The URL can be used to link to this page

Home My WebLink About203-138Nolan 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: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. T40938BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T49038BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' 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): 10,500'N/A Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 4,750 psi Production 10,540 psi 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 N/A; N/A N/A; N/A 10,182' 6,268' 5,977' Beaver Creek Beluga Gas 20" 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 13CO 237D Same 10,144'3-1/2" ~1,966psi 10,462' See Schematic Length July 21, 2025 3-1/2" 10,462' Perforation Depth MD (ft): 7,288' See Attached Schematic 6,870 psi 3,060 psi 3,450 psi 165' 6,973' 165' 2,296' Size 144' 9-5/8"7,267' 2,275' MD Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 10,462' 10,160 psi 2,296' 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 FEDA028083 203-138 50-133-20525-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Ryan LeMay, Operations Engineer AOGCC USE ONLY Tubing Grade: ryan.lemay@hilcorp.com 661-487-0871 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: Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.08 08:55:54 - 08'00' Noel Nocas (4361) 325-482 By Grace Christianson at 9:41 am, Aug 15, 2025 CT BOP test to 3000 psi, if CT is used. 10-404 DSR-8/19/25BJM 8/15/25 Yes 8/15/25 Bryan McLellan X A.Dewhurst 15AUG25JLC 8/19/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.20 09:34:48 -08'00'08/20/25 RBDMS JSB 082025 Lease: State/Prov:Alaska Country:USA Angle/Perfs: 158' 21' 10/5/2023 3/19/2024 Well Name & Number:Beaver Creek Unit #13 A - 028083 County or Parish:Kenai Peninsula Borough Revised By:D Ambruz Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:1.3º / 100 ft @ 2,200'Maximum Deviation:28º @ 4,178' Date Completed:01/22/04 Ground Level (above MSL): RKB (above GL): TD 10,500' MD 10,182' TVD Excape System Details - 8 Conventional flappers - Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 7,749' Module 8 - 7,788' Module 7 - 7,986' Module 6 - 8,144' Module 5 - 8,183' Module 4 - 8,245' Module 3 - 8,416' Module 2 - 8,512' Module 1 - NA Excape System Details - BHP monitoring line volume tank located from 7,668' - 7,706' BC-13 Pad 3 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. PBTD 10,429' MD 10,111' TVD Permit #:203-138 API #:50-133-20525-00 Prop. Des:A - 028083 KB elevation:179' (21' AGL) Latitude: Longitude: Spud:11/9/2003 TD:12/6/2003 Rig Released:12/15/2003 @ 06:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 10,462' TVD 0' 10,144' 8-1/2" hole Cmt w/ 1,475 sks class G cmt TOC 3-1/2" Csg (1/16/04 CBL) - 6,730' Directional Data: KOP - 2,200' at 1.3 deg/100' build EOB - 4,178', 28.1 deg hole angle Drop - 4,240' @ 0.8 deg/100' Hold - 8,550', 1.0 deg hole angle to TD Tree cxn: 6-1/2" Otis LB20- LB30 Lease: State/Prov:Alaska Country:USA Angle/Perfs: 158' 21' 10/5/2023 7/7/2025 Well Name & Number:Beaver Creek Unit #13 A - 028083 County or Parish:Kenai Peninsula Borough Revised By:R LeMay Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:1.3º / 100 ft @ 2,200'Maximum Deviation:28º @ 4,178' Date Completed:01/22/04 Ground Level (above MSL): RKB (above GL): TD 10,500' MD 10,182' TVD Excape System Details - 8 Conventional flappers - Mod 1 - no flapper - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 7,749' Module 8 - 7,788' Module 7 - 7,986' Module 6 - 8,144' Module 5 - 8,183' Module 4 - 8,245' Module 3 - 8,416' Module 2 - 8,512' Module 1 - NA Excape System Details - BHP monitoring line volume tank located from 7,668' - 7,706' BC-13 Pad 3 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. PBTD 10,429' MD 10,111' TVD Permit #:203-138 API #:50-133-20525-00 Prop. Des:A - 028083 KB elevation:179' (21' AGL) Latitude: Longitude: Spud:11/9/2003 TD:12/6/2003 Rig Released:12/15/2003 @ 06:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 10,462' TVD 0' 10,144' 8-1/2" hole Cmt w/ 1,475 sks class G cmt TOC 3-1/2" Csg (1/16/04 CBL) - 6,730' Directional Data: KOP - 2,200' at 1.3 deg/100' build EOB - 4,178', 28.1 deg hole angle Drop - 4,240' @ 0.8 deg/100' Hold - 8,550', 1.0 deg hole angle to TD Tree cxn: 6-1/2" Otis LB20- LB30 From:McLellan, Bryan J (OGC) To:Ryan Lemay; AOGCC Records (CED sponsored) Cc:Donna Ambruz Subject:BCU 13 (PTD 203-138) sundry approval Date:Friday, August 15, 2025 3:28:37 PM Ryan, Hilcorp has verbal approval to proceed with the sundry that was submitted today for adding perfs to this well. If CT is required, BOP test pressure is 3000 psi. Notify inspectors for opportunity to witness the test. Gavin, please include this in the wellfile. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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: 5/31/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240531 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/25/2024 AK E-LINE JB/GR/RBP MPI 2-14 50029216390000 186149 5/8/2024 READ CaliperSurvey MPS-17 50029231150000 202173 5/14/2024 READ LeakPointSurvey PBU GNI-03 50029228200000 197189 5/21/2024 READ PressureTemperatureLog PBU GNI-04 50029233670000 207117 5/22/2024 READ CaliperSurvey PBU GNI-04 50029233670000 207117 5/20/2024 READ PressureTemperatureLog TBU K-12RD2 50733201560200 208088 5/17/2024 READ CaliperSurvey TBU K-17 50733202480000 173001 5/16/2024 READ CaliperSurvey Please include current contact information if different from above. T38865 T38866 T38867 T38868 T38869 T38869 T38870 T38871 BCU 13 50133205250000 203138 1/25/2024 AK E-LINE JB/GR/RBP Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.31 13:00:13 -08'00' 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: 3/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240319 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 12/5/2023 AK E-LINE Plug/Cement/Cutter GP ST 18742 37 (AN 37) 50733203940000 187109 11/12/2023 AK E-LINE PERF IRU 241-01 50283201840000 221076 2/25/2024 AK E-LINE Perf/GPT KU 13-06A 50133207160000 223112 2/9/2024 AK E-LINE GPT MPU CFP-02 50029212580000 184242 3/13/2024 READ CaliperSurvey NCIU A-18 50883201890000 223033 12/13/2023 AK E-LINE GPT/Plug/Perf PBU L-122 50029231470000 203051 3/2/2024 AK E-LINE LowerPatchPacker PBU L4-14 50029219730000 189098 11/22/2023 AK E-LINE PERF SRU 241-33B 50133206960000 221053 3/4/2024 AK E-LINE GPT/Cmnt/CIBP/Perf Please include current contact information if different from above. T38648 T38649 T38650 T38651 T38652 T38653 T38654 T38655 T38656 BCU 13 50133205250000 203138 12/5/2023 AK E-LINE Plug/Cement/Cutter Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.21 11:50:20 -08'00' 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: 3/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240315 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 12/6/2023 AK E-LINE Cement-JetCut BCU 13 50133205250000 203138 2/11/2024 AK E-LINE CIBP-Perf BCU 19RD 50133205790100 219188 2/20/2024 AK E-LINE Perf-CIBP BRU 232-26 50283200770000 184138 11/26/2023 AK E-LINE GPT-PLUG-PERF BRU 244-27 50283201850000 222038 2/27/2024 AK E-LINE GPT-Perf GP ST 18742 37 (AN- 37) 50733203940000 187109 11/22/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 11/3/2023 AK E-LINE GPT-PERF KBU 42-6 50133205460000 204209 2/16/2024 AK E-LINE Patch PBU L-122 50029231470000 203051 12/7/2023 AK E-LINE Patch NCIU A-12B 50883200320200 223053 12/6/2023 AK E-LINE Perf-GPT NCIU A-17 50883201880000 223031 12/10/2023 AK E-LINE Perf-GPT NCIU B-02 50883200900100 197210 3/9/2024 AK E-LINE GPT-Perf SRU 241-33B 50133206960000 221053 3/6/2024 AK E-LINE GPT-Cmnt-CIBP- Perf Please include current contact information if different from above. T38630 T38630 T38631 T38632 T38633 T38634 T38635 T38636 T38637 T38638 T38639 T38640 T38641 BCU 13 50133205250000 203138 12/6/2023 AK E-LINE Cement-JetCut BCU 13 50133205250000 203138 2/11/2024 AK E-LINE CIBP-Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.18 08:49:06 -08'00' 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 BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -08'00' 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: 3/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240307 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/9/2024 AK E-LINE GPT-Perf BCU 19RD 50133205790100 219188 1/25/2024 AK E-LINE Perf BCU 13 50133205250000 203138 12/8/2023 AK E-LINE CMT CUT END 2-34 50029216620000 186172 10/29/2023 AK E-LINE PERF KBU 42-6 50133205460000 204209 2/19/2024 AK E-LINE Perf MPU C-13 50029213280000 18567 2/15/2024 AK E-LINE Whipstock Please include current contact information if different from above. T38604 T38604 T38605 T38606 T38607 T38608 BCU 13 50133205250000 203138 BCU 13 50133205250000 203138 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.07 13:13:02 -09'00' 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. Some people who received this message don't often get email from eli.wilson@hilcorp.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Eli Wilson - (C) Cc:Regg, James B (OGC) Subject:RE: BCU BC-13 Coil Tubing 10-424 Form Date:Wednesday, January 31, 2024 3:46:37 PM Attachments:Fox 8 12-27-23 Revised.xlsx image001.png Eli, Attached is a revised report changing the start and finish date to 12/27/23. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Eli Wilson - (C) <Eli.Wilson@hilcorp.com> Sent: Friday, December 29, 2023 1:56 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: BCU BC-13 Coil Tubing 10-424 Form All, See attached Fox #8 Coiled Tubing BOPE test form for BCU BC-13. Thanks, %HDYHU&UHHN8QLW 37' revised report start and finish date Eli Wilson Wellsite Supervisor, GPB / CIO / KEN Hilcorp Wells Group Cell: 907-342-9840 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:8 DATE: 12/27/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22031380 Sundry #323-623 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular: Valves:250/3500 MASP:2136 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 2 1.75" Hydrolic P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" Pipe Rams P Flow Indicator NA NA #2 Rams 1 Blind/Shears P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2-1/16"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)2950 P Kill Line Valves 2 2-1/16"P Pressure After Closure (psi)2250 P Check Valve 0NA200 psi Attained (sec)4 P BOP Misc 0NAFull Pressure Attained (sec)19 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4/1400 P No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 21 P Coiled Tubing Only:#2 Rams 22 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.5 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/26/2023 Waived By Test Start Date/Time:12/27/2023 13:30 (date) (time)Witness Test Finish Date/Time:12/27/2023 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Test fluid: FW. Coil BOPE Test. Tested Combi Pipe/Slips and BS rams to 250 psi low / 3500 psi high as per BLM sundry. AOGCC sundry 3000 psi. Terrence Rais Hilcorp Eli Wilson BCU 13 Test Pressure (psi): trais@foxak.com eli.wilson@hilcorp.com Form 10-424 (Revised 08/2022)2023-1227_BOP_Fox8_BCU-13 +LOFRUS$ODVND//&MEU 9 9 9 99 9 99 9 9 -5HJJ MEU 9 1 Junke, Kayla M (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, January 8, 2024 3:31 AM To:Chad Helgeson; Rixse, Melvin G (OGC) Cc:Donna Ambruz; Scott Warner Subject:RE: BC-13 (PTD# 203-138) Sundry # 323-623 Cement Bond Log Chad, Hilcorp has approval to proceed with the perforaƟons per the approved sundry. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Sunday, January 7, 2024 2:03 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Scott Warner <Scott.Warner@hilcorp.com> Subject: BC‐13 (PTD# 203‐138) Sundry # 323‐623 Cement Bond Log Bryan/Mel, AƩached is the CBL we ran on BC‐13 Annulus cement job. The Proposed TOC for this job was ~5000 and we have cement to 4940’. Our top proposed perf for this project is 6163. Per Sundry # 323‐623, we are required to send this to you and wait for approval to perforate. We plan to perforate Tuesday if we get approval from AOGCC. Please review and let us know if we have approval to proceed with Step 22. Chad Helgeson Operations Engineer Kenai Asset Team 907‐777‐8405 ‐ O 907‐229‐4824 ‐ C 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. 1 Junke, Kayla M (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Wednesday, January 3, 2024 5:20 PM To:McLellan, Bryan J (OGC); Maercklein, William C Cc:Stephen Garcia - (C); Donna Ambruz Subject:BC-13 (PTD# 203-138) Sundry # 323-623 Cement retainer change Bryan/Will, We ran into a snag before we started pumping our cement annulus isolaƟon. Last week we were rigged up and planning the job, but we cancelled it aŌer pumping the ball to set our cement retainer due to cold weather, so we set the cement retainer on proposed depth. We are on step 4 of the 3‐1/2” x 9‐5/8” IA cemenƟng procedure. So we waited unƟl warmer weather and aŌer the new year. Yesterday we tried to sƟng into the retainer and were unsuccessful, (we believe due to some sand that got int eh ﬂuid somehow and plugged up the cement retainer). I wanted to let you know that we are conƟnuing with our conƟngency plan if we were unable to get circulaƟon (step 7 in Eline procedure). We are going to cut the tubing again (above where we set the cement retainer ~6500’) establish circulaƟon and pump a fullbore cement job instead of the through coil cement retainer. We will leave a minimum of 50Ō of cement above the cut (per BLM COAs) and take the cement on the backside sƟll to ~5000’. ‐ Proposed TOC in tubing will be 6450. ‐ Proposed TOC in annulus will be 5000 sƟll. I am wriƟng to inform you of this change, but I think we are sƟll covered from the conƟngency we wrote in the Sundry, although slightly different. If you have any issue with this change or quesƟons, please let me know as we plan to execute the work tomorrow. Thanks Chad Helgeson Operations Engineer Kenai Asset Team 907‐777‐8405 ‐ O 907‐229‐4824 ‐ C 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: 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. 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: 11/30/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231130 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 11/13/2023 YELLOW JACKET GPT BCU 13 50133205250000 203138 10/5/2023 YELLOW JACKET PERF KBU 13-08 50133203040000 177029 10/16/2023 YELLOW JACKET CALIPER KU 12-17 50133205770000 208089 10/4/2023 YELLOW JACKET CALIPER/TEMP KU 24-7RD 50133203520100 205099 10/4/2023 YELLOW JACKET CALIPER MPU B-32 50029235700000 216151 9/20/2023 YELLOW JACKET RCT MPU L-47 50029235500000 215117 10/25/2023 YELLOW JACKET CUT NS-05 50029232440000 205009 9/9/2023 YELLOW JACKET PERF NS-16A 50029230960100 206141 9/12/2023 YELLOW JACKET PERF NS-20 50029231180000 202188 9/11/2023 YELLOW JACKET PERF NS-24 50029231110000 202164 9/10/2023 YELLOW JACKET PATCH PTM P1-13 50029223720000 193074 10/24/2023 YELLOW JACKET PL Please include current contact information if different from above. T38164 T38164 T38165 T38166 T38167 T38168 T38169 T38170 T38171 T38172 T38173 T38174 12/1/2023 YELLOW BCU 13 50133205250000 203138 11/13/2023 JACKET GPT YELLOW BCU 13 50133205250000 203138 10/5/2023 JACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 10:42:44 -09'00' 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: 11/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-13 50133205250000 203138 11/13/2023 HALLIBURTON RMT3D MPU B-28 50029235660000 216027 11/20/2023 HALLIBURTON LDL MPU B-28 50029235660000 216027 11/21/2023 HALLIBURTON MFC MPU C-20 50029219140000 189015 11/21/2023 HALLIBURTON LDL NS-24 50029231110000 202164 11/20/2023 READ LeakPointSurvey PBU 13-20 50029207050000 182009 11/16/2023 HALLIBURTON WFL-TMD3D PBU L-216 50029232060000 204065 7/20/2023 PROBE MSIL (CBL) PBU S-09A 50029207710100 214097 7/7/2023 PROBE MSIL (CBL) PBU S-32A 50029220990100 212082 7/13/2023 PROBE MSIL (CBL) PBU S-124 50029233230000 206136 7/15/2023 PROBE MSIL (CBL) Please include current contact information if different from above. T38150 T38151 T38151 T38152 T38153 T38154 T38155 T38156 T38157 T38158 11/29/2023 BCU-13 50133205250000 203138 11/13/2023 HALLIBURTON RMT3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.29 11:22:45 -09'00' David 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: 11/27/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: BCU 13 PTD: 203-138 API: 50-133-20525-00-00 Compensated Sonic - CBL 1/16/2004 Please include current contact information if different from above. PTD: 203-138 T38148 11/28/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.28 08:46:01 -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: Cement Annulus 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): 10,500'N/A Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 4,750 psi Production 10,540 psi 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 chelgeson@hilcorp.com 907-777-8405 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 Chad Helgeson, Operations Engineer AOGCC USE ONLY 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 FEDA028083 203-138 50-133-20525-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 10,462' 10,160 psi 2,296' Size 144' 9-5/8"7,267' 2,275' MD See Attached Schematic 6,870 psi 3,060 psi 3,450 psi 165' 6,973' 165' 2,296' November 30, 2023 3-1/2" 10,462' Perforation Depth MD (ft): 7,288' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 13CO 237D Same 10,144'3-1/2" ~2,136psi 10,462' N/A Length N/A; N/A N/A; N/A 10,182'10,429'10,111' Beaver Creek Beluga Gas 20" 13-3/8" See Attached Schematic m n P s 66 t s 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 10:52 am, Nov 17, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.16 14:32:12 - 09'00' Noel Nocas (4361) A.Dewhurst 21NOV23 DSR-11/20/23BJM 11/27/23 MITIA to 2000 psi within 30 days after returning well to production. CT BOP test to 3000 psi 10-404 X *&:JLC 11/28/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.28 13:30:37 -09'00'11/28/23 RBDMS JSB 113023 BCU-13 Cement Annulus Well Name: BCU-13 API Number: 50-133-20525-00-00 Current Status: Offline Gas Well Permit to Drill Number: 203-138 First Call Engineer: Chad Helgeson (907) 777-8405 (O)(907) 299-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Maximum Expected BHP: 2,747 psi @ 6106’ TVD 0.45 psi/ft gradient at TD MASP: 2,136 psi BHP minus 0.1 psi/ft gradient Well History: BCU-13 was completed in Jan. 2004. Perforations were added in 2014. The well was cleaned out with coil in 2023, and several zones were reperforated. The well did not flow post coil work in 2023 with any sustained production. The goal of this sundry is to plugback the lower Beluga, pump a cement annulus isolation job and perforate the upper Beluga. All existing and proposed perfs are in the Beluga Gas Pool/PA. Notes Regarding Wellbore Condition x 3-1/2” cement top @ 6,730’ per CBL dated 1/16/04 x Cement on 9-5/8” was circulated to Surface x Max Inclination = 28.1 degrees at 4178’ MD x Current fluid level – 4930’ (Eline GPT 11-13-23) E-Line procedure 1. RU pump truck and batch mixer. Mix 8 bbls of 9.4 ppg NaCl corrosion inhibited brine (~1,300ft of KW fluid) Pump into well followed by 106 bbls of PW. To kill well and place original drill weightmud between plugs 2. MIRU E-line and pressure control equipment PT lubricator 250psi low / 2,500psi high. 3. MU 3-1/2” CIBP, RIH and set 3-1/2” CIBP plug at ±7,656’ MD (do not set across a collar) a. Tag plug after set and confirm tag b. BLM Regulations call for plug to be set 50’-100’ of perfs @ 7,708’ MD 4. RIH and dump bail 35’ of cement on top of plug (planned est ToC ±7,623’ MD) 5. Pressure tubing to 700 psi with 0 psi on annulus o 9-5/8” x 3-1/2” Annulus is 10.5 ppg drilling mud 6. MU and RIH with jet cutter o Cut tubing at ±6,590’ MD (~8ft above collar) 7. Establish circulation from tubing to IA o If unable to establish circulation, run CBL to see if solid mud is settled and evident on shallowe r o Repeat cut ~50ft shallower if CBL doesn’t indicate any solids buildup 8. RDMO EL 9. Once circulation is established in both directions, circulate a minimum of 500 bbls of fluid (until returns are clean): o IA volume = ~404 bbls i. 3-1/2” x 9-5/8” = 0.0613 x 6,590ft = ~404 bbls o Tubing volume = 0.0087 bbl/ft x 6,590ft = ~57 bbls 10. CMIT-TxIA to 2500psi (no chart required) – ensure tubing punch did not rupture casing BCU-13 Cement Annulus 3-1/2” x 9-5/8” IA Cementing Procedure 1. MIRU CTU, 24hr notice for BOP test 2. Conduct BOP test to 250psi Low / 3500psi High 3. RIH with 3-1/2” Cement retainer on 1.75” coil tubing and set @ 6490’, establish circulation up 3-1/2” x 9-5/8” annulus 4. RU cement truck, PT lines to 250psi low / 3,000psi high 5. Mix and pump ~15.3ppg cement down the coil, taking returns up the 3-1/2” x 9-5/8” IA o Manage IA back pressure to keep the cement from running away down tubing 6. Planned TOC in IA is ±5,000’ MD. (±67 bbls required) a. 0.0613bbl/ft x 1590ft =97 bbls 7. Displace per OE to cement retainer, 57bbls with fresh water b. 0.0087 bbl/ft x 6,575ft = ~57 bbls c. use wiper ball down coil if available 8. Unstab coil from retainer, circulate 50 bbls 9. Test cement retainer float (check valve) o If necessary trap pressure on the tubing (~600psi) with annulus pressure at 0 psi to ensure cement doesn’t u-tube 10. RDMO cementers 11. POOH with coil 12. Wait minimum of 24hrs on cement 13. MIRU EL and pressure control equipment 14. PT lubricator to 250psi Low / 2,500 psi High 15. RIH and tag TOC and complete CBL (submit CBL to AOGCC and obtain approval before perforating) 16. RD EL 17. MIT-IA to 2500psi for 30 charted minutes 18. RIH with coil tubing and tag retainer with a nozzle to drift tubing for perf guns 19. Reverse lift water from wellbore (recover ~57 bbls) 20. Trap N2 pressure on tubing per OE/RE recommendation for perforating, ~1800 psi (25% underbalanced) 21. RDMO CT E-Line Perf procedure 22. MIRU E-line and pressure control equipment 23. PT lubricator to 250psi low / 2500 psi High 24. RIH and perforate as directed by reservoir team Pool/PA Zone Top MD Btm MD TopTVD Btm TVD Amt Beluga BEL5 ±6,163’ ±6,170’ ±5,876’ ±5,883’ ±7 Beluga BEL5 ±6,209’ ±6,216’ ±5,920’ ±5,927’ ±7 Beluga BEL6 ±6,235’ ±6,260’ ±5,946’ ±5,969’ ±25 Beluga BEL7 ±6,276’ ±6,288’ ±5,985’ ±5,996’ ±12 Beluga BEL7 ±6,304’ ±6,318’ ±6,012’ ±6,025’ ±14 Beluga BEL8 ±6,337’ ±6,366’ ±6,044’ ±6,070’ ±29 Beluga BEL8 ±6,384’ ±6,402’ ±6,089’ ±6,106’ ±18 97 bbls per Chad Helgeson email 11/27/23. -bjm Displacement volume should be CT volume, not production tubing volume. -bjm BCU-13 Cement Annulus a. Proposed perfs are also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot and record. e. These sands are in the Beluga Gas Pool per CO 237D. 25. Turn well over to operations and flow the well. If the well is productive the rest of the perfs will not be completed on this sundry. Post-Perf MIT-IA 26. Perform MIT-IA to 2000psi once job is complete and well has been brought online within 30 days. E-line Procedure (Contingency) If any zone produces sand and/or water or needs isolated: 1. MIRU Eline 2. Pressure test equipment to 2,500 psi High/250 psi Low 3. Eline run PT to find fluid level 4. Use N2 or Gas Lift to push fluid below perfs (verify fluid depth with PT tool) 5. PU 3-1/2” CIBP, WRP, or patch a. If a CIBP is set (it must be set within 50ft of the top perf being plugged back) Note: All proposed perforations are in the same Pool / PA. A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together in same PA. 6. If necessary to cleanout or unload well with coiled tubing, a. MIRU coil equipment (provide 24hr notice as necessary for BOP witness) b. Test BOPs, 3,000 psi High/ 250 psi Low c. Cleanout using water & N2 d. Set 3-1/2” plug or patch e. Blow well dry with coil using N2. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations 4. Fox BOP Schematic 5. Schlumberger BOP Schematic 26.Perform MIT-IA to 2000psi once job is complete and well has been brought online within 30 days. Lease: State/Prov:Alaska Country:USA Angle/Perfs:1ºĺ3º 158' 21' 10/5/2023 10/11/2023 Well Name & Number:Beaver Creek Unit #13 A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:1.3º / 100 ft @ 2,200'Maximum Deviation:28º @ 4,178' Date Completed:01/22/04 Ground Level (above MSL):RKB (above GL): TD 10,500' MD 10,182' TVD Excape System Details - 9 Excape modules placed -Green control line fires bottom module -Red control line fires top 8 modules - Ceramic flapper valves below each moduleExcape System Details -8 Conventional flappers -Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 7,749' Module 8 - 7,788' Module 7 - 7,986' Module 6 - 8,144' Module 5 - 8,183' Module 4 - 8,245' Module 3 - 8,416' Module 2 - 8,512' Module 1 - NA Excape System Details -BHP monitoring line volume tank located from 7,668' - 7,706' BC-13 Pad 3 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. PBTD 10,429' MD 10,111' TVD Permit #: 203-138 API #: 50-133-20525-00 Prop. Des: A - 028083 KB elevation: 179' (21' AGL) Latitude: Longitude: Spud: 11/9/2003 TD: 12/6/2003 Rig Released: 12/15/2003 @ 06:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 10,462' TVD 0' 10,144' 8-1/2" hole Cmt w/ 1,475 sks class G cmt Capillary Tubing 3/8" 2205 Stainless Steel Top Bottom MD 0' 0' TVD 0' 0' (***Pulled 05/14/2009***) SCHEMATIC TOC 3-1/2" Csg (1/16/04 CBL) - 6,730' Directional Data: KOP - 2,200' at 1.3 deg/100' build EOB - 4,178', 28.1 deg hole angle Drop - 4,240' @ 0.8 deg/100' Hold - 8,550', 1.0 deg hole angle to TD Tree cxn: 6-1/2" Otis LB-20A LB-20B LB-21 LB-23ALB-23B LB-25 LB-25 LB-26 LB-27 LB-27 LB-29 LB-29 LB-29 LB-29 LB-30 LB-30 LB20- LB30 Lease: State/Prov:Alaska Country:USA Angle/Perfs:1ºĺ3º 158' 21' 10/5/2023 11/16/2023 Well Name & Number:Beaver Creek Unit #13 A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Chad Helgeson Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:1.3º / 100 ft @ 2,200'Maximum Deviation:28º @ 4,178' Date Completed:01/22/04 Ground Level (above MSL):RKB (above GL): TD 10,500' MD 10,182' TVD Excape System Details -8 Conventional flappers -Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 7,749' Module 8 - 7,788' Module 7 - 7,986' Module 6 - 8,144' Module 5 - 8,183' Module 4 - 8,245' Module 3 - 8,416' Module 2 - 8,512' Module 1 - NA -Green control line fires bottom module -Red control line fires top 8 modules Excape System Details -BHP monitoring line volume tank located from 7,668' - 7,706' BC-13 Pad 3 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. PBTD 10,429' MD 10,111' TVD Permit #: 203-138 API #: 50-133-20525-00 Prop. Des: A - 028083 KB elevation: 179' (21' AGL) Latitude: Longitude: Spud: 11/9/2003 TD: 12/6/2003 Rig Released: 12/15/2003 @ 06:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 10,462' TVD 0' 10,144' 8-1/2" hole Cmt w/ 1,475 sks class G cmt PROPOSED SCHEMATIC TOC 3-1/2" Csg (1/16/04 CBL) - 6,730' Directional Data: KOP - 2,200' at 1.3 deg/100' build EOB - 4,178', 28.1 deg hole angle Drop - 4,240' @ 0.8 deg/100' Hold - 8,550', 1.0 deg hole angle to TD Tree cxn: 6-1/2" Otis LB20- LB30 Tbg cut @ 6590' 9.4 ppg KWF Proposed TOC @ ~5000' Cmt retainer @ CIBP @ 7656' w/ 35ft of 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. Coiled Tubing BOP Dressed for 1.75” CT 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO, N2 Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 6268, 6347, Total Depth measured 10,500 feet 6380, 6502, 7656 feet true vertical 10,182 feet N/A feet Effective Depth measured 6,268 feet N/A feet true vertical 5,977 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 10,462' MD 10,144' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Scott Warner, Operations Engineer 323-623 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 165' 0 04563 0 6810 1131 measured TVD 9-5/8" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-138 50-133-20525-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028083 Beaver Creek / Beluga Gas Beaver Creek Unit (BCU) 13 Plugs Junk measured Length Production Liner 7,267' 10,462' Casing Structural 6,973' 10,144' 7,288' 10,462' 165'Conductor Surface Intermediate 20" 13-3/8" 144' 2,275' 4,750psi 10,540psi 3,060psi 3,450psi 6,870psi 10,160psi 2,296'2,296' Burst Collapse 1,500psi 1,950psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.03.22 11:49:22 -08'00' RBDMS JSB 040224 DSR-3/29/24 Page 1/4 Well Name: BCU-013 Report Printed: 3/14/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:11/13/2023 End Date: Report Number 2 Report Start Date 12/5/2023 Report End Date 12/6/2023 Operation PJSM and PTW, Spot in Ak-Eline unit and mast truck. R/u Fox fluid pump and lines, P/t 250-2500psi. Lined up down Tubing and Pumped 8bbls of 9.4ppg corrosion inhibited brine followed by 106bbls of PW at 2bpm/2000psi. R/d fox pump. M/u tools and stab on well, PT lubricator 250-2500psi. RIH CCL, wt bars, setting tool and 2.75"OD CIBP for 3-1/2" tbg. Pull correlation pass, Set CIBP @ 7656'md. Picked up then tag plug and confirmed set. POOH. L/d setting Tools. M/u 2.5" x 30' dump bailer, load with 5gals of cement. RIH and dump cement on CIBP at 7656'. POOH. L/d EL for night. M/u 2.5" x 30' dump bailer, load with 5gals of cement. RIH and dump cement on CIBP at 7656'. POOH. L/d EL for night. Report Number 3 Report Start Date 12/6/2023 Report End Date 12/7/2023 Operation Held PJSM and approved PTW. Warmed up equipment M/u 2.5" x 30' dump bailer, load with 5gals of cement. RIH and dump cement on CIBP at 7656'. POOH. Made 3 more bail dump trips, total of 5 bailer runs and dumped a total of 35gals = 70' of cement on CIBP. TOC @ 7586'. M/u GR/CCL, Wt Bars and 2.5" jet cutter for 3-1/2" Tbg. CCL to cutter offseat = 20.8'. RIH correlate. Spot CCL at 6569.2. R/u Pump Truck and pressured up on tbg and trapped 700psi. Cut Tbg at 6590'(8' above collar) presure fell from 700psi to 350psi. No change in IA pressure. POOH. L/d tools and SDFN. Report Number 4 Report Start Date 12/8/2023 Report End Date 12/9/2023 Operation Report Number 5 Report Start Date 12/27/2023 Report End Date 12/28/2023 Operation Move CTU from Fox energy shop to location. PJSM & PTW w/Production. Pull wellhouse w/Cruz crane support. Spot CTU & PCE trailer. N/U BOPE stack and flow cross to wellhead. R/U 2" 1502 hardline to choke and return tank. Completed BOPE testing as per AOGCC/BLM Sundry 250 psi low / 3500 psi high. AOGCC waived witness (12/26/23 14:53 pm, Jim Regg). Pre load MEOH spear in coil and c/o packoffs. Secure well, shut off equipment, and SDFN. Report Number 6 Report Start Date 12/28/2023 Report End Date 12/29/2023 Operation Complete PJSM / PTW w/Production. Cruz 75 ton crane sheave is frozen. Troubleshoot. MIRU Fox coil w/75 ton crane support. Pick up injector head. Stab on well. Fluid pack reel w/meoh spear followed by 28 bbls of FW. Shell test BOPE to 250 psi low / 3500 psi. Unstab from well. Pressure test CTC to 3500 psi. M/U BHA = 2.25" x .85' CTC, 2.13" x 1.58' Disco (5/8" ball), 2.125" x 6.75' Hyd Setting Tool (1/2" ball), 2.75" x .95" WLAK, 2.75" x 1.55' SV Cement Retainer. BHA OAL = 9.39'. RIH w/YJ CMT Retainer BHA. Pump min rate while RIH. Load & launch 1/2” ball. Fox coil pump cavitating. Having issues moving fluid. Fox pump problems. Swap to cement pump. Discuss cold weather issues and plan forward w/OE. Set retainer 6,502’ ctm. Unsting from retainer. Pooh pumping min rate. POOH w/BHA while pumping min rate. In lubricator w/BHA. Unstab from well and verify setting tool is fully stroked and retainer is gone. Stab on well. Blow reel down with N2 (28 MSCF). Blow down surface lines w/N2. Unstab from well, install tree cap, break down riser, and lay down injector head. SDFN. Report Number 7 Report Start Date 1/2/2024 Report End Date 1/3/2024 Operation PJSM and fill out PTW. Spot coil unit. R/U 2” 1502 hardline from reel to choke. Pick up injector head. M/U YJ Cmt Stinger BHA and stab on well. 400 bbl upright on location, spot tank. Load 125 bbls of 120 degree FW in tank. RIH w/YJ cement stinger BHA pumping min rate. Depth: 4250’ ctm, Circ: 414 psi, WHP: 71, RIHW 10k. Depth 6,200’. Shut in CTBS. Pressure up tubing to 480 psi and test retainer. Good test. Bleed pressure off. Tag & sting into retainer @ 6,510’ ctm. Put 6k down. Unable to circulate up IA. Stack more weight. No circulation up IA. Unsting and circulate down coil and up CTBS no issues. Wash down .5 bpm at 450 psi. Sting into retainer 9k down. Circ pressured up. Unsting and coil is locked up, possibly picked up some fill. Pooh w/BHA On surface w/bha, setting tool plugged with what appears to be sand, small cement chunks. Tear down setting tool and clear. RIH w/YJ stinger BHA. Sting into retainer @ 6,502' ctm, pumping, dry, changing speed. Unable to establish circulation through retainer. API: 50-133-20525-00-00 Field: Beaver Creek Sundry #: 323-623 State: ALASKA Rig/Service:Permit to Drill (PTD) #:203-138 Page 2/4 Well Name: BCU-013 Report Printed: 3/14/2024www.peloton.com Well Operations Summary Operation Unsting from retainer. PT tubing above retainer to 1000 psi, good test. Discuss plan forward w/OE. Pooh w/BHA pumping PD. 2000’, blow down reel w/N2 while pooh. Write manifests for return tank fluids. On surface w/BHA. Secure well. Begin rigging down. SDFN. Report Number 8 Report Start Date 1/4/2024 Report End Date 1/5/2024 Operation PJSM & PTW. Review plan forward w/Eline & Cement crew. Spot unit and crane. Begin rigging up Ak Eline 9/32” cable. Install P-sub on well. Pick up grease head and risers. M/U BHA CH, WB, GG, 2.5” jet cutter. RIH w/2.50” jet cutter. Tag cement retainer @ 6,491’ elm. Pull up to 6,471’ + 10.5’ = 6,481.5’ elm - cut depth. Cut tubing, good indication on voltage, weight indicator, and line. Pooh w/tools. Unstab from well. Jet cutter fired. Install tree cap on P-sub. Rig up 2” 1502 from cement unit to P-sub on wellhead. Spot FW truck. Online down tubing w/cement pump 2 bpm. At 4.3 bbls away got good returns off IA to return tank. Shut in and PT lines to 3000 psi. Circulate Tbg x IA. 3 bpm 440 psi, 5 bpm 730 psi. Off pump. Return tank = 72 bbls. Cement wet, verify weight on mud scale = 15.2 ppg. Online w/#15.2 ppg cement down tubing while taking returns up 9-5/8" x 3-1/2" annulus. 97 bbls of cement away, off pump. Launch 3-1/2" wiper plug. Displace wiper plug w/56 bbls of FW, hold back pressure on IA while cement turns corner. Final tubing pressure 610 psi, IA zero. Shut in IA and tubing to lock in pressures on well. Wash up cement pump. Pull remaining fluid from return tank. Return tank = 220 bbls. Calculated IA TOC = 5000'. Calculated Tbg TOC = 6,450'. R/D cement pump and hardline. Install parachute on wellhead and install heater. Report Number 9 Report Start Date 1/6/2024 Report End Date 1/7/2024 Operation PJSM & PTW. Review plan forward w/Eline & Cement crew. Spot unit and crane. Spot Eline unit. Tie CH 6/2. Set up crane. Lay out and make up risers and trolley. M/U grease head. Pick up riser & PCE. Stab on well. PT 250 psi / 3000 psi. RIH w/CCL, Junk Basket w/2.55” GR. PUW #1000 @ 5,500’. #1200 @ 6,100’. Tagged 6,356’. Pulled up to 6,250’ and hung up in grease head. Troubleshoot ice in grease head. Shut BOP, unstab above BOP and clamp cable. Pump MEOH to flow tubes. Pull wire down from grease head. Cable is good. Flow tubes were froze up. Re-tag TOC 6,356’ elm. Pooh w/BHA. OOH w/empty junk basket. M/U CBL BHA. RIH w/CBL BHA. Log CBL from 6,329' up to 4,800' @ 75 fpm. IA TOC = 4,936’ corrected, Tubing TOC = 6,329’ corrected. Secure well. RDMO AK Eline. Report Number 10 Report Start Date 1/7/2024 Report End Date 1/8/2024 Operation PJSM and fill out PTW. Spot coil unit. N/U flow cross and BOPE stack to well. R/U 2” 1502 hardline from reel to choke. Pick up injector head and stab on well. Fill reel w/FW. Function test BOPE rams. Shell test BOPE stack 250 psi low / 3500 psi high as per AOGCC approval email 12/12/23 (Jim Regg). Fox tractor having regen issues, mechanic on location. Blow reel dry w/N2 and bring out spare tractor to run CTU hydraulics. SDFN. Will continue job in the morning w/spare tractor. Release YJ and Cruz. SDFN. Report Number 11 Report Start Date 1/8/2024 Report End Date 1/9/2024 Operation PJSM & PTW. Review plan forward w/Coil crew. Pick up injector head and stab on well. Fill reel w/FW. Good returns at tank. Function BOPE, shell test 250 psi low / 3500 psi high. Unstab from well. M/U CTC, PT to 3500 psi. Pull test 20k. M/U YJ milling bha = 2.18" CTC, 2.12" DFCV, 2.12" Bidi Jars, 2.12" Disco (5/8" seat), 2.12" Circ Sub (9/16" seat), 2.12" Motor, 2.75" Tri Cone Bit. BHA OAL = 21.30'. RIH w/YJ milling BHA. PUW 15k @ 5,000’ ctm. See bobble 6,330’ ctm, pass through. Dry tag TOC 6,397’ ctm. PUH and establish free spin 1.25 bpm / 2200 psi. Milled cement 6,397’ to 6,425’ ctm. 200-300 psi motor work. Pumped 37 bbl bottoms up. Make wiper trip up to 6,300’. RIH to 6,422' ctm. Load & launch 9/16” ball. 28 bbls away, ball seated. Shear circ sub 1750 psi. Return tank volume = 100 bbls. Online w/N2. RIH to 6422 to circ out fluid. 30 bbls of 65.75 bbls recovered. N2 at BHA pumping at 800-1000scfm. Begin pooh pumping N2. 65 bbls of 65.75 bbls of returns. Pooh w/BHA. In lubricator w/BHA. Trap 1800 psi of N2 on well. Unstab from well. B/D YJ BHA. Recovered 9/16” ball. R/D kill/choke side iron. R/D BOPE stack & flow cross. Travel to shop. API: 50-133-20525-00-00 Field: Beaver Creek Sundry #: 323-623 State: ALASKA Rig/Service: Page 3/4 Well Name: BCU-013 Report Printed: 3/14/2024www.peloton.com Well Operations Summary Report Number 12 Report Start Date 1/9/2024 Report End Date 1/10/2024 Operation PJSM, Crew Start & warm up equipment, Skid equipment & unit to location, Spot in & rig up equipment. Pressure test lube & valves 250 low/2500 high. Pick up & make up GPT & run in hole, Fluid Level 6238' Tagged @ 6421' Log from 6391' to 5000'. Send to town. Shift 5' down, Pull out of hole, Lay down GPT, Pick up 1 x 20' x 2-3/8", 6 spf, 60 deg, 10.8 grams, Run in hole & tag @ 6421' & perform, Correlation pass from 6421' to 5100', Send to town for verification, On depth, TS-CCl-9.1', Pull onto depth 6375.9', Perf Bel 8 @ 6385'-6405', OG psi: 1682, 5-1678, 10-1677, 15-1673, Pull out hole, Lay down tools for the night, Hand over to production for the night. Report Number 13 Report Start Date 1/10/2024 Report End Date 1/11/2024 Operation PJSM, Start & warm equipment. Pick up & test lube 250/2500-good, Run in hole with CCL/GR/GPT, Fluid level @ 5290', Tag Bottom @ 6421', Pull out of hole, Pick up & run 2.80" gauge ring 6367', Pull out of hole, Rig up N2 & push fluid away, Start & warm up N2 unit, Spot in & rig up, Issues priming pump work on N2 unit, Line test to 4000 psi good, Pressure up on well to 4000 psi, no break. shut down. Pick up & run in the hole with CCL/GR/GPT, Run in hole to tag fluid @ 6404' Pull out of hole to surface, Pick up 2.75" CIBP, Run in hole & correlate set @ 6380'. Tag & confirm-good, Pull out of hole to pick up 2-3/8" x 20' gun, Run in hole & pull correlation pass from 6380' to 5000', send to town (confim on depth), Pull on depth CCl-TS=8.7', perfing BEL 8 sands from 6346' to 6366', OG PSI: 1808, 5-1816, 10-1825, 15-1837, Pull out of hole, Secure well, Lay down gun & eline lube, Flow well to 1300 psi no LELS detected, Monitor build 10 psi per min. Hand over to production. Report Number 14 Report Start Date 1/11/2024 Report End Date 1/12/2024 Operation PJSM, Start & warm equipment Pick up & test lube 250/2500-good, PIck up CCL/GR/GPT, Run in hole to find fluid @ 6350' (light fluid), Tag bottom @ 6380' (no fill), Pull out of the hole logging, Overpull on line @ 840', Check wellhead frozen in wellhead. Rig up methenol pump pump methonal & diesel into lube with triplex. LIne free check up & down-good. Pull out the hole, lay down CCl/GR/GPT, PIck up gun #3, Run in hole to perf BEL 8/7 sands @ 6325'-6345' (20'), Pull out of hole with monitoring pressure OG- 1638, 5-1636, 10-1633, 15-1629, Lay down gun #3, Pick up Gun #4 run in hole & perf BEL 7 sands @ 6326'-6306', Pull out of hole while monitoring pressure, OG- 1621, 5-1617, 10-1615, 15-1612, Secure well, Lay down tools & equipment, Hand over to production to flow test. Report Number 15 Report Start Date 1/20/2024 Report End Date 1/21/2024 Operation AKE-ine arrives at BC office, PTW, PJSM and mobe to well site. Spot e-line and support equipment. M/U GPT / JBGR with 2.30" gauge ring. PT 250/2500 psi. Pass. Open swab with well flowing at 710 psi / 3.5-3.75 mcf. Tied in with BEL-7 correlation and tagged PBTD at 6364' (BEL 7/8 perfs: 6306'-6366'). CIBp at 6380'. Notable pressure deflection at 6342'. POOH. M/U PL tool string with GR/CCL/Press/Temp/Cap/Spinner, perform surface cals, move to well head. Open swab and RIH. At 5800' start dynamic down pass at 20 fpm to 6360'. Repeat up pass at 20 fpm to 5800'. Repeat sequence at 40 and 60 fpm. Drop down and perform station stops at 6360'. 6340', 6320', 6300' and 6250'. POOH. OOH. Secure well. RDMO e-line. Report Number 16 Report Start Date 1/26/2024 Report End Date 1/27/2024 Operation Travel to Beaver Creek office. PJSM & Permit. Travel to location. R/D AK E-Line off BCU-19RD. Swap out unit over mechanical. MIRU AK E-Line. PT 250/3000 PSI. Test good. Attempt RIH w/ 2.87" GR - Junk Basket - CCL. Great deal of trouble getting through transition square edge in cap. RIH w/ 2.87" GR - Junk Basket - CCL w/ well flowing. Original sit down was 6347'. Worked tools. Was able to get to 6365'. Perfs are 6306' to 6366' Log up hole to 5100' to capture short joint at 5189'. Sent log to town. POOH. OOH. L/D lubricator. Nite cap well. Secure equipent. SDFN. - Plan forward: Set RBP. Report Number 17 Report Start Date 1/27/2024 Report End Date 1/28/2024 Operation Travel to Beaver Creek office. PJSM & Permit. Travel to location. One heater on location. Fire & warm equipment at -32 ambient. Several hours thawing equipment & jumping batteries. All equipment running & ready. Prep RBP. Stab on to well. RIH w/ 2.85" OD RBP (Retrievable) plug w/ well shut in. Sat down 6361'. Make tie in pass. CCL to center element 14.7'. Target depth 6347. CCL to be at 6332.3' to place center element at 6347'. Sent tie in log to town. Town approved. Position & set RBP at 6347'. P/U hole 100'. Go back down & tag RBP in place at 6347'. POOH. OOH. Running tool in good shape. RDMO AK E-Line. Report Number 18 Report Start Date 2/6/2024 Report End Date 2/7/2024 API: 50-133-20525-00-00 Field: Beaver Creek Sundry #: 323-623 State: ALASKA Rig/Service: Page 4/4 Well Name: BCU-013 Report Printed: 3/14/2024www.peloton.com Well Operations Summary Operation MIRU Pollard Slickline w/.125 wire. PT lubrucator 250 psi / 3000 psi. RIH w/2.5” x 5’ DD bailer. FL @ 1700’. Tagged 6,318’ slm / 6,347’ MD. Work bailer. Pooh. OOH w/empty bailer. Metal marks on bailer bottom, no fill. Discuss plan forward w/OE. RDMO Pollard Slickline. Report Number 19 Report Start Date 2/9/2024 Report End Date 2/10/2024 Operation Complete PTW & PJSM. MIRU AK Eline. MIRU Fox N2 pump to flow line. Transfer N2 to pump. Pick up greasehead & lubricator. Stab on well. PT PCE to 250 psi / 3000 psi. Fox online w/N2 down tubing 700 scfm/1800 psi. Fox continue N2 pumping down tubing, 700 scfm @ 1800 psi. Ak Eline RIH w/GPT BHA. Tagged RBP 6,343’ elm, no fluid. Fox offline w/N2 pump. 84,000 scf pumped = 902 gallons. Log GPT from RBP @ 6,347' to surface. Send logs to RES / GEO and shift -2'. M/U 2.75” Big Boy CIBP. CCL to 12.6’. 13’ COE. RIH w/2.75” Big Boy CIBP. Tagged RBP and log correlation pass 6,345' - 6000' verified by RES/GEO. Set plug CCL 6,287.4’ + 12.6’ CCL to top of plug = 6,300’ elm. Good indication of set. PUH and tag plug. Looks good. Pooh. M/U 2.50” x 10’ gun (6 spf). CCL to TS = 92” or 7.7’. CCL to bottom of gun = 18’. RIH w/Gamma / CCL, and 2.50” x 10' gun (6 spf). Log correlation pass 6,300' - 6000', log verified by RES/GEO. No shift. Log CCL on depth = 6,267.3' + 7.7' (CCL to TS) = 6,275'. WHP = 1650 psi. Perforate BEL7 sands 6,275' - 6,285'. Good indication of gun firing. Pooh. 15 min WHP = 1625 psi. Pooh w/gun while monitoring WHP. On surface confirmed shots fired. Secure well. Lay down lubricator. SDFN. Production to begin bleeding WHP to 500 psi through the night. Report Number 20 Report Start Date 2/10/2024 Report End Date 2/11/2024 Operation MIRU Pollard SL w/.125 wire. Stab on well w/2.25" LIB. PT PCE to 250 / 3000. RIH w/2.25" LIB. See Fluid Level @ 5,835'. Tagged CIBP @ 6,300'. Pooh w/tools. RDMO Pollard SL. Install tree cap & PT. Production to jump gas from BC-18 and see if they can push fluid away through the night for Eline. Report Number 21 Report Start Date 2/11/2024 Report End Date 2/12/2024 Operation Complete PTW & PJSM. MIRU Ak Eline. Pick up grease head & lubricator. Stab on well. PT PCE to 250 psi / 3500 psi. RIH w/GPT. Fluid level 5,270’. Online N2 down tubing 1000 scfm. WHP slowly built up to 3500 psi. Off pump, WHP dropping slowly. FL @ 5,460’. Pressure up w/N2 to 3500 psi. Off pump. WHP slowly dropping. Keep bumping WHP to 3500 psi. Log fluid level = 5,850’. Tagged plug 6,300’ elm. Well dry. Pooh. OOH w/GPT. M/U 2.75” BB plug. CCL to top of plug = 12.6’. RIH w/2.75” Big Boy CIBP. Tagged plug @ 6,300’. Make correlation pass and send to RES/GEO. No depth shift. Log CCL on depth = 6,255.4’ + 12.6’ = 6,268’ top of plug. Set plug. PUH and tag plug good. Pooh. M/U gun gamma and 2.5” x 10’ gun. CCL to TS = 9.7’. RIH w/gun gamma & 2.50” x 10’ gun (6 spf). Make correlation pass 6,268’ up to 6050’. Send log to GEO/RES. Depths good. Log CCL on depth 6,226.3’ + 9.7’ = 9,236’ top shot. WHP 1848 psi. Shots fired. Perforate BEL6 6,236’ – 6,246’. Good indication of guns firing. Pooh. 15 min WHP 1736 psi. OOH w/gun, confirm shots fired. Secure well. RDMO Ak Eline. Rig down complete. Turn well over to production. Flowing 2.2 MM @ 1400 psi. Report Number 22 Report Start Date 3/10/2024 Report End Date 3/10/2024 Operation MIT-IA passed to 2000 psi. Max applied pressure= 2127 psi. Target Pressure = 2000 psi. Pressured IA to 2058 psi. MIT-IA lost 21 psi in the first 15 minutes and 11 psi in the 2nd 15 minutes for a total of 31 psi in 30 minutes. Bled IA to 0 psi API: 50-133-20525-00-00 Field: Beaver Creek Sundry #: 323-623 State: ALASKA Rig/Service: Lease: State/Prov:Alaska Country:USA Angle/Perfs:1ºĺ3º 158' 21' 10/5/2023 3/19/2024 Well Name & Number:Beaver Creek Unit #13 A - 028083 County or Parish:Kenai Peninsula Borough Revised By:D Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:1.3º / 100 ft @ 2,200'Maximum Deviation:28º @ 4,178' Date Completed:01/22/04 Ground Level (above MSL):RKB (above GL): TD 10,500' MD 10,182' TVD Excape System Details -8 Conventional flappers -Mod 1 - no flapper -Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 9 - 7,749' Module 8 - 7,788' Module 7 - 7,986' Module 6 - 8,144' Module 5 - 8,183' Module 4 - 8,245' Module 3 - 8,416' Module 2 - 8,512' Module 1 - NA -Green control line fires bottom module -Red control line fires top 8 modules Excape System Details -BHP monitoring line volume tank located from 7,668' - 7,706' BC-13 Pad 3 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. PBTD 10,429' MD 10,111' TVD Permit #:203-138 API #:50-133-20525-00 Prop. Des:A - 028083 KB elevation:179' (21' AGL) Latitude: Longitude: Spud:11/9/2003 TD:12/6/2003 Rig Released:12/15/2003 @ 06:00 hrs Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Intermediate Casing 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 10,462' TVD 0' 10,144' 8-1/2" hole Cmt w/ 1,475 sks class G cmt SCHEMATIC TOC 3-1/2" Csg (1/16/04 CBL) - 6,730' Directional Data: KOP - 2,200' at 1.3 deg/100' build EOB - 4,178', 28.1 deg hole angle Drop - 4,240' @ 0.8 deg/100' Hold - 8,550', 1.0 deg hole angle to TD Tree cxn: 6-1/2" Otis LB20- LB30 Tbg cut @ 6590' 12/6/23 9.4 ppg KWF TOC @ 4,936' 1/6/24 Cmt retainer @ 6502' 12/28/23 CIBP @ 7656' w/ 70' of cement, TOC @ 7586' 12/5/23 CIBP set at 6380' ELM (1/12/24) BEL 6/7/8 RBP set at 6347' ELM (1/27/24) CIBP 6268' (2/11/24) 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,500'N/A Casing Collapse Structural Conductor 1,500 psi Surface 1,950 psi Intermediate 4,750 psi Production 10,540 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 9.3# / L-80 10,462' February 24, 2023 N/A; N/A N/A; N/A See Schematic See Schematic 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 203-138 50-133-20525-00-00 Beaver Creek Beluga Gas & Tyonek Gas Same CO 237D Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 13 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 10,182'10,429'10,111'~2,894psi N/A MD 6,870 psi 3,060 psi 3,450 psi 165' 2,296' 6,973' 165' 2,296' 7,288' Perforation Depth MD (ft): 10,462'3-1/2" 9-5/8"7,267' 20" 13-3/8" 144' 2,275' 10,160 psi10,144'10,462' m n P s 66 t 2 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 7:23 am, Feb 21, 2023 323-106 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.02.18 07:24:47 -09'00' Dan Marlowe (1267) Beluga Gas Pool BJM 2/22/23 DSR-2/22/23 X SFD 2/21/2023 CT BOP test to 3500 psi. SFD 10-404 GCW 02/23/23 JLC 2/23/2023 2/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.23 14:32:36 -09'00' RBDMS JSB 022423 Well Work Prognosis Well Name: BCU-13 API Number: 50-133-20525-00 Current Status: Shut In Leg: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz Permit to Drill Number: 203-138 First Call Engineer: Chad Helgeson Office: 907-777-8405 Cell: 907-229-4824 Second Call Engineer: Jake Flora Office: 907-777-8442 Cell: 720-988-5375 Max Expected BHP: 3721 psi @ 8271’ TVD Using 0.45 psi/ft gradient MASP: 2894 psi @ surface Using 0.1 psi/ft gradient AAC 25.280(b)(4) Well History: BCU-13 was completed in Jan. 2004. The last adperfs were added in 2014. On 1/19/23 a 2.5” LIB was run in the hole and found a restriction @ 7889’ MD (picture in appendix). On 1/23/23 SL ran a 2.5” LIB after swabbing the well and broke wire at 7050’ MD. The SL toolstring and 130’ of 0.160 wire was left in the hole. The final SL tag depth was 6952’ prior to rigging down. There is presumably fill on top of the SL toolstring. Objective: Rig up Coiled Tubing, clean out to top of fish, fish SL wire & toolstring, mill out restriction and clean out well. Procedure: 1. RU Coiled Tubing. Provide 24 hour notice to AOGCC. Test BOP’s to 250 psi low/3500 psi high. 2. RIH w/ wire grab on coil MHA. Clean out from tag depth @ ~6952’ (taking returns to OTT)t to SL fish and attempt to retrieve fish. a. Once ~130’ of wire is recovered the SL rope socket fishing neck is a 1.75” (2 ½” JDC pulling tool, verify w/ SL) b. Retrieve SL fish (2.5” LIB and tool string). 3. RIH w/ ~2.75” OD dual tapered mill MHA. Continue to clean out to restriction @ 7889’ taking returns to OTT or to formation. 4. Mill out restriction. a. On 12/7/21 a SL 1.98” gauge ring tagged fill @ 8415’. b. Once through the restriction and made it to fill @ ~8415’. Contact OE on progress milling/cleaning out past tag depth. Possibly clean out to below bottom perf interval below. 5. Blow down well with N2 to top of fill. 6. Return well to production. 7. RU Eline. PT lubricator to 250 psi low/3500 psi high. 8. Selectively perf/reperf the below zones. PERFORATION DETAIL Zone Top MD Btm MD TopTVD Btm TVD Amt Date Comments BEL20 7708' 7745' 7390' 7428' 37' REPERF & ADD BEL20 7763' 7778' 7444' 7459' 15' REPERF & ADD BEL21 7847' 7864' 7529' 7546' 17' REPERF & ADD BEL22 7918' 7953' 7600' 7635' 35' REPERF & ADD BEL23 7967' 7977' 7649' 7659' 10' REPERF BEL26 8153' 8173' 7835' 7855' 20' REPERF & ADD BEL27 8196' 8266' 7878' 7948' 70' REPERF & ADD BEL28 8350' 8360' 8032' 8042' 10' REPERF BEL28L 8395' 8423' 8076' 8105' 28' REPERF & ADD BEL29L 8475' 8502' 8157' 8183' 27' REPERF & ADD BEL29L 8520' 8540' 8202' 8222' 20' REPERF BEL30 8571' 8594' 8253' 8276' 23' REPERF & ADD Well Work Prognosis Contingency: 1. If any zone produces sand and/or water or needs isolated: 2. RU E-line, pressure test lubricator 250 psi low/3,000 psi high. 3. RIH and set a casing patch, WRP, or set a CIBP w/ 35’ of cement above the zone that needs isolated. Attachments 1. Current schematic 2. Proposed schematic 3. BOP schematic 4. N2 Procedure 5. SL Fish 6. LIB Well Work Prognosis Current Schematic Well Work Prognosis Proposed Schematic Well Work Prognosis BOP’s Well Work Prognosis Well Work Prognosis N2 Procedure Well Work Prognosis SL Fish Well Work Prognosis LIB 1/19/23 Well Work Prognosis Current Schematic Well Work Prognosis Proposed Schematic Well Work Prognosis BOP’s Well Work Prognosis N2 Procedure Well Work Prognosis SL Fish Well Work Prognosis LIB 1/19/23 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~03 - 1315 Well History File Identifier Production Scanning . 07 Page Count from Scanned File: I (Count does include cover sheet) page~ount Matches Number in s~anri.ng ~7paration: V YES r-: 'A.~. I Date:~ :)7/ Ö0 If NO in stage 1, page(s) discrepancies were found: Organizing (done) ~wo-sided ,11I1111/11111111111 RESCAN pZtolor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: C Maria) I r Date: d- d-7 tJ b Project Proofing BY: é:. Maria ~ or- Date: ;;).. /d-,7 Din (3 x3~=, qO+ Dated- fì--7 ¡ 0 ~ Scanning Preparation BY: C. Maria) Stage 1 BY: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: VVtf 1111111111111111111 vuP 151 151 {~ = TOTAL PAGES q b (Count does not include cover she¡~) iAA.j' 151 , V f 1111111111111111111 NO 151 ~f NO YES 151 1111111111111111111 1111111111111111111 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc OF tl �,e a THE STATE i Cava F_. . . �w�� /%j tea+ _.,. :.. 77- /, 333 West Seventh Avenue GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 ki Main: 907.279.1433 0 ALAS" 907.27/ 7542 Stan Porhola SCANNED JUL 2 2 2014 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 " C 3 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU #13 Sundry Number: 314-088 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy '. Foerster Chair DATED this L day of February, 2014. Encl. 1 RECEWED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 8'2014 APPLICATION FOR SUNDRY APPROVALS D 4-iJ1(9- 20 MC 25.280 AOGCC p 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q - Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number • Exploratory ❑ Development ❑✓ . 203-138 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service El • 6.API Number. Anchorage,Alaska 99503 50-133-20525-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 498' ..11L3' Beaver Creek Unit(BCU)#13 • Will planned perforations require a spacing exception? Yes ❑ No Q -v.Zt'' 1 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083• Beaver Creek/Beluga Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,500' • 10,182' 10,429' 10,111' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 165' 165' 3,060 psi 1,500 psi Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1/2" 10,461' 10,143' 10,160 psi 10,540 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,461' Packers and SSSV Type: N/A;N/A Packers and SSSV MD(ft)and TVD(ft): N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: - Detailed Operations Program U BOP Sketch H Exploratory U Stratigraphic U Development U Service H 14.Estimated Date for 15.Well Status after proposed work: 02/23/14 Commencing Operations: Oil ❑ Gas 0 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer / Signature �l`"`�4 / //Phone 907-777-8412 Date 2 f$ /? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Lk^ CYWV Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 1 1 2014 Spacing Exception Required? Yes ❑ No © Subsequent Form Required: /D — l 0 Lf APPROVED BY Approved by: LV6_, J,/ •LA< COMMISSIONER THE COMMISSION Date: .-.2 -. (-74 Z• Submit Form and Form 10-403( evised 10/ 12) Appr v I s d rilmonths from the date of approval. Attachments in Duplicate ' lYi ISA ini : : Well Prognosis Well: BCU-13 Hilcorp Alaska,LL Date:2/18/2014 Well Name: BCU-13 _ API Number: 50-133-20525-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: February 23`d, 2014 Rig: N/A Reg.Approval Req'd? None Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-138 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,425 psi @ 8,275' TVD (Based on flowing survey July 2013 run to 8,650' MD) Maximum Expected BHP: —3,000 psi @ 7,922' ND (Based on potential BHP estimate for zone at 8,240' MD) Max.Allowable Surface Pressure: —2,208 psi (Based on potential reservoir conditions and gas gradient to surface(0.10psi/ft) Brief Well Summary Beaver Creek Unit#13 was drilled as a Grass roots EXCAPE monobore completion in 2003 to target gas sands in the lower Beluga formation. All 9 EXCAPE modules were perforated and fracture stimulated.Additional perforations were added in the fall of 2013 with a slight increase in production.The well is currently on production making around 2.20 MMCF/D with 1 bwpd. Notes Regarding Wellbore Condition • Well is currently flowing at 2.20 MMCF/D with a 175 psi flowing tubing pressure. • Wellbore deviation at the perforations is less than 3 degrees. Maximum deviation is 28 degrees. OBJECTIVE OF WORKOVER Add new perfs in the Lower Beluga sands(LB-28, LB-24, LB-21, LB-20). E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 2. RU 2.0" 6 spf HC wireline guns. 3. RIH and perforate Lower Beluga interval LB-28 from 8,240'-8,260' (2 runs,total of 12 spf). 4. RIH and perforate Lower Beluga interval LB-24 from 8,085'-8,092' (2 runs,total of 12 spf). 5. RIH and perforate Lower Beluga interval LB-21 from 7,850'-7,863' (2 runs,total of 12 spf). 6. RIH and perforate Lower Beluga interval LB-20 from 7,706'-7,712' (2 runs,total of 12 spf). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Perforate well while flowing during each perf run. d. Record tubing pressures before and after each perforating run. 7. RD E-line. 8. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic BC-13 ACTUAL Pad 3 SCHEMATIC uil� r,i \I tl t. I.t.l. 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 Prop. Des: A-028083 . Li Conductor KB elevation: 179' (21'AGL) III 20" K-55 133 ppf PE Latitude: Top Bottom Longitude: ! MD 0' 165' Spud: 11/9/2003 i, TVD 0' 165' TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' " TVD 0' 2,296' Tree cxn:6-1/2"Otis 16"hole Cmt w/568 sks of Class G TOC 3-1/2"Csg Intermediate Casing (1/16/04 CBL)-6,730' ' + 9-5/8" L-80 47 ppf BTC ,.l y, Top Bottom Excape System Details ,y, a7 MD 0' 7,288' -BHP monitoring line volume tank .41 TVD 0' 6,973' 19 located from 7,668'-7,706' .x° h 12-1/4"hole Cmt w/1,144 sks of Class G / Production Tubing Capillary Tubing 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel Top Bottom Top Bottom , MD 0' 10,462' MD 0' 0' ,; + TVD 0' 10,144' TVD 0' 0' . -D{ E 8-1/2"hole Cmt wl 1,475 sks class G cmt (***Pulled 05/14/2009***) ) Excape System Details Excape System Details ti -9 Excape modules placed 8 Conventional flappers -Green control line fires bottom -Mod 1 -no flapper w module Ceramic flapper valves y < -Red control line fires top 8 modules below each module as A .r -Ceramic flapper valves below each follows: module Flappers MD(RKB): Module 9- 7,749' Perfs MD(RKB): 7 Module 8- 7,788' � I Module 9 7,730'7,740' Module 7- 7,986' Module 8- 7,769'-7,779' Module 6- 8,144' 2-1/8"HC-7,918'-7,954'(9/07/13-12spf) Module 5- 8,183' Module 7- 7,967'-7,977' Module 4- 8,245' Module 6- 8,125-8,135' Module 3- 8,416' T Module 5- 8,164'-8,174' Module 2- 8,512' '. Module 4- 8,223'-8,236' Module 1 - NA 2-1/8"HC-8,395-8,403'(8/16/13-12spf) Module 3- 8,397-8,407' 2-1/8"HC-8,411'-8,415'(8/16/13-12spf) Tagged fill @ 9,213' (9/07/13) ---->{ Module 2- 8,491'-8,501' w/2.25"gauge ring Module 1 - 8,584'-8,594' IE-]1 2-1/8"HC-8,586'-8,590'(8/16/13-12spf) Directional Data: ' iffil ", KOP-2,200'at 1.3 deg/100'build I- EOB-4,178',28.1 deg hole angle Drop-4,240'@ 0.8 deg/100' TD PBTD Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: _ 1.3°/100 ft @ 2,200' Angle/Perfs: 1°-.3° Maximum Deviation: 28°@ 4,178' Date Completed:_ 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 9/7/2013 Schematic Revision Date: 9/9/2013 .. „ 14 BC-13 PROPOSED Pad 3 SCHEMATIC 1,310' FNL, 1,480' FWL, Hi!cora Alaska,LLC Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 Prop. Des: A-028083 ' Conductor KB elevation: 179' (21'AGL) .w I1.11:1 20" K-55 133 ppf PE Latitude: Top Bottom ' j. MD 0' 165' Longitude: ,. 1 TVD 0' 165' Spud: 11/9/2003 ! TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 his p,f 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' + r TVD 0' 2,296' Tree cxn:6-1/2"Otis 16"hole Cmt w/568 sks of Class G TOC 3-1/2"Csgi (1/16/04 CBL)-6,730' Intermediate Casing 9-5/8" L-80 47 ppf BTC A Top Bottom Excape System DetailsMD 0' 7,288' -BHP monitoring line volume tank I TVD 0' 6,973' located from 7,668'-7,706' 12-1/4"hole Cmt w/1,144 sks of Class G II Production Tubing Capillary Tubing3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel +i.I e Top Bottom Top Bottom ;� MD 0' 10,462' MD 0' 0' ` I I TVD 0' 10,144' TVD 0' 0' . . I 8-1/2"hole Cmt w/1,475 sks class G cmt (***Pulled 05/14/2009***) w, ll' ..--4 Excape System Details i Excape System Details -9 Excape modules placed -8 Conventional flappers , Green control line fires bottom -Mod 1 -no flapper module Ceramic flapper valves I '°` -'Red control line fires top 8 modules below each module as -Ceramic flapper valves below each follows: S' a' module Flappers MD(RKB): Module 9- 7,749' EJ Peds MD(RKB):l Module 8- 7,788' - 2"HC - 7,706'-7,712'(Proposed) ' Module 7- 7,986' Module 9- 7,730'-7,740' Module 6- 8,144' Module 8- 7,769'-7,779' 2"HC - 7,850'-7,863'(Proposed) Module 5- 8,183' ( p ) Module 4- 8,245' 2-1/8"HC-7,915-7,954'(9/07/13-12spf) Module 3 8,416' • r,Ij Module 7- 7,967'-7,977' Module 2- 8,512' 2"HC - 8,085'-8,092'(Proposed) Module 1 - NA Module 6- 8,125-8,135' ___ Module 5- 8,164'-8,174' , ) , , Module 4- 8,223'-8,236' Tagged fill @ 9,213' (9/07/13) .,„..-->f; 2" HC - 8,240'-8,260'(Proposed) • w/2.25"gauge ring 2-1/8"HC-8,395-8,403'(8/16/13-12spf) . Module 3- 8,397'-8,407' 2-1/8"HC-8,411'-8,415'(8/16/13-12spf) Directional Data: ' '' Module 2- 8,491'-8,501' KOP-2,200'at 1.3 deg/100'build , ' Module 1 - 8,584'-8,594' EOB-4,178',28.1 deg hole angle 2-1/8"HC-8,586'-8,590'(8/16/13-12spf) Drop-4,240'@ 0.8 deg/100' TD PBTD Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD • Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 1.3°/100 ft @ 2,200' Angle/Perfs: 1°-.3° Maximum Deviation: 28°@ 4,178' Date Completed: 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 2/17/2014 Davies, Stephen F (DOA) From: Stan Porhola [sporhola@hilcorp.com] Sent: Thursday, February 20, 2014 10:22 AM To: Davies, Stephen F (DOA) Subject: RE: BCU 13 and BCU 16RD: Planned Perforations Steve, Current wells on production from Beaver Creek in the Beluga Gas Pool: BCU-12 BCU-13 BCU-16RD BCU-18 BCU-13 => BCU-12 is 2,300' BCU-13 => BCU-16RD is 1,600' BCU-13 => BCU-18 is 3,100' BCU-13 => BCU-09 is 1,420' (closest well open to Beluga not producing but open in Beluga) BCU-16RD=> BCU-12 is 3,300' BCU-16RD=> BCU-13 is 1,600' BCU-16RD=> BCU-18 is 4,650' BCU-16RD=> BCU-09 is 1,750' (closest well open to Beluga not producing but open in Beluga) Regards, Stan Porhola ( Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, February 18, 2014 2:35 PM To: Stan Porhola Subject: BCU 13 and BCU 16RD: Planned Perforations Stan, What are the distances from the planned perforation intervals in BCU 13 and BCU 16RD and perorations that are, or will be, open to the same gas pool in the closest wells? Thanks, Steve Davies AOGCC 907-793-1224 1 STATE OF ALASKA 'S ALA.OIL AND GAS CONSERVATION COMMIOON Ur-T„ 0 3 2013 REPORT OF SUNDRY WELL OPERATIONS AnGra 1.Operations Abandon U Repair Well LJ Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development EI Exploratory ❑ 203-138 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service El 6.API Number: Anchorage,Alaska 99504 50-133-20525-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 . Beaver Creek Unit(BCU)13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool • 11.Present Well Condition Summary: Total Depth measured 10,500 feet Plugs measured N/A feet true vertical 10,182 feet Junk measured N/A feet Effective Depth measured 10,429 feet Packer measured N/A feet true vertical 10,111 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 165' 165' 3,060 psi 1,500 psi Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1/2" 10,461' 10,143' 10,160 psi 10,540 psi Liner ))�s Perforation depth Measured depth See Attached SchematicS � i� l SCAO True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,461'MD 10,143'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1355 3 0 188 Subsequent to operation: 0 2447 3 0 198 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q - Service ❑ Stratigraphic ❑ 1 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 • WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-437 Contact Stan Porhola Email sporholaCc�hilcorp.com Printed Name Stan Porhola Title Operations Engineer i di Signature -;:% ,. % C" tom-et. Phone 907-777-8412 Date "r, Sr;`' , Form 10-404 Revised 10/2012 147'/q / Submit Original Only '- r0/f(/> . • BC-13 ACTUAL Pad 3 SCHEMATIC Hikor l Alaska,LLC 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 Prop. Des: A-028083 I.� Conductor KB elevation: 179' (21'AGL) , 1 20" K-55 133 ppf PE Latitude: Top Bottom '. MD 0' 165' Longitude: / TVD 0' 165' Spud: 11/9/2003 TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Tree cxn:6-1/2"Otis 16"hole Cmt w/568 sks of Class G TOC 3-1/2"Csg Intermediate Casing (1/16/04 CBL)-6,730' , 9-5/8" L-80 47 ppf BTC Vi Top Bottom Excape System Details )'f MD 0' 7,288' BHP monitoring line volume tank -1111 TVD 0' 6,973' located from 7,668'-7,706' } 12-1/4"hole Cmt w/1,144 sks of Class G �i t r Capillary Tubing 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel Al Production Tubing ') �ft� Tom Bottom Top Bottom i�' MD 0' 10,462' MD 0' 0' 7 TVD 0' 10,144' TVD 0' 0' . -Ili r 8-1/2"hole Cmt w/1,475 sks class G cmt (***Pulled 05/14/2009***) )r -B) Excape System Details Excape System Details I i -9 Excape modules placed -8 Conventional flappers -Green control line fires bottom -Mod 1 -no flapper module Ceramic flapper valves U1 -Red control line fires top 8 modules below each module as Le -Ceramic flapper valves below each follows: module Flappers MD Module 9- 7,749' Perfs MD(RKB): Module 8- 7,788' Module 9 7,730'7,740' Module 7- 7,986' = ' Module 8- 7,769'-7,779' Module 6 8,144' 2-1/8"HC-7,918'-7,954'(9/07/13-12spf) Module 5 8,183' $4 Module 7- 7,967'-7,977' Module 4- 8,245' r Module 6- 8,125'-8,135' Module 3 8,416' ,# Module 5- 8,164'-8,174' Module 2- 8,512' Module 4- 8,223'-8,236' Module 1 - NA 2-1/8"HC-8,395'-8,403'(8/16/13-12spf) Module 3- 8,397'-8,407' 2-1/8"HC-8,411'-8,415'(8/16/13-12spf) Tagged fill @ 9,213' (9/07/13) Module 2- 8,491'-8,501' w/2.25"gauge ring 1'. Module 1 - 8,584'-8,594' 2-1/8"HC-8,586'-8,590'(8/16/13-12spf) Directional Data: ' ■ KOP-2,200'at 1.3 deg/100'build EOB-4,178',28.1 deg hole angle Drop-4,240'@ 0.8 deg/100' TD PBTD Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: 1.3°/100 ft @ 2,200' I Angle/Perfs:I 1°-.3° Maximum Deviation: 28°@ 4,178' Date Completed: 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date:_ 9/7/2013 Schematic Revision Date: 9/9/2013 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-13 50-133-20525-00 203-138 8/16/13 9/7/13 Daily Operations: 08/16/2013 - Friday Mobe to BCU 13. Spot equipment and rig up on well. Arm perf gun. Pressure test lubricator to 250 psi low and 3000 psi high. Shut well in.; RIH w/GPT tool, 2-1/8" x 4', HC, 6 spf, 60 deg phase perf gun and tie into Reeves CBL log dated 16-Jan-04. Fluid level was 8,430'. Spot gun from 8,586' to 8,590'. TP was 550 psi and BHP was 603 psi. Fired gun. Lay lubricator down and take off GPT tool and add CCL RIH w/2-1/8" x 4', HC, 6 spf, 60 deg phase perf gun and tie into Reeves CBL log dated 16- Jan-04. Fluid level was still at 8,430'. Spot gun from 8,586'to 8,590'. TP was 550 psi and BHP was 600 psi. Fired gun. RIH w/GPT tool, 2-1/8" x 4'( loaded) x 2-1/8" x 8' (blank) x 2-1/8" x 8' (loaded), HC, 6 spf, 60 deg phase perf gun and tie into Reeves CBL log dated 16-Jan-04. Fluid level still 8430'. Spot gun from 8,395' to 8,415'. TP was 550 psi and BHP was 579 psi. Fired gun. RIH w/CCL, 2-1/8" x 4' ( loaded )x 2-1/8" x 8' (blank) x 2-1/8" x 8' (loaded), HC, 6 spf, 60 deg phase perf gun and tie into Reeves CBL log dated 16-Jan-04. Spot gun from 8,395'to 8,415'. Fired gun and saw no significant pressure change. Monitored well for 10 min and POOH. Rig down off well and turn well over to production. 08/23/2013 - Friday RU Eline unit. MU lubricator. MU tools string w/CCL/GPT tool,jars, and 20' of 2-1/8" HC guns loaded 6 SPF 60 degree phased. Shut well in. All pressures available on SCADA. RIH(1) w/20' of 2-1/8" HC guns to 8,500'. Pull correlation pass at 35 FPM to get on depth. Correlate to Priority correlation log run 8-17-13. Pull up into position. Fire guns perforating 8,520'- 8,540'. SITP 450 psi. BHP 530 psi. POOH. BHP 539 psi. OOH. SITP 470 psi. RIH(2)w/10' of 2-1/8" HC guns loaded 6 SPF 60 degree phased. Pull correlation pass to get on depth to Priority correlation pass run 8-17-13. Fire guns perforating 8,350'- 8,360'. SITP 480 psi. BHP 530 psi. OOH. SITP 480 psi. No noticable pressure increase. RIH(3) w/20' of 2-1/8" HC guns loaded 6 SPF 60 degree phased. Pull correlation pass to get on depth w/ Priority log run 8-17-13. Pull up into position. Fire guns perforating 8,320'-8,340'. SITP 490 psi. BHP 542 psi. POOH. SITP 495 psi. OOH. SITP 500 psi. RD Priority E line unit. 09/07/2013-Saturday MIRU Pollard E-Line,Attempted to pressure test to 1,500 psi, 0-ring leaked, replaced and re-tested good. RIH W/2-1/4" GR, GR/CCL, tagged fill at 9,213', POOH. MU and RIH W. GPT tool, 2 1/8" X 20', 6 SPF HC, correlated and got on depth, perforated 7,934'-7,954'. Tbg Pressure 180 psi, Recorded tbg psi/temp for 30 mins, POOH. MU and RIH W/CCI, 2-1/8"X 20', 6 SPF HC, correlated and got on depth, perforated 7,934'-7,954'. Tbg pressure now 206 14, MU and RIH W/CCI, 2-1/8"X 16', 6 SPF HC, correlated and got on depth, perforated 7,918'-7,934'. No change in tbg pressure. POOH. MU and RIH W/CCI, 2- 1/8"X 16', 6 SPF HC, correlated and got on depth, perforated 7,918'-7,934'. No change in psi, flow rate from average of 1.3 million up to 2.4 million, POOH, RDMO Pollard E-Line Unit. , Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent Tuesday,August 20,2013 9:01 AM To: 'Stan Porhola' Cc: Chad Helgeson; 'Davies, Stephen F (DOA) (steve.davies @alaska.gov)' Subject: RE:Verbal Approval Request to add additional intervals for perforating Beaver Creek# 13(PTD 203-138) Stan, As the new proposed perforations are within the approved TVD window, you have verbal approval to add the addition zones as stated below. A follow-up sundry will not be required , this email will be sufficient documentation. ? ?1-i--. Guy Schwartz Senior Petroleum Engineer KED _ �i AOGCC 907-444-3433 cell 907-793-1226 office From: Stan Porhola [mailto:sporhola ahilcorp.com] Sent: Monday, August 19, 2013 4:42 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson Subject: Verbal Approval Request to add additional intervals for perforating Beaver Creek#13 (PTD 203-138) Guy, We are requesting verbal approval to add additional perforated intervals to the approved sundry(313-437)for well Beaver Creek#13 (PTD 203-138),all of which are in the Beluga Gas Pool: 8,320'—8,340' (shoot 6 spf) 8,350'—8,360'(shoot 6 spf) 8,520'—8,540'(shoot 6 spf) Regards, Stan Porhola I Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC sp rliol ia'hilcor_p.ccan Office: (907) 777-8112 Mobile: (907) :3:3 1-8228 1 w I-1- 3 •to-l3 BC-13 PROPOSED Ye---- Pad 3 SCHEMATIC Ilileorp Ala4a.IAA. 1,310' FNL, 1,480' FWL, Sec.34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 Prop. Des: A-028083 Conductor KB elevation: 179' (21'AGL) 20" K-55 133 ppf PE Latitude: Top Bottom Longitude: MD 0' 165' Spud: 11/9/2003 TVD 0' 165' TD: 12/6/2003 Riq Released: 12/15/2003 Surface Casinq @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Tree cxn:6-1/2"Otis 16"hole Cmtw/568 s ks of Class G TOC 3-1/2"Csg ri Intermediate Casing (1/16/04 C BL)-6,730' ': yu 9-5/8" L-80 47 ppf BTC V )' Top Bottom 6 Excape System Details . ) 0 MD 0' 7,288' -BHP monitoring line volume tan,, - TVD 0' 6,973' located from 7,668'-7,706' -- -=,--- 12-1/4"hole Cmt w/1,144 sks ofClassG tilt' .4 l '4 Production Tubing Capillary Tubing 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel t .,: Y Top Bottom Top Bottom 5;, MD 0' 10,462' MD 0' 0' d TVD 0' 10,144' TVD 0' 0' 8-1/2"hole Cmtw/1,475sks class Gcmt (***Pulled 05/14/2009***) ,�Rib' , -4 14 Excape System Details Excape System Details 141 9 Excape modules placed -8 Conventional flappers 1 - en control line fires bottom -Mod 1-no flapper 1!I module Ceramic flapper valves =__ _ - control line fires top 8 modules -- below each module as - - -Ceramic flapper valves below each follows: P E .._. . module FlappersMD(RKB): lJ % Perfs MD(RKB): Module 9- 7,749' 10'Prop-u_- To Module 8- 7,788' :, spf) Nodule 7- 7,986' Module 9- 7,730'-7,740' Module 6- 8,144' ,- i Module 8- 7,769'-7,779' Module 5- 8,183' ��r Prc i-7,917'-7,9: ?spf) Module 4- 8,245' I I Module 7- 7,987'-7,977' Nodule 3- 8,416' 20' Prop.,ed-8 ' spf) Prop Module 2- 8,512' Module 6- 8,125-8,135' Module 1 - NA d-8,1eu 0, 'spf) Module 5- 8,184'-8,174' i A=-- I t t a Module 4- 8,223'-8,236' Proposed-8,228'-8,21 spf! Tagged fill @ 9,397' (7/19/13) >; Proposed-8,320'-8,340'(6spf) )c- ',... w/2.25"gauge ring '. - - 2 -','1'-8..360'16-r' yc 2-1/8"HC-8,395'-8,403'(8/16/13-12spf) mii Directional Data: Module 3- 8,397'-8,407' D ire -2,200'at 1.3degl100'build 2-1/8"HC-8,411'-8,415'(8/16/13-12spf) EOB-4,178',28.1 deg hole angle Module 2- 8,491'-8,501' +" Drop-4,240'@ 0.8 deg/100' TD PBTD Module 1 - 8,584'-8,594' Hold-8,550',1.0 deg hole angle to TD 10,500'MD 10,429' MD 2-1/8"HC-8,586-8,590'(8/16/13-12spf) 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Frov: Alaska Country:! USA Angle cKOP and Depth 1.3°/100 ft att 2,200' IAngle/Perfs:I 1° ,3° Maximum Deviation _ 28°@ 4,178' Date Completed: 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Dow nhole Revision Date: Proposed Schematic Revision Date: 8/19/2013 BC-13 PROPOSED Pad 3 liilcorp.Alaska.LLC 1,310' FNL, 1,480' FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 Prop. Des:. A-028083 i • 1 -, Conductor KB elevation: 179' (21'AGL) •i.'• K-55 133 ppf PE Latitude: f1 Top Bottom -Longitude: { MD 0' 165' Spud: 11/9/2003 1 TVD 0' 165' TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0'' 2,296' I� TVD 0' 2,296' Tree cxn:6-1/2"Otis C j L__I 16"hole Cmt w/568 sks of Class G TOC 3-1/2"Csg (1/16/04 CBL)-6,730' Intermediate Casing 9-5/8" L-80 47 ppf BTC *; I1 Top Bottom Excape System Details�. J MD 0' 7,288' -BHP monitoring line volume tank t` ?;I l' TVD 0' 6,973' located from 7,668'-7,706' ' jlr 1 12-114"hole Cmt W/1,144 sks of Class G L I Production Tubing Capillary Tubing _- . 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel r Top Bottom Top Bottom MD 0' 10,462' MD 0' 0' TVD 0' 10,144' TVD 0' 0' 1<1 - 8-112"hole Cmt w/1,475 sks class G cmt (***Pulled 05/1412009***) •' «' lr Excape System Details ;41 41 Excape System Details -8 Conventional flappers *1 9 Excape modules placed -Mod 1 -no flapper i.` =( L -Green control line fires bottom -Ceramic flapper valves module below each module as f: / 1 , , -Red control line fires top 8 modules follows. -Ceramic flapper valves below each Flappers MD(RKB): module Module 9- 7,749' . ' IiI Module 8- 7,788' I Perfs MD(RKB): Module 7- 7,986' l l Proposed-7,725'-7,744'(12spt) Module 6- 8,144' I Module 9- 7,730'-7,740' Module 5- 8,183' Module 8- 7,769'-7,779' Module 4- 8,245' Proposed-7,917'-7,953'(12spf) Module 3- 8,416' Module 7- 7,967'-7,977' Module 2- 8,512' Proposed-8,125'-8,136'(12spf) Module 1 - NA ' • Module 6- 8,125'-8,135' T Proposed-8,158'-8,168'(12spf) • { j ti , Module 5- 8,164'-8,174' Tagged fill @ 9,397' (7/19/13) I -->�• Module 4- 8,223'-8,236' w/2.25"gauge ring J Proposed-8,228'-8,261'(12spf) Proposed-8,395'-8,403'(12spf) Module 3- 8,397'-8,407' Directional Data; f Proposer)-8,411'-8,415'(12spf) KOP-2,200'at 1.3 deg/100'build Module 2- 8,491'-8,501' EOB-4,178',28.1 deg hole angle Module 1 - 8,584'-8,594' Drop-4,240'©0.8 deg/100' TD PBTD Proposed-8,586'-8,590'(12spf) • Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: _ 1.3°/100 ft @ 2,200' I Angle/Perfs:I 1°-.3° Maximum Deviation: 28°@ 4,178' Date Completed:_ 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 8/10/2013 OF Tifk, ew- \ %% s� THE STATE Alaska O it and Gas °ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola SCANNED NO V 2 Operations Engineer ® 3 g' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit#13 Sundry Number: 313-437 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Ic day of August, 2013. Encl. ' STATE OF ALASKA 1,6 . 6 AUG 12 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 4151/3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ ■ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ?a3 138 Exploratory El Development Ei 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20525-00 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 498 • Beaver Creek Unit(BCU)#13 • Will planned perforations require a spacing exception? Yes ❑ No IS ' 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 • Beaver Creek/Beluga Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): ■ 10,500' ' 10,182' 10,429' 10,111' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 165' 165' 3,060 psi 1,500 psi Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1/2" 10,461' 10,143' 10,160 psi 10,540 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,461' Packers and SSSV Type: N/A;N/A Packers and SSSV MD(ft)and ND(ft): N/A;N/A 12.Attachments: Description Summary of Proposal 1151 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development U Service LJ 14.Estimated Date for 15.Well Status after proposed work: 08/16/13 7 Commencing Operations: Oil Ill Gas o WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporholaia' hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature 4:PrvIIN. Phone 907-777-8412 Date i j0 j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Pi 3�"1 31 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes LI No Ei Subsequent Form Required: /0— '/dK APPROVED BY Approved by: ( COMMISSIONER THE COMMISSION Date:g -7 S— /3 P•I L•f3 Submit Form and ' ^� �.{p t 3 ip�dj Q o (t A rov i I fo 1 onths from the date of approval. Attach Fens in Duplicate `) `l� RD�JM t I 1 / t+�� PP � PP �/12f `� • • Well Prognosis Well: BCU-13 Hilcorp Alaska,Lb Date:8/09/2013 Well Name: BCU-13 API Number: 50-133-20525-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: August 15th, 2013 Rig: N/A Reg.Approval Req'd? None Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 203-138 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,425 psi @ 8,275' TVD (Based on flowing survey July 2013 run to 8,650' MD) Maximum Expected BHP: — 1,425 psi @ 8,275'ND (Based on flowing survey July 2013 run to 8,650' MD) Max. Allowable Surface Pressure: —598 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft) Brief Well Summary Beaver Creek Unit#13 was drilled as a Grass roots EXCAPE monobore completion in 2003 to target gas sands in the lower Beluga formation. All 9 EXCAPE modules were perforated and fracture stimulated.The well is currently on production making around 1.35 MMCF/D with 3 bwpd. Notes Regarding Wellbore Condition • Well is currently flowing at 1.35 MMCF/D with a 185 psi flowing tubing pressure. • Wellbore deviation at the perforations is less than 3 degrees. Maximum deviation is 28 degrees. • OBJECTIVE OF WORKOVER Add new perfs and re-perforate in the Lower Beluga sands.✓ Y<V E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 2. RU 2.125" 6 spf HC wireline guns. 3. RIH and perforate Lower Beluga interval from 8,586'-8,590' (2 runs,total of 12 spf). • 4. RIH and perforate Lower Beluga interval from 8,411'-8,415' (2 runs,total of 12 spf). ' 5. RIH and perforate Lower Beluga interval from 8,395'-8,403' (2 runs,total of 12 spf). ' 6. Flow Well for 5-7 days before adding additional perfs. 7. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 8. RU 2.125"6 spf HC wireline guns. 9. RIH and perforate Lower Beluga interval from 8,228'-8,261' (4 runs,total of 12 spf). - 10. RIH and perforate Lower Beluga interval from 8,158'-8,168' (2 runs,total of 12 spf). 11. RIH and perforate Lower Beluga interval from 8,125'-8,136' (2 runs,total of 12 spf). 12. RIH and perforate Lower Beluga interval from 7,725'-7,744' (2 runs,total of 12 spf). 13. Flow Well for 5-7 days before adding additional perfs. 14. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. • Well Prognosis Well: BCU-13 Hilcorp Alaska,L ■ Date:8/09/2013 15. RU 2.125" 6 spf HC wireline guns. 16. RIH and perforate Lower Beluga interval from 7,917'-7,953' (2 runs,total of 12 spf). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Utilize Pressure/Temperature tool on 15t run for each interval. d. Perforate well while flowing during each perf run. e. Record tubing pressures before and after each perforating run. 17. RD E-line. 18. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • • ., BC-13 ACTUAL Pad 3 SCHEMATIC Hilcorp Alaska,LLC 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 t` Prop. Des: A-028083 , r 1' Conductor KB elevation: 179' (21'AGL) 20" K-55 133 ppf PE Latitude: Top Bottom Longitude: , ` ` MD 0' 165' Spud: 11/9/2003 c TVD 0' 165' TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' 4. TVD 0' 2,296' Tree cxn:6-1/2"Otis 4, 16"hole Cmt w/568 sks of Class G '" 7 TOC 3-1/2"Csg Intermediate Casing (1/16/04 CBL)-6,730' 40, 9-5/8" L-80 47 ppf BTC i t. Top Bottom Excape System Details ti MD 0' 7,288' BHP monitoring line volume tank -111 TVD 0' 6,973' located from 7,668'-7,706' 41 12-1/4"hole Cmt w/1,144 sks of Class G -11 t 1 ' , ) 44. Production Tubing Capillary Tubing '',< 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel ' Top Bottom Top Bottom ;; ‘41;`( MD MD 0' 10,462' MD 0' 0' , 1 TVD 0' 10,144' TVD 0' 0' 6 8-1/2"hole Cmt w/1,475 sks class G cmt (***Pulled 05/14/2009***) Excape System Details " Excape System Details - -8 Conventional flappers 9 Excape modules placed Mod 1 -no flapper + control line fires bottom module -Ceramic flapper valves below each module as 1 - = !!control line fires top 8 modules follows: 4.' -Ceramic flapper valves below each 1 Flappers MD(RKB): } module Module 9- 7,749' ` Perfs MD(RKB): - 7 Module 7 88' od , Module 7- 7,986' Module 9- 7,730-7,740 Module 6 8,144' Module 8- 7,769'-7,779' Module 5 8,183' Module 7- 7,967'-7,977' Module 4- 8,245' Module 6- 8,125'-8,135' Module 3- 8,416' it Module 5- 8,164'-8,174' Module 2- 8,512' Module 4- 8,223'-8,236' Module 1 - NA ' Module 3- 8,397'-8,407' Module 2- 8,491'-8,501' r Module 1 - 8,584'-8,594' Tagged fill @ 9,397' (7/19/13) >r1 ti' w/2.25"gauge ring r` '" ej Directional Data: KOP-2,200'at 1.3 deg/100'build EOB-4,178',28.1 deg hole angle Drop-4,240'@ 0.8 deg/100' TD PBTD Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 1.3°/100 ft @ 2,200' I Angle/Perfs:I 1°-.3° Maximum Deviation: 28°@ 4,178' Date Completed: 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 7/19/2013_ Schematic Revision Date: 8/8/2013 • 0 • .. BC-13 PROPOSED Pad 3 SCHEMATIC Ili!carp Alaska,LLC 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 203-138 API#: 50-133-20525-00 .t MD Prop. Des: A-028083 Conductor KB elevation: 179' (21'AGL) 20" K-55 133 ppf PE•Latitude: Top Bottom Longitude: 0' 165' Spud: 11/9/2003 TVD 0' 165' TD: 12/6/2003 Rig Released: 12/15/2003 Surface Casing @ 06:00 hrs 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' Tree cxn:6-1/2"Otis 16"hole Cmt w/568 sks of Class G TOC 3-1/2"Csg Intermediate Casing (1/16/04 CBL)-6,730' 9-5/8" L-80 47 ppf BTC Top Bottom Excape System Details MD 0' 7,288' -BHP monitoring line volume tank TVD 0' 6,973' located from 7,668'-7,706' !•, 12-1/4"hole Cmt w/1,144 sks of Class G _ Production Tubing Capillary Tubing y„ I 3-1/2" L-80 9.3 ppf EUE 8rd 3/8" 2205 Stainless Steel Top Bottom Top Bottom • . , MD 0' 10,462' MD 0' 0' # '/ TVD 0' 10,144' TVD 0' 0' ---_ 8-1/2"hole Cmt w/1,475 sks class G cmt (***Pulled 05/14/2009***) f; • Excape System Details Excape System Details 9 Excape modules placed -8 Conventional flappers Mod 1 -no flapper -Green control line fires bottom •-Ceramic flapper valves ___, module below each module as -Red control line fires top 8 modules follows: ' -Ceramic flapper valves below each Flappers MD(RKB): module Module 9- 7,749' , jam Perfs MD(RKB): Module 8- 7,788' Module 7- 7,986' : •; I Proposed-7,725'-7,744'(12spf) Module 6- 8,144' 44 Module 9- 7,730'-7,740' Module 5 8,183' I Module 8- 7,769'-7,779' Module 4- 8,245' Proposed-7,917'-7,953'(12spf) Module 3 8,416' Module 7- 7,967'-7,977' Module 2- 8,512' 1jf Proposed-8,125'-8,136'(12spf) Module 1 - NA f. Module 6- 8,125'-8,135' Proposed-8,158'-8,168'(12spf) ,'4 tit Module 5- 8,164'-8,174' Tagged fill @ 9,397' (7/19/13) k-� t •; Module 4- 8,223'-8,236'• w/2.25"gauge ring $ Proposed-8,228'-8,261'(12spf) �= Proposed-8,395'-8,403'(12spf) Module 3- 8,397'-8,407' Directional Data: • ' Ili l `' Proposed-8,411'-8,415'(12spf) KOP-2,200'at 1.3 deg/100'build w Module 2- 8,491'-8,501' EOB-4,178',28.1 deg hole angle Module 1 - 8,584'-8,594' Drop-4,240'@ 0.8 deg/100' TD PBTD Proposed-8,586-8,590'(12spf) / Hold-8,550', 1.0 deg hole angle to TD 10,500'MD 10,429' MD 10,182' TVD 10,111' TVD Well Name&Number: Beaver Creek Unit#13 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 1.3°/100 ft @ 2,200' I Angle/Perfs:l 1°-■3° Maximum Deviation: 28°@ 4,178' Date Completed: 01/22/04 Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 8/10/2013 u M Marathon MARATHON Oil Company • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 May 26, 2009 . ~~ `~ ~~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek #13 ~~,~~ ., ,~~li ~ ;~ `.4 ~~J Dear Mr. Maunder: ~~ pia ~ ~~/ sk`~ ~i qy ~ C/~ /~ ~~ cQ 20 s 0 ~~~~ C'~,~~ ~ 9 v,~~~~~ C~~~f~~/ ~~ Attached for your records is the Report of Sundry Well Operations, 10-404, for BC-13 well. This report covers the work performed to raise the 3/8" capillary string up-hole from 8,580' MD to 0' MD. This well is being reevaluated to determine the actual effectiveness of foamer as a wellbore fluids removal agent. Marathon completed this work on May 13, 2009. As agreed upon, no AOGCC approval is required for capillary string depths adjustments. So there is no sundry approval number reflected on this 10-404 form. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~.~,;~. ~. s k:~d Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Well Schematic KJS ~EC~I Y ~~.~E~ STATE OF ALASKA 6.3-09 ALA OIL AND GAS CONSERVATION COM~ION SAY ~ ,~ ZOOS ~~~ REPORT OF SUNDRY WELL OPERATIONS ~13~~~~ Alaska Qi! ~ C~ ~~n ~. t;Omr~iis~i~r~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Othe,~ l.ril. ,,st Capillary Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ String setting Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ depth 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: p ^ Develo ment ~ Exploratory^ 203-138' 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20525-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 179' x(21' AGL) Beaver Creek #13 ' 8. Property Designation: 10. Field/Pool(s): ~ A - 028083 ~ Beaver Creek Field /Beluga 8~ Tyonel Pools 11. Present Well Condition Summary: Total Depth measured 10,500' - feet Plugs (measured) NA true vertical 10,182' , feet Junk (measured) NA Effective Depth measured 10,429' ~ feet true vertical 10,111' , feet Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 165' 165' Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1/2" 10,461' 10,143' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,730' - 8,594' gross True Vertical depth: 7,412' - 8,276' Excape 3-1 /2" L-80 10,461' Tubing: (size, grade, and MD) Capillary 3/8" 2205 Stainless Steal 0' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): The 3/8" capillary string was moved up-hole from 8,580' MD to 0' MD. Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,904 1 650 358 Subsequent to operation: 0 2,158 - 650 374 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: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician Signature Phone (907) 283-1371 Date May 26, 2009 V $ Form 10-404 Revised 04/2006 (~ ~ ~ ^ ~ t'~` ~ ~ ~+~~ ~ ~~N ?,} ? mit Original Only ,` Marathon Operations Summary Report ,,,~~, Q~~CO~~y Well Name: BEAVER CREEK 13 Daily Operations Re ort Date: 5!142009 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU BJ Dynacoil. Pull 3B" capillary string. Flange up tree cap and secure well. RDMO BJ Coiltech to BC 10 to install capillary string. Ops Trouble Start Timz End Time Dur hrs O s Code Adivi Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG AF Held PJSM w! operator, BJ Dynacoil, and ASRC. Discussed Simops, cranelmanlift ops, emergency procedures, and smoking/muster area. Obtained safe work permit. 08:00 10:45 2.75 KURD COIL AF Spot Dynacoil unit and RU. Split injector head and reloaded extra tubing on spool. Set injector on tree. 10:45 12:45 2.00 RUNPUL COIL AF Pull capillary string. String Wt: 1100#. Overpull to get free: 2800#. POOH @ 90 fpm. 12:45 15:15 2.50 RURD OTHR AF Change out well cap spool. Wait on roustabout with correct hammer wrenches. Pressure test tree cap- good test. 15:15 16:30 1.25 RURD COIL AF RD injector head and Dynacoil unit. RDMO Dynacoil unit to BC 10 for capillary string install. Turn in safe work permit, sign out, and leave location. www.peloton.com Report Printed: 5/20/2009 203-138 50-133-20525-00 A - 028083 on: 179' (21' AGL) 11 /9/2003 12/6/2003 sed: 12/15/2003 @ 06:00 hrs Tree cxn = 4-3/4" Otis • Beaver Creek 13 1,310' FNL, 1,480' FWL, Sec. 34, T7N, R10W, S.M. CagillarY Tubing 3/8" 2205 Stainless Steal Top Bottom MD 0' 0' TVD 0' 0' Excape System Details - BHP monitoring line volume tank located from 7,668' - 7,706' Ceramic flapper valves below each module as follows: Module 9 - 7,760.7' Module 8 - 7,799.6' Module 7 - 7,997.8' Module 6 - 8,157.3' Module 5 - 8,196.3' Module 4 - 8,257.8' Module 3 - 8,426.3' Module 2 - 8,521.8' Module 1 - NA ~~ ~~ s ~ +! M MARATHON Drive Pige 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' 16" hole Cmt w/ 568 sks of Class G 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G ~r~' •.,. 1= h ~, t ~ M'. ~' t `~ C ,,~y A ~ ~' Fj °'~ ~~ ~.~ ~~ ~ ~: « ,.. ~Ij ? ~ ~~ .~~ ~, ~~ i - TD PBTD 10,500' MD 10,429' MD 10,182' TVD 10,111' TVD Well Name & Number: BC-13 Lease: Beaver Creek Gas Field County or Parish: Kenai Penisula State: Alaska Country: USA Perforations (MD): 7,730' - 8,594' (TVD): 7,412' - 8,276' Angle @ KOP and Depth: 1.3° / 100ft @ 2,200' Angle/Perfs: - 1.5° Dated Completed: 1/22/2004 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 5/26/2009 Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom w/ 6.25" OD MD 0' 7,571' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,475 sks class G cmt - 9 Excape modules placed -Green control line fires bottom module - Red control line fires top 8 modules -Ceramic flapper valves below each module Perfs MD (RKB): Module 9 - 7,730'-7,740' Module 8 - 7,769'-7,779' Module 7 - 7,967'-7,977' Module 6- 8,125'-8,135' Modules- 8,164'-8,174' Module 4 - 8,223'-8,236' Module 3 - 8,397'-8,407' Module 2 - 8,491'-8,501' Module 1 - 8,584'-8,594' BC-13 & BC-14Cap-String Reporting Requirements Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 03, 2008 10:28 AM To: 'Skib Kevin J.' Subject: R . BC-1 & BC-10 Cap-String Reporting Requirements Kevin, ~~~" ~ ~~ You have captured our discussion. Call or message with any further questions. will put a copy of this message in the files. Thanks for the compliment. Tom Maunder, PE AOGCC From: Skiba, Kevin ]. [mailto:kskiba@marathonoil.com] Sent: Wednesday, December 03, 2008 9:19 AM To: Maunder, Thomas E (DOA) Subject: BC-13 & BC-10 Cap-String Reporting Requirements Tom, As per our telephone conversation, no 10-403 sundry is required to pull the capillary string out of BC-13 well for use in BC-10 well. Documentation of the BC-13 work will be reported on the follow-up 10-404 Report of Sundry Well Operations. A 10-403 Application for Sundry Approvals will be submitted for the installation of the BC-10 capillary string. No 10-403 approval will be required for reinstalling a replacement capillary string back into BC- 13, when one becomes available. As with removing the BC-13 string, documentation of this reinstallation work will be provided on a follow-up 10-404 Report of Sundry Well Operations. I realize that you are a busy person. I appreciate your willingness to take the time to work through and clarify issues, as they come up. Your helpful approach is a refreshing aspect in dealing with the many hurdles, which need to be overcome, of bringing gas/oil to market. Thanks again for all your help, Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 12/3/2008 M Marathon MARATHON Oil Company July 28, 2008 ~~~~~~~ AuG ? ~~. 2aas Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Report of Sundry Well Operations Field: Beaver Creek Unit Well: Beaver Creek Unit #13 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 /v~.._ i` a~j $ Attached for your records is the10-404 Report of Sundry Well Operations for BCU-13 well. This report covers the capillary string installation performed under Sundry #308- 215. The capillary string was installed on 6/30/2008 and set at a depth of 8,580' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~~g ~s ~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD ~-, -.__~. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMII~IONJ~}i_ REPORT OF SUNDRY WELL OPEF,~.ATl~IS '~ ~~ 11 Q ~~'a~ LUU 1. Operations Abandon Repair Well Plug Perforations Stimulate C4h~r ~ Install Capillary Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development Q~ Exploratory^ 203-138' 3. Address: PO BoX 1949 Stratigraphic ^ Service[] 6. API Number: Kenai Alaska, 99611-1949 50-133-20525-00-00' 7. KB Elevation (ft): 9. Well Name and Number: 179' 21' AGL ~ Beaver Creek #13' 8. Property Designation: 10. Field/Pool(s): A - 028083 ~ Beaver Creek Field / Beluga ~ Tyonel Pools 11. Present Well Condition Summary: Total Depth measured 10,500' ~ feet Plugs (measured) NA true vertical 10,182' , feet Junk (measured) NA Effective Depth measured 10,429' ° feet true vertical 10,111'4 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 165' 165' Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1 /2" 10,461' 10,143' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,730' - 8,594' gross True Vertical depth: 7,412' - 8,276' Excape 3-1 /2" L-80 10,461' Tubing: (size, grade, and MD) Capillary 3/8" 2205 Stainless Steal 8,580' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,235 1 0 510 Subsequent to operation: 0 3,405 1 0 545 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 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: 308-215 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician - Signature ~ Phone (907) 283-1371 Date July 28, 2008 Form 10-404 Revised 04/2006 ~~~~~~~L Submit Original Only M Marathon operations Summary Report „~,T,~r ;~~~ ComPa~Y Well Name: BEAVER CREEK 13 Report Date: 8CJ8f2008 Job Category: R&M MAINTEHAHCE Edit 2i HrS~mmary Deploy 3+~" capillary string at 85$0' KBD, RD. Hook up foamer and pump skid. ~rtTlne ErOTme Drr 0 COOe ACltl COtle Ops St3Els Tro~bkCOde Edit Canme~t 06:00 0?:00 1 .00 SAFETY MTG Held PJSM and discussed safety alarms, issues around well head. 0?:00 08:00 1 .00 RURD COIL MI spot up equipment. MU tree connection to well. PT tree connection to 3000 psig. Gaod test. PU injector go to well. MU pump in mandrel and double checks. Set ressure sattin at 3500 si . 08:00 09:00 1 .00 RURD COIL Injector on well. Open well. RIH with 318" capillary string with knuckled wobble bar with centralizers. On depth at 8580' KBD setting depth. No roblems while runnin in well with ca strip . 09:00 11:00 2.00 RK COIL P= 510 psig, 2.2 MMCFPD rate @ 1 .0 BPD. Secured cap string. disconnect injector and take to ground. Start pumping Foamer to fill line. Pumped 24 gals. Stopped pumping and finished rig down of Dyna coil unit. 11:00 12:00 1 .00 RURD COIL Cleaned up around well head. Secured well by locking open all tree valves. Dyna coil capillary string hung. BJ completed hook up chemical pump and started pumping product. 12:00 13:00 1.00 RURD COIL D na Coil left lease. www.peloton.com Report Printed: 7C28l2008 203-138 Beaver Creek 13 50-133-20525-00 A-o28o83 1,310' FNL, 1,480' FWL, on: 179' (21'AGL) Sec. 34, T7N, R10W, S.M. 11 /9/2003 12/6/2003 sed: 12/15/2003 @ 06:00 hrs Tree cxn = 4-3/4" Otis TOC (est.) - ???' Excaae Svstem Details - BHP monitoring line volume tank located from 7,668' - 7,706' Caoillarv Tubing 3/8" 2205 Stainless Steal Top Bottom MD 0' 8,580' TVD 0' 8,580' Ceramic flapper valves below each module as follows: Module 9 - 7,760.7' Module 8 - 7,799.6' Module 7 - 7,997.8' Module 6 - 8,157.3' Module 5 - 8,196.3' Module 4 - 8,257.8' Module 3 - 8,426.3' Module 2 - 8,521.8' Module 1 - NA M ~Ar~-n~oM Drive Piae 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' 16" hole Cmt w/ 568 sks of Class G Intermediate Casino 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom w/ 6.25" OD MD 0' 7,571' TVD 0' 7,544' 8-1/2" hole Cmt w/ 1,475 sks class G cmt r " " M TD PBTD 10,500' MD 10,429' MD 10,182' TVD 10,111' TVD - 9 Excape modules placed - Green control line fires bottom module - Red control line fires top 8 modules -Ceramic flapper valves below each module Module 9 - 7,730'-7,740' Module 8 - 7,769'-7,779' Module 7 - 7,967'-7,977' Module 6 - 8,125'-8,135' Module 5 - 8,164'-8,174' Module 4 - 8,223'-8,236' Module 3 - 8,397'-8,407' Module 2 - 8,491'-8,501' Module 1 - 8,584'-8,594' Well Name & Number: BC-13 Lease: Beaver Creek Gas Field County or Parish: Kenai Penisula State: Alaska Country: USA Perforations (MD): 7,730' - 8,594' (TVD): 7,412' - 8,276' Angle/Perfs: Angle KOP and Depth: Dated Completed: 1/22/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 7/28/2008 • ~y 9 ~; ~ f~ ' t I ~ ~ , q ~„ l.J ~.. -~'~ `~"~~ ~ € ~ SARAH PAL/N, GOVERNOR -~c~r~~ ~IL ~D ~ / 333 W. 7th AVENUE, SUITE 100 CU1~5ERQATIUI~ CUl-Ii-IISSIUI~T J ANCHORAGE, ALASKA 99501-35 / PHONE (907) 279-1433 ' FAX (907) 276-7542 Dennis Donovan 39 Production Engineer Marathon Oil Company PO Box 1949 ~~~~~~ JUN ~ 200$ Kenai AK 99611-1949 b3 ~ 3 ~ o~. ~~ Re: Beaver Creek Field, Beluga/1~onek Gas Pool, Beaver Creek # 13 Sundry Number: 308-215 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, T. Seamount, Jr. Chair DATED thisZ b day of June, 2008 Encl. 1 M Marathon MARATHON Oil Company June 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 SUN 1 ~ 2GGu~ Al~slca Oil G~~ ," ~ :; Arh Reference: 10-403 Sundry Notice Field: Beaver Creek Unit, Pad 3 Well: Beaver Creek Unit #13 (PTD 203-138) Dear Mr. Maunder: We propose to run a 3/8" capillary string in BCU #13. With the availability of a capillary injection unit on the Peninsula starting the week of June 23~d 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 8580' MD. The past capillary string installation into KTU 24-6H (PTD 199-073) has yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would like to continue to install capillary strings in other wells like BCU #13 and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~/~ Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File DMD KJS .~• ..i,11,~~ STATE OF ALASKA 6~ ~" ~'I~AL~ OIL AND GAS CONSERVATION COM~IG~~N ~ ~ 2OO& ~4' APPLICATION FOR SUNDRY AP~~~01~(~$~~ ~~,~~ Commi~S~an ~ 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^ ~~ 'C'~B~~Jaiver^ OtherO Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: ~ Development ^ Exploratory ^ 203-138 3. Address: pp BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20525-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S a i E ? ^ ~ Beaver Creek #13 p c ng xception Required Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~ A- 028083 ~ 179' (21' AGL) Beaver Creek Field /Beluga 8~ Tyonel Pools 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,500' ~ 10,182' ~ 1 0,429' 10,111' ~ NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 165' 165' Surface 2,275' 13-3/8" 2,296' 2,296' 3,450 psi 1,950 psi Intermediate 7,267' 9-5/8" 7,288' 6,973' 6,870 psi 4,750 psi Production 10,440' 3-1/2" 10,461' 10,143' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,730' - 8,594' gross 7,412' - 8,276' 3-1/2" L-80 10,461' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development /^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 26, 2008 Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name De nis M. Donovan Title Production Engineer Signature Phone Date (907) 283-1333 June 18, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a~_J Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~3F~. ,iUN 3 0 2008 Subsequent Form Required: ~ l~~--( APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: ~,~ ~ ORGIN,~L Form 10-403 Revised 06/2006 Submit in Duplicate .. 2008 Capillary String Installation Page 1 2008 Capillary String Installation Program CLU, SU, BC, KGF .and NGF WBS#s SD#3 - W0.08.18049.CAP.001 KBU 11-8Y, 33-6X, 41-7 - W0.08.18053.CAP.001 BC 13 - W0.08.18054.CAP.001 CLU 6 - W0.08.18056.CAP.001 SU 32-9 - W0.08.18117.CAP.001 GO 6 - W0.08.18196.CAP.001 Objective -Install a 3/8" Capillary String into these wells to alleviate liquid loading. We intend to treat the producing fluid level in each of these 8 wellbores with foamer. Install and Complete CICM (injection skids) to utilize on wellheads. We have seen an incremental increase on KTU 24-6H capillary string installation of approximately 475MCFD. Procedure Companies Evolved: UOSS, BJDC, BJCS, BigG .~ Installation Order ell Maximum Setting De th Maximum String Len th Minimum String Needed at Surface trin Size and T e lan a Connection Est'd Producing Fluid Level a De th Gauge Ring ID run Recommended Setting Depth From PT+Ta 1 CLU 6 8042' 8200' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 7880' 8058' 2.300" 8020' 2 SU 32-9 6200' 6250' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 3 BC 13 8590' 8750' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 7900' 10055' 2.300" 8580' 4 GO 6 10120' 10300' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 5 SD 3 9290' 9450' 45' 2205 3/8" X 0.049" WT 4-1/16 5M RX39 TBD TBD TBD TBD 6 KBU 41-7 6910' 7050' 45' 2205 3/8" X 0.049" WT 3-1/8" 5M RX35 TBD TBD TBD TBD 7 KBU 11-8Y 8145' 8300' 45' 2205 3/8" X 0.049" WT 3-1/16" 10M BX154 TBD TBD TBD TBD 8 KBU 33-6X 8200' 8350' 45' 2205 3/8" X 0.049" WT 3-1116" 10M BX154 TBD TBD TBD TBD 2008 Capillary String Installation Page 2 Installation Procedure: 1.) BJCS: (Hold PJSM and JSA) a) Complete placement of 3 new CICM skids on wells CLU 6, SD 3, and KBU 41-7, all other wells have units placed. They will complete Installation of items that are pertinent to operation of CICM. b) Move NS#3 CICM to GO#6 well 2.) UOSS: (Hold PJSM and JSA) a) Removal of all well houses to setup for BJ Dynacoil Unit b) Replacement of CICM roof on (3) new skids, after tanks are set inside containment. 3.) Big G: (Hold PJSM and JSA) a) Complete explosion proof electrical end fittings for CICM b) Complete tubing for hookup of Dynacoil - if needed. -Placement of an open conduit under the well house wall for easy routing of 3/8" id tubing for skid hookup. This will prevent multiple tubing disconnects when well work is needed, thus reducing exposure to trapped pressure. 4.) BJDC: 1. Hold PJSM and Complete JSA/JHA 2. Move in rig up BJ Dynacoil unit. 3. Replace tree-cap flange with specified internally threaded flange listed above in the matrix. 4. MU BHA and secure to 3/8" string. 5. MU WHA to internally threaded flange 6. MU Trailer Haskell Pump to WHA with 1"male NPT tie back assembly 7. Pressure test flange assembly against a closed valve to 1.5 times SITP with Trailer Haskell Pump. 8. "SHUT IN WELL AT WING VALVE" -This will prevent BHA from traveling down flowline. BHA is small and capable of flowing into flow-Tee 9. RIH with capillary below "Est'd Producing Fluid Level". All strings must be set into the producing fluid level to prove the most effective. 10. Set Rattiguns and Leave 1.5 times SITP or greater as requested by BJDC on hydraulic pack off. 11. "OPEN WELL TO PRODUCTION" 12. Leave remaining spool of tubing outside of well for soap injection skid hookup. 13. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 14. Lockout/Tagout Swab, Upper Master and Lower Master. (Install BJ Dynacoil signs on all valves stating "Do Not Operate BJ Dynacoil in wellhead". Proceed to Lockout valves with production lock and cable.) 15. Hookup injection line to CICM, and set specified rate for each well. 16. RDMO, Cleanup site, Sign-out • Permit#: 203-138 Beaver Creek 13 API #: 50-133-20525-00 Proo. Des: A-028083 1,310' FNL, 1,480' FWL, KB elevation: 179' (21' AGL) Sec. 34, T7N, R10W, S.M. wBS #: 11 /9/2003 12/6/2003 sed: 12/15/2003 @ 06:00 hrs Tree cxn = 4-3/4" Otis TOC (est.) - ???' Excaae Svstem Details - BHP monitoring line volume tank located from 7,668' - 7,706' -Ceramic flapper valves below each module as follows: Module 9 - 7,760.7' Module 8 - 7,799.6' Module 7 - 7,997.8' Module 6 - 8,157.3' Module 5 - 8,196.3' Module 4 - 8,257.8' Module 3 - 8,426.3' Module 2 - 8,521.8' Module 1 - NA ri i i ;' ~. ,r ,~,. ~, M ~ar~-n~oM Drive Piae 20" K-55 133 ppf PE Top Bottom MD 0' 165' TVD 0' 165' Surface Casino 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,296' TVD 0' 2,296' 16" hole Cmt w/ 568 sks of Class G 9-5/8" L-80 47 ppf BTC Top Bottom MD 0' 7,288' TVD 0' 6,973' 12-1/4" hole Cmt w/ 1,144 sks of Class G Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd `~ Top Bottom w/ 6.25" OD MD 0' 7,571' ,i TVD 0' 7,544' ~~ 8-1 /2" hole Cmt w/ 1,475 sks class G cmt s 8 ~i ~~ 10,500' MD 10,429' MD 10,182' TVD 10,111' TVD - 9 Excape modules placed -Green control line fires bottom module - Red control line fires top 8 modules - Ceramic flapper valves below each module Module 9 - 7,730'-7,740' Module 8 - 7,769'-7,779' Module 7 - 7,967'-7,977' Module 6 - 8,125'-8,135' Module 5 - 8,164'-8,174' Module 4 - 8,223'-8,236' Module 3 - 8,397'-8,407' Module 2 - 8,491'-8,501' Module 1 - 8,584'-8,594' Well Name & Number: BC-13 Lease: Beaver Creek Gas Field County or Parish: Kenai Penisula State: Alaska Country: USA Perforations (MD): 7,730' - 8,594' (TVD): 7,412' - 8,276' Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 1/22/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revison Date: 6/17/2008 • M Marathon MARATHON Oil Company • Alaska Asset Team Northern Business Unit P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 i~~~EIV~D t,« ~~r., ~ ~ ~~~7 August 13, 2007 2r ~ ~~~r ~; ~~)t~: ~'~ ~~ ~~),,J ~,~,~a'~~%.~' ~laska WiI ~w ~#~ ~Qn~, Carr~~n~ac~ar~ John K. Norman /d~CNnfe~C Chairman AOGCC ~s~,,~ ~ ,~ ~ 333 West 7~h Ave S ~~~"~- Suite 100 ~~,~"~~~~ ~~~~ (r~ ~. ~~ Anchorage, AK 99501 ~J `_ _ v ~~ Re: Beaver Creek Gas Field, Beluga Gas Pool, Beaver Creek 13 ~ PTD: 203-138 Dear Mr. Norman: ~c~ l ~y~,~ A~ck~o~c~s-e.f (L~~ci~-~~~~~c %.`\:o~ ~ l~~vS~~~c)-~~ c~t~~c~~n. '' ~ Marathon Oil Company has received your letter dated July 26, 2007 which states that the AOGCC has identified deficient reporting for this well. The first deficiency noted is that an operations summary of the rig related and non-rig related initial completion work for this well was not submitted. Marathon's investigation of this issue noted that the drilling portion of the operations summary was submitted but, as you state, the completion ~ summar~r was not filed. Please find attached the daily operations summaries for the completion wo'-~r "on-'fhis well. You also indicate that a Form 10-421 was not submitted for this well. Pfease find attached a completed 10-421 for the potential test data recorded during the initial testing. 3~S~S ~~~a~~ ..,~, a~c~-SL5 ~,.~,c~ ~ During review of records for this well, Marathon also discovered other reporting issues that we wish to remedy at this time. A Form 10-403 for the initial completion activities to fracture stimulate this well appears to be missing from the records. The com pleted form is attached for your review, post-work approval, and record. (Note: Form ~~~~ 10-403 for stimulation activities was discussed between Ken Walsh and Winton Aubert and documented in an email dated 3/21/06. In that conversation, Marathon was advised that the AOGCC would notrepuire the Form 10-403 to be submitted for past activities where a Form 90-407 had already been filed.. Such is the case here.) This completion activity was previously reported on Form 10-407, however the Form 10-407 was submitted prior to establishing commercial production from the well. (note: this possibly explains in part why a Form 10-421 was not submitted timely). Please find attached a copy of the original Form 10-407 taken from the AOGCC ' website files with corrections noted in Section 26 with test information. Additionally, you requested an explanation for failing to provide the required information. The activities forwhich missing Form 10-404's were discovered occurred more than 3 years ago, and due to personnel turnover, we regrettably cannot explain these omissions although organizational transition at about the same time period certainly contributed to the problems. Marathon understands that these are very serious omissions and has recently prepared and committed to a plan to prevent reporting deficiencies. We have undertaken several new steps including: development of better tracking tools, defined roles and responsibilities, and a commitment to educate employees and review regulations. Also, we will continue to review our records and report and correct any past deficiencies promptly upon discovery. ~ ~ Marathon regrets the past reporting omissions for this well and is committed to preventing anyfuture omissions. If you would like any other information or have additional questions, please contact me at 907-565-3042. Sincerely, yndon C. Ibele, PE Production Coordinator Enclosures: 10-403 Sundry cc: Houston Well File Operational Summaries Kenai Well File Well Schematic KDW 10-421 Sundry 10-407 Revised Original Sundry • • RECEIV~~ __ AUG 1 4 ~ool Marathon 0il Company P~e 1 of 3' 4perations Summary Report ~~a~ko p~l &~as cons. Commissian Anch~tra~e Legal Well f~me: BEAVER CREEK 13 Common W~I N~me: BEAVER CREEK 13 Spud Date: 12/9/2003 Event Nam~: ORI(31NAL COMPLETION Start: 1/16r2004 Er~i: Cc~ntrac~or Name: CsLAClER DRLLLING Riq Releaae: 12t15~2003 Group: Rig Name: GLACIER DR1LL1tdG Rig Numb~r: 1 E?~e ~ro~a , To Htw~ Gc~e ~ Pt~~e 1M~Q04 ~Y~O -1~00 3.00 WAIT E~P WBFREP 12~Op -14:40 Z.~O Rl~ EQ1P WBPREP 14:~ - 2f}:00 A.O~ LOG_, C~G W~PREP 2t1:00 - 20:3L1 0.50 LOG_ CSG W9PREP 2A:30 - 21:00 0.."A RURD ~QIP WBPREP 1123J2004 0~:30 - f1D:30 1.A0 SAFET'Y Si-fTG CAAPS'TM 0~:30 -1(k30 1.t10 PUMP FRAC C~STM 1 ~:34 -11:30 1.00 Pt1MP_ FP2/4C C.k+~'$TM 11:30 -13:30 2.A0 PUMP Ft~uC CMPSTM 13:30 -14:30 1.00 PtJMP_ FRAC C.MPSTAA 14:30 - 95.-00 Q50 Pt11~tP FRI4C (~+lPSTM 15:D0-1~:00 1.0~ PUMP FRAC CIu~STM 16:90 -1f~34 3.'SO RURD C4(L Ciu~S'fAA 1Q:~Q-06:00 10.60 TR1P BtIA Cl~APSTM 1/24/2Q04 dt:~ - t3~04 2.{~0 TRlP_„_ 6FiA CMP$TM aS:CO - t?~30 Q.StI SAFETY ~MMTG f~i1PSTM Q~B::~ - Q(~kAO 0.50 ~'ER~ G-~S76A O~:Ofl -11:AC 2.OA PtjMf' FRAC CI~'S7'FA 14:A0 -11:30 0.30 P13A~ FFtAC CMPSTM 11:~ - 9~30 1.00 Pi1N~' FFtJ1C CAAF'STM '12:30 -16:Q0 ~.5t} WRITOA! OTHR CMPSTA# 16:00 -19:30 3.50 RURD CC}1 L p~STM 4~:39 - tiD:~ 4.3(! 1'RIP BHA CI~STM 04:90 - 02:~ 2.00 TRlP_ ~HA C1u~STM 112.312{l04 O~t:00 - 08:00 200 SgCU WELL C114F'STM 08:OD - 11:00 3.OQ WAIT E~P CM3~STAA 11:A0 -11:30 0.5Q 8AFE1'Y SbA'fG ChAPSTAA De~iption aF Clp~ation~ W~ trudc r~ a~f mad, ee-om 3n~C b~eaic t~ and wc truc9c ~ir vslw ~trst cwt in the mcunir-Q. -30 bMo-ir c~np fr+~irKt p~ms RlJ RNV~s tivFndItw bool s01np. IV4+ p~ tan v~tl. PW 1lte sf~w r~ith bAOm UuCk. M41 wC trut~ 1~o puU wc~cari on ~aw lir~ 4~ ksap -iquid keun ca~cl~np ~rcwexf as liquid is disD3awd wkh win v-4~ila runnis~g in wtiq. Qn botLOm with ads-p~sa~d aaNc c~nePtt bp~ q~sd ~tl at 10~W' tC~1D. ROOH maicing up 30 FPM. Tesp ~ c~m~nt ~ 6750` 1IVMn toal at tr~a. tcwl s~c~c in tr~t b~cstust ~ Ec~, ts~r AA~etharwl in U-ae. htook up fresst ti~tt~r ttea~ter. Tc~ol Ictote in 15 minutsr. Drwmn btd LoG! and farwat~d b~ m Mchotage ' piot ba RD. Lop good Flnkfi RD. R~ kR l~ss~. liricf PJ8M. Disd~s~d stips trips and talis dt tinar. Disan~sd c~~ertticsl tr~cers. T~st E~ro m~r+oi ~r~s to 10.000. V~rt!{~d sFat d~on ~quiptnealt workirty IMt-{~r1Y• Rressuts fw3 6U inc W~ss and aqui~n~nt 40 ~l00 psi. Ts~at ha~bur0on flovrbac~c lirses to 4'S00 {ui. ~n~k do~m rnodule cu~ p~s ai 8582-8"~3. G3d up t~ trtaGnw~t Prp d~nical pumps. Purnped 48 ~ ped fadtoa-~a~d by ~ bbk stuny rarrtping tnom 2-6 ppg. Tra~hn~t scre~ned aut rA~n 2 p{sp hit perfs. Shut doartf and c~eon frac tquipr»e~L Fbwbadc ar~t b ditRe~ar tanlc :tEsrnpting b su~e pa~s an w~{o~ci i~i~ in tubing. W~ sbwly dled. Nc . Fl~h out saufacs tulss to ~i}fiuser ~ and k~la,~r linas ciry. ManiEcx wetl. SITP sbwly ir~sssing. Attempt to fbw wetl s~cond t)me. Wdl disd no sur.cesc. Flush stuiaca lir-~. Atlrmpt ~ pump intc wrsU rvitho~ut ruc~a. Fi~h iinss and b~w sarr~e dry. RD frac lines RUtFiD Ccailsd Tubing EquiPrr-ent Run in Hol~ with C.o~d T~arrg tutd claan cu~t pr4ppar-t tD 10371'. Tagp~d fam and sticky fdl. P~ic up and C:BU. PuY a~d af lid~ w~h Cailwd Tubir~p anr! RD sarne. h1~8d PJ~M Prassur~ up a~ redJfns srru! p~rEorate madula 2 at Thaw twt ira~ ftac trtitdc, c~emic~l pump t§~es. and fc~ tartk rrtsr7ifodd. Pump into modult iwo psrfs. Same fo t{pht m tr~aL 15 BPM at 8700 P&• P~bOratad mod~ia tlxte Der[~ st Pumpsd 73 bbl pad, 100 bbis of alurry rampir~g from 2 ppg - 6 ppg. Trsatm~t icraarwd out wh~n 4 ppg hit p~er#s. Pta~d 1730 1 bs of 16f30 in parEa. At~eanpied to 4lorvbtdc twe!! b ct~an cw# ~~sant fiUed utbir~g wi~tau! sut:a~ss. Shut dc~wn and ~tisft out irsc i~ artd E~ow sme tlty. Call ~Oii tl~g. Wsit on Ca11bg persont~e! RU/RO Caisd Tubing E4ui~une~nt snd 4est lines to 4Bd0 psi. Run In Ho~s wifh Coil~d Tubing u~d dsan out prnppant from t~inp. qear~d ait ~0 8622'. Saw rw indic,a~at ot ~Y ~cs~ ~pars• Pull ouf o¢ tiole aqth Cahd Tubar~g, RD aam~. 3QFN. Seouro W , 31FN Wait cn frec equipm~nt to rMarm up. Trouble s#arting c~d enpines an frac trucks. H~d PJSM Printe~l: 9nr2007 t2:sa~z PIA ~ ~ REC~IVED Marathon O~l Company AU G 1 4 a~ge 2 of 3 Operationa ~umrnsr~/ Report Alaska 0~l & G~~ Cons. Commi~~ Anchar~~~ Legal Wel! Name: BEAVER CREEK 13 Common WeU N~rne: BEAVER CREEK 13 Spud Date: 12/9/2003 Event Narr~: ORI(31NAL COMPLETION St~rt: 1/16/2004 End: Contrac~r Narr~: (3lACiER DRILLING Rig R~lease: 12115l2003 Group: Rig Name: GLACIER DRlLL1NG Rig tdumber: 1 Qa~ ~rorrt - To Mours Cacfe ~ P~ De~x'ip#on c~ Op~r~#~ans it2~tZflf~N 1l:~ -14:3Q 3.~ WAIT C~AT CAAPSTM Wait on brtak~r Lrcfing at bea~n. Brak~ daemcisl rxat brs~ir-8 gel, AAiac ir~ah loradc~ chernc~a! and test sama v~ ~otl raKUi4s. 14:30 -15'00 Q..rsp PERF CA~tPSTM Pm^k~rtte rrsodutm 4 pdfs 833$-8238. VerilyA guns Bncf. !S:(a0 -18.~00 1.~ RUMP_ FRAC CMPSTM Cad up ik~id to 2~Ik eystrrn. Verfiy chamtca! pumps sst t^~tec~ly. 18:OA -17:Ot! 1.t~0 PWMP_ FRAC CMPSTk! Pump t~laJ a! 213 ~s. Ramped slurry from Z ppp . E p~ip, plsdd 31,~ ibs ~ proppsni. (8T.5% 16t3 vftawa and 12.5X 2af40 A~sc sartd) 17:~ -17:30 0.50 PUN~ FRAC Ct~rIPSTMI Ra^forst~ rtwdule ~ o~ia E7~47S, gtsqk da~m ~ qa~ lppp qaks 17:~-1~30 1.Q0 PUt~ 1~-1fl:A0 0.30 PUb~ 1~00-1fl:30 Q.50 PUMf~' 1l:3A - 2~90 0.30 PUAAP ZD:00 - 31:0~ 4.0p PUMP 21:~0 - Q2~00 S.(K1 RURD t32.'OQ - Ot.'fl0 4.00 PUMP i/28~2A04 t#~f~0-14:OL1 14:00 - 15:00 3J11/2004 OT:00 - 07:3(1 07:30 - ~00 O~:OU - 92:00 12:Q0 - 13:30 PUAit~' c~f 9sl tio op~ parfs. FRAC CAAPSTM P~rtnraLt moduls B Dsrfs 8128-~138. Tro~t p~e~rla with 413 !~ls. Rampad frcam 2 ppg - app9. PlaCad 4&flt~0 tbs prop~artt (87.6°~ 18J30 c>ttawa and 12.5~6 24/40 tl~ sand} F#tA~ GNP5TIA P~rata mcdule 7 pads 79d8-7DT8. Tre~ p~ wdit~ 27~t bb~. iiampsd from 2 ppy - i pqs. Piao~d 2;~.OElQ itas (~7.5% 1613D t#~wa arod 42.~% 2A140 t~x 8end) FFtJ-C CddPSTAA Pariorat~ modul~ ~ Der~s 7770-7TSLI. Br~rk dcr~+n p~s ~tA 1040 gats of g~1 m ~aan perfs. FRAC CMF'STM Pe~OraSR n~ocf~e ~ parts TT30-77i0. Tr~et ~ wri~t +4t~ bDis. uP i~'1' PFKi. ~.000 ~u picprp~flt (~7.5% 1~130 At~a and 13.SX 2Q140 tltst s~!) FRA~C CA+~STM Fk~th a~t frsc Ek~-e~ and a~uipm~t uui l~wr same c~y. RD frac fir~. COIL CA~STM RU oodl tubir~p equipm~rt Mix up 40t1 bW of !JX KCL P~p~re t~st littec to 48U0 psl. N2_ (~STlA R1M wttl~- ooi! tubinp artd dean out wNl to 10~54'. Ta~pp~d fam s~elc ~. Waald r~t vaah. Pidc up 6o abcKre tpp mcdule asad wssh badc tlv~h mocluhs attempW~g E~ locs~ta sxr~ps ftrpp~rs. Sav ra ' ~f ta~in snY of sfz fla~pers. N2_ (~AP~I'h! Pi)OH wi~ oe~tl fu~g b 9~00' ~nd bap~n ~rp w~eW in. WeEi 1.00 TRJP_ BHA_ CMPSTk1 P~,dl cu~t c~ Hole wr~h Coilsd Tubsnp and RD aame. Tum wsU owar to well testeB u~d Proc~ltxxl dspartm~L O.SO ~AFETY 3MTG CA+~FLW PJSM, e~in werk permit~ dlscuas pof~nrial hazards with H~lium b~ottle at welthesd, PLT w~h w~! #}owing. We11 st 4.2 MlWSCFD wiifi 135Q FTP. Add 21' to sli slm dmpths in ~po~t for KB clpth me~ur~n~t VMd! stwt in at SSV vd~t trea c~p r~ bted cfown. 1.SQ RURfl_ SUK Ch~FLW RU ec{~dptmm~t tcf and tree. AAU tcx~ sbing ' of 2.45 " gsuge ring, 10' s0em, T s~-an8 J~rs, 3' oil Jars. S' stem.l0' stem,l0' sEsm, and rop~t sockst. PT lubficafcu to S!"Fp. R1H b 400' and notros c~unter xd~ ha~ lins in wrong al~s~re gnoove. POQH and place wlre in aorred proc~re. PT tubric~tor tn SI7P ans! RIH. Opsn vrall tp 4.2 mmmsdpd u~d 1~.50 psi. 3.00 SEl'REL TOOL CM~FLW R1H wi~ 2.45' cockie a~tter ~uge rir~g it 160 fpm-~9 ~ T740 SLM, 7761 KB. Flsppe~- at 77A1. PU and 1c, T80A' C~lC. RtH ~ incrsosirtg sp~sds to 480 FPM wdth muttipb att~npts t4 brwk ft~r, pulf~d ~ wiri 2Q0 k~s ~e tims. Repeatad tags and feee PU m~d~k timas. Shut in wmU. Rili arpcJ ta~sd M-PDsr P4J tras. RtFi and taype~A st 7TE9i' strn. ~ tr.s m na~ a~m and ~ awr eao u~e. ~,o ~ m r.~o~ ana ~,u.e tn.. ~oori m~x at ~e r~r-~. c>~e„ ,~ ~ ~ 4 mmsc#pd utd 135t1 ps1. 1.50 SETREL TOOL CA~'FLW Of3ti wkh ~ts, bot~an of ~uge riny s~arred on bottom with ~ thnt indicsted bt>tborn of bod s~ hitbng a,un~q shary~. P~r aide of flapp~ cs~e aasertebly' in op~n pe~si~-• Sared pr+e~i ~ toof strir~p and gauge ring. MU 2.35" FAtjor OD ~. RtH arul taG ~P ~~ 16fl fpm, PU fr~e. Tag with 'uxrsasinq t~pssd Ep S00 fptrt and gc p,;nsea: amzeo~ is:u:os au • • Marathon 0il Cornpany AU G 1 4~e 3 a~ 3 Op~Ca~tN1S ~l1mt"rialy Rep4rt Alaaka Oil ~ G~a Con~. CQm~issi~ Le~l W~I! Name: BEAVER CREEK 13 Common Wsll Rlam~: BEAVER CREEK 13 Event N~: ORIGtNAL COMPLETION Contrac~w' Nam~e: f311lCtER DR11L1NG Fti~ Nams: C3L.ACIER DRILLIPIG t?~ Fram - To F~wrs C~ ~ Ph~s~ 3111/3004 12:OG -13:3i'~ 1.3~1 9iETlR~L TOOi. f~'FlW 19:3~1-14:16 A.7~ SETREL TOOd. C~'~L.W 14:15 -15:34 1.25 SETR,Et. TQOL Cl4~FLW 95:3Q-~i1:30 4.00 3ETREL 700L CMPFLW 1~:~ - 20:30 1.00 RUt~O~ SUK CAd~'FLW ilbi2G#k4 15:00 -15:~i Q.lfS 18:35 -16:30 O.S'1 18:30 -16:48 0.25 ~s:~-~a:oo ~.~s ~ An~hor~~~ ~ Spud Date: 12/9/2Q03 Start: 1 /1 812 004 End: Ri~ Releas~: 12/1512003 Group: Rig Number: 1 C~cr'iption c~f Q~ttt~ns tlvou~ wi~t bobbl~ a- ir-dlt~ttcx, PU ta ?~10' OK. FttH t3 E454 a~td tp .PU at-aw is trp. F21H at 40Q ipm, ~ t~. until 8#85' sdm. I~t1 frae, R!H at 4{3~ fpm, taq hvice at 84~5' slm, PU ~d Ftlhi at 400 tprn to 872~' stm b~ow ab modulec~ OK. POOH o0 76Q4'. C.ut ra~e bo 2.9 rnmstdpd, 1450 itp. RkH st 1601pm and tap ftapp~r at 7740' slm. PU anci RJH 2.35" swape with at 300 fpm wkh balah~e at Aapp~r. Tap at TT~O' stm. PU tr~s 100'~ RlH at 330 ipm t1o tap ~- 87tt0', RQOH to 76U0'. Stwt in wodl. RIH st 1lf0 fpm, tag st ~0', PU t00' ~w. RiN ~ 8218', PU SO' frw tl~n p~ed cs~ 80f9 IErt snd dort~ruasd io ctsp ~dr 100 bM4~'e p~tp ins. ttt~i to t704' tt 300 ipm. dc. PO~Ckki b T~tp' OlC. R1H at 160 fpm tfl P~TTD af 10?T~' s~nt a+i~1 l~40 TAC,i UPS. PC~F! b 7~(10'. SITP 1700 psi. tapac~ +wi! to 4 mmscf~d a! 1~Apsi. R!H at 1!~ FP'AA snd ta~perci at 7TT8'. PU ~usd Ri41 with no prr~iaar-s Oo au 8Td0'. POOH wih 2.33 s+~pag~, marking~ on swspe ~ rt~etai ~ c~sramic grooYes ai ba+r~ad odQ~s ~~e, major UD smcolh. Sarsd prs~-t cn mol str61q ~d sa~age. Very Gti1s sand n~d w~-en dumpinp sartd bust~r. R!H wi~ 2.53 C?D s~wrape at 16~ FPM ~d d~id not ~. no prnbl~ms Eo 8700'. POOH w~h 2.55 ~age to 76~'. SI weU. Wsit 1S mirw~c fa~ flow to stab7ize. Rlti t~ 67~ at 1Q0' {ptn rKttt rw . PQON. AtU 2.7" OD cx-okie cu~or peuge riny. PT tn ~ p~aa+e, R1H at 180 fpm with 2.7Q csookie cbrtt~ ga~,tps rir-p m 7735' slm tp up. PU v~itl~ 9~ mc an~ putl, jars do na r~w boalt. *~ down w+~tt 60 rss~t }us, p~+ w~h 400 ~s av~' pull orme fr'ae. Sad ~ tii~tly at 60 tpm and pu wrdtl~ 2~0-3~)0 kbs o~ ciarmmai PU w+~pht. SAut in wNl in an ~rr+pt t~ 9rt b3' . Ft1H and tap in sams ptseae w~h s~rrne awr puU. ROOH. C,~a~ cwt ~wqe c~rp w~ 2.53 ~r~s lroai prsrious -tnt. F~41Fi 4es m7'QO' clid not tsp tn~tttir~. PflCk~l. Fi~l da~ sJeckW~e p~srtL YY~i rr~s tr~+k b~lc to t~hcrp b sjwnl off tirte irt irar n~w lir-a ttii~op Saturd~ry. R~t wW ~- p~ rate usd pt~,u7s. Sorn~ sand nc~d w~ dumpdng sffatd busi~r. Passed aH ftapfa~rs w[th 2.!bS O~ ~v~qs witt~ tltiape spnUu ~o PLT sUittg. MqRU wirs line wtii MU 2.5' GR aath 1.5" tcQ! string. Hidd P.l~141 ptior to reg~iing up cn w~sli. Di~ssd pro~oadu~. WHPa 1210 p~ip. Pl' kituieator witfi WHP. RIH sai ekw~a~ af 8t1~' KB~D. PU Oaol RtH tiavit cSown t,o b'f98' IC~. Sak dowr- ttrod Oo PU k~si t~ ~sr ac~n and tc~cal s2rirtp mo~rnent. Wcuk wirs vriU~ no n~ov~otnent cxa ~aois. O~nsd uP d~oke Oo hy sr~d int~e &yw ral~ u~ red~ pres~u~. Tool eVing rtu~vsd. tiad tspert~tar POOH rdffi~ ~o{s. OOFI v~th GR bund tnti trbw up tooi had frac sand around toad. Dsdded to RD unit. W[re line a~r leti badsa. GR sat d~wn beiwmen modules #4 and ~!5 at 8198' K8D Pnr~w: ~a~z ~~aa:a3~ ! • ~ ~.A~~~ ~~ R~~~IVED ALA~SFCA OtL AND GtAS CC?!~lSERVATKIN Ct?~1MlSSIC~AI A~ ~ 1~~Q07 WELL GO~IIPLETIQN OR RECOMPLETIOAi REPORT AND LOG _ _ _ ___. __- ,~ wa.~.: aQ ~] ~p~,.+ ^ ,~ Q waap ~k~ ? ~ ,~~,. ,~~.,» ~~ eMU ^ wwr~ wor~~ r~. a c~.n,p.~,~ ~ o~r ~s e~o r..e ~ ~ ~. ~. Pptmk b Ck!! ~i+aib~r: Mwc ilr~e~ t~ Coa~pny a AMa~ ,06l8R # /~ py~ ~ p~. P.Q. ~t l06tN, I~aeNep~. AK i0it~f7~i t tA~oi~ 6b f I.tialrmn d MFM ~~ , t~rb TD IINaf~ t1~ 1NirlMor Mi Mlaab*r ~ OQMr11t G1111it /b. tS s~+~.r: t~ w+~. ~iaer wn., a.~ s~, rni. R~aw. sx ~ e.k.~an p~y: ~a ~ ~r~ T~P~t MaM~Yw i~10s~1t Pli. 9~IK.tM iWt.. Ma at 7lM. RiaMt, C.1t ~yl~ O~rlh ~iD. MINYIn: ~ ~ ~ 101l~' 11D / iQ110.f' TVO tOf~OD ND! tOt~t.~" T110 a. Sl?~.~ ~r y~.~1 2leiy~ 4 11. 0~f ~~1! ~C x• itN/OAD p 9R~7N.4Q T~of~• 4 NA fLtA1D {i. l11-M~r d~p~, il OM~Aora: s~ tt i N0. pntMlL R r~apMlp OM~fan: 7. I~d tMe Rr~ fVl1 0. Tt~idrws d Me~e~r1C NA o:s~~ ~.p ~ ~~ ~~ ~ ~~~ ~wwrw~at qws t~ re~u~ ~rD • 7tR et'rar aM sor.~a r+rr~6 f~or, w ea~Mr; ~ ar+~. rra'n.n.'~: ~I! OI~M9K ?7~D~7TIp, 77?O~~17l0. 7!M'JA'f. tffd~i'1~ 8t0iitTD. ~ MMiiIOR iMaillO~ M~ ~ 1~~dimd DMMa 7~tlr7hl~l. l~N~7+~6t, 7'Na7'~. TltO~T~iKi. TiM1A7'ii~7~ Tf1l~7'~, ~i~M, i1Tlittt, ~4 OM~ af Pfint !'~dudNK 1~100 4 af G~s (~Iw~, ~ri UR lIC.~ RmiM~ ---- 2 ~D ~6~j O~M MM69rt T~111d lR~utli~1 br AIG~: Me~ ~° ~ u~o~ .5 .wrwtse -- a~ 1Zt! .3 ~ lMwa Q~rr ar -tCp: p ~ ei ~iq, . Mt (c~: a ar-- w~ 308~0 •~S w- ( ~NE QATA a. •.. ...a' r . s . . ~~~..r+llv~'i~wawi•~~~~~~~4~~~A~^~~kfl~~ ~N ~~~~~ , 4y - ~ .., ':..~ t ~f: ~ .,. ~ ..i.< :• ~ ~ ~: ~ ~ t'~G1•'~ ~ r. rt C: ~~'~l ~1 !'~1' ~ "` ~~ • :r.' i ~':i~ ~ ' ~: ~~r.- ~ ~~~~~~ d . ,'ti . . . ' . i ..~ iii""~n:~w~ llonlf 4t}~iQa' Rs~lad MO~d CflNI'WUED QIV R$Y~BE ZtDE commission ty' f" ~! ~ • ) 3 R~C~IVED AUG 1 4 2007 Alaska Qil & Gas ~ons. ~o mmiss~o~ ~a. o~oac ~~s - z~. - Fo~-n~ TESrs Anc orage ~,c~m ana un.ay sun,mariaa ~ r~a. wc ~ ee~d..~d a~ah de~ded wpportln0 data es ~aaa~ery~ if no tes~ +~s mnd~ed, ~! "NOr1a'. ~awreau~~e xso r~s PryptR'8s 9076 1„OwOfON{~t17 7$Oi 71eg $~Q~ l.mwrlduptt0 7~B 7~1e 1941 u~t~-18 ~ossA r~c 2'f07 I.Ar~t 4M~M 7TOt 73e9 1493 t~rr ~kl0~s 7~lB 7ae 2Tfl1 tlx~r MN~E'I '~01 ~~t ~gp,Q LervdrMt~l•L~A 7i108 Tl~O 7R37 L+OwIr d~Np-!~ T967 7810 ~ L.eryt 91iU'l ~ 8~8 77~ ~,$ LoMe/ MYu~Bi 81a0 7812 $g~y L4Ywr O~tt7 ~804 T911 ~$QB 6~OMrr~ ~06 7aW gg7$ t~ra.w~ao asu ~ aata ~ ~~~ a~x ~ ua a ~: O~adian~! Swv.r, Qpsr~iwa sua~n+.nr, walboro oi~pr.m . t lMe~by o~l!lNt~tt 1M fo»ppiap is hw and aortsat fo Use bat of m~r bioa~d~s. Corwat~ Rdtd~e4 t~luf~~~ R auu lon ~.~ T~It ~r. ~.cis~plslforN ~ntlfa~r ~po+1~ ~d~"""~'~- Plwri~ W7 /71 Dake ~Q~t I~m 226:: NN~tod of Op~On: Fia~p, Cias I.,Tt, Rod Purep~ F'-l~drautle Ra-p~ Submsr~, w~ bd 'kfl~a~icpr,,, ~' '~~,. CtY'+et (~)~ .. ~ , ~ .. . • . e~ . 4...0.•~_ , ~m~: ~~~,~,.~~~. ~ ~AR 15 200~': ~«„~: ~~~~~,. ~~,..~•~•. ... ,. . - ~,i:~ '..;; ~. _ . . .. , ~.~.. v,. :'• `""' • - , Fcrm tQi07 Revised 4f~D09 • RT-GL: 21.00' RT-THF: 20.33' 1309A' FNL, 1479.5' FWIL, Sec. 34, T7N, R10W, S.M. Tns cxn = 4-3/4' Otis Ezcaos Svstem Details - BHP monifsring lint volum~ tardc ~ocar~d rrom 7saa~ - noa~ - C~ramic flapper valves below eadi module as follows: 1 - NA 2 - 6521.8' 3 - 8426.3' 4 - 8257.8' 5 - 8198.3' 6 - 8157.3' 7 - 7997.8' s - ns~.a~ s - n6o.r BC-13 .~ ,. :, •a i~ :• ~ t~ ,~ -%s 1~ ~ M.~ ~ '4 yi ~~ • M MwRwTMOM riv Pi : 20", 133 ppf, K-55 to 165' ~ Surface C~sirw: 13-3/8". 68 ppf, K-55, BTC ~ 2296' Cmt w/ 568 sks of class G a ai N ~ 0 ~ .~nt Casirg: ~5,8"~ 4~ ppf. ~-80~ BTC ~ M88' j~O C m Cmt w/ 978 sks of class G ~ G7 L~ ^ ? N D n ~~ ~ ~ m ~ ~ ~ ~ rw A N ~ Prod. Tubina: 3-1/2'. fl.3 ppf. L. n o ~ T ~~~ 80, EUE Srd with 6.25' OD prot~cton to 10461' ~ Cmt w/ 1475 sks of clasa G S' ~ - 9 Excape modules placed - Groen control line fires botLom 1 modulea - Red control line fires top 8 modules - Ceramic flapper valves babw ~ach Module 9 - 7730'-7740' Module 8 - 7769'-7779' Modub 7 - 7968.5'-7976.5' Modua 8 - 8125'-8135' Module 5 - 8184'-8174' Module 4 - 8225.5'-8235.5' nnod~ie s - asar-saor Module 2 - 849'I'-8501' Module 1 - 8584'-8594' TD -10500 ' PBTD -10429 ' ~ STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMM ON GAS WELL OPEN FLOW POTENTIAL TEST REPt~,$'CEIVECa 1a. Test: ~ Initial Annual Special ib. Type Test: Stabiiized ~ Non Sta~iljzed. ~ ~ul6point ~~~~ fm P al ell Test Data t ~] Constant Time ^ Isochronal a Other 2. Opera#or Name: 5. Date Completed: 91. Pe ityy~ ~~i~~~~ ~Q~(p~SS~~ ~ ~' Marathon Oil Company 3/26/2004 203 138 8 8 3. Address: 6. Date TD Reached: 12. API Number: P~ BOX 1949 Kenai, Alaska 99611-9949 ~2~s/2oo3 ~0-133-24525-00-00 4a. Location af Well {Gavemmentai Section): 7. KB Elevation (ft): 13. Well Name and Number. Surface: 1302' FNL, 1474' FWL, Sec.34, T7N, ft10W, S.M. 179' Beaver Creek No. 13 Top of Productive Horizon: 8. Plug Back Depth{MD+TVD): 14. Field/Poo1(s}: 2407.25' FNL, 2685.19' FWL, Sec.34, T7N, R'lOW, S_M. 10429' MD ! 10130.5' ND Beaver Creek Field / Beluga and To#al Depth: 9. Total ~epth {MD +'rVp): Tyonek Pools 2448.11' FNL, 2716.48' FNVL, Sec.34, T7N, R10W, S.M_ 10500' MD /14181.5' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 317286.35 y- 2433$92.31 Zone- 4 N/A A-02$083 TPi: x- 318480.00 y- 2432768.90 Zone- 4 16. Type of Completion {Desa-ibe}: Total Depth: x- 318511.22 y- 2432727,56 Zone- 4 Excape Completion, Multi Zone-Frac Stimulated 17. Casing Size Weight per foof, lb. l.D, in inches Set at ft. 19. Perforations: From To 3-112" 9.3 2.992" 10.461' ~rID 7730'-7740'_7770'-7780'_7968'-7678'_8128'-8138_8185'- 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 8175'_8228'-8238'_8396'-8406'_8490'-8500'_8582'-$592' (Atl N/A N!A WA N/A 10' Zones in MD) 20. Facker set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): tV/A WA NIA 0.564 24a. Froducing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: ai 2284psi Estd SIWHP 24d. Barometric Pressure (Pa): ~ Tubing ~Q Casing Est'd 161 p~ ~pg EsYd 2861 psia @ Datum 10170.5' PBTVD 14.73 psia 25. length of Flow Channel {~}: Verticai Depth (H): Gg: % CO2: °lo N2: °to N2S: Prover. Meter Run: Taps: 773~' 7412' 0.564 0 0 0 Welltester run 26. FLdW DATA TUBING DATA CASING DATA No. Prover Choke Line )( Orifice Size (in.) Size {in) p~~sure Psig Diff. Hw Temp, F° Pressure psig Temp. ~° Pressure psig Temp. F° --- __ _ _ _ _ Duration of Flow Hr. '~ ~ 3.828 X '1.504 760 33 134 2210 60 - - 3.75 2~ 3.826 X 9.500 790 93 86 2050 64 _ - 5.00 3• 3.826 X 1.750 810 68 82 1910 66 - - 4.00 4• 3.8~6 X 9.750 840 84 82 1810 66 - - 1.00 ~• X No. Basic Cosffi~ient (24Hour) Fb or Fp h~ Pressure Pm Flow Temp. Factor Ft Gravity Factor F9 Super Comp. Factor F v P Rate of Flow Q~ Mcfd 1. 34.3 66.49$12027 774.73 9.00 1.332 1.0325 2283 2. 46.5 89.43153806 804.73 9.~0 1.332 1.0483 4162 3. 67.2 74.67261881 $24.73 1.00 1.332 1.0512 5016 4. 68.5 82.99397568 854.73 1.00 1.332 9.d541 5687 5. No. Pr Temperature T Tr z for Separator Gas Gg for Flowing Fluid G 1. 1.13 594 1.73 0.938 0.564 N/A 2- 1_17 546 1.b9 0.910 3. 1.20 542 9.58 0.905 Cri6calPressure 673.1 4• 1.25 542 '1.58 0.900 Critical Temperature 343.2 5. ~S _ r . ~ k~'~. ~~+Jr ~. ~ ~OD~ s~~~,y 7 ~/` / Pc 22s5 pc2 526541 8.6 ~ P~ No. Pt Pt~ Pc2-Pt~ ~ Pv~ Pc2-Pv~ P~ Ps2 Pf -Ps2 1. 2225 4949068 316351 2. 2t~5 ` ~262780 1(102639 3. 9925 ' 37t34~78 'i5fi1141 4. ~825 3 i293~8 193~71 5. 25. AOF (Mcfd} 9,369 Remarks: E~ccape well. SIVItHi' es~cnated at 2280 psig. I hereby c~rtify that~the foregoing is true and correct to the best of my knowledge. Signed ~ 0.50~ Dennis M Donovan Jr. Title Production Engineer Date ~/~oi2oo~ DEFINITIONS OF SYMBOLS RECEIV~D AUG 14 2047 AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hol pressure opposi#e the producing face were reduced to zero psia Alaska Oi) &~as Cons. C0~'NrtiS5i0ft Fb Basic orifice factor Mcfd/ hwPm Anchorage Fp Basic critica! flow prover or positive chake factor McFd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factar- ~ dimensionless Ft Flawing temperature factor, dimensionless G Spec~c gravity of flowing fluid (air-1.000), dimensionless Gg Specific gravity of separator gas (air-1.00), dimensionless GOR Gas-oil ratio, cu. ft. af gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Me#er differential pressure, inches of water H Vertical depth corresponding to L, feet {TVD} L Ler~gth of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensiontess Ps Flowing pressure at vertical dep#h H, psia Pt Flawing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flaw, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute #emperature, degrees Rankin Z Compressibility factor, dimensioNess Recommended procedures for tests and calculations may be found in the Manua! of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Okiahoma City, Oklahoma. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N GAS WELL OPEN FLOW POTENTIAL TEST RE~~~IVED 1a. Test: ~ Initial Annual Special 1b. Type Test: Stabilized ~ Nory~Stal9ili~ed~ 20 Multipoint H U l~ 1 ~ Constant Time ~ Isochronal ^~ Other Tni ial Well Test Data 2. Operator Name: 5. Date Completed: ~~gRgrQj~t$~ ~~PQ~er~~~p~pISS10(1 Marathon Oil Company 1/26/2004 203-13#~CI10~8 8 3. Address: 6. Date TD Reached: 12. API Number: PO BOX 1949 Kenai, Alaska 99611-1949 12/6/2003 50-133-20525-00-00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1302' FNL, 1474' FWL, Sec.34, T7N, R10W, S.M. 179' Beaver Creek No. 13 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 2407.25' FNL, 2685.19' FWL, Sec.34, T7N, R10W, S.M. 10429' MD / 10110.5' TVD Beaver Creek Field / Beluga and Total Depth: 9. Total Depth (MD +~/D): Tyonek Pools 2448.11' FNL, 2716.48' FWL, Sec.34, T7N, R10W, S.M. 10500' MD / 10181.5' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 317286.35 y- 2433892.31 Zone- 4 N/A A-028083 TPI: x- 318480.00 y- 2432768.90 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 318511.22 y- 2432727.56 Zone- 4 Excape Completion, Multi Zone-Frac Stimulated 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 3-1/2" 9.3 2.992" 10,461' MD 7730'-7740' 7770'-7780' 7968'-7678' 8128'-8138' 8165'- _ _ _ _ ' ' ' ' ' ' ' ' ' 18. Tubing Size Weight per foot, ib. I.D. in inches Set at ft. -8592 (All 8175 _8228 -8238 _8396 -8406 _8490 -8500 _8582 10' Zones in MD) N/A N/A N/A N/A 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fiuid (G): N/A N/A N/A 0.564 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: at 228opsi Estd SiwHP 24d. Barometric Pressure (Pa): ~ Tubing ~ Casing EsYd 161 F° @PBTVD Est'd 2861 psia @ Datum 10110.5' PBTVD 14.73 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N2: % HZS: Prover: Meter Run: Taps: 7730' 7412' 0.564 0 0 0 Welitester run 26. FLOW DATA TUBING DATA CASING DATA N Prover Choke Li X O if pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow o. ne r ice Psig Hw F° psig F° psig F° Hr. Size (in.) Size (in.) ~• 3.826 X 1.500 760 33 134 2210 60 - - 3.75 2• 3.826 X 1.500 790 93 86 2050 64 - - 5.00 3. 3.826 X 1.750 810 68 82 1910 66 - - 4.00 4• 3.826 X 1.750 840 84 82 1810 66 - - 1.00 5. X N Basic Coefficient 24 H ~ Pressure Flow Temp. Gravity Factor Super Comp. F Rate of Flow o. - our) ( h Pm Factor F g actor (~~ Mcfd Fb or Fp Ft Fpv 1. 34.3 66.49812027 774.73 1.00 1.332 1.0325 2283 2. 46.5 89.43153806 804.73 1.00 1.332 1.0483 4162 3. 67.2 74.67261881 824.73 1.00 1.332 1.0512 5016 4. 68.5 82.99397568 854.73 1.00 1.332 1.0541 5687 5. for Separator for Flowing Temperature No. Pr Tr z Gas Fluid T Gg G 1. 1.13 594 1.73 0.938 0.564 N/A 2. 1.17 546 1.59 0.910 3. 1.20 542 1.58 0.905 Critical Pressure 673.1 4. 1.25 542 1.58 0.900 Critical Temperature 343.2 5. Form 10-421 Revised 1/2004 CONTINUED ON REVERSE SIDE Submit in Duplicate DEFINITIONS OF SYMBOLS ~~~ElV~D AUG ~. ~ 20~7 AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if fhe boftom hofe pressure opposite the producing face were reduced to zero psia Alaska Qil & 6as Cons. Commission~ Fb Basic orifice factor Mcfd/ h~ ARChofeqA Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= ~ dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibilityfactor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 • ,~ •, ,~~ ~, r ~N MICROFILMED 03/01 /2008 D4 NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslR~icrofilm Marker.doc . ~V~VŒ (ID~ ~~~~æ~ . AI.ASIiA OIL AND GAS CONSBRVATlON COJDIISSION CERTIFIED MAIL RETURN RECEIPT REQUESTED SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 sCANNED JUL 3 1 2007 Re: Kenai Gas Field, Beluga Gas Pool, Beaver Creek 13 PTD: 203-138 Dear Mr. Donovan: A recent review of the me for the subject well has revealed that Marathon Oil Company has not submitted operations information regarding the work performed to complete this well. According to the operations data received, the rig was released December 15, 2003 and a cement bond log was run January 16, 2004. Also, there is no testing information regarding the determined potential of this gas well as required by 20 MC 25.225. The deficient operations reports and potential test information and an explanation of the reason for failing to provide the required information must be submitted not later than 15 days after the receipt of this letter. The Commission reserves the right to pursue enforcement actions regarding these matters. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person may not appeal C mmission decision to Superior Court unless rehearing has been requ Sin DATED thiSzk. day of July 2007 Enc!. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Alaska Department of Law ~~ , UtVtTED STATES. PO$TAL SERVICE ~ ~ First-Class Mail Postage & Fees Paid USPS r s Permit No. G-10 • Sender: Please print: your name, address, and ZIP+4`~ this bo > ~' ~. (G-- G':+ ate of ~as~a ®; cs ,. ' Alas9ca Oi! a>ad ~a;>rvat~~ ~o ' ~to>a~, ~ ~, 333"dV+rst 7th Ave., ~~ i~ `~eo ' ~" Bch®rage, A,laiska~ 9301 ~ ~`' ~. - N . - ~., Cs ~~. '4~~~k ~}1l li lit k}}:351'kl~liklF'i iS 11 ~11 rk I3311~11 i~3i5t31~ Pto: ao3-13g ~~ ~~ _- ~. m ~ '~~ ~~ r-9 ~rw ~ ,, ~ ~ - r" ~ h ~i KE~AI ~`' `14611= ~~ ' ~~~ t _:~ ~. X ~ Postag® $ `~. X11 .~iok a ce~ined Fee R t 42.65 ~ g ~`'~~~ Postm ~ e um Receipt Fee (Endorsement Requiretl) X2.15 `~ ar~ ~ " .; E~~'~ «, Ci Residcted Da!rvery Fee ~~~' u~ ~ ~ ..J] ra (EndorsementRequlred) ~~(~ O ~ Total Postage & Fees ~ 5 21 A` ~ 7 ul . 6 , q ,O ['~ Sent o ~ , _ -- -Vy-- ~-~ ~ " a Street, Apt No.; - ---~'"""'""" -- -•~ r y~- -..__ --=`---'- °--- or PO Box No. C/ty, State. ZlP+4 '---°--°-----------°------ ---°--------------- ~., ~. ^ Complete. items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ~ ^ Print your name and address on the reverse so that we can return the card to you. ^ Attach this. card to the back of the mailpiece, or on the front if space permits.. 1. Articl Addressed to: /lar~.~-lrr~1 ~l ~ C0~ nniUle ^ Agent ~ ^ Addressee ,~ eceived by (Pr'n d Name C. Dat of Delivery D. Is delivery address different from item t ^ es If YES, enterdelivery address below: ^ No U (/ ~ ~ /~ / / 3. Se e Type Certified Mail ^ press Mail /~ ^ Registered Return Receipt for Merchandise ~~n ~ /) "' ~ ~ 9 ~~~ - ~ 9~ 9 ^ Insured Mait , ^ C:O.D. 4. Restricted Delivery? (Extra Fee) ^ Yes 2. Article Number - ' - : °~-- _ (Transfer from serv/ce tabeij ~ 0 ~ 5 11, 6 ~ '0 ~ 0 ~,, +. 5 7 5 5: 9 513 6°: `PS Form 3811, February. 2004 DomesticYReturn Receipt ` ~--~ _^ .102595-02-M-1540 I'. ~ I"" "'" M MARATHON ~ ) Marathon Oil Company ) Alaska Asset Team Northern Business Unit P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 February 8,2006 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Federal Express RE: Marathon Oil Company Beaver Creek #13 (BCD 13) API 50-133-20525-00 CONFIDENTIAL } 3 c( J~ Dear Howard: The following CONFIDENTIAL well data are being forwarded to AOGCC. BCD 13 One CD (contents listed on attached) containing the following digital data: Directional Survey Data ........................................................................................ digital EPOCH Mud Log Data (as listed on attached) ......................................................digital Digital Well Logs (as listed on attached) ...............................................................digital Please confirm your receipt of this data by signing one copy of this letter and returning to my attention at the letterhead address. Thank you, MARATHON OIL COMPANY 11~ Kaynell Zeman Geological Technician Received by: cfLJ I ú fi& Ä1N (p Date: Attachments ) f1~~f 3 'j F/ It ) , Marathon Oil Company Beaver Creek #13 API 50-133-20525-00 Beaver Creek Unit Kenai Peninsula, Alaska C()NFIDENTIAL CD CONTENTS Directional Survey Name ,;I" y_.' -~;.. w ' ~ BCU _13 _Dir _Sur, dat Digital Well Data ,~,,,. "" N'" "W_o' _...~ NO. Name ..... L8 13mainsplicedepth .Ias t@JBCU13_RFT_Data.xls [g PLOTSQUADbcu 13. dpk ErOCH Mu~ Log .DatalDML DATA Name'" ~ BEAVERCREEK#13.DBF ~ BEAVERCREEK#13,hdr ~ BEAVERCREEK#13.MDX ~ BEAVERCREEK#13_SCL.DBF .~ BEAVERCREEK#13_SCL.MDX ~ BEAVERCREEK#13_TVD.DBF ~ BEAVERCREEK#133VD.MDX ~ BEAVERCREEK#13R.DBF ~ BEAVERCREEK#13R,MDX EPOCH Mud Log DatalLAS FILE _UH'...·___,,_...,"..__..._._. ._.... Moo __._....."......__..._R__.._._.._..... ...... m" ... . . ".., '~'H'" .,.,."_ Name .... liJ BEA VERCREEK#13,las EPOCH Mud Log DataILITH AND REMARKS Name ....j !'] BeaverCreek13 _Lith, txt BeaverCreek13 _Remarks. txt EPOCH Mud Log DataILOG PDF FILES Name·' ~ BEA VERCREEK# 13 _DRILDYN, pdf ~ BEAVERCREEK#13~MUDLOG_MD.pdf ~ BEAVERCREEK#13_MUDLOG_TVD,pdf ) Marathon Oil Company Beaver Creek #13 API 50-133-20525-00 Beaver Creek Unit Kenai Peninsula, Alaska CONFIDENTIAl.. E~OCH Mud ~og Da~alMORNING REPORTS Name Á I .é:J 20031108, htm ,~20031109,htm @j 20031110,htm [} 20031111 ,htm ,~20031112,htm ,~20031114,htm ,:t)20031115,htm ;Íj20031116.htm ,tj 20031117 ,htm ;~ 20031118. htm ;(}20031119.htm ;!fl20031120. htm ,~20031121.htm ~(] 20031122. htm ~20031123.htm ,~20031124 ,htm ~20031125.htm ;iÐ 20031126. htm .:() 20031127 . htm ;~20031128.htm ;;1) 20031129. htm ,i) 20031130. htm .lJ 20031201 . htm ,t] 20031202. htm .~ 20031203 .htm .{}20031204.htm ,~20031205. htm ,!Ú 20031206. htm ~ ~ ~t~ DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031380 Well Name/No. BEAVER CK UNIT 13 Operator MARATHON OIL CO -----~- MD 10500~ TVD 10182 ~ Completion Date 1/26/2004 / Completion Status 1-GAS Current Status 1-GAS UIC N ----------- REQUIRED INFORMATION Mud Log No - -----~------ -- ---------- Samples No DATA INFORMATION Types Electric or Other Logs Run: SP/GR-EL-Density/Neutron-Sonic-Single Arm Caliper-MFT-VSP Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name -----.-- ----- ------- ~------- Well Cores/Samples Information: Name ----- Cuttings ------ -----------------~ ADDITIONAL INFORMATION Well Cored? Y§ Chips Received? y'iì'f--. Analysis ~ Received? ------- ------- 5fc:~ cr!tJOú ~3 API No. 50-133-20525-00-00 Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH C~-~m;;~~ --- Ù(" ~u \AJ ì ,'__ J), i) \' u~- (Ñ /"'- (\.h G t LV rk \'" ''-4ì r V\ k ,<;,~ ~'^"; ~ ~ ~ .~__=_~t -''''. í~ ¿_ _ k; ZQ Î "^'''-- \¿ W\<>."","", '" . : l ,c." - Compliance Reviewed By: ~ )ù-'\~ 4 Interval Start Stop 2303 10500 Sample Set Number Comments Sent Received 1126 ..---~ - Daily History Received? ~ Formation Tops ~ Received Comments ~ -- Sf! ~ ~ -IQj) ¡ VI < : ~ì liD tIN YV'ó ",- - ~ G '^:C - ) ; <'l'J í. n" 4 (ðeft/IV -/1 (::/ ~ .i ~ ,);7 .:l;S'\ fs . rv ~~I Date: \ ~ r:l, Á-'- ~ +1 /HJL ý Marathon Oil Company February 2, 2004 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Alaska .....liness Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Delivered by Courier RE: Marathon Oil Company Beaver Creek Unit No. 13 (BCD 13) Well Samples CONFIDENTIAL The following CONFIDENTIAL well samples are being forwarded to AOGCC. A listing is attached. Marathon Oil Company BC No. 13 Beaver Creek Unit Beaver Creek Gas Field, Cook Inlet, Alaska Sec. 34, T-7-N, R-10-W, Seward Meridian API #: 50133205250000 2 sets of 13 Boxes - Dry Samples When the samples have arrived, please confirm your receipt by signing one copy of this letter and returning to my attention at the letterhead address. Thank you, Kaynell Zeman Technical Assistant Attachments 11(" ,.( tlL I Received by: ~\) is..; 't ' l ~ -...¡:; Date: ) h,~ ,.l~~ "-it l kJl~. I~~ fý'. lit ~~ f"'ïi0tt 11 Á~ Pf{) "l)3···-j)t F/'(~ AOGCC February 2, 2004 Page 2 ') Marathon Oil Company BC No. 13 Beaver Creek Unit Beaver Creek Gas Field, Cook Inlet, Alaska Sec. 34, T-7-N, R-I0-W, Seward Meridian API #: 50133205250000 13 Boxes - Dry Samples BCU #13 Dry Samples Depth From Depth To (Feet) (Feet) 2,303 3,360 3,360 4,380 4,380 5,240 5,240 6,180 6,180 6,800 6,800 7,350 7,350 7,860 7,860 8,380 8,380 8,840 8,840 9,350 9,350 9,850 9,850 10,350 10,350 10,500 } Box No. IB&C 2B&C 3B&C 4B&C 5B&C 6B&C 7B&C 8B&C 9B&C 10 B&C 11 B&C 12 B&C 13 B&C ) } Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 , , M Marathon MARATHON "Oil Company ~ March 9, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Completion Report 10-407 for permit 203-138 Field: Beaver Creek / Beluga & Tyonek Well: BC-13 Dear Mr. Aubert, Enclosed please find the Well Completion or Recompletion Report with associated attachments. Beaver Creek No. 13 has been completed cased hole with a 3.5" monbore production string to surface. I apologize for the delay in getting out this completion notice. Should you require further information, I can be reached at 907-529-0524/713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, ~~ James Thompson Sr. Completions Engineer Enclosures: Completion Report Directional Survey Operations Summary Wellbore Diagram MAR I 5 200 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG PluggedDAbandoned D Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory [K] No. of Completions Other Service Stratigraphic Test D 5. Date Comp., Susp., ."tJipermitto Drill Number: or Aband: 1/26/20Çj\. 203-138 1a. Well Status: OilD Gas[] GINJ D WINJD WDSPLD 2. Operator: Name: Marathon Oil Company 3 Address: P.O. Box 196168, Anchorage, AK 99519-6168 4a. Location of Well (Governmental Section): Surface: 1302 FNL, 1474' FWL, Sec. 34, T7N, R10W, S.M. Top of Productive 2407.25' FNL, 2685.19' FWL, Sec. 34, T7N, R10W, S.M. Horizon: Total Depth: 2448.11' FNL, 2716.48' FWL, Sec. 34, T7N, R10W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: x- TPI x- Total Depth x- 317286.35 y- 2433892.31 Zone- 4 2432768.90 Zone- 4 2432727.56 Zone- 4 NoD 318480.00 y- 318511.22 y- 18. Directional Survey: ves[] 21. Logs Run: SP/GR-IEL-Density/Neutron-Sonic-Single Arm Caliper-MFT-VSP 6. Date Spudded: lP API Number: 11/9/200j , 50- 133-20525-00-00 7. Date TO Reached: 12/6/2003 8. KB Elevation (ft.): 179' 9. Plug Back Depth (MD + TVD): 10429' MD /10110.5' TVD 10. Total Depth (MD+TVD): 10500' MD/ 10181.5' TVD 11. Depth where SSSV Set: NA feet MD 19. Water Depth, if Offshore: NA feet MSL 14. Well Name and Number Beaver Creek No. 13 15. Field/Pool(s): Beluga & Tyonek 16. Property Designation: A-028083 17. Land Use Permit: NA 20. Thickness of Permafrost: NA 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SEITING DEPTH MD SEITING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20" 129.0 K-55 0 165 0 165 Driven NA Na 13-318" 68.0 K-55 0 2296 0 2296 16" 568 sx NA 9-5/8" 47.0 L-80 ° 7288 0 6973 12-1/4" 1144 sx NA 3-1/2" 9.3 L-80 ° 10461 0 10143 8-1/2" 1475 sx 80,000 23. Perforations Open to Production (MD + TVD of Top and Bottom Interval, Size, and Number; if none, state "none"): Measured Depths: 773o-7740, 7770-7780, 7968-7678, 8128-8138, 8165-8175, 8228-8238, 8396-8406, 8490-8500, 8582-8592 True Vertical Depths: 7412-7422,7452-7462,7650-7660,7810-7820, 7847-7857,7910-7920,8078-8088,8172-8182,8264-8274 \ .', ~"-,'~' ~ ; i~5J~~ ~ .. ;,i~:'~~ -,~--------_._,.......,¡ None r- ~ ~--:r r ('~:' '"",,. ~"I:J.;.'. ..,.~I~~,'t:":, ~'~~'1; l"\":""~ r\\;, \ ,.:,." 1'- 1..._" Form 1 0-407 Revised 4/2003 24. SIZE 3- 1/2" TUBING RECORD DEPTH SET (MD) 10461 PACKER SET (MD) NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See No. 23 0 to 46,000 Ibx 16/30 Ottawa Sand Flowing Water-Bbl: NA Water-Bbl: 24 ~~t ~ :,!' '."', CONTINUED ON REVERSE SIDE Choke Size: GaS-Oil Ratio: 26164th NA oil Gravity - API (corr): NA 1\¡AR I 6 .-, ~. .', 26. PRODUCTION TEST Date of First Production: 1/27/2004 Method of Operation (Flowing, Gas Lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas- MCF: 1/27/2004 11 Test Period -~ NA NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Press: ### 0 24-Hour RatE -~ NA ### 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if nessary).,," Submit core chips; if r.lone~..st~U;:"~~~\ In _. . , .,,1,':" ifr \..7 ) ) NAME GEOLOGIC MARKERS MD 29. FORMATION TESTS 28. TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". Lower Beluga-16 Lower Beluga-17 Lower Beluga-18 Lower Beluga-19 Lower Beluga-20A Lower Beluga-20B LOwer Beluga-21 Lower Beluga-23A Lower Beluga-23B Lower Beluga-25 Lower Beluga-26 Lower Beluga-27 Lower Beluga-28 Lower Beluga-30 Tyonek 7429 7506 7563 7612 7701 7766 7801 7908 7967 8078 8160 8230 8258 8526 10130 7113 7189 7246 7294 7383 7448 7483 7590 7649 7760 7842 7911 7940 8208 9812 Pressures 3075 2704 1941 2107 1493 2781 2504 1837 2383 3388 3623 2206 3373 4212 2050 30. List of Attachments: Directional Survey, Operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name James R. Thomspon S~nature ~ ¡Z~ Title Sr. Completions Engineer Phone 907-529-0524/713-296-2730 Date 3/9/2004 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection~r~j?ctiO~;~~U!-I~,,~~, ;, Other (explain). ~ ":. ",. ,. ''0 ..~ r ,~-:' ':/ Item 27: If no cores taken, indicate "none.". MAR 1 5 200/ Item 28: list all test information. If none, state "None". . 1'4 '., , . Form 10-407 Revised 4/2003 ) ) MARATHON Oil Company Pad #3 BC-13 slot #13 Beaver Creek Unit Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10500> svy6981 Date printed Date created Last revised 15-Dec-2003 10-Nov-2003 15-Dec-2003 Field is centred on n60 38 50.050,w150 59 49.92 Structure is centred on n60 38 50.050,w150 59 49.92 Slot location is n60 39 29.233,w151 1 6.362 Slot Grid coordinates are N 2433892.314, E 317286.347 Slot local coordinates are 3979.51 N 3809.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 ft above mean sea level). Bottom hole distance is 1690.36 on azimuth 132.69 degrees from wellhead. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in fEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 2433825.50 2433813.73 2433801.18 2433787.98 2433773.90 2433867.57 2433861.33 2433854.00 2433845.74 2433836.24 2433885.13 2433883.22 2433880.39 2433876.89 2433872.71 2433893.87 2433892.66 2433891.28 2433888.27 2433886.60 2433896.77 2433896.72 2433896.44 2433895.93 2433895.08 2433896.27 2433896.10 2433896.20 2433896.32 2433896.51 2433895.75 2433895.93 2433895.80 2433896.02 2433896.36 2433894.21 2433894.52 2433894.84 2433895.05 2433895.30 2433893.14 2433893.32 2433893.64 2433893.82 2433893.98 2433892.31 2433892.49 2433892.75 2433893.12 2433893.21 317341.57 317353.95 317367.64 317382.20 317397.78 317295.56 317302.65 317310.80 317320.13 317330.43 317277.90 317279.09 317281. 32 317284.92 317289.60 317275.06 317274.85 317275.26 317276.55 317277.15 317277.58 317276.88 317275.96 317275.39 317275.30 317281.14 317280.45 317279.60 317278.89 317278.25 317285.01 317284.03 317283.27 317282.63 317282.13 317286.48 317286.49 317286.33 317285.91 317285.34 317286.73 317286.64 317286.76 317286.59 317286.42 317286.35 317286.77 317286.92 317286.82 317286.80 G RID COO R D 8 Easting Northing 86.04 103.12 121.69 141. 34 162.34 23.69 33.13 44.09 56.55 70.56 -1. 20 0.97 4.53 9.56 15.83 -9.27 -8.59 -7.34 -4.34 -2.76 -9.43 -9.90 -10.38 -10.44 -9.93 -6.50 -6.89 -7.57 -8.17 -8.77 -3.34 -4.17 -4.63 -5.25 -5.84 -1.20 -1.41 -1.75 -2.20 -2.78 -0.29 -0.48 -0.61 -0.86 -1. 09 0.00 0.19 0.12 -0.21 -0.28 2.15 1. 99 2.60 1. 73 2.54 56.24E 68.79E 82.67E 97.43E 113.23E 65.988 77.558 89.898 102.878 116.728 24.608 30.74S 37.94S 46.068 55.40S 7.328 9.208 12.008 15.45S 19.558 1.38N 0.17N 1.20S 4.198 5.858 4.32N 4.26N 3.97N 3.45N 2.60N 3.88N 3.70N 3.78N 3.89N 4.07N 3.42N 3.58N 3.43N 3.64N 3.98N 1.90N 2.20N 2.53N 2.73N 2.98N 0.83N LOIN 1. 34N 1. SIN 1.66N O.OON 0.18N 0.44N 0.82N 0.90N R E C TAN G U L A R Dogleg Vert COO R DIN ATE 8 Deg/100ft Sect SURVEY LISTING Page 1 Your ref : MWD <0-10500> Last revised : 15-Dec-2003 ) 2.05 2.91 2.12 2.44 2.48 9.59E 16.77E 25.03E 34.48E 44.93E 0.75 1. 84 2.40 2.04 1.96 8.34W 7.12W 4.85W 1.19W 3.55E o .84 0.87 1. 30 0.13 0.14 11. 31W 11 .50W 11.07W 9.74W 9.11W 0.67 0.62 0.22 1.15 0.60 8.83W 9.53W 10.45W 11. 01W 11 . 09W 0.31 0.07 0.85 1. 01 0.95 5.27W 5.96W 6.80W 7.52W 8.16W 0.91 0.69 0.41 1. 01 0.77 1.39W 2.38W 3.13W 3.78W 4.28W 0.19 0.07 0.65 0.89 0.99 0.11E O.llE 0.06W 0.48W 1. 05W 0.68 0.82 0.17 1. 04 0.97 0.38E 0.28E 0.39E 0.22E 0.04E 0.00 0.18 0.74 0.38 0.84 O.OOE 0.42E 0.56E 0.47E 0.44E 3105.10 3165.74 3225.93 3284.73 3343.07 2800.63 2862.91 2923.93 2984.67 3045.06 2487.78 2549.74 2612.64 2675.43 2737.12 2117.90 2179.89 2244.88 2362.83 2426.81 1801.94 1862.93 1927.93 1991. 92 2054.92 1493.96 1556.96 1618.95 1679.95 1741. 94 1053.98 1180.98 1241. 97 1306.97 1371.97 707.99 803.99 866.99 928.99 990.99 407.00 467.00 527.00 586.99 647.99 0.00 169.40 225.10 287.00 347.00 True Vert Depth 133.24 132.16 131.17 131.47 131.02 129.53 131. 35 130.82 130.54 132.93 143.90 148.91 135.74 131.46 130.36 197.27 177.68 153.68 158.38 160.05 278.57 256.07 248.75 194.66 179.59 254.58 256.56 288.26 258.85 298.19 348.41 261.19 256.23 312.52 283.00 1. 39 357.35 326.60 261.10 312.89 267.92 12.70 26.59 278.35 27.79 0.00 67.04 0.27 326.75 131.61 Azimuth Degrees 15.12 16.34 17.95 19.02 20.59 3113.00 3176.00 3239.00 3301.00 3363.00 7.72 9.53 10.84 12.35 13.79 2802.00 2865.00 2927.00 2989.00 3051.00 1. 51 2.64 3.96 5.20 6.41 2488.00 2550.00 2613.00 2676.00 2738.00 1. 34 0.96 1. 63 1. 55 1. 63 2118.00 2180.00 2245.00 2363.00 2427.00 0.53 0.81 0.90 0.62 0.94 1802.00 1863.00 1928.00 1992.00 2055.00 0.63 0.67 0.96 0.44 0.86 1494.00 1557.00 1619.00 1680.00 1742.00 0.28 0.84 0.60 0.76 0.33 1054.00 1181.00 1242.00 1307.00 1372.00 0.22 0.15 0.53 0.49 0.78 708.00 804.00 867.00 929.00 991.00 0.26 0.36 0.30 0.46 0.25 407.00 467.00 527.00 587.00 648.00 0.00 0.31 0.42 0.33 0.18 0.00 169.40 225.10 287.00 347.00 Measured Inclin Depth Degrees MARATHON Oil Company Pad #3, BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska ) ) MARATHON Oil Company Pad #3, BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska Measured Inclin Depth Degrees 3425.00 3488.00 3551.00 3614.00 3678.00 3742.00 3805.00 3867.00 3929.00 3991.00 4055.00 4116.00 4178.00 4240.00 4303.00 4364.00 4426.00 4490.00 4554.00 4617.00 4680.00 4742.00 4804.00 4866.00 4930.00 4993.00 5056.00 5118.00 5180.00 5242.00 5305.00 5367.00 5430.00 5492.00 5555.00 5618.00 5680.00 5742.00 5804.00 5867.00 5930.00 5992.00 6054.00 6118.00 6180.00 6242.00 6304.00 6368.00 6430.00 6492.00 22.80 23.66 24.72 25.62 26.43 26.98 27.07 27.02 26.92 26.71 26.70 27.30 28.15 28.04 27.90 28.01 27.92 27.90 27.67 27.68 27.78 26.81 26.44 26.30 26.22 26.13 26.07 25.87 25.73 25.69 24.91 24.36 24.07 23.39 23.11 22.94 22.90 22.76 22.15 21.09 20.54 19.93 18.69 17.55 17.06 16.61 15.86 15.24 15.09 14.93 Azimuth True Vert Degrees Depth 130.22 130.71 129.17 130.17 130.28 129.98 130.50 130.24 130.24 130.02 129.93 131.90 133.12 132.48 132.46 132.46 132.31 132.47 132.65 132.09 132.70 133.15 133.53 133.01 132.68 132.73 132.79 132.97 133.28 133.41 133.96 134.50 134.20 133.44 132.97 133.03 132.90 132.70 133.02 132.85 133.22 132.20 132.28 132.66 132.42 132.12 131.88 130.76 130.86 130.52 3400.67 3458.56 3516.03 3573.05 3630.56 3687.73 3743.85 3799.07 3854.33 3909.66 3966.84 4021.19 4076.07 4130.76 4186.41 4240.29 4295.05 4351. 60 4408.23 4464.02 4519.78 4574.88 4630.30 4685.85 4743.25 4799.79 4856.36 4912.10 4967.92 5023.78 5080.74 5137.10 5194.55 5251. 31 5309.20 5367.18 5424.28 5481.43 5538.72 5597.29 5656.18 5714.35 5772.86 5833.69 5892.88 5952.22 6011.75 6073.41 6133.25 6193.13 8URVEY LI8TING Your ref Last revised R E C TAN G U L A R Dogleg Vert COO R DIN ATE 8 Deg/100ft 8ect 131.648 147.768 164.338 181.448 199.578 218.118 236.608 254.868 273.028 291. 058 309.538 327.678 347.168 367.008 386.958 406.258 425.858 446.058 466.238 485.948 505.7l8 525.078 544.148 563.028 582.278 601.128 619.948 638.418 656.868 675.328 693.918 711.948 730.008 747.288 764.308 781.118 797.578 813.918 830.028 845.838 861.118 875.658 889.448 902.878 915.348 927.428 939.028 950.358 960.958 971. 428 130.63E 149.53E 169.33E 189.95E 211.39E 233.38E 255.23E 276.71E 298.17E 319.56E 341.60E 362.52E 383.78E 405.20E 426.99E 448.09E 469.57E 491. 69E 513.67E 535.28E 556.93E 577.75E 597.96E 618.01E 638.77E 659.19E 679.54E 699.44E 719.13E 738.69E 758 . 16E 776.68E 795.16E 813 . 1 6E 831.29E 849.31E 866.98E 884.63E 901.99E 918.98E 935.35E 951.10E 966.28E 980.96E 994.55E 1007.84E 1020.72E 1033.60E 1045.88E 1058.05E 3.60 1. 40 1.96 1. 58 1. 27 185.24 210.08 235.86 262.62 290.68 Page 2 MWD <0-10500> 15-Dec-2003 G RID COO R D 8 Easting Northing 317414.95 317433.61 317453.15 317473.51 317494.67 317516.37 317537.94 317559.14 317580.32 317601.43 317623.19 317643.83 317664.79 317685.91 317707.40 317728.20 317749.37 317771.18 317792.85 317814.16 317835.51 317856.03 317875.95 317895.71 317916.17 317936.31 317956.37 317975.98 317995.39 318014.67 318033.85 318052.09 318070.29 318088.03 318105.89 318123.66 318141.07 318158.47 318175.58 318192.33 318208.46 318223.99 318238.96 318253.44 318266.83 318279.94 318292.64 318305.35 318317.46 318329.47 2433758.72 2433742.31 2433725.45 2433708.03 2433689.57 2433670.71 2433651.89 2433633.30 2433614.82 2433596.47 2433577.66 2433559.21 2433539.40 2433519.24 2433498.96 2433479.34 2433459.42 2433438.89 2433418.38 2433398.34 2433378.25 2433358.57 2433339.20 2433320.02 2433300.46 2433281.30 2433262.18 2433243.41 2433224.67 2433205.91 2433187.02 2433168.72 2433150.38 2433132.83 2433115.54 2433098.46 2433081.74 2433065.13 2433048.76 2433032.69 2433017.17 2433002.39 2432988.38 2432974.72 2432962.05 2432949.77 2432937.98 2432926.45 2432915.67 2432905.02 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1690.36 on azimuth 132.69 degrees from wellhead. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.88 0.40 0.21 0.16 0.37 319.42 348.02 376.19 404.29 432.23 0.07 1. 77 1. 65 0.52 0.22 460.96 488.64 517.49 546.68 576.23 0.18 0.18 0.12 0.38 0.41 604.83 633.90 663.86 693.69 722.95 0.48 1. 60 0.66 0.44 0.26 752.26 780.69 808.48 836.01 864.33 0.15 0.10 0.35 0.31 0.11 892.12 919.83 946.98 973.97 1000.86 1. 29 0.96 0.50 1. 20 0.53 1027.78 1053.61 1079.44 1104.38 1129.25 0.27 0.10 0.26 1. 00 1. 69 1153.89 1178.03 1202.09 1225.77 1248.98 0.90 1.14 2.00 1. 79 0.80 1271. 37 1292.81 1313.31 1333.21 1351.66 0.74 1. 21 1. 08 0.25 0.29 1369.61 1386.95 1404.10 1420.31 1436.36 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1690.36 on azimuth 132.69 degrees from wellhead. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 2432737.80 2432737.43 2432737.05 2432736.48 2432735.83 2432740.99 2432740.17 2432739.43 2432738.75 2432738.21 2432745.08 2432744.28 2432743.43 2432742.57 2432741.76 2432750.12 2432748.91 2432747.81 2432746.83 2432745.92 2432757.47 2432755.91 2432754.21 2432752.62 2432751.30 2432765.97 2432763.81 2432761.85 2432760.28 2432758.90 2432781.75 2432777.38 2432773.80 2432770.92 2432768.40 2432810.22 2432803.63 2432798.43 2432792.42 2432786.78 2432845.87 2432837.93 2432830.10 2432822.84 2432816.30 2432894.11 2432883.62 2432873.28 2432863.52 2432854.18 COO R D 8 Northing 318502.81 318503.47 318504.14 318504.70 318505.22 318499.20 318499.98 318500.81 318501.58 318502.21 318496.45 318497.00 318497.57 318498.12 318498.61 318494.26 318494.76 318495.23 318495.58 318495.95 318489.84 318490.98 318492.03 318493.03 318493.78 318482.90 318484.75 318486.30 318487.60 318488.71 318465.78 318470.24 318474.21 318477.74 318480.55 318434.87 318441.51 318447.05 318453.81 318460.31 318397.31 318406.41 318414.99 318422.46 318428.98 318341.84 318353.76 318365.70 318376.99 318387.75 G RID Easting 1677.21 1677.94 1678.69 1679.49 1680.31 1672.39 1673.53 1674.64 1675.66 1676.49 1667.58 1668.54 1669.53 1670.52 1671.44 1662.53 1663.72 1664.82 1665.75 1666.64 1654.27 1656.17 1658.10 1659.92 1661.37 1643.39 1646.22 1648.69 1650.71 1652.47 1620.10 1626.35 1631.69 1636.23 1640.01 1578.08 1587.43 1595.03 1604.08 1612.67 1526.29 1538.36 1549.97 1560.39 1569.63 1452.84 1468.71 1484.49 1499.40 1513.64 Vert 8ect 8URVEY LI8TING Page 3 Your ref : MWD <0-10500> Last revised : 15-Dec-2003 Dogleg Deg!100ft 0.15 0.13 0.15 0.55 0.29 1233.92E 1234.58E 1235.25E 1235.82E 1236.36E o .44 0.18 0.21 0.21 0.42 1230.26E 1231.05E 1231.89E 1232.67E 1233.31E 0.19 0.15 0.06 0.14 0.28 1227.45E 1228.01E 1228.59E 1229. 15E 1229.65E 0.10 0.13 0.36 0.13 0.25 1225.18E 1225.70E 1226.18E 1226.55E 1226.93E 0.27 0.32 0.17 0.40 0.82 1220.65E 1221.81E 1222.88E 1223.91E 1224.68E 0.76 0.68 0.57 0.80 0.18 1213.58E 1215 . 4 6E 1217.04E 1218.36E 1219.50E 1. 92 1. 44 1.81 1.05 0.95 1196.22E 1200.74E 1204.77E 1208.34E 1211.19E 0.37 0.51 0.86 0.58 1. 67 1164.88E 1171.62E 1177.24E 1184.09E 1190.67E 1. 36 1. 00 1. 21 1. 60 1. 99 1126.78E 1136.00E 1144.70E 1152.28E 1158.90E 0.03 0.35 1. 41 1.16 1. 40 1070.58E 1082.66E 1094.75E 1106.19E 1117.09E 1136.008 1136.368 1136.738 1137.298 1137.938 1132.878 1133.688 1134.405 1135.078 1135.608 1128.815 1129.618 1130.458 1131. 308 1132.108 1123.818 1125.018 1126.108 1127.088 1127.988 1116.538 1118.075 1119.758 1121. 338 1122.648 1108.138 1110.275 1112.208 1113.758 1115.128 1092.618 1096.915 1100.438 1103.268 1105.748 1064.618 1071.108 1076.218 1082.138 1087.678 1029.548 1037.348 1045.038 1052.188 1058.625 982.145 992.458 1002.615 1012.198 1021.378 R E C TAN G U L A R COO R DIN ATE 8 9041.62 9104.61 9167.61 9229.60 9291.59 8730.65 8792.64 8854.63 8917.62 8980.62 8420.69 8481.69 8543.68 8605.67 8668.66 8105.74 8168.73 8231.72 8294.71 8356.70 7794.86 7856.83 7919.80 7981.77 8043.75 7487.07 7548.00 7609.95 7671.92 7733.89 7177.99 7238.67 7300.44 7363.28 7424.16 6871. 88 6940.24 6993.71 7055.04 7116.44 6563.27 6625.10 6688.04 6749.16 6810.46 6254.97 6314.91 6376.92 6439.16 6502.58 True Vert Depth 121. 28 116.36 120.93 146.96 133.70 138.08 133.00 128.34 133.41 124.87 144.22 145.68 144.22 149.30 146.43 158.31 154.65 157.94 161. 51 152.06 139.76 146.09 148.75 145.06 155.56 137.37 140.24 141.02 138.21 142.15 133.09 134.13 127.52 129.29 133.02 135.16 132.73 131.86 129.74 130.50 130.32 130.12 133.02 133.61 134.93 130.58 130.40 129.63 130.28 129.93 Azimuth Degrees 0.72 0.66 0.74 0.77 0.78 9360.00 9423.00 9486.00 9548.00 9610.00 1. 02 1. 08 0.98 0.88 o . 64 9049.00 9111.00 9173.00 9236.00 9299.00 0.87 0.96 0.93 0.95 0.78 8739.00 8800.00 8862.00 8924.00 8987.00 1.17 1. 20 0.98 0.92 0.89 8424.00 8487.00 8550.00 8613.00 8675.00 1. 79 1. 78 1. 85 1. 63 1.19 8113.00 8175.00 8238.00 8300.00 8362.00 2.87 2.48 2.13 1. 64 1. 64 7805.00 7866.00 7928.00 7990.00 8052.00 6.31 5.44 4.47 3.82 3.29 7495.00 7556.00 7618.00 7681. 00 7742.00 7.73 7.86 8.31 8.49 7.46 7186.00 7255.00 7309.00 7371. 00 7433.00 11.37 10.74 10.17 9.18 7.96 6873.00 6936.00 7000.00 7062.00 7124.00 14.94 14.73 13.85 13.12 12.21 6556.00 6618.00 6682.00 6746.00 6811.00 Measured Inclin Depth Degrees MARATHON Oil Company Pad #3, BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska ) ) ,) MARATHON Oil Company 5URVEY LI5TING Page 4 Pad #3, BC-13 Your ref MWD <0-10500> Beaver Creek Unit, Kenai Peninsula, Alaska Last revised 15-Dec-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D 5 Depth Degrees Degrees Depth C 0 0 R D I N A T E 5 Deg!100ft 5ect Easting Northing 9672 .00 0.74 132.23 9353.59 1138.495 1236.96E 0.07 1681.14 318505.81 2432735.26 9734.00 0.75 141.69 9415.58 1139.085 1237.51E 0.20 1681.94 318506.35 2432734.67 9796.00 0.93 137.50 9477.58 1139.775 1238.10E 0.31 1682.84 318506.93 2432733.97 9858.00 0.63 140.67 9539.57 1140.405 1238.65E 0.49 1683.68 318507.48 2432733.33 9921.00 0.66 145.25 9602.57 1140.975 1239.08E 0.09 1684.37 318507.90 2432732.75 9983.00 0.77 136.16 9664.56 1141. 565 1239.57E 0.25 1685.14 318508.38 2432732.15 10046.00 0.59 154.04 9727.56 1142.165 1240.01E 0.44 1685.86 318508.81 2432731.55 10108.00 0.63 126.18 9789.56 1142.655 1240.42E 0.48 1686.50 318509.21 2432731.06 10170.00 0.50 155.13 9851.55 1143.098 1240.81E 0.50 1687.09 318509.60 2432730.60 10232.00 0.62 160.63 9913.55 1143.668 1241.04E 0.21 1687.63 318509.81 2432730.04 10294.00 0.65 145.44 9975.55 1144.265 1241.35E 0.27 1688.27 318510.11 2432729.43 10357.00 0.69 149.59 10038.54 1144.888 1241.74E 0.10 1688.98 318510.50 2432728.80 10420.00 0.54 168.25 10101.54 1145.505 1241.99E 0.39 1689.58 318510.74 2432728.18 10442.00 0.57 137.83 10123.54 1145.685 1242.09E 1. 33 1689.78 318510.83 2432727.99 10500.00 0.57 137.83 10181.53 1146.118 1242.48E 0.00 1690.35 318511.22 2432727.56 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1690.36 on azimuth 132.69 degrees from wellhead. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) MARATHON Oil Company Pad #3, BC-l3 Beaver Creek Unit, Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 10500.00 10181.53 Top MD Top TVD Rectangular Coords. ) 5URVEY LI5TING Page 5 Your ref MWD <0-10500> Last revised : 15-Dec-2003 Comment Comments in wellpath -------------------- -------------------- 1146.115 1242.48E Projection to TD Casing positions in string 'A' Rectangular Coords. ------------------------------ ------------------------------ Rectangular Coords. Bot MD Bot TVD ----------------------------------------------------------------------------------------------------------- Casing 0.00 0.00 0.00 0.00 0.00 0.00 Target name O.OON O.OON O.OON O.OOE O.OOE O.OOE 165.00 7288.00 2296.00 165.00 6972.92 2295.86 0.17N 1074.205 2.505 Geographic Location Targets associated with this wellpath Rectangular Coordinates ------------------------------------- ------------------------------------- T.V.D. 0.40E 1175.00E 10.45W 20 Conductor 9 5/8 Casing 13 3/8 Casing ----------------------------------------------------------------------------------------------------------- Revised BC13 ToplL Beluga L2 BC13 TD Revised 13-A BC13 ToplL BelugaL30 Tyonek T2 13-Aug-03 7639.00 10179.00 8346.00 9389.00 1099.975 1099.975 1099.975 1099.975 1202.96E 1202.96E 1202.96E 1202.96E 6-Aug-2003 6-Aug-2003 6-Aug-2003 13-Aug-2003 .~..".__.."-~~.._,-.._,--- Legal Well Name: Common Well Name: Event Name: DATE 11/5/2003 11/6/2003 11/7/2003 11/8/2003 11/9/2003 11/10/2003 11/11/2003 11/12/2003 11/13/2003 11/14/2003 11/15/2003 11/16/2003 ) -.---,.,..-..,-----...-.'""'--,----.,,- ,~..._...__________._.,_'"_,_______..__.,,~._u_'.___,__"..____'".._'"u.,___.,_.___.,_"_._.____._,.__,._. Marathon Oil Company Final Weill Event Summary Page 1 of 2 SEAVER CREEK 13 SEAVER CREEK 13 ORIGINAL DRILLING TMD 165 (ft) 165 (ft) 165 (ft) 165 (ft) 165 (ft) 1,263 (ft) 2,300 (ft) 2,303 (ft) 2,303 (ft) 2,303 (ft) 2,303 (ft) 2,541 (ft) 11/17/2003 3,541 (ft) 11/18/2003 4,754 (ft) 11/19/2003 5,805 (ft) 11/20/2003 6,477 (ft) 11/21/2003 6,630 (ft) Start Date: 11/5/2003 24 HOUR SUMMARY End Date: 12/9/2003 Mob rig. MIRU. Finsih load out f/ CLU #1RD, move & RU drilling equipment @ Be 13. RU drilling equipment. Finish R/U drilling equipment. Weld on 21-1/4" starting head. Install 21-1/4" 2M diverter. Install 16" diverter line. R/U floor. Install 16" diverter line. P/U 4" DP. Function test diverter & diverter valve, test Koomey. gas & PVT alarms. P/U bit, motor & 1 jt HWDP. Tag fill @ 29' RKB. Spud @ 05:00 hrs, 11/09/2003. C/O 20" conductor f/ 29' to 59' RKB. c/o 20" conductor to 91'. POOH. P/U MWD. C/O conductor to 165'. Drill f/165' to 1171' MD. CBU. WT to shoe. SR. TIH. Drill f/1171' to 1263' MD. Drill f/1263' to 2300' MD. CBU. WT. C & C hole for casing. C & C for casing. Trip to run casing. RU & run 6 jts 13-3/8" casing. Hit bridge. Attempt to work past bridge. POOH/LD csg. Make mill run/work junk f/185'-86'/wash to 196'. POOH. TIH w/ biUj/basket to 2300'. Drill f/2300'-03'. C & C. POOH. POOH w/ biUj/basket. Run/cmt 13-3/8" casing. N/D diverter line. woe. RD diverter line & diverter. Cut off 20", remove starting head. Make final cut, install/test multi-bowl wellhead. NU BOP. PU CO BHA & TIH w/ HWDP. POOH to test BOP for AOGCC. Test BOPE. TIH w/ C/O BHA. PU & rack back 4" DP. P/U DP. TIH, test casing to 2000 psi. Tag TOe @ 2249' MD. Drill shoe track & new formation to 2323' MD. LOT to 15.4 ppg EMW. Displace hole to new mud. Trip for BHA. Drill f/2323' to 2541' MD. Drill f/2541' to 3352' MD. CBU. Pull to shoe. Clean flow line tee. TIH. Drill f/3352' to 3541' MD. Drill f/3541' to 4353' MD. WT. Drill f/4353' to 4754' MD. Drill f/4754' to 5356' MD. WT. Drill f/5356' to 5795' MD. Rig rpr. Drill f/5795' to 5805' MD. Dir drill and survey F/5805' to 6410'. Circ. clean. POOH. POOH for bit. Test BOPE. P/U new bit and RIH to shoe. Slip and cut. Cont. RIH to 6200'. W/R 6200' to 6477'. Drill F/6477' to 6630'. -.. - - .." ---.. -,-_._-_.,~----,--,~-~-,- Printed: 3/10/2004 5:05:56 PM ) ,...-..-....,..--.---.--.....-..".'"-.--.----.......-....._......__....~..,_._.._._.._--_._~.--,_._._......._._....-,_..._-,-------_......__....._._.,-._._....,."~_._--_.._,,..,,-"-,..._--"~..._-----_._-._,,--_.".__.... Legal Well Name: Common Well Name: Event Name: DATE 11/22/2003 11/23/2003 11/24/2003 11/25/2003 11/26/2003 11/27/2003 11/28/2003 11/29/2003 11/30/2003 12/1/2003 12/2/2003 12/3/2003 12/4/2003 12/5/2003 12/6/2003 12/7/2003 12/8/2003 12/9/2003 Marathon Oil Company Final Weill Event Summary Page 2 of 2 SEAVER CREEK 13 SEAVER CREEK 13 ORIGINAL DRILLING TMD 6,944 (ft) 7,308 (ft) 7,308 (ft) 7,308 (ft) 7,308 (ft) 7,410 (ft) 7,685 (ft) 8,095 (ft) 8,669 (ft) 9,170 (ft) 9,535 (ft) 9,727 (ft) 9,727 (ft) 9,930 (ft) 10,288 (ft) 10,500 (ft) 10,500 (ft) 10,500 (ft) Start Date: 11/5/2003 24 HOUR SUMMARY End Date: 12/9/2003 Drill F/6630' to 6862'. Circ. clean. Wiper trip to 5043'. RIH. Drill F/6862' to 6944'. Drill F/6944' to 6987'. Repair rig. Drill F/6987' to 7308'. Circ. clean. Circ. Wiper trip to CSG shoe. Circ. clean. POOH LID dir tools and bit. C/O to upper 95/8" rams. Test door seals. Test run 9 5/8" hanger assy. R/U CSG tools. Run 9 5/8" CSG. Run 9 5/8" CSG. R/D Weatherford CSG tool and RIU cement head and line. Cement CSG. B/O hanger LJ and set packoff. C/O rams. Test BOPE. Prep rig to P/U BHA. Rig repair. P/U 8.5" Bit and BHA. RIH. Drill shoe tract and shoe. Drill 20' new hole to 7328'. Displace well to new mud. Perform FIT to 16.3ppg EMW. Drill F/7328' to 7410'. Drill F/7410' to 7614'. CBUX2. Wiper trip. Service rig. RIH. Drill F/7612' to 7685'. Drill F/7685' to 8046'. Circ. clean. Wiper trip. Drill F/8046' to 8095'. Drill F/8095' to 8669'. Circ. clean. Wiper trip to previously drilled hole. Drill F/8669' to 9170'. Drill F/9170' to 9232'. Circ. clean. Wiper trip to shoe. RIH. Drill F/9232' to 9535'. Drill F/9535' to 9727'. Circ. cond mud for trip. Wiper trip to the shoe. Service rig. RIH. Circ. clean. Cir & raised MW f/10.0 to 10.3 befor tripping for MWD batteries ~ C/O bit & mud mtr Drlg 8 1/2 hole to 9873 - POOH to 7200' f/ hole in DP - RIH - Drlg ahead CIR BTMS UP - PREPARE TO SHORT TRIP AT 10288' Condition Hole F/8 1/2 Logs Logging 8 1/2 hole Finish Logging 8 1/2 hole _". ___·_·_.._n._._,______·n' _ . _ ___...__,...,__, ._._ Printed: 311012004 5:05:56 PM ) ',) .. ,,__.._____.."M."_.~._M....._._.__._.....M._ 0.. _M......_........_.,_.,..._...___M_...___._.._,_...._.,._,.......__.M.._.._._....__..__..._._.... ...__.._..._._..__..__.__._._........_..._.._..._...._..__.~..- -_..._..,-,-,-_.__.- Legal Well Name: Common Well Name: Event Name: DATE 12/10/2003 12/11/2003 12/12/2003 12/13/2003 12/14/2003 12/15/2003 Marathon Oil Company Final Weill Event Summary Page 1 of 1 BEAVER CREEK 13 BEAVER CREEK 13 ORIGINAL COMPLETION TMD 10,500 (ft) 10,500 (ft) 10,500 (ft) 10,500 (ft) 10,500 (ft) 10,500 (ft) Start Date: 12/9/2003 24 HOUR SUMMARY End Date: 12/15/2003 Make clean out trip to btm - Make wiper trip to shoe & back to btm - pump hi-vis sweep - Cir & cond mud - POOH to 9 5/8 shoe - Start laying dn 4" drill pipe Finish laying dn 4" DP - RIU Excape completion & start running 3 1/2" 9.3# L80 EUE 8rd csg Ran 317 jts of 31/2 L80 9.3# EUE 8rd Excape completion & logged into place w/ Expro Cmt 31/2 Excape completion - N/D BOP's - N/U tree - Clean pits Clean pits & rig - Change out #2 carrier mtr - Install new hand rails - While rigging down Rigging Down - Release Rig from Be #13 @ 060012-15-03 n. ____no ___.__,_,,_____.__~ ____ ___.no". ,_.____.._________ Printed: 3/10/2004 5:06:17 PM ) ) _..._._____,__....."_.,_,___._~".__,_'"_..._...~"_"_.________....__.,___..._,_.__'.__..___._..._...__..__.__..______,___.___.._............ 'h........_...._........._......._...·._,_.·__..·_.,_._..·.··._._..__.._.___,_...,_.__._._,_,,_....~.._..._._ ___.._"......._......,._,."...._.___..__.____.__.__......_.__...._.._... Legal Well Name: Common Well Name: Event Name: DATE 1/16/2004 Marathon Oil Company Final Weill Event Summary BEAVER CREEK 13 BEAVER CREEK 13 ORIGINAL COMPLETION Start Date: 1/16/2004 TMD 24 HOUR SUMMARY (ft) RU Reeves wireline to run compensated Sonic cement bond log End Date: Page 1 of 1 ---. Printed: 3/10/2004 5:06:31 PM API: 50-133-2052500 RT-GL: 21.00' RT·THF: 20.33' 1309.9' FNL, 1479.5' FWL, Sec. 34, T7N, R10W, S.M. Tree cxn = 4-3/4" Otis TOC (est.) - ???' Excape System Details - BHP monitoring line volume tank located from 7668' - 7706' Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 1 - NA Module 2 - 8521.8' Module 3 - 8426.3' Module 4 - 8257.8' Module 5 - 8196.3' Module 6 - 8157.3' Module 7 -7997.8' Module 8 - 7799.6' Module 9 - 7760.7' Well Name & Number: County or Parish: Perforations (MD) I BHP: Dated Completed: Prepared By: BC..13 TO -10500' PBTD -10429 ' BC-13 I lease: Kenai State/Prov. See diagram (TVD) BHT: I 12/15/2003 J. R. Thompson Completion Fluid: last Revison Date: IDrive Pipe: 20", 193 ppf, K-55 to 165' Surface Casinq: 13·3/8",68 ppf, K-55, BTC @ 2296' Cmt wi 568 sks of class G Int. Casinq: 9-5/8", 47 ppf, L-80, BTC @ 7288' Cmt wi 978 sks of class G Prod. Tubinq: 3-1/2", 9.3 ppf, L- 80, EUE 8rd with 6.25" 00 protectors to 10461' Cmt wi 1475 sks of class G Excape System Details - 9 Excape modules placed . Green control line fires bottom 1 modules . Red control line fires top 8 modules - Ceramic flapper valves below each module Perfs MD (RKB): Module 1 - 8584'-8594' Module 2 - 8491'-8501' Module 3 - 8397'-8407' Module 4 - 8225.5'-8235.5' Module 5 - 8164'-8174' Module 6·8125'-8135' Module 7 - 7966.5'-7976.5' Module 8 - 7769'-7779' Module 9 - 7730'-7740' Beaver Creek Gas Field Alaska ICountry: IUSA 6% KCL 1/14/2004 ~ ~Â¿?..tIß¿7 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Marathon Oil Company for an order granting an exception to spacing requirements of Title 20 AAC 25.055 to provide for The drilling of the Beaver Creek Unit No. 13 gas development Well. ) Conservation Order No. 498 ) ) Marathon Oil Company ) Beaver Creek Unit No. 13 ) ) October 7,2003 IT APPEARING THAT: 1. Marathon Oil Company submitted an application dated August 20, 2003 requesting exception to the well spacing provisions of Title 20 AAC 25.055(a)(4) to allow drilling the Beaver Creek Unit No. 13, gas development well to a location which is within the same governmental section and within 3000 feet of another well capable of producing from the same pool. . 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on August 28, 2003 pursuant to 20 AAC 25.540. 3. No protests to the application were received. SCANNED JUL 0 5 2007 FINDINGS: 1. The Beaver Creek Unit No. 13 (BCU 13) gas development well will be drilled as a deviated hole with a surface location 1479 feet from the west line (FWL) and 1310 feet from the North line (FNL) of Section 34, T7N R10W, Seward Meridian (SM) to a bottomhole location 2680 FWL and 2411 FNL of Section 34, T7N R10W, SM. 2. Offset landowners, owners and operators within 3,000 feet of the anticipated productive interval of the BCU 13 well have been notified. 3. No protests to the spacing exception application were received. 4. The location of the BCU 13 well was selected as a favorable structural position for Tyonek Formation gas reserves on the Beaver Creek Unit structure, if successful the well will access reserves that are not producible from any existing wells. 5. An exception to the well spacing provisions of Title 20 AAC 25.055 (a)(4) is necessary to allow the drilling of the BCU 13. CONCLUSIONS: 1. The requested spacing exception for the BCU 13 well should be granted, except that the Commission must take such action as will offset any advantage which Marathon Oil I . Conservation Order No. 498 October 6, 2003 Page 2 of 2 . Company may have over adjoining owners by reason of the drilling the BCU 13 well as an exception, and so that drainage to the tract with respect to which the exception is granted wi1l be prevented or minimized. 2. Evaluation of the lateral extent of the Tyonek Formation gas reserves in the BCU 13 wi1l be required to insure protection of the correlative rights of adjoining owners. NOW, THEREFORE, IT IS ORDERED: 1. Marathon Oil Company's application for exception to the well spacing provision of 20 AAC 25.055(a)(4) is conditionally approved. 2. The BCU 13 well may not be placed on regular production until Marathon Oil Company has evaluated the lateral extent of the Tyonek Formation gas reserves in the BCU 13 and the Commission has been provided that evaluation and has had the opportunity to take additional action to offset any advantage Marathon may have over other owners by reason of dri1ling BCU 13 to the exception location. DONE at Anchorage, Alaska and dated October 7, 2003. Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission ~ 4L... ~ Randy R drich, Commissioner "' Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., lOth day after the application for rehearing was filed). . . Permit / Project 2031380 Date Category De.\wiption 8/12/2003 Start Time 9:15:21 AM End Tîme 9:23:21 AM Drill Permit App SubJect BCU 13 Will Tank phones: will email revised directional survey. Duration UIC Notes Contact-Primary Contact-Secondary Primary File Secondary File Hyperlinks to Related Files Company Company Hyperlinks to Image Files Thursday, June 28, 2007 Page 60f6 . . Permit / Project 2031380 Date Start Time 4:17:56 PM End Time 4:43:22 PM Duration UIC 8/11/2003 Category SubJect Drill Permit App BCU13 Dett'cription Plot revised directional survey. Email from Will Tank saying data has a bust in it. Email to Will saying to forward next revision to Bob Crandall. Note... Contact-Primary Contact-Secondary Primary File Company Company Secondary File Hyperlinks to Related Files Hyperlinks to Image Files Thur,Yday, June 28, 2007 Page.5 of6 . . Permit / Project 2031380 Date Category Des'cription 8/11/2003 Start Time 9:11 :12 AM End Time 9:24:59 AM Drill Permit App SubJect BCU 13 Review past work and pass permit file on to Bob Crandall. Duratio/l UIC Note,v Contact-Primary Contact-Secondary Primary File Secondary File Hyperlinks to Related Files Company Company HyperUnks to Image Files Thur,Yday, June 28, 2007 Page 4 of6 . . Permit / Project 2031380 Date Start Time 8:00:32 AM End Time 8:34:53 AM Duration UIC 8/6/2003 Category SubJect BCU 13 Drill Permit App De.\'cription Howard has input all Beaver Creek Unit wells. Measure distances between B-10 and B-13 on screen spider plot (large scale). B-13 will be less than 1320' from B-10 in pool. So a spacing exception will be necessary if Marathon doesn't move well course. Notes Separation of BCU 10 from proposed BCU 13 T/Beluga: 1180 feet apart T/Lower Beluga: 1270 feet apart TD: 1260 feet apart Contact-Primary Contact-Secondary Primary File Company Company Secondary File Hyperlinks to Related Files Hyperlinks to Image Files Thursday, June 28, 2007 Page 3 of6 . . Permit / Project 2031380 Date Start Time End Time 1 :44: 1 0 PM Duration UIC 8/5/2003 1:16:56 PM Category Description SubJect BCU 13 Drill Permit App Bob Lantz phones. He will nudge well course to lie outside the 1320' offset required by C0237 and re-submit PTD form and directional survey. Notes Contact-Primary Bob Lantz Contact-Secondary Primary File Company Marathon Company 907-564-6427 Secondary File HyperUnks to Related Files Hyperlinks to Image Files Thur.çday, June 28, 2007 Page 2 of6 . . Permit to Drill or Project Report Permit / Project 2031380 Date Start Time End Time 2:55:01 PM UIC 8/4/2003 1 :46:36 PM Duration Category Description Subiect BCU13 Drill Permit App Governed by CO 237. Spacing exception may be needed; spacing minimum is 1320' from nearest well within pool. My calcs show 1259' at top prod int and 1228' at TD.. Appears to be 60 - 100 feet too close to BCU 10. Will check GeoFrame. Pass app to WGA. Note!.' Contact-Primary Contact-Secondary Company Company PrimaryFile \ \Aogcc1 \sfdavies \Daily _Document_Record\2003\030803 _2031380_BC U_13_0ffset_Distances.xls \ \Aogcc1 \sfdavies \Daily _Document_Record\2003\030803 _2031380 _BCU_ 13_ OffseCDistances.xls Secondary File HyperUnks to Related Files HyperUllks to Image Files Thursday, June 28, 2007 Page] of6 J- \ ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Marathon Oil Company (MaC) for a spacing exception to allow the drilling and production of the Beaver Creek No. 13 Gas Development Well. MaC by letter dated August 20, 2003, has requested the Commission to issue an order in conformance with 20 AAC 25.055 allowing the drilling and regular production of the Beaver Creek No. 13 Gas Development Well from a location within the same governmental section and within 3000 feet of another well capable of producing from the same pool. The surface location of the proposed well is 1479 feet from the west line and 1310 feet from the north line of Section 34, T7N, RI0W Seward Meridian (SM). The proposed bottomhole location is 2411 feet from the north line and 2680 feet from the west line of Section 34, T7N, Rl OW, S.M. The Commission has tentatively set a public hearing on this application for September 30, 2003 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on September 15, 2003. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1230. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on September 29, 2003. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1230 no later than September 15, 2003. ~~ Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission Published August 28, 2003 AO: 02414005 ) [1 tA!· (~¡"11? r~ L/j~)!·\/A .__' ï.."n.S ~~" LI'\\. L.. \\ FRANK H. MURKOW5KI, GOVERNOR AI1ASIiA. OIL AND GAS CONSERVATION COMMISSION Willard J. Tank Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Re: Beaver Creek BC 13 Marathon Oil Company Permit No: 203-138 Surface Location: 1309.9 FNL, 1479.5 FWL, Sec. 34, T7N, R10W, SM Bottomhole Location: 2410.6' FNL, 2679.8 FWL, Sec. 34, T7N, R10W, SM Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Marathon Oil Company assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~¿, ~, Randy iuedrich ~ Commissioner BY ORDER OF THE COMMISSION DATED this~ day of August, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section , , M MARATHON 4 Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 14,2003 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 G 1 5 Z003 Reference: Replacement Drilling Permit Application Field: Beaver Creek Field Well: Beaver Creek Unit BC-13 Dear Ms. Palin Enclosed please find a revised PERMIT TO DRILL application, along with the associated attachments. This permit is to replacéÍ:he one sent to you on August 1, 2003. After submitting the original permit it was discovered that the Beluga pay zone location would be a non-standard location. The intent to drill a development well in the Beaver Creek Unit remains, with 2 changes; a Beluga pay zone location that is a standard location, and the deepening of the well to the Tyonek formation. Please note that Marathon is requesting a waiver for 20 ACC 25.035 (c) (1) (b) requiring the /" vent line to be as large as the hole drilled and a wavier for 20 ACC 25.035 (e) (1) (b) -",,/" requiring a two pipe ram stack. The requests are specified on page 11 of the attached drilling prognosis. If you require further information, I can be reached at 907-564-6310 or bye-mail at wjtan k@marathon.com. Sincerely, kJLJ),~ Willard J. Tank Senior Drilling Engineer Enclosures OR\G\NAL \NGI\- 111sl2.0Ðš ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill[!] Re-entry 0 Redrill 0 1 b. Current Well Class: Stratigraphic Test 0 Exploratory 0 Service 0 Development Oil 0 Development Gas [!] Multiple zone[!] Single zoneO 2. Operator Name: Marathon Oil Company 5. Bond: [!] Blanket o Single WellO 11. Well Name and Number: Bond No. 5194234 BC-13 /'. 3. Address: P.O. Box 196168, Anchorage, AK 99519-6168 4a. Location of Well (Governmental Section): Surface: 1,309.9' FNL, 1,479.5' FWL, Sec. 34, T7N, R10W, S.M. 8. 6. Proposed Depth: MD: 10,496' TVD: 10,179' 7. Property Designation: A-028083 Land Use Permit: 12. Field/Pool(s): Beaver Creek I Beluga & Tyonek Total Depth: 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. 4b. Location of Well (State Base Plane Coordinates): 2560 10. KB elevation 13. Approximate Spud Date: "",,,", 9/22/2003 14. Distance to Nearest Property: 3,881' 15. Distance to Nearest Well within Pool: 1 ,510' (BC-10 Beluga cut point) Top of Productive NIA Horizon: 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. 9. Acres in Property: Surface: x- 317,286.14' y- 2,433,891.50' Zone- 4 16. Deviated Wells: (Height Above GL): 179 (21' above GL) 17. Anticipated Pressure (see 20 MC 25.035) feet Kickoff Depth: 2,500 ft. 18. Casing Program: Size Casing 20" 13 3/8" 95/8" 31/2" Maximum Hole Angle: 26.74 0 Max. Downhole Pressure: 5,894 Setting Depth psig. /' Max. Surface Pressure: 3,846 psig. Quantity of Cement c.f. or sacks. (Including Stage Data) Specifications Top Bottom Hole Driven Weight 129# 68# 40# 9.3# Grade Coupling Length MD TVD MD TVD K-55 PE +1- 100' 0' 0' 100' 100' K-55 BTC 2,300' 0' 0' 2,300' 2,300' L-80 BTC 7,270' 0' 0' 7,270' 6,954' L-80 EUE 10,496' 0' 0' 10,496' 10,179' PRESENT WELL CONDITION SUMMARY (to be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft.) Plugs (measured) Effective depth MD (ft) Effective Depth TVD(ft): + 1- 982 sks. / + I - 1,172 sks. /' + 1-1,282 sks. / 171/2" 12 1/4" 81/2" 19. Total Depth MD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee [!] Property Plat[!] BOP Sketch [!] Drilling Program [!] Time v. Depth PlotO ¡('''~ ~1ï~lhjW:.H~·fã'~ ~n'alysis 0 :.\ I r 2~ ~~ 25.050 R~qUir~~ents 0 ~\~,IG 1 b ?O(ì3 Diverter Sketch [!] Seabed ReportO Drilling Fluid Program [!] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. P'oted Name Wmaro J. Taok J1~ ~ Signature Contact Title Senior Drilling Engineer Phone 907-564-631 0 Date 8/14/2003 Permit to Drill / Number: :2- 0 3 - ~ ~ <¡{ Commission Use Only IAPI Number: Ipermit Approval Þ h " 50- /33 -..2.. 0 52-S Date: oe/ L-/ / ,.,) Samples required OYes §NO Mud log required / OYes ~NO Directional survey required ~ves ll,,~~ \J~t !e·~ I See cover letter for other requirements. ~NO ONo is ¥p~\tt!-d. Conditions of approval: _ L 1) HYdrO~e~ sulfid~ measures pves Other: \.e..S l pO r E ro Lfooo r s, . Pe,(' 'Z.-o A-A-'- 'LS. 0 ~ ç é k") L 2-)) t ¿, Ii Approved by: v~ ~~ COMMISSIONER BV ORDER OF THE COMMISSION Date ~ "'- Submit in duplicate Form 10-401 Revised 3/2003 OR!G¡r'~AL ) ) MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Beaver Creek Unit BC #13 Revised J/" 8/14/03 Originator: W.J. Tank Drilling Superintendent: P .K. Berga Drilling Manager: C.W. Truby dAti Page 1 of 12 ) ') Table of Contents General Well Data.................................................................................................................................. .................................3 Geologic Program Summary................................................................................................................................ ...................3 Summary of Potential Drilling Hazards................................................................................................................................... .4 Formation Evaluation Summary................................................................................................................................... ...........4 Drilling Program Summary........................................................................................................................................... ............5 Casing Program................................................................................................................................ .......................................6 Casing Design........................................................................................................................................ .................................6 Maximum Anticipated Surface Pressure.................................................................................................................................6 BOPE Program....................................................................................................................... .................................................7 Wellhead Equipment Summary .................................................................................................................... ..........................8 Directional Program Summary............... .................................................................................................................................8 Directional Surveying Summary............................... ................................................................................ ...............................9 Drilling Fluid Program Summary..............................................................................................................................................9 Drilling Fluid Specifications................................................................ .................................... ............ ....................................10 Solids Control Equipment................................................................................................................... .......... .........................10 Cement Program Summary. ..................................... ................................................................................ ............................ .11 Regulatory Waivers and Special Procedures......................... .............................................................................................. .11 Hydraulics Summary............................................................................................................................................. ................ .12 Formation Integrity Test Procedure ................................................................................................... ..................... .............. .12 Page 2 of 12 ) ) General Well Data Well Name BC #13 Lease/License Surface Location 1,309.9' FNL, 1,479.5' FWL, Sec. 34, T7N, R10W, S.M. WBS Code DD.03.09342.CAP .DRL Slot/Pad Pad 3 Field Beaver Creek Spud Date 9/22/03 (est.) KB Elev. 179 County/Province Kenai Borough API No. Ground Level Elev. 158 (NGVD29) State / Country Alaska Well Class Development Perm. Datum KB Total MD 10,496' Rig Contractor Glacier Drilling Water Depth N/A Total TVD 10,179' Rig Name #1 Water Protection Depth Comments: GeoloQic PrOQram Summary MD - RKB TVD - RKB Pore Pressure Pore Pressure Possible Fluid Formation (ft) (ft) (psi) (ppg) Lithology Content Sterling B-2 5,297 5,074 Sandstone Gas / Water Sterling B-3 5,342 5,114 4.4 Sandstone Gas / Water Sterling B-4 5,480 5,239 7.9 Sandstone Gas / Water Upper Beluga UB-1 6,126 5,839 Sandstone Gas Upper Beluga UB-2 6,262 5,969 8.5 Sandstone Gas Upper Beluga UB-3 6,335 6,039 Sandstone Gas Middle Beluga 6,737 6,429 Sandstone Gas Lower Beluga LB-17 7,521 7,204 5.8 - 9.4 Sandstone Gas Lower Beluga LB-19 7,672 7,354 5.8 - 9.4 Sandstone Gas Lower Beluga LB-20 7,742 7,424 5.8 - 9.4 Sandstone Gas Lower Beluga LB-21 7,847 7,529 5.8 - 9.4 Sandstone Gas Lower Beluga LB-23 7,957 7,639 5.8 - 9.4 Sandstone Gas Lower Beluga LB-24 8,072 7,754 6.5 - 9.4 Sandstone Gas Lower Beluga LB-25 8,137 7,819 6.7 - 9.4 Sandstone Gas Lower Beluga LB-28 8,407 8,089 6.7 - 9.4 Sandstone Gas Lower Beluga B-30 8,664 8,346 6.7 - 9.4 Sandstone Gas Tyonek 8,927 8,609 8.5 Sandstone Gas Tyonek T2 9,707 9,389 2.9 - 8.5 Sandstone Gas Comments: Surface Location Coordinates From Lease/Block Lines Latitude Longitude UTM North (Y) UTM East (x) Tolerance 1,309.9' FNL, 1,479.5' FWL, Sec. 34, T7N, R10W, S.M. 60039' 29.225" N 1510 l' 6.366" W 2,433,891.50' 317,286.14' Page 3 of 12 Depth Target Lower Beluga LB-23 Lower Beluga LB-30 Tyonek T2 WellTD MD (ft) 7,957 8,664 9,707 11 ,496 TVD (ft) 7,639 8,346 9,389 10,179 Comments: Summary of Potential Drillina Hazards Hazard Event Lost Circulation in Low Pressure Sterling, Beluga, and Tyonek Sands Comments: Potential Hazards Statement ') Location 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. 2,410.6' FNL, 2,679.8' FWL, Sec. 34, T7N, R10W, S.M. Discussion Control losses by using sufficiently sized LCM. ) Horizontal Displacement (ft) +N/-S +E/-W (Y) (X) -1101 1,200 -1101 1,200 -1101 1,200 -1101 1,200 Tolerance (ft) Circle 100' radius Circle 100' radius Circle 100' radius Circle 100' radius 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 brake (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 +/- 5,297' MD (5,074' TVD) to total depth of the well. These sands will run from normal pressured to severely depleted and lost circulation and differential sticking are potential hazards. The Flo-Pro mud system 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. Formation Evaluation Summary Interval Surface 0' - 2,300' MD Intermediate LWD None None 2,300' -7,270' MD Production None 7,270' - 11,496' MD Completion N/A * Log run if borehole conditions allow Coring Requirements: None Comments: Electric Logs None None None Mud Logs Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Basic with GCA, shale density, temperature in and out, sample collection (10' samples). N/A Triple combo (PEX), Digital Sonic (DSI), CMR Plus*, MDT* GR, CCL Page 4 of 12 ) ) CONDUCTOR: Drilling Program Summary 1. Drive 20" conductor to +1-100 ft. RKB. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20" SOW x 21 1/4", 2M flanged. 4. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. 5. Function test diverter and diverter valve. ./' SURFACE: 1. 2. 3. 4. 5. 6. 7. Drill a 17 1/2" hole to 2,300' MD (2,300' TVD) per the directional plan. // RIH with 13 3/8" casing and hang off in the slips. Make up stab-in sub and centralizer on 4" drill pipe. TIH with inner string and latch into stab-in float collar. Cement 13 3/8" casing. Sting out and circulate drill pipe clean. TOOH with inner string. PU 133/8" casing, set casing slips in 20", cut off 13 3/8", ND diverter. Install 13 3/8" slip lock connection X 13 5/8" 5M flanged multibowl wellhead. /" NU 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/4,000 psi. Set wear bushing. Test surface casing to 2,000 psi. INTERMEDIATE: 1. 2. 3. 4. 5. 6. 7. 8. Drill out float equipment and make 20' of new hole. CBU. Test shoe to leak off. Estimated EMW is 14.6 ppg. Drill 12 1/4" directional hole to 7,270' MD (6,954' TVD) as per directional plan. Make wiper trip. . Change out variable pipe rams with 9 5/8" casing rams. Run test plug and test casing rams to 4,000 psi. /' Run and cement 95/8" casing. Land hanger in multibowl wellhead. Back out landing joint. Change out 9 518" casing rams with variable pipe rams. Run test plug and test pipe rams to 250/4,000 psi. Set wear bushing. Test casing to 4,000 psi. /' // PRODUCTION: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Drill float equipment and 20' of new formation wI 8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 15.8 ppg. Drill a 8 1/2" hole to.~ .MDI{ta.l1~TVD) per the directional program. /' TOOH. RU logging domiJàtty. ~n óþen hole logs as per plan. RD logging company. TIH to TD for wiper trip. TOOH and laydown BHA and drill pipe. Pull wear bushing. Run 3 1/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging company. / Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. wac. PU 3 1/2" casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 3 1/2" casing. /" LD BOP. Set 3 1/2" packoff. N U 13 5/8" 5M X 3 1/8" 5M tubing head adapter and 3 1/8" 5M tree. Test tree to 5,000 psi. Rig down and move out drilling rig. Note: Perforating guns will be run on the outside of the 3 1/2" production casing with a flapper valve just below each perforating gun. Guns to be activated by control line to surface. COMPLETION: Completion will be done without a rig. / Page 5 of 12 ) ) Casin~ Pro~ram MD (ft) Connection API Ratings <I.) c: Casing /' Makeup +-' ,.-.. ~:=- 0 êi) / !:!? ëñ OJ (J) ëñ 0- Size Weight 0.0. Torque Hole Size :J .9: = a. c: g co 0......... <I.) (in) Top Bottom (Ibslft) Grade Type (in) (ft-Ibs) (in) ü I- 13 3/8 Surface 2,300 68 K-55 BTC 14.375 N/A * 17.50 3,450 1,950 1,300 95/8 Surface 7,270 40 L-80 BTC 10.625 N/A * 12.25 5,750 3,090 979 31/2 Surface 10,496 9.3 L-80 8rd 4.5 3,200 8.5 10,160 10,530 207 Comments: * The make up of the buttress connection will be to the proper mark. Casin~ Desi~n Casing Shoe Safety Factors Casing Maximum Surface <I.) c: Setting Mud Wt Frac. Form (J) 0- 0 +-' .!!! ëñ Size Weight Depth When Set Grad Press Pressure !:!? Õ c: :J <I.) (in) (Ib/ft) Grade (TVD) (Ib/gal) (Ib/gal) (Ib/gal) (psi) co ü I- 13 3/8 68 K-55 /' 2,300 9.2 14.6 8.5 1,576 2.16 1.38 4.08 95/8 40 L-80 (' 6,954 9.4 15.8 8.5 3,846 1.16 1.02 2.75 31/2 9.3 L-80 10,179 9.4 15.0 8.5 3,481 1.10 1.72 1.60 Comments: Maximum Anticipated Suñace Pressure Setting Depth Casing Size TVD MAWP * (in) (ft) (psi) 13 3/8 2,300 1,576 9 5/8 6,954 3,846 3 1/2 10,179 3,481 * MAWP = Maximum anticipated wellhead pressure ** MASP = Maximum anticipated surface pressure MASP ** Mud/Gas (psi) Ratio 1,576 0/100 3,846 50/50 3,481 0/100 Comments: MASP CALCULATIONS: Surface casing: 13 3/8" (2,300' MD, 2,300' TVD) MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (14.6 ppg + 0.5 ppg) x .052 x 2,300' - (.1 x 2,300') MASP = 1,806 psi - 230 psi MASP = 1,576 psi. Page 6 of 12 ) Intermediate casing: 95/8" (7,270' MD, 6,954' TVD) ) MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASP = (15.8 ppg + 0.5 ppg) x .052 X 6,954' - (.052 x 9.4 x 3,477') - (.1 x 3,477') MASP = 5,894 psi - 1,700 psi - 348 psi MASP = 3,846 psi Production casing: 3 1/2" (10,496' MD, 10,179' TVD) MASP = Formation pressure - Hydrostatic pressure of gas column. MASP = 8.5 ppg x .052 X 10,179' - (.1 x 10,179') MASP = 4,499 psi - 1,018 psi MASP = 3,481 psi. BOPE ProQram Casing Casing Size (in) Casing Test Test Fluid Press Density (psi) (Ib/gal) MAWP (psi) MASP (psi) Surface 13 3/8 1,576 1,576 2,000 9.2 Intermediate 95/8 3,846 3,846 4,000 9.4 Production 31/2 3,481 3,481 4,000 9.4 Comments: Blowout Preventers BOPS Size & Rating (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets // Test Pressure Low/High (psi) 250/4,000 250/4,000 250/4,000 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 and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets. 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 mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Page 7 of 12 Casing Test Pressures ) ) Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Wellhead Equipment Summary Component Casing Head Tubing Head Adapter Flange Comments: Description 13-5/8" 3M X 13-3/8" Slip Loc W/2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, PR1 13-5/8" 3M Studded Bottom X 13-5/8" 5M Fig Top, W/2, 2-1/16" 5M Studded Outlets, U,AA,PSL 1 ,PR1 13-5/8" 5M X 3-1/8" 5M W/ Seal Pocket and 3" H BPV Threads Casing Hanger Type 13 5/8" x 9 5/8" Fluted Mandrel 135/8" x 3 1/2" Manual Slip Control lines and electric cable for the EXCAPE system will be routed through the tubing head side outlet. Directional ProQram Summary Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +E/-W VS No. Description (ft) (ft) (°/100') C/100') (°/100') (deg) (deg) (ft) (ft) (ft) Tie On 0 0 0 0 0 0 0 0 0 0 2 KOP 2,500 2,500 0 0 0 0 132.52 0 0 0 3 Build up Section 2.5 0 ?:l 132.52 4 End of Build 3,569.60 3,531.19 2.5 0 0,/ 26.74 132.52 -165.65 180.64 245.09 5 Ho/d Section 0 0 0 26.74 132.52 6 End of Hold 5,282.62 5,061.02 0 0 0 26.74 132.52 -686.58 748.72 1,015.86 7 Drop Section -1.0 0 1.0 132.52 8 End of Drop to the 7,956.62 7,639.00 -1.0 0 1.0 0 132.52 -1,100.70 1,200.32 1,628.59 Target 9 TD 10,496.62 10,179.00 0 0 0 0 132.52 -1,100.70 1,200.32 1,628.59 Comments: Potential Well Interference: Vertical section calculated from a reference azimuth of 132.52° taken from surface location to bottom hole location. Well BC #3RD BC#5 BC#6 BC#9 BC #10 BC #11 // Distance (ft) 66.4 96.7 126.9 71.9 209.2 175.8 Depth (MD) 600 2,400 2,500 1 ,400 1,200 1,300 No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 8 of 12 ) ~ 3000-: ~ :s C> C> ~ C> 0 ~ 0 .£3 Ë & 5000-: i Q ] '-8 0 Q) ~ > ~ ~ ;: 0 CI) I: . 9000-: I 0000': "¡ , , , I ' , , , I ' , , , I ' , , , I ' , , , -3000 -2000 -1000 0 Vertical Section at 132.52° [3000ftJin] Directional Surveying Summary Interval o - 2,300' 2,300' -7,270' 7,270' - 10,496' Comments: MWD Survey X X X Magnetic Multishot Drilling Fluid Program Summary Interval - TVD From To (ft) (ft) 0 2,300 2,300 6,954 6,954 10,179 Comments: Density (Ib/gal) 8.6 - 9.2 Fluid Description Gel/ Gelex Spud Mud ') W est( - )/East( +) [1 OOOftJin] Gyro Multishot Comments / 9.0 - 9.4 6% Flo-Pro w/ Safecarb Additives Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL Flo-Vis, PoluPac UL, KCI, SafeCarb F, Ventrol 401, Barite, Caustic, Conqor 404, SafeScav NA Flo-Vis, DualFlo, KCI, Greencide 25G, SafeCarb F, Ventrol 401, Barite, Caustic, Conqor 404, SafeScav NA Minimum Inventory Gel Viscosifier Barite / 9.2 - 9.4 6% Flo-Pro w/ Safecarb See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff into the low pressure zones. ----" Page 9 of 12 ) ) Drillin~ Fluid Specifications Interval- TVD LSRV ,., From To Density / Vis 1 min PV (ft) (ft) (/b/gal) (seclqt) (lb.l10Ofe) (cP) 0 2,300 8.6 - 9.2 60 - 100 2,300 6,954 9.0 - 9.4 40,000 8 -14 6,954 10,179 9.2 - 9.4 40,000 10 - 14 Comments: YP Fluid Loss Drill Solids (lb/100 ff) (cc) pH (%) 25 - 35 NC - 12 +/- 9.5 <7% 6-8 +/- 9.5 +/- 5 <5 +/- 9.5 +/- 5 Solids Control Eauipment c: 0 () (¡) ~ 1$ e> Q) ro L- c: Q) 0 :E .s:: ro (,) Q) L- Q) 0> (f) (f) (f) "0 .2 (¡) c: Æ ë3 0> 0> is ï:: c: c: ~ ro ïi) "0 ë E E e ro (f) .s:: Q) Q) :J Q) :J :J Q) Interval C/') 0 0 ~ ü ü Ü N Comments 0- 10,496' MD X X X X Closed Loop System, Full Containment Item Shaker 2 - Derrick ModeI2E48-90F-3TA Desander N/A Desilter 1 - Derrick Model 0522 Mud Cleaner N/A Centrifuge 2 - MI/Swaco units Cuttings Dryer N/A Cuttings Injection Marathon G&I Facility Zero Discharge N/A Equipment Specifications (quantity, design type, brand, model, flow capacity, etc) Comments: The solids control equipment will consist of two flowline cleaners, a desilter, 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. Page 10 of 12 ) ) Cement Program Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry WOC Hole Size MD TVD Size MD TVD To TOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (fe) (ft3) (hrs) (%) 13 3/8 2,300 2,300 17.5 0 0 1,622 2,454 8 50 95/8 7,270 6,954 12.25 1,800 1,800 1,731 2,544 8 50 3 1/2 10,496 10,179 8.5 7,000 6,674 1,152 1,526 N/A 35 Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (lb/gal) (sx) (ft3/SX) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr Lead 13 3/8 Tail Type I Cement 12 982 2.50 2,454 0 10.84 Fresh 812 0 500 1,183 Lead Class "G" 12 570 2.53 1 ,443 1,800 10.63 Fresh 9 5/8 Tail Class "G" 13.5 602 1.83 1 ,101 5,000 9.25 Fresh 10 0 60 820 Lead 3 1/2 Tail Class "G" 15.7 1,282 1.19 1,526 7,000 4.03 Fresh 24 0 500+ 2,431 Comments: See cement prognosis for details and spacer specifications. Regulatory Waivers and Special Procedures vJ tJ.. "'..(2/ . I AOGCC Regulation 20 ACC 25.035 (c) (1) (b) I Requirement to have vent line diameter at least as large as the hole to be drilled. Marathon is requesting a waiver from the above regulation for BC #13. Our Glacier 1 drilling rig is outfitted with a 16" diverter line. For BC #13 the plan is to drill 17 ~" surface hole to a total vertical depth of 2,300'. This well is being drilled from the Beaver Creek 3 pad. The direct offset to this well BC #11 was drilled in April, 2003 and no gas was detected in this well above this TVD and no problems were encountered in the surface hole. The BC #11 well was drilled with the 16" diverter line without any problems. To date, 6 wells have been drilled from this pad with no gas seen above this TVD. I AOGCC Regulation 20 ACC 25.035 (e) (1) (b) I Requirement for 2 pipe rams, one blind ram, and one annular for a API 5K or above BOP stack. No WA-( Je-.l yf'~¡l ~Æ"..Q ~ - (/.''):Jç y} ..~~ Marathon is requesting a waiver from the above regulation for BC #13. We are requesting that tfle BOP stack be configured with one pipe ram instead of two, due to rig height restrictions in the running of the 3 1/2" production casing. .1 t --:1-- 'i-E.. -,- 10 The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 3 1/2" casing is cemented and the BOP stack is picked up. This is prior to setting the casing on slips and cutting the casing sticking up. These lines control firing of the perforating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. A similar waiver was requested for an offset well on this pad BC #11 on 1/15/2003 and was granted. No problems were .//' encountered while doing this operation on the above well this year. Page 11 of 12 ) ) Hvdraulics Summary Rig mud pumps available are shown below. Max Press @ Displacement @ Liner 10 Stroke 90% WP 95% eff Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On 5 8 2,597 2.04 175/357 Surface National Oil 3 A600PT 5 8 2,597 2.04 175/357 Intermediate Well 5 8 2,597 2.04 175/357 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hole Standpipe Min Nozzle Depth-MD Size Pump Rate Pressure AV ECD Size (ft) (in) (gpm) (psi) (fpm) (lb/gal) (32"s) Remarks 1 -12 o - 2,300 17.5 550 1,900 48 1 - 14 Actual Data from BC #11 2 -16's 2,300 - 7,270 12.25 545 2,000 107 3 - 22's Actual Data from BC #11 1 -15 7,270 - 10,496 8.5 436 2,000 226 3 - 20's Actual Data from BC #11 Comments: See separate hydraulics calculations. Formation Integritv Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 12 of 12 121 1/4" 2M Diverter I ~ I Diverter Spool ) ~ I I " ~ Marathon Oil Well BC-13 Diverter ) Flow line ~ I I / 116" Automatic Knife Valve 0/- / 1/' / " / I I " \ " I I í \ '--~ " 116" Diverter Line < I /1 ÞI IChoke (JŒI[1 X I t ) Marathon Oil Well BC-13 BOP Stack Flow Nipple - />- 13 5/8" 5M Annular Preventer . '> / 1 1 1 1 > < 13 5/8" 5M Double Ram Preventer I ~ I Pipe Ram I Blind Ram 21/16" 5M Check Valve 2 1/16" 5M Manually \ Operated Valves 1 > ~~ I, r IIXIIXIJŒillJ 1135/8"5MCross I ~::\ "- I I ( ) IFlow Line I I / // / 3 1/8" 5M Hydraulically Operated Valve 3 1/8" 5M Manually Operated Valve ) Marathon Oil Well BC-13 /" Choke Manifold ) IT 0 Gas Buster To Blooey Line Bleed off Line to Shakers I I I I ~ ~ ø I I I I I I I, I , I , I I ~J ~ t [ OJ { 'I I I (=1, ~ ø L ]@[J®[ 0 J®[J0L 'I I I ø I I I I "----J [~ ~ I , I I I I \.....--....I , I I I I \-1 r----\ I I ø I I I I r--'1 ~ '-----l 13" 5M Valves i 2 9/16" 10M Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke ~ IFrom BOP Stack ) ) Surface Use Plan for Beaver Creek #13 Surface location: Anticipated at 1,309.9' FNL, 1,479.5' FWL, Sec. 34, T7N, R10W, S.M. 1) Existi ng Roads Existing roads which will be used for access to Beaver Creek #13 are shown on the attached map. Kenai, Alaska is the nearest town to the site and is also shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access Beaver Creek #13. 3) Location of existing wells Well BC-13 will be drilled on pad BC 3. A pad drawing is enclosed that shows existing wells and the proposed location of BC-13. 4) Location of existing and/or proposed facilities The locations of existing production facilities are shown on the enclosed pad drawing. These facilities will be upgraded to handle the additional gas production. 5) Location of Water Supply A water supply well exists on the pad that Beaver Creek #13 will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. If the pad requires minor leveling, the sand and gravel will be obtained from the approved gravel pit in the SW/4, NE/4, Sec. 5 T6N, R10W, S.M. Other materials will be obtained from various vendors and suppliers in Alaska. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be injected into approved disposal wells Beaver Creek # 2 (Alaska Oil and Gas Conservation Commission Disposal Injection Order No.4) or hauled to Pad 34- 31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). ) ) d) Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Sand R will collect and transport sanitary wastes to their ADEC approved disposal facility. 9) Plans for reclamation of the surface Beaver Creek #13 will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of Beaver Creek #13 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Beaver Creek Unit is the U.S. Fish and Wildlife Service. The minerals are under the jurisdiction of the U.S. Bureau of Land Management. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: "ð /1'-110 :3 Name and Title: .y~~ Willard J: ~ank, se¡¡fo~ Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6319 o o Ó o en <D ;;:; x + + o N 85ï7'10w W X=316.217.57 Y=2.434,004.64 + Y 2,434,200.00 ..... Y 2.433.800.00 796.11' ') o X=317.010.97 Y= 2,433. 938. 95 24' ACCESS ROAD ") ) ,... I I I ( I I I I I I I I I I TOE OF BERM I I PAD LIMITS . \/ I I I I I I I I I I I I I I I I I ~--.......-- o o Ó o LO r: ;;:; x :9 ------- - - -- -...... ............ .................. .................. .............................. ...... ...... ........... ..... ..... '\ " " " "- " "- "- "- I I I I I I I I I I I I I I I I I I I I I / + I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I / / / / / / + "'-.. .~ £DGE PAD I J OPERATIONS AREA B.C.U. NO. 10 wi 8w CMP X=317,355.76 Y=2,434,097.30 @) B.C.U. NO. 11 8' ø CSP X=317.294.56 Y=2,434,069.90 @) C.P. #1 X-317,489.05 Y=2,434,064.92 ELEV.=168.20' C.P. #2 X=317.174.00 Y=2.434.038.87 I ELEV.-163.92' I I / / / I 1.8' X 1.9' METER BO I / -----.....3.0· x 4.0' + CONCRETE PAD WI CONTROL PANEL 6.1' x 5.0' B.C.U. NO. 6 00 ME1HANOL TANK 14.5' SILO 0 X-317.305.34 Y=2,434,023.22 HEATER ¡(15.1' x 2.6' SKID) 4" GUARD 1:1 ~PIPE o t::J.......... 3.8' x 5.3' -./ ~ FIRE EXTINGUISHER , BUILDING ""- 3" GUARD PIPE O 8.C.U. NO. 9 o 14.5' SILO X-317,379.72 o Y-2,434,004.02 6.1' x 5.0' METHANOL TANK +8 CHEM?è~'L ;;N~ 0 8.C.U. NO. 5 14.5' SILO X=317,312.59 Y=2,433.991.43 ~. 8.,<' 13.C.U. NO. 3 lb' 0 X=317.318.08 o '(-2.433,959.65 " "- "- "- "- '\ \ I \ \ \ I I ) I I I I I I I I I I I I I I I I I I I ..... ..... "- ..... '-------------- ......-..............-........-........ TOE OF BERM I J................. PAD LI"'TS --______________ 4 1 \2W GUARD POST '\ ~ 3w GUARD j/ PIPE f;;;--:.. ~~~T~BL NO. 9T-P~O' WATER TANK :9 .... ** fl7ì:'1Jj" ~.7' ° g~~~D x:x tJ x:x /v. : flo ° o .... èo ffO' 6~PAK ~~. ~~ÅT~kINE 8.6 NO. 9 LINE HEA TER ~ T-PAKS o B.C.U. NO. 13 ASP ZONE 4 NAD27 GRID N: 2,433,891.50 GRID E: 317,286.14 LATITUDE: 60·39'29.225" N LONGITUDE: 151·01'06.366" W 1,309.9' FNL, 1,479.5' FWL SECTION 34, T7N, R10W, S.M. + + & -. ) Q 27 29 II ~\)~ ~ 9 10 V1CINITY MAP 1· - 2 MILES SCALE: 1" = 6(1 fl LEGEND tie GLOIBLM MONUMENT FOUND THIS SURVEY 0 : FOUND r REBAR wi ALCAP . SET r REBAR WI ALCAP ~ FOUND SURVEY MONUMENT OF RECORD -() POWER POLE :¢: LIGHT POLE @ . EXISTING WELL CHRISTMAS TREE e MONITOR WELL Þ<I , VALVE -0 PIPING CONTINUES UNDERGROUND ~ ' ELECTRICAL JUNCTION BOX ~ 8. SEPTIC VENT fl NOTES ~ !J ~ 1. ELEVATIONS AT THE TOP OF PIPES FOR MONITORING WELLS TAKEN WITH COVER OFF OR OPEN. 2. REFERENCE DATUM IS NAVD 88 FOR ELEVATIONS SHOWN BASED ON NGS MONUMENT D 81. 3. ALL BEARINGS ARE GRID UNLESS NOTED OTHERWISE. 4. BASIS OF COORDINATES IS CONTINUOUSLY OPERATING REFERENCE STATION KEN 1, IN A.S.P. ZONE 4. (NAD 27) 5. KEN 1 LOCATION: . LA T: 60·40'32.315"N LONG: 151 ·20'52.519"W X == 258,310.40 Y == 2,441,360.73 ABBREVIA TION'3: a.llE. = OVERHEAD ELECTRIC O.H. P /W = OVERHEAD PIPEWA Y .~ ¿; c ,'........""11 _......';.~ OF Ai.~!" ,: t¡'t- -Ib.-r:.,", =* 49IHJ'Ii *~ ... .. ~ .. ~ ~ ... SOOTT IId.ANEz E I~ - "'~ 48211-5 "'" ~ f f ('/""£",~ ~ ,...... I',,,........" 28 )0- m :::E 3 o 11 i!5 ~ É Ii: 5 en w Q ww ~~ ~~ 5~ ä!a:: ........ r5r5 aa ~ Q ~~ ~:;;: C'I~ ë:i a:: C'I... )-C") ZQ CCCC a. a. :Ern OCC Uc:J :!~ OW ZW 03 :l:g: ...w ~~ CCw :Em ~I~· ~ ~ 10 <D ~ Õ c:i z > ~ w ~ ~ ::) ~ en c:i I- Z ... ~ - m ::) ~ a:I ¡¡: . en c( Q c( a. ~ 2 a) ~ C'I I ¡ ~ ~ Q 111 c.. \0 ::1 N ~ [I !... [I \J' IiJ'I ~ IiJ'I s:: S:::P ~ ~ ~ ~ ~ c s:: 11. .J ~ m ~ \.) - !~~ ; m \) ~ o 2' (]'I a: ~ I- (]'I \0 \0 (]'I (]'I ~ <{ ò Ò <D <0 :::E a ~ ~ 3 :::E ):. ~ g ):. m < Õ m S 0 0 en en i Š N ¡.; ~ < a:: II:: a:: 0 0 ~ :x: CI J: en . : PROPOSEQ LOCAT10N ÞO'R\ BCU is I Q·N- PAD 3 . t - .) AT~ BEAVER CREEK PRODUCTION FACILITY IN: PAD 3 KENAI PENINSULA BOUROUGH. AK. . A·PPLlCA TION BY: MARATHON OIL COMPA.NY . .' MARÁ THÖ~Oll: t:OMP.ANY P.O. BO'X 18:0 16.8 . ANCHO·RAGE;AK. 9951'9 J:(EN'Å" NAT10NAL WILDLIFE R~FUG'E P'LAN VIE:W . . 0 . . 1000 2000 I - 0--_ .' I SCALE 'N '~EET .' PURPOSE: DRILL & COMPLETE BCU 13 ADJACENT PRO'PERTY OWNER.S PAD 7 PAD 3 1A Marathon 011 C~mø.ny Ao.d .., \. ""Q"'~.Y--- \),c n . .' ~ -;' .~ - SEC. 3 o . ~<?U 7 " BC.u 2 ~Q r PAD 2 . J ,} . . " . " " .' BEAVER LAk'e SEC. 34 ~ ",' SE~.. 33 ~ '-----, ~~-) (. I .~~ .. .. . . ~ .' ¡.: f2<Ç" 'BCU 10 ,. . ~/' ..::~'" 11.";'" ;".. . BC·U ...._. va . . II . ~.~ BCU SCCÞotIL--nÖ . . B 8 , !~ ~ ~ CU 6 """--....... Be U 3 " BCU 4 0 -- PR.oDUCT~ON P.AD N Dr11l81t& (" . I . ~ I ~ . \ 'J.,. 8000 - '- ....-"! '~_.~ ·SCAJ.,E IN FEET ·Ó. . S·EC 34 T7N R 10W 8M VICINITY MAp. , . . ,. ~:) J ) ~ ~I\, . '/ ~.,rt 1 _ ''2-;! Æ, í'" ~:Í ~ o & .,~ .........;~ .:p~ ", ¡ . /ii:. 1- '~ ~): .</ i .: {. '..... -...,. ~~ ·0 ~, I ~l ¡ " th~,} " ~~'.þý- ~ MilES I 15000 18000 21000 fEET --1--~ 4 '5 KILOMETERS . 1 60 2' 9000 .12000 - ...--. - ·2 3 ~_J__o 3000 0 3000 ......--.....-- ---. I .5. 0 ..... ..... ..... ~ Þ-I .' ~ALASKA . , 1.. - , ..... .. .. .....n.,.... ~ QUADRANGLE LOCATION . CONTOUR INTERVAL 50 FEET DOTTED UHES R£I'RfSEHT is·FOOT CONtouRS NATIONAL Gmomc 'VERTICAL" DATUM OF' li~ .. ýZG~ k.y S' 24' ïïiiül ...·.,LÌ rf' T. 1".6 N. 13 T. 1. Topography by photogramme'trlc methods from aerial photographs taken 1950. cuture revised In part from aerral photographs Field annotated 1980. Map not field checked Projection and lODO-meter grId ticks: Universal Transverse Mercator, zone 4 lO,ODO-foot grid tIcks based on Alaska coordinate system, lone 5: .1927 North AmerIcan datum Gray land lines represent unsúrveyed and unmarked locations "p'redetermin~~ by the Bureau of Land Management ' Folio s- 16, Seward Meridian . FOR SALE BY U. S. GEOLÓGICAL SVRVEV FAIRBANKS; ALASKA 99701, DENVER, COLORADO 80225, OR RESTON, VIRGINIA Z20SZ A FOLDER DESCRIBING '¡'OPOG~HIC' MAPS AND SYMBOLS IS AVAILABLe' ON REQUEST UTM GRID AND 111I0 MACNmc NORTH DECLINATiON AT"C£NTER Of SHUT Swamps, as portrayed. Indicate only the wetter areas, 'usually of low relief, as interpreted from aerial photographs To place on the predicted NQrth American Datum 1983 move the projection lines 67 meters north ~nd .121 meters east There may be private Inho/dlngs within the boundarIes ot th.. N"tinn,, or State reservations shown on this map \ BCD 13 2003 DEVELOPMENT. WELL ( 13"-r I.J..:.I ; )::(;-1...· I' " -~ I w.... . .......... PIT .- · -,-. . ¡'\. , ... ) MilT... 0 ... I ";ë'1 1 Of" ,1&1: I I· I I :!€ I ¡....: I ,x' I 5V 9l. 5V CJl. ~~ I I A-6OO PT A-6QD PT :1:' I ;~ . I I 751f1 c I 1: I 6 ~ ~ ~ I - ! - 11- ' . ' I '-": ~ .JL I .. \ ~. ..t , I ~ 1 I i · -. __t. i _I ~ ~ .. . · I . .., T .... ,- . I g11ll J 751P ' 75 HP 6X5 '6 X :5 i 11- U- 4_ ~ 2 ... , ~i ~ I ... .. . ~ .. ~- \.... ~e~ GLACIER DRilLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT ~ ·-c ( . ...... ... .... '\ JIEaUEI ,¡ '," ,... ( . . . ----. 75HP 6X5 u- : :...2 I ICDDMY ~ X 12· r I 1 I L_____.___ I I I I I I J i I f _ t ,,- ..... , , ',PŒIŒJV' CIII::'~A~ I, I I , ~ I ....-- I , -" -- ~-----i ~-----~t r ' , L__.J U J f 1 , I I r--' n I r. I IJ I I I II I. I.l 11 I. 1,1 ill ! I... t J II t I' '. I I t tl J ¡I. I I· II 1 t I h . I I II L____..J L.__ ___ It r--------, -. . ...'" ..." 1 1 L.. I \..1 _""" I ! j r-----' I I ¡ I ŒNTRIFU6E) I IMT I I 4' X 10" I I I I I I I I I I DlI4P I ¡ -\ I t t ~ I I ".... . '-_.____J 14..... r-cr ) ) Creoted by jone9 For: W Tank MARATHON Oil Company Dato platted: 13-Aug-2003 Plat Referenco is BC- 1 3 Vers. 113. Coordinates ore in foet refcranco slot 1/13. True VGrtic;ol Depths ore refereJ'ncc RKB (Glaclcr 1). r~íill BAKER HUGHES INTEQ Structure: Pad #3 Well BC-13 M MARATHON Field Beaver Creek Unit Location Kenai Peninsula, Alaska East (feet) -> 200 o 200 400 500 800 1000 1200 1400 1500 200 600 - 3000 - Ll 13 3/8 Casing 2.50 KOP 7.50 12.50 DLS: 2.50 17.50 22.50 End of Build - 0 132.52 AZIMUTH - 200 1629' (TO TARGET) /(f U1 ~ô 0 - 400 c ***Plane of Proposal*** ~ -+ ~<' ::r- "...--.... - 500 ~ ([) ([) cr -+ "---'" - 800 I V TRUE Casing_1000 deg per 100 It - 1200 - 1400 o !Estm'd RKB: 179' 600 - 1200 - 1800 - 2400 - r-.... +- (I) (I) '+- "---'" 3600 - ..c õ... 4200- (I) o TANGENT ANGLE 26.74 DEG o ü 4800 End of Hold 26.00 24.00 5400 - 22.00 20.00 PROF~LE COMMENT DATA 18.00 ---- ---- 6000 - DLS: 1.00 deg per 100 It 16.00 14.00 12.00 ----- Poinl MD Inc Dir TVD North Easl V. Sect Deg/100 6600 - 10.00 5/6 Casing 8.00 13 3/8 Casing 2300.00 0.00 132.52 2300.00 0.00 0.00 0.00 0.00 9 6.00 7200 - 4.00 KOP 2500.00 0.00 132.52 2500.00 0.00 0.00 0.00 0.00 2.00 End of Drop ___ Top/L Belugo LB-23 End of Build 3569.60 26.74 132.52 3531.19 - 165.65 180.64 245.09 / 2.50 7800 - End of Hold 5282.62 26.74 132.52 5061.02 - 686.58 748.72 1015.86 0.00 8400 - ---0- Top/L Beluga LB-30 9 5/8 Cosing 7269.98 6.87 1 32.52 6954.00 -1072_93 1170_03 15B7.50 1.00 End of Drop 7956.58 0.00 90.00 7638.96 - 11 00.70 1200.32 1628.59 1.00 9000 - Top/L Beluga LB-23 7956.60 0.00 90.00 7638.98 - 11 00.70 1200.32 162B.59 1.00 - TARGET ANGLE T yonek T2 I 9600 - 0.00 DEG Top/L Beluga LB-30 8663.62 0.00 270.00 8346.00 - , 100.70 1200.32 1528.59 0.00 I Tyonek 12 9706.62 0.00 270.00 9389.00 -1100.70 1200.32 1628.59 0.00 I 10200 - .3 1/2 Li ner Ll T.D. [3 1/2 Liner 10496.60 0.00 270.00 10178.98 -1100.70 1200.32 1528.59 0.00 600 0 600 1200 1800 ~___.__.__.____1Q496.6~ I 0.00 270.00 10179.00 -1100.70 - 1200.32 1528.59 0.00 i +- L (I) > (I) ::Ji L r- ~ V Vertical Section (feet) - > Azimuth 132.52 with reference 0.00 N. 0.00 E from slot #'3 ) ) MARATHON Oil Company Pad #3 BC-13 slot #13 Beaver Creek Unit Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License BC-13 Verso #3 prop5504 Date printed Date created Last revised 13-Aug-2003 23-Jul-2003 13-Aug-2003 Field is centred on n60 38 50.050,w150 59 49.92 Structure is centred on n60 38 50.050,w150 59 49.92 Slot location is n60 39 29.240,w151 1 6.309 Slot Grid coordinates are N 2433893.000, E 317289.000 Slot local coordinates are 3980.23 N 3807.35 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company PROPOSAL LISTING Page 1 Pad #3, BC-13 Your ref BC -13 Verso #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13 -Aug-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 o R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 132.52 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 132.52 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 132.52 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 132.52 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 132.52 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 132.52 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 132.52 700.00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 132.52 800.00 0.00 N 0.00 E 0.00 0.00 ) ) 900.00 0.00 132.52 900.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 132.52 1000.00 0.00 N 0.00 E 0.00 0.00 1100.00 0.00 132.52 1100.00 0.00 N 0.00 E 0.00 0.00 1200.00 0.00 132.52 1200.00 0.00 N 0.00 E 0.00 0.00 1300.00 0.00 132.52 1300.00 0.00 N 0.00 E 0.00 0.00 1400.00 0.00 132.52 1400.00 0.00 N 0.00 E 0.00 0.00 1500.00 0.00 132.52 1500.00 0.00 N 0.00 E 0.00 0.00 1600.00 0.00 132.52 1600.00 0.00 N 0.00 E 0.00 0.00 1700.00 0.00 132.52 1700.00 0.00 N 0.00 E 0.00 0.00 1800.00 0.00 132.52 1800.00 0.00 N 0.00 E 0.00 0.00 1900.00 0.00 132.52 1900.00 0.00 N 0.00 E 0.00 0.00 2000.00 0.00 132.52 2000.00 0.00 N 0.00 E 0.00 0.00 2100.00 0.00 132.52 2100.00 0.00 N 0.00 E 0.00 0.00 2200.00 0.00 132.52 2200.00 0.00 N 0.00 E 0.00 0.00 2300.00 0.00 132.52 2300.00 0.00 N 0.00 E 0.00 0.00 13 3/8" Casing 2400.00 0.00 132.52 2400.00 0.00 N 0.00 E 0.00 0.00 2500.00 0.00 132.52 2500.00 0.00 N 0.00 E 0.00 0.00 KOP 2600.00 2.50 132.52 2599.97 1. 47 S 1. 61 E 2.50 2.18 2700.00 5.00 132.52 2699.75 5.89 S 6.43 E 2.50 8.72 2800.00 7.50 132.52 2799.14 13.25 S 14.45 E 2.50 19.61 2900.00 10.00 132.52 2897.97 23.53 S 25.66 E 2.50 34.82 3000.00 12.50 132.52 2996.04 36.72 S 40.04 E 2.50 54.33 3100.00 15.00 132.52 3093.17 52.78 S 57.56 E 2.50 78.09 3200.00 17.50 132.52 3189.17 71.69 S 78.18 E 2.50 106.07 3300.00 20.00 132.52 3283.85 93.41 S 101.87 E 2.50 138.21 3400.00 22.50 132.52 3377.05 11 7.91 S 128.58 E 2.50 174.46 3500.00 25.00 132.52 3468.57 145.13 S 158.26 E 2.50 214.73 3569.60 26.74 132.52 3531.19 165.65 S 180.64 E 2.50 245.09 End of Build 4000.00 26.74 132.52 3915.56 296.53 S 323.37 E 0.00 438.75 4500.00 26.74 132.52 4362.09 448.58 S 489.18 E 0.00 663.72 5000.00 26.74 132.52 4808.62 600.63 S 654.99 E 0.00 888.69 5282.62 26.74 132.52 5061.02 686.58 S 748.72 E 0.00 1015.86 End of Hold 5356.62 26.00 132.52 5127.32 708.79 S 772 . 94 E 1. 00 1048.72 5456.62 25.00 132.52 5217.58 737.89 S 804.67 E 1. 00 1091. 77 5556.62 24.00 132.52 5308.57 765.91 S 835.23 E 1. 00 1133.24 5656.62 23.00 132.52 5400.28 792.86 S 864.62 E 1. 00 1173.12 5756.62 22.00 132.52 5492.66 818.73 S 892.83 E 1. 00 1211. 39 5856.62 21.00 132.52 5585.70 843.50 S 919.84 E 1. 00 1248.03 5956.62 20.00 132.52 5679.37 867.17 S 945.65 E 1. 00 1283.06 6056.62 19.00 132.52 5773.63 889.73 S 970.25 E 1. 00 1316.44 6156.62 18.00 132.52 5868.46 911.17 S 993.64 E 1. 00 1348.17 All data is in feet unless otherwise stated. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Bottom hole distance is 1628.59 on azimuth 132.52 degrees from wellhead. Total Dogleg for wellpath is 53.48 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company PROPOSAL LISTING Page 2 Pad #3,BC-13 Your ref BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13 -Aug-2003 Measured Inclin. Azimuth True Vert R E C T AN G U L A R Dogleg Vert Depth Degrees Degrees Depth C o 0 R D I N ATE S Deg/100ft Sect 6256.62 17.00 132.52 5963.83 931. 49 S 1015.80 E 1. 00 1378.24 6356.62 16.00 132.52 6059.71 950.69 S 1036.73 E 1. 00 1406.64 6456.62 15.00 132.52 6156.08 968.75 S 1056.43 E 1. 00 1433.36 6556.62 14.00 132.52 6252.89 985.67 S 1074.88 E 1. 00 1458.40 6656.62 13.00 132.52 6350.13 1001. 45 S 1092.09 E 1. 00 1481.74 6756.62 12.00 132.52 6447.75 1016.08 S 1108.04 E 1. 00 1503.39 6856.62 11.00 132.52 6545.74 1029.55 S 1122.73 E 1. 00 1523.32 6956.62 10.00 132.52 6644.07 1041.87 S 1136.17 E 1. 00 1541.55 7056.62 9.00 132.52 6742.70 1053.02 S 1148.33 E 1. 00 1558.05 7156.62 8.00 132.52 6841.60 1063.01 S 1159.22 E 1. 00 1572.83 7256.62 7.00 132.52 6940.74 1071.84 S 1168.84 E 1. 00 1585.88 7269.98 6.87 132.52 6954.00 1072.93 S 1170.03 E 1. 00 1587.50 9 5/8" Casing 7356.62 6.00 132.52 7040.10 1079.49 S 11 77.19 E 1. 00 1597.20 7456.62 5.00 132.52 7139.63 1085.96 S 1184.25 E 1. 00 1606.79 7556.62 4.00 132.52 7239.32 1091.27 S 1190.03 E 1. 00 1614.63 7656.62 3.00 132.52 7339.14 1095.39 S 1194.53 E 1. 00 1620.74 7756.62 2.00 132.52 7439.04 1098.34 S 1197.75 E 1. 00 1625.10 7856.62 1. 00 132.51 7539.01 1100.11 S 1199.68 E 1. 00 1627.72 7956.58 0.00 90.00 7638.96 1100.70 S 1200.32 E 1. 00 1628.59 End of Drop ") ) 7956.60 0.00 90.00 7638.98 1100.70 8 1200.32 E 1. 00 1628.59 Top/L Beluga LB-23 7956.62 0.00 132.52 7639.00 1100.70 8 1200.32 E 1. 00 1628.59 BC13 Top/L Beluga L23 08/06/03 8000.00 0.00 270.00 7682.38 1100.70 8 1200.32 E 0.00 1628.59 8100.00 0.00 270.00 7782.38 1100.70 8 1200.32 E 0.00 1628.59 8200.00 0.00 270.00 7882.38 1100.70 8 1200.32 E 0.00 1628.59 8300.00 0.00 270.00 7982.38 1100.70 8 1200.32 E 0.00 1628.59 8400.00 0.00 270.00 8082.38 1100.70 8 1200.32 E 0.00 1628.59 8500.00 0.00 270.00 8182.38 1100.70 8 1200.32 E 0.00 1628.59 8600.00 0.00 270.00 8282.38 1100.70 8 1200.32 E 0.00 1628.59 8663.62 0.00 270.00 8346.00 1100.70 8 1200.32 E 0.00 1628.59 BC13 Top/L BelugaL30 08/06/03 9000.00 0.00 270.00 8682.38 1100.70 8 1200.32 E 0.00 1628.59 9500.00 0.00 270.00 9182.38 1100.70 8 1200.32 E 0.00 1628.59 9706.62 0.00 270.00 9389.00 1100.70 8 1200.32 E 0.00 1628.59 Tyonek T2 10000.00 0.00 270.00 9682.38 1100.70 8 1200.32 E 0.00 1628.59 /10496.60 0.00 270.00 10178.98 1100.70 8 1200.32 E 0.00 1628.59 3 1/2" Liner 10496.62 0.00 270.00 10179.00 1100.70 8 1200.32 E 0.00 1628.59 BCD TD Revised 13 -Aug-03 All data is in feet unless otherwise stated. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1628.59 on azimuth 132.52 degrees from wellhead. Total Dogleg for wellpath is 53.48 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska PROPOSAL LI8TING Page 3 Your ref BC-13 Verso #3 Last revised : 13-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 2300.00 2300.00 0.00 N 0.00 E 13 3/8" Casing 2500.00 2500.00 0.00 N 0.00 E KOP 3569.60 3531.19 165.65 8 180.64 E End of Build 5282.62 5061. 02 686.58 8 748.72 E End of Hold 7269.98 6954.00 1072.93 8 1170.03 E 9 5/8" Casing 7956.58 7638.96 1100.70 8 1200.32 E End of Drop 7956.60 7638.98 1100.70 8 1200.32 E Top/L Beluga LB-23 7956.62 7639.00 1100.70 8 1200.32 E BCD Top/L Beluga L23 08/06/03 8663.62 8346.00 1100.70 8 1200.32 E BCD Top/L BelugaL30 08/06/03 9706.62 9389.00 1100.70 8 1200.32 E Tyonek T2 10496.60 10178.98 1100.70 8 1200.32 E 3 1/2" Liner 10496.62 10179.00 1100.70 8 1200.32 E BCD TD Revised 13 -Aug-03 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 10496.62 10179.00 1100.708 1200.32E 3 1/2 Liner 0.00 0.00 O.OON O.OOE 7269.98 6954.00 1072.938 11 70. 03E 9 5/8 Casing 0.00 0.00 O.OON O.OOE 2300.00 2300.00 O.OON O.OOE 13 3/8 Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- BC13 Top/L Beluga L2 BC13 Top/L BelugaL30 BC13 TD Revised 13-A Tyonek T2 13-Aug-03 7639.00 8346.00 10179.00 9389.00 1100.708 1100.708 1100.708 1100.708 1200.32E 1200.32E 1200.32E 1200.32E 6-Aug-2003 6-Aug-2003 6-Aug-2003 13-Aug-2003 -, ) MARATHON Oil Company Pad #3 BC-13 slot #13 Beaver Creek Unit Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License BC-13 Verso #3 propSS04 Date printed Date created Last revised 13-Aug-2003 23-Jul-2003 13-Aug-2003 Field is centred on n60 38 SO.050,w150 59 49.92 Structure is centred on n60 38 50.050,w150 59 49.92 Slot location is n60 39 29.240,w151 1 6.309 Slot Grid coordinates are N 2433893.000, E 317289.000 Slot local coordinates are 3980.23 N 3807.35 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company PROPOSAL LISTING Page 1 Pad #3,BC-13 Your ref BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13 -Aug-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth C o 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 317289.00 2433893.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3569.60 4000.00 4500.00 5000.00 5282.62 5356.62 5456.62 5556.62 5656.62 5756.62 5856.62 5956.62 6056.62 6156.62 0.00 2.50 5.00 7.50 10.00 12.50 15.00 17.50 20.00 22.50 25.00 26.74 26.74 26.74 26.74 26.74 26.00 25.00 24.00 23.00 22.00 21.00 20.00 19.00 18.00 0.00 0.00 0.00 0.00 132.52 132.52 132.52 132.52 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2599.97 2699.75 2799.14 2897.97 2996.04 3093.17 3189.17 3283.85 3377.05 3468.57 3531.19 3915.56 4362.09 4808.62 5061.02 5127.32 5217.58 5308.57 5400.28 5492.66 5585.70 5679.37 5773.63 5868.46 ) O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON O.OON 1.478 5.898 13.258 23.538 36.728 52.788 71.698 93.418 117.918 145.138 165.658 296 .538 448.588 600.638 686.588 708.798 737.898 765.918 792.868 818.738 843.508 867.178 889.738 911.178 O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE O.OOE 1.61E 6.43E 14.45E 25.66E 40.04E 57.56E 78.18E 101. 87E 128.58E 158.26E 180.64E 323.37E 489.18E 654.99E 748.72E 772.94E 804.67E 835.23E 864.62E 892.83E 919.84E 945.65E 970.25E 993.64E 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.50 2.50 2.50 2.50 0.00 2.18 8.72 19.61 34.82 ) 0.00 0.00 0.00 0.00 317289.00 317289.00 317289.00 317289.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433893.00 2433891.50 2433887.01 2433879.53 2433869.08 2433855.68 2433839.36 2433820.14 2433798.06 2433773.16 2433745.50 2433724.64 2433591.61 2433437.08 2433282.54 2433195.19 2433172.61 2433143.04 2433114.55 2433087.16 2433060.88 2433035.70 2433011.64 2432988.71 2432966.92 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1628.59 on azimuth 132.52 degrees from wellhead. Total Dogleg for wellpath is 53.48 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.00 0.00 0.00 0.00 0.00 132.52 132.52 132.52 132.52 132.52 MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska 0.00 0.00 0.00 0.00 0.00 132.52 132.52 132.52 132.52 132.52 0.00 0.00 0.00 0.00 0.00 132.52 132.52 132.52 132.52 132.52 0.00 0.00 0.00 0.00 0.00 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 132.52 Measured Inclin Depth Degrees 6256.62 6356.62 6456.62 6556.62 6656.62 6756.62 6856.62 6956.62 7056.62 7156.62 7256.62 Azimuth Degrees 17.00 16.00 15.00 14.00 13.00 132.52 132.52 132.52 132.52 132.52 12.00 11.00 10.00 9.00 8.00 132.52 132.52 132.52 132.52 132.52 7.00 132.52 True Vert Depth 5963.83 6059.71 6156.08 6252.89 6350.13 6447.75 6545.74 6644.07 6742.70 6841.60 6940.74 R E C TAN G U L A R COO R DIN ATE 8 931.498 950.698 968.755 985.678 1001.458 1016.088 1029.558 1041.875 1053.025 1063.018 1071. 848 1015.80E 1036.73E 1056.43E 1074.88E 1092.09E 1108.04E 1122.73E 1136.17E 1148.33E 1159.22E 1168.84E 2.50 2.50 2.50 2.50 2.50 54.33 78.09 106.07 138.21 174.46 0.00 0.00 0.00 0.00 0.00 317289.00 317289.00 317289.00 317289.00 317289.00 PROP08AL LI8TING Page 2 Your ref BC-13 Verso #3 Last revised : 13-Aug-2003 Dogleg Deg/100ft 2.50 2.50 0.00 0.00 0.00 214.73 245.09 438.75 663.72 888.69 0.00 1. 00 1. 00 1. 00 1. 00 1015.86 1048.72 1091.77 1133.24 11 73.12 1. 00 1. 00 1. 00 1. 00 1. 00 1211.39 1248.03 1283.06 1316.44 1348.17 1. 00 1. 00 1. 00 1. 00 1. 00 1378.24 1406.64 1433.36 1458.40 1481.74 1. 00 1. 00 1. 00 1. 00 1. 00 1503.39 1523.32 1541.55 1558.05 1572.83 1. 00 1585.88 0.00 0.00 0.00 0.00 0.00 317289.00 317289.00 317289.00 317289.00 317289.00 0.00 0.00 0.00 0.00 0.00 317289.00 317289.00 317289.00 317289.00 317289.00 0.00 0.00 0.00 0.00 0.00 317289.00 317289.00 317289.00 317289.00 317289.00 317289.00 317290.58 317295.34 317303.25 317314.30 317328.48 317345.75 317366.08 317389.43 317415.77 317445.03 317467.10 317607.82 317771.29 317934.76 318027.17 318051.05 318082.33 318112.47 318141.44 318169.25 318195.88 318221.33 318245.58 318268.64 Vert 8ect G RID Easting 318290.49 318311.13 318330.55 318348.74 318365.70 318381.43 318395.92 318409.16 318421.15 318431.89 318441.38 COO R D 8 Northing 2432946.26 2432926.75 2432908.40 2432891.20 2432875.16 2432860.29 2432846.60 2432834.08 2432822.74 2432812.59 2432803.63 ., 7269.98 6.87 132.52 6954.00 1072.938 11 70. 03E 1. 00 1587.50 318442.55 2432802.52 7356.62 6.00 132.52 7040.10 1079.498 1177.19E 1. 00 1597.20 318449.60 2432795.85 7456.62 5.00 132.52 7139.63 1085.968 1184.25E 1. 00 1606.79 318456.57 2432789.27 7556.62 4.00 132.52 7239.32 1091. 278 1190.03E 1. 00 1614.63 318462.27 2432783.88 7656.62 3.00 132.52 7339.14 1095.398 1194.53E 1. 00 1620.74 318466.70 2432779.68 7756.62 2.00 132.52 7439.04 1098.348 1197.75E 1. 00 1625.10 318469.87 2432776.69 7856.62 1. 00 132.51 7539.01 1100.118 1199.68E 1. 00 1627.72 318471.78 2432774.89 7956.58 0.00 90.00 7638.96 1100.708 1200.32E 1. 00 1628.59 318472 .41 2432774.29 7956.60 0.00 90.00 7638.98 1100.708 1200.32E 1. 00 1628.59 318472.41 2432774.29 7956.62 0.00 132.52 7639.00 1100.708 1200.32E 1. 00 1628.59 318472 .41 2432774.29 8000.00 0.00 270.00 7682.38 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 8100.00 0.00 270.00 7782.38 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 8200.00 0.00 270.00 7882.38 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 8300.00 0.00 270.00 7982.38 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 8400.00 0.00 270.00 8082.38 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 8500.00 0.00 270.00 8182.38 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 8600.00 0.00 270.00 8282.38 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 8663.62 0.00 270.00 8346.00 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 9000.00 0.00 270.00 8682.38 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 9500.00 0.00 270.00 9182.38 1100.708 1200.32E 0.00 1628.59 318472.41 2432774.29 9706.62 0.00 270.00 9389.00 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 10000.00 0.00 270.00 9682.38 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 10496.60 0.00 270.00 10178.98 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 10496.62 0.00 270.00 10179.00 1100.708 1200.32E 0.00 1628.59 318472 .41 2432774.29 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Bottom hole distance is 1628.59 on azimuth 132.52 degrees from wellhead. Total Dogleg for wellpath is 53.48 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska PROP08AL LI8TING Page 3 Your ref BC-13 Verso #3 Last revised : 13-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 2300.00 2300.00 O.OON O.OOE 13 3/8" Casing 2500.00 2500.00 O.OON O.OOE KOP 3569.60 3531.19 165.658 180.64E End of Build 5282.62 5061.02 686.588 748.72E End of Hold 7269.98 6954.00 1072.938 1170.03E 9 5/8" Casing 7956.58 7638.96 1100.708 1200.32E End of Drop 7956.60 7638.98 1100.708 1200.32E Top/L Beluga LB-23 7956.62 7639.00 1100.708 1200.32E BC13 Top/L Beluga L23 08/06/03 8663.62 8346.00 1100.708 1200.32E BC13 Top/L BelugaL30 08/06/03 9706.62 9389.00 1100.708 1200.32E Tyonek T2 10496.60 10178.98 1100.708 1200.32E 3 1/2" Liner 10496.62 10179.00 1100.708 1200.32E BC13 TD Revised 13-Aug-03 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 10496.62 10179.00 O.OOE 7269.98 6954.00 O.OOE 2300.00 2300.00 1100.708 1072.938 O.OON 1200.32E 1170.03E O.OOE 3 1/2 Liner 9 5/8 Casing 13 3/8 Casing 6-Aug-2003 6-Aug-2003 6-Aug-2003 13-Aug-2003 1200.32E 1200.32E 1200.32E 1200.32E 1100.70S 1100.70S 1100.70S 1100.70S 7639.00 8346.00 10179.00 9389.00 BC13 Top/L Beluga L2 BC13 Top/L BelugaL30 BC13 TO Revised 13-A Tyonek T2 13-Aug-03 Revised ------------------------------------------------------------------------------------------------------- Target name Rectangular Coordinates T.V.O. ------------------------------------- ------------------------------------- Geographic Location Targets associated with this wellpath } ') For: W il COnI a Coordinates Structure : Pad #3 Well : 80-13 INT·EQ Field Beaver Creek Unit Location Kenai Peninsula, Alaska 200 100 0 100 (.;on 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1S00 1900 200 20Cl 100 100 080D CI 1100 CI i400 ICICI - 1700 ICICI 2C100 " " j600 12:100 20Cl - 2C1C1 1800 " 2600 " " 12900 :iOCl " J900 13200 jClO " - " 3500 ~ " UJ - (!) 2100 " ~,4"200 j800 0 (!) 400 - 4100 4C10 c: '+-~ " - '-' " 14400 ::J " ~ " 4S00 1470 0 SOD - SOCl --+, :J " " 2400 " I 600 600 " I V " V " 700 " IDa 700 " 2700 " " EòOO 1 '». =)400 800 " " 900 - 900 ,-3000 " '" 6jOO ___ 1000 - (:ÔQQ o,~ 1000 3jOO ",6900 " 7200 1100 - 16c_13110179 - I 100 1200 I~'-------I :200 200 100 0 10D 200 300 400 500 600 700 800 900 1000 1100 1200 lJOO :400 1500 1600 1700 IEòClCl 19C1Cl East ( 1 OJiTI pa Structure: Pad #3 Wei! : BC-13 Fie!d ; Beaver Creek Unit LocatiQn : Kenai Peninsula, (--\ U TR r\ U 1 (J 20 .'[ 1 LU 50 60 29 r, L 80 o 90 2 ^! 00 1 C) í20 í30 'Ì "-'1 n LLU ¿ o 2C]C) í 60 19C) í8 o or 0 io 6 ravelling linder ~ ¡::- eet v I Aii de s s ow Measured de s 0 f ere nee Weil ) ) MARATHON Oil Company Pad #3 BC-13 slot #13 Beaver Creek Unit Kenai Peninsula, Alaska 3-D M I N I MUM 0 I S TAN C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License BC-13 Vers. #3 prop5504 Date printed Date created Last revised 13 -Aug-2003 23-Jul-2003 13 -Aug-2003 Field is centred on n60 38 50.050,w150 59 49.92 Structure is centred on n60 38 50.050,w150 59 49.92 Slot location is n60 39 29.240,w151 1 6.309 Slot Grid coordinates are N 2433893.000, E 317289.000 Slot local coordinates are 3980.23 N 3807.35 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Last revised Distance 9-Apr-2001 209.2 5-Sep-1992 96.7 5-Sep-1992 126.9 14-Dec-1994 71.9 25-Feb-2003 66.5 2-Jun-2003 66.4 17-Apr-2003 175.8 Minimum Distance method M.D. Diverging from M.D. 1200.0 8880.0 2400.0 2400.0 2500.0 10496.6 1400.0 8780.0 600.0 600.0 600.0 600.0 1300.0 1300.0 PMSS <0 - 8854>, ,BC-10,Pad #3 GMS <8000-16247'>, ,BC-5,Pad #3 GMS <0-15844'>"BC-6rPad #3 Schlumberger <5943-8858'>,rBC-9rPad #3 MSS <0-6387>, rBC-3,Pad #3 MWD <6433-10005>, ,BC-3Rd,Pad #3 MWD <0-8931>, ,BC-11,Pad #3 MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska CLEARANCE LISTING Page 1 Your ref : BC-13 Verso #3 Last revised: 13-Aug-2003 Reference wellpath Object wellpath M.D. T.V.D. Rect Coordinates M.D. T.V.D. 0.0 0.0 O.ON O.OE 0.3 0.3 100.0 100.0 O.ON O.OE 100.9 100.9 PMSS <0 - 8854>, ,BC-10,Pad #3 Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 205.3N 63.7E 17 .2 215.0 215.0 205.0N 64.0E 17.3 214.8* 214.8* ) ) 200.0 200.0 O.ON O.OE 201.9 201.9 204.0N 65.0E 17.7 214.1* 214.1* 300.0 300.0 O.ON O.OE 302.2 302.1 202.6N 66.4E 18.1 213.2* 213.2* 400.0 400.0 O.ON O.OE 402.2 402.1 201.1N 67.7E 18.6 212.2* 212.2* 500.0 500.0 O.ON O.OE 500.1 500.1 199.9N 68.9E 19.0 211.4* 211.4* 600.0 600.0 O.ON O.OE 599.8 599.7 199.5N 70.2E 19.4 211.5 211. 5 700.0 700.0 O.ON O.OE 700.4 700.3 199.0N 71.2E 19.7 211.4* 211.4* 800.0 800.0 O.ON O.OE 800.1 800.1 198.7N 71.9E 19.9 211.3* 211.3* 900.0 900.0 O.ON O.OE 900.7 900.6 198.4N 72 .5E 20.1 211.2* 211.2* 1000.0 1000.0 O.ON O.OE 1002.7 1002.6 197.4N 73.0E 20.3 210.5* 210.5* 1100.0 1100.0 O.ON O.OE 1101.4 1101.3 196.1N 73.2E 20.5 209.3* 209.3* 1200.0 1200.0 O.ON O.OE 1199.1 1199.0 195.7N 73.8E 20.6 209.2* 209.2* 1300.0 1300.0 O.ON O.OE 1296.3 1296.1 195.5N 77.7E 21.7 210.4 210.4 1400.0 1400.0 O.ON O.OE 13 94.8 1394.4 195.0N 83.8E 23.3 212.3 212.4 1500.0 1500.0 O.ON O.OE 1489.2 1488.3 194.6N 92 .9E 25.5 216.0 216.3 1600.0 1600.0 O.ON O.OE 1582.1 1580.4 195.1N 105.5E 28.4 222.7 223.5 1700.0 1700.0 O.ON O.OE 1674.6 1671.6 196 . 7N 121.3E 31.7 232.9 234.7 1800.0 1800.0 O.ON O.OE 1765.9 1760.8 199.2N 139.9E 35.1 246.6 249.9 1900.0 1900.0 O.ON O.OE 1858.4 1850.8 203.1N 161.1E 38.4 263.8 269.3 2000.0 2000.0 O.ON O.OE 1944.1 1933.3 206.7N 184.2E 41.7 284.8 294.1 2100.0 2100.0 O.ON O.OE 2028.9 2013.7 210.6N 210.8E 45.0 310.2 325.0 2200.0 2200.0 O.ON O.OE 2115.0 2094.2 215.3N 240.9E 48.2 339.9 361.7 2300.0 2300.0 O.ON O.OE 2194.5 2167.7 220.1N 270.9E 50.9 373.3 405.5 2400.0 2400.0 O.ON O.OE 2270.5 2236.6 225.2N 302.3E 53.3 410.8 452.9 2500.0 2500.0 O.ON O.OE 2350.9 2308.4 230.6N 338.3E 55.7 452.0 500.7 2600.0 2600.0 1. 58 1. 6E 2439.6 2387.1 237.3N 378.4E 57.6 494.3 544.7 2700.0 2699.7 5.98 6.4E 2532.8 2470.1 245.1N 420.1E 58.8 535.6 587.5 2800.0 2799.1 13.38 14.5E 2623.9 2551.4 252.9N 460.6E 59.2 575.5 628.7 2900.0 2898.0 23.58 25.7E 2709.4 2627.5 260.3N 499.0E 59.0 614.6 667.9 3000.0 2996.0 36.78 40.0E 2799.6 2707.4 268.4N 539.9E 58.6 652.9 704.6 3100.0 3093.2 52.88 57.6E 2892.3 2789.5 277.0N 582.2E 57.8 690.1 739.6 3200.0 3189.2 71.78 78.2E 2988.4 2874.7 285.8N 625.8E 56.9 725.7 773.3 3300.0 3283.9 93.48 101.9E 3085.2 2960.7 293.9N 669.4E 55.7 759.3 804.6 3400.0 3377.0 11 7 . 98 128.6E 3176.1 3041.4 301. 4N 710.5E 54.2 791.9 834.6 3500.0 3468.6 145.18 158.3E 3280.0 3133.7 309.4N 757.5E 52.8 823.3 863.9 3600.0 3558.3 174.98 190.7E 3376.3 3219.6 315.3N 800.8E 51.2 852.8 894.5 3700.0 3647.6 205.38 223.9E 3470.3 3303.5 320.8N 842.8E 49.6 882.2 928.6 3800.0 3737.0 235.78 257.0E 3561.1 3384.5 326.1N 883.4E 48.1 912.3 963.3 3900.0 3826.3 266.18 290.2E 3643.2 3457.5 330.9N 920.8E 46.6 943.4 997.7 4000.0 3915.6 296.58 323.4E 3733.6 3537.3 336.0N 962.7E 45.3 975.7 1030.0 4100.0 4004.9 326.98 356.5E 3827.5 3620.5 341.9N 1005.9E 44.2 1008.4 1060.8 4200.0 4094.2 357.48 389.7E 3934.7 3715.8 349.2N 1054.5E 43.3 1041.3 1089.6 4300.0 4183.5 387.88 422.9E 4049.0 3818.4 355.3N 1104.5E 42.5 1072.4 1116.7 4400.0 4272.8 418.28 456.0E 4165.5 3924.0 361.1N 1153.3E 41.8 1102.3 1141.2 4500.0 4362.1 448.68 489.2E 4285.8 4034.5 366.1N 1200.7E 41.1 1130.2 1164.2 4600.0 4451. 4 479.08 522.3E 4410.6 4150.4 370.5N 1246.7E 40.5 1156.3 1187.1 4700.0 4540.7 509.48 555.5E 4541.8 4273.8 372.9N 1291. 3E 39.8 1179.5 1208.8 4800.0 4630.0 539.88 588.7E 4640.7 4367.4 374.6N 1323.1E 38.8 1201.8 1228.5 4900.0 4719.3 570.28 621. 8E 4755.1 4476.6 377 . 8N 1357.0E 37.8 1224.0 1247.2 5000.0 4808.6 600.68 655.0E 4887.5 4604.3 380.8N 1391.9E 36.9 1244.2 1265.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 2 Pad #3,BC-13 Your ref : BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath PM88 <0 - 8854>"BC-10,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 4998.8 4712.5 382.8N 1417.8E 35.7 1262.8 1281.6 5200.0 4987.2 661.58 721. 3E 5123.2 4834.2 384.8N 1443.6E 34.6 1280.6 1297.6 5300.0 5076.6 691.88 754.5E 5243.4 4952.6 387.0N 1463.9E 33.3 1297.1 1312.7 5400.0 5166.4 721.58 786.8E 5353.4 5061.4 388.4N 1479.9E 32.0 1312.7 1326.3 5500.0 5257.0 750.28 818.1E 5472.5 5179.7 389.8N 1493.6E 30.7 1327.3 1337.9 5600.0 5348.3 777 . 78 848.1E 5606.2 5313 . 0 391.2N 1503.0E 29.3 1340.3 1347.6 5700.0 5440.3 804.28 877.0E 5738.1 5444.9 390.6N 1506.8E 27.8 1350.7 1357.4 5800.0 5532.9 829.68 904.7E 5833.4 5540.2 389.9N 1507.3E 26.3 1360.3 1367.4 5900.0 5626.3 853.98 931. 2E 5931.4 5638.2 389.1N 1507.3E 24.9 1370.1 1377.7 6000.0 5720.2 877.18 956.5E 6025.3 5732.1 388.3N 1507.1E 23.5 1380.0 1388.1 6100.0 5814.7 899.28 980.5E 6117.5 5824.3 387.6N 1507.1E 22.3 1390.4 1398.3 6200.0 5909.8 920.18 1003.4E 6217.2 5924.0 386.7N 1507.2E 21.1 1400.6 1408.4 ) 6300.0 6005.4 940.08 1025.0E 6313.0 6019.8 385.6N 1507.2E 20.0 1410.6 1418.0 6400.0 6101. 5 958.78 1045.4E 6413.2 6120.0 384.5N 1507.1E 19.0 1420.4 1427.1 6500.0 6198.0 976.28 1064.6E 6512.0 6218.8 383.1N 1507.2E 18.0 1429.7 1435.7 6600.0 6295.0 992.78 1082.5E 6612.1 6318.8 381. 4N 1507.3E 17.2 1438.4 1443.8 6700.0 6392.4 1007.98 1099.2E 6707.1 6413.8 379.8N 1507.1E 16.4 1446.6 1452.4 6800.0 6490.2 1022.18 1114.6E 6795.6 6502.3 379.0N 1506.4E 15.6 1454.9 1460.9 6900.0 6588.4 1035.08 1128.7E 6882.1 6588.8 379.2N 1505.5E 14.9 1463.5 1468.5 7000.0 6686.8 1046.98 1141. 6E 6989.9 6696.6 379.3N 1503.7E 14.2 1471 .4 1475.2 7100.0 6785.6 1057.58 1153.2E 7091. 6 6798.3 379.0N 1501.6E 13 .6 1478 . 2 1480.9 7200.0 6884.6 1067.08 1163.6E 7200.4 6907.0 378.3N 1498.7E 13 .1 1483.8 1485.6 7300.0 6983.8 1075.38 1172.6E 7300.7 7007.3 377.3N 1496.2E 12.6 1488.4 1489.7 7400.0 7083.3 1082.48 1180.4E 7403.9 7110.5 375.9N 1494.3E 12.1 1492.0 1492.6 7500.0 7182.9 1088.48 1186.9E 7509.5 7216.0 374.0N 1491.9E 11.8 1494.3 1494 . 6 7600.0 7282.6 1093.28 1192.1E 7591. 0 7297.5 373.0N 1490.5E 11.5 1496.3 1496.8 7700.0 7382.5 1096.88 1196 .1E 7689.5 7396.1 3 72 . 5N 1489.4E 11.3 1498.3 1498.5 7800.0 7482.4 1099.38 1198.7E 7789.5 7496.0 371 . 8N 1488.1E 11.1 1499.3 1499.3 7900.0 7582.4 1100.58 1200.1E 7886.9 7593.4 371.4N 1486.4E 11.0 1499.5 1499.5 8000.0 7682.4 1100.78 1200.3E 7986.0 7692.5 370.9N 1484.5E 10.9 1498.8 1498.9 8100.0 7782.4 1100.78 1200.3E 8086.9 7793.3 370.6N 1482.9E 10.9 1498.2 1498.3 8200.0 7882.4 1100.78 1200.3E 8191.7 7898.2 369.7N 1482.7E 10.9 1497.3 1497.4 8300.0 7982.4 1100.78 1200.3E 8297.0 8003.4 368.4N 1482.6E 10.9 1496 .1 1496.2 8400.0 8082.4 1100.78 1200.3E 8398.9 8105.3 366.9N 1482.3E 10.9 1494.7 1494 . 8 8500.0 8182.4 1100.78 1200.3E 8503.7 8210.1 365.2N 1481. 9E 10.9 1493.0 1493.2 8600.0 8282.4 1100.78 1200.3E 8608.5 8314.8 363.1N 1481. 3E 10.9 1490.8 1491.2 8700.0 8382.4 1100.78 1200.3E 8707.8 8414.2 361.0N 1480.8E 10.9 1488.7 1489.0 8800.0 8482.4 1100.78 1200.3E 8807.6 8513.9 359.0N 1479.9E 10.8 1486.5 1486.9 8900.0 8582.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1485.4 9000.0 8682.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1490.2 9100.0 8782.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1501.7 9200.0 8882.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1519.7 9300.0 8982.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1544.0 9400.0 9082.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1574.3 9500.0 9182.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1610.2 9600.0 9282.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1651. 4 9700.0 9382.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1697.5 9800.0 9482.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1748.1 9900.0 9582.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1802.9 10000.0 9682.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1861.4 10100.0 9782.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1923.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) ( 179 . 00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 3 Pad #3,BC-13 Your ref : BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath PM88 <0 - 8854>, ,BC-I0,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 10200.0 9882.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 1988.4 10300.0 9982.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 2056.2 10400.0 10082.4 1100.78 1200.3E 8854.0 8560.3 358.0N 1479.4E 10.8 2126.6 ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 2800.0 2900.0 2500.0 2600.0 2699.7 2799.1 2898.0 3000.0 3100.0 2996.0 3093.2 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON 1. 58 5.98 13.38 23.58 36.78 52.88 Obj ect wellpath O.OE O.OE O.OE O.OE O.OE 0.0 99.0 199.0 299.0 399.0 O.OE O.OE O.OE O.OE O.OE 499.0 599.2 699.5 799.7 899.2 O.OE O.OE O.OE O.OE O.OE 999.6 1099.8 1199.4 1299.0 1398.7 O.OE O.OE O.OE O.OE O.OE 1498.9 1599.3 1699.4 1799.4 1899.2 O.OE O.OE O.OE O.OE O.OE 1999.0 2099.1 2199.0 2299.5 2399.6 O.OE 1.6E 6.4E 14.5E 25.7E 2499.0 2598.7 2698.3 2797.9 2896.6 40.0E 57.6E 2993.7 3091.6 M.D. T.V.D. 1.0 100.0 200.0 300.0 400.0 500.0 600.2 700.5 800.7 900.2 1000.6 1100.8 1200.4 1299.9 1399.7 1499.9 1600.3 1700.4 1800.3 1900.1 2000.0 2100.0 2200.0 2300.5 2400.5 2500.0 2599.7 2699.3 2798.8 2897.6 2994.7 3092.6 CLEARANCE LI8TING Page 4 Your ref : BC-13 Verso #3 Last revised : 13-Aug-2003 GM8 <8000-16247'>"BC-5,Pad #3 Rect Coordinates Horiz Min'm Bearing Dist TCyl Dist 98.5N 98.5N 98.4N 98.4N 98.4N 98.4N 98.5N 98.3N 97.6N 97.3N 97.2N 96.6N 96.0N 95.9N 96.1N 96.4N 96.2N 95.8N 95.3N 95.0N 94.9N 94.8N 94.7N 94.5N 93.8N 94.0N 94.1N 94.5N 94.9N 95.1N 95.8N 96.8N 24.4E 24.5E 24.6E 24.8E 25.1E 25.1E 24.8E 24.5E 24.4E 24.1E 23.7E 23.1E 22.7E 22.2E 22.4E 22.4E 22.4E 22.5E 22.5E 22.7E 22.9E 23.1E 23.5E 23.4E 23.2E 23.0E 22.6E 22.7E 22.9E 22.9E 23.1E 24.3E 13.9 14.0 14.0 14.2 14.3 101.5 101.5* 101.5* 101.5 101. 5 101.5 101.5* 101.5* 101. 5 101.5 14.3 14.1 14.0 14.1 13 .9 101. 6 101.6* 101.3* 100.6* 100.2* 101.6 101.6* 101.3* 100.6* 100.3* 13.7 13 .4 13.3 13 .0 13 .1 100.0* 99.3* 98.6* 98.4* 98.7 100.0* 99.3* 98.6* 98.4* 98.7 13 .1 13.1 13 .2 13.3 13 .5 98.9 98.8* 98.4* 98.0* 97.7* 98.9 98.8* 98.4* 98.0* 97.7* 13 .5 13.7 13 .9 13.9 13 .9 97.6* 97.5* 97.6 97.3* 96.7* 97.6* 97.5* 97.6 97.3* 96.7* 13.7 12.4 9.2 4.5 358.7 96.8 97.9 101. 7 108.5 118.7 96.8 97.9 101.9 108.8 119.6 352.7 347.5 133.6 153.2 135.7 156.9 3200.0 3189.2 71.78 78.2E 3188.2 3189.1 97.3N 25.9E 342.8 176.9 183.3 3300.0 3283.9 93.48 101.9E 3282.8 3283.7 97.8N 27.2E 338.7 205.3 216.1 3400.0 3377.0 117.98 128.6E 3375.2 3376.1 98.3N 27.8E 335.0 238.5 255.7 3500.0 3468.6 145.18 158.3E 3467.5 3468.4 98.8N 28.2E 331.9 276.4 302.1 3600.0 3558.3 174.98 190.7E 3557.6 3558.5 99.0N 28.4E 329.3 318.4 353.3 3700.0 3647.6 205.38 223.9E 3647.3 3648.3 98.8N 28.5E 327.3 361. 5 402.5 3800.0 3737.0 235.78 257.0E 3734.7 3735.6 98.9N 28.3E 325.6 405.3 451. 7 3900.0 3826.3 266.18 290.2E 3825.3 3826.3 99.0N 28.3E 324.3 449.4 501.0 4000.0 3915.6 296.58 323.4E 3914.6 3915.6 99.0N 28.3E 323.3 493.5 550.3 4100.0 4004.9 326.98 356.5E 4004.5 4005.4 99.0N 28.3E 322.4 537.8 599.9 4200.0 4094.2 357.48 389.7E 4095.0 4095.9 99.0N 28.4E 321.6 582.0 649.9 4300.0 4183.5 387.88 422.9E 4183.9 4184.8 98.7N 28.5E 321.0 626.2 700.1 4400.0 4272.8 418.28 456.0E 4271.0 4272.0 98.5N 28.3E 320.4 670.7 750.6 4500.0 4362.1 448.68 489.2E 4360.8 4361. 7 98.4N 28.0E 319.9 715.5 801.1 4600.0 4451. 4 479.08 522.3E 4448.5 4449.4 98.5N 28.0E 319.4 760.2 851.7 4700.0 4540.7 509.48 555.5E 4536.5 4537.4 98.9N 27.9E 319.1 805.2 902.3 4800.0 4630.0 539.88 588.7E 4625.4 4626.3 99.1N 27.6E 318.7 850.3 953.0 4900.0 4719.3 570.28 621.8E 4714.6 4715.5 99.4N 27.4E 318.4 895.4 1003.7 5000.0 4808.6 600.68 655.0E 4804.1 4805.0 99.7N 27.2E 318.1 940.6 1054.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 5 Pad #3,BC-13 Your ref : BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath : GM8 <8000-16247'>"BC-5,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 4893.2 4894.2 100.lN 27.1E 317.9 985.7 1105.8 5200.0 4987.2 661.58 721. 3E 4981.9 4982.8 100.5N 27.0E 317.7 1030.9 1156.7 5300.0 5076.6 691.88 754.5E 5071.0 5071.9 100.8N 26.7E 317.4 1076.0 1205.4 5400.0 5166.4 721.58 786.8E 5159.9 5160.9 101.0N 26.4E 317.2 1120.2 1244.0 5500.0 5257.0 750.28 818.1E 5247.7 5248.7 101.6N 26.3E 317.1 1163.0 1280.7 5600.0 5348.3 777.78 848.1E 5338.3 5339.2 102.4N 26.2E 317.0 1204.3 1315.5 5700.0 5440.3 804.28 877.0E 5431.6 5432.5 103.2N 26.0E 316.8 1244.1 1348.6 5800.0 5532.9 829.68 904.7E 5528.8 5529.7 103.7N 26.0E 316.7 1281.9 1380.2 5900.0 5626.3 853.98 931. 2E 5621.5 5622.4 104.1N 26.1E 316.6 1318.0 1410.1 6000.0 5720.2 877 .18 956.5E 5714.9 5715.8 104.2N 25.8E 316.5 1352.5 1438.2 6100.0 5814.7 899.28 980.5E 5809.1 5810.0 104.3N 25.4E 316.4 1385.4 1464.7 6200.0 5909.8 920.18 1003.4E 5902.8 5903.7 104.1N 24.7E 316.3 1416.6 1489.5 6300.0 6005.4 940.08 1025.0E 5991.5 5992.4 104.0N 23.7E 316.2 1446.6 1512.7 6400.0 6101.5 958.78 1045.4E 6087.8 6088.7 104.3N 22.9E 316.1 1475.0 1534.4 6500.0 6198.0 976.28 1064.6E 6184.4 6185.3 105.0N 22.4E 316.1 1501.8 1554.7 6600.0 6295.0 992.78 1082.5E 6281.8 6282.7 105.5N 21.7E 316.0 1526.9 1573.4 6700.0 6392.4 1007.98 1099.2E 6380.1 6381. 0 105.8N 20.9E 315.9 1550.2 1591.0 6800.0 6490.2 1022.18 1114.6E 6477.3 6478.2 106.0N 20.1E 315.9 1571.8 1606.5 6900.0 6588.4 1035.08 1128.7E 6575.5 6576.4 106.2N 19.3E 315.8 1591.7 1620.3 7000.0 6686.8 1046.98 1141. 6E 6673.3 6674.2 106.4N 18.4E 315.8 1609.9 1633.6 7100.0 6785.6 1057.58 1153.2E 6793.3 6794.1 106.6N 17.4E 315.7 1626.4 1645.8 7200.0 6884.6 1067.08 1163.6E 6876.6 6877.4 106.3N 17.6E 315.7 1640.1 1656.9 7300.0 6983.8 1075.38 11 72 . 6E 6963.2 6964.1 106.8N 17.2E 315.7 1653.1 1666.5 7400.0 7083.3 1082.48 1180.4E 7060.7 7061.5 107.6N 16.2E 315.6 1664.9 1674.6 7500.0 7182.9 1088.48 1186.9E 7165.6 7166.5 108.5N 15.3E 315.6 1675.0 1681.1 7600.0 7282.6 1093.28 1192.1E 7274.5 7275.4 109.0N 14.7E 315.6 1682.8 1686.4 7700.0 7382.5 1096.88 1196.1E 7376.3 7377 . 2 109.1N 14.3E 315.6 1688.4 1690.5 7800.0 7482.4 1099.38 1198.7E 7469.1 7469.9 109.3N 13 .8E 315.6 1692.6 1693.6 7900.0 7582.4 1100.58 1200.1E 7574.2 7575.0 109.8N 13.3E 315.6 1695.1 1695.3 8000.0 7682.4 1100.78 1200.3E 7674.5 7675.4 11 0 . IN 13 .OE 315.6 1695.8 1695.8 8100.0 7782.4 1100.78 1200.3E 7775.5 7776.3 110.3N 12.6E 315.6 1696.2 1696.2 8200.0 7882.4 1100.78 1200.3E 7878.5 7879.3 110.2N 12.1E 315.5 1696.5 1696.5 8300.0 7982.4 1100.78 1200.3E 7966.9 7967.8 110. ON 11.8E 315.5 1696.6 1696.8 8400.0 8082.4 1100.78 1200.3E 8020.9 8021.7 11 0 . 9N 10.8E 315.5 1699.0 1700.6 8500.0 8182.4 1100.78 1200.3E 8094.3 8095.1 113 . IN 8.3E 315.5 1703.5 1706.5 8600.0 8282.4 1100.78 1200.3E 8169.8 8170.4 116.3N 5.2E 315.5 1709.4 1713 .8 8700.0 8382.4 1100.78 1200.3E 8251.0 8251.4 121. ON 1. 9E 315.6 1716.4 1722.8 8800.0 8482.4 1100.78 1200.3E 8329.9 8330.0 127.0N l.4W 315.6 1724.7 1733.1 8900.0 8582.4 1100.78 1200.3E 8406.5 8406.2 13 3 . 7N 4.8W 315.7 1734.1 1744.9 9000.0 8682.4 1100.78 1200.3E 8495.0 8494.1 142.6N 9.0W 315.8 1744.6 1758.4 9100.0 8782.4 1100.78 1200.3E 8571. 9 8570.5 151.7N 12.5W 315.9 1756.3 1773.0 9200.0 8882.4 1100.78 1200.3E 8649.8 8647.5 162.4N 16.1W 316.1 1769.3 1789.2 ) ) ) 9300.0 8982.4 1100.78 1200.3E 8732.5 8729.2 174.9N 19.7W 316.3 1783.1 1807.1 9400.0 9082.4 1100.78 1200.3E 8809.4 8804.9 188.0N 22.4W 316.5 1798.0 1825.3 9500.0 9182.4 1100.78 1200.3E 8876.5 8870.6 201.3N 23.9W 316.8 1814.2 1843.5 9600.0 9282.4 1100.78 1200.3E 8965.9 8957.7 221.7N 24.8W 317.2 1831. 7 1862.1 9700.0 9382.4 1100.78 1200.3E 9062.3 9051.2 244.9N 24.5W 317.7 1849.5 1881.4 9800.0 9482.4 1100.78 1200.3E 9161.1 9146.8 270.0N 22.7W 318.3 1867.4 1901.1 9900.0 9582.4 1100.78 1200.3E 9255.2 9237.6 294.7N 20.0W 318.8 1885.5 1921. 2 10000.0 9682.4 1100.78 1200.3E 9346.3 9325.0 319.9N 16.1W 319.4 1904.1 1942.1 10100.0 9782.4 1100.78 1200.3E 9436.9 9411.8 345.6N 11.9W 320.0 1923.2 1963.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3, BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska CLEARANCE LI8TING Page 6 Your ref : BC-13 Verso #3 Last revised : 13-Aug-2003 Reference wellpath Object wellpath GM8 <8000-16247'>"BC-5,Pad #3 M.D. T.V.D. Rect Coordinates M.D. T.V.D. 10200.0 9882.4 1100.78 1200.3E 9531.7 9502.2 10300.0 9982.4 1100.78 1200.3E 9623.8 9589.6 10400.0 10082.4 1100.78 1200.3E 9710.8 9671.7 Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 373.5N 6.2W 320.7 1942.6 1984.8 401.7N 0.5E 321.4 1962.3 2007.0 429.6N 8.2E 322.1 1982.8 2030.5 ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 2800.0 2900.0 2500.0 2600.0 2699.7 2799.1 2898.0 3000.0 3100.0 3200.0 3300.0 3400.0 2996.0 3093.2 3189.2 3283.9 3377.0 3500.0 3600.0 3700.0 3800.0 3900.0 3468.6 3558.3 3647.6 3737.0 3826.3 4000.0 4100.0 4200.0 4300.0 4400.0 3915.6 4004.9 4094.2 4183.5 4272.8 4500.0 4600.0 4700.0 4800.0 4900.0 4362.1 4451.4 4540.7 4630.0 4719.3 5000.0 4808.6 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON 1. 58 5.98 13.38 23.58 36.78 52.88 71.78 93.48 11 7 . 98 145.18 174.98 205.38 235.78 266.18 296.58 326.98 357.48 387.88 418.28 448.68 479.08 509.48 539.88 570.28 600.68 40.0E 57.6E 78.2E 101.9E 128.6E 158.3E 190.7E 223.9E 257.0E 290.2E 323.4E 356.5E 389.7E 422.9E 456.0E 489.2E 522.3E 555.5E 588.7E 621.8E 655.0E Object wellpath O.OE O.OE O.OE O.OE O.OE 0.0 99.0 199.0 299.0 399.0 M.D. T.V.D. 1.0 100.0 200.0 300.0 400.0 500.1 600.1 700.3 800.2 900.4 1000.5 1100.5 1200.5 1300.5 1400.5 1500.5 1600.5 1700.3 1800.3 1900.1 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2699.7 2799.1 2898.0 2996.0 3093.2 3189.2 3283.9 3377.0 3468.6 3558.1 3646.6 3735.7 3823.9 3911.8 4000.7 4091.1 4181.3 4265.4 4354.8 4443.0 4527.6 4619.0 4709.2 4793.8 CLEARANCE LI8TING Page 7 Your ref: BC-13 Verso #3 Last revised : 13-Aug-2003 GM8 <0-15844'>"BC-6,Pad #3 Rect Coordinates Horiz Min'm Bearing Dist 130.0N 13 0 . ON 13 0 . ON 13 0 . ON 130.0N 13 0 . ON 13 0 . ON 129.8N 129.7N 129.4N 129.1N 128.7N 128.4N 128.0N 127.6N 127.1N 126.7N 126.4N 126.2N 126.1N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 126.0N 125.9N 125.8N 125.6N 125.4N 125.4N 125.3N 125.1N 125.8N 126.5N 127.1N 127.5N 128.0N 129. ON 16.5E 16.5E 16.5E 16.5E 16.5E 16.5E 16.4E 16.3E 16.2E 16.0E 15.8E 15.6E 15.4E 15.2E 15.1E 15.1E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 15.0E 14.9E 14.6E 14.0E 13 .2E 12.1E 10.7E 9.6E 9.0E 8.1E 7.2E 6.7E 5.6E 4.1E 3.2E 2.6E 7.2 7.2 7.2 7.2 7.2 131.0 131.0* 131.0 131.0 131.0 TCyl Dist 131.0 131. 0* 131. 0 131.0 131.0 131.0 131.0* 130.9* 130.7* 130.4* 130.1* 129.7* 129.3* 128.9* 128.5* 128.0* 127.6* 127.3* 127.1* 127.0* 126.9* 126.9* 126.9 126.9 126.9 126.9 128.2 132.2 139.3 150.0 126.9 128.3 132.4 139.8 151. 2 O.OE O.OE O.OE O.OE O.OE 499.1 599.1 699.3 799.3 899.4 O.OE O.OE O.OE O.OE O.OE 999.5 1099.5 1199.5 1299.5 1399.5 7.2 7.2 7.2 7.1 7.1 131.0 131.0* 130.9* 130.7* 130.4* 164.7 183.8 207.6 236.0 269.1 167.1 188.3 215.2 248.4 288.1 O.OE O.OE O.OE O.OE O.OE 1499.5 1599.5 1699.3 1799.3 1899.1 O.OE O.OE O.OE O.OE O.OE 1999.0 2099.0 2199.0 2299.0 2399.0 7.0 6.9 6.8 6.8 6.8 130.1* 129.7* 129.3* 128.9* 128.5* 306.7 348.5 391.9 435.7 480.0 335.1 387.2 436.6 486.5 536.9 O.OE 1. 6E 6.4E 14.5E 25.7E 2499.0 2599.0 2698.8 2798.2 2897.0 2995.1 3092.2 3188.2 3282.9 3376.1 3467.6 3557.1 3645.6 3734.7 3822.9 3910.8 3999.7 4090.2 4180.4 4264.4 4353.9 4442.1 4526.7 4618.1 4708.3 4792.9 6.8 6.8 6.8 6.8 6.8 128.0* 127.6* 127.3* 127.1* 127.0* 524.6 569.5 614.4 659.2 704.2 587.0 637.5 688.7 740.2 792.0 MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska 6.8 6.8 6.8 6.8 6.8 126.9* 126.9* 126.9 126.9 126.9 749.8 795.3 841.3 887.3 933.0 843.4 895.3 946.8 997.9 1049.1 6.8 6.0 3.7 0.2 355.9 351.2 346.6 342.3 338.4 335.0 332.1 329.7 327.7 326.1 324.7 323.6 322.6 321.8 321.1 320.5 320.0 319.6 319.2 318.8 318.5 318.2 978.9 1100.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ CLEARANCE LI8TING Page 8 Your ref BC-13 Verso #3 Last revised : 13-Aug-2003 1480.7 1458.2 1436.4 TCyl Dist 326.1 1446.7 326.8 1426.2 327.8 1404.5 Horiz Min'm Bearing Dist 409.8E 437.9E 470.9E 74.1N 66.6N 57. ON Rect Coordinates GM5 <0-15844'>"BC-6,Pad #3 CLEARANCE LI5TING Page 9 Your ref : BC-13 Verso #3 Last revised : 13-Aug-2003 1200.3E 10234.0 10178.8 1200.3E 10341.8 10282.6 1200.3E 10463.2 10399.0 M.D. T.V.D. Object wellpath 1100.78 1100.75 1100.75 Rect Coordinates 10200.0 9882.4 10300.0 9982.4 10400.0 10082.4 Reference wellpath M.D. T.V.D. MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit,Kenai Peninsula, Alaska All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 1503.3 1616.0 1593.5 1570.5 1548.0 1525.8 1716.5 1698.7 1679.4 1659.3 1638.1 1760.2 1756.4 1751.6 1744.4 1732.2 1758.9 1760.2 1760.8 1761.3 1761.7 1744.6 1749.4 1752.9 1755.3 1757.0 1701.4 1712.7 1722.6 1731.2 1738.5 1625.3 1643.4 1659.8 1675.0 1688.9 1514.2 1539.5 1563.3 1585.8 1606.3 1362.7 1396.5 1428.4 1458.7 1487.2 1151.3 1202.6 1251. 8 1290.0 1327.0 TCyl Dist 325.4 1467.3 322.0 1576.3 322.7 1554.5 323.3 1532.4 324.1 1510.4 324.7 1488.6 319.0 1685.6 319.5 1664.2 320.1 1642.5 320.7 1620.2 321.3 1597.9 316.2 1759.0 316.5 1754.5 317.4 1742.5 318.0 1724.8 318.4 1705.7 316.0 1758.6 316.0 1760.1 316.0 1760.8 316.0 1761.2 316.1 1761.7 315.9 1739.2 315.9 1746.2 315.9 1751.4 315.9 1754.7 315.9 1756.6 315.9 1677.8 315.9 1693.4 315.9 1707.5 315.9 1719.8 315.9 1730.5 316.0 1573.5 316.0 1597.7 315.9 1620.4 315.9 1641.4 315.9 1660.1 316.3 1427.3 316.3 1459.9 316.2 1490.8 316.1 1519.9 316.1 1547.5 316.9 1245.1 316.8 1284.5 316.6 1322.9 316.5 1359.5 316.4 1393.9 317.9 1024.9 317.7 1070.6 317.5 1116.1 317.2 1160.6 317.1 1203.7 Horiz Minim Bearing Dist 385.4E 252.1E 280.8E 308.0E 335.5E 360.2E 118.9E 144.8E 173.0E 201.1E 225.7E 15.1W 6.6W 38.0E 66.3E 90.0E 22.2W 22.9W 22.9W 22.2W 21. 5W 18.4W 19.7W 20.4W 20.7W 21. 3W 14.9W 15.3W 16.1W 16.9W 17.6W 9.9W 11.0W 12.2W 13 .6W 13 .9W 4.7W 6.0W 7.0W 7.7W 8.8W 2.4W 3.0W 3.8W 4.1W 4.1W 1. 6E 0.6E O.lE 1. OW 2.0W 80.1N 111. ON 104.8N 98.5N 92.1N 86.0N 142.0N 134.7N 127.8N 121. 8N 116.6N 168.8N 169.4N 165.1N 157.6N 150.4N 163.1N 164.8N 165.9N 167.1N 168.3N 155.3N 156.3N 157.9N 159.6N 161.2N 146.5N 148.2N 150.2N 151.7N 153.7N 139.5N 140.7N 141.9N 143.5N 144.7N 13 3 . 4N 134.3N 13 5 . 6N 137.0N 138.2N 131.6N 131.5N 131.9N 132.7N 13 3 . ON 129.8N 13 0 . 2N 13 0 . 7N 130.6N 13 0 . 9N Rect Coordinates GM5 <0-15844'>"BC-6,Pad #3 ) 1200.3E 10141.7 10089.9 1200.3E 9656.8 9624.8 1200.3E 9761.7 9725.5 1200.3E 9860.1 9819.8 1200.3E 9959.5 9915.2 1200.3E 10049.4 10001.3 9139.8 9242.1 9347.3 9445.7 9531.2 8356.7 8473.5 8770.6 8907.7 9016.0 7752.1 7864.2 7976.7 8068.8 8201.3 7253.7 7353.6 7457.6 7555.0 7651.7 6758.2 6853.1 6953.5 7051.1 7153.4 6267.6 6364.5 6456.7 6567.5 6656.2 5796.4 5884.7 5981.7 6075.8 6171.2 5340.8 5434.1 5518.3 5620.6 5714.2 4885.8 4977.8 5068.7 5154.5 5244.4 M.D. T.V.D. 9152.9 9258.7 9367.8 9470.3 9559.4 8356.3 8473.5 8774.2 8914.4 9025.4 7751.6 7863.7 7976.2 8068.3 8200.9 7253.1 7353.0 7457.1 7554.4 7651. 2 6757.5 6852.4 6952.8 7050.5 7152.8 6266.8 6363.8 6455.9 6566.7 6655.5 5795.6 5883.8 5980.8 6074.9 6170.4 5339.9 5433.2 5517.4 5619.7 5713.4 4884.9 4976.9 5067.8 5153.6 5243.6 Obj ect wellpath 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1192.1E 1196.1E 1198.7E 1200.1E 1200.3E 1153.2E 1163.6E 11 72 .6E 1180.4E 1186.9E 1082.5E 1099.2E 1114.6E 1128.7E 1141. 6E 980.5E 1003.4E 1025.0E 1045.4E 1064.6E 848.1E 877.0E 904.7E 931. 2E 956.5E 688.2E 721. 3E 754.5E 786.8E 818.1E 1100.78 1100.75 1100.75 1100.78 1100.75 1100.75 1100.75 1100.75 1100.75 1100.78 1100.78 1100.75 1100.75 1100.75 1100.75 1100.75 1100.75 1100.78 1100.78 1100.75 1100.75 1093.25 1096.85 1099.35 1100.58 1100.75 1057.58 1067.05 1075.35 1082.45 1088.48 992.75 1007.95 1022.15 1035.05 1046.95 899.25 920.15 940.05 958.75 976.25 777.75 804.25 829.65 853.95 877 .15 631.05 661.55 691.85 721.55 750.25 Rect Coordinates 9782.4 10100.0 9282.4 9382.4 9482.4 9582.4 9682.4 9600.0 9700.0 9800.0 9900.0 10000.0 8782.4 8882.4 8982.4 9082.4 9182.4 9100.0 9200.0 9300.0 9400.0 9500.0 8282.4 8382.4 8482.4 8582.4 8682.4 8600.0 8700.0 8800.0 8900.0 9000.0 7782.4 7882.4 7982.4 8082.4 8182.4 8100.0 8200.0 8300.0 8400.0 8500.0 7282.6 7382.5 7482.4 7582.4 7682.4 7600.0 7700.0 7800.0 7900.0 8000.0 6785.6 6884.6 6983.8 7083.3 7182.9 7100.0 7200.0 7300.0 7400.0 7500.0 6295.0 6392.4 6490.2 6588.4 6686.8 6600.0 6700.0 6800.0 6900.0 7000.0 5814.7 5909.8 6005.4 6101.5 6198.0 6100.0 6200.0 6300.0 6400.0 6500.0 5348.3 5440.3 5532.9 5626.3 5720.2 5600.0 5700.0 5800.0 5900.0 6000.0 4897.9 4987.2 5076.6 5166.4 5257.0 5100.0 5200.0 5300.0 5400.0 5500.0 Reference wellpath M.D. T.V.D. ) MARATHON Oil Company CLEARANCE LISTING Page 10 Pad #3,BC-13 Your ref : BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Obj ect well path Schlumberger <5943-8858'>"BC-9,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 6.1 0.0 III . 7N 91. 2E 39.2 144.2 144.2 100.0 100.0 O.ON O.OE 106.1 100.0 111 . 7N 91. 2E 39.3 144.2* 144.2* 200.0 200.0 O.ON O.OE 206.1 200.0 111 . 6N 91.3E 39.3 144.2* 144.2* 300.0 300.0 O.ON O.OE 306.1 300.0 III . 4N 91. 5E 39.4 144.2* 144.2* 400.0 400.0 O.ON O.OE 406.1 400.0 III . 2N 91. 6E 39.5 144.1* 144.1* 500.0 500.0 O.ON O.OE 506.2 500.1 III . ON 91.9E 39.6 144.1* 144.1* 600.0 600.0 O.ON O.OE 606.4 600.3 11 0 . 7N 92 .1E 39.8 144.0* 144.0* 700.0 700.0 O.ON O.OE 707.3 701.2 11 0 . 2N 92.2E 39.9 143.6* 143.6* 800.0 800.0 O.ON O.OE 810.5 804.4 108.2N 92.3E 40.5 142.3* 142.3* 900.0 900.0 O.ON O.OE 917.8 911.5 101.9N 91.7E 42.0 137.6* 138.0* 1000.0 1000.0 O.ON O.OE 1023.8 1016.6 89.6N 88.4E 44.6 126.9* 128.0* 1100.0 1100.0 O.ON O.OE 1129.4 1120.4 70.1N 84.0E 50.1 111.3* 113.0* 1200.0 1200.0 O.ON O.OE 1229.0 1216.7 45.4N 79.2E 60.2 92.8* 94.4* 1300.0 1300.0 O.ON O.OE 1326.1 1309.3 16.6N 74.5E 77.5 76.9* 77.5* 1400.0 1400.0 O.ON O.OE 1420.2 1397.6 15.7S 70.1E 102.6 71.9* 71.9* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) 1500.0 1500.0 O.ON O.OE 1511.5 1481.9 50.48 65.6E 127.6 84.7 87.1 1600.0 1600.0 O.ON O.OE 1599.4 1561.4 87.48 60.6E 145.3 113.2 121.6 1700.0 1700.0 O.ON O.OE 1681.4 1634.0 125.38 55.4E 156.2 152.0 170.1 1800.0 1800.0 O.ON O.OE 1769.1 1710.3 168.28 49.7E 163.5 197.0 222.0 1900.0 1900.0 O.ON O.OE 1856.9 1786.9 210.68 43.9E 168.2 243.0 276.2 2000.0 2000.0 O.ON O.OE 1942.3 1861.4 252.18 38.1E 171.4 290.2 332.8 2100.0 2100.0 O.ON O.OE 2025.3 1933.4 293.08 32.8E 173.6 338.6 391.4 2200.0 2200.0 O.ON O.OE 2109.5 2006.1 335.28 27.8E 175.3 388.2 450.8 2300.0 2300.0 O.ON O.OE 2192.2 2077.2 377.28 23.0E 176.5 438.7 511.7 2400.0 2400.0 O.ON O.OE 2277.5 2150.3 420.88 18.0E 177.6 489.7 573.6 2500.0 2500.0 O.ON O.OE 2358.8 2219.9 462.68 12.9E 178.4 540.9 635.5 2600.0 2600.0 1. 58 1. 6E 2440.0 2289.0 504.98 8.1E 179.3 591.7 683.3 2700.0 2699.7 5.98 6.4E 2526.8 2362.6 550.58 3.0E 180.4 640.5 727.5 2800.0 2799.1 13 .38 14.5E 2614.6 2437.2 596.68 2.7W 181.7 686.7 768.9 2900.0 2898.0 23.58 25.7E 2709.0 2517.3 646.18 9.1W 183.2 730.5 807.6 3000.0 2996.0 36.78 40.0E 2800.2 2595.1 693.28 15.2W 184.8 771.2 844.1 3100.0 3093.2 52.88 57.6E 2887.4 2669.5 738.48 21. 2W 186.6 809.8 877.9 3200.0 3189.2 71.78 78.2E 2975.7 2744.7 784.28 27.8W 188.5 846.5 908.0 3300.0 3283.9 93.48 101.9E 3066.2 2821.7 831. 28 34.6W 190.5 881.2 934.2 3400.0 3377.0 11 7 . 98 128.6E 3156.3 2898.4 878 .18 41. 3W 192.6 914.3 956.9 3500.0 3468.6 145.18 158.3E 3268.1 2994.0 935.38 49.5W 194.7 944.8 976.9 3600.0 3558.3 174.98 190.7E 3405.0 3113.9 1000.78 59.6W 196.9 970.7 996.0 3700.0 3647.6 205.38 223.9E 3527.6 3223.3 1055.48 68.1W 199.0 994.0 1018.4 3800.0 3737.0 235.78 257.0E 3636.5 3322.0 1100.58 76.8W 201.1 1015.6 1040.7 3900.0 3826.3 266.18 290.2E 3738.9 3415.4 1141. 58 85.6W 203.2 1037.5 1061.9 4000.0 3915.6 296.58 323.4E 3842.8 3510.8 1181. 68 94.8W 205.3 1059.3 1082.6 4100.0 4004.9 326.98 356.5E 3966.3 3625.3 1226.78 105.7W 207.2 1080.4 1102.8 4200.0 4094.2 357.48 389.7E 4072.4 3724.5 1263.38 114.4W 209.1 1100.7 1124.1 4300.0 4183.5 387.88 422.9E 4178.6 3824.4 1298.28 122.8W 210.9 1120.5 1145.6 4400.0 4272.8 418.28 456.0E 4277.3 3917.5 1329.98 131.1W 212.8 1141.1 1167.4 4500.0 4362.1 448.68 489.2E 4376.4 4011.3 1360.78 13 9. 5W 214.6 1162.0 1189.2 4600.0 4451. 4 479.08 522.3E 4478.1 4108.0 1391.48 148.1W 216.3 1183.2 1209.0 4700.0 4540.7 509.48 555.5E 4579.0 4204.0 1421.28 155.9W 218.0 1204.6 1224.6 4800.0 4630.0 539.88 588.7E 4729.4 4348.3 1462.28 167.0W 219.3 1225.2 1237.0 4900.0 4719.3 570.28 621.8E 4922.1 4536.8 1499.78 178.7W 220.7 1240.2 1246.4 5000.0 4808.6 600.68 655.0E 5087.1 4700.4 1520.38 185.2W 222.4 1250.4 1252.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 11 Pad #3,BC-13 Your ref : BC-13 Verso #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13 -Aug-2003 Reference wellpath Object wellpath : 8chlumberger <5943-8858'>"BC-9,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 5258.1 4871.1 1530.38 188.5W 224.3 1256.2 1256.9 5200.0 4987.2 661.58 721.3E 5376.9 4989.8 1531.08 189.4W 226.3 1259.2 1259.8 5300.0 5076.6 691.88 754.5E 5466.3 5079.2 1530.38 189.8W 228.4 1262.8 1264.4 5400.0 5166.4 721. 58 786.8E 5552.6 5165.5 1529.88 190.1W 230.4 1268.0 1270.8 5500.0 5257.0 750.28 818.1E 5642.3 5255.2 1529.38 190.7W 232.3 1274.6 1278.6 5600.0 5348.3 777.78 848.1E 5732.7 5345.6 1528.88 191.2W 234.1 1282.3 1287.6 5700.0 5440.3 804.28 877.0E 5821.7 5434.6 1528.38 191.8W 235.9 1291.0 1297.6 5800.0 5532.9 829.68 904.7E 5914.0 5526.9 1527.98 192.6W 237.5 1300.7 1308.0 5900.0 5626.3 853.98 931.2E 6009.6 5622.5 1527.88 193.1W 239.1 1310.8 1319.2 6000.0 5720.2 877.18 956.5E 6097.1 5710.0 1527.38 193.9W 240.5 1321.5 1330.2 6100.0 5814.7 899.28 980.5E 6198.9 5811.8 1526.78 195.0W 241.9 1332.6 1341.0 6200.0 5909.8 920.18 1003.4E 6299.0 5911.9 1525.98 195.7W 243.2 1343.4 1350.8 6300.0 6005.4 940.08 1025.0E 6406.4 6019.2 1524.88 195.5W 244.4 1353.5 1361.1 6400.0 6101.5 958.78 1045.4E 6494.2 6107.0 1523.88 195.3W 245.5 1363.4 1371.7 6500.0 6198.0 976.28 1064.6E 6581.7 6194.5 1523.08 195.7W 246.5 1373.8 1381.7 6600.0 6295.0 992.78 1082.5E 6680.6 6293.5 1522.08 196 .4W 247.5 1384.1 13 90.9 6700.0 6392.4 1007.98 1099.2E 6786.6 6399.4 1520.78 196.7W 248.4 1393.6 1400.2 6800.0 6490.2 1022.18 1114.6E 6873.2 6486.0 1519.68 196.9W 249.2 1402.7 1409.0 6900.0 6588.4 1035.08 1128.7E 6973.0 6585.8 1518.28 197.8W 250.0 1411.8 1417.2 7000.0 6686.8 1046.98 1141. 6E 7071.9 6684.7 1516.88 198.5W 250.7 1420.1 1424.2 7100.0 6785.6 1057.58 1153.2E 7184.9 6797.7 1515.18 198.7W 251.3 1427.3 1430.4 7200.0 6884.6 1067.08 1163.6E 7272.7 6885.5 1513.68 198.5W 251.8 1433.5 1436.8 7300.0 6983.8 1075.38 1172.6E 7363.8 6976.6 1512.38 199.3W 252.3 1439.8 1442.8 7400.0 7083.3 1082.48 1180.4E 7455.1 7067.9 1511. 28 200.2W 252.7 1445.8 1448.3 7500.0 7182.9 1088.48 1186.9E 7564.4 71 77.2 1509.58 201.8W 253.1 1451.2 1452.6 ) ,) 7600.0 7282.6 1093.28 1192.1E 7658.2 7270.9 1507.58 202.8W 253.5 1455.2 1456.4 7700.0 7382.5 1096.88 1196.1E 7752.0 7364.7 1505.78 204.3W 253.7 1459.0 1459.9 7800.0 7482.4 1099.38 1198.7E 7884.4 7497.0 1503.28 205.7W 254.0 1461.5 1461.5 7900.0 7582.4 1100.58 1200.1E 7968.1 7580.7 1501.38 205.8W 254.1 1461.9 1462.0 8000.0 7682.4 1100.78 1200.3E 8044.5 7657.1 1499.88 207.4W 254.2 1463.4 1463.7 8100.0 7782.4 1100.78 1200.3E 8142.1 7754.6 1498.88 209.6W 254.2 1465.3 1465.6 8200.0 7882.4 1100.78 1200.3E 8250.1 7862.7 1498.08 211 . 9W 254.3 1467.2 1467.3 8300.0 7982.4 1100.78 1200.3E 8350.1 7962.6 1496.78 213 . 7W 254.4 1468.5 1468.7 8400.0 8082.4 1100.78 1200.3E 8449.1 8061. 6 1496.08 215.7W 254.4 1470.3 1470.5 8500.0 8182.4 1100.78 1200.3E 8561.5 8173.9 1494.78 217.4W 254.5 1471.5 1471.5 8600.0 8282.4 1100.78 1200.3E 8668.1 8280.6 1493.28 218.2W 254.5 1471.8 1471.8 8700.0 8382.4 1100.78 1200.3E 8777.0 8389.4 1492.48 218.3W 254.6 1471.7 1471.7 8800.0 8482.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1471.4 8900.0 8582.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1475.6 9000.0 8682.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1486.6 9100.0 8782.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1504.1 9200.0 8882.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1528.0 9300.0 8982.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1557.9 9400 . 0 9082.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1593.6 9500.0 9182.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1634.6 9600.0 9282.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1680.5 9700.0 9382.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1731.1 9800.0 9482.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1785.8 9900.0 9582.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1844.3 10000.0 9682.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1906.2 10100.0 9782.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 1971.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 12 Pad #3,BC-13 Your ref: BC-13 Verso #3 Beaver Creek Unit, Kenai Peninsula, Alaska Last revised : 13 -Aug-2003 Reference wellpath Object wellpath : 8chlumberger <5943-8858'>"BC-9,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 10200.0 9882.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 2039.2 10300.0 9982.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 2109.7 10400.0 10082.4 1100.78 1200.3E 8858.0 8470.4 1492.08 218.1W 254.6 2182.5 ) ) ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3, BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 2800.0 2900.0 2500.0 2600.0 2699.7 2799.1 2898.0 3000.0 3100.0 3200.0 3300.0 3400.0 2996.0 3093.2 3189.2 3283.9 3377.0 3500.0 3600.0 3700.0 3800.0 3900.0 3468.6 3558.3 3647.6 3737.0 3826.3 4000.0 4100.0 4200.0 4300.0 4400.0 3915.6 4004.9 4094.2 4183.5 4272.8 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON 1. 58 5.98 13.38 23.58 36.78 52.88 71.78 93.48 11 7 . 98 145.18 174.98 205.38 235.78 266.18 296 . 58 326.98 357.48 387.88 418.28 40.0E 57.6E 78.2E 101.9E 128.6E 158.3E 190.7E 223.9E 257.0E 290.2E 323.4E 356.5E 389.7E 422.9E 456.0E Obj ect wellpath O.OE O.OE O.OE O.OE O.OE 0.0 94.5 195.0 294.8 394.8 O.OE O.OE O.OE O.OE O.OE 494.7 594.0 689.4 785.3 880.0 O.OE O.OE O.OE O.OE O.OE 977.3 1073.1 1166.5 1257.2 1343.4 O.OE O.OE O.OE O.OE O.OE 1430.6 1513.9 1594.0 1675.7 1750.8 O.OE O.OE O.OE O.OE O.OE 1825.7 1898.6 1963.1 2032.3 2110.8 O.OE 1. 6E 6.4E 14.5E 25.7E 2187.8 2265.4 2347.2 2427.2 2505.4 2582.8 2656.7 2732.0 2806.6 2879.1 2948.7 3020.1 3095.0 3170.4 3247.6 3333.6 3413.5 3493.8 3572.4 3649.3 M.D. T.V.D. 6.0 100.5 201.0 300.8 400.8 500.6 599.9 695.3 790.8 884.5 980.3 1074.2 1165.4 1253.2 1335.8 1418.0 1495.4 1568.8 1642.5 1709.2 1774.5 1837.0 1891. 2 1948.4 2012.5 2075.1 2137.9 2204.1 2268.8 2332.0 2394.4 2453.9 2514.4 2574.3 2632.3 2688.0 2745.0 2804.9 2865.2 2927.2 2996.4 3060.9 3126.0 3189.9 3252.6 CLEARANCE LI8TING Page 13 Your ref: BC-13 Verso #3 Last revised: 13-Aug-2003 M88 <0-6387>, ,BC-3,Pad #3 Rect Coordinates Horiz Min'm Bearing Dist TCyl Dist 66.0N 65.7N 64.9N 64.0N 63.1N 62.3N 61.7N 64.4N 71.5N 82.0N 95.1N 108.9N 124.5N 141.9N 161.1N 183.4N 206.6N 230.5N 256.7N 282.3N 309.4N 337.5N 363.7N 392 . 9N 426.1N 458.6N 492.3N 527.1N 560.4N 593.0N 625.5N 657.1N 689.8N 722. ON 753.4N 783.8N 815.1N 847.8N 880.4N 913 .6N 950.3N 984.2N 1018.0N 1050.9N 1082.9N 29.9E 29.5E 28.3E 27.0E 26.0E 25.3E 24.7E 26.2E 31.4E 39.9E 51.1E 63.3E 76.4E 90.8E 106.5E 125.2E 145.5E 167.0E 190.6E 213 .6E 238.1E 263.2E 286.2E 312.0E 342.8E 373.6E 404.3E 437.5E 470.7E 503.3E 535.5E 565.9E 596 . 6E 627.4E 657.4E 686.1E 715.4E 746.3E 777.6E 809.6E 845.1E 877.8E 910.4E 942.2E 973.4E 24.4 24.2 23.5 22.9 22.4 22.1 21.8 22.1 23.7 26.0 28.3 30.2 31.5 32.6 33.5 34.3 35.2 35.9 36.6 37.1 37.6 37.9 38.2 38.5 38.8 39.2 39.2 39.0 38.5 37.8 36.8 1022.8 35.6 1082.2 34.2 1141.9 32.8 1201.9 31.3 1262.3 29.6 1323.2 27.9 1384.6 26.4 1446.4 25.0 1508.8 23.8 1571.6 22.7 1634.5 21.7 1697.6 20.7 1760.7 19_8 1823.9 19.0 1887.3 72.7 72.1* 70.8* 69.5* 68.3* 70.8 69.5* 68.3* 67.3* 66.5* 69.7 78.6 92.5 67.3* 66.5* 69.8 79.1 93.8 109.7 128.5 150.1 174.8 203.6 111.6 131.3 154.4 181. 9 215.4 236.7 273.5 313.4 356.4 402.2 254.6 299.1 349.1 405.5 468.7 450.9 502.4 556.4 612.7 670.2 538.0 609.5 682.0 754.5 827.6 728.3 787.1 845.9 904.7 963.7 901.3 976.6 1052.9 1130.0 1207.5 1285.4 1363.9 1443.6 1525.6 1610.3 1698.3 1787.5 1870.8 1954.6 2039.5 2126.2 2213.4 2301. 2 2390.1 2479.2 4500.0 4362.1 448.68 489.2E 3726.9 3315.7 1114.9N 1005.2E 18.3 1950.8 2568.2 4600.0 4451. 4 479.08 522.3E 3804.8 3379.2 1146.8N 1037.1E 17.6 2014.4 2656.9 4700.0 4540.7 509.48 555.5E 3883.0 3443.1 11 7 8 . 7N 1069.0E 16.9 2078.0 2745.9 4800.0 4630.0 539.88 588.7E 3961. 3 3507.2 1210.6N 1100.9E 16.3 2141.7 2836.0 4900.0 4719.3 570.28 621.8E 4037.7 3569.7 1241.6N 1131. 9E 15.7 2205.5 2927.3 5000.0 4808.6 600.68 655.0E 4114.5 3632.6 1272.7N 1163.0E 15.2 2269.5 3019.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 14 Pad #3,BC-13 Your ref : BC-13 Verso #3 Beaver Creek Unit, Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath : M88 <0-6387>"BC-3,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 4194.0 3697.7 1304.7N 1195.4E 14.7 2333.5 3112.9 5200.0 4987.2 661. 58 721. 3E 4271.3 3761. 0 1335.6N 1227.2E 14.2 2397.5 3206.5 5300.0 5076.6 691.88 754.5E 4346.0 3822.2 1365.4N 1258.1E 13 .8 2461. 6 5400.0 5166.4 721.58 786.8E 4421.1 3883.8 1395.3N 1289.0E 13.3 2525.6 5500.0 5257.0 750.28 818.1E 4491. 2 3941.1 1423.3N 1317.9E 13.0 2589.5 5600.0 5348.3 777.78 848.1E 4555.6 3993.8 1449.4N 1344.2E 12.6 2653.4 5700.0 5440.3 804.28 877.0E 4619.8 4046.4 1475.7N 1370.3E 12.2 2717.4 5800.0 5532.9 829.68 904.7E 4690.5 4104.1 1504.9N 1398.6E 11.9 2781.3 5900.0 5626.3 853.98 931.2E 4768.0 4167.4 1537.0N 1430.0E 11.82844.9 6000.0 5720.2 877.18 956.5E 4846.1 4231. 0 1569.2N 1461.7E 11.7 2908.1 6100.0 5814.7 899.28 980.5E 4920.5 4291. 5 1599.7N 1492.3E 11.6 2970.9 6200.0 5909.8 920.18 1003.4E 4990.8 4348.7 1628.7N 1521.3E 11.5 3033.5 6300.0 6005.4 940.08 1025.0E 5061.2 4405.7 1657.9N 1550.4E 11.4 3095.7 6400.0 6101.5 958.78 1045.4E 5136.9 4467.0 1689.3N 1581.9E 11.5 3157.7 6500.0 6198.0 976.28 1064.6E 5218.3 4532.7 1722.8N 1616.3E 11.6 3219.1 6600.0 6295.0 992.78 1082.5E 5299.9 4598.4 1756.1N 1651.4E 11.7 3279.9 6700.0 6392.4 1007.98 1099.2E 5383.7 4665.8 1790.1N 1687.8E 11.9 3340.2 6800.0 6490.2 1022.18 1114.6E 5469.8 4735.1 1824.9N 1725.2E 12.1 3399.8 6900.0 6588.4 1035.08 1128.7E 5549.7 4799.5 1857.2N 1759.8E 12.3 3458.8 7000.0 6686.8 1046.98 1141.6E 5624.3 4859.6 1887.4N 1792.1E 12.5 3517.3 7100.0 6785.6 1057.58 1153.2E 5686.4 4909.6 1912.6N 1819.0E 12.6 3575.5 7200.0 6884.6 1067.08 1163.6E 5766.4 4973.8 1945.4N 1853.7E 12.9 3633.4 7300.0 6983.8 1075.38 1172.6E 5827.9 5023.1 1970.7N 1880.3E 13.1 3691.0 7400.0 7083.3 1082.48 1180.4E 5907.8 5087.0 2003.8N 1915.1E 13.4 3748.3 7500.0 7182.9 1088.48 1186.9E 5968.6 5135.5 2029.1N 1941. 5E 13.6 3805.3 7600.0 7282.6 1093.28 1192.1E 6035.3 5188.6 2057.1N 1970.5E 13.9 3862.0 7700.0 7382.5 1096.88 1196.1E 6114.9 5251.9 2090.6N 2005.3E 14.2 3918.3 7800.0 7482.4 1099.38 1198.7E 6187.5 5309.5 2121.1N 2037.3E 14.6 3974.3 7900.0 7582.4 1100.58 1200.1E 6259.7 5366.7 2151.4N 2069.3E 15.0 4029.9 8000.0 7682.4 1100.78 1200.3E 6331. 4 5423.3 2181.5N 2101. 3E 15.3 4085.1 8100.0 7782.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4140.6 8200.0 7882.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4197.3 8300.0 7982.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4255.6 8400.0 8082.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4315.5 8500.0 8182.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4376.8 8600.0 8282.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4439.5 8700.0 8382.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4503.6 8800.0 8482.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4569.0 8900.0 8582.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4635.6 9000.0 8682.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4703.4 9100.0 8782.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4772.3 9200.0 8882.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4842.3 9300.0 8982.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4913.3 9400.0 9082.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 4985.4 9500.0 9182.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5058.4 9600.0 9282.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5132.2 9700.0 9382.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5207.0 9800.0 9482.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5282.6 9900.0 9582.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5359.0 10000.0 9682.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5436.2 10100.0 9782.4 1100.78 1200.3E 6387.0 5467.2 2204.9N 2126.3E 15.6 5514.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. ) ) ) Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Reference wellpath Object wellpath CLEARANCE LISTING Page 15 Your ref: BC-13 Verso #3 Last revised : 13-Aug-2003 MSS <0-6387>, ,BC-3,Pad #3 MARATHON Oil Company Pad #3rBC-13 Beaver Creek Unit, Kenai Peninsula, Alaska M.D. T.V.D. Rect Coordinates M.D. T.V.D. 10200.0 9882.4 1l00.7S 1200.3E 6387.0 5467.2 10300.0 9982.4 1l00.7S 1200.3E 6387.0 5467.2 10400.0 10082.4 1l00.7S 1200.3E 6387.0 5467.2 Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 2204.9N 2126.3E 15.6 5592.7 2204.9N 2126.3E 15.6 5672.0 2204.9N 2126.3E 15.6 5751.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska CLEARANCE LISTING Page 16 Your ref: BC-13 Verso #3 Last revised : 13-Aug-2003 Reference wellpath Obj ect wellpath MWD <6433-10005>"BC-3Rd,Pad #3 Horiz Min'm TCyl ) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.2 0.2 66.0N 29.9E 24.4 72.5 72.5 100.0 100.0 O.ON O.OE 100.5 100.5 65.7N 29.5E 24.1 72.0* 72.0* 200.0 200.0 O.ON O.OE 201.0 201.0 64.9N 28.2E 23.5 70.7* 70.8* 300.0 300.0 O.ON O.OE 300.8 300.8 63.9N 27.0E 22.9 69.4* 69.4* 400.0 400.0 O.ON O.OE 400.8 400.8 63.1N 26.0E 22.4 68.2* 68.2* 500.0 500.0 O.ON O.OE 500.7 500.6 62.3N 25.3E 22.1 67.2* 67.2* 600.0 600.0 O.ON O.OE 600.0 599.9 61.7N 24.7E 21.8 66.4* 66.4* 700.0 700.0 O.ON O.OE 695.4 695.3 64.3N 26.1E 22.1 69.6 69.8 800.0 800.0 O.ON O.OE 791.4 790.8 71.4N 31.4E 23.7 78.6 79.1 900.0 900.0 O.ON O.OE 886.0 884.5 82.0N 39.9E 25.9 92 .5 93.8 1000.0 1000.0 O.ON O.OE 983.3 980.3 95.0N 51.1E 28.3 109.7 111.5 1100.0 1100.0 O.ON O.OE 1079.1 1074.2 108.8N 63.3E 30.2 128.5 131.3 1200.0 1200.0 O.ON O.OE 11 72.5 1165.4 124.4N 76.3E 31.5 150.0 154.4 1300.0 1300.0 O.ON O.OE 1263.2 1253.2 141.8N 90.8E 32.6 174.8 181. 9 1400.0 1400.0 O.ON O.OE 1349.4 1335.8 161.1N 106.5E 33.5 203.5 215.4 1500.0 1500.0 O.ON O.OE 1436.6 1418.0 183.4N 125.2E 34.3 236.7 254.5 1600.0 1600.0 O.ON O.OE 1519.9 1495.4 206.6N 145.5E 35.2 273.4 299.0 1700.0 1700.0 O.ON O.OE 1600.1 1568.8 230.4N 167.0E 35.9 313.3 349.1 1800.0 1800.0 O.ON O.OE 1681.8 1642.5 256.6N 190.5E 36.6 356.3 405.4 1900.0 1900.0 O.ON O.OE 1756.8 1709.2 282.2N 213.6E 37.1 402.1 468.6 2000.0 2000.0 O.ON O.OE 1831.7 1774.5 309.4N 238.1E 37.6 450.8 538.0 2100.0 2100.0 O.ON O.OE 1904.7 1837.0 337.5N 263.2E 37.9 502.3 609.5 2200.0 2200.0 O.ON O.OE 1969.1 1891.2 363.7N 286.1E 38.2 556.4 682.0 2300.0 2300.0 O.ON O.OE 2038.4 1948.4 392 . 9N 312.0E 38.5 612.6 754.5 2400.0 2400.0 O.ON O.OE 2116.8 2012.6 426.1N 342.8E 38.8 670.2 827.5 2500.0 2500.0 O.ON O.OE 2193.8 2075.2 458.6N 373.6E 39.2 728.3 901.3 2600.0 2600.0 1. 58 1. 6E 2271.4 2137.9 492.2N 404.3E 39.2 787.0 976.6 2700.0 2699.7 5.98 6.4E 2353.2 2204.2 527.1N 437.4E 39.0 845.8 1052.9 2800.0 2799.1 13.38 14.5E 2433.2 2268.8 560.4N 470.6E 38.5 904.7 1129.9 2900.0 2898.0 23.58 25.7E 2511.4 2332.0 593.0N 503.2E 37.8 963.6 1207.5 3000.0 2996.0 36.78 40.0E 2588.8 2394.4 625.5N 535.5E 36.8 1022.7 1285.4 3100.0 3093.2 52.88 57.6E 2662.8 2454.0 657.1N 565.9E 35.6 1082.1 1363.9 3200.0 3189.2 71.78 78.2E 2738.0 2514.4 689.8N 596.6E 34.2 1141.8 1443.6 3300.0 3283.9 93.48 101.9E 2812.7 2574.3 722.0N 627.3E 32.8 1201.9 1525.6 3400.0 3377.0 11 7.98 128.6E 2885.1 2632.3 753.4N 657.4E 31.3 1262.3 1610.2 3500.0 3468.6 145.18 158.3E 2954.8 2688.0 783.8N 686.1E 29.6 1323.1 1698.3 3600.0 3558.3 174.98 190.7E 3026.1 2745.0 815.1N 715.4E 27.9 1384.5 1787.5 3700.0 3647.6 205.38 223.9E 3101.0 2804.9 847.8N 746.3E 26.4 1446.4 1870.8 3800.0 3737.0 235.78 257.0E 3176.4 2865.3 880.4N 777.5E 25.0 1508.8 1954.5 3900.0 3826.3 266.18 290.2E 3253.7 2927.2 913 . 6N 809.6E 23.8 1571.6 2039.5 4000.0 3915.6 296.58 323.4E 3339.6 2996.4 950.3N 845.0E 22.7 1634.5 2126.1 4100.0 4004.9 326.98 356.5E 3419.5 3060.9 984.2N 877.7E 21.7 1697.5 2213.4 4200.0 4094.2 357.48 389.7E 3499.8 3126.0 1018.0N 910.4E 20.7 1760.7 2301.2 4300.0 4183.5 387.88 422.9E 3578.4 3190.0 1050.9N 942.2E 19.8 1823.9 2390.0 4400.0 4272.8 418.28 456.0E 3655.4 3252.6 1082.9N 973 .4E 19.0 1887.2 2479.2 4500.0 4362.1 448.68 489.2E 3732.9 3315.7 1114.8N 1005.1E 18.3 1950.7 2568.1 4600.0 4451.4 479.08 522.3E 3810.8 3379.3 1146.8N 1037.1E 17.6 2014.3 2656.9 4700.0 4540.7 509.48 555.5E 3889.0 3443.1 11 7 8 . 7N 1069.0E 16.9 2078.0 2745.8 4800.0 4630.0 539.88 588.7E 3967.4 3507.2 1210.5N 1100.8E 16.3 2141.7 2836.0 4900.0 4719.3 570.28 621.8E 4043.8 3569.8 1241. 5N 1131.8E 15.7 2205.5 2927.3 5000.0 4808.6 600.68 655.0E 4120.5 3632.6 1272.7N 1163.0E 15.2 2269.4 3019.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company CLEARANCE LI8TING Page 17 Pad #3, BC-13 Your ref : BC-13 Verso #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath MWD <6433-10005>, ,BC-3Rd,Pad #3 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 4200.0 3697.7 1304.7N 1195.4E 14.7 2333.4 3112.9 5200.0 4987.2 661.58 721. 3E 4277.3 3761. 0 1335.6N 1227.2E 14.2 2397.4 3206.4 5300.0 5076.6 691.88 754.5E 4352.0 3822.3 1365.4N 1258.0E 13.8 2461. 5 3294.7 5400.0 5166.4 721.58 786.8E 4427.1 3883.8 1395.3N 1289.0E 13 .3 2525.5 3366.9 5500.0 5257.0 750.28 818.1E 4497.2 3941. 2 1423.3N 1317.9E 13 .0 2589.4 3437.2 5600.0 5348.3 777.78 848.1E 4561.6 3993.9 1449.3N 1344.2E 12.6 2653.4 3506.0 5700.0 5440.3 804.28 877.0E 4625.9 4046.4 1475.6N 1370.2E 12.2 2717.3 3573.7 5800.0 5532.9 829.68 904.7E 4696.5 4104.1 1504.9N 1398.6E 11. 9 2781.2 3640.9 5900.0 5626.3 853.98 931.2E 4774.1 4167.4 1537.0N 1429.9E 11.8 2844.9 3707.1 TCyl Dist 24.7 4848.2 24.7 4873.2 24.7 4900.2 Horiz Min'm Bearing Dist 3170.0E 3170.0E 3170.0E 3172 . 2N 3172.2N 3172.2N Rect Coordinates MWD <6433-10005>, ,BC-3Rd,Pad #3 CLEARANCE LI8TING Page 18 Your ref : BC-13 Verso #3 Last revised : 13-Aug-2003 8713.3 8713.3 8713.3 M.D. T.V.D. 1200.3E 10005.0 1200.3E 10005.0 1200.3E 10005.0 Object wellpath 1100.78 1100.78 1100.78 Rect Coordinates 10200.0 9882.4 10300.0 9982.4 10400.0 10082.4 Reference wellpath M.D. T.V.D. MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 4621.6 4638.9 4658.3 4677.7 4698.4 4537.3 4555.9 4572.5 4588.2 4605.1 4451.3 4470.6 4487.4 4502.5 4518.8 4321.1 4352.6 4380.9 4406.5 4430.0 4105.4 4154.7 4201.7 4245.0 4285.2 3834.9 3896.0 3952.2 4004.7 4055.6 3771.8 24.7 4825.0 24.5 4725.3 24.6 4744.4 24.7 4763.5 24.7 4783.1 24.7 4803.7 24.2 4641.2 24.3 4657.2 24.4 4673.9 24.5 4690.2 24.5 4707.2 18.4 4410.1 18.7 4464.7 19.1 4519.6 19.5 4574.5 24.0 4625.4 16.1 4139.7 16.7 4193.8 17.2 4247.8 17.6 4301.8 18.1 4355.8 13.9 3862.0 14.2 3918.3 14.6 3974.3 15.0 4029.8 15.3 4085.1 12.6 3575.5 12.9 3633.3 13.1 3690.9 13.43748.2 13.6 3805.2 11.7 3279.9 11.9 3340.2 12.1 3399.8 12.3 3458.8 12.5 3517.3 11.6 2970.9 11.5 3033.4 11.4 3095.7 11.5 3157.6 11.6 3219.1 11.7 2908.1 3170.0E 3127.3E 3136.4E 3151.9E 3158.3E 3164.7E 3082.8E 3092.0E 3104.7E 3114.8E 3123.4E 2367.1E 2398.9E 2434.7E 2474.7E 3052.3E 2165.7E 2218.5E 2256.7E 2298.1E 2335.6E 1970.5E 2005.3E 2037.2E 2069.2E 2101. 3E 1818.9E 1853.6E 1880.3E 1915.0E 1941.4E 1651.4E 1687.8E 1725.2E 1759.8E 1792.1E 1492.2E 1521.2E 1550.4E 1581.9E 1616.3E 1461.7E ) 3172 . 2N 3122.2N 3131 . 6N 3148.7N 3156.7N 3165.2N 3079.7N 3087.8N 3100.0N 3109.6N 3118.2N 2408.3N 2436.1N 2468.6N 2505.5N 3052.6N 2238.5N 2282.9N 2315.1N 2349.7N 2381.3N 2057.1N 2090.5N 2121.1N 2151.4N 2181.5N 1912.6N 1945.3N 1970.6N 2003.8N 2029.1N 1756.1N 1790.1N 1824.9N 1857.2N 1887.3N 1599.7N 1628.7N 1657.9N 1689.3N 1722.8N 1569.2N 1200.3E 10005.0 8713.3 8397.9 8461.1 8574.0 8624.2 8673.4 8060.1 8129.2 8225.4 8304.0 8369.5 5879.4 5935.3 5999.8 6072.9 7836.8 5534.0 5623.4 5689.0 5759.6 5824.4 5188.6 5251.9 5309.5 5366.7 5423.4 4909.6 4973.9 5023.1 5087.0 5135.5 4598.4 4665.8 4735.1 4799.6 4859.7 4291.6 4348.7 4405.8 4467.0 4532.7 4231.0 9682.8 9747.4 9862.6 9913.8 9964.2 9339.5 9409.6 9507.4 9587.3 9653.9 6912.0 6982.1 7062.6 7153.8 9112.5 6477.5 6590.5 6673.0 6761.8 6843.1 6041.3 6120.9 6193.5 6265.7 6337.4 5692.4 5772.5 5833.9 5913.9 5974.6 5305.9 5389.7 5475.8 5555.8 5630.3 4926.5 4996.8 5067.2 5143.0 5224.3 4852.1 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1200.3E 1192.1E 1196 .1E 1198.7E 1200.1E 1200.3E 1153.2E 1163.6E 11 72 .6E 1180.4E 1186.9E 1082.5E 1099.2E 1114.6E 1128.7E 1141.6E 980.5E 1003.4E 1025.0E 1045.4E 1064.6E 956.5E 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1100.78 1093.28 1096.88 1099.38 1100.58 1100.78 1057.58 1067.08 1075.38 1082.48 1088.48 992.78 1007.98 1022.18 1035.08 1046.98 899.28 920.18 940.08 958.78 976.28 877.18 ') 10100.0 9782.4 9282.4 9382.4 9482.4 9582.4 9682.4 9600.0 9700.0 9800.0 9900.0 10000.0 8782.4 8882.4 8982.4 9082.4 9182.4 9100.0 9200.0 9300.0 9400 . 0 9500.0 8282.4 8382.4 8482.4 8582.4 8682.4 8600.0 8700.0 8800.0 8900.0 9000.0 7782.4 7882.4 7982.4 8082.4 8182.4 8100.0 8200.0 8300.0 8400.0 8500.0 7282.6 7382.5 7482.4 7582.4 7682.4 7600.0 7700.0 7800.0 7900.0 8000.0 6785.6 6884.6 6983.8 7083.3 7182.9 7100.0 7200.0 7300.0 7400.0 7500.0 6295.0 6392.4 6490.2 6588.4 6686.8 6600.0 6700.0 6800.0 6900.0 7000.0 5814.7 5909.8 6005.4 6101.5 6198.0 6100.0 6200.0 6300.0 6400.0 6500.0 5720.2 6000.0 ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3rBC-13 Beaver Creek Unit, Kenai Peninsular Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 2800.0 2500.0 2600.0 2699.7 2799.1 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON 1. 5S 5.9S 13.3S Obj ect wellpath O.OE O.OE O.OE O.OE O.OE 0.0 100.0 200.1 300.1 400.2 O.OE O.OE O.OE O.OE O.OE 500.1 600.0 699.9 799.9 900.0 O.OE O.OE O.OE O.OE O.OE 1000.3 1100.8 1201.0 1300.4 1397.0 O.OE O.OE O.OE O.OE O.OE 1496.5 1596.7 1696.8 1796.9 1896.9 O.OE O.OE O.OE O.OE O.OE 1997.1 2097.3 2198.1 2298.4 2398.5 O.OE 1.6E 6.4E 14.5E 2498.8 2599.1 2698.5 2797.9 M.D. T.V.D. 0.0 100.0 200.1 300.1 400.2 500.1 600.0 699.9 799.8 899.9 1000.1 1100.6 1200.7 1300.1 1396.7 1496.2 1596.3 1696.4 1796.5 1896.5 1996.7 2096.8 2197.6 2297.9 2398.0 2498.3 2598.6 2698.0 2797.3 CLEARANCE LISTING Page 19 Your ref : BC-13 Verso #3 Last revised : 13-Aug-2003 MWD <0-8931>"BC-11,Pad #3 Rect Coordinates Horiz Min'm Bearing Dist TCyl Dist 177.0N 177.0N 176.9N 176.8N 176.7N 176.7N 176.6N 176.6N 176.7N 176.7N 176.6N 176.2N 175.5N 174.8N 175.3N 177.4N 179.6N 181.7N 183.7N 185.7N 187.6N 189.4N 191.1N 192.3N 193.4N 194.4N 195.2N 195.9N 196.8N 9.6W 12.9W 15.7W 18.5W 20.0W 2.9E 2.8E 2.6E 2.3E 1.6E 0.7E 0.3W 1. 6W 3.4W 6.1W 19.8W 19.2W 18.4W 17.6W 16.8W 15.8W 14.6W 13 .2W 12.0W 10.9W 9.7W 8.7W 7.8W 6.9W 0.9 0.9 0.9 0.7 0.5 177.0 177.0* 176.9* 176.9* 176.7* 177.0 177.0* 176.9* 176.9* 176.7* 0.2 359.9 359.5 358.9 358.0 176.7* 176.6* 176.6 176.7 176.8 176.7* 176.6* 176.6 176.7 176.8 356.9 355.8 354.9 354.0 353.5 176.9 176.6* 176.2* 175.8* 176.5 176.9 176.6* 176.2* 175.8* 176.5 353.6 353.9 354.2 354.5 354.8 178.6 180.6 182.6 184.6 186.5 178.6 180.7 182.7 184.6 186.5 355.2 355.6 356.0 356.4 356.8 188.3 190.0 191.5 192.7 193.7 188.3 190.0 191.6 192.7 193.8 357.1 357.0 356.0 354.2 194.7 196.9 202.3 211.2 194.7 197.1 202.8 212.4 ) ) 2900.0 2898.0 23.58 25.7E 2897.1 2896.5 197.8N 6.0W 351.9 223.6 225.8 3000.0 2996.0 36.78 40.0E 2995.4 2994.9 198.6N 4.9W 349.2 239.5 243.5 3100.0 3093.2 52.88 57.6E 3092.6 3092.1 199.3N 3.8W 346.3 259.4 266.0 3200.0 3189.2 71.78 78.2E 3188.5 3187.9 199.9N 2.7W 343.4 283.4 294.0 3300.0 3283.9 93.48 101.9E 3282.4 3281. 8 200.7N 1.8W 340.6 311.9 328.2 3400.0 3377.0 117.98 128.6E 3375.3 3374.7 201.6N 1.2W 337.9 344.9 369.1 3500.0 3468.6 145.18 158.3E 3467.1 3466.5 202.4N 0.8W 335.4 382.2 417.4 3600.0 3558.3 174.98 190.7E 3556.2 3555.6 203.1N 0.5W 333.2 423.6 473.5 3700.0 3647.6 205.38 223.9E 3638.5 3637.9 204.3N 0.2W 331.3 467.0 528.6 3800.0 3737.0 235.78 257.0E 3720.1 3719.4 207.0N O.OE 329.9 512.2 587.0 3900.0 3826.3 266.18 290.2E 3796.7 3795.9 211 . 2N 0.6E 328.7 559.1 649.2 4000.0 3915.6 296.58 323.4E 3875.0 3873.9 217.4N 1. 5E 327.9 607.8 716.1 4100.0 4004.9 326.98 356.5E 3950.5 3949.0 225.0N 2.9E 327.4 657.9 790.2 4200.0 4094.2 357.48 389.7E 4025.4 4023.4 234.5N 5.0E 327.0 709.4 871.4 4300.0 4183.5 387.88 422.9E 4099.6 4096.6 245.9N 7.9E 326.8 762.4 965.0 4400.0 4272.8 418.28 456.0E 4169.3 4165.0 258.6N 11.2E 326.7 817.0 1072.5 4500.0 4362.1 448.68 489.2E 4235.8 4230.0 272 . 6N 14.6E 326.7 873.4 1180.8 4600.0 4451. 4 479.08 522.3E 4289.2 4281.7 285.4N 17.3E 326.5 931.8 1285.4 4700.0 4540.7 509.48 555.5E 4344.9 4335.3 300.2N 20.1E 326.5 992.1 1387.7 4800.0 4630.0 539.88 588.7E 4408.5 4396.1 318.7N 23.5E 326.6 1054.1 1488.0 4900.0 4719.3 570.28 621.8E 4457.0 4442.1 333.8N 26.5E 326.6 1117.4 1586.5 5000.0 4808.6 600.68 655.0E 4504.4 4486.6 350.0N 29.6E 326.7 1182.6 1682.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON 0 il Company CLEARANCE LI8TING Page 20 Pad #3,BC-13 Your ref : BC-13 Vers. #3 Beaver Creek Unit,Kenai Peninsula, Alaska Last revised : 13-Aug-2003 Reference wellpath Object wellpath MWD <0-8931>, ,BC-11,Pad #3 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5100.0 4897.9 631.08 688.2E 4546.9 4525.9 365.8N 32.5E 326.7 1249.8 1777.4 5200.0 4987.2 661.58 721.3E 4588.7 4564.2 382.4N 35.2E 326.7 1318.9 1870.2 5300.0 5076.6 691.88 754.5E 4626.0 4597.9 398.0N 37.4E 326.7 1389.6 1956.9 5400.0 5166.4 721.58 786.8E 4664.3 4632.3 415.0N 39.6E 326.7 1461.3 2018.4 5500.0 5257.0 750.28 818.1E 4724.1 4685.1 442.5N 43.3E 327.0 1532.9 2077.2 5600.0 5348.3 777.78 848.1E 4797.7 4750.1 476.9N 48.2E 327.5 1603.6 2132.8 5700.0 5440.3 804.28 877.0E 4880.0 4822.7 515.2N 54.4E 328.1 1673.0 2186.0 5800.0 5532.9 829.68 904.7E 4979.1 4910.5 560.4N 62.3E 328.8 1740.5 2236.7 5900.0 5626.3 853.98 931. 2E 5066.5 4988.3 599.5N 69.8E 329.3 1805.9 2285.2 6000.0 5720.2 877.18 956.5E 5151. 0 5063.8 636.6N 76.9E 329.8 1869.7 2331. 0 6100.0 5814.7 899.28 980.5E 5242.2 5145.8 675.9N 84.2E 330.4 1931.8 2374.0 6200.0 5909.8 920.18 1003.4E 5334.7 5229.4 714.9N 91.1E 330.8 1992 .1 2413.4 6300.0 6005.4 940.08 1025.0E 5425.6 5311.8 752.7N 97.9E 331.3 2050.8 2450.0 6400.0 6101.5 958.78 1045.4E 5519.0 5396.5 791.2N 105.8E 331. 8 2107.6 2484.8 6500.0 6198.0 976.28 1064.6E 5629.7 5497.2 836.3N 115.8E 332.4 2162.5 2517.1 6600.0 6295.0 992.78 1082.5E 5722.0 5581.2 873.3N 124.6E 332.8 2215.5 2546.9 6700.0 6392.4 1007.98 1099.2E 5825.3 5675.7 914.0N 134.4E 333.3 2266.7 2574.1 6800.0 6490.2 1022.18 1114.6E 5919.0 5761.7 950.1N 142.9E 333.8 2316.1 2598.7 6900.0 6588.4 1035.08 1128.7E 6020.4 5855.0 988.8N 152.2E 334.2 2363.8 2622.2 7000.0 6686.8 1046.98 1141. 6E 6100.1 5928.4 1018.9N 159.3E 334.6 2409.9 2644.7 7100.0 6785.6 1057.58 1153.2E 6197.4 6018.1 1055.7N 167.5E 335.0 2454.8 2665.3 7200.0 6884.6 1067.08 1163.6E 6297.5 6110.6 1093.0N 176.1E 335.4 2497.9 2683.2 7300.0 6983.8 1075.38 11 72 . 6E 6388.8 6195.2 1126.6N 183.4E 335.8 2539.5 2698.4 7400.0 7083.3 1082.48 1180.4E 6485.6 6285.0 1161.9N 190.8E 336.2 2579.5 2710.3 7500.0 7182.9 1088.48 1186.9E 6600.7 6392.0 1203.5N 199.5E 336.7 2617.9 2719.4 7600.0 7282.6 1093.28 1192 .1E 6793.2 6572.1 1269.3N 215.7E 337.5 2653.2 2725.7 7700.0 7382.5 1096.88 1196.1E 6914.2 6687.0 1306.6N 224.1E 338.0 2684.2 2730.0 7800.0 7482.4 1099.38 1198.7E 7177.5 6940.2 1376.9N 238.4E 338.8 2710.6 2733.2 7900.0 7582.4 1100.58 1200.1E 7256.7 7017.2 1395.3N 241.8E 339.0 2732.5 2735.5 8000.0 7682.4 1100.78 1200.3E 7861.8 7615.8 1467.7N 257.7E 339.8 2736.7 2737.5 8100.0 7782.4 1100.78 1200.3E 7963.5 7717.4 1470.9N 259.3E 339.9 2739.1 2739.8 8200.0 7882.4 1100.78 1200.3E 8070.9 7824.8 1474.0N 261.1E 340.0 2741.3 2741.8 8300.0 7982.4 1100.78 1200.3E 8172.7 7926.6 1476.8N 262.9E 340.0 2743.3 2743.9 8400.0 8082.4 1100.78 1200.3E 8269.9 8023.7 1479.4N 264.1E 340.1 2745.4 2746.0 8500.0 8182.4 1100.78 1200.3E 8365.4 8119.1 1482.2N 265.4E 340.1 2747.6 2748.4 8600.0 8282.4 1100.78 1200.3E 8461.9 8215.6 1485.1N 266.8E 340.1 2750.0 2750.8 8700.0 8382.4 1100.78 1200.3E 8559.4 8313_1 1488.2N 268.2E 340.2 2752.5 2753.4 8800.0 8482.4 1100.78 1200.3E 8653.9 8407.5 1491.3N 269.5E 340.2 2755.1 2756.2 8900.0 8582.4 1100.78 1200.3E 8745.3 8498.8 1494.6N 270.7E 340.3 2758.0 2759.4 ) ) 9000.0 8682.4 1100.78 1200.3E 8838.9 8592.3 1498.2N 272.0E 340.3 2761. 2 2762.7 9100.0 8782.4 1100.78 1200.3E 8931.0 8684.3 1501.8N 273.1E 340.4 2764.5 9200.0 8882.4 1100.78 1200.3E 8931.0 8684.3 1501. 8N 273.1E 340.4 2769.8 9300.0 8982.4 1100.78 1200.3E 8931.0 8684.3 1501.8N 273.1E 340.4 2778.8 9400.0 9082.4 1100.78 1200.3E 8931. 0 8684.3 1501.8N 273.1E 340.4 2791.2 9500.0 9182.4 1100.78 1200.3E 8931.0 8684.3 1501.8N 273.1E 340.4 2807.3 9600.0 9282.4 1100.78 1200.3E 8931.0 8684.3 1501. 8N 273.1E 340.4 2826.7 9700.0 9382.4 1100.78 1200.3E 8931.0 8684.3 1501. 8N 273.1E 340.4 2849.5 9800.0 9482.4 1100.78 1200.3E 8931. 0 8684.3 1501.8N 273.1E 340.4 2875.7 9900.0 9582.4 1100.78 1200.3E 8931.0 8684.3 1501.8N 273.1E 340.4 2905.0 10000.0 9682.4 1100.78 1200.3E 8931.0 8684.3 1501. 8N 273.1E 340.4 2937.5 10100.0 9782.4 1100.78 1200.3E 8931.0 8684.3 1501.8N 273.1E 340.4 2972.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3,BC-13 Beaver Creek Unit, Kenai Peninsula, Alaska CLEARANCE LI8TING Page 21 Your ref: BC-13 Verso #3 Last revised : 13-Aug-2003 Reference wellpath Object wellpath MWD <0-8931>"BC-11,Pad #3 M.D. T.V.D. Rect Coordinates M.D. T.V.D. 10200.0 9882.4 1100.78 1200.3E 8931.0 8684.3 10300.0 9982.4 1100.78 1200.3E 8931.0 8684.3 10400.0 10082.4 1100.78 1200.3E 8931. 0 8684.3 Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 1501.8N 273.1E 340.4 3011. 3 1501.8N 273.1E 340.4 3052.5 1501.8N 273.1E 340.4 3096.3 ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #13 and TVD from RKB (Glacier 1) (179.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 132.52 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. I I IN Prepared For: MARAT ON OIL COMPANY Well Beaver Creek # 13 Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: lJee Dewees Presented to: Win Tank Revised August 13th ,2003 e e - ~IFE ---... Marathon Oil Company Wen Name: Beaver Creek # 13 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will; Enclosed is the recommended drilling fluid program for the Beaver Creek # 13 Well to be drilled this year. The following is a brief synopsis of the program. Overview: Beaver Creek # 13 is a development well targeting the Beluga and Tyonek formations at the Beaver Creek field. F10-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 3 1/2" liner cemented in place. Surface Interval: The surface interval will be drilled with the standard Ge1/Ge1ex spud mud. No problems were noted in this interval while drilling Beaver Creek # 11. Intermediate Interval: This interval will be drilled with a F10-Pro fluid. After drilling out the surface cement, the well will be displaced to a standard F10-Pro KC1 fluid. Safecarb bridging material will be maintained according to the mud program to minimize losses to the formation. Fluid loss should be maintained @ 7 -8 cc' s API. Production Interval: This interval will be drilled with the modified Flo-Pro fluid. After drilling out the intermediate cement and 20- 25 feet of new hole, the well will be displaced to a modified F10-Pro KC1 fluid. Fluid loss should be maintained @ < 5 cc's API for this interval. Gas encountered may require the mud weight to be increased to +/- 11.0 ppg. Completion: This program assumes the well will be completed with 6% KC1 brine. Tony Tyka1sky Project Engineer M-I Drilling Fluids Reference Wells: Beaver Creek # 9, #10, #11 NOTE: This pr02:ram is provided as a 2uide onlv. Well conditions will always dictate fluid properties required. _j~~'í~ , -- -;¡~ - ~;jIFE -- ~ ~ e e Marathon Oil Company Wen Name: Beaver Creek # 13 Location: Kenai, Alaska. EXECUTIVE SUMMARY Our overall goal is no spills and no incidents while providing fluids and solids control services to our customer. Our goal for Beaver Creek # 13 is to remove drill solids from the mud system at a cost of less than $0.23 per pound. This has been the average for the last three years of centrifuge van operations With the revised fluid formulation (increasing the fluid agent concentration and maintaining a lower fluid loss), we expect to minimize formation damage and hole enlargement as demonstrated on Beaver Creek #3 RD. Use of the MI Swaco centrifuge van for the last three years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $500,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. ~~IFE ~ e e - ~IFE Marathon Oil Company Wen Name: Beaver Creek # 13 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth Interval (ft) Benchmark 1 Benchmark 2 Benchmark 3 Benchmark 4 Fluid cost per foot Volume Usage Solids Removal o - 2300' > $7.13 ft > 2795 bbls 2300 - 7270' > $29.86 ft > 3640 bbls 7270 - > $26.29 ft > 1610 bbls 10496' Total Avg. Max. Project < $23.78 < 8045 bbls < $0.23 Ib No Spills from Targets for Centrifuge Van Drilling Operation Interval F!i-~ ~IFE mœ Marathon Oil Company Wen Name: Beaver Creek # 13 Location: Kenai, Alaska. 13 3/8" 17-1/2" 2300' 2300' Gel/Gelex Spud Mud 8.6 - 9.4 5 $19,518 Screens 150/180 mesh Desilter Centrifuge Van 9 5/8" 12-1/4" 7270' 6954' Flo- Pro w/SafeCarb 9.0 9.6 14 $157,137 Screens 180 - 210 mesh Desilter Centrifuge Van 3-112" 8-1/2" 10496' 10179' Flo-Pro w/SafeCarb 9.0-9.6 10 $91,048 Screens 230 - 210 mesh Desilter Centrifuge Van 3 1/2" 8-1/2" Completion 10496' 10179' 6% KC1 8.55 2 $8,216 y Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). y Condition the mud prior to running casing for all intervals. y Cost does not include the use of any lubricants. IFE ") ) ---:S'1IFE Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Product Usage Summary PRODUCT U nit Size Surface IntermediateProductión Co~pleti()l1i ... ..... 16" 12-1/4" 8~112" . 3-1/2" TotaltJsage M-I Bar 100 lb 140 364 161 0 665 M - I Gel 100 lb 559 0 0 0 559 Soda Ash 50lb 20 18 8 0 46 Caustic Soda 50lb 28 36 16 0 50 Conqor 404 55 gal 0 8 5 0 13 SafeScav NA 55 gal 3 7 4 0 14 Sodium Bicarbonate 50lb 28 18 16 0 62 Conqor 303 55 gal 0 0 0 10 10 Flo Vis 25lb 0 291 64 4 359 Gelex 2lb 70 0 0 0 70 DualFlo 50lb 0 0 258 0 258 Polypac Supreme UL 50lb 17 109 0 0 126 Greencide 25G 55 gal 0 0 4 0 4 Bioban BP Plus 1 lb 0 291 129 0 420 KCI 50lb 0 1529 676 315 2520 Safecarb Fine 50lb 0 1456 644 0 2100 KlaGard 55 gal 0 0 14 0 14 SafeKleen 55 gal 0 1 1 1 3 Defoam X 5 gal 0 40 18 0 58 Engineer Service 1 day 5 14 10 2 31 ~I SIFE ~¡ ) ) ~IFE Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Offset Well Information Well Hole Size Depth PPG PV YP FL Comments BC#9 12.25 559 9.1 23 51 14 1865 9.5 12 13 14 LOT 12.0 EMW 8.5 2332 9.6 14 12 10.4 Drlg ahead 3158 9.8 15 12 10.8 4151 9.4 15 13 8.8 4929 9.4 18 16 6.8 5965 9.4 23 18 5.8 Hole tight on trip - lower fluid loss 6 6330 9.6 21 25 5.2 LOT 14.0 EMW 6346 9.7 19 30 4.5 Coring 7068 9.9 20 23 4.6 Gas, increase mud weight 7584 9.9 20 18 4.6 Drill ahead 8082 10 23 20 5 Coring 8540 10 23 22 6.6 Drlg ahead 8881 9.9 26 19 4.2 Trip ok @ TD. BC #10 8.5 215 8.65 12 37 20 Spud in 2385 8.9 16 13 10.6 Condition mud for cagin run w/Desco CF 6.125 3198 8.85 5 19 7.2 Drlg out, LOT 16.42 EMW, FloPro fluid 4516 9 6 21 7.6 Drlg 1318' in one day 5260 9 7 24 7.5 Drlg ahead 6440 9.25 8 29 7.1 Short trip - backreaming required 6906 9.3 9 27 7 Trip for bit - backream 7480 9.4 10 25 6.4 Trip in - OK 7788 9.5 10 25 6.3 Bit trip - backream through new hole section 8418 9.35 9 21 5.8 Trip in - OK drlg ahead 8587 9.4 9 19 6 Drlg ahead, trip for bit, backream new hole section 8854 9.55 9 20 6 @ T.D. POH for logs 8854 Spot 16 PPG pill on bottom prior to running casing BC #11 17.5 400 8.75 15 25 14 Spud in 1520 8.95 17 36 12.2 Drlg ahead 2202 9.4 15 25 9.4 TO of surface interval 12.25 2242 9.2 7 19 14.8 Drill out 3697 9.35 10 18 18.6 Drill ahead 4656 9.35 8 20 19.6 Drill ahead 5714 9.35 9 22 18.4 Short trip ok 5910 9.5 9 20 18.4 Adding SafeCarb to combat losses to formation 6620 9.4 10 20 15.4 Drlg ahead 6825 9.5 11 28 17.8 Drlg ahead, add Lubetex 7120 9.5 11 29 7 Drlg ahead control fluid loss with Pac 7260 9.6 12 31 7 Condition mud, run & cement casing 8.5 8036 9.35 10 26 6.8 Dril out drlg ahead 8652 9.4 10 24 7.4 Drlg ahead getting 1000 unit of gas 8931 9.55 9 22 8 At td - run logs ~elFE ~ ) ) ~IFE =:=;'....."'..~ ~~ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterlng B3 & B4 Sands - Refer to fluid formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. => FLUID LOSS CONTROL - In the intermediate interval the API fluid loss will be maintained in the < 5 cc's range. In the production interval the API fluid will be maintained at less than 5 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. It is particularly important to maintain a low hardness «200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If additions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained around 40,000 cps. In addition to adequate additions of FloVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. => DRILL SOLIDS - MBT - The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRISION - SafeScav NA additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm => GREENCIDE 25G ADDITIONS - Greencide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un- acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. r:!J elÆ ~ ') '.) ~..,...~ IFE ~;:".........~ ~~ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. Interval Summary - 17-1/2" hole o - 2300' Drilling Fluid System Gel/Gelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens -150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec./qt) (lb./l00ft2) (ml/30min) (% ) o - 2300' 8.6-9.2 60 - 100 25 - 35 NC - 12 +/- 9.5 <7% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. ~ Lower funnel viscosity to +/ - 75 after gravel zone has been drilled. ~ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. ~ Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval - 2452 barrels. ~ Estimated haul off volume - 5480 barrels. ~ ~IFE œm ) ) ~:i:~IFE Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Interval Summary - 12-1/4" hole 2300 - 7270' Drilling Fluid System Flo-Pro Fluid Key Products Flo- Vis / PoluPac UL / KCI / SafeCarb F, Ventrol 401 / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) ( cp.) ( cps) (ml/30min) (% ) 2300 - 5000' 9.0- 9.4 8 -12 40,000 6-8 +/- 9.5 +/- 5% 5000 - 7270' 9.2 - 9.4 10 - 14 40,000 6-8 +/- 9.5 +/ - 8% ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the following formula: ~ Drill water; .25 ppb Soda Ash; 2 ppb FloVis; ; 2 ppb PolyPac UL; 21 ppb KCI; 20 ppb SafeCarb Fine; Caustic Soda for pH of 9.5; Conqor 404 for 2000 ppm; SafeScav NA for DO reading of < 3 ppm ~ After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak off test ~ If running coals become a problem, treat with a 2 PPB addition ofVentrol401 and Asphasol D. ~ Estimated volume usage for interval- 3640 barrels. ~ Estimated haul off volume - 6535 barrels. ~ Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~ 91FE æm Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. 1.0 0.8 c: .2 "S =ê 1iJ Õ 0.6- () N ü? () u t '" c.. Q) :> :¡:; '" :¡ E 0.3T ;:¡ U 0.2 0.1 o . 1 xi 0-2 Oil Co. Beaqver Creek #13 Kenai Gas Field Stel1ing 83 & 84 Sands 100 mDarcy Max Permeability : Sand Control Device: © 1999-2001 M-IL-t.C - All Rights Reserved D10 Target I Blend: 0.4 D50 Target I Blend: 10.0 D90 Target I Blend: 32.4 0.9 microns 9.2 microns 23.5 microns Brand Name B=Safe-Carb 10 IF) D=Safe-Carb 40 1M) E=Safe-Carb 250 IC) Bridqinq Aqent Ob/bbl),lol % 20.0 100.00 0.0 0.00 0.0 0.00 u .--- B 100.0% Calcium Carbonate added: Avg Error 0 - 100 % CPS Range: Max Error 0 -100 % CPS Range: 20 Ib/bb! 3.16 % 13.33 % 1x'101 h'102 . Particle Size (microns) y Zone of interest - Sterling B-3 & B-4 sands )y Pore Pressure 4.4 -7.9 ppg - Maximum Porosity -100 mD )y Measured Depth - 5163' y Build additional volume as needed usin2 the blend listed above. IFE ') ") ~~~Ë~.·.':~ IFE ~ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. Interval Summary 8-1/2" hole Flo-Pro Fluid Formula Input Description Beaver Creek # 13 Mud Weight 9.05 Prehydrated Gel No Weight Material. Code SafeCarb Prehydrated Gel Cone. Weight Material SG 2.8 KCI Chloride Weight Material Price 0.35 KCI.Wt% 6 Sea Water No KCI Price 0.2516 Sea Salt No NaCI Chloride M-IGel NaCI Wt% M-I Gel Price NaCI Price Output -1 bbl I # Products Concentration Volume Cost Field,lb Lab, gm Field, bbl Lab, ml 1 bbl 1 Water 325.19 325.19 0.929 325.19 0.00 2 FloVis Plus 1.00 1.00 0.002 0.67 7.88 3 Dual Flo 8.00 8.00 0.015 5.33 1 3.44 4 SafeCarb Fine 20.00 20.00 0.02 7.92 1 0.44 5 Potassium Chloride 20.76 20.76 0.025 8.68 5.22 6 Greencide 25G 0.25 0.25 0.001 0.30 1.08 7 CONQOR 404 2.00 2.00 0.004 1.43 3.59 8 Caustic Soda 0.50 0.50 0.001 0.23 0.29 9 SafeScav NA 0.25 0.25 0.001 0.25 0.21 10 KlaGard 4.00 4.00 0.008 2.86 6.31 10 Lubetex As needed for torque reduction Desired Mud Properties PPG LSRV pH CI API Fluid Loss 9.05 +/- 40,000 9.5 30000 > 5.0 ee's DO PV YP Conqor404 >3 12-18 30 - 40 +/- 2000 Mix fluid in the order listed above. Wait for 1 - 2 circulations before adding SafeScav NA to the system. Alternate additions of Greencide 25G and SafeScav NA as needed. Maintain 8 ppb concentration of DualFlo to maintain as Iowa API fluid loss as possible. Plan on daily additions of DualFlo to achieve> 5.0 cc's API Fluid Loss Reduce concentration of FloVis as needed to maintain rheology. I I I Total I Calculated Mud Weight Total Chloride 380.1 380.1 9.050 29600 1.000 350 45.77 ~.IFE ~ ) ) ~:T^~ IFE ~ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Interval Summary - 8-1/2" hole 7270 - 10496' Drilling Fluid System Flo- Pro Fluid Key Products Flo- Vis / DualFlo / KCI / Greencide 25G / SafeCarb F, KlaGard / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) ( cp.) ( cps) (ml/30min) (% ) 7270 - 10496' 9.2 - 9.4 10 - 14 40,000 <5 +/- 9.5 +/- 5% ~ Use one rig pit for drilling out intermediate casing. In other rig pits, build new Flo-Pro fluid using the above formula. ~ If running coals become a problem, treat with a 2 PPB addition ofVentrol401 and Asphasol D. ~ Periodic additions of Greencide 25G will be needed to control bacteria build-up. ~ Estimated volume usage for interval - 1610 barrels. ~ Estimated haul off volume - 2738 barrels. ~ Condition mud prior to running 3-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~~IÆ ~' ) -' ~/.'~ IFE Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - HSE Issues HANDLING OF DRilliNG FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENT AL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. ~ .IFE E~ Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. Product Function PPE M-I BAR Weighting Agent E M-I GEL Viscosity control E GElEX Bentonite Extender E FlOVIS Viscosifier E DUAl-FlO Modified Starch E POlYPAC Fluid Loss Reducer E XCD Viscosifyer E HEC Loss Circulation Material E Safe-Carb F,M,C Bridging and weighting E agent lOWATE Weighting agent E Nut Plug Loss Circulation Material E M-I Seal F, M, C Loss circulation Material E Mix II F,M,C Loss circulation Material E DESCO CF Dispersant E SPERSENE CF Dispersant E TANNATHIN Dispersant E VENTROl 401 Surfactant ? SAl T (Solar) Densifier E BROMIDE (NaBr) & Densifier F Brine Solution POT ASSIUM Shale Inhibitor E CHLORIDE - IFE Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. Product Function PPE CAUSTIC SODA Alkalinity control X CAUSTIC POT ASH pH Modifier X BORAX Inorganic Borate E SAPP Sodium Pyrophosphate E SODA ASH Alkalinity control E SODIUM Alkalinity control E BICARBONATE CITRIC ACID pH Adjuster E BIOBAN BP-PLUS Biocide J GREEN CIDE 25G - Biocide J DEFOAM X - Defoamer J G-SEAL Sized graphite LCM E KLA-GARD Shale Control agent J LUBE TEX Lubricant J D-D CWT Detergent J Con cor 404 Corrosion Inhibitor J SAFEKLEEN Drilling fluid additive J AsphasolD Shale Inhibitor J Soltex Shale Inhibitor J SafeScav NA Oxygen Scavenger J IFE ) Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions Pf'f-fJ ~ ~ r ~ ~c~3IFE ~ ~ ) ") ~'~ IFE ~'~"\!"';'"':"'<-'.'.' .,-,..,'".'_,,-,no Marathon Oil Company Well Name: Beaver Creek # 13 Location: Kenai, Alaska. - Project Team Bob Williams Senior Engineer Floyd Faulkner Senior Engineer ~ ~iIIII~nI"rR ··'IV·_·····,·m,,~,.. .......... "It Craig Bieber District Manager ~- ~....'!\ ,...,.-.¡~' 1~""'11T-;'f·"""'··-¡-:·'.'.. ,;~~~ ..- ..".\, .,,'...'.. ';r Project Engineer ~ Deen Bryan Tech Service , Gus Wik 'ii". Warehouse Manager i~ ~~ðl'I~'_I'\'I/lItI~I.D\_;M~~I\"'~~","""" ·...'i.:I:I,n\ìl!.~~!l:N:.t..'.1\'4......."iJ . MI Project Engineer and Tech Service Engineer will coordinate between the Marathon office, ng, warehouse, and the M - I field engineers. . Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. Project Team Title Home Cellular Craig Bieber District Manager 907 345-1239 907229-1196 Deen Bryan Tech Service 907 373-2713 907 223-1634 Tony Tykalsky Project Engineer 907 376-4613 907 227-2412 Gus Wik Warehouse Manager 907776-8722 907 776-8680 Bob Williams Senior Engineer 907 248-5857 907 590-3636 Floyd Faulkner Senior Engineer 907 349-8147 907 590-3636 ~ ~IFE ~ r....~ ~~i Check No Check Date Bank Bank No Vendol ') 1087564 07/31/2003 NCBAS 7780 5001123 . ... : ,!'ivolce: Number . invoIce Date Document ·No: Marathon Oil Company P. o. Box 3128 Houston, TX 77253 ) R~~~ul~¥~lr~ÃY~~LE DEPARTMENT Accounts Payable - Customer Se Phone: rvice713-296-4336 Gros5 Amoun~ ." Dj~-coLin~ :.'. 1n~:oÚ~eiPay )1~~~unt 100.0C 100.00 Hndlg AL .. . Re~it. CQmment . AL10000 07/30/2003 1900021656 Fee For Perm; t To Dr; LL TOTAL: 100.00 100.00 £~' ~ it'''·" ø !:~,t~t It AUG 0 4 2C03 Aliii z:fŒ (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) _ ïÏ'~~['" ~ïj~iÏl·~~;'¡iÙ:"':I·~il ~[ëj":f.;'~·iïj;' ~·I ï.~: 1·:¡ï.j:1 ::(ï.j~~ï:J~{ï.j~(ëj:ï'iïj~ï·~ï~ï~'j['i. ==*i.¡¡¡¡¡¡ i: 1:1.1 ~I·:i :ï~·~'ï'iliï'Ú.'¡, i~~l'ii[ï.j·:('j~]=-Iï~.·.ï~ [ëtIII PORM 2501 REV. 5/00 ------,..- . 7780 Marathon Oil Company H:;~;'~O , ;i.¡.I:.frî~1¡¡¡, , \" ,\"" 56~389/412 ~e] ~1..'1::1 i"'~' ~ (e] ~ I CQNlAIIISSJPN ........................ ., ~ª~WeS7fi7TflAll.~ ~f' t'~~ ANCH()RÄßE;,ÄK2Ø~50~!\·\ii::li!,:ii. \::,'~I,::':,: '1,::\,:::::\:.", -' ',' ''c: ,', ··i:i.li.I,1 I ,I:.,',·',::;:',·:,:\;:- ':'..:,::'~ ~ U.S. Funds MATCH AMOUNT IN WORDS WITH NUMBERS By: r A ~~""iZ·······>';' . ..... ·ff··· .... ;,,; '~".'.'. . :......... .. .... ",uPM?.~..·.'. '.~ L .' : I' ~, \\',':~:~::" NATIONAL CITY BANK Ashland, Ohio þoe. bundled and.OOI}()Q .Do~lar5 .... . . . . . 1 - '. '.. 7 'I~;s[~¡;J'~"i-:'IJ~ I~~~r:~~~ :1·~~7i~i~·ïT.'i:.'.;·~ÚI~'~;;;;-~·~~.: [~'J'.~' (;:;r~: ~.¡.(~~. :I·;'~ ¡~I~~,'~I'\'J ~~;N. ':.'I~~"'·~llt~;t~] ~];¡i~.~~[~tI III 0 0 0 ~ 0 8 7 5 b ... III I: 0 ... ~ 2 0 ~ B g 5 I: 0 ~ B ~ ... B ... III ~WEI2L~PERMIT CHECKLIST:: Company _M8MItfDlH1LLC_0____.___.______ _ ______m._______________..___ Well Name: J~E8\l.ER.CK.UNlT_ _1.3____. __d._________.________ Program _QE.\C..._._________ Well bore seg [] :;":¡.'<~..'".',.....:...,,~_·.::i,._.'~·, r . ,"., , ".: .".- _.~._"..,,,.~ ,'~"""r... - - PTD#: 2031380 Field & Pool _B_E8...\LEH..c_RE_EI$:...aE1U_G1LG..8S_-=-1i0_5_0_0_.___._________B.EAVER C~6ŒiKl, crf'á~èJN .__QE..V_L~GAS__ GeoArea _820 Unit _5.02..12____ On/Off Shore .00.____ Annular Disposal 0 Administration 11 P~(I'Y)it fee attaçhe.d _ . _ . _ Y~s . . . . _ . . _ . b .LeC!s.e .numberappropriate. Yes 13 .U_niq!J~ W~II_ n.arn~ .a[lq Ol!.mb_er _ _ . _ . _ . _ _ _ _ _ _ _ _ . . . _ . _ . . _ _ _ _ . _ _ _ . . _ _ _ . _ Y~$ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . _ . _ . _ _ _ . . _ . _ _ . . . . . . . . . . . _ :4 We.IUo.cat~d in.a. d.efine.d .pool. . No. _ ._ _ . Th.e well has two objeGtives; the BeC!v~( Creek, Beluga_ Gas Pool.and th~.B~aver C(eek Tyonek_ Un.defined Pool ¡5WelUQcated proper .distance. from drilling unìtb.oundary Y~s . 16 We.IIJQcat~d pr.ope.r .distance. from otl:u~r wells. . _ No . The.Se!uga Formation.Pfo.POse_dcompletion Jo.cation .is. consistent wi.th po.ol. rutes,.bJJt the Tyonek IOGation ;7 .S_ufficienLaçreag.e_ayailable inßriIJi09 lJnjt. . . . _ . . . . No. _ will be the sec.olJd completion in a section and.require a spacing e~ception.. . 18 Ifd~viated, js.weJlbo.re platinclu.ded _ y~s _ I~o _~;::::; ~:;::r:~:~:Pd inJQrçe_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~:: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Pe(mit c.aIJ þe i.ssu.e.d witbo.ut co.nse.rvatioll order. . . _ _ No. Appr Date 12 P~(mit c.aIJ þe issl!.e.d witbo.ut ad.minist(ative_apprpval _ . _ Yes _ _ . . . _ . RPC 8/25/2003 13 Can permit be approved before 15-day wait No , 14 _WeJI .IQcated wi.thin area and_strata _authorized by.IIJjectiOIJ Ord.e( # (put. 10# in_ c.or:nm~lJts). (For NA_ _ _ ~ 15 .AJI wel!s_wit)1Ln .1l4JlJite_are_a_of reyieW idelJtifieq (Fp( ~efVjc_ewell Only). _ _ _ _ _ _ .. .. _ . . _ _ _ NA _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ . _ .. _ _ _ .. _ .. _ _ _ _ _ _ .. _ _ _ _ . _ _ . . _ _ _ . . _ . . 16 Pre.-produ.ced injector; _duratio.n.of pre-pro.duGtiOIJ I~$s. th~n 3 months. (For_s!3r:.vi.ce well o.n)y) . _ NA _ . . _ _ . . . _ _ . . . _ . . _ . . . _ . _ 17 ACMP_ Finding _of ConsIstency. h.a$ bee.n.i$.sued_ for_ ìtli$ pr.ojeçt. NA_ _ . . . .. Engineering Appr Date WGA 8/15/2003 Geology Appr RPC Date 8/25/2003 Geologic Commissioner: (}fJ' - --.-----,.- _._---_.~- ---------.-------..-.----.-.,,--------.------."--------------------~-----,------_.---,---,-----_._-----_. 18 _C.o[lqU_ctor st(ing.prQv[d!3d . .. . . .. . .. . . . _ . _ . . . . _ Yes . _ . . . ZQ" @ 1 QO~. . _ . . . _ _ . _ . . . ._ _ . _ _ _ 19 _S_urfC!c!3 .ca$.ing. pJoteGts. all..known USQWs _ _ _ _ _ . . Yes. . . _ . . _ _ . _ . _ . .. _ _ . _ . _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 20 _CMTv.ol.adequ.ate.to çircJJtate.o.n.cond.uctor_& su.rf.c.sg _ _ _ Ye$.. . _ . _ _ _ . _ _ . _ . _ _ 21 .CMTv_otadequ.ate.totie-inJQng.stringto.s!Jrfç~g_.. _ _ _.. . ..... Ye$ _ _ _. .. _ _ _. _. _.. .. _ _... . . . _ _ _ _ _ _ _ _ . _ _ _ . _ _ 22 .CMTwil! Goyer_all know.n.pro_duGtiye bo.rizon.s. _ _ _ _ _ . _ . . . _ . . Yes _ _ . _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ . . _ _ . . _ _ _ _ . _ . . . _ _ _ . . _ . _ _ . . . . 23 .G_asing de..sig!ls aclequate. fp( C,T, B .&. permafr.ost .. _ _ . . _ _ . . _ . . . .. . _ _ Yes. . _ . . . _ . . _ . . _ ........ _ _ _ _ . . _ .. . . . . . . 24 A.dequate.tan.kage_oJ re_serye pit. . . . . _ . _ _ _ _ _ _ _ _ _ . . . . _ . _ .. . _ . .. .. _ . _ . _ _ _ _ Yes _ . . .. _ _ _ Glacier.R,ig 1.... _ . .. _ . _ . . _ . . _ . .. .. _ _ _ .. _ . . . 25 J(aJe-.drill., hC!s..8. 1.0:-403 fo.r aban.donment peeO appro.ved . _ _ _ _ _ _ _ . _ . _ _ _ .NA _ _ _ _ _ _ . _ . _ . . . .. . . _ . _ . _ _ _ . 26 Adequfite weUQore. ~epªrÇltjo_n ..pro-po~e.d _ .. .. _ .. _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ Ye$ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf.divecte.r Je.q.uire.d, do.es it .m.eet reguJations_ _ _ _ .. . _ _ _ _ _ . . . .. _ _ No_ _ _ _ _ _ . _ Waiyer.request~d_ fpr 1.6~' ve.nt IJn.e,. . _ . _ _ _ _ . . . . . _ . _ _ . . . _ _ . . . . _ . . _ . _ . . . _ 28 .DriUiIJ9 fJu.jd_program sGhematic.& eq_uipJist.adequat.e. . _ _ . . _ _ _ _ . _ _ . _ . . . . . _ .. _ . . Yes. _ _ _ . _ . Max MW.9A RP9, _. _ _ . . . . . . . . _ _ _ . _ .. . . . _ .. _ _ _ _ _ _ .. _ _ .. . . _ . _ _ 29 _BOPEs,.dp .they meet. reguJa.tion _ _ _ _ . . .. _ _ _ . . . _ . . _ . _ . . . .. . . . . . Yes _ _ _ _ . . _ . . _ _ _ _ _ _ . . . _ .. . .. _ _ _ _ . . _ . . . . _ _ . _ _ . _ _ _ _ _ . . . . _ 30 _BOPE.pre..ss ratiIJg appropriate;.test to_(pu.t psig in.comr:nents). . . . . . . _ . _ _ _ _ . . . . _ _ . Y~$ . . .. _ _ . .. Te.st t.oAPOO_psi. .M$~ 38.46 psi.. .. _ _ . . _ ... .. _ . . _ . . .. .. _ .. _ . .. . . . _ . . 31 .C.hoke.manifQld cQrnpJies w/API. RP-53 (May 84). . _ _ _ _ . _ . _ . . . _ _ _ _ _ .. . _ _ _ _ Y~$ _ _ . . _ . . . _ .. . _ . _ _ _ . . . _ . . . . . . _ . . _ 32 Wo.rk will OCC_U( withOlJLoperat.ion .sblJtdow.n_ _ _ . _. .. _ _ _ . . .. _ Y~s _ . _ _ _ . _ . . . _ .. . . _ . . . _ _ . . 33 J$. pre$.el1ce. o.f H2S gas. probable _ . _ . . _ _ .. . . _ . _ . . _ . _ . . _ . . . . .. _ _ .. _ . . . _ _ _ _ No_ _ . . .. _ _ . . _ _ _ _ . . .. . _ . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ . _ _ _ . . _ _ 34 Meçba.ni.caLcondjUo[lpfwe.lI$withinI:\Oßyerifiecl(For.s_erviceweIJonJYJ... _ . _' _ NA _ _ _ _...... _ _ _. _ _ _ _.. _.......... _ _. _ _'.. _. _ _ _. .. _ _ _ _ _ _ _ _. _ _ _.. - - - - - - - - ( -----..-------- ---,----,_._--- -----.-,,-.-.---.....- 35 Permit. c.an þ~ i.s$l!.e.d w!o. hy.drog~n_ s_ul.fiçfe r:neaS.!Jres _ _ _ . . . _ . _ _ _ . . . . . _ _ _ . _ _ . .. _ Y~s _ _ _ _ . _ _ _ _ _ _ _ _ _ . .. _ _ _ _ . _ . . _ . _ . _ . . . . _ __ _ . _ . . . . . .. . _ . _ . . _. _ _ . . . .. _ 36 .D_ata.pre.seoted on_ Rote_ntial pveJpres.sure .;zone.s _ _ _ . _ _ _ . . . . .. _ _ _ _ _ _ . . . . . . _ _ Ye$ .. . . . _ . .. ß~Se(voir press.!Jre_eXPe.cte.d to. be. nOfl1JC!1 to_s_eve.rely de.p)ete_d; wil.! be drj.lled with_ 9..~ -_ 9...4 ppg.I1JUd, $i;z~d.. 37 .SeÎ.soiic_analysjs_ o.f shallow gas_zpoe.s_ . . . _ _ . . .. .. _ _ . _ _ _ . _ .. _ .. _ .. _ _ _. _.... NA.. _ . . . .C.aC03 wiJl.be JJse_d .to co.ntrol Je..akoff ioto Jow_pJessure inte.rvals. . . . . . _ . . . _ _ . 38 _Seabe.d _conditiplJ survey .(if qff-sh_ore) _ _ _ _ _ _ . .. .. _ _ _ _ . . . . . _ _ _ _ . _ _ _ _ _ _ _ . . . _ NA _ _ . _ . _ . .. _.. _ . _ _ _ _ . _ . . _ .. . . . . . . _ _ . _ _ _ _ . _ _. _. _ _ _ _ .. _ _ _ .. . . _ _ . _ .. . _ . 39 _ Go.nta_ct namelp)1QneJorweelsly progre~s_repo.rt$ [e~plorator:y.o!1IYl _ _ . . . _ _NA _ _ _ _ . . .. .. _ _ _ _ . _ . . _ _ .. . _ . _ _ . _ _ _ _ _ _ _ .. _ _ _ . _ . . _ . . _ _ _ _ _ _ _ _ _ _ . _ _ . . . . .. . _ _ .. Date: Engineering Commissioner: Date Proposed to be a 1-Gas development well. Public Commissioner 9 /¿ì~l R~R Date g!^¡. ~ Os