R/U long bales and CSG elevators. Pull wear bushing. PJSM. Run 4.5" 12.6PPF L-80 IBT/521 Hydrill slotted liner assy. cIa to short bales and DP elevators. P/U Baker Packer assy and M/U. RID Weatherford tong. RlU DP tongs. Run 41/2" slotted liner assy on 4 " DP(run 24 Jnts 3.5" HWDP from derrick, UD jars and 1Jnt HWDP). 'DENSITY(ppgf I 10.05 I"PP, I ECD I IM.úD· DATAl DA.ILY COST' '. :FV,' . PYNP' . qELS, . :,WUHTHP FÇIT~SOL, ··,>OIUWAT'· '<!D/oS'andJMB:I:" '::'P~/pM 27 11 I I 113.0 187 I 7.001 .: ,,". SiT I ~l.IN.· ' , SiZE. 9RR 11 6.125 BIT I RUN 8,185.00 ': P.f/Mf . . I I 'C~M COST 73,986.00 : C"C~ " . ¡ H2S . LIME: . ··E5':·:. ..6RPM' 114,000 I . MANUF. Hughes WOB RPM , . . :.' ,TYPE: ATJ4 ",. ..,l3rr~. , '$,E.RI~L NÖ.~: ," .~ETSOR TFÄ. DEPTH. IN DATE IN . " I~Ó~'[).:L~B~ci.o-R M67JD 15/15/15111 11,857.0 5/14/2002 2-3-WT-A-E-I-NO-TD PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP GPM . ... , . '.': BHA BHA2iO'IL:~~.~~ liFF m: IpibKUPISLACK OFtROTwr. I TORQUE(~aximi~) I BHAH~S I ~ARHR$ I MWD HFÍS MTR HRS ¡5S H~S BHA DESCRIPTION 61/8" Mill tooth bit, 31/2"IF X 31/2" REG Bit sub w/float, HT-38-B X 3 1/2"IF-P, 4" 14PPF S-135 HT-38 DP (40), 3 1/2" IF-B X 3 1/2"IF-P , 3 1/2" HWDP (3), 4 3/4" Daily Jars, 3 1/2" HWDP (21), 3 1/2"IF-P X HT-38-B ,4" 14PPF S-135 HT-38 DP CASING SUMMARY LAST CASING TEST: MD(ft) TVD(ft) 1,703 (psi) @ 11.50 (ppg) 9,435 8,679 REQUIREMENTS Recieved exemption on 05/16/2002 from Winton Abert w/AOGCC to finish running completion with out BOP test 05/17/02. COMPANY Marathon Epoch Well Services M-I Drilling Fluids Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 48.00 Baker Oil Tools 2 48.00 Rand K industrial 1 24.00 Weatherford 18 228.00 , POB . @ 06:00: NO. HOURS 1 20.00 2 24.00 2 24.00 SERVICE LAST BOP TEST: 5/10/2002 SIZE (in) ID(iriY $HOETE$T(ppg) 7.000 6.276 15.27 NEXT BOP TEST: WT(lblft) GRADE 26.00 L-80 5/17/2002 BURSt (psi) . 7,240 Printed: 5/17/2002 7:02:15 AM ) ) 'MARA THON' OIL CO.MPANY Page r of: 1 . . , ·Daily.Completion Report ST I KB I GL 124 HRS PRO~TMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 I 11,857 8,743 4 4.00 5 18-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD JWBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 D.01.G0338.CAP.CM;:) 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000q 92.2000 54,852.08 270,712.08 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/16/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 11,806 (ft) (in) @ 0 (ft) 15.27 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS Running 4.5" Production TBG. 24 HR FORECAST Run TBG. Space out and land hanger. NID BOP NIU tree. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: Run 41/2" slotted liner. Set packer. Release flpacker and CBU. POOH UD DP. R/U TBG running tools. Run 4.5" production TBG. FRQM' Tq,.·· !:iRS' 06:00 08:30 2.50 08:30 09:00 0.50 09:00 10:00 1.00 ", ,".. . .. . .. . .: '.' .' , '" ,,'," .. '. .', " . . ... I:. .' \ ~ -.: DËPTH' FM DEPiHro SUB: AF AF AF 10:00 12:00 2.00 12:00 01 :00 13.00 01 :00 03:00 2.00 03:00 06:00 3.00 AF AF AF AF :'.',()~ERATIONS..SUMMARY.· ' : ,.:.::: ^ ,".,.:.....: ." ,. . . PHASE'. ':·',"'OP:- .. . . PESÇRIPTIÓN.. CSGpR RSCL Run 41/2" slotted liner on 4" DP to 11806'. CSGPR PACOP Drop ball and chase wlmud pump. CSGPR PACOP Pressure up to 3000psi w/mud pump. Increase pressure to 4200psi wltest pump to set 7" Baker Premier Packer. Attempt to shear ball seat w/5200psi. Seat did not shear. Release pressure from DP. Close, annular and pressure up to 500psi on annulus wlDP open. Packer seal held OK. Release from packer and P/U. CBU from above packer(max gas 1800units @ B/U). POOH UD DP. cIa to long bales. R/U Weatherford TBG running tools. PJSM. Run 4.5" 12.6PPF BTC-MOD L-80 TBG(50Jnts of 233 total in hole). . . CSGPR CANDC CSGPR LDDP CSGPR PRPT CSGPR PRPT .~~~~~TY.(P~9) ·1 10.05 I ¡~p.·1 , " I ~qD·1 .. I MUD:'PATAI·DAIL'(:COST:' '.q:y.:: 'PV/Vp' :G'EL$'" WLJH11':t"Þ, .: .FCIT.SOL,C)I~ÅT·::· :!:-'<Y~S,~nd/MBT.··· : PhïpM 27 11 I I 113.0 187 7.001 .ï '\ I": .. "COMPANY:' ,'.,: Marathon Epoch Well Services M·I Drilling Fluids Inlet Drilling Alaska . II;' J : SEijVICE: . LAST BOP TEST: 5/10/2002 SIZE (in) ID (in) SHOE TEST (ppg) 7.000 6.276 15.27 4.500 3.958 15.27 625.00 Pf/Mf·:· I I·COM:'CO~T 74,611.00 ÓI/Cä":" ':·H2S:· ."tIME:"'.i:S::,6RPIIÎI: 114,000 I '. PE~~ÖNNELD~TA'I' . " . -NO.) ,.''"HÓqRS' . ,'. 'CbMPA~V:,::- 2 48.00 Baker Oil Tools 2 48.00 Rand K industrial 1 24.00 Weatherford 18 228.00 Sand R '.'. PQS @·:"Oß:OO::.· ..:' SEÄvIC,e: '," '. Nä ..' -: H()I,i~s . 1 20.00 2 24.00 2 24.00 2 20.00 CASINGSUMMARV LAST CASING TEST: MAX SICP MD (ft) 1,703 (psi) @ 11.50 (ppg) 9,435 1,703 (psi) @ 11.50 (ppg) 11,806 TVD (ft) 8,679 8,743 NEXT BOP TEST: WT (Ib/tt) GRADE 26.00 L-80 12.60 L-80 5/17/2002 BURST (psi) 7,240 8,350 Printed: 5/18/2002 10:02:20 AM ) ) DAILY WELL OPERATIONS REPOk I MARATHON OIL COMPANY DATE: 5/19/2002 FILL DEPTH/DATE: 9350' X-Nipple DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: WBS # TOOL STRING: " KJ, 3' R Stem, KJ, 3' Stem, KJ, 3' R Stem, KJ, 3' stem, KJ, 3' R. Stem, OJ, Hrs. WIRELlNE CREW: Biggs/Doherty/Doherty PROD: RSO #: 455-864 SUMMARY OF OPERATIONS 19:00 Arrived @ KGF Office, checked in 19: 15 Moved equipment to Rig 19:30 Checked in @ Rig Office, attended Rig safety meeting, discussed procedure w/ Rowland and Rig crew 20:30 R/U W/L, twist test - 23,22 & 23 - good 22:00 P. T. Lub to 1000 # - good 22:30 RIH w/ 3.88" GR, sat down @ 4400', beat free, POOH 23:30 RIH w/3.81 GR to X-Nipple @ 9350', POOH 24:00 Continue on next day FIELD: TUBING: New Well Set PX Plug In progress Kenai Gas Field 4 1/2" WELL #: KTU 32-7 H CASING: TREE CONDITION: WIRE TEST: New' 23, 22 & 23 DD.01.G0338.CAP.CMP 12 DRILL: X Ticket #: P-166 Vendor Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Equipment 12 hr min 2.88" Gauge Ring 3.81" Gauge Ring Roller Stem Daily Cost $2,080.00 $50.00 $50.00 $200.00 Cumulative Cost $2,080.00 $2,130.00 $2,180.00 $2,380.00 DAILY COST: $2,380.00 CUM: REPORTED BY: Rowland Lawson ) ) MARATHON Oil COMPANY Page 1 of 1 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS N/U tree and clean pits. 24 HR FORECAST N/U tree and test. Clean pits and release rig. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 4.500 (in) @ Daily Completion Report ST I KB I GL 124 HRS PROtTMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 11,857 8,743 5 5.00 6 19-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS COS- GLACIER DRILLING 1 907-283-1312 11,637 ~D.01.G0338.CAP.CM::I 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 176,564.00 473,776.08 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/16/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 11,806 (ft) (in) (Q>. 0 (ft) 15.27 OP COMMENTS: Run and land 4.5" Production TBG. Test annulus to 1000psi. Set BPV. N/D BOP. N/U tree. FROM TO HRS DEPTH FM DEPTH TO SUB OPERATIONS SUMMARY PHASE OP DESCRIPTION PRPT Cont. RIH w/41/2" 12.6PPF L-80 IBT Production TBG(183joints of 232 jnts total). PRPT M/U chemical injection mandrel. PJSM with crew coming on. RIU control line running equipment. Install control line to mandrel and test. PRPT Cant. RIH w/Production TBG banding control line to tubing(1 03 bands). PRPT Space out w/2-6'pups below top joint. M/U Vetco TBG hanger and landing joint. Terminate control line. R/U circulating hose and circulate packer flu'd long way into the annulus. Land TBG hanger. TESTOT Pressure up on annulus and test to 1000psi/5min. UD landing joint. Set BPV. TESTOT RID Weatherford. MISC Flush and blow down lines. NDNUW NID BOP. NDNUW N/U Tree. 06:00 11 :30 5.50 AF RCMP 11:30 12:30 1.00 12:30 16:30 4.00 16:30 21:00 4.50 21:00 23:00 2.00 23:00 00:00 1.00 00:00 01:00 1.00 01:00 05:00 4.00 05:00 06:00 1.00 DENSITY(ppg) 10.05 I PP I FV PVIYP GELS WLlHTHP 27 11 AF RCMP AF AF RCMP RCMP AF RCMP AF RCMP AF RCMP AF RCMP AF RCMP IECDI ¡MUD DATAl DAILY COST I FCIT.SOL OILIWAT %Sand/MBT Ph/pM 113.0 /87 7/ 625.00 Pf/Mf I CUM COST 75,236.00 CIICa H2S LIME ES 6RPM 114,000 I COMPANY Marathon Epoch Well Services M-I Drilling Fluids Inlet Drilling Alaska Baker Oil Tools SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 48.00 Rand K industrial 2 48.00 Weatherford 1 24.00 Sand R 18 228.00 Weaver 1 20.00 Vetco SERVICE POB @ 06:00: NO. HOURS 2 24.00 2 24.00 2 20.00 1 10.00 2 48.00 LAST BOP TEST: 5/10/2002 SIZE (in) 10 (in) SHOE TEST (PPQ) 7.000 6.276 15.27 4.500 3.958 15.27 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) 1,703 (psi) @ 11.50 (ppg) 9,435 1,703 (psi) @ 11.50 (ppg) 11,806 TVD (ft) 8,679 8,743 NEXT BOP TEST: WT (lb/ft) GRADE 26.00 L-80 12.60 L-80 5/17/2002 BURST (psi) 7,240 8,350 Printed: 5/20/2002 9:04:19 AM ) ) DAILY WELL OPERATIONS REPOkf MARATHON OIL COMPANY DATE: 5/20/2002 FILL DEPTH/DATE: 9350' X-Nipple DATE LASTWL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELlNE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS 00:50 Continued from 5-19-02, RIH w/ 3.813" PX Plug Body to 9350', set, POOH 03:30 RIH w/ P Prong to 9350', set, POOH 04: 15 R/D W /L, made report FIELD: TUBING: 5/19/2002 Set 3.813" PX Plug Complete Kenai Gas Field 4 1/2" CASING: TREE CONDITION: WIRE TEST: Same as 5-19-02 Biggs/Doherty/Doherty WBS# Hrs. PROD: NOTE: 10 # Fluid in hole 55 degree deviation Use of Roller Stem advised Vendor Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Equipment 4" X-line Running Tool 3" SB Pulling Tool 12 hr min Roller Stem 3.813" PX Plug (1 st day) Daily Cost $250.00 $100.00 $2,080.00 $160.00 $400.00 DAILY COST: $2,990.00 REPORTED BY: CUM: WELL #: KTU 32-7 H New N/A DD.01.G0338.CAP.CMP 12 DRILL: X Ticket #: P-167 Cumulative Cost $250.00 $350.00 $2,430.00 $2,590.00 $2,990.00 Rowland Lawson I) '') J MARATHON OIL COMPANY Page 1 of 1 Daily Completion Report ST I KB I GL 124 HRS PROtTMD I TVD I DFS I DOL I REPT NO. DATE OH 87.00 66.00 11,857 8,743 6 6.00 7 20-May-2002 RIG NAME & NO. I RIG PHONE AUTH MD I WBS SAPIWBS cos- GLACIER DRILLING 1 907-283-1312 11,637 d>D.01.G0338.CAP.CM;) 653,300 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.000d 92.200C 34,106.00 507,882.08 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 5/20/2002 5/10/2002 I NEXT CASING LEAKOFF PPG 11,806 (ft) (in) @ 0 (ft) 15.27 WELL NAME KENAI TYONEK UNIT 32-7H SUPERVISOR R CLawson CURRENT STATUS 24 HR FORECAST Riq released to KU21-7 WO i 06:00hrs OS/20/2002. FIELD NAME STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai BorouQh 4.500 (in) @ OP COMMENTS: N/U tree. Test tree void OK. Tree test failed. RIU WL. Set plug in X-nipple @ 9350'. R/D wireline. Set BPV. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 07:30 1.50 07:30 08:00 0.50 08:00 11 :00 3.00 11 :00 16:30 5.50 16:30 18:00 1.50 TA 18:00 19:30 1.50 TA 19:30 22:00 2.50 TA 22:00 22:30 0.50 TA 22:30 00:30 2.00 TA 00:30 04:00 3.50 TA 04:00 05:30 1.50 TA 05:30 06:00 0.50 TA AF TA TA OPERATIONS SUMMARY PHASE OP XMBO NDNUW NU tree. Set TWC. XMBO TESTEQ Test tree void to 5000psi. Test tree to 5000psi failed. Pull TWC set BPV. XMBO TESTEQ N/D tree. Seal on seal sleeve between hanger neck and adaptor flange failed. Replace seal and N/U tree. Pull BPV and install TWC. Test failed. Pull TWC and install BPV. XMBO TESTEQ N/D tree and wrap teflon around o-ring grooves in seal sleeve to get more o-ring surface area on seal face. N/U BOP. Pull BPV and set TWC. Test tree. Seals failed. Pull TWC and set BPV. N/D tree. Call in dimensions of sealing ares to Vetco Engineer. All dimensions are in spec with drawing but seal sleeve is looser than expected in hanger neck. XMBO TESTEQ N/U tree. Install TWC. Test tree wlo seal sleave to 250/5000psi 10min(th's test ring gasket between tubing head and tree,and seal on outside of hanger). Remove BPV. Begin to RID rig while wait on Pollard WL. PJSM prior to RIU Pollard WL. RIU WL. Fill lubricator and test to 1000psi. Run 3.81" gauge to 9350', POOH. PJSM with crew coming on. RIH and set 3.81" plug in X-nipple @ 9350', POOH. RIH and set 2" prong in plug, POOH. RID Pollard wireline. Set BPV. DESCRIPTION TA XMBO XMBO XMBO XMBO XMBO RDMO WLlN WLlN WLlN WLlN XMBO XMBO WLlN WLlN During last 24hrs dismanted pump engine cooling system in preperation for modification. DENSITY(ppg) FV PVNP 27 11 10.05 I PP I GELS WLlHTHP Rig released to KU21-7WO @ 06:00hrs OS/20/2002. ECD ¡MUD DATAl DAILY COST I 625,00 I CUM COST 75,861.00 FCIT.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf Cl/Ca H2S LIME ES 6RPM /13.0 187 71 114,000 I COMPANY Marathon Inlet Drilling Alaska Rand K industrial SERVICE LAST BOP TEST: 5/10/2002 SIZE (in) 10 (in) SHOE TEST (ppq) 7.000 6.276 15.27 4.500 3.958 15.27 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Weaver 18 228.00 Pollard WL 1 6.00 Vetco POB @ 06:00: NO. HOURS 1 10.00 3 31.50 2 36.00 SERVICE CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) 1,703 (psi) @ 11.50 (ppg) 9,435 1,703 (psi) @ 11.50 (ppg) 11,806 NEXT BOP TEST: WT (lb/ft) GRADE 26.00 L-80 12.60 L-80 5/17/2002 BURST (psi) 7,240 8,350 TVD (ft) 8,679 8,743 Printed: 5/20/2002 9:04:39 AM ) DAILY WELL OPERATIONS Rt:.r-¿RT PAGE 1 OF 1 MARATHON OIL COMPANY DATE: 5/23/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: TUBING: Kenai Gas Field 4.5", 12.6 ppf CASING: TREE CONDITION: BENCHES OPEN: WIRELlNE CREW: Hrs. WELL #: KTU 32-7h 9-5/8", 40# new repair tree Moore 4 SUMMARY OF OPERATIONS Pull BPV, set 2-way check. ND tree and tubing head adaptor. Replace faulty tubing head bushing. NU tubing head adaptor and tree. Pressure test void to 5000 psi. Pressure test tree to 5000 psi. Pull 2-way check. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: Greg Ruge (ASS Vetco) DATE: 5/27/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELlNE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS 07:30 Load Truck, depart Shop 08:00 Arrive @ KGF, hold safety meeting 08:30 Started equipment, moved equipment to Pad 09:00 Start RIU 10:30 R/U, await Hydro Pump 11 :40 RIH wi 3.72 Centralizer & 3" JDC to 9320', latched and pulled Prong, POOH 13:40 RIH wi Daniels KOT & 1 5/8" Daniels PIT to 1958', wit, no latch, POOH 14:25 RIH wi same wi Knuclke Joint above KOT to 1958', wit, no latch, POOH, Tool sheared 15:00 RIH wi same to 9320', latched and pulled Dummy Valve 15:20 RIH wi Injection Valve to 1958', set Valve, POOH 15:50 RIH w/3 1/2" GS to 9324', latched Plug, Plug stuck, wit for 1 hr, Plug came free, POOH 18:00 OOH, started RID 19:30 Travel back to Shop MARATHON OIL COMPANY Tool Cost: Roller Stem 3" JDC Daniels KOT 1 5/8" JDC 3 1/2" GS Vendor Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. DAILY COST: $4,413.00 ) ') DAILY WELL OPERATIONS REPOkf NIA FIELD: TUBING: CASING: TREE CONDITION: WIRE TEST: Good 22 Kenai Gas Field 41/2" WELL #: KTU 32-7 H Pull Plug, pull & set Valve Complete RS, KJ, 12' R. Stem, KJ, OJ, Stem D. PollardlTi. Doherty/Th. Doherty WBS# Hrs. PROD: DD.01.G0338.CAP.CMP 12 DRILL: Ticket #: P-168 $200.00 $100.00 $300.00 $75.00 $200.00 Equipment 12 hr min PX Plug 4 days @ 200.00 Tools Fuel Daily Cost $2,080.00 $800.00 $875.00 $58.00 Cumulative Cost $2,080.00 $2,880.00 $3,755.00 $3,813.00 CUM: REPORTED BY: Rowland Lawson ) MARATHON OIL COMPANY ) DAILY WELL OPERATIONS REPORT DATE: 5/30/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: TUBING: Kenai Gas Field WELL #: 4.5", 12.6# CASING: TREE CONDITION: WIRE TEST: KTU 32-7h 9-5/8", 40# New initial unload following completion WBS # DD.01.G0338.CAP.CMP HRS PROD: X DRILL: SUMMARY OF OPERATIONS 5/28/02 - MIRU 1.75" BJ coil tubing. RU flowback iron. SDFN. Ticket #: 5/29/02 0800 Finish RU flowback iron. Held prejob safety meeting. Pressure test coil tubing BOPE to 300/3500 psi. Pressure te$t flowback iron to 300/3500 psi. 1615 RIH with coil tubing to 500'. Pump nitrogen at 500 scfm. Took a while to get returns to the gas buster. Once returns established, RIH circulating nitrogen at 500 - 1000 scfm. A nitrogen rate of 750 scfm seems best able to lift the 10.0 ppg completion fluid. RIH to 10,100' CTM circulating at 750 scfm. Getting some gas influx, but appears pretty weak. Wellhead pressure ranges from 100 psi to 400 psi on a constant choke setting. Circulate nitrogen at 750 scfm at 10,100' until we run out of nitrogen (unable to get more nitrogen because the nitrogen plant is down). POOH with well continuing to blow. Total liquid recovery = 262 bbl, compared to an "ideal" hole volume of 221 bbl. (The "ideal" hole volume is to the TO of the well assuming a gauge open hole section.) Caught sample of the later flowback fluid, which weighs 9.94 ppg. 2330 Shut in the swab valve, open the wing valve to take returns through the flowback iron. Well was shut-in less than 5-minutes during change-over. Flow well on an 18/64" positive choke with 150 psi flowing tubing pressure (caluc;lated rate = 275 mcfd). Continue to flow until 0230 hrs (5/30/02) when it is no longer showing any signs of building, then shut the well in. At 0600 hrs, SITP = 600 psi. Vendor BJ Coiltech Veco PTS Misc. Misc. Equipment coil, nitrogen crane, vac truck, labor flowback hands trucking misc. equipment DAILY COST: $60,911.96 CUM: Daily Cost $41,313.96 $2,484.00 $3,176.00 $4,315.00 $9,623.00 Cumulative Cost REPORTED BY: Gary Eller ) ') MARATHON OIL COMPANY DAilY WEll OPERATIONS REPORT DATE: 5/31/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: TUBING: Kenai Gas Field WELL #: 4.5", 12.6# CASING: TREE CONDITION: WIRE TEST: KTU 32-7h 9-5/8", 40# New initial unload following completion WBS # DD.01.G0338.CAP.CMP HRS PROD: X DRill: SUMMARY OF OPERATIONS 0600 Well KTU 32-7h is shut-in to build pressure. (5/30 ) 1000 SITP = 1050 psi. Open well to flow on an 18/64" choke. Ticket #: 1200 Flowing tubing pressure is down to 200 psi. Has not produced any water. Shut well in. 1830 SITP = 1000 psi. Open well to flow on an 18/64" choke. 2030 Flowing tubing pressure is down to 200 psi. Has not produced any water. Shut well in. 0330 SITP = 1000 psi. Open well to flow on an 18/64" choke. (5/31 ) 0530 Flowing tubing pressure is down to 200 psi. Has not produced any water. Shut well in. 0600 SITP = 350 psi at report time. Summary: Blew well down three times from 1000 psi to 200 psi. Blowdown took 2 hours each time, and the buildup to 1000 psi took about 7 hours each time. Not showing any improvement over time. Vendor Equipment Daily Cost Cumulative Cost Veco crane, vac truck, labor PTS flowback hands $4,029.00 DAILY COST: $4,029.00 CUM: REPORTED BY: Gary Eller ) ') MARATHON OIL COMPANY DAilY WEll OPERATIONS REPORT DATE: 6/7/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: TUBING: Kenai Gas Field WELL #: 4.5", 12.6# CASING: TREE CONDITION: WIRE TEST: KTU 32-7h 9-5/8",40# New jet well Phill Rafferty (BJ Coiltech) WBS # DD.01.G0338.CAP.CMP HRS PROD: X DRill: SUMMARY OF OPERATIONS Ticket #: 6/5/02 - MIRU 1.75" BJ coil tubing. Will take returns to the diffuser tank. SDFN. Produced well on an 18/64" choke from 0800 hrs to 1600 hrs. SITP began at 1600 psi, but well blew down and flowed all day at 100 psi. Shut well in at 1600 hrs. 6/6/02 0600 Held prejob safety meeting. Pressure test coil tubing BOPE to 300/3500 psi. Pressure test flowback iron to 300/3500 psi. SITP = 1575 psi. Well has been shut-in since 1600 hrs on 6/5/02. 0930 Blew well down. RIH with coil tubing to 11,750' without circulating. Began circulating nitrogen at 1000 scfm. Pump pressure = 1600 psi when nitrogen turned the corner. Wellhead = 0 psi. POOH slowly with coil while continuing to jet. 1250 Stop coil at 10,315'. Still no returns to surface, and pump pressure has increased to 2400 psi. Have pumped 134,000 cf of nitrogen. Continue to POOH with coil. Finally got returns to surface when coil reached 9600'. Continue to POOH to 9100', and cut nitrogen rate to 750 scfm. Have recovered 53 bbl from well bore (no way to sample fluid with existing flowback iron). 1430 RIH with coil to 11,600', continuing to circulate nitrogen at 750 scfm. Pump = 1000 psi, wellhead = 350 psi. POOH jetting. Continue jetting up to 7300', and turn off nitrogen. Total fluid recovery increased to 60 bbl and quit. Pump = 760 psi, wellhead = 175 psi. POOH, allowing well to continue venting. 1900 RDMO coil tubing. Well producing on an 18/64" choke with 75 psi FTP. Shut well in at 2000 hrs on 6/6/02. Vendor BJ Coiltech Veco Equipment coil, nitrogen crane, vac truck, labor Daily Cost Cumulative Cost Misc. misc. equipment DAILY COST: $0.00 CUM: REPORTED BY: Gary Eller ) ') MARATHON OIL COMPANY CAlLY WELL OPERATIONS REPORT DATE: 6/10/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: TUBING: Kenai Gas Field WELL #: 4.5", 12.6# CASING: TREE CONDITION: WIRE TEST: KTU 32-7h 9-5/8" 40# New flow well to atmospheric tank WBS # DD.01.G0338.CAP.CMP HRS PROD: X DRILL: SUMMARY OF OPERATIONS 6/7/02 Well was left shut-in until 11 00 hrs on 6/7/02. Ticket #: 1100 Opened up well on an 18/64" choke. SITP = 1300 psi. Took a couple hours to blow down. Installed SPIDR gauge, continued to produce well for the remainder of the day on an 18/64" choke with 100 psi FTP. 6/8/02 Produce well all day on an 18/64" choke with 100 psi FTP. 6/9/02 Produce well all day on an 18/64" choke with 100 psi FTP. 6/10/02 Produce well on an 18/64" choke with 100 psi FTP. Downloaded SPIDR gauge and sent to Anchorage. Continued to produce well throughout the day. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: $0.00 CUM: REPORTED BY: Gary Eller ) ) DAILY WELL OPERATIONS REPOk f MARATHON OIL COMPANY DATE: 6/25/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELINE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS Ticket #: 14:30 Started RIU on 32-7H, RIU Roller Stem and Lead Stem for High Angle Flowing Well 15:45 RIH wi 2.81 GR to 9528' MD, POOH 17:37 RIH wi Tandem Elect. Gauges, moving 150' a min to 9500' 19:01 POOH making stops for Flowing Survey 22:15 OOH, download Gauges 22:40 Start RID 23:30 Depart Field 24:00 Arrived @ PWL Shop NIA FIELD: TUBING: NIA Flowing Survey Complete Kenai Gas Field 4 1/2 WELL #: KTU 32-7H 13 3/8 Good 22 CASING: TREE CONDITION: WIRE TEST: RS ,ABU, R Stem, L. Stem, RStem, L.Stem ,KJ, RStem ,R Stem, KJ, OJ ,SA D. Pollard/Ti. Doherty WBS# Hrs. PROD: DD.01.G0338.CAP.CMP 10 DRill: P-181 Tool Cost: Shock Absorber Anti-blowup Lead Stem Roller Stem Tandem Gauges 2.81 Gauge Ring $50.00 $50.00 $150.00 $200.00 $800.00 $50.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 5 of 12 hr min $762.50 $762.50 Pollard Wireline Inc. 5 add hrs $625.00 $1,387.50 Pollard Wireline Inc. Tools $1,300.00 $2,687.50 Pollard Wireline Inc. Fuel $21.91 $2,709.41 Pollard Wireline Inc. DAILY COST: $2,709.41 CUM: REPORTED BY: Wayne Cissell ) ) DAILY WELL OPERATIONS REPOk r MARATHON OIL COMPANY DATE: 6/27/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELlNE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS 12:30 Moved equipment on Pad 12:45 Start R/U 14:01 Start Gauges, RIH to 9500', set 30 min 16:03 Start, POOH @ 150' a min, make stops 19:00 OOH, download Gauges, data - good 19:30 Start R/D 20: 15 Start moving equipment back to Bull Rail 20:40 Depart field 21 :00 Arrived @ Shop FIELD: TUBING: Kenai Gas Field 4 1/2" WELL #: KTU 32-7H 13 3/8" Good 22 Static Survey Complete CASING: TREE CONDITION: WIRE TEST: (1.5") RS, KJ, R. Stem, KJ, OJ, SA D. PollardlW atson WBS# Hrs. PROD: DD.01.G0338.CAP.CMP 9 DRILL: Ticket #: P-183 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. 6 of 12 hr min $915.00 $915.00 Pollard Wireline Inc. 3 add hrs $375.00 $1,290.00 Pollard Wireline Inc. Tandem Gauges $800.00 $2,090.00 Pollard Wireline Inc. Shock Absorber $50.00 $2,140.00 Pollard Wireline Inc. Roller Stem $200.00 $2,340.00 DAILY COST: $2,340.00 CUM: REPORTED BY: S. Bookey · <. ~""-:I A ¡:;-;:¡ C ~_JL_1 -) : f Ã~i,~~l OFFICE OF THE GOVERNOR OFRCEOFMANAGEMENTANDBUDGET DIVISION OF GOVERNMENTAL COORDINATION ) TONY KNOWLES, GOVERNOR CJ SOUTHCENTRAL REGIONAL OFFICE 550 W 7TH AVENUE, SUITE 1660 ANCHORAGE, ALASKA 99501 PH: (907) 269-7470/FAX: (907) 269-3981 LJ CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562/FAX: (907) 465-3075 IJ PIPELINE COORDINATOR'S OFFICE 411 WEST 4TH AVENUE, SUITE2C ANCHORAGE, ALASKA 99501-2343 PH: (907) 271-4317/FAX: (907) 272-3829 February 13,2002 Charles A. Underwood, Jr. Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519 SUBJECT: REVIEW NOT REQUIRED KBU-41-7X and KTU 32-7H ~D~-OàS- \ ... t;>Od-a"-\ ~ Dear Mr. Underwood: The Division of Governmental Coordination (DGC) reviewed the Coastal Project Questionnaire (CPQ) and other information regarding the above referenced project. Based upon the information you provided, your proposed project does not require a state review for consistency with the Alaska Coastal Management Program (ACMP). You are not relieved from obtaining required permits and approvals from state, federal or local agencies, before you begin the proposed work. Nothing in this letter excuses you from compliance with other statutes, ordinances, or regulations that may affect any proposed work. This decision is ONLY for the proposed project as described. If there are any changes to the proposed project, including its intended use, prior to or during its siting, construction, or operation, contact this office immediately to determine if further review and approval of the revised project is necessary. Thank you for your cooperation with the ACMP. Si~erely,.. / -;;",: "f- ~~ï4Y~t7'- Kaye Laughlin Proj ect Review Coordinator Cc: Daniel Bevington, Kenai Peninsula Borough M~tt R~der, A ONR (DO&G) Mark Fink, ADF&G Tom Maunder, AOGA Bob Blankenberg, ADEC RECE'VED ~ +- APR l' 5 ""þ~-¡" AllllllØiI&Ga&ConI.w..t¡øon Aftd1cl¥ 01-A35LH o printed on recycled paper ) ) Alaska Region Domestic Production " , M MARATHON f Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 26, 2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KTU 32-7H Permit No.: 202-043 Dear Mr. Maunder Enclosed please find the APPLICATION FOR SUNDRY APPROVALS and cementing program. The sundry documents one change since the well was permitted for drilling. This is a minor change and is explained below. CementinQ prOQram: Because of the low pore pressure and high permeability in the 1st intermediate section (12 ~" hole section to 6,527' MD, 6,500' TVD), the cementing program for this zone was modified to a lighter 12.8 ppg. tail cement instead of the original 13.5 ppg. slurry. The hydrostatic weight from this slurry easily exceeds the pore pressure of any zone that will be encountered, but will help to minimize cement losses due to it's lower density. No proposed cement tops have been changed, only the cement density. If you require further information, I can be reached at 907-564-6310 or bye-mail at wjtank@marathon.com. Sincerely, kjkJ }~ Willard J. Tank Senior Drilling Engineer Enclosure RECEIVED MAR 2 8 2002 AIlllraOllIGllCanl. CommiIIion (~~ ) ) n:\drlg\kgf\43-6xrd\KBU 32-7H AOGCC Sundry.xls ~ ð:q ()~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend _ Repair Well X Pull Tubing 5. Type of Well: Developmen~ Exploratory ____ Stratigraphic _ Service Operation Shutdown Plugging Re-enter Suspended Well_ Time Extensior Stimulate Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address p, 0, Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface Change in Cement Program 6. Datum Elevation (OF or KB) 87' KB above MSL 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KTU 32-7H 9. Permit Number 202-043 10. API Number 50-133-20511-00 11. Field/Pool Kenai Gas Field/Tyonek feet 79'FNL, 4325'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1429'FNL, 4025'FWL, Sec. 7, T4N, R11W, S.M. At Effective Depth At Total Depth 1429'FNL, 2025'FWL, Sec. 7, T4N, R11W, S.M, 12. Present Well Condition Summary Total Depth: measured true ve rtical 5630 feet 5629 feet Currently Drilling Casing Structural Conductor Surface Length 118 Size 20" Cemented Driven Measu red Depth 139 True Vertical Depth 139 1496 13-3/8" 614 sx 1517 1517 RECEIVE'D MAR 2 8 2002 ~CI'GllCanl.c.iIIiOn ArdIoMgI 13. Attachments Description Summary of Proposa~ Detailed Operations Program _ BOP Sketch 14. Estimated Date for Commencing Operation 3/16/2002 16. If Proposal was Verbally Approved 15. Status of Well Classification as: Oil Gas X Suspended_ Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed jtJúw}4..L Willard J. Tank Title Senior Drilling Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Approval No. Plug Integrity BOP Test Location Clearance t ..~- "1 Mechanical Integrity Tes~ -Subsequent Form Required 1 o--,"\~~ ~ .Q~ ~-\v...)'(t \ \ Date 3/26/2002 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By Cammy Oechsli Commissioner Date tmttljÅte ORIGINAL ) ~ Opeï;~ator Name: Marathon Oil Co Well Name: KTU 32-7H I Pad 41-7 - Revision No.2 Job Description: Intermediate Casing Date: March 14,2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via 6,500 ft 6,527 ft 12.25 in Casino 9 5/8" 0.0. (8.835" .1.0) 40 # 9 5/8 in, 40 Ibs/ft Total Mix Water Required Weighted Spacer MCS-4D Density 1 st Lead Slurry Lead Cement Density Yield Tail Slurry Intermediate Tail Density Yield Displacement Drilling Mud Density Report Printed on: March 14. 2002 7:4 7 PM Page 6 5,946 gals 30 bbls 10.0 ppg 487 sacks 12.0 ppg 2.53 cflsack 133 sacks 12.8 ppg 1.79 cflsack 489 bbls 9.2 ppg ) (£j Proposal No: 100170389C Gr4109 ) Oper.ator Name: Marathon Oil Co Well Name: KTU 32-7H / Pad 41-7 - Revision No.2 Job Description: Intermediate Casing Date: March 14, 2002 WELL DATA ANNULAR GEOMETRY ANNULARI.D. (in) 12.515 CASING 12.250 HOLE SUSPENDED PIPES DIAMETER (in) O.D. I 9.625 I I.D. 8.835 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 3,031 ft x 0.3132 cf/ft 500 ft x 0.3132 cf/ft 80 ft x 0.4257 cf/ft WEIGHT (Ibs/ft) 40 ) E£j Proposal No: 100170389C DEPTH(ft) MEASURED I TRUE VERTICAL 1,500 I 1,500 6,527 I 6,500 DEPTH(ft) MEASURED I TRUE VERTICAL 6,527 I 6,500 6,447 ft 9.20 ppg Water Based 117 0 F 105 0 F with 30 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 1234.2 cf 203.6 cf 34.1 cf (inside pipe) 1471.8 cf 262 bbls Top of Lead Cement estimated to be 3,000'MD Top of Tail Cement estimated to be 6,027'MD Report Printed on: March 14,20027:47 PM Page 7 = Gr4115 ) Opetator Name: Marathon Oil Co ,. Well Name: KTU 32-7H 1 Pad 41-7 - Revision NO.2 Job Description: Intermediate Casing Date: March 14, 2002 ) !£j Proposal No: 100170389C FLUID SPECIFICATIONS Weighted Spacer 30.0 bbls MCS-4D + 20 Ibs/bbl Kol Seal + 30.8 Ibs/bbl Bentonite + 92 Ibs/bbl Barite, Bulk + 1 Ibs/bbl Cello Flake + 6 Ibs/bbl MCS-D @ 10 ppg FLUID VOLUME VOLUME CU-FT FACTOR AMOUNT AND TYPE OF CEMFNT 1 st Lead Slurry 1234 2.53 = 487 sacks Class G Cement + 0.75% bwoc Calcium Chloride + 20% bwoc LW-6 + 0.25 Ibs/sack Cello Flake + 0.4% bwoc CD-32 + 5 Ibs/sack Kol Seal + 1 % bwoc Sodium Metasilicate + 20% bwoc MPA-1 + 94.3% Fresh Water 238 1.79 = 133 sacks Class G Cement + 1 gals/100 sack FP-6L + 0.15% bwoc Sodium Metasilicate + 0.9% bwoc BA-10A + 5% bwoc MPA-1 + 22% bwoc LW-6 + 2% bwow Potassium Chloride + 0.2% bwoc R-3 + 0.6% bwoc CD-32 + 51.5% Fresh Water Tail Slurry Displacement CEMENT PROPERTIES 488.9 bbls Drilling Mud @ 9.2 ppg Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Free Water (mls) @ 0 F @ 45 0 angle SLURRY NO.1 12.00 2.53 10.63 10.63 SLURRY NO.2 12.76 1.79 5.80 5.81 0.0 Slight additive adjustments should be expected to achieve the desired slurry properties. Lost Circulation while drilling this section is anticipated. Use of Lost Circulation material in the MCS-4D Spacer system and the lead cement is recommended to aid in maintaining circulation during the cement ¡nh Report Printed on: March 14, 2002 7:47 PM Page 8 Gr4129 KTU 32-7H Request for Waiver (Diverter Size) ) ) Subject: KTU 32-7H Request for Waiver (Diverter Sile) Date: Tue, 26 Feb 2002 17:04:36 -0900 From: "Tank, W J (Will) It <WJTank@MarathonOil.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Berga, P K (Pete) " <PKBerga@MarathonOil.com>, "Lambe, Steven S." <SSLambe@MarathonOiLcom>, "Eller, J Gary" <JGEller@MarathonOil.com> Tom, Marathon is requesting a waiver from AOGCC Regulation 20 ACe 25.035 (c) (1) (b) which requires a vent line diameter at least as large as the hole to be drilled. Our Glacier 1 drilling rig is outfitted with a 16" diverter line. For KTU 32-7H we are currently planning to drill the surface hole at a 17 1/2" diameter. This well would be drilled from Pad 41-1 with a surface hole total depth of 1,500' TVD. To date 15 wells have been drilled from this pad with no gas seen above this TVD. The direct surface location offset to the west of this well was the Beluga well KBU 44-6 just completed last week. No gas was seen above this TVD and no problems were encountered in the surface hole. Additionally, geologic information indicates that the sands down to at least 1,500' are water saturated and do not pose a risk to drilling operations with a 16" diverter system. If you need any additional information, or have any questions, please contact me at 564--6310. Respectfully, WiHard J. Tank Senior Drilling Engineer Marathon Oil Company Anchorage, Alaska 1 of 1 2/27/02 6:49 AM ) ) ~~IÆ~E : J !Æ~!Æ~~~!Æ /1 ALASIiA. OIL AND GAS CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 W.J.Tank Senior Drilling Engineer . Marathon Oil Company PO Box 196168 Anchorage AK 99519 Re: Kenai Unit KTU 32-7H Marathon Oil Company Permit No: 202-043 Sur Loc: 79' FNL, 4325' FWL, Sec. 7, T4N, R11 W, SM Btmhole Loc. 1429' FNL, 2025' FWL, Sec. 7, T4N, R11W, SM Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application Kenai Unit KTU 32-7H. 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 BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. CàS~ h/éov Cammy Oechsli Taylor ' Chair . BY ORDER O~!HE COMMISSION DATED thiS'lk day of February, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. g:\cmn\drlg\sterling\su44-10'AOGCCPTD.XLW ) STATE OF ALASKA '\ µGA- 'L/l-t¿,!O"L ALA..... ,A OIL AND GAS CONSERVATION corvhvlISSION Æ;;>-( ~ PERMIT TO DRILL c?><- 210 AAC 25.005 Jtt1 H zIzb/ðz_ 1 a. Type of Work Drill[8] Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 79'FNL, 4325'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 1429'FNL, 4025'FWL, Sec. 7, T4N, R11W, S.M. At Total Depth 1429'FNL, 2025'FWL, Sec. 7, T4N, R11W, S.M. Re-DrillD DeepenD 12. Distance to Nearest Property Line(unit boundary 9,300 feet 16. To be Completed for Deviated Well: Kickoff Depth 5800 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well 1,550 Hole Casi ng Weight Driven 20" 133 17-1/2" 13 3/8" 68 12 1/4" 95/8" 40 81/2" 7" 26 Specifications Grade Coupling K-55 PE K-55 BTC L-80 BTC L-80 BTC 1b. Type of well. Explorat0rG Stratigraphic TesD ServiceD Development GaŒ Single ZoneŒ] 5. Datum Elevation (DF or KB) 10. Field and Pool 87' KB feet Kenai Gas Field/.se~ug6 'Tj~ ..--$ J Development aiD Multiple Zone[] 6. Property Designation A-028142 7. Unit or Property Name Kenai Unit 8. Well Number KTU 32-7H 9. Approximate Spud Date 3/11/2002 14. Number of Acres in Property 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) / feet 6000 11637' MD/8754'TVD feet 17. Anticipated Pressure /i (see 20 AAC 25.035 (e) (2» 89,8 0 Maximum Surface 2547 psig atTotal Depth (TVD) 8690' Setting Depth Top Bottom Length MD TVD MD TVD 80-1 00' 0' 0' 80-1 00' 80-100' 1500' 0' 0' 1500' 1500' 6527' 0' 0' 6527' 6500 9428' 6327' 6320' 9428' 8690' Quantity of Cement (including stage data) 647 sx 909 sx 500 sx t<l:liI::IVCD Jl1N 3 0 2002 Alaska Oil & Gas Cons. Commission Kenai Unit well KTU 32-7H will be directionally drilled to an estimated total depth of 11,637' MDI 8,7~~~rom the existing Kenai Gas Field pad 41-7.This horizontal D-1 sand well will be an open hole completion with tubing run thru the build section only. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing FeeŒ] Property Pla0 BOP Sketch[8] Drilling Fluid Progra~ Time vs Depth PloD Refraction AnalYSi{] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Phone: 564-6310 Title Senior Drilling Engineer Commission Use Only Permit Number API Number . Approval Date 1J.'l fì See Cover Letter 2D7 - ot../8 50-- /33 - 2057/-è¿ V\ . J,lf, ,~ rJ\ For Other Requirements Conditions of Approval Samples Required DYes ~No Mud Log Required DYes ~No Hydrogen SfJlfide Measures DYes ~ No Directional Survey Required ~Yes D No Required Working Pressure for BOPE D2M ~3M D5M D 10M D 15M C\ % tl'J Other: ~~\~,Q~ da~~c.. 35 ~~S ~<""\'-, \S ~'\ \<c"~,~(.ç\~ \\~ S~~cJ?JL-?¡,I ORIGINAL SIGNED BY o Taylor Seamount Signed j;du~ - W. J. Tank Approved by Form 10-401 Rev. 12-1-85 Diverter SketcrŒ] Seabed Repor[] Drilling prograrr[8J 20 AAC 25.050 ReqUirementO Date: 01/30/2002 Commissioner by order of the Commission Date ~ .~ If DI- Submit in Triplicate ORIGINAl ) ) DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: PAD: SLOT: KTU 32-7H 41-7 NA FIELD: Kenai Gas Field WBS No.: TYPE: Development Prepared by: W.J. Tank REVISION NO.: DATE: 1/28/2002 SURFACE LOCATION: 79' FNL, 4,325' FWL, Sec. 7, T4N, R11W, S.M. TARGET: Tyonek D-1 Sandstone 1,429' FNL, 4,025' FWL, Sec. 7, T4N, R11W, S.M (TVO = 8,744') BOTTOMHOLE LOCATION: 1,429' FNL, 2,025' FWL, Sec. 7, T4N, R11W, S.M (TVD = 8,754') KB ELEVATION: GL ELEVATION: 87 ft. mean S.L. 66 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling Upper Beluga Middle Beluga Lower Beluga Tyonek 3,572 4,657 5,313 6,040 7,423 3,572 4,657 5,313 6,039 7,169 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) POTENTIAL / CONTENT Sterling Upper Beluga Middle Beluga Lower Beluga Tyonek 0-1 Coal Base D-1 Sand TD 3,572 4,657 4,313 6,040 7,423 9,428 9,563 11,637 3,572 4,657 5,313 6,039 7,169 8,690 8,737 8,754 gas/water gas/water gas/water gas/water gas/water gas/water gas/water page 1 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis.xls ) ) III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS /. The diverter system will consist of a 21 1/4" X 2000 psi annular preventer and a 16" 0.0. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi ,,' double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. I The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: j 21 1/4" 2,000 psi flange top x 20" weld on bottom. CASING HEAD: 135/8" 3000 psi top x 13 3/8" SLC bottom with base plate for 20", two 2" line pipe outlets, one 2" ball valve. (Multibowl System) CASING SPOOL: TUBING HEAD: 135/8" 5,000 psi top x 135/8" 3,000 psi bottom, 21/16" 5,000 psi studded outlets, one 21/16" 5,000 psi gate valve. CHRISTMAS TREE: 4 1/16" 5,000 psi x 135/8" 5,000 psi bottom, including two master valves, one flow tee, one wing valve, one swab valve, and one pnuematic actuated wing valve. page 2 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis ) ') IV. CASING PROGRAM: CASING DESCRIPTION DEPTH SET FROM TO HOLE TYPE SIZE WT. GRADE THREAD (MD) (MD/TVD) SIZE CONDUCTOR: 20" 133 ppf K-55 PE Surf 139'/139' Driven SURFACE: 13 3/8" 68 ppf L-80 BTC Surf 1 ,500'/1 ,500' 17 1 /2" INTERM 1: 9 5/8" 40 ppf L-80 BTC Surf 6,527'/6,500' 12 1/4" INTERM 2/ LINER: 7" 26 ppf L-80 BTC 6,327' 9,428'/8,690' 81/2" CASING DESIGN SETTING FRAC GRD FORM PRES DESIGN FACTORS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP TENS COLL BURST 13 3/8" 68 ppf L-80 1,500' 18.5 663 1,348 3.15 3.16 6.53 /' 9 5/8" 40 ppf L-80 6,500' 14.3 2,873 2,547 1.91 1.05 2.73 / 7" 26 ppf L-80 8,690' 16.7 3,841 2,547 2.20 1.08 2.06 ,/ All tubulars are new. /i page 3 n:\drlg\kgt\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis , ) V. CEMENTING PROGRAM SURFACE: 133/811 1,500'/1,500' SLURRY: Class IIGII + required additives. See cement prognosis. /' TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.0 ppg. 2.50 cu. fUsk 10.84 gal/sk 5:30 hrs:min 50 % in open hole. 647 sks. /' RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. 3. M/U stab-in float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Run inner cementing string with stabing sub and centralizer. Weatherford has false rotary and slips. 8. Pump spacer as follows: 40 bbl Mud Clean II @ 8.4 ppg 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. 11. Displace cement. Sting out. 12. Check floats. 13. POOH with inner string. WOC 14. N/D diverter. Weld on casing head and N/U blowout preventers. 15. Test BOPE. Run wear bushing. page 4 n:\drlg\kgt\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis ) ) V. CEMENTING PROGRAM (continued) INTERM 1 95/8" @ 6,527'/6,500' LEAD SLURRY: Class "G" + required additives. See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: /' 3,000 ft. 12.0 ppg. 2.53 cu. fUsk 10.63 gal/sk hrs:min 50 % / 118 sks. TAIL SLURRY: Class "G" + required additives. See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 3,500 ft. 13.5 ppg. 1.84 cu. fUsk 9.28 gal/sk 7:30 hrs:min 50% ./ 791 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: 40.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 1 Ibs/bbl Cello Flake + 20 Ibs/bbl Kol Seal + 30.8 Ibs/bbl Bentonite + 92 Ibs/bbl Barite, Bulk @ 10 ppg 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. Land mandrel hanger in multibowl. 12. Bump plug wI 500-1 ,000 psi over final circulating pressure. Check floats. 13. WOC page 5 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis ') ) V. CEMENTING PROGRAM (continued) INTERM 21 LNR 7" @ 6,327' MD to 9,428'/8,690' SLURRY: Class "G" + required additives. See cement prognosis. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: / 6,327 ft. 15.7 ppg. 1 .18 cu. fUsk 5.03 gal/sk 4:22 hrs:min 50 % 500 sks. ""' RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (seal-lock all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing liner on 4" drillpipe. Circulate and condition well. 6. Set hydraulic liner hanger. M/U cementing head and test all lines. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: 50.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 9 Ibs/bbl Potassium Chloride + 30.15 Ibs/bbl Bentonite + 119 Ibs/bbl Barite, Bulk @ 10.5 ppg 9. Mix and pump slurry. Drop top plug. 10. Displace cement with water. 11. Bump plug wI a minimum of 500 psi over displacement pressure. Check floats. 12. Sting out of liner hanger, pull up 5 stands, reverse out cement. 13. WOC. 14. Dress off and test liner top. Run polish mill. 15. Run and set liner hanger packer with weight. page 6 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis.xls VI. MUD PROGRAM DEPTH FROM 0' 1,500' 6,500' 8,690' DEPTH TO TVD 1,500' 6,500' 8,690' 8,754' ) WEIGHT ppg 9.0 - 9.2 9.0 - 9.2 9.2 - 12.2 9.2 - 9.5 See Mud Prognosis for details. MUD PROPERTIES PV cp 10-15 8 - 14 15 - 20 8 - 10 WATER LOSS 8 - 12 8 - 10 6-8 NC ) MUD TYPE Freshwater gel Freshwater gel FLO PRO/KCL Solids free MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS CONDUCTOR: SURFACE: INTERM 1: INTERM 2 I LNR: LOGGING PROGRAM No logging is planned for this interval. No logging is planned for this interval. No logging is planned for this interval. RUN #1: GR/CNULDT/AIT/DSI/NGT/MSFL / MUD LOGGING The well will be mud logged from surface to TO at 11,637' MD. None Planned No open hole tests are planned for this well. page 7 CORING PROGRAM TESTING PROGRAM n:\drlg\kgt\wells\kbu 44-6\KTU 32-7H Drilling Prognosis.xls ) ) VIII. OTHER INFORMATION DIRECTIONAL PLAN NORTH East VERT DESC MD TVD INCL AZIM COORD COORD SECTION RKB 87 87 0 0 0 0 0 END of TURN 5,800 5,800 0.0 145.4 0 0 0 KOP 6,133 6,132 10.0 145.4 -24 17 -17 build @ 3.0 deg/100ft END of BUILD 6,809 / 6,725 43.8 145.4 -272 188 -188 build @ 5.0 deg/100ft END of HOLD 7,581 7,283 43.8 145.4 -711 491 -491 END BUILDITURN 9,358 / 8,655 60.0 270.0 -1350 -39 39 build @ 5.0 deg/100ft TARGET D1 COAL 9,428 8,690 60.0 270.0 -1350 -100 100 TARGET D1 SAND 9,637 / 8,744 89.8 270.0 -1350 -300 300 build @ 14.21 deg/100ft Total Depth 11 ,637 8,754 89.7 270.0 -1350 -2300 2300 POTENTIAL INTERFERENCE: / WELL DISTANCE (ft.) DEPTH (MD) KU 43-6A 51 1,200 KBU 44-6 56 500 KU 43-6 80 900 KU 13-5 96 1,300 No serious interference exists. See Directional Plan & Anticollision Data for more details. page 8 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis ') ) IX. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +1-120 ft. RKB. Weld startir;g flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 21 1/4" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: / / Drill a 17 1/2" hole to 1,500' MD/1 ,500' TVD per the directional plan. Run and cement 133/8" casing. wac. Cutoff 13 3/8" and 20". Connect 13 3/8" SLC »y 13 5/8" 3M wellhead. N/U 13 5/8" 5M BOP'S. I Test BOP'S and choke manifold to 250/3,000 psi. Set wear bushing. Test surface casing to 1,500 psi. INTERMEDIATE 1 : Drill out float equipment and make 20' of new hole. CBU. Test shoe to leak off. Estimated EMW is 18.5 ppg. Drill 12 1/4" directional hole to 6,527' MD/6,500' TVD as per directional plan. Lost circulation is likely through this entire interval. Make wiper trip. Run ~d cement 9 5/8" casing. Land casing in multibowl head. wac. Set wear bushing. Test casing to 2,600 psi. INTERMEDIATE 2: Drill float equipment and 20' of new formation wi 81/2" bit. CBU. Test shoe to leak off. Estimated EMW 14.3 ppg. Drill a 8 1/2" hole to 9,428' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run 7" casing liner on drill pipe and set hanger at 9,428'. Cement. Bump plug with 500 psi over displacement pressure. wac. Cle~out to top of liner. Test liner to 2,600 psi. Run liner hanger packer. Set packer and test to 2,600 psi. Set wear bushing. PRODUCTION: Drill float equipment and 20' of new formation wi 6 1/8" bit. CBU. Test shoe to leak off. Estimated EMW 16.7 ppg. Drill a 6 1/8" hole to 11,637' per the directional program. Make a wiper trips as necessary. Trip out laying down. Pull wear bushing. COMPLETION: Run permanent packer and tail pipe, set in 7" liner. Run 4 1/2" tubing and sting into packer. Land tubing in hanger. Set BPV's in hanger. N/D BOPE and N/U tree. Test tree to 5,000 psi. Rig down and move out drilling rig. page 9 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis. xis ') ) X. POTENTIAL HAZARDS Well KTU 32-7H To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the b;e¡;fk(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. / This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 3,572' MD/3,572' TVD to total depth of the well. These sands will run from normal pressured to severly depleted and lost circulation and differential sticking are potential hazards. The fresh water gel and FLOPRO mud systems that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. XI. NOTES MASP CALCULATIONS: Surface casing: 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (18.5 ppg + 1.0 ppg) x .052 x 1500' - (.115 x 1,500') MASP = 1 ,521 psi - 173 psi MASP = 1 ,348 psi. Intermediate casing: 9 5/8" MASP = Kick pressure at 7" shoe + S.F. - Hydrostatic pressure of gas column - Hydrostatic pressure of mud column MASP = (12.2 ppg + 0.5 ppg) x .052 x 8,690' - (.10 psi/ft x 4,345') - (.052 x 12.2 ppg x 4,345') MASP = 5,739 psi )36 psi - 2,756 psi MASP = 2,547 psi Intermediate liner: 7" MASP = MASP for 9 5/8" intermediate Tubulars All tubulars are new. page 10 n:\drlg\kgf\wells\kbu 44-6\KTU 32-7H Drilling Prognosis.xls }.---.-..-----.--- MA,RA TH 0 N Created by Sutherland For: W Tank Date plot led : 2ó-Jon-2002 Pial Rererence is KTU J2-7H Version H2. Coordinales ore in feel relerence slot HKTU32-7H. True vertical Depths ore relerence Est RKB. rtiÍÌiiæ BAKE. HUG.. INTEQ 0 500 - 1000 - 1500 - 2000 - 2500 - ~ 3000 - - Q) Q) <+0- "-'" 3500 - ....c - n. Q) 4000 - 0 0 4500 - U :;:: !..... Q) > 5000 - Q) ::} !..... 5500 - l- I V 6000 - 6500 - 7000 - 7500 - 8000 - 8500 - 9000 - Structure: Pad 41-7 Field Kenai Gas Field ! 0.00 Ll 13 3/8 Casing \()'1.- ,,\1:).. "ç{ <;) " èJ' ",~o~ -<! '\ X ..) ") ~ 2000 Azimuth 270.00 with reference 0.00 N, 0.00 E trom slot #KTU32-7H Sterling Top Top Upper Beluga Top Middle Beluga 0.00 KOP 3.00 9.00 Top Lower Beluga 15.00 J 25 00 DLS: 5.00 deg I.. ' 9 5/8 Casing 35.00 43.78 End of Build/Turn per 100 ft Top Tyonek ~\t>. \'1.- Begin Build/Turn , ~ DLS: 5.00 deg per 100 ft è- / <Q 0r¿ ~.~ ~ ")().,\" èJ' ")"). '1.-' "'-4,0~ ")~. ()'1.- -<! <Q' <Qt>. '\ þ.. ~"). & X ,. ..)") ~'\~ ~ 0~r¿ '\ 1000 500 o 500 1000 1500 V ertica I Section (feet) - > ---.---------. ì)- Oil Company Well KTU32-7H Location: Kenai Peninsula, Alaska <- West (feet) 2400 1600 1200 2000 1-,>-(/ \J'~ '.> "Ý, 1 0-;> C9.f ð)' ~ ð, ~ "!-: o..=> ---- Point ----- Tie on End o( Turn (net of Build End or Hold 2500 Ene! 01 ßuildíTurn Torget KTV.3.2-7H-T/DICo 9-427.~ Torç¡.t KTU..)2-7H-Tyonek 915.]7.0,", I.O. I< Iorget KN32-7H-116J7.06 /~,~ \ MARATHON . 800 400 o 400 800 9 5/8 Casing ~\.. End of Build/Turn o - 400 l/) o s:: :T - 800 ,,-.., - CD ~ '-' I V - 1200 ~ .. p- +;.(/ .> \J' ~, (~ ~ 19.... '.1: J..o -;>~ :fð )' '%, ~/ " - 1600 ~ ~ WELL PROFILE DATA ---- WO 0;, M) 0.00 0.00 0.00 ~.OO 0.00 0.00 I 0.00 Eoot V. Soot 009/100 0.00 0.00 0.00 0.00 ~.OO 0.00 61J3.J..\ 145.35 6'3'.64 -23.87 16.50 -'6.50 43.18 145.35 6725.45 -271.57 167.68 -187.68 <3.78 145.35 7262.69 -710.97 491.35 -491.J5 60.00 270.00 86~~.00 -1 3~0.00 - 39.38 '9.J8 60.00 270.00 8690.00 - I J5O.oo -100.00 100.00 69.78 270.00 814'.00 - 1 '50.00 - JOO.oo 300.00 3.00 6808.8~ / ~.OO 7580.66 0.00 9"7.~2 ~oo 0.00 I '4.21 89.~_ 27000 875~~__:!}~0"ºº __:_~~.º-O,ºº.~Q(),-oa___._o..~) ) ) MARATHON Oil Company Pad 41-7 KTU32-7H slot #KTU32-7H Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KTU 32-7H Version #2 prop5055 Date printed Date created Last revised 25-Jan-2002 4-Jan-2002 25-Jan-2002 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000,N Slot location is n60 27 33.502,w151 14 42.682 Slot Grid coordinates are N 2361929.791. E 275232.506 Slot local coordinates are 56.86 S 4326.28 E Projection type: alaska - Zone 4, Spheroid: Clarke· 1866 Reference North is True North MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7.KTU32-7H Your ref: KTU 32-7H Version #2 Kenai Gas Field,Kenai Peninsula. Alaska Last revised : 25-Jan-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 145.35 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 145.35 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 145.35 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0..00 145.35 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 145.35 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 145.35 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 145.35 700.00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 145.35 800.00 0.00 N 0.00 E 0.00 0.00 900.00 0.00 145.35 900.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 145.35 1000.00 0.00 N 0.00 E 0.00 0.00 1100.00 0.00 145.35 1100.00 0.00 N 0.00 E 0.00 0.00 1200.00 0.00 145.35 1200.00 0.00 N 0.00 E 0.00 0.00 1300.00 0.00 145.35 1300.00 0.00 N 0.00 E 0.00 0.00 1400.00 0.00 145.35 1400.00 0.00 N 0.00 E 0.00 0.00 1500.00 0.00 145.35 1500.00 0.00 N 0.00 E 0.00 0.00 1600.00 0.00 145.35 1600.00 0.00 N 0.00 E 0.00 0.00 1700.00 0.00 145.35 1700.00 0.00 N 0.00 E 0.00 0.00 1800.00 0.00 145.35 1800.00 0.00 N 0.00 E 0.00 0.00 1900.00 0.00 145.35 1900.00 0.00 N 0.00 E 0.00 0.00 2000.00 0.00 145.35 2000.00 0.00 N 0.00 E 0.00 0.00 2100.00 0.00 145.35 2100.00 0.00 N 0.00 E 0.00 0.00 2200.00 0.00 145.35 2200.00 0.00 N 0.00 E 0.00 0.00 2300.00 0.00 145.35 2300.00 0.00 N 0.00 E 0.00 0.00 2400.00 0.00 145.35 2400.00 0.00 N 0.00 E 0.00 0.00 2500.00 0.00 145.35 2500.00 0.00 N 0.00 E 0.00 0.00 2600.00 0.00 145.35 2600.00 0.00 N 0.00 E 0.00 0.00 2700.00 0.00 145.35 2700.00 0.00 N 0.00 E 0.00 0.00 2800.00 0.00 145.35 2800.00 0.00 N 0.00 E 0.00 0.00 2900.00 0.00 145.35 2900.00 0.00 N 0.00 E 0.00 0.00 3000.00 0.00 145.35 3000.00 0.00 N 0.00 E 0.00 0.00 3100.00 0.00 145.35 3100.00 0.00 N 0.00 E 0.00 0.00 3200.00 0.00 145.35 3200.00 0.00 N 0.00 E 0.00 0.00 3300.00 0.00 145.35 3300.00 0.00 N 0.00 E 0.00 0.00 3400.00 0.00 145.35 3400.00 0.00 N 0.00 E 0.00 0.00 3500.00 0.00 145.35 3500.00 0.00 N 0.00 E 0.00 0.00 3572.00 0.00 145.35 3572.00 0.00 N 0.00 E 0.00 0.00 Sterling Top 3600.00 0.00 145.35 3600.00 0.00 N 0.00 E 0.00 0.00 3700.00 0.00 145.35 3700.00 0.00 N 0.00 E 0.00 0.00 3800.00 0.00 145.35 3800.00 0.00 N 0.00 E 0.00 0.00 3900.00 0.00 145.35 3900.00 0.00 N 0.00 E 0.00 0.00 4000.00 0.00 145.35 4000.00 0.00 N 0.00 E 0.00 0.00 4100.00 0.00 145.35 4100.00 0.00 N 0.00 E 0.00 0.00 4200.00 0.00 145.35 4200.00 0.00 N 0.00 E 0.00 0.00 4300.00 0.00 145.35 4300.00 0.00 N 0.00 E 0.00 0.00 4400.00 0.00 145.35 4400.00 0.00 N 0.00 E 0.00 0.00 4500.00 0.00 145.35 4500.00 0.00 N 0.00 E 0.00 0.00 4600.00 0.00 145.35 4600.00 0.00 N 0.00 E 0.00 0.00 4657.00 0.00 145.35 4657.00 0.00 N 0.00 E 0.00 0.00 Top Upper Beluga 4700.00 0.00 145.35 4700.00 0.00 N 0.00 E 0.00 0.00 All data is in feet unless otherwise stated. Coordinates from slot #KTU32-7H and TVD from Est RKB (87.00 Ft above mean sea level). Bottom hole distance is 2666.93 on azimuth 239.59 degrees from wellhead. Total Dogleg for wellpath is 162.52 degrees. Vertical section is from wellhead on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) -) ) ) MARATHON Oil Company PROPOSAL LISTING Page 2 Pad 41-7.KTU32-7H Your ref: KTU 32-7H Version #2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised: 25-Jan-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 4800.00 0.00 145.35 4800.00 0.00 N 0.00 E 0.00 0.00 4900.00 0.00 145.35 4900.00 0.00 N 0.00 E 0.00 0.00 5000.00 0.00 145.35 5000.00 0.00 N 0.00 E 0.00 0.00 5100.00 0.00 145.35 5100.00 0.00 N 0.00 E 0.00 0.00 5200.00 0.00 145.35 5200.00 0.00 N 0.00 E 0.00 0.00 5300.00 0.00 145.35 5300.00 0.00 N 0.00 E 0.00 0.00 5313.00 0.00 145.35 5313.00 0.00 N 0.00 E 0.00 0.00 Top Middle Beluga 5400.00 0.00 145.35 5400.00 0.00 N 0.00 E 0.00 0.00 5500.00 0.00 145.35 5500.00 0.00 N 0.00 E 0.00 0.00 5600.00 0.00 145.35 5600.00 0.00 N 0.00 E 0.00 0.00 5700.00 0.00 145.35 5700.00 0.00 N 0.00 E 0.00 0.00 5800.00 0.00 145.35 5800.00 0.00 N 0.00 E 0.00 O.OO.KOP 5900.00 3.00 145.35 5899.95 2.15 S 1.49 E 3.00 -1.49 6000.00 6.00 145.35 5999.63 8.61 S 5.95 E 3.00 -5.95 6039.63 7.19 145.35 6039.00 12.35 S 8.54 E 3.00 -8.54 Top Lower Beluga 6100.00 9.00 145.35 6098.77 19.34 S 13.37 E 3.00 -13.37 6133.33 10.00 145.35 6131.64 23.87 S 16.50 E 3.00 -16.50 6233.33 15.00 145.35 6229.24 41. 67 S 28.80 E 5.00 -28.80 6333.33 20.00 145.35 6324.58 66.40 S 45.89 E 5.00 -45.89 6433.33 25.00 145.35 6416.94 97.87 S 67.64 E 5.00 -67.64 6533.33 30.00 145.35 6505.62 135.85 S 93.88 E 5.00 -93.88 6633.33 35.00 145.35 6589.93 180.03 S 124.42 E 5.00 -124.42 6733.33 40.00 145.35 6669.24 230.10 S 159.02 E 5.00 -159.02 6808.85 43.78 145.35 6725.45 271.57 S 187.68 E 5.00 -187.68 End of Build/Turn 7000.00 43.78 145.35 6863.47 380.36 S 262.87 E 0.00 -262.87 7423.15 43.78 145.35 7169.00 621.19 S 429.31 E 0.00 -429.31 Top Tyonek 7500.00 43.78 145.35 7224.49 664.93 S 459.54 E 0.00 -459.54 7580 . 88 43.78 145.35 7282.89 710.97 S 491. 35 E 0.00 -491.35 Begin Build/Turn 7600.00 43.11 146.35 7296.77 721. 85 S 498.73 E 5.00 -498.73 7700.00 39.78 151.99 7371. 75 778.57 S 532.71 E 5.00 -532.71 7800.00 36.76 158.43 7450.28 834.68 S 558.75 E 5.00 -558.75 7900.00 34.14 165.78 7531. 77 889.74 S 576.66 E 5.00 -576.66 8000.00 32.02 174.08 7615.60 943.34 S 586.29 E 5.00 -586.29 8100.00 30.50 183.27 7701.14 995.08 S 587.58 E 5.00 -587.58 8200.00 29.67 193.12 7787.72 1044.55 S 580.51 E 5.00 -580.51 8300.00 29.60 203.24 7874.69 1091. 38 S 565.13 E 5.00 -565.13 8400.00 30.29 213.17 7961.39 1135.21 S 541. 57 E 5.00 - 541. 57 8500.00 31.69 222.50 8047.16 1175.71 S 510.01 E 5.00 -510.01 8600.00 33.71 230.97 8131. 35 1212.58 S 470.67 E 5.00 -470.67 8700.00 36.25 238.50 8213.31 1245.53 S 423.87 E 5.00 -423.87 8800.00 39.21 245.10 8292.43 1274.30 S 369.96 E 5.00 -369.96 8900.00 42.48 250.87 8368.10 1298.69 S 309.35 E 5.00 -309.35 9000.00 46.02 255.95 8439.74 1318.51 S 242.51 E 5.00 -242.51 9100.00 49.75 260.43 8506.80 1333.60 S 169.93 E 5.00 -169.93 9200.00 53.64 264.44 8568.79 1343.85 S 92.17 E 5.00 -92.17 9300.00 57.65 268.06 8625.22 1349.18 S 9.82 E 5.00 -9.82 9357.52 60.00 270.00 8655.00 1350.00 S 39_38 W 5.00 39.38 Top Tyonek D1 Coal 9357.62 60.00 270.00 8655.05 1350.00 S 39.46 W 0.00 39.46 End of Build/Turn 9427.52 60.00 270.00 8690.00 1350.00 S 100.00 W 0.00 100.00 KTU32-7H-T/D1Coal- 1/4/02 9427.62 60.01 270.00 8690.05 1350.00 S 100.09 W 14.21 100.09 Begin Build/Turn All data is in feet unless otherwise stated. Coordinates from slot #KTU32-7H and TVD from Est RKB (87.00 Ft above mean sea level). Bottom hole distance is 2666.93 on azimuth 239.59 degrees from wellhead. Total Dogleg for wellpath is 162.52 degrees. Vertical section is from wellhead on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ') MARATHON Oil Company PROPOSAL LI STI NG Page 3 Pad 41-7,KTU32-7H Your ref: KTU 32-7H Version #2 Kenai Gas Fie1d,Kenai Peninsula, Alaska Last revised: 25-Jan-2002 Measured Inc1in. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R 0 I N ATE S Deg/lOOft Sect 9505.41 71.07 270.00 8722.21 1350.00 S 170.79 W 14.21 170.79 9563.33 79.30 270.00 8737.00 1350.00 S 226.73 W 14.21 226.73 Top Tyonek 0-1 Sand 9605.41 85.29 270.00 8742.64 1350.00 S 268.42 W 14.21 268.42 9637.03 89.78 270.00 8744.00 1350.00 S 300.00 W 14.21 300.00 KTU32-7H-Tyonek 01 Heel - 1/4/2 9672.94 89.78 270.00 8744.14 1350.00 S 335.91 W 0.01 335.91 9772.94 89.77 270.00 8744.53 1350.00 S 435.91 W 0.01 435.91 9872.94 89.76 270.00 8744.94 1350.00 S 535.91 W 0.01 535.91 9972.94 89.76 270.00 8745.35 1350.00 S 635.90 W 0.01 635.90 10072.94 89.75 270.00 8745.78 1350.00 S 735.90 W 0.01 735.90 10172.94 89.74 270.00 8746.22 1350.00 S 835.90 W 0.01 835.90 10272.94 89.74 270.00 8746.67 1350.00 S 935.90 W 0.01 935.90 10372.94 89.73 270.00 8747.13 1350.00 S 1035.90 W 0.01 1035.90 10472.94 89.72 270.00 8747.61 1350.00 S 1135.90 W 0.01 1135.90 10572.94 89.72 270.00 8748.09 1350.00 S 1235.90 W 0.01 1235.90 10672.94 89.71 270.00 8748.59 1350.00 S 1335.90 W 0.01 1335.90 10772.94 89.70 270.00 8749.10 1350.00 S 1435.90 W 0.01 1435.90 10872.94 89.70 270.00.. 8749.62 1350 .00 S 1535.89 W 0.01 1535.89 10972.94 89.69 270.00 8750.16 1350.00 S 1635.89 W 0.01 1635.89 11072.94 89.68 270.00 8750.70 1350.00 S 1735.89 W 0.01 1735.89 11172.94 89.68 270.00 8751.26 1350.00 S 1835.89 ,W 0.01 1835.89 11272.94 89.67 270.00 8751.83 1350.00 S 1935.89 W 0.01 1935.89 11372.94 89.66 270.00 8752.41 1350.00 S 2035.89 W 0.01 2035.89 11472.94 89.66 270.00 8753.00 1350.00 S 2135.88 W 0.01 2135.88 11572.94 89.65 270.00 8753.61 1350.00 S 2235.88 W 0.01 2235.88 11637.06 89.65 270.00 8754.00 1350.00 S 2300.00 W 0.01 2300.00 KTU32-7H-Tyonek 01/TO-1/4/02 All data is in feet unless otherwise stated. Coordinates from slot #KTU32-7H and TVD from Est RKB (87.00 Ft above mean sea level). Bottom hole distance is 2666.93 on azimuth 239.59 degrees from wellhead. Total Dogleg for we11path is 162.52 degrees. Vertical section is from wellhead on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') MARATHON Oil Company Pad 41-7,KTU32-7H Kenai Gas Field,Kenai Peninsula, Alaska Comments in wellpath ------------ ------------ MD Rectangular Coords. Comment TVD ) PROP05AL LI5TING Page 4 Your ref: KTU 32-7H Version #2 Last revised : 25-Jan-2002 ......... __.. __.. ___ __... ..__.._...... .__...... 00"""" __... __....... ___............ __ _................................... __ ....... ........................ ___.............. __........... 3572.00 3572.00 0.00 N 0.00 E 5terling Top 4657.00 4657.00 0.00 N 0.00 E Top Upper Beluga 5313.00 5313.00 0.00 N 0.00 E Top Middle Beluga 5800.00 5800.00 0.00 N 0.00 E KOP 6039.63 6039.00 12.35 5 8.54 E Top Lower Beluga 6808.85 6725.45 271. 57 5 187.68 E End of Build/Turn 7423.15 7169.00 621.19 5 429.31 E Top Tyonek 7580.88 7282.89 710.97 5 491. 35 E Begin Build/Turn 9357.52 8655.00 1350.00 5 39.38 W Top Tyonek 01 Coal 9357.62 8655.05 1350.00 5 39.46 W End of Build/Turn 9427.52 8690.00 1350.00 5 100.00 W KTU32-7H-T/D1Coal- 1/4/02 9427.62 8690.05 1350.00 5 100.09 W Begin Build/Turn 9563.33 8737.00 1350.00 5 226.73 W Top Tyonek 0-1 5and 9637.03 8744.00 1350.00 5 300.00 W KTU32-7H-Tyonek 01 Heel - 1/4/2 11637.06 8754.00 1350.00 5 2300.00 W KTU32-7H-Tyonek D1/TD-1/4/02 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 9427.52 8690.00 O.OOE 6526.86 6500.00 O.OOE 1500.00 1500.00 1350.005 133.205 O.OON 100.00W 7" Liner 92.05E 9 5/8" Casing O.OOE 13 3/8" Casing -------- Targets associated with this wellpath Revised Target name Geographic Location LV.D. Rectangular Coordinates .. -........-....................... -.. ............ .....-.. .......... -...- ---.....-.. ---...... ..........-................... -..-.......... ....- -....... --- _.. ....- ........ ...--..... -......... -..... --..... KTU32-7H-T/D1Coal- 1 KTU32-7H-Tyonek 01 H KTU32-7H-Tyonek D1/T 8690.00 8744.00 8754.00 1350.005 1350.005 1350.005 100.00W 300.00W 2300.00W 4-Jan-2002 4-Jan-2002 4-Jan-2002 :) l20 3/4" 3M Diverter 1-. I Diverter Spool Marathon Oil Well KTU 32-7H Diverter ) I Flow line "'> I I ...... / I /' 116" Automatic Hydraulic Valve I \ :::0: ~ / I I '\ "- I I í 116" Diverter Line I Flow Nipple I 13 S/8" SM Annular Preventer 13 S/811 SM Double Ram Preventer 3 1/8" SM Manually Operated Valves 13 S/8" SM Single Ram Preventer ") ) I ~ I Marathon Oil Well KTU 32-7H BOP Stack ) -. IFlow Line I I ~ "> I I ""- ./ / I 1 ( I Pipe Ram I I Blind Ram I 3 1/8" SM Hydraulically Operated Valve ( I /1 JI IChoke()@(I xl t .... I I ( I Pipe Ram I ) I I ( I I í ) ~~ :~ IXlIXl) Kill I I I~:)./ 13 S/8" SM Cross I ~ ""- \ 3 1 /8" SM Manually Operated Valve ) Marathon Oil Well KTU 32-7H Choke Manifold ) ITO Gas Buster I To Blooey Line Bleed off Line to Shakers ~ ~ I, I CJ®Cj , CJ®C~ t ~ ( ~ \.--1 ~ J ( ~ r-~ ~ ~ J ~ 1 I ( ~ \.--1 ~-~ J®C '\ t 13" 5M Valves o J®CJ®l, \.--J I i 2 9/16" 10M Swaco Hydraulically Operated Cho ke ~ IFrom BOP Stack 3 1/8" 5M Manually Adjustable Choke I I 1 I L________ I J I I I I r I 1 f t "'--....., ~'~œmV'\ IŒGASSER) 1 \. ,,, It I .....-..... -, . _ 1mI:i{ .. ~-----i ~-----~t r- ' , L__~ U J f 1 J f I r--' " ~ I r J IJ r I t I II I I r , ~- 11 I I Ii! ';,1 at: III I ... t J LJ III J ä l 1 i '1 1 1 ~ ! I M 11 1 J i . I U I 1 ~ . I ~ tll ~ ~ 1 I ~ II I L_____..J L_____.JI I r--~-----;ì I I . ....\" "'\' IlL.. I .tI J I I r-cr -y-- -'.. 1.~-4I" ) r-----ì f I ~ I CENTRIFUGE} I UNIT I I 4' X 1tt' I I I I I I I I I I DlI4P I 1 ,-, I 1 ......~ I I I L_____.J j" .) K[]D~ 3~ X 12' 75 HP 6 X 5 I U· ~ :..2 e ,--. r " '--- ._ç ( ~ 1DIiH '- ~ 7'5HP 15 HP 6 X 5 '6 X :5 U· 11" t . - ,I - . ... .. ·1 I~ ! .. .. . 41: .e---. \ . . Œ&\SSER .1 l~:'J .. I" . ...~-r Q--y. I 75 t9 . 6 )( :5 11"" J = ..t I 4 '" . e. ..,J -. 5V 9L A-600 P'T II" - ar... i ~ --- I 5\11 9l "-600 PT I' -. J . T , . 4-- .. ... PI.L m ....--. I~: ,w: :~ ¡Ld: 'x. ~¡ .>: :t: : T ;¡OJ .,. a· ..... --- . .¡'\. . 14........ - , I I . -. . ...... --.... : i . .. ; ~ - I .- J' ftA \'1·'·~ ,.)' -;1, L~I ~ . ~-D" þr~ ~ i .:r=-I ):('-l...,I: 3 4 MIL~" L~~~=¿~~_::i~-~=_i~",=î=-~~~_;3:.:~:=~::-~~,::~~"=~:~::~:o~~ ¡l~riany KTU 32-7H "'---".--.----. SCAL F 1: 63 360 Source Map: USGS, 1951 Kenai, Alaska 8-4, 1:63,360 ...' .__.__n.____._., ~~_.__.._..J!5Ji!'!...ALÇ-4¿.______ .-......'---.--: 7"(", .-'-----~,~:.,...,-,.---.-;.-:'-...: ...,.......1_. .. ···..-·..·---·..·r~:::..:T···..:· -......-.- ~-."IT;;~~t~~ ~..~-~~---. --..-.-.. ",.. _":~~7€g3a · . ) ) .~,ò~,:.~..\¡, '\ NORTH . 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I ' "'.-" .\ ----'. ./ .,:.. \ I - r '., ".:) '. \_....', \' ~__(~~~~;,~_ _H,jt __L_:~, _ _/,C;t>~ - ~ ...__,,_.__.. __.ß ..:-;) ii1 , co "'v' .~" ,~ .:~£.~5' ~I ,II¡. I v"¡ i ¡ ::E ~~ ii ~: '~ "~~b ': g ~ .,¡... ? .' r..:',~: . .;?:(, 17 18 14 f..~t r:..~ . ,..,'," ......"".'"._,----_.....'-_._."""...".."-.."..,,~.,,..,, .'. . . ¡" I ..~ I I I ,j I L.·..:¡ ! : ~" '12 I \i1!i J .. ·1 :C).) ¡~ I Ej j ."/ I ~i ~,. 1 ¡, ..!......._....... J . . i I. I I / I r \ ""::'.,! I ;,..1".,,, J 1 f~-i AJ¡!};LJ ...,::):/.., 24 _ - ../).',,:.:f ¡" f?:':'~J ,i. ( ':P¡åd. :"f .' I I KTU 32-7H A STERLING UPPER BELUGA MIDDLE BELUGA LOWER BELUGA UPPER TYONEK DEEP TYONEK -10,000' X D1 Control ~ D1 Çompletion D1 Horizontaì Completion Proposed D1 Horizontal Segment Structure Top Tyonek D1 Sandstone C.I.: 100' o I MILE '~ -.... ~ -t-- ~ o o o í , N~XkLJ I(;)U-1 .~eflt/: / --Or- " KDU-~::r'-,~ \ KßU 41-7~ad KU-14T ;f- X U-2 KDU-7 X + ¡! ff I I o ;:- KDU-6 X / I I I I I I [} ...... -JKDU-5 l... V" . KDU 4~D X " + (P. . '''<9- ~ \9('2 C90~ L.~ I '"&><2 .-. ~ I 'L._., ~ ¿:::::::pO HM4094 ) ! T5N-R11W '-·1 -+ . L.~ UNIT I rOUNDARY --.. / ....- . '\ ~-. I Q ..J D1 Net Pay I \_~ 1 "- \ I \ I I '}(KDU-3 I T4tJ-R11W '" { + ï!- KTU 32-7H 2002 Completion 2000' Lateral / PTD 11,63~' MD L' I i-" + +- MARATHON OIL COMPANY ALASKA REGION KENAI FIELD KENAI, ALASKA KTU 32·7H NET W.I. : 100% December 2001 o:\frehand\kenai\ Tyonék\32-7hlocaogcc. fh9 II- 0 0 0 ¡. 0 0 2 ~ 0 L,III I: 0 L, ¡. 2 0 ~ B g 51: 0 ¡. B ~ L, B L,III r- · /I bIJ(,i - · ~l¥;\~!~¡¡¡¡¡¡¡\1if~!!i\i¡¡¡I\îìì&ììi¡'\¡TIi\î1;;iM;¡i;\ii:1¡A):;¡;;;:;4;j;;;1;;;~rillr1t%j~¡¡t\it1iiÝJ*M¡11jj¥Ât;i1 ,;,;""",:,:""",:,:"",1"""'1:":",',,, ',',1,1,'" 1"""""",'):,",",',1'1"""1 I I .~~~~i~.~~~4:'i~~'~i¡i:~~~]þ.~:f~~-~¡~"~Ji-'ì])~t~~~'~?f~-(·1j~f~~i1r.i.~i~'~I(á:1-' i~~-i~\'''.:I~~I~I~Ji~:¡-~~Il~1[~~~ri:t~Y~.fflf_ NATIONAL CITY BANK Ashland, Ohio U.S. Funds ACCOUNT$.'PA' ',Marathon Oil Company 'P;"Q.ßox 3128 ' Houston,TX 71253 77.80 _. I' ~ ~ ['].If·~: 111 ~ I ~ ~"}.."SW.:.':1 ~ II ~ [.... :J.:.' ~ I'Y" ~ I'. i: I :ttJ: l:(tJ ~t :f.:.t~ ;<ei :[.) 11 ~ I i'.:.':1:11 ~ .'J [.] ~ ~ ~ ~ I ~ I =I:] ~ ~'1"'..1{.] ~ I t.:.' I ~ ~~ I'j I [~:[.].~ :11 ~ (I ~ [t Rl\if'2šõffiEv.-5ÎÕÕ-:----:---:-----··-:-·-------"7"""- "...~--~_._--...,---:----_.,--._~----------.----' - - - .~- , -,---- '''-.'' ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K7'rA 32- 7/1 CHECK 1 ST ANDARD LETTER DEVELOPMENT /' DEVELOPMENT REDRll..L EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNULAR DI~OSAL f71 NO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, ,API No. . Production should continue to be reported as a function of the originaJ API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel' (na,me on permit). Annular disposal bas ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved.. . Annular Disposal of driUing wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. '. . ANNULUS L-> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill the above referenced well. Tbe permit is approved ,sùbject 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. (Company Name) will assume tbe liability of any protest to tbe spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY ß4,P( 4 -I'-~ WELL NAME ¡'¿r it \ :{¿ - "711 PROGRAM: Exp _ Dev ~ Redrll _ Serv _ Wellbore seg _ Ann. disposal para req _ FIELD & POOL L/t.j~>7() INITCLASS ~£i/ f-9~ GEOLAREA (~2/~ UNIT# ()...~//2..CJ ON/OFFSHORE ()n ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. ., . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP~'k DA T~ 12. Permit can be issued without administrative approval.. . . . . N /J 1.) 2. . .:J t, - D d..3.. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . . N l) yo; V t1/L ~ i /(!)o' TV f) , )_ 15. Surface casing protects all known USDWs. . . . . . . . . . @N AI( ~Jv,·¡¡';'.> ,.L>,-~$'tJ ~6>-7J 13Q:;:> ~~¿>(..Jr.{~CA.- ~~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ?i! N t./D c.t==- /Z- ILl7" ID2(j.::J)(i )(C '), ,..6"b ¡/ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ J\' 18. CMT will cover all known productive horizons. . . . . . . . . . 112.' NN I-\ck.--¡ w.;.t..c ~Ceç ~ U;;1d o('..G/I.f . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 'éiJ 20. Adequate tankage or reserve, pit.. . . . . . . . . . . . . . . , èj) N 4(OI.C{¡.-,r ( ~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ¥-.* /U/A r ,>'\~'\c.' ~~"'"> \.-.~~ ~~" ~~",~cJ 22. Adequatewellbore separation proposed.. . . . , . . . . . . . ø N C[o Ç..(c. f C\"'P,PW¡Î- 5('. . c\"'\ \...\~~\\«>~~\\\",~ \c'l.~ ~è\ (.;x:c \ 23. Ifdiverterrequired,doesitmeetregulations. . . . . . . . . . h6J Itoll!;Ve.;ý't'eý "nA - ýe'bl-ur-.ec.. 1,ÞJ~'''ev, 1øAAL 2-5',035 {c)lO(ß). ., 24. Drilling fluid program schematic & equip list adequate. . . . . ~ NN , , \\---~~<- ~)\..}~~<::'ð G,~\O'I,\ 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . '-.1.1 t ~ ~ "-_ 26. BOPE press rating appropriate; test to 3000 psig. ~. N N\AA f :: '¡'S47 pc:. (. ,nJt..V:: c,<:;c¡ . þ~ :. '¿~OC' 'f t.i . . ~~"'-. ~~ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N) I~~~~~.~ \\...X.1\.~~~_.. 28. Work will occur without operation shutdown. . . . . . . . . . . N . Æ5ffl( 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Ÿ .@ ;:)(~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . (J) N ,"7 31. Data presented on potential overpressure zones. . . . , . . Y Y Î~$L,),-r=-~ ~Xfe.t.1-k-f ~ r~ ~6-Yh. <tn,;ry-n-td...{"" 10 ..s<!!~y!.J ~~.u '¿¡s. 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . YN APPR DATE 33, Seabed condition survey (if off-shore). . . . . . . . . . . . . yk Y N .ft "Z. U .DZ- 34. Contact name/phone for weekly progress reports [exploratoty'only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENG~E.ERING: UIC/Annular: COMMISSION: RPC_ TEr.lj:!r1Y/(')6<,.. COT SFD~ .._ . WGA yJG¡k DTS ¿I?.. 6 J 0 ~ . ~ JMH <-~1V\ \-\ ~/J'2lçJ 0 L- APPR DATE ~C? Æ 2-/ ~b I cJ '2. ~ P{;;(,-@ GEOLOGY APPR DATE l -\ .( Y N Y N Ii Jr- a . I 1_; ( I ,-W W-fLíAJ,.-Øovr' d'\) S }W~U ý"'óLú'.';> tel Commentsllnstructions: G:\geology\permits\checklist.doc