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Home My WebLink About200-179From:McLellan, Bryan J (OGC) To:Stefan Reed Subject:RE: [EXTERNAL] RE: KBU 44-06 (PTD# 200-179) - Cement Plug Date:Monday, January 5, 2026 10:08:00 AM Attachments:image003.png Stefan, This plan is conditionally approved, recognizing that the existing cement plug has passed a witnessed MIT, verifying well integrity and isolation of all formations. Condition of approval is confirmation of no-flow for 15-minutes after bleeding any pressure before open-hole deployment of cement bailer. AOGCC witness is not required. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Friday, January 2, 2026 6:01 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: KBU 44-06 (PTD# 200-179) - Cement Plug Thanks Bryan. As discussed, Hilcorp will plan to dump bail the cement on top of existing plug per the below plan. 1. MIRU E-Line 2. Verify no pressure on well and perform 15-min no flow test. If pressure is on well, we will bleed off and perform the same 15-min no flow test. 3. Once well confirmed dead and no flow. Open well and deploy cement bailer in well (open hole) taking displacement returns to tank. 4. Dump bail 25’ (~3.7bbls) on top of plug @ ~1,460’. 5. RDMO E-line. 6. Witnessed tag and test already completed on plug 12/31/2025 and 1/1/2026 respectively. No additional witnessed tag or tests required. CAUTION: This email originated from outside the State of Alaska mail system. Do not CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, January 2, 2026 5:13 PM To: Stefan Reed <stefan.reed@hilcorp.com> Subject: [EXTERNAL] RE: KBU 44-06 (PTD# 200-179) - Cement Plug Stefan, Hilcorp should bring it into compliance with 20AAC25.112(c)(2)(A) or (C), either bring the cement height 100’ above the stub by the displacement method or dump bail another 25’ of cement on top of the existing plug. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Friday, January 2, 2026 10:19 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KBU 44-06 (PTD# 200-179) - Cement Plug click links or open attachments unless you recognize the sender and know the content is safe. Bryan, As discussed, on well KBU 44-06 slickline tagged TOC at 1,460’(1/1/2026) and well was PT’d to 2200psi (1/2/2026) both witnessed. The 9-5/8” CIBP was set at 1,640’ and the 9-5/8” casing was cut at 1,494’. We laid in 25bbls of 15.3ppg cement. The planned cement top was 1,400’, since we have a passing pressure test is the 1,460’ cement top acceptable? Sundry attached. Thank you. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 T41317KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -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: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:7 Township:4N Range:11W Meridian:Seward Drilling Rig:Rig Elevation:Total Depth:7,440 ft MD Lease No.:FEDA028142 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 1509 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 5,437 Feet Csg Cut@ 1,500 Feet Production:3-1/2"O.D. Shoe@ 7,393 Feet Csg Cut@ 1650 Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 1625 1461 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2234 2220 2211 IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jason Yeoman Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Production casing/tubing is 3.5-inch Excape completion. Refer to attached memo for remarks. 12/31/2025 - 1/1/2026 Josh Hunt Well Bore Plug & Abandonment Kenai Beluga Unit 44-06 Hilcorp Alaska LLC PTD 2001790; Sundry 325-579 Remarks Memo Test Data: P Casing Removal: rev. 3-24-2022 2026-0101_Plug_Verification_KBU_44-06_jh                    2026-0101_Plug_Verification_KBU 44-06_remarks_jh Page 1 of 1 Plug Verification KBU 44-06 PTD 2001790; Sundry 325-579 AOGCC Inspector J. Hunt REMARKS 12/31/2025: I traveled to location and met with Jason Yeoman representing Hilcorp Alaska LLC. When I arrived, I received a phone call telling me there were only 4 bolts holding the dry hole tree to the wellhead. They would need time to install and torque the rest of the bolts as well as get the slickline unit rigged up. I asked for a copy of the sundry and well schematic so I could look them over – those documents were not available. I informed him of the required paperwork necessary for the job and to call me when the slickline unit is ready. I left location and headed home. I returned a few hours later and met with Jason Yeoman again. He had the required paperwork. Slickline was rigged up and ready to tag the top of cement (TOC). This cement plug is founded on a 95/8-inch CIBP set at 1,625 ft MD and is intended to seal off the wellbore and the surface shoe in preparation for a re-drill. Slickline ran in the hole with a blind box, weight pipe, spangs and jars. The tagging assembly was 21.5 feet long and weighed approximately 125 lbs. They tagged TOC at of 1,461 ft MD RKB (RKB is 21 ft). This depth came up 52 feet shy of the required 100 feet of cement above the casing shoe. AOGCC Drilling Engineer Bryan McLellan approved Hilcorp to dump bail another 25 feet of cement on top of this plug. After slickline was rigged down they attempted an MIT but had several problems with the test manifold leaking. It was also well past change-out time for field crew so we elected to come back during daylight and try again after the test manifold was rebuilt. 1/1/2026: I traveled back to KGGU 44-06 and met with Jason Yeoman. An MIT of the 133/8-inch surface casing pipe, wellhead, and cement plug was performed and passed.     CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:RE: KBU 44-06 (PTD# 200-179) - Rig 401 Work String Date:Friday, December 26, 2025 8:20:00 AM Attachments:image003.png Stefan, Confirming that I verbally approved this change. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Monday, December 22, 2025 10:35 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 44-06 (PTD# 200-179) - Rig 401 Work String Bryan, Following up on our conversation earlier today confirming your verbal approval of the 2-7/8” work string instead of the 3-1/2” work string stated in the sundry. As mentioned, BOP’s were tested for 2-7/8” work string. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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. From:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:RE: KBU 44-06 (PTD# 200-179) - Rig 401 BOP Test Date:Friday, December 19, 2025 5:24:00 PM Attachments:image003.png Stefan, Hilcorp has approval to proceed as written below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Friday, December 19, 2025 4:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 44-06 (PTD# 200-179) - Rig 401 BOP Test Bryan, As discussed, the 401 rig is moving on to KBU 44-06 and we have found that this wellhead has a primary plate that will not fit through the BOP stack (See attached diagrams). The primary plate is the seal between the tubing and annulus and is a 13.75” OD. The BOP stack is a 13- 5/8” ID. Hilcorp’s Request: 1. BOP Test per our standard procedure with the test pump against the installed pack off plug. 2. Nipple down BOPs at the wellhead ( 1 connection) and remove the primary plate. 3. Nipple up BOPs. 4. Shell test against the wellbore to test broken connection at wellhead. Current wellbore status (updated diagram attached): Tested (1600psi) plug/cement in tubing @ ~3865’ Tubing Cut ~1660’ CMIT-TxIA after cut to 1650psi - passed Pack off plug ~ 36’ tested to 4100psi Please let me know if you have any questions. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 7,440' 7,217' (fill) Casing Collapse Structural Conductor Surface 2,260psi Intermediate 3,090psi Production 10,530psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng stefan.reed@hilcorp.com 206-518-0400 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Stefan Reed, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 200-179 50-133-20498-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.3# / L-80 TVD Burst 7,393' 10,160psi 1,507' Size 114' 9-5/8"5,437' 1,509' MD See Attached Schematic 5,750psi 5,020psi 114' 5,309' 114' 1,509' October 13, 2025 3-1/2" Excape Tbg 7,393' Perforation Depth MD (ft): 5,437' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 44-06CO 510C Same 7,261'3-1/2" ~1,211psi 7,393' 5310, 5400 Length N/A; N/A N/A; N/A 7,308' 5,275' 5,149' Kenai Gas Field Sterling 4 Gas, Sterling 5 Gas 20" 13-3/8" See Attached Schematic m n P s t _ N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-579 By Gavin Gluyas at 2:24 pm, Sep 24, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.09.24 10:56:33 - 08'00' Noel Nocas (4361) BOP test to 3000 psi, annular test to 2500 psi X BJM 10/7/25 and Beluga-Tyonek Gas Provide 24 hrs notice for AOGCC opportunity to witness cement plug tag and pressure test. X A.Dewhurst 07OCT25 10-407 10/08/25 RWO Well: KBU 44-06 Date: September-2025 Well Name: KBU 44-06 API Number: 50-133-20498-00 Current Status: Shut-in Gas Well Permit to Drill Number: 200-179 First Call Engineer: Stefan Reed (907) 777-8433 (206) 755-0301 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Maximum Expected BHP: 1600 psi @ 3897 TVD (Based on offset data, 8ppg KWF) Max. Potential Surface Pressure: 1211 psi (Based on expected BHP minus gas gradient to surface (0.10psi/ft) Brief Well Summary KBU 44-06 drilled and completed in 2002 targeting the Beluga/Upper Tyonek formation and completed as an Excape completion. The well came online making 5 MMCFD. The well went offline in 2014 due to sand production. Perf add to the UB-8 in 2019 was unsuccessful. In 2021 a remedial IA cement squeeze was done and the well was perforated in the sterling sands. The well produced at steady decline until 2023 when it loaded up with water. Slickline attempted to swab well in September 2023 with no success, it has remained shut in since. The objective of this project is to prepare the well for future sidetrack. Well Status KBU 44-06 is currently a shut-in Excape well that has been offline since September 2023. Notes Regarding Wellbore Condition Slickline drifted w/ a 2.80 GR to 4,391 8/12/2025 3-1/2 x 9-5/8 TOC: 3/14/21 CBL confirms TOC @ ~2,475 9-5/8 annulus TOC: Calculated at 2424 using 25% washout E-Line Procedure (with pump truck): 1. MIRU e-line and pump truck. PT PCE to 3,000 psi High. 2. Load well with water (8.4ppg) 3. Set 3-1/2 CIBP at ±3,865. 4. Dump bail a minimum 25 of cement (~9gals) on top of plug. 5. Drift & tag top of cement, pressure test to 1500psi for 30 minutes. a) Provide AOGCC 24 hour notice to witness tag and test. 6. Cut tubing at ±1,650. Circulate with water to confirm TxIA communication. 7. Cut tubing again as needed to establish communication. Slickline Procedure: 1. MIRU Slickline 2. Set pack-off plug in first joint below tubing hanger. 3. Pressure up to confirm plug is holding. 4. RDMO Workover Procedure: 1. MIRU 401 workover rig 2. Install TWC, ND tree, NU 13-5/8 BOP TWC can not be set per Stefan Reed 10/1/25 phone call. BOP will be tested against pack-off plug in the tubing. -bjm Pressure test TxIA to 1500 psi after cutting tubing. -bjm RWO Well: KBU 44-06 Date: September-2025 3. Test BOPE Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. BOPs will be closed as needed to circulate the well during this workover. 4. Pull TWC 5. Circulate well w/ warm water. 6. Pick up on hanger 7. Pull and lay down tubing Note: record number clamps/bands for control lines and cable, save centralizers (do not drop set screws downhole) Contingency: If equipment, cable, or control line are left downhole, a casing scraper run will be made to push it to bottom. 8. MIRU Eline 9. Drift well w/ ±8.4 GR. 10. Set 9-5/8 CIBP at ±1,625 11. Dump bail 25 of cement (~80 gals) on top of plug. 12. Tag plug and pressure test to 1500psi a. Provide AOGCC 24hr notice to witness tag and test 13. Log CBL in 9-5/8 casing to confirm free pipe. 14. RDMO Eline 15. PU 3.5 PH6 work string. 16. Make up YJ casing cutter. 17. Trip in hole and cut casing at ±1,500 18. Trip out casing cutter 19. Circulate well with warm water. Establish circulation in 9-5/8x13-3/8 casing annulus. 20. Install 9-5/8 rams and test. a. Provide AOGCC 24hr notice to witness test 21. Pull and lay down 9-5/8 casing a. If unable to pull casing or circulate well: i. Rig up casing jacks and attempt to pull casing or ii. make a shallower cut and reattempt to circulate/pull casing. 22. PU 3.5 PH6 work string. 23. Make wiper trip to casing cut, ~1,500 24. MU and Trip in hole w/ 13-3/8 CIBP 25. Set 13-3/8 CIBP at ±1,490, within 25 of 9-5/8 casing stub. 26. Pressure test 13-3/8 casing to 2000psi. 27. MIRU Eline 28. Log caliper in 13-3/8 casing. 29. Dump bail 25 of cement (~160 gals) on top of plug. 30. ND BOP, NU Tree 31. RDMO Rig 401 Post Rig Procedure: 1. MIRU Slickline. 2. Drift & Tag top of cement. Pressure test casing to 1500psi. a. Provide AOGCC 24hrs notice to witness tag and PT. 3. RDMO Slickline The 9-5/8" plug and 13-3/8" cement plug should be combined to comply with 20 AAC 25.112(b), (c)(2) & (c)(3). -bjm The 9-5/8" plug and 13-3/8" cement plug should be combined to comply with 20 AAC 25.112(b), (c)(2) & (c)(3). -bjm Lay in cement by displacement method from 9-5/8" CIBP at 1615' md to at least 100' above the surface casing shoe. See updated proposed wellbore diagram. -bjm RWO Well: KBU 44-06 Date: September-2025 Attachments: Current Well Schematic Proposed Well Schematic 401 Workover Rig 13-5/8 BOP Diagram Lease: State/Prov:Alaska Country:USA Perf (TVD): July 13, 2021 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:Jake Flora February 22, 2002 Prepared By: Dated Completed: 3,884' - 5,370' 3809' - 7,120'Perf (TVD): 1.5º / 100ft @ 1,800' ~ 1ºAngle/Perfs: Well Name & Number: Municipality: PBTD 5,275' MD 5,149' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002 TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg ***3/10/2021 cement IA with 116 bbls 15.3# cement **** 5344' downhole sensor, conductor wire 5400' CIBP w/ 10' cmt top (8/29/19) Excape System Details: Control Lines:red line: cemented with 1 gallon on 7/2/21green line: cemented with 2 gallons on 7/2/21 Module 16 5910' - 5920' (frac'd 7/9/02)Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02)Module 12 6151' - 6161' (frac'd 7/9/02)Module 11 6291' - 6301' (frac'd 7/9/02)2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08)Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02)Module 8 6563' - 6573' (frac'd 7/8/02)Module 7 6630' - 6640' (frac'd 7/8/02)1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08)Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08) Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' SCHEMATIC Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date Statu Sterling P4-B1A 3,884' 3,904' 2-1/8" 3 Open 03/18/21 Open P4-B2 3,983' 3,993' 2-1/8" 3 Open 03/18/21 Open Upper Beluga UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Isolated Tree cxn = 4-3/4" Otis 2424' 9-5/8 x 12-1/4 TOC (calc w 25% washout) 2475' 3-1/2 x 9-5/8 annulus TOC (3/14/21 CBL) 4575' Jet Cut tubing on 2/22/21 5310' Set CIBP w 35' cmt on 2/22/21 UB-8 B1A B2 Superseded by updated schematic. -A.Dewhurst 07OCT25 Lease: State/Prov:Alaska Country:USA Perf (TVD): Angle/Perfs: Prepared By: Dated Completed: 3,884' - 5,370' 3809' - 7,120' 1.5º / 100ft @ 1,800' ~ 1º Well Name & Number: Municipality: July 13, 2021 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:Jake Flora February 22, 2002 PBTD 5,275' MD 5,149' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg ***3/10/2021 cement IA with 116 bbls 15.3# cement **** 5344' downhole sensor, conductor wire 5400' CIBP w/ 10' cmt top (8/29/19) Excape System Details: Control Lines:red line: cemented with 1 gallon on 7/2/21green line: cemented with 2 gallons on 7/2/21 Module 16 5910' - 5920' (frac'd 7/9/02)Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02)Module 13 6111' - 6121' (frac'd 7/9/02)Module 12 6151' - 6161' (frac'd 7/9/02)Module 11 6291' - 6301' (frac'd 7/9/02)2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08)Module 10 6424' - 6434' (frac'd 7/9/02)Module 9 6492' - 6502' (frac'd 7/9/02)Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02)1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08)Module 6 6722' - 6732' (frac'd 7/8/02)1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08)Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02)Module 1 7242' - 7252' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' SCHEMATIC Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date Status Sterling P4-B1A 3,884' 3,904' 2-1/8" 3 Open 03/18/21 Open P4-B2 3,983' 3,993' 2-1/8" 3 Open 03/18/21 Open Upper Beluga UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Isolated Tree cxn = 4-3/4" Otis 2424' 9-5/8 x 12-1/4 TOC (calc w 25% washout) 2475' 3-1/2 x 9-5/8 annulus TOC (3/14/21 CBL) 4575' Jet Cut tubing on 2/22/21 5310' Set CIBP w 35' cmt on 2/22/21 UB-8 B1A B2 Lease: State/Prov:Alaska Country:USA Perf (TVD): Angle/Perfs: September 19, 2025 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:S. Reed February 22, 2002 Prepared By: Dated Completed: 3,884' - 5,370' 3809' - 7,120' 1.5º / 100ft @ 1,800' ~ 1º Well Name & Number: Municipality: PBTD 5,275' MD 5,149' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD ~1500'5,437' TVD ~1498' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD ~1650'7,393' TVD ~1648'7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg ***3/10/2021 cement IA with 116 bbls 15.3# cement **** 5344' downhole sensor, conductor wire 5400' CIBP w/ 10' cmt top (8/29/19) Excape System Details: Control Lines:red line: cemented with 1 gallon on 7/2/21green line: cemented with 2 gallons on 7/2/21 Module 16 5910' - 5920' (frac'd 7/9/02)Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02)Module 13 6111' - 6121' (frac'd 7/9/02)Module 12 6151' - 6161' (frac'd 7/9/02)Module 11 6291' - 6301' (frac'd 7/9/02)2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08)Module 10 6424' - 6434' (frac'd 7/9/02)Module 9 6492' - 6502' (frac'd 7/9/02)Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02)1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08)Module 6 6722' - 6732' (frac'd 7/8/02)1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08)Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' Proposed Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date Status Sterling P4-B1A 3,884' 3,904' 2-1/8" 3 Open 03/18/21 Open P4-B2 3,983' 3,993' 2-1/8" 3 Open 03/18/21 Open Upper Beluga UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Isolated Tree cxn = 4-3/4" Otis 2424' 9-5/8 x 12-1/4 TOC (calc w 25% washout) 2475' 3-1/2 x 9-5/8 annulus TOC (3/14/21 CBL) 4575' Jet Cut tubing on 2/22/21 5310' Set CIBP w 35' cmt on 2/22/21 UB-8 B1A B2 9-5/8" CIBP w/ 25' Cement @ ~1,625' 3-1/2" Tubing Cut @ ~1,650' 3-1/2" CIBP w/ 25' of cement @ ~3,865' 9-5/8" Casing Cut @ ~1,500' 13-3/8" CIBP w/ 25' of cement @ ~1,490' Superseded Lease: State/Prov:Alaska Country:USA Perf (TVD): Angle/Perfs: September 19, 2025 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:S. Reed February 22, 2002 Prepared By: Dated Completed: 3,884' - 5,370' 3809' - 7,120' 1.5º / 100ft @ 1,800' ~ 1º Well Name & Number: Municipality: PBTD 5,275' MD 5,149' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD ~1500'5,437' TVD ~1498' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD ~1650'7,393' TVD ~1648'7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg ***3/10/2021 cement IA with 116 bbls 15.3# cement **** 5344' downhole sensor, conductor wire 5400' CIBP w/ 10' cmt top (8/29/19) Excape System Details: Control Lines:red line: cemented with 1 gallon on 7/2/21green line: cemented with 2 gallons on 7/2/21 Module 16 5910' - 5920' (frac'd 7/9/02)Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02)Module 13 6111' - 6121' (frac'd 7/9/02)Module 12 6151' - 6161' (frac'd 7/9/02)Module 11 6291' - 6301' (frac'd 7/9/02)2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08)Module 10 6424' - 6434' (frac'd 7/9/02)Module 9 6492' - 6502' (frac'd 7/9/02)Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02)1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08)Module 6 6722' - 6732' (frac'd 7/8/02)1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08)Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02)Module 1 7242' - 7252' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' Proposed Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date Status Sterling P4-B1A 3,884' 3,904' 2-1/8" 3 Open 03/18/21 Isolated P4-B2 3,983' 3,993' 2-1/8" 3 Open 03/18/21 Isolated Upper Beluga UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Isolated Tree cxn = 4-3/4" Otis 2424' 9-5/8 x 12-1/4 TOC (calc w 25% washout) 2475' 3-1/2 x 9-5/8 annulus TOC (3/14/21 CBL) 4575' Jet Cut tubing on 2/22/21 5310' Set CIBP w 35' cmt on 2/22/21 UB-8 B1A B2 9-5/8" Casing Cut @ ~1,500' 9-5/8" CIBP w/ Cement top @ ~1,400' 3-1/2" Tubing Cut @ ~1,650' 3-1/2" CIBP w/ 25' of cement @ ~3,865' Isolated CIBP set at ~1625' MD. -bjm 13-5/8"GK Annular Height: 54.125" Weight: 14,000 LBS 13-5/8" TYPE U Double BOP Height: 56" Width: 112" Weight 14,800 LBS TOP RAMS 2-7/8" TO 5"" MULTI-RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" 5M Manual Gate valves 4-1/16" 5M Manual Gate valve & 4-1/16" HCR Full Mud Cross Assy. width w/ valves installed Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 11.55' BOP Total weight: 31,000 LBS 13-5/8" 5m BOP Package W/ 4-1/16" 5M Valves Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 1 Dewhurst, Andrew D (OGC) From:Stefan Reed <stefan.reed@hilcorp.com> Sent:Tuesday, 7 October, 2025 09:20 To:Dewhurst, Andrew D (OGC) Cc:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] KU 44-06 Plug for Redrill Sundry (325-579) Attachments:KBU 44-06_Proposed_Schematic 7-Oct-2025.pdf; KBU 44-06 Schematic 07-13-21.pdf Andrew, Sorry about that. Converting to PDF was causing some formatting issues I didnt catch. Attached are updated schematics showing all the excape intervals. Let me know if you need anything else. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, October 6, 2025 4:23 PM To: Stefan Reed <stefan.reed@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] KU 44-06 Plug for Redrill Sundry (325-579) Stefan, Im completing my review of the KU 44-06 sundry and noticed that some of the open perforation intervals appear missing on the schematics. The current schematic has modules 5-16; the proposed schematic has modules 2-16. Would you con rm that there is also an open interval from 7,242 to 7,252 MD? If so, would you please send revised schematics that show all the intervals? Thanks, Andy You don't often get email from stefan.reed@hilcorp.com. Learn why this is important 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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. 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From:Jacob Flora To:Brian Glasheen Subject:FW: Cementing Follow Up Report: Excape Control Lines Date:Wednesday, October 25, 2023 10:24:20 AM Boom From: Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent: Monday, July 12, 2021 2:20 PM To: bryan.mclellan@alaska.gov Cc: Taylor Wellman <twellman@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: Cementing Follow Up Report: Excape Control Lines Bryan, Below are the ¼” control lines we squeezed with the grease pump and Halliburton’s FineCem squeeze cement on the Excape IA squeezed wells we did in early January 2021. As you will notice the lines took a varying amount of cement. The 0.25” lines have an ID of 0.152” and capacity of 0.00094 gllons/ft. 2 gallons equates to 2127’ of control line. I plan on updating the WBDs and notating the cement volume pumped on each. Let me know if there is anything additional you would like to see here- Thanks, Jake PTD Well cement volume pumped date cemented 202-091 KBU 11-08Y 2 gallons on each line (7/2/2021) 205-141 KBU 41-06 1.5 gal red, 2 gal yellow and 2 gal green (7/2/2021) 204-209 KBU 42-06 2 gal yellow, 1.5 green and 1 gal red (7/2/2021) 200-179 KBU 44-06 1 gal red and 2 gal green (7/2/2021) 207-149 KBU 14-06Y 1.5 gal green and 0.5 gal red (7/2/2021) 203-217 KBU 23-07 1 gal red, .5 gal green and 1 gal yellow (7/2/2021) 203-025 BCU-11 2 gallons on each line (7/3/2021) 200-179 KBU 44-06 1 gal red and 2 gal green (7/2/2021) 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 and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Cement Packer, N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,440 feet 5310, 5400 feet true vertical 7,308 feet feet Effective Depth measured 5,275 feet N/A feet true vertical 5,149 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" Excape Tbg 9.3# / L-80 7,393' MD 7,261' TVD Packers and SSSV (type, measured and true vertical depth)N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 WINJ WAG 0 Water-Bbl MD 114' 1,509' 16 Oil-Bbl measured true vertical Packer 3-1/2"7,393' 5,309' 7,261' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field - Sterling Gas 5.1, 4, 3N/A measured TVD Tubing Pressure 660 Kenai Beluga Unit (KBU) 44-06 N/A FEDA028142 5,437' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-179 50-133-20498-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-054 114 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,770 0 Representative Daily Average Production or Injection Data 114' 1,509' 5,437' 7,393' Conductor Surface Intermediate Production 10,530psi Casing Structural 20" 13-3/8" 9-5/8" Length 5,750psi 5,020psi Collapse 2,260psi 3,090psi jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,160psi 114' 1,507' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:06 am, Apr 09, 2021 agerager Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 09:49:56 -08'00' Taylor Wellman (2143) Sterling 4 Gas BJM 7/16/21 SFD 4/15/2021 SFD 4/15/2021 RBDMS HEW 4/9/2021 DSR-4/12/21 SFD 4/15/2021 Rig Start Date End Date 2/22/21 3/19/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 44-06 50-133-20498-00-00 200-179 02/22/2021 - Monday YJOS arrive on location. PTW and safety meeting. MIRU YJOS E-line unit. Make up CIBP. Stab on well. PT stack 250/3,000 psi. RUN #1: RIH with 7' 1-11/16" WB, 1-11/16" CCL and 1-11/16" MSST with 2.75" OD CIBP - 9' from CCL to middle of plug. Set plug at 5,310' (CCL depth 5301'). POOH to surface. Ice build up in wellhead. MIRU hot oil truck with 60/40 methanol. Pressure up on lubricator to free tools. Close swab and master. RUN #2: RIH with 1-11/16" ccl and 30' of 2.5" bailer loaded with cement. tag top of plug at 5,310' pick up 1' and dump cement. POOH to surface. Run #3: RIH with 1- 11/16" CCL and 30' of 2.5" bailer. Dump cement onto of plug. Total cement dumped 12 gallons = 35' in 3.5" tubing. POOH to surface. MIRU HAK hot oil truck loaded with 60/40 methanol. Run #4: RIH with 7' 1-11/16" WB, 1-11/16" CCl, 1- 11/16" centralizer and 2.50" OD jet cutter assembly. 5.5' CCL to cut. Online with hot oil truck. Pressure up tubing to 2,500 psi and chart pressure for 10 minutes prior to cut. IA = 80 PSI, OA 0 psi. Cut tubing at 4,575' (CCL 4,569.5'). Post cut tubing pressure dropped to 1,700 psi. IA dropped to 0 psi. POOH. Rig down E-line. Use yellow jacket crane to move wellhouse from 41-06 area to allow production to run 1502 iron. Spot 2 rain for rent tanks next to 44-06 and install pump in sub and tree cap on tubing for wellbore circulation. Location secure. Move hot oil truck to KDU-1 and attempt IA pt. Ran out of fluid before pressure build. Will come back later. HES cementing crew arrive on location. Hold PSJM for moving in and rigging up. Spot equipment, tractor trailers stuck due to snow load. Spot trucks around well. Rig up HES cementing to pump in sub on tubing head adapter. Hold pre job safety meeting. fluid pack lines and wellbore. 1:1 returns at return tank. Shut in down hole valve. PT pump lines 250/4,300 psi. Perform 10 minute combo test on tubing and IA to 1,500 psi and chart. Small drop in test pressure . Possibly due to thermal. Fresh water for cement job is 95 degrees F. Pump 530 sks of cement at 15.3 PPG. 1.24 ft/sk. 5.60 GL/SK pumped at a total of 116.6 BBLS of cement at 650 psi, 4 bbls/min. Shut down. Drop wiper ball and chase with displacement. Pump 39.5 BBLS of H2O for displacing cement from tubing into IA. 4 BBL/min at 1690 psi. HES shut down pumps. Job went as planned. Close master and swab valve. Start hauling returned fluids to G&I. Rig down HES equipment. HAK pump in sub and return iron. Prep rain for rent tanks for rig down. HES data graph for combo PT sent to town engineer. Location walk around complete. SDFN. 03/10/2021 - Wednesday Cut tubing at 4,575' Set plug at 5,310' 3/14/21 - CBL run from surface to ~5570' md. Est TOC at 2814' md. Poor cement from ~4220-4570' md. BJM K pumped at a total of 116.6 BBLS of cement a Total cement dumped 12 gallons = 35' in 3.5" tubing. tag top of plug at 5,310' pick up 1' and dump cement. Pump 39.5 BBLS of H2O for displacing cement from tubing into IA. Pressure up tubing to 2,500 psi and chart pressure for 10 minutes prior to cut. Perform 10 minute combo test on tubing and IA to 1,500 psi and chart. S Rig Start Date End Date 2/22/21 3/19/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 44-06 50-133-20498-00-00 200-179 Arrive on location. PTW and JSA. Spot equipment and rig up lubricator. Flange in wing area leaking, ops working on repairing while cont to rig up. Flange leak repaired. PT to 250 psi low and 3.000 psi. Have a short in the jar. Troublshoot and repair. Cont. rig up. Stab onto well. PT to 250 psi low and 3.000 psi. (GUN# 1) RIH w/ 20' x 2-1/8" (3 SPF / 60 deg phasing) strip gun. Logged correlation pass. Send to town for approval. Town wants to depth shift +4'. Shifted log down 4' and pull into position and fired. Good indication of firing. POOH. **** PERFORATED INTERVAL @ 3,884'' - 3,904' **** (CCL top shot = 19.2' / CCL stop depth = 3,864.8'). Initial psi @ 382# (fired @ 12:33). 5 min. = 274# / 10 min = 208# / 15 min = 173#. OOH. Bleed off and confirmed all shots fired. Ops to flow well to see what it does before completely rigging down. Ops brought well online but not flowing. Standby for town to make decision. Town decided that they want to shoot 2 other interval, so start working on getting 2 x 10' guns made up. Jake called and want to run a GPT to see where fluid level is before running other guns. Pollard rounding up GPT tool. Make up GPT on toolstring and stab back on to well. RIH w/ GPT toolstring. Found fluid level @ 3,904' (btm of new perfs at this depth). Pooh and bleed off. Set and arm 10' x 2-1/8" strip guns. (GUN# 2) RIH 10' x 2-1/8" strip gun (3 SPF / 60 deg phasing) Logged correlation pass. Send to town for approval. Town says on depth . Pull into position and fired. Good indication of firing. POOH. **** PERFORATED INTERVAL @ 3,983' - 3,993' **** (CCL top shot = 24.2' / CCL stop depth = 3,958.8') Initial psi @ # (fired @ 19:42) 5 min. = 300# / 10 min = 461# /15 min = 504#. OOH tbg psi = 540# when shut in. Bleed off and confirmed all shots fired. Town want's to flow over night and see what it does. Lay down equipment on location. Crew departs location ***Job continued on 3/19/21*** 03/19/2021- Friday Well flowing good enough per town, instructed to rig down. Eline crew arrives on location and finishes rigging down equipment. Eline departs location and moves equipment to shop. ****Job Complete**** 03/18/2021 - Thursday PERFORATED INTERVAL @ 3,884'' - 3,904' 5/17/21 MITIA to 2000 psi passed. See attached data. BJM PERFORATED INTERVAL @ 3,983' - 3,993' 7/2/21 Excape control lines cemented. See attached report. BJM Lease: State/Prov:Alaska Country:USA Perf (TVD): March 26, 2021 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:Donna Ambruz February 22, 2002 Prepared By: Dated Completed: 3,884' - 5,370' 3809' - 7,120'Perf (TVD): 1.5º / 100ft @ 1,800' ~ 1ºAngle/Perfs: Well Name & Number: Municipality: PBTD 5,275' MD 5,149' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002 TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 pp g ***3/10/2021 cement IA with 116 bbls 15.3# cement **** 5344' downhole sensor, conductor wire 5400' CIBP w/ 10' cmt top (8/29/19) Excape System Details: Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02)Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) Module 11 6291' - 6301' (frac'd 7/9/02) 2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08)Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02)1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08) Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08) Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Dro p:4,200' Final Angle:0º @ 5,415' SCHEMATIC Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date Statu Sterling P4-B1A 3,884' 3,904' 2-1/8" 3 Open 03/18/21 Open P4-B2 3,983' 3,993' 2-1/8" 3 Open 03/18/21 Open Upper Beluga UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Isolated Tree cxn = 4-3/4" Otis 2424' 9-5/8 x 12-1/4 TOC (calc w 25% washout) 2475' 3-1/2 x 9-5/8 annulus TOC (3/14/21 CBL) 4575' Jet Cut tubing on 2/22/21 5310' Set CIBP w 35' cmt on 2/22/21 UB-8 B1A B2 d Sterling Gas Pool 4 SFD 4/15/2021 Customer:Hilcorp Customer Contact:Cole Bartlewski LSD: Job #: Date: Fluid Pumped: KBU 44-06 IA MIT WATER 2021-05-17 13:32 Ticket #: Phone #: Operator: KBU 44-06 COLE BARTLEWSKI 907-690-2854 Total Fluid Pumped:8.4 USG 1Winston, Hugh E (CED)From:Jake Flora - (C) <Jake.Flora@hilcorp.com>Sent:Monday, July 12, 2021 2:20 PMTo:McLellan, Bryan J (CED)Cc:Taylor Wellman; Donna Ambruz; Jake Flora - (C)Subject:Cementing Follow Up Report: Excape Control Lines Bryan, Below are the ¼” control lines we squeezed with the grease pump and Halliburton’s FineCem squeeze cement on the Excape IA squeezed wells we did in early January 2021. As you will notice the lines took a varying amount of cement. The 0.25” lines have an ID of 0.152” and capacity of 0.00094 gllons/ft. 2 gallons equates to 2127’ of control line. I plan on updating the WBDs and notating the cement volume pumped on each. Let me know if there is anything additional you would like to see here‐ Thanks, Jake PTD Well cement volume pumped date cemented 202‐091 KBU 11‐08Y 2 gallons on each line (7/2/2021) 205‐141 KBU 41‐06 1.5 gal red, 2 gal yellow and 2 gal green (7/2/2021) 204‐209 KBU 42‐06 2 gal yellow, 1.5 green and 1 gal red (7/2/2021) 200‐179 KBU 44‐06 1 gal red and 2 gal green (7/2/2021) 2 207‐149 KBU 14‐06Y 1.5 gal green and 0.5 gal red (7/2/2021) 203‐217 KBU 23‐07 1 gal red, .5 gal green and 1 gal yellow (7/2/2021) 203‐025 BCU‐11 2 gallons on each line (7/3/2021) 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. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/31/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 44-06 (PTD 200-179) PERF 03/18/2021 Please include current contact information if different from above. PTD: 2001790 E-Set: 34861 Received by the AOGCC 03/31/2021 03/31/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 44-06 (PTD 200-179) MRCBL Memory Radial Cement Bond Log 03/14/2021 Please include current contact information if different from above. PTD: 2001790 E-Set: 34795 Received by the AOGCC 03/19/2021 03/22/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 44-06 (PTD 200-179) RCBL Radial Cement Bond Log 01/20/2021 Please include current contact information if different from above. PTD: 2001790 E-Set: 34634 Received by the AOGCC 01/29/2021 Abby Bell 02/01/2021 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: _______________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/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,440'7,217' (fill) Casing Collapse Structural Conductor Surface 2,260psi Intermediate 3,090psi Production 10,530psi 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 Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 7,308'7,323'7,191'1,211 5400' (CIBP) N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 200-179 50-133-20498-00-00 Kenai Beluga Unit (KBU) 44-06 Kenai - Sterling Gas Pools 5.1, 4, 3 Length Size CO 510a Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 TVD Burst 7,393' 10,160psi MD 5,750psi 5,020psi 114' 1,507' 5,309' 114' 1,509' 7,261'3-1/2" 20" 13-3/8' 114' 9-5/8"5,437' 1,509' 7,393' Perforation Depth MD (ft): 5,437' See Attached Schematic 7,393' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: February 14, 2021 3-1/2" Excape Tbg Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:35 pm, Jan 26, 2021 321-054 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.26 13:59:14 -09'00' Taylor Wellman cement packer/ SFD 1/27/2021 10-404 DSR-1/27/21gls 1/28/21 GAS * CBL over 3.5" tubing post IA cement placement Perforate New Pool Perforate f Comm 1/28/21 dts 1/28/2021 JLC 1/28/2021 RBDMS HEW 1/29/2021 Well Prognosis Well: KBU 44-06 Date: 01-25-2021 Well Name: KBU 44-06 API Number: 50-133-20498-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: 02/14/2021 Rig: N/A Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-179 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) AFE Number: Maximum Expected BHP: 1600 psi @ 3897’ TVD (Based on offset data) Max. Potential Surface Pressure: 1211 psi (Based on expected BHP minus gas gradient to surface (0.10psi/ft) Well Status KBU 44-06 is currently a shut-in Excape well that has been offline since Dec 2014. Brief Well Summary KBU 44-06 drilled and completed in 2002 targeting the Beluga/Upper Tyonek formation and completed as an Excape completion. The well came online making 5 MMCFD. The well went offline in 2014 due to sand production. Perf add to the UB-8 in 2019 was unsuccessful. The well has cum’d just under 10 BCF and 123 MBW of water. The initial target will be the Sterling B4B which is not producing anywhere in the field at this time. Notes Regarding Wellbore Condition x MITIA PASSED 1/20/21 x 3-1/2” x 9-5/8” TOC: 1/20/21 CBL confirms TOC @ 4620’ x 9-5/8” annulus TOC: Calculated at 2424’ using 25% washout x RIH w/ CIBP on 8/29/2019, set at 5,400’ with 10’ cement E-Line Procedure (with pump truck) 1. MIRU e-line and pressure control equipment. PT lubricator to 3,000 psi High. 2. Set CIBP at 5310’. 3. Pressure up tubing to 2500 psi. 4. Jet Cut 3.5” tubing at ~4500’, look for communication with IA, attempt to circulate well. 5. If well will not circulate at 3000 psi tubing pressure discuss with OE, it may be necessary to cut again further up-hole to achieve circulation. If it will circulate RD E-line, continue circulating to clean up for IA cement job. IA Cementing Procedure 6. RU cement truck, PT lines. 7. Mix and pump 115 bbls 15.3# cement down tubing, with returns from IA. Planned TOC in IA is 2700ft. 8. Displace 3.5” tubing to the jet cut depth (~39 bbls) 9. SI master valve, hold pressure. Discuss freeze protecting with Operator. WOC 3 days. Slickline / E-Line Procedure / CTU Contingency 10 min MIT for record ( chart) verify UB-8 isolation. Isolate UB-8 perfs . 31/2" x 95/8"= Cut tubing 4500 ft The initial target will be the Sterling B4B which is not producing anywhere in the field at this time. 4500 - 2700 ft x .0639 = 115 bbls MITIA PASSED 1/20/2 ok . 0639 bbl/ft KBU 44-06 is currently a shut-in Excape well that has been offline since Dec 2014. Well Prognosis Well: KBU 44-06 Date: 01-25-2021 10. MIRU Slick-Line, PT Lubricator. Log memory CBL from TD to surface. Send log to AOGCC. Coil Tubing Milling Contingency (if cement is left too high in 3.5” tubing) I. MIRU CTU, 24hr notice for BOP test II. Conduct BOP test 250psi low, 3000psi high III. RIH w milling BHA, mill out cement to ~10’ above jet cut depth IV. Blow down well with nitrogen, trap pressure for perforating, RDMO CTU. 11. Swab well down. 12. Pressure up well with well gas or Nitrogen. 13. RU E-Line, PT Lubricator. Perforate below zones from the bottom up: a. Discuss wellhead pressure with OE. If necessary RU Nitrogen to pressure well prior to perforating. Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom PA Pool CO Estimated Reservoir Pressure P3_A8 ±3,660' ±3,696' 36' ±3,597' ±3,633' Sterling KENAI, STERLING 3 GAS CO 510A 400 PSI P3_A9 ±3,706' ±3,711' 5' ±3,641' ±3,646' Sterling KENAI, STERLING 3 GAS CO 510A 250 PSI P3_A10 ±3,730' ±3,750' 20' ±3,663' ±3,683' Sterling KENAI, STERLING 3 GAS CO 510A 250 PSI P3_A10 ±3,761' ±3,786' 25' ±3,693' ±3,718' Sterling KENAI, STERLING 3 GAS CO 510A 250 PSI P3_A11 ±3,826' ±3,860' 34' ±3,754' ±3,788' Sterling KENAI, STERLING 3 GAS CO 510A 250 PSI P4_B1A ±3,883' ±3,912' 29' ±3,808' ±3,837' Sterling KENAI, STERLING 4 GAS CO 510A 120 PSI P4_B2 ±3,955' ±3,971' 16' ±3,876' ±3,892' Sterling KENAI, STERLING 4 GAS CO 510A 120 PSI P4_B2A ±3,977' ±3,993' 16' ±3,897' ±3,913' Sterling KENAI, STERLING 4 GAS CO 510A 1600 PSI P4_B3 ±4,020' ±4,058' 38' ±3,938' ±3,974' Sterling KENAI, STERLING 4 GAS CO 510A 1600 PSI P5.1_B4A ±4,088' ±4,156' 68' ±4,002' ±4,067' Sterling KENAI, STERLING 5.1 GAS CO 510A 1600 PSI P5.1_B4B ±4,186' ±4,265' 79' ±4,096' ±4,172' Sterling KENAI, STERLING 5.1 GAS CO 510A 1600 PSI 10a. KENAI, P3_A8 ±3,660' ±3,696' 36' ±3,597' ±3,633' Sterling STERLING 3 CO 510A 400 PSI GAS KENAI, P3_A9 ±3,706' ±3,711' 5' ±3,641' ±3,646' Sterling STERLING 3 CO 510A 250 PSI GAS KENAI, P3_A10 ±3,730' ±3,750' 20' ±3,663' ±3,683' Sterling STERLING 3 CO 510A 250 PSI GAS KENAI, P3_A10 ±3,761' ±3,786' 25' ±3,693' ±3,718' Sterling STERLING 3 CO 510A 250 PSI GAS KENAI, P3_A11 ±3,826' ±3,860' 34' ±3,754' ±3,788' Sterling STERLING 3 CO 510A 250 PSI GAS (notice not required if SLB CTU) Conduct MIT-T and MIT-IA for 15 min (1500 psi) KENAI, P4_B1A ±3,883' ±3,912' 29' ±3,808' ±3,837' Sterling STERLING 4 CO 510A 120 PSI GAS KENAI, P4_B2 ±3,955' ±3,971' 16' ±3,876' ±3,892' Sterling STERLING 4 CO 510A 120 PSI GAS KENAI, P4_B2A ±3,977' ±3,993' 16' ±3,897' ±3,913' Sterling STERLING 4 CO 510A 1600 PSI GAS KENAI, P4_B3 ±4,020' ±4,058' 38' ±3,938' ±3,974' Sterling STERLING 4 CO 510A 1600 PSI GAS KENAI, P5.1_B4A ±4,088' ±4,156' 68' ±4,002' ±4,067' Sterling STERLING 5.1 CO 510A 1600 PSI GAS KENAI, P5.1_B4B ±4,186' ±4,265' 79' ±4,096' ±4,172' Sterling STERLING 5.1 CO 510A 1600 PSI GAS cement packer CBL Well Prognosis Well: KBU 44-06 Date: 01-25-2021 b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. A CIBP with 35’ cement top is required to isolate each pool before perforating a new pool 14. POOH. 15. RD E-Line. 16. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Nitrogen (Contingency) 1. If Nitrogen is required to pressure up well prior to perforating: 2. MIRU Nitrogen Unit, review Nitrogen SOP, pressure well to desired perforating pressure. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 3-1/2” Casing Patch or set 3-1/2” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: Current Well Schematic Proposed Well Schematic Standard Well Procedure – N2 Operations CTU BOP Schematic Note: verify Escape control line integrity after jet cut and perforating. may need to cement control lines for zonal isolation. gls Lease: State/Prov:Alaska Country:USA Perf (TVD): Prepared By: Dated Completed: 5,361' - 5,370' 5,778' - 7,120'Perf (TVD): 1.5º / 100ft @ 1,800' ~ 1ºAngle/Perfs: Well Name & Number: Municipality: January 25, 2021 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:Jake Flora February 22, 2002 PBTD 7,323' MD 7,191' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002 TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg 5344' downhole sensor, conductor wire Excape System Details: Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) Module 11 6291' - 6301' (frac'd 7/9/02) 2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08) Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08) Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08) Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' SCHEMATIC Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Tree cxn = 4-3/4" Otis 9-5/8 x 12-1/4 TOC @ 2424' (calc w 25% washout) 3-1/2 x 9-5/8 TOC @ 4620' (1-20-21 CBL) UB-8 TOC 4620ft Proposed Sterling Perforations Sand MD Top MD Btm TVD Top TVD Btm P3_A8 ±3,660'±3,696'±3,597'±3,633' P3_A9 ±3,706'±3,711'±3,641'±3,646' P3_A10 ±3,730'±3,750'±3,663'±3,683' P3_A10 ±3,761'±3,786'±3,693'±3,718' P3_A11 ±3,826'±3,860'±3,754'±3,788' P4_B1A ±3,883'±3,912'±3,808'±3,837' P4_B2 ±3,955'±3,971'±3,876'±3,892' P4_B2A ±3,977'±3,993'±3,897' ±3,913' P4_B3 ±4,020'±4,058'±3,938' ±3,974' P5.1_B4A ±4,088'±4,156'±4,002' ±4,067' P5.1_B4B ±4,186'±4,265' ±4,096' ±4,172' Lease: State/Prov:Alaska Country:USA Perf (TVD): January 25, 2021 Kenai Gas FieldKenai Beluga Unit 44-6 Kenai Penisula Borough Perforations (MD): Angle @ KOP and Depth: Last Revison Date:Jake Flora February 22, 2002 Prepared By: Dated Completed: 5,361' - 5,370' 5,778' - 7,120'Perf (TVD): 1.5º / 100ft @ 1,800' ~ 1ºAngle/Perfs: Well Name & Number: Municipality: PBTD 7,323' MD 7,191' TVD TD 7,440' MD 7,308' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. Permit #:200-179 API #:50-133-20498-00-00 KB Elevation:87' (21' AGL) Property Des:A-028142 Spud Date:1/31/2002 TD Date:2/17/2002 Rig Released:2/22/2002 @ 21:00 hrs Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg 5344' downhole sensor, conductor wire Excape System Details: Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) Module 11 6291' - 6301' (frac'd 7/9/02) 2-1/8" 6 spf 60º 6349' - 6356' (perfed 3/25/08) Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6674' - 6689' (perfed 3/25/08) Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0º 6762' - 6784' (perfed 3/19/08) Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60º 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) KOP:@ 1,500' MD Build: 1.5 deg/100' Hold Angle:18º @ 2,715' MD Drop:4,200' Final Angle:0º @ 5,415' PROPOSED Perforation Detail Sands Top (MD) Btm (MD) Gun Size SPF Status Date UB-8 5,361' 5,370' 2-3/8" 5 Open 08/30/19 Tree cxn = 4-3/4" Otis 9-5/8 x 12-1/4 TOC @ 2424' (calc w 25% washout) 3-1/2 x 9-5/8 TOC @ 4620' (1-20-21 CBL) Jet Cut tubing @ ~4500' Set CIBP @ ~5310' Planned 3-1/2 x 9-5/8 annulus TOC @ ~2700' Planned Sterling Perfs ~3660' - 4265' CBL required for TOC TOC 4620 ft C MIT-IA 1500 psi UB-8 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coiled Tubing HydraCo 60K Injector Head & Gooseneck Weight = 3500 lbs 3" 500psi ArmorPak Stripper Bowen Type 5K 5.5" Lubricator 5K CJS ArmorPak Guide Bowen Type 5K x 5-1/8" 10K Flange 5-1/8" 10K Quad BOP 1.ArmorPak 1.5" x 1.5" Pipe Ram 2.ArmorPak 1.5" x 1.5" Pipe Ram 3.Shear Ram 4.Blind Ram 5-1/8 10K Spool with 2-1/16" 10K Outlets - Kill Port Manual Valve 1: 2-1/16" 10K Manual Valve 2: 2-1/16" 10K Manual Valve 3: 2" Weco 1502 Adapter Spool 5-1/8" 10K x 7-1/16" 5K Adapter Spool 7-1/16" 5K x 5-1/8" 5K 5-1/8" 5K ArmorPak 1.5" x 1.5" CT Head Wellhead STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Llj Fracture Stimulate Li Pull Tubing L1 Operations shutdown Ll Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plugfor Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Stratigraphic❑ Exploratory ❑ Service ❑ 200-179 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20498-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028142 Kenai Beluga Unit (KBU) 44-06 9. Logs (List lags and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai - Beluga/Up Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 7440 feet Plugs measured N/A feet true vertical 7308 feet Junk measured 7217 (fill) feet Effective Depth measured 7323 feet Packer measured N/A feet true vertical 7191 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20" 114' 114' Surface 1,509' 13-3/8" 1,509' 1,507' 5,020psi 2,260psi Intermediate 5,437' 9-5/8" 5,437' 5,309' 5,750psi 3,090psi Production 7,393' 3-1/2" 7,393' 7,261' 10,160psi 10,530psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" Excape Tbg 9.3# / L-80 7,393' MD 7,261' TVD Packers and SSSV (type, measured and true vertical depth) 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 0 0 0 0 Subsequent to operation: 0 0 0 0 10 14. Attachments (required per 20 AAC 25.070, 25.071, &26.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Development E] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ ESTER ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-369 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramera[7.hilcom.com Authorized Signature: !� // /f r Date: �b 21 Contact Phone: 777-8420 Form 10-404 Revised 4/2017�///� ��,.�' RBDMS OCT 072019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 44-06 E-Line 1 50-133-20498-00-00 1 200-179 8/29/19 1 8/30/19 Daily Operations: 08/29/2019 - Thursday PTW, JSA and SIMOPS with AKE-Line and SLB N2. Rig up lubricator and hard lines. PT lub and hard lines to 250 psi low and 4,000 psi high. RIH w/GPT tool tie in to log sent from town. Found fluid level at 1,700' and stopped at first mod. Wanted to make sure we had perfs to push fluid in. POOH. Send correlation log to town and was 17' off. Added wt bars and run in hole with GPTto 2,000'. Started pumping N2 and watched fluid go by all the way to 5,900'. Pump N2 on a 1,000 scf up to 2,300 psi. Pump total of 1,000 gals of N2. POOH. RIH w/2-1/2" Plug and tie into the shifted GPT log. Ran correlation log and send to town. Get ok to set plug at 5,400' with 1,850 psi on tubing. Spotted and set plug at 5,400'. Lost 150 lb line tension when set. Picked up 30' and went back and tagged plug. POOH. Good set. RIH w/ 2-1/2" x 20' bailer filled with 3.7 gal of 17 ppg cement and dump on top of plug at 5,400'. POOH. Good dump. Est TOC - 5,390' and CIP - 2200 hrs. Rig down lubricator and secure well. Will be back at 10 am in the morning to pert well. 08/30/2019 - Friday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3000 psi high. TP - 1,890 psi. RIH w/ 2- 3/8" x 9' HC Razor, 5 spf, 60 deg phase and tie into Plug log. Run correlation log and send to town. Shifted log 1' up per town. Spotted and fired gun from 5,361' to 5,370' with 1,890 psi on tubing. Pressure stayed at 1,890 for 15 min. POOH. All shots fired and gun was dry. TP - 1,877 psi. Fired gun at 1412 hrs. Rig down lubricator from well and turn over to field. Get equipment ready to move to KBU 22-06 tomorrow. 200-179 2/22/2002 21:00 hrs Tree cxn " Otis KOP: 0 1,500' MD Build: 1.5 ded100' Hold Anoie: 180 @ 2,715' MD Drop: 4,200' Final Angle: 00 @ 5,415' Promore downhole sensor 0 5,344' MD (5,21T ND) w/ 7/18" electric cable (dust - armored, 7 -strand conduclor) to surface OnelOKpreasure sensors one temperature sensor 15 Conventional flappers, Mod 1 no flapper - Module 1 fired using RFID tag (315/02) - Both control lines open for methanol injection (7/9/02) Kenai Penisula Borough - Ceramic flappers removed with coil (719/02) Flapper depth ul 11f Module 16 5928' Module 15 5964' Module 14 6045' Module 13 6129' Module 12 6169' Module 11 6309' Module 10 6441' Module 9 6512' Module 8 6581' Module 7 6648' Module 6 6740' Module 5 6892' Module 4 7000' Module 3 7068' Module 2 7215' Module 1 NA KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T414, R11 W, S.M. CIBP @ 5,400' w 10' Cmt (TOC 5,390') 8/29/19 SCHEMATIC U Hilcorp Alaska Conductor 20" K35 133 ppf r0. Bonom MD 0' 114' TVD 0' 114- S.0.. 14'S.0.. Casino 13-3/8" L40 68 ppf BTC 9�j=r4 MD Tor 1,509' TVD 0' 1.507- 17-112" hole, Chat .1650 aks (186 bichd 12 ppg, Type 1 with 140 We cost to funia... Intennedlate Caelnc 83/8" L40 appf Bort To v Bottom MO 0' 5,437' / J TVD 0' 5,309- 12-::/4 ,309' 12-1/4" hole, Cort w/ 93 she (42 bbl.) Class G 12 ppg Lead, followed w/515 aka (168 bbls) Class G 13.5 pp, T.H. No retuma to aU fac.. Production Casino 3-112" L40 9.3 Ppf EUE eb w/5.25" OD Motted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261- 8-112" hole, Coot w/ 930 sks (50 bbls) Class G 10.5 ppg xn sem as - ec con m IIrIe or mod 9 -1g -Green control Ilne for Ipodul6s2- 1s 2-8 ule- era a tag pe P with Kenai Penisula Borough QjjQ gg pg rac' o u e7'Igg .jI2d3 1' - 0 71' raac' �ta1' ul 11f 1' ` roc %908 �I 60° - D t5,361' Angle/Peds: � u 66spf 0° (j)Jy18)) � 2, 1-11/16"6 spf 0° Module 5 31' /8/ 6762'-6784' PPerfeddd773/19/08) 6874'-6884' frac'd7/8/02) 1-11/16" 6spf 60° 6938'-6950'(erfed 3/19108) Module 4 rac'd 7/8/02) 6982'-6992'11,111.1-d Module 3 7050'-706 0' racd 7/8/02) Module 2 7198'-7208' radd 7/8/02)) Module 1 7242'-725 2' 718/02 • Kenai Beluga Unit 44-6 Lease: Perforation Detail PBTD Kenai Penisula Borough State/Prov: Alaska 'Damaged pipe ( reduced ID) @ 6,431'(3119108) Ed,ToM13BtmMDIur 7,323' MD S- PF tat D t5,361' Angle/Peds: 'Sl ckline tagged fill @ 7,217' MD (6/6!03) Dated Completed: 5,370' 23/8" 5 Open 08/30/19 Well Name & Number: Kenai Beluga Unit 44-6 Lease: TD PBTD Kenai Penisula Borough State/Prov: Alaska 'Damaged pipe ( reduced ID) @ 6,431'(3119108) 7,440' MD 7,323' MD Ped (ND): 'Tag reduced ID @ 6,429'(4/16109) w/ 2.5" & 1.9" LIB 7,308' ND 7,191' ND Angle/Peds: 'Sl ckline tagged fill @ 7,217' MD (6/6!03) Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910'- 7,252' Ped (ND): 5,778' - 7,120' Angle @ KOP and Depth. 1.5° / 100ft @ 1,800' Angle/Peds: - 1e Dated Completed: February 22, 2002 Prepared By: Donna Ambruz Last Revison Date: September 18, 2019 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Field, Beluga/Upper Tyonek Gas Pool, KBU 44-06 Permit to Drill Number: 200-179 Sundry Number: 319-369 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.oloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 104 Daniel T. Seamount, Jr. Commissioner DATED this lS day of August, 2019. RBDMS±j AUG 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AUG 13 2019 5'E0+._k C bet 1. Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑� Stratigraphic ❑ Service ❑ 200-179 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20498-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510a Will planned perforations require a spacing exception? Yes ❑ No M Kenai Beluga River (KBU) 44-06 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028142 Kenai / Beluga/Up Tyonek Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,440' 7,308' 7,323' 7,191' -1,726 psi N/A 7,217' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20 114' 114' Surface 1,509' 13-3/8" 1,509' 1,507' 5,020psi 2,260psi Intermediate 5,437' 9-5/8" 5,437' 5,309' 5,750psi 3,090psi Production 7,393' 3-1/2" 7,393' 7,261' 10,160psi 10,530psi 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" Excape Tubing 9/3# / L-80 7,393' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary L4J Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for Ift 15. Well Status after proposed work: Commencing Operations: August,Wd, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: {nasse(oilhilcoro.com Contact Phone: 777-8354 ZM '4 Authorized Signatur : Date: COMMISSIO SE ONLY Conditions of approval: fqotify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other:�^ $- �1 1 T L iq '4BDMSpU6 19 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: I O _ 1-10f APPROVED BY S/1 �^ Approved by: THE COMMISSION Date: ,./ ! � �p 1/{ /C'�OMMISSIONER �(/ ��7� I (� D I A Submit Form and it �(0 Form 1 Revised 4/2 17 Approved applicati 'L3S,lAt 1/n1 alLbl the date of approval. Attachments Duplicate y�� vI N � B Wir t4i r H Elilwrn Alaska, Lb Well Prognosis Well: KBU 44-06 Date:08/09/2019 Well Name: KBU 44-06 API Number: 50-133-20498-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: August , 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-179 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Maximum Expected BHP: -2,249 psi @ 5,230' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: -1,726 psi (0.10 psi/ft gas gradient) Brief Well Summary The KBU 44-06 was initially drilled and completed in 2002. It was initially completed w/ 3.5" casing as a multi- stage fracked Lower Beluga / Upper Tyonek completion. The well went down in 2014 due to sand and Hilcorp has been unable to return the well to production in the original completed intervals (^3.6 Bscf of cum production). 9 The purpose of this work/sundry is to plug back and add perforations in the UB -8 sand in the Upper Beluga formation. Mlr 1A Procedure: 1. MIRU E -line, PT lubricator to 2,000 psi Hi 250 Low. 2. RU with PT tool to determine fluid level. POOH p -c z- '"j a. Note: Prior to running PT tool, pressure up well with gas to try to push fluid away. 3. MU 3-1/2" CIBP. RIH and set at ^'5,400'. POOH 4. MU Bailer and dump bail 10' of cement on top of plug. POOH. RD E -line. 5. RU Slickline. Swab fluid down to -5,370'. Confirm depth with Engineer prior to concluding swabbing operations. RD Slickline. Pressure well with methane to achieve desired underbalance. 6. RU E -line. RU perforating guns. 7. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT Upper Beluga UB -8 5,361' 5,370' 9 a. Bleed tubing pressure as require by Engineer. b. Proposed perfs shown on the proposed schematic in red font. c. Use Gamma/CCL/to correlate. Engineer to provide correlation log. d. Record tubing pressures before and after each perforating run. 8. POOH and RD E -line. 9. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 2/17/2002 ld: 2/22/2002 (fig- 21:00 hrs Tree czn = 43/4" is KOP. @ 1,500' MD Build: 1.5 deg/100' Hold Angle: 180 @ 2,715' MD Pro : 4,200' Final Angle: 00 @ 5,415' Promote downhole sensor @ 5.344 MD (5.217 TVD) w/ 7116" electric Cable (dual - armored, 7 -strand conductor) to surface. One 10K pressure sensors one temperature sensor 15 Conventional flappers, Mod 1 no flapper - Module 1 fired using RFID tag (3/5102) - Both control lines open for methanol injection (719/02) 6.172'-6.198' - Ceramic flappers removed with Coil (7/9102) Flapper depth Perforations (MD): Module 16 5928' Module 15 5964' Module 14 6045' Module 13 6129' Module 12 6169' Module l l 6309' Module 10 6441' Module 9 6512' Module 8 6581' Module 7 6648' Module 6 6740' Module 5 6892' Module 4 7000' Module 3 7068' Module 2 7215' Module 1 NA KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11 W, S.M. C/ U Hilcorp Alaska Conductor 20" K45 133 par Top am.. MD 0' 114' TVD a' 114' Sudasa Casino 13JA" L20 66 Plot BTG Top 9.5[11 VI 0' 1,609' TVD 0' 1,SOT 174/Y' holo, Cost .1650 sks(1tl6 MIS) 12 ppg, Type 1 with 840 hm, sot to •urhes. Intermediate Osino 92/r 1.20 M ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12.114" bole, Can wl 93 sow (42 bbls) Class 12 poll Lead, foll.em.1615 sks (166 bbls) Class G 13.5 ppg Tsil. No alums to surface. INmuction Casino 3412" 120 9.0 ppf EUE SM wM.25" OD eloped couplings to 1.386' Top a.". IAD ;ierrya 7,393' 8-1R" bole, Cmt w/ 930 sk. (50 bbl.) Cies. G 10.5 poll 1 1.4j 9- 6spf 00 6722' 6 spf 0° 6762' 5 6874' 6spf 600 6938' 3 7050 2 7198' 1 7242' PROPOSED Perforations Kenai Beluga Unit 44.6 _jw) Kenai Gas Field Municipality: 6.172'-6.198' 1 ° Perforations (MD): 5,910' .7,252- TO 7,440' MD PBTD I 7,323' MD Angle Q KOP and Depth: 'Damaged pipe ( reduced ID) @ 8,431'(3/19/08) 'Tag reduced ID @ 6,429(4116/09) w/ 2.&'& 1.9" LIB 'Slicklme Angle/Perfs: 7,308' TVD 7,191' TVD February 22, 2002 tagged fill @ 7,217' MD (6/6103) Well Name & Number: Kenai Beluga Unit 44.6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910' .7,252- Pert (TVD): 5,778' - 7,120' Angle Q KOP and Depth: 1.5°1100h @ 1,800' Angle/Perfs: - 1° Dated Completed: February 22, 2002 Prepared By: James Ostroot Last Revison Date: April 17, 2009 33-20498-00-00 n: 87' (21'AGL) s: A-028142 2/22/2002 21:00 hire Tree can = 4-3/4" Otis KOP: @ 1,500' MD Build: 1.5 deg/100' Hold Angle: 180 @ 2,715' MD 270D: 4,200' Final Angle: 0'@5,415' Promom downhole sensor @5344' MO (5,217' TVD) .17/16" electric cable (dual - rumored, 7 -strand conductor) to surface. One 101K pressure sensors one temperature sensor 15 Conventional flappers, Mod 1 no flapp - Module 1 fired using RFID tag (3/5/02) - Both control lines open for methanol injection (7/9/02) Sand. - Ceramic flappers removed with coil (7/9/C Flapper depth UB -8 Module 16 5928' Module 15 5964' Module 14 6045' Module 13 6129' Module 12 6169' Module 11 6309' Module 10 6441' Module 9 6512' Module 8 6581' Module 7 6648' Module 6 6740' Module 5 6892' Module 4 7000' Module 3 7068' Module 2 7215' Module 1 NA PROPOSED Perforations 6,172'- 6.198' KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T414, R11 W, S.M. PROPOSED SCHEMATIC U Hilcorp Alaska Conductor 20" K-55 133ppf TD PBTD 7,440' MD 7,323' MD 7,308' TVD 7,191' TVD A 11 60- 7 0° 7 7 66sPf 0° 6 spf 0° 5 6spf 60° 4 3 2 1 Kenai Beluga Unit 44-6 Top Bottom MD 9 114' Kenai Gas Field Sand. TN O 0' 114' Btm (MDI Gun $is. SPF Su,lace Casino UB -8 5,361' 133/8" L-80 68ppf BTC Proposed Angle KOP and Depth: Top am.. Angle/Perfs: — 1e MD 0' 1,509 February 22, 2002 TVD 0' 1,50T Prepared By: James Ostroot 17-112" hob, Chit w1650 airs (186 Ma) 12 ppg, Type l with 140 bbl. chit to side... Intermediate Casino ' (n//��1 �J 1, VA`"" P V 9 -MI. L-80 40 ppf Butt Top Bottom MD V 5,437' S TVD 0' 5,3o9 ` 6 2-1/4" hole, Clot wl 93 a"(42 Mrs) Class 12 ppg Lead, followed w1515 sks(10 bbls) Class �✓J!/!�/" G13.6 ppg Tail. No Mums to surface. Production Cas'na 3-1/2" L-00 9.3 ppf EUE BM w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,39T TVD 9 7,261' 8-112" hole, Cmt w/ 930 sk. (50 bbl.) Class G 10.5 ppg TD PBTD 7,440' MD 7,323' MD 7,308' TVD 7,191' TVD A 11 60- 7 0° 7 7 66sPf 0° 6 spf 0° 5 6spf 60° 4 3 2 1 `Damaged pipe ( reduced ID) @ 6,431'(3/19/08) `Tag reduced ID @ 6,429'(4/16109) W/ 2.5" & 1.9" LIB `Slickline tagged fill @ 7,217' MD (6/6/03) Well Name & Number: Kenai Beluga Unit 44-6 Perforation Detail Kenai Gas Field Sand. ToplMD1 Btm (MDI Gun $is. SPF Status Date UB -8 5,361' 5,370' Proposed `Damaged pipe ( reduced ID) @ 6,431'(3/19/08) `Tag reduced ID @ 6,429'(4/16109) W/ 2.5" & 1.9" LIB `Slickline tagged fill @ 7,217' MD (6/6/03) Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska ICountry: USA Perforations (MD): 5,910'- 7,252' Pert (TVD): 5,778' - 7,120' Angle KOP and Depth: 1.5. / 100ft @ 1,800' Angle/Perfs: — 1e Dated Completed: February 22, 2002 Prepared By: James Ostroot Last Revison Date: April 17, 2009 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Thursday, August 15, 2019 1:11 PM To: Taylor Nasse Cc: Donna Ambruz; Bo York Subject: RE: [EXTERNAL] RE: KBU 44-06 (PTD 200-179) add perfs Taylor, Thanks for the clarification. Keep close eye on the IA pressures on all of these after perforating. We are getting close to the estimated TOC on all of these wells. There are possible channels that may exist down to these zones even if IA pass a MIT currently. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv schwarz@alaska.aov). From: Taylor Nasse <tnasse@hilcorp.com> Sent: Thursday, August 15, 2019 11:59 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: RE: [EXTERNAL] RE: KBU 44-06 (PTD 200-179) add perfs Hi Guy - The TOC for KBU 22-06 that is listed on the schematic (5,150') is accurate, with good cement isolation from 5,390'- 5,474'. The TOC for KBU 34-06 that is listed on the schematic (4,100') is also accurate, with good cement isolation from 4,110'-4,750'. For KBU 44-06 they didn't run a CBL for some reason, but they did run a caliper log prior to casing and cementing and had full returns during the cement job, bumped the plug, and the floats held. Based on the calculated hole volume from the caliper run and the volume of cement pumped, I came up with an estimated 630' of cement above the 9-5/8" shoe (Est. TOC =4,805'). As we discussed, we will plan to perform a charted MIT to 1,500 psig for 30 minutes prior to perforating and will closely monitor the IA after perforating. I also forgot to include the CIBP and cement on the proposed schematic, but we'll definitely have it on the schematic for the 10-404, if that works. I'll also plan to add my estimated TOC to the schematic as well. If you have further questions or need additional information, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907) 903-0341 cell From: Schwartz, Guy L (CED)[mailto:¢uv.schwartzPalaska.aov] Sent: Thursday, August 15, 2019 8:54 AM To: Taylor Nasse <tnasse@hilcorp.com> Subject: [EXTERNAL] RE: KBU 44-06 (PTD 200-179) add perfs This goes for all your KBU addperfs wells. Have a couple more. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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). If may contain confidential and/or privileged information. The unauihorized review, use or disclosure of such information may violate state or federal law. If you ore 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 Guy Schwartz at (907-793-1226) or (Guv schwartz®alaska.gov). From: Schwartz, Guy L (CED) Sent: Thursday, August 15, 2019 8:39 AM To: Taylor Nasse <tnasse@hilcorp.com> Subject: KBU 44-06 (PTD 200-179) add perfs Taylor, Did you look at the CBL to verify TOC is above your proposed perfs.? Also your proposed schematic doesn't indicate the CIBP with cement. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 if to you, contact Guy Schwartz at (907-793-1226 ) or (Guv schwartz@alaska aov). u ~ Marathon IIM1pRAiHON ~Alaska Prvduction LLC M~athon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~rv~~ 0 C T ~: ~ ~00'~ October 14, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations ~.t~lc~a pil & Gas Con~. ~ommission pnch4raqA ab' L`7~ ~, Field: Kenai Gas Field Well: Kenai Beluga Unit 44-6 ~ ,u~~;;~; Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 44-6 well. The AOGCC provided approval for the addition of 26' of perforations under Sundry # 308-382. Marathon no longer intends to perform this activity and is closing out this sundry as a Non-Work activity:~Other wells in this program experienced reduced production when perforated, which was caused by additional water infiltrating the wellbore. This decision is intended to minimize the risk of loosing crucial production while entering the high demand season. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, , ..2~11~v-~~ . `j Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS - ~ STATE OF ALASKA ~~T ~ ~ ~Q~(~ Looq ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONSAIas~Ca Qi18~Gas Cons. Commission Anchorag~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Non-Work of PerFormed: Alter Casing ~ Pull Tubin~ Perforate New Pool ~ Waiver ~ Time Extension ^ Perforations Change Approved Program ~ Operat. Shutdowr0 Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: f ame: Development Q Exploratory^ 200-179 3. Address: p0 BOx 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20498-00-00 7. KB Elevation (ft): 9. Well Name and Number: '~„ 87' 21' AGL Kenai Belu a Unit 44-6 8. Property Designation: 10. Field/Pool(s): ~~~~k ~~' (~'- ~, A- 028142 Kenai Gas Field / eluga Pool 11. Present Well Condition Summary: Total Depth measured °'~ 7,44p' feet Plugs (measured) NA true vertical 7,308' feet Junk (measured) NA Effective Depth measured 7,32g' feet true vertical 7,191' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 93' 20" 114' 114' 3,060 psi 1,500 psi Surface 1,488' 13-3/8" 1,509' 1,507' 5,020 psi 2,260 psi Intermediate 5,416' 9-5/8" 5,437' 5,308' 5,750 psi 3,090 psi Production 7,372' 3-1/2" 7,393' 7,261' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 5,910' - 7,252' True Vertical depth: 5,778' - 7,120' Excape Tubing 3-1/2" L-80 7,393' Tubing: (size, grade, and MD) Capillary String Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): The approved perforation additions were not added because of the additional water infiltration issues experience with some of the other Treatment descriptions including volumes used and final pressure: wells, in this program, after they were perforated. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations 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: 308-382 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician a Signature ~ ,`~ Phone (907) 283-1371 Date October 14, 2009 Form 10-404 Revised 04/2006 ~ ~~~~ ~~ Submit Original Only Kyle Miranda Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 ~~ ~ ` f ° ill,',' .~ ~ ~U~it: c 7`:r+:T'~~P~~w Re: Kenai Gas Field, Upper Tyonek/Beluga Gas Pool, 44-6 Sundry Number: 308-382 p`~,O b Dear Mr. Miranda: 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, Cathy . Foerster Commissioner DATED this 'day of October, 2008 Encl. • ` M Marathon MARATHON Oil Company October 20, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th 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 ~~~.~:: At,~sk~ Oid ~ G~~, ~; ~ ~ , A~~ . a . ~ , i Reference: 10-403 Application of Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 44-6 Dear Mr. Maunder: Attached for your records is the10-403 Application of Sundry Approvals for KBU 44-6 well. Marathon proposes to enhance gas production by adding 26' of perforations to the Beluga formation. The proposed operation will be performed during one perforating gun run at: MD TVD ft 6,172' - 6,198' 6,040' - 6,066' 26 Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application of Sundry Approvals cc: Houston Well File Well Schematic Kenai Well File Perforation Procedure KJS KM r STATE OF ALASKA ` J,U LA~OIL AND GAS CONSERVATION COMN~ON `APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~~ ~~" ~~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q - Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 200-179- 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20498-00-00- 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: E R ? ~ ^ Kenai Beluga Unit 44-6 _ Spacing xception equired Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A - 028142 87' (21' AGL) Kenai Gas Field /Beluga Pool 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): 7,440' - 7,308' - 7,323' - 7,191' - NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 93' 20" 114' 114' 3,060 psi 1,500 psi Surface 1,488' 13-3/8" 1,509' 1,507' 5,020 psi 2,260 psi Intermediate 5,416' 9-5/8" 5,437' 5,308' 5,750 psi 3,090 psi Production 7,372' 3-1 /2" 7,393' 7,261' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,910' - 7,252' gross 5,778' - 7,120' gross 3-1/2" L-80 7,393' 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 ^ BOP Sketch ^ Exploratory ^ Development ~ ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 4, 2008 Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. !hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kyle Miranda Title Production Engineer Si nature ~ /hone Date g ~ (907) 283-1370 October 20 2008 , ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3v~_38ot Plug Integrity ^ BO leara n P Test ^ Mechanical Integrity Test ^ Locati on C ce ^ / ( i l / ~ Other: •v~t:.~\Cbt~~~'O` ~~V~ ~~Ev~~ .l lid G.C~~ ~r.3/ J®+'~~C..(~-~~ ~~~r Subsequent Form Required: ~~ APPROVED BY Approved by: P~~~i~/~ COMMISSIONER THE COMMISSION Date: /D ~ ~~v Form 10-403/Revised 06/2006 ; T; ~~ ~ ~ g ~ '~,f~3#~ ~~ ~ ~~ ~ ~ Submit in Duplicate ~.. • M MARATHONI Marathon Oil Corporation Field: Kenai Beluga Unit WBS: Not requested yet Pad: 41-7 KBU 44-6 • September 18, 2008 Well Status: 1.712 MMcf/d @ 364 psi (SCADA 9-17-08) and 8 bwpd (TOW 9-17-08). Objective: Perforate the following Beluga sands. Depth and surface pressure to fire guns: 6172' - 6198' (26' net, 20' & 6' tandem guns, one run) - 700 psi Guns to be used: 2-3/8" RTG (Retrievable Tubing Gun) guns loaded 4 SPF 60 degree-phased with TAG-2375-402NTX charges and PX-1 firing head. API target performance: 0.27" entrance hole and 19.21" penetration. Max gun swell in air: 2.575" OD. Procedure• a) Remove well house if needed. b) MI diesel man-lift and lights. c) MIRU Expro E-line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment. d) Hold PJSM. e) PT lubricator to 2000 psi (MPSP+) with KCL H2O or methanol, weather dependent. f) RIH with dummy guns to minimum depth needed for CCL correlation. POOH GR. 2. a) RIH w/ 26' of guns (type shown above). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 700 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 6172' - 6198' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. e) LD spent perf gun and lubricator. RD Expro. Return well to production. Flow test. 3. Produce well to sales. CONTACTS Ken Walsh: 907-283-1311 (w) Jennifer Enos: 713-296-3319 (w) 907-394-3060 (c) 713- 408-3583 (c) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (c) KGF Operators: 907-283-1305 • • 40% dd MD Formation Formation WAM calculated AT SURFACE Bottom tvd Pressure* pressure firlnr pressure a! 40°,', dd temp 6198 6066 1331 799 698 117 *estimated reservoir pressure No actual MFT data. Did not add earlier due to depletion KBU 44-6 Add perfs - MDD 10/20/2008 9:28:13 AM #: ,200-179 'S0-133-20498-00-00 ration: 87' (21' AGL) :y Des: A-028142 ate: 1/31/2002 :• 2/17/2002 eased: 2/22/2002 Tree cxn = 4-3/4" Otis KOP: @ 1,500' MD Build: 1.5 deg/100' Hold Angle: 18° @ 2,715' MD Drop: 4,200' Final Angle: 0° @ 5,415' KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. ,, a ~~,, ~~! M MAiGT110N Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. Excape Svstem Details - 16 Excape modules run - Module 1 fired using RFID tag (3/5102) - Both control lines open for methanol injection (7/9/02) - Ceramic flappers removed with coil (7/9/02) Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) Module 11 6291' - 6301' (frac'd 7/9/02) 2-1/8" 6 spf 60° 6349' - 6356' (perfed 3/25/08) Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02) 1-11/16" 6 spf 0° 6674' - 6689' (perfed 3/25/08) Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0° 6762' - 6784' (perfed 3/19/08) Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60° 6938' -6950' (perfed 3/19/08) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-114" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,393' TVD 0' 7,261' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg @ 5,344' MD (5,217' TVD) w/ 7/16" electric cable (dual- armored, 7-strand conductor) to surface. One 10K pressure sensors one temperature sensor Damaged pipe (reduced ID) @ 6,431' (3/19/08) Slickline tagged fill @ 7,217' MD (6/6/03) TD PBTD 7,440' MD 7,323' MD 7,308' TVD 7,191' TVD PROPOSED Additional Perforati.~ 6,172' - 6,198 Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910' - 7,252' Perf (TVD): 5,778' - 7,120' Angle @ KOP and Depth: 1.5° 1100tt @ 1,800' Angle/Perfs: - 1° Dated Completed: February 22, 2002 Prepared By: Kevin Skiba Last Revison Date: October 20, 2008 M Marathon MARATHON Oil Company • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 9071283-1350 April 22, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 44-6 Dear Mr. Maunder: ab~"~'1~ Attached for your records is the 10-404 Sundry Report for KBU 44-6 well. This sundry covers the perforation work completed under Sundry #308-068. Fifty six feet of perforations were added to the Beluga formation to access zones between the existing Excape modules. The four perforating operations were conducted on (6,938'-6,950'), (6,762'-6,784'), (6,674'-6,689'), and (6,349'-6,356') measures depth intervals. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~.~~J Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Operations Summary Kenai Well File Current Well Schematic KJS KDW APR 2 4 2008 Alaska Oil 8 Gas Cons. Commission Anchorage ~~~ APR ~ ~ zoos STATE OF ALASKA ~/ ~~ ALA OIL AND GAS CONSERVATION COMAA1~510N ~C~Cf~E~ APR 2 4 Z00& REPORT OF SUNDRY WELL OPERATIO~g -Ar2iSMca fit & Gas Cons. C~rnmic~i~-~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Othe hOCB~e Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ 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 ^~ Exploratory^ 200-179 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20498 00-00 7. KB Elevation (ft): 9. Well Name and Number: 8T 66' AGL Kenai Belu a Unit 44-6 8. Property Designation: 10. Field/Pool(s): ,~~ A - 028142 -~~0~ Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7,440' ~ feet Plugs (measured) NA true vertical 7,3pg' ~ feet Junk (measured) NA Effective Depth measured 7,323' ~ feet true vertical 7,191' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 93' 20" 114' 114' 3,060 psi 1,500 psi Surface 1,488' 13-3/8" 1,509' 1,507' 5,020 psi 2,260 psi Intermediate 5,416' 9-5/8" 5,437' 5,308' 5,750 psi 3,090 psi Production 7,372' 3-1/2" 7,393' 7,261' 10,160 psi 10,530 psi Liner Perforation depth: Measured depth: 5,910' - 7,252' gross True Vertical depth: 5,778' - 7,120' gross Tubing: (size, grade, and measured depth) NA NA NA 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 1,650 16 0 400 Subsequent to operation: 0 1,850 41.5 0 405 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: 308-068 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer ~( nQ Signature ~w` ~ „~ ~ Phone (907) 283-3111 Date Aprll 22, 2008 Form 10-404 Revised 04/2006 ~,~ :,yu~ ~~, ~~R ~' ~ ~Q~~ ~~~~ Submit Original Only 50-133-20498-00-00 'ation: 8T (21' AGL) y Des: A-028142 ate: 1 /31/2002 2/17/2002 cased: 2/22/2002 @ 21:00 hrs Tree cxn = 4-3/4" Otis KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. ri KOP: @ 1,500' MD Build: 1.5 deg/100' Hold Angle: 18° @ 2,715' MD DfOp: 4,200' Final Angle: 0° @ 5,415' - 16 Excape modules run - Module 1 fired using RFID tag (3/5/02) - Both control lines open for methanol injection (7/9/02) - Ceramic flappers removed with coil (719/02) Perfs: Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) Module 11 6291' - 6301' (frac'd 7/9/02) 2-1/8" 6 spf 60° 6349' - 6356' (perfed 3/25/08) Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 718/02) Module 7 6630' - 6640' (frac'd 7/8/02) 1-11/16" 6 spf 0° 6674' - 6689' (perfed 3/25/08) ¢' Module 6 6722' - 6732' (frac'd 7/8/02) 1-11/16" 6 spf 0° 6762' - 6784' (perfed 3/19/08) 8- Module 5 6874' - 6884' (frac'd 7/8/02) 1-11/16" 6spf 60° 6938' -6950' (perfed 3/19/08) ~- Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 7/8/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) ~~ !M L' l • M MARATNOM Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' rvD 0' 114' Surface Casinst 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,509' rvD 0' 1,507' 17-112" hole, Cmt w/ 650 sks (186 bbls)12 ppg, Type 1 with t40 bbls cmt to surface. Intermediate Casing 9-5/8" L-80 40 ppf Butt Top Bottom MD 0' 5,437' rvD 0' 5,309' 12-1/4" hole, Cmt w/ 93 sks (42 bbls) Class G 12 ppg Lead, followed w1515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. 3-1 /2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,440 TVD 0' 7,308' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg Promore downhole sensor @ 5,344' MD (5,217' rvD) w/ 7/16" electric cable (dual- armored, 7-strand conductor) to surface. One 10K pressure sensors one temperature sensor ' Damaged pipe (reduced ID) @ 6,431 (3/19/08) Additional Perforations 7,080' - 7.090' 6.903' - 6.918' 6.844' - 6.858' 6.646' - 6.657' 6.362' - 6,398' 6.172' - 6.198' ~' ~ r S' .* Slickline tagged fill @ 7,217' MD (6/6/03) _ TD PBTD S~~ n1~~ 7,440' MD 7,323' MD 7,3os' rvD 7,1ar rvD Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910' - 7,252' Perf (TVD): 5,778' - 7,120' Angle @ KOP and Depth: 1.5° / 100ft @ 1,800' Angle/Perfs: Dated Completed: February 22, 2002 Prepared By: Kevin Skiba Last Revison Date: April 22, 2008 ~~ `~~~~ • • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 44-6 Page 1 of 4 Common Well Name: KENAI BELUGA UNIT 44-6 Spud Date: 1/31/2002 Event Name: MAINTENANCE/REPAIR Start: 3/10/2008 End: Contractor Name: GLACIER DRILLING Rig Release: 2/22/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To ~ Hours Code Code Phase Description of Operations 3/11/2008 07:45 - 08:10 0.42 SAFETY MTG_ CLNOUT PJSM and discuss Lift plan JSA. 08:10 - 08:30 0.33 PREP_ LOC_ CLNOUT Electrician disconnect power to WH. 08:30 - 09:00 0.50 PREP_ LOC_ CLNOUT Lift off Well House. 09:00 - 10:00 1.00 BLOWD EOIP CLNOUT Operations install LOTO of flow line. Vent gas. 10:00 - 10:40 0.67 CHANG EOIP CLNOUT Roustabouts install 3" 600 valve on flow cross of flow line to RU SAND BUSTER. 10:40 - 11:15 0.58 SAFETY MTG_ CLNOUT Hold Pollard PJSM and discuss JSA. 11:15 - 13:00 1.75 SERVIC EOIP CLNOUT Vetco-gray to grease tree valves. Pollard RU lubricator and MU tools string. 13:00 - 13:30 0.50 RURD_ OTHR CLNOUT Roustabouts install 2" chicksan to sand/gas busters 13:30 - 14:00 0.50 RURD_ SLIK CLNOUT Pollard carry lubricator to WH. Prepare to PT lubricator to 2000 psi. 14:00 - 15:45 1.75 WAITON ORDR CLNOUT Commotion in adjacent well house. Check on personnel inside. All OK. Shut down ALL operations and equipment. Call operations. Report to muster area and account for all personnel. Wait for ALL CLEAR. 15:45 - 16:30 0.75 RURD_ SLIK CLNOUT Recieve ALL CLEAR. Retum to location and RD. Secure well head and location. Suspend operations until morning. 16:30 - 16:45 0.25 SECUR WELL CLNOUT Turn in Permit and sign out. 3/12/2008 07:30 - 08:00 0.50 RURD_ SLIK CLNOUT Start Equipment and light towers. 08:00 - 08:50 0.83 SAFETY MTG CLNOUT Obtain Safe Work Permit. Hold PJSM and discuss Pollad JSA. 08:50 - 09:10 0.33 RURD SLIK CLNOUT PU lubricator. Call vac truck to vac out cellar. WH is too flooded to be _ able to see footing. 09:10 - 09:25 0.25 RURD_ SLIK CLNOUT Pressure test lubricator to 2000 psi. Test good. 09:25 - 09:40 0.25 RUNPU SLIK CLNOUT RIH(1) w/ 2-1/2" DD bailer w/ chisel bottom and 15' of 1/3/4" stem. 09:40 - 10:15 0.58 BAIL_ FILL CLNOUT Tag 6432' KB. Work tools. Fall thru to 6444' KB. Module 10 mfla er. Very sticky pulling up @ 6432' KB. Work tools. Fall thru to 6444' KB again. POOH. 10:15 - 11:00 0.75 RURD_ SLIK CLNOUT OOH. Bailer full of formation water. No sand or solids. 11:00 - 11:24 0.40 BAIL_ FILL CLNOUT PU mule shoe/flapper bottom for 2-1/2" DD bailer and RIH (2) 11:24 - 11:35 0.18 BAIL_ FILL CLNOUT Drop thru Module 10 flapper @ 6444' KB and taq ua ~ 6650' KB•(~Qodule 7 fla0,p~r~~ 11:35 - 12:10 0.58 RUNPU SLIK CLNOUT Drop thru flapper for Module # 7. Tag at 6720' KB. Work tool-fell thru to 6733'KB. (Trash on Module 6 flapper?) Worked tools-fell thru again. Continue RIH to 6820' KB. POOH to check tool. 12:10 - 12:30 0.33 RURD_ SLIK CLNOUT OOH. Bleed pressure. Recover bailer full of frac sand. 12:30 - 13:20 0.83 BAIL_ FILL CLNOUT RIH (3) Fluid level at approx. 5800' wlm. Tag @ 6444' KB. Hit one good lick and fall thru. Continue in hole to 6745' KB (Module 6 flapper). Work tools- Set down-6968' KB. Worked tools and fell to 7009' KB Module 4 flapper). Continue to work tools-fell to 7102' KB. POOH. OOH. Recoverfull bailer of frac sand. 13:20 - 14:25 1.08 BAIL_ FILL CLNOUT RIH (4) w/ 2-1/2" DD bailer to 6434' KB. Work tools-fal- to 6837'KB- Set down work tools fall to 7028' 14:25 - 14:40 0.25 BAIL_ FILL CLNOUT Tag @ 7150' KB work to 7156' KB. Acts like we are bailing sand, instead of fiphtinq flappers. 14:40 - 15:05 0.42 RUNPU SLIK CLNOUT POOH. 15:05 - 15:40 0.58 RURD SLIK CLNOUT OOH. Bailer full of frac sand. 15:40 - 16:15 0.58 RUNPU SLIK CLNOUT RIH (5) w/ 2-1/2" braided line brush. Tag @ 7035' KB. Work tools down to 7090' KB. Sticky. Work tools gently.. 16:15 - 17:15 1.00 RUNPU SLIK CLNOUT Stuck Ccil 7066'KB. No spang action. Suggests we have sand above tools. Pull a "bind" on tools and open up well to flow slowly-able to pull free. POOH. Shut well in. 17:15 - 18:00 0.75 RURD_ SLIK CLNOUT OOH. Bleed lubricator down and RD. 3/14/2008 07:30 - 08:00 0.50 RURD_ SLIK CLNOUT Start Equipment and light towers. Printed: 3/2712008 1:44:35 PM • • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 44-6 Common Well Name: KENAI BELUGA UNIT 44-6 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Code I Phase 3/14/2008 08:00 - 09:00 1.00 SAFETY MTG_ CLNOUT 09:00 - 09:40 I 0.671 REPAIR I EQIP I CLNOUT 09:40 - 09:50 0.17 RURD_ SLIK CLNOUT 09:50 - 10:05 0.25 TEST_ EQIP CLNOUT 10:05 - 10:15 0.17 RURD_ SLIK CLNOUT 10:15 - 10:45 0.50 RUNPU SLIK CLNOUT 10:45 - 11:00 0.25 BAIL_ FILL CLNOUT 10:15 - 11:00 I 0.751 RURD I SLIK I CLNOUT 11:00 - 11:30 0.50 RURD ~ SLIK CLNOUT 11:30 - 11:40 0.17 TEST_ EQIP CLNOUT 11:40 - 12:15 0.58 RUNPU SLIK CLNOUT 12:15 - 12:30 0.25 RURD_ SLIK CLNOUT 12:30 - 12:50 0.33 RURD_ SLIK CLNOUT 12:50 - 12:55 0.08 TEST_ EQIP CLNOUT 12:55 - 13:20 0.42 RUNPU SLIK CLNOUT 13:20 - 14:45 1.42 JAR_ BHA_ CLNOUT 14:45 - 16:00 1.25 BLOWD BG CLNOUT 16:00 - 17:00 17:00 -18:00 1.00 RUNPUL~SLIK CLNOUT 1.00 RURD (SLIK CLNOUT 18:00 - 18:15 3/18/2008 09:00 - 09:30 09:30 - 10:00 10:00 - 10:30 0.25 SECUR WELL CLNOUT 0.50 RURD_ SLIK CLNOUT 0.50 RURD_ SLIK CLNOUT 0.50 SAFETY MTG CLNOUT 10:30 - 11:30 1.00 RURD_ SLIK CLNOUT 11:30 - 11:55 0.42 TEST EQIP CLNOUT 11:55 - 12:30 0.58 RUNPU SLIK CLNOUT 12:30 - 13:20 0.83 RUNPU SLIK CLNOUT 13:20 - 13:25 0.08 RURD_ SLIK CLNOUT 13:25 - 13:40 0.25 TEST_ EQiP CLNOUT 13:40 - 14:10 0.50 RUNPU SLIK CLNOUT 14:10 - 15:00 0.83 RUNPU SLIK CLNOUT 15:00 - 15:15 0.25 FLOW_ BACK CLNOUT 15:15 - 15:45 0.50 FLOW_ BACK CLNOUT 15:45 - 15:50 0.08 FLOW BACK CLNOUT 15:50 - 16:00 0.17 RUNPU SLIK CLNOUT 16:105 - 17:15 10.00 RURDU I SLIK CLNOUT Page 2 of 4 Spud Date: 1/31/2002 Start: 3/10/2008 End: Rig Release: 2/22/2002 Group: Rig Number: 1 Description of Operations Hold PJSM and discuss Pollad JSA. Wait for permit. Obtain Safe work Permit. Cut 150' of wire. R&R stuffing box. R&R Hydraulic jars. PU lubricator. MU tool string w/ 2-1/2" DD bailer w/ mule shoe. Pressure test lubricator to 2000 psi. Test good. Ask operations to shut in well. RIH(1) w/ 2-1/2" DD bailer w/ chisel bottom and 15' of 1/3/4" stem. Tag @6432' KB. Work tools. Fall thru to 6444' KB. Module 10 flapper. Hung up on flapper. Wait for jars to trip. One lick and tools come free. POOH. to look at tools. OOH. Scrape marks on side of bailer. Recover 1 pint of sand and solids, and bailer full of fluid. PU 2.625" fluted swage, 2' of stem, 2.55" fluted centralizer. Test OTS. Test good. RIH(2) w/ same. Drop thru Module 10 flapper @ 6444' KB> stop and work this area. Continue RIH and tag up @ 6713' KB.(Between Modules 6&7) Work this area. Sticky. POOH to check tools. OOH. Vent lubricator. Metal scrape marks on swage. Drop off 2' of stem and 2.55" fluted centralizer. Test OTS. Test good. RIH(3) w/ 2.625" fluted swage on knuckle joint to 6714' KB. Set down. Worked tool. Pick up. Set down and work tools. Tools stuck. Jar on tools. Ask operations to flow well. Pull a bind on tools. Loosing weight. Tool pulls free. POOH. RD equipment. Close valves. Install tree cap. PTest tree cap. Test good Secure well and location. Turn in permit. Sign out and leave loc. Sign in and get Safe work Permit. Travel to location and spot equipment. Hold PJSM and discuss Pollad JSA. Discuss alarms and muster area. Discuss job scope. PU lubricator. MU tool string w/ 2.30" OD GR. Pressure test lubricator to 150 psi w/WHP. Test good. PTest lubricator to 2000 psi. Test good. RIH(1) w/ 2.30" OD GR. Well flowing. Tag TD @ 7197' KB. POOH. Well flowing at 600 to 700 psi. Suspect well plugoing (a~ choke. Operators working on choke. Wing valve closed to prevent getting blown up hole. PU 11'04" X 2-1/8" shot dummy gun Test OTS. Test good. RIH(2) w/ same. Drop to Module 10 flapper @ 6427" KB. Set down. Very sticky, Had to beat on tool for 15 minutes to get free. POOH. OOH. Ask operations to flow well. 2.6 Mscf @ 960 psi. Well flowing -WHP 860 psi. Well flowing -WHP 740 psi. RIH(3) w/ same. Run to 53' wlm. and set down. 1501bs overpull. POOH. OOH. RD equipment. Close valves. Install tree cap. PTest tree cap. Test good Printed: 3/27/2008 1:44:35 PM e • • Marathon Oil Company Page 3 of 4 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: K ell Name: K e: Name: From - To ENAI B ENAI B MAINTE GLACIE GLACIE Hours ELUGA ELUGA NANCE/ R DRILL R DRILL Code UNIT UNIT 4 REPAI ING ING ode 44-6 4-6 R Phase Spud Date: 1/31/2002 Start: 3/10/2008 End: Rig Release: 2/22/2002 Group: Rig Number: 1 Description of Operations 3/18/2008 17:15 - 17:30 0.25 SECUR WELL CLNOUT Secure well and location. Turn in permit. Sign out and leave loc. 3/19/2008 08:00 - 09:00 1.00 RURD_ SLIK PR2EVL Sign in and get Safe work Permit. 09:00 - 09:20 0.33 SAFETY MTG_ PR2EVL Hold PJSM and discuss Expro JSA. Discuss alarms and muster area. Discuss job scope. 09:20 - 10:25 1.08 RURD_ ELEC PR2EVL PU lubricator. 10:25 - 10:30 0.08 RURD_ ELEC PR2EVL PU 2- 7' x 1-11/16" weight bars, Hydraulic and Spang jars, 1-10' RTG Dummy gun. 10:30 - 10:46 0.27 TEST_ EQIP PR2EVL Pressure test lubricator to 150 psi w! WHP. Test good. PTest lubricator to 3000 psi. Test good. 10:46 - 11:25 0.65 RUNPU ELEC PR2EVL RIH(1) w/ 10' X 2-118" RTG Dummy gun. Well flowing 1.5 MMscf @ 553 psi. Run in to 7050'. Hung up in Module 10 for 15 min. 11:25 - 11:35 0.17 RUNPU ELEC PR2EVL PUH to Module 10. 11:35 - 13:20 1.75 RUNPU ELEC PR2EVL Begin swaging and working thru Module 10. 13:20 - 14:05 0.75 RUNPU ELEC PR2EVL POOH. Module 10 still sticky. __ 14:05 - 14:46 0.68 RURD_ ELEC PR2EVL PU GR/CCL 1-11/16" tools. PT OTS. Test good. 14:46 - 15:25 0.65 RUNPU ELEC PR2EVL RIH(2) Start correlation pass. 15:25 - 16:00 0.58 RUNPU ELEC PR2EVL End correlation pass 7210'-5770'. POOH. Determine casing damaged-possibly parted casing in Module 10 perfs. 16:00 - 16:45 0.75 RURD_ ELEC PR2EVL RD equipment for the night. 16:15 - 16:30 0.25 RURD_ ELEC PR2EVL Close swab valve. Install tree cap. PTest tree cap. Test good 16:30 - 17:00 0.50 SECUR WELL PR2EVL Secure well and location. Turn in permit. Sign out and leave loc. 3/20/2008 10:00 - 10:50 0.83 RURD_ ELEC PR2EVL Sand location prior to commencement of work. 10:50 - 11:10 0.33 SAFETY MTG_ PR2EVL Hold PJSM and discuss Expro JSA, Discuss alarms and muster area. Discuss job scope. Hold Explosives Safety meeting. Post signage and guard at gates. 11:10 - 11:40 0.50 RURD_ ELEC PR2EVL PU lubricator. 11:40 - 11:50 0.17 TEST_ EQIP PR2EVL PU 2- 7' x 1-11/16" Spiral 6 spf RTG. PTest OTS to 3000psi. Good test. Dummy gun. 11:50 - 12:30 0.67 RUNPU ELEC PR2EVL RIH(1) w/ 12' RTG. Well shut in w/ 1150 psi. 12:30 - 12:40 0.17 RURD_ ELEC PR2EVL Run correlation log. Set down @ 7052' wlm. 12:40 - 12:44 0.07 RUNPU ELEC PR2EVL Pull into position (6934' CCL depth. Bleed WHP down of 1000 psi. 12:44 - 12:50 0.10 PERF_ CSG_ PR2EVL Shoot 12' 1-11/16" 6 spf 60 degree phased gunst'c~ 6938'-6950' (OH). 10:44 1000 psi. 12:46 1040 psi. 12:48 1060 psi. 12:54 1080 psi 13:20 1140 psi 14:05 1160 psi 12:50 - 13:20 0.50 RUNPU ELEC PR2EVL POOH. 13:20 - 13:30 0.17 TEST_ EQIP PR2EVL PU 22' 1-11/16" 6 spf zero degree phased, decentralized guns. PTest OTS. 13:30 - 14:10 0.67 RUNPU ELEC PR2EVL RIH (2) w/ 22' RTG guns. 14:10 - 14:22 0.20 RUNPU ELEC PR2EVL Run correlation log. 14:22 - 14:55 0.55 PERF_ CSG_ PR2EVL Pull into position (CCL depth 6759') and shot 22' gun @ 6762- 6784' OH . 1160 psi on Well head.. POOH. 14:55 - 15:40 0.75 RURD_ ELEC PR2EVL OOH. RD equipment for the night. 14:40 - 16:30 1.83 RURD_ ELEC PR2EVL Close swab valve. Install tree cap. PTest tree cap. Test good 16:30 - 17:00 0.50 SECUR WELL PR2EVL Secure well and location. Turn in permit. Sign out and leave loc. 3/26/2008 08:00 - 08:30 0.50 SAFETY MTG_ PR2EVL Hold PJSM and discuss Expro JSA. Discuss alarms and muster area. Discuss job scope. 08:30 - 09:30 1.00 RURD_ ELEC PR2EVL Begin RU. MU lubricator and tool string. Well flowing 1.7 Mscf/d @ 422 psi. Shut well in to build pressure for underbalance. Printed: 3/27/2008 1:44:35 PM • ~ Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 44-6 Common Well Name: KENAI BELUGA UNIT 44-6 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date I From - To I Hours II Code Code ~ Phase 3/26/2008 9:30 - 09:40 ~0.17I SAFETY MTG_ PR2EVL 09:40 - 10:10 ~ 0.50 ~ TEST_ ~ EOIP ~ PR2EVL 10:10 - 10:50 0.67 RUNPU ELEC PR2EVL 10:50 - 11:00 0.17 RUNPU ELEC PR2EVL 11:00 - 11:07 0.12 RUNPU ELEC PR2EVL 11:07 - 11:40 0.55 PERF CSG PR2EVL 11:40 - 12:00 0.33 TEST_ EOIP PR2EVL 12:00 - 12:05 0.08 SAFETY MTG PR2EVL 12:05 -12:10 0.08 RURD_ ELEC PR2EVL 12:10 - 12:40 0.50 RUNPU ELEC PR2EVL 12:40 - 12:50 0.17 RUNPU ELEC PR2EVL 12:50 - 12:52 0.03 RUNPUL~ ELEC ~ PR2EVL 12:52 - 14:55 2.05 PERF_ I CSG_ PR2EVL 14:55 - 15:40 0.75 RUNPU ELEC PR2EVL 14:40 - 16:30 1.83 RURD_ ELEC PR2EVL 16:30 - 17:00 0.50 SECUR WELL PR2EVL Page 4 of 4 ~ Spud Date: 1/31!2002 Start: 3/10/2008 End: Rig Release: 2/22/2002 Group: Rig Number: 1 Description of Operations Hold Explosives Safety Meeting. post signage and guards at both entrances to pad. Shut down cell phones on location. Arm and PU 15'- x 1-11/16" 6 spf. 0 degree phased RTG. PTest lubricator to 3000psi. Good test. RIH (1) w/ 15' x 1-11/16" 6 spf zero degree phased RTG. Run correlation log. Set down in Module 5. Pull into position (6671' CCL depth). Flow well down to WHP 980 psi. Shoot 15' 1-11/16" 6 spf zero deg_ree phased guns ~ 6674'-6689' (OH). POOH. 11:07 1020 psi. Shoot guns 11:10 1030 psi. 11:18 1050 psi. 11:40 1100 psi PU 7' 2-1/8" 6 spf 60 degree phased guns. Hold Explosives Safety Meeting. post signage and guards at both entrances to pad. Shut down cell phones on location. Arm guns. Test OTS. RIH (2) w/ 7' 2-1/8" 6 spf 60 degree phased RTG guns. Run correlation log. Pull into position (CCL depth 6343.5'). Shoot 7' gun @ 6349- 6356' (OH). 1000 psi on Well head. POOH 12:52 1000 psi Shoot guns 13:02 1040 psi 13:05 1060 psi OOH. RD equipment for the night. Close swab valve. Install tree cap. PTest tree cap. Test good Secure well and location. Tum in permit. Sign out and leave loc. Printed: 3/27/2008 1:44:35 PM • • d SARAH PAL/N, GOVERNOR CO~TLv~~- ~j~O ~ ~~+ *0 333 W. 7th AVENUE, SUITE 100 •~~7 ii 1,+~••••••~~~uui~~'iiiiii-77 i ANCHORRGE, ALASKA 99501-3539 PHONE (907) 279-1433 Michael A. Mullin FAx (so7) z7sasaz Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, Alaska 99611-1949 Re: Kenai Gas Field, Upper Tyonek Beluga Gas Pool, Kenai Beluga Unit 44-6 Sundry Number: 308-068 ~~~ LIAR ~ 2008 ~~~ ~ ~ "~ 1 Dear Mr. Mullin: 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 ffie with the Commission an application for rehearing. A request for rehearing is considered timely ff 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, DATED this ~' day of March, 2008 Encl. • Marathon MARATHON Oil Company February 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field Well: Kenai Beluga Unit 44-6 ` Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEtVE® MAR 4 3.2008 Alaska Oil & Gas Cons, Commission Anchorage Marathon requests permission to enhance gas production from KBU 44-6 well by adding perforations to the Beluga formation. Plans are to add 10 intervals of perforations between the existing Excape module perforations. The additional perforation intervals will extend from a depth of 6,172' MD to 7,090'MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ' _, ° ~~ ~~%V U'~ Kevin J. Skiba Production Technician Enclosures: 10-403 Sundry Notice Work Scope Procedure Current Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS MAM ORIGINAL i ~~ p ~ ,~~ ~ STATE OF ALASKA MAC ~ 3 O ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAI.a I~ 8 Gas C SSi01'1 20 AAC 25.280 Anni~n 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 200-179 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20498-00-00 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: _ ^ Spacing Exception Required? Yes ^ No ~ Kenai Beluga Unit 44-6 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A - 028142 ' 87' (66' AGL) Kenai Gas Field /Beluga Pool 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): 7,440' ~ 7,308'- 7,323' - 7,191' , NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 93' 20" 114' 114' 3,060 psi 1,500 psi Surface 1,4gg' 13-3/8" 1,509' 1,507' 5,020 psi 2,260 psi Intermediate 5,416' 9-5/8" 5,437' 5,308' 5,750 psi 3,090 psi Production 7,372' 3-1/2" 7,393' 7,261' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,910' - 7,252' gross 5,778' - 7,120' gross NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Michael A. Mullin Titfe Senior Production Engineer Signature Phone (907) 283-1337 Date February 29, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `~.I~ ~ ©~g Plug Integrity ^ BOP Test [!~ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~ Q - `` 'APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: ~ ~-O~ Form 10-403 Revised 06/2006 ~~''1'` ~ Ll~ ~~~ `~ ~~ ~~ Submit in Duplicate .' ~~ • • Well KBU 44-6 Clean out and add Perfs WO. Page 1 Well KBU 44-6 CTU Clean out Produce well Add Proposed Beluga perforations Kenai Gas Field, Pad 41-7 WBS # Objective - We plan to clean out well using CTU to a minimum depth of 7217. RU Expro Wire Line Service and add the ten Beluga intervals listed below. Flow well to production. Background -Well KBU 44-6 is currently completed in the Beluga Sands. The Well is currently producing 1.2 Mcf @ 400 psi. Tagged fill at 6431' KB (12/28/2007). Procedure BJ CoilTech Services 1.) Hold PJSM and fill out safe work permit. 1. Move in rig up BJ CTU, N2, working and flow-back tanks, and Sand Buster w/ bypass to gas buster. 2. Test BOP's. *** Notify the AOGCC James Regg (t~ 907-276-7542 (24 or longed Arior to testing the BOP's 3. Clean out with 1-3/4" Coil tubing to a minimum depth of 7217' KB. 4. Jet well in with N2. Flow to sales. 5. RD coil unit. Expro Americas 2.) Hold PJSM and fill out safe work permit. 1. MIRU Expro. Add the following Beluga perforations using 2.125" Owen ShoGun NTX Charges, 60 degree phasing, spiral wound: a. 7080-7090 10' b. 6938-6950' 12' M. Sulley- 2-28-2008 • • Well KBU 44-6 Clean out and add Perfs WO. Page 2 c. 6903-6918' 15' d. 6844-6858' 14' e. 6726-6784' 38' 2. Flow test and evaluate the above group of perforations over night before shooting the remaining intervals. Note: Flow test and evaluate intervals nightly. 3. a. 6674-6689' 15' b. 6646-6657' 11' c. 6362-6398' 36' d. 6349-6356' 7' e. 6172-6198' 26' 3.) Continue to flow well to sales. Evaluate. M. Suiley- 2-28-2008 • • API #: 50-133-20498-00-00 KB Elevation: 87' (21' AGL) Property Des: A-028142 Spud Date: 1/31/2002 TD Date: 2/17/2002 Rig Released: 2!22/2002 @ 21:00 hrs Tree cxn = 4-3/4" Otis KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11W, S.M. t KOP: @ 1,500' MD Build: 1.5 deg/100' Hold Anale: 18 deg @ 2,715' MD DfOp: 4,200' Final Angle: 0 deg @ 5,415' 'Excape System Details - 16 Excape modules run - Module 1 fired using RFID tag (3/5/02) - Both control lines open for methanol injection (7/9/02) - Ceramic flappers removed with coil (7/9/02) Perfs: Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 719/02) Module 11 6291' - 6301' (frac'd 7/9/02) Module 10 6424' - 6434' (frac'd 7/9/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8!02) Module 6 6722' - 6732' (frac'd 7/8/02) Module 5 6874' - 6884' (frac'd 7/8/02) Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 718/02) Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Slickline tagged fill @ 7217' MD (6/6/03) PBTD TD 7,323' MD 7,440' MD 7,191' TVD 7,308' TVD Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910' - 7,252' Perf (TVD): 5,778' - 7,120' Angle @ KOP and Depth: 1.5° / 100tt @ 1,800' Angle/Perfs: Dated Completed: February 22, 2002 Prepared By: Kevin Skiba Last Revison Date: January 24, 2008 M Mat~nroN Surface Casing 13-3I8" L-80 88 ppf BTC Top Bottom MD 0' 1,509' TVD 0' 1,507' 17-112" hole, Cmt wl 650 sks (186 bbls) 12 ppg, Type 1 with ±40 bbls cmt to surface. Intermediate Casing 9-518" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-114" hole, Cmt wl 93 sks (42 bbls) Class G 12 ppg Lead, followed w/515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. Production Casing 3-1/2" L-80 9.3 ppf EUE 8rd w/5.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,440 TVD 0' 7,308' 8-1/2" hole, Cmt w/ 930 sks (50 bbls) Class G 10.5 ppg @ 5344' MD (5217' TVD) w/ 7/16" electric cable (dual- armored, 7-strand conductor) to surface. One 10K pressure sensors one temperature sensor a': 200-179 50-133-20498-00-00 ~ation: 8T (21' AGL) y Des: A-028142 ate: 1 /31 /2002 2/17/2002 eased: 2/22/2002 @ 21:00 hrs Tree cxn = 4-3/4" Otis Proposed KBU 44-6 Pad 41-7 42' FNL, 4,283' FWL Sec. 7, T4N, R11 W, S.M. l ~i KOP: @ 1,500' MD Build: 1.5 degl100' Hold Angle: 18 deg @ 2,715' MD ~ , Drop: 4,200' Final Angle: 0 deg @ 5,415' ~~ a~ ~~ ,, ., y.. Excaoe S vstem Details - 16 Excape modules run - Module 1 fired using RFID tag (3/5/02) -Both control lines open for methanol injection (7/9/02) -Ceramic flappers removed with coil (7/9/02) Perfs: (PROPOSED) Module 16 5910' - 5920' (frac'd 7/9/02) Module 15 5948' - 5958' (frac'd 7/9/02) Module 14 6027' - 6037' (frac'd 7/9/02) Module 13 6111' - 6121' (frac'd 7/9/02) Module 12 6151' - 6161' (frac'd 7/9/02) 6172-6198 Module 11 6291' - 6301' (frac'd 7!9/02) 6349-6356 6362-6398 Module 10 6424' - 6434' (frac'd 719/02) Module 9 6492' - 6502' (frac'd 7/9/02) Module 8 6563' - 6573' (frac'd 7/8/02) Module 7 6630' - 6640' (frac'd 7/8/02) 6646-6657 6674-6689 Module 6 6722' - 6732' (frac'd 7/8/02) ,. 6726-6784 6844 &858 - Module 5 6874' - 6884' (frac'd 7/8102) 6903-6918 6938-6950 Module 4 6982' - 6992' (frac'd 7/8/02) Module 3 7050' - 7060' (frac'd 718/02) 7080-7090 Module 2 7198' - 7208' (frac'd 7/8/02) Module 1 7242' - 7252' (frac'd 7/8/02) t r~ f~J M MARATHON Conductor 20" K-55 133 ppf Top Bottom MD 0' 114' TVD 0' 114' Surface Casing 13-318" L-80 68 ppf BTC Top Bottom MD 0' 1,509' TvD o' 1 so7• 17-1/2" hole, Cmt w/ 650 sks (186 bbls) 12 ppg, Type 1 with t40 bbls cmt to surface. Intermediate Casino 9-518" L-80 40 ppf Butt Top Bottom MD 0' 5,437' TVD 0' 5,309' 12-1/4" hole, Cmt w193 sks (42 bbls) Class G 12 ppg Lead, followed wI515 sks (168 bbls) Class G 13.5 ppg Tail. No returns to surface. 3-112" L-80 9.3 ppf EUE 8rd w15.25" OD slotted couplings to 7,388' Top Bottom MD 0' 7,440 TVD 0' 7,308' 8-1/2" hole, Cmt wl 930 sks (50 bbls) Class G 10.5 ppg Promore downhole sensor @ 5344' MD (5217' TVD) w/ 7/16" electric cable (dual- armored, 7-strand conductor) to surface. One 10K pressure sensors one temperature sensor Slickline tagged fill @ 6431' MD (12/28/07) Slickline tagged fill @ 7217' MD (6/6/03) PBTD 7,323' MD 7,191' TVD Well Name & Number: Kenai Beluga Unit 44-6 Lease: Kenai Gas Field Municipality: Kenai Penisula Borough State/Prov: Alaska Country: USA Perforations (MD): 5,910' - 7,252' Perf (TVD): 5,778' - 7,120' Angle @ KOP and Depth: 1.5° / 100ft @ 1,800' Angle/Perfs: Dated Completed: February 22, 2002 Prepared By: Mike Sulley Last Revison Date: February 28, 2008 - ~ :, , ~r ~~E w `. ,, ~ y: ~ -: r %' '~ .Q~. s~. :i ., i• f~~ ~ -~ 5~ PROPOSED Additional Perforations 7080-7090 8938-6950 8903-6918 8844-6858 8726-8784 6674-6689 6646-6657 6362-6398 6349-6356 6172-6198 TD 7,440' MD 7,308' TVD • Marathon Oil Company Alaska Asset Team Marathon P.O. Box 1949 M MARATHON OBI Company Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 January 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave ~` ~ FHB ~ ~ 200 Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Well: Sundry #: Kenai Gas Field Kenai Beluga Unit 44-6 304-022 Dear Mr. Maunder: aoo_-_.x_7.9 The AOGCC approved Marathon's requested to add perforations to KBU 44-6 on January 30, 2004. Marathon still intends to add perforations to KBU 44-6 but the work scope has been updated. Considering the length of time since Sundry #304-022 was approved and the slight change to the work scope, Marathon elects to close out Sundry #304-022 as a non-work sundry. Anew Application for Sundry Approvals 10-403 will be submitted which covers the present work scope. If you have any questions or need additional information please call me at (907) 283- 1371. Sincerely, D,~ n~~- Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS RECEIVE JAN 3 1 200 dlasha ail & Gas ~QOS, ~r,o~,, :IOfI 1.Operations Abandon Repair Well Plug Perforations Stimulate Other ~ ~~Work Pertormed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ ~n Waiver^ Time Exten3~'91'~ S~~ 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 0 Exploratory^ 200-179 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20498-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' (66' AGL Kenai Belu a Unit 44-6 - 8. Property Designation: 10. Field/Pool(s): FED A - 028142 ~ Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7,440' feet Plugs (measured) NA true vertical 7,3p8' feet Junk (measured) NA Effective Depth measured 7,323' feet true vertical 7,191' ~ feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 93' 20" 114' 114' 3,060 psi 1,500 psi Surface 1,488' 13-3/8" 1,509' 1,507' 5,020 psi 2,260 psi Intermediate 5,416' 9-5/8" 5,437' 5,308' 5,750 psi 3,090 psi Production 7,372' 3-1/2" 7,393' 7,261' 10,160 psi 10,530 psi Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 5,910' - 7,252' gross True Vertical depth: 5,778' - 7,120' gross Tubing: (size, grade, and measured depth) NA NA NA 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations 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: 304-022 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Production Technician Signature ,~,L~ ~ ~ Phone (907) 283-1371 Date January 29, 2008 V Form 10-404 Revised 04/2006 i~a~`~ Submit Original Only flAY/ Casing & Cement • Marathon oil Well Name: KENAI BELUGA UNIT 44 -6 *�� D ZOO- R°i 1 `� . For String: Surface Casing Detail: Casing Description Prop Run? Run Date Set Depth (mKB) Set Tension (tonnef) Wellbore Centralizers Scratchers Surface No 2/2/2002 00:00 459.99 0.0 KENAI BELUGA UNIT 44 -6 Comment Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 36 Casing Casing 339.7 315.3 101.195 L -80 BTC 440.55 5.90 446.46 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment Stab in Float Collar Casing 339.7 315.3 BTC 0.56 446.46 447.01 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Shoe Joint Casing 339.7 315.3 101.195 L -80 BTC 12.46 447.01 459.47 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment Float Shoe Casing 339.7 315.3 BTC 0.52 459.47 459.99 shoe Cementing Job Details: Cementing Start Date Cementing End Date 2/3/2002 00:00 ' Ceme nting Company Comment Coil tubing unit indicator: N Wait on cement (hrs): 6.5 Descnption Type String Wellbore SURFACE CASING ' Cas i ng I Surface, 459.99mKB KENAI BELUGA UNIT 44 -6 Ce Stage #1,. Description: . . . Float Failed? ? Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (kPa) No 'Plug Failed Yes No No ' No Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Retum (m') 1 0.00 459.94 Top Plug? Yes !Bottom Plug? No 'Initial Pump Rate (m' /min) 'Final Pump Rate (m' /min) (Pump Start Time 'Pump End Time Avg Pump Rate (m' /min) !Drill Out Dia (mm) !Final Pump Pressure (kPa) !Plug Bump Pressure (kPa) Pressure Release Date 0.0 6,205.3 Comment Annular flow after cement job (Y /N): N Cement Flbids: `. LEAD Class !Density (kg /m') !Yield (m'/tonne) !Volume Pumped (m') 1,437.9 1.5611 46.11 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 6.5 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Fluid Type ! Amount (1000kg) Mix H2O Ratio (m'/tonne) Percent Excess Pumped (%) LEAD 29.5 0.911 50.0 Cement Fluid Additives :Add Amount - `- - .:Aidunt Units • - COnc{lnit ' , Cone Type r - - Calcium Chloride 1.5 % BWOC CD -32 0.3 % BWOC FP -6L 0.01 gal /sack Fresh Water 96.2 % LW -6 20.0 % BWOC MPA -1 20.0 % BWOC Sodium Metasilicate 1.0 % BWOC Wellheads .... . . Install Date (Type (Job !Removed Date !Comment JUN 1 3 4.)1z www.peloton.com Page 1/1 Report Printed: 8/3/2011 ftAW • Casing & Cement • . Marathon Oil i Well Name: KENAI BELUGA UNIT 44 -6 For String: Intermediate Casing Detail: - Casing Description Prop Run? Run Date Set Depth (mKB) Set Tension (tonnef) Welibore Centralizers Scratchers Intermediate No 2/12/2002 00:00 1,657.16 0.0 KENAI BELUGA UNIT 44 -6 Comment Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 9 5/8" Hanger Neck Casing 244.5 224.4 BTC 0.32 6.36 6.68 hanger Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 13 1/2" Mandrel Casing 342.9 224.4 BTC 0.15 6.68 6.83 Hanger (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 9 5/8" Hanger Pup Casing 244.5 224.4 BTC 0.83 6.83 7.66 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 13 CASING JOINT(S) Casing 244.5 224.4 59.527 L -80 BTC 1,622.96 7.66 1,630.62 0 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 244.5 224.4 BTC 0.46 1,630.62 1,631.07 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 CASING JOINT(S) Casing 244.5 224.4 59.527 L -80 BTC 25.57 1,631.07 1,656.64 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 CASING FLOAT Casing 244.5 224.4 BTC 0.52 1,656.64 1,657.16 ThreadLock Y /N: Y SHOE shoe Cementing Job Details: . Cementing Start Date Cementing End Date Cementing Company 2/13/2002 00:00 ' B.J. SERVICES Comment No retums during job. Coil tubing unit indicator: N Tool company: FLOAT SHOE AND FLOAT COLLAR Description Type String Welibore INTERMEDIATE CASING Description ' Type 'String 1,657.16mKB KENAI BELUGA UNIT 44 -6 CementStage#1. Description: - . Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (kPa) No ' No No No ' No Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Retum (m') 1 0.00 1,066.80 Top Plug? Bottom Plug? Initial Pump Rate (m' /min) Final Pump Rate (m' /min) Pump Start Time Pump End Time Yes ' Yes ' 0.795 ' Avg Pump Rate (m' /min) 'Drill Out Dia (mm) !Final Pump Pressure (kPa) (Plug Bump Pressure (kPa) 'Pressure Release Date 0.604 4,826.3 8,273.7 Comment I Annular flow after cement job (Y /N): N Hours circulated between stages: 2 Pressure before cementing: 250 Returns: NONE Time cementing mixing started: 23:50 Cement Fluids :. LEAD Class ' Density (kg /m') Yield (m'ttonne) Volume Pumped (m') CLASS G 1,437.9 1.5861 6.68 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 0 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 23.5 Fluid Type ' Amount (1000kg) Percent Excess Pumped ( %) LEAD 4.2 Mix H2O Ratio (m "'tonne) 0.921 50.0 Cement Fluid Additives ' - Add Amount - Amount Units - Conc Unit - ,.. Conc - Type. • _ - , ASA -301 1.0 % BWOC CD -32 0.4 % BWOC FP -6L 1.0 G /100SX KOL -SEAL 5.0 Ibs /sack www.peloton.com Page 1/2 Report Printed: 8/3/2011 i! s /J • Casing & Cement • Marathon oil Well Name: KENAI BELUGA UNIT 44 -6 For String: Intermediate Cement Fluid Additives Add Amount Amount Units Conc Unit Cone Type LW -6 18.0 % BWOC MPA -1 20.0 % BWOC R -3 0.2 % BWOC TAIL Class Density (kg /m') Yield (m'/tonne) Volume Pumped (m') CLASS G 1,617.7 1.149 26.71 Comment Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 114 Fluid Type Amount (1000kg) Mix H2O Ratio (m'/tonne) Percent Excess Pumped ( %) TAIL 23.4 0.89 50.0 Cement Fluid Additives Add Amount Amount Units Conc Unit Conc Type ASA -301 0.1 % BWOC BA -90 10.0 % BWOC BA -96 2.5 % BWOC FP -6L 1.0 GAL /100SX CALC2 2.0 % BWOC ACCELERATOR Wellheads . - Install Date 'Type 'Job 'Removed Date Comment I www.peloton.com Page 2/2 Report Printed: 8/3/2011 • f/f fl) • Casing • & Cement • MarathCln011 W eII Name: KENAI BELUGA UNIT 44 -6 �'�-D 20,3 �� -1 For String: Production ,Casing Detail: Casing Description Prop Run? Run Date Set Depth (mKB) Set Tension (tonnef) Wellbore Centralizers Scratchers Production No 2/21/2002 00:00 2,252.00 0.0 KENAI BELUGA UNIT 44 -6 Comment Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing (cut -off joint) Casing 88.9 76.0 13.840 L -80 EUE 9.61 -0.50 9.11 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 17 Casing Casing 88.9 76.0 13.840 L -80 EUE 1,617.38 9.11 1,626.50 rigid centr jnts 43,45 1 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 2.47 1,626.50 1,628.96 rigid centr (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Promore pressure Casing 88.9 76.0 13.840 L -80 EUE 3.18 1,628.96 1,632.14 sensor (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing pups Casing 88.9 76.0 13.840 L -80 EUE 1.84 1,632.14 1,633.98 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 17 Casing Casing 88.9 76.0 13.840 L -80 EUE 161.54 1,633.98 1,795.53 rigid centr even jts & 41 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #16 Excape 88.9 76.0 13.840 L -80 EUE 10.86 1,795.53 1,806.38 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 0.62 1,806.38 1,807.01 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #15 Excape 88.9 76.0 13.840 L -80 EUE 10.91 1,807.01 1,817.92 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 3.06 1,817.92 1,820.98 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 76.0 13.840 L -80 EUE 9.61 1,820.98 1,830.59 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #14 Excape 88.9 76.0 13.840 L -80 EUE 11.58 1,830.59 1,842.17 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing pups Casing 88.9 76.0 13.840 L -80 EUE 4.32 1,842.17 1,846.48 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 76.0 13.840 L -80 EUE 9.61 1,846.48 1,856.10 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #13 Excape 88.9 76.0 13.840 L -80 EUE 11.58 1,856.10 1,867.68 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 0.63 1,867.68 1,868.31 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #12 Excape 88.9 76.0 13.840 L -80 EUE 11.58 1,868.31 1,879.90 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 3.07 1,879.90 1,882.97 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing Casing 88.9 76.0 13.840 L -80 EUE 28.75 1,882.97 1,911.71 rigid centr.jnt #22 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #11 Excape 88.9 76.0 13.840 L -80 EUE 10.97 1,911.71 1,922.69 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing Casing 88.9 76.0 13.840 L -80 EUE 28.82 1,922.69 1,951.51 rigid centr. jnt #19 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #10 Excape 88.9 76.0 13.840 L -80 EUE 11.53 1,951.51 1,963.04 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 76.0 13.840 L -80 EUE 9.61 1,963.04 1,972.65 (black) www.peloton.com Page 1/3 Report Printed: 8/3/2011 . . j,��6 /j • Casing & Cement Marathon Oil Well Name: KENAI BELUGA UNIT 44 -6 For String: Production Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #9 Excape 88.9 76.0 13.840 L -80 EUE 11.68 1,972.65 1,984.33 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 76.0 13.840 L -80 EUE 0.62 1,984.33 1,984.95 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 76.0 13.840 L -80 EUE 9.60 1,984.95 1,994.56 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #8 Excape 88.9 76.0 13.840 L -80 EUE 10.92 1,994.56 2,005.47 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 76.0 13.840 L -80 EUE 9.61 2,005.47 2,015.08 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #7 Excape 88.9 76.0 13.840 L -80 EUE 10.94 2,015.08 2,026.02 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing pups Casing 88.9 58.2 13.840 L -80 EUE 6.81 2,026.02 2,032.84 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 58.2 13.840 L -80 EUE 9.58 2,032.84 2,042.42 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #6 Excape 88.9 58.2 13.840 L -80 EUE 11.71 2,042.42 2,054.13 eccentric centr top & btm Module Jts Item Description Icon 00 (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing pups Casing 88.9 58.2 13.840 L -80 EUE 6.70 2,054.13 2,060.83 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing Casing 88.9 58.2 13.840 L -80 EUE 28.80 2,060.83 2,089.63 rigid centr. jnt #12 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #5 Excape 88.9 58.2 13.840 L -80 EUE 11.03 2,089.63 2,100.65 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg/m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 58.2 13.840 L -80 EUE 3.07 2,100.65 2,103.73 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing Casing 88.9 58.2 13.840 L -80 EUE 19.14 2,103.73 2,122.86 rigid centr. jnt #9 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #4 Excape 88.9 58.2 13.840 L -80 EUE 10.97 2,122.86 2,133.83 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing Casing 88.9 58.2 13.840 L -80 EUE 9.56 2,133.83 2,143.39 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #3 Excape 88.9 58.2 13.840 L -80 EUE 10.97 2,143.39 2,154.36 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing pups Casing 88.9 58.2 13.840 L -80 EUE 5.58 2,154.36 2,159.94 (black) Jts Item Descnption Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 3 Casing Casing 88.9 58.2 13.840 L -80 EUE 28.77 2,159.94 2,188.71 rigid centr. jnt #6 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #2 Excape 88.9 58.2 13.840 L -80 EUE 10.61 2,188.71 2,199.32 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Casing pup Casing 88.9 58.2 13.840 L -80 EUE 1.85 2,199.32 2,201.17 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Excape module #1 Excape 88.9 58.2 13.840 L -80 EUE 11.72 2,201.17 2,212.89 eccentric centr top & btm Module Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing Casing 88.9 58.2 13.840 L -80 EUE 19.21 2,212.89 2,232.11 rigid centr. jnt #4 (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Float collar Casing 88.9 58.2 13.840 L -80 EUE 0.30 2,232.11 2,232.41 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 2 Casing Casing 88.9 58.2 13.840 L -80 EUE 19.29 2,232.41 2,251.70 rigid centr. jnt #2 (black) www.peloton.com Page 2/3 Report Printed: 8/3/2011` / IP • Casing & Cement • Marathon oil Well Name: KENAI BELUGA UNIT 44 -6 For String: Production Casing Components Jts Item Description Icon OD (mm) ID (mm) Wt (kg /m) Grade Top Thread Length (m) Top (mKB) Btm (mKB) Comment 1 Float shoe Casing 88.9 58.2 13.840 L -80 EUE 0.30 2,251.70 2,252.00 ThreadLock Y /N: Y shoe Cementing Job Details: Cementing Start Date Cementing End Date Cementing Company 2/22/2002 00:00 B.J. SERVICES Comment Coil tubing unit indicator: N Tool company: Gemoco Wait on cement (hrs): 12 Description Type String Wellbore PRODUCTION CASING #1 Casing Production, 2,252.00mKB KENAI BELUGA UNIT 44 -6 Cement Stage #1 Description: Float Failed? Plug Failed? Full Return? Pipe Reciprocated? d? Pressure Held (kPa) No No No Yes 'Pipe Rotated? Stage Number Top Depth (mKB) Bottom Depth (mKB) Cement Volume Return (m') 1 0.00 1,809.60 Top Plug? Bottom Plug? Initial Pump Rate (m' /min) Final Pump Rate (m'/min) Pump Start Time Pump End Time No Yes 0.477 Avg Pump Rate (m' /min) 'Drill Out Dia (mm) 'Final Pump Pressure (kPa) (Plug Bump Pressure (kPa) !Pressure Release Date 0.437 8,273.7 11,721.1 Comment PIPE MOVEMENT NOTES: Drag down 67000 Drag up 90000 Pipe movement: RECIPROCATING Time stopped reciprocating: 09:00 Time started reciprocating: 10:30 Time stopped rotating: 00:00 Time started rotating: 00:00 Annular flow after cement job (Y /N): N Hours circulated between stages: 3 Pressure before cementing: 400 Excess volume measured from: 5437' - 7393 Pressure left on after job: 1700 Returns: yes Time cementing mixing started: 17:00 .Cementfluids • LEAD Class Density (kg /m') Yield (mMonne) Volume Pumped (m') CLASS G 1,881.3 0.737 39.75 Comment Displacement fluid used: OTHER Time displacement started: : Wait on Cement Time: 12 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 110 Fluid Type Amount (1000kg) Mix H2O Ratio (m'/tonne) Percent Excess Pumped ( %) LEAD 42.0 0.42 35.0 Cement Fluid Additives Add.. _ Amouni Amount Units Cohc Unit Conc Type Wellheads Install Date 'Type 'Job 'Removed Date !Comment www.peloton.com Page 3/3 Report Printed: 8/3/2011 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~n.:~,~,.. /.: ~:.."\ ,;;,.~~ "- ~\'" .1\ Permit to Drill 2001790 ý-- FJ.yJ ;tû {J '-( DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 ~-)IJ~~~ API No. 50-133-20498-00-00 Well Name/No. KENAI BELUGA UNIT 44-06 Operator MARATHON OIL CO MD 7440 ~ TVD 7308 -------- -- REQUIRED INFORMATION ---~- -----~--~ DATA INFORMATION Types Electric or Other Logs Run: 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 / N Analysis Received? ~ t..- c:: .. ~ ~ r---J c:::> c:::> ..þ ".----------- -"- - ----- --------------- Comments: ----------- Compliance Reviewed By: Completion Date 3/5/2002 Mud Log No ~ Interval Start Stop 5350 7440 Completion Status 1-GAS Current Status 1-GAS UIC N L'~ ( ) ~~\.- }1 E ;<. IN (if ö..r/ C~ ý( (~, IlJ 0 . y> L- N 1:1 ~~ - Vv \J ~. r l~:'f--(~:~~~G ~~-A. D/ I' ~ uV' {i "1 l-N,J&l----- Samples No Directional Survey We- \{ J../l , }fi0Jtl^' (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments Sent Sample Set Number Comments Received 1107 Daily History Received? '- QxN ®N Formation Tops #1 Jv .f-r:J ð - Date: s- /J;t ~ L! ') ') . . , Alaska Business Unat Domestic Production " , M MARATHON f Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 27,2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 44-6 Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KBU 44-6. The proposed work is to target additional pay by adding perforations to the wellbore-:- The perfs to be added are included in the enclosed procedure. This work for perforating Phase 1 is expected to begin Tuesday, February 3. The Phase 2 perfs will be added some time later. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus @marathonoil.com. Sincerely, ~rJr Denise M. Titus Production Engineer Enclosu res RECEIVED JAN 2 8 2004 A1aska Oil & Gas Cons. Commission Anchorage ".' ... .... ".-... . ....-. -- --- .. ORIGINAL SCANNED JUL 2 1 2004 ') STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMlvilSSION APPLICATION FOR SUNDRY APPROVALS AOGCC 44-6 Add Pefs 10-403.XLS W6A- 'I¡Sf 2.00 't /) ~ yz 0/' </- 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Repair Well Pull Tubing 5. Type of Well: Developmen~ Exploratory _ Stratigraphic _ Service Operation Shutdown Plugging Variance 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 42'FNL, 4283'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. At Effective Depth Add perforations / At Total Depth 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 7440 7308 feet Plugs (measured) feet Effective Depth: measured true vertical feet feet 7323 7191 Junk (measured) Casing Structu ral Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth 114' 1,509' 5,437' 7,323' 20" 13-3/8" 9-5/8" 3-1 /2" Driven 650 sx 608 sx 930 sx measured Beluga Sand: 5910'-20',5948'-58',6027'-37',6111'-21', 6151'-61', 6291'-301', 6424'-34', 6492'-502',6563'-73',6630'-40',6722'-32', 6874'-84', 6982'-92',7050'-60',7198'-208',7242'-52' Re-enter Suspended Well_ Time Extensior Stimulate Perforate X Other 6. Datum Elevation (DF or KB) '87' KB above MSL 7. Unit or Property Name Kenai Beluga Unit 8. Well Number ./ KBU 44-6 9. Permit Number 200-179 / feet 10. API Number / 50-- 133-20498-00 11. Field/Pool Kenai Gas Field/Beluga N/A N/A True Vertical Depth 114' 1,509' 5,437' 7,323' 114' 1,507' 5,308' 7,191 ' true vertical Beluga Sand: 5778'-88',5816'-26',5895'-905',5979'-89', 6019'-29', 6159'-69', 6292'-302', 6360' -70', 6431'-41', 6498'-508', 6590'-600', 6742'-52', 6850'-60', 6698'-28', 7066'-76', 7110'-20' Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments Description Summary of Proposa~ 15. Status of Well Classification as: Detailed Operations Program_ BOP Sketch 14. Estimated Date for Commencing Operation 2/3/2004 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l~;1W1-- Suspended .____ _ __^,~._.::.at:.'Þ:? /01 Denise M. Titus Title Production Engineer OR COMMISSION USE ONLY . e may witness Location Clearance equent Form Required 10-- if (} '-I __6ft.. FE8 0" 200~~ ~' R· \ G \ " I A L II"\CA~tDiomL 2 JD~Of . '!~ . ð:f .. ~ \\ ~ ub It In Tr IIcate. . ~ , '" Conditions of Approval: Notify Commis . Plug Integrity_ Mechanicallntegri Approved by Order of the Commissi n Form 10-403 Rev. 06/15/88 Approval No. * J ¿; 7'- ¿:; ¿;- ¿;- ~M. ) ) Marathon Oil Company Alaska Region KBU 44-6 Kenai Gas Field, Pad 14-6 Add Perforations Procedure WBS # WO.03.09901.EXP History: KBU 44-6 is a cemented 3-1/2" Beluga Excape completion. Additional pay has been identified in the wellbore. Objective: Perforate additional pay. / Procedure: 1. Ensure location and tree are prepped for wireline including liner installation and house removal if necessary. 2. MIRU wireline unit. 3. Perforate the following zones with 2-3/8" 4SPF, retrievable guns: Phase 1: L14 7080' -7090' (10') L12 6938'-6950' (12') LI0 6844' -6858' (14') LI0 6762'-6784' (22') L 9 6646' -6657' (11') L4 6362'-6398' (36') L 3 6349' -6356' (7') M 4 6172'-6198' (26') M 13 6068'-6094' (22'** leave 6076'-80' blank) / Phase 2: M5 5825' -5856' (31' ) / M5 5785' -5800' (15') M5 5763'-5770' (7') M4 5670' -5700' (30' ) M4 5622' -5660' (38') M3 5596'-5612' (16') Ml 5511' -5550' (17') 4. Clean up location. RDMO eline, and return well to system per instruction of production engineer. Flow back to open top tank if necessary. SCANNED JUL 2 1 200~ '\ MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU5 195-054 KTU 43-06XRD 1 77-029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-1 79 KBU 44-06 SCANNED JUl 2 1 2GG4 ,) Alaska I. ~ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 20, 2002 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 VIA COURIER RE: Marathon KBU #44-6 - CONFIDENTIAL Accompanying this letter are five (5) boxes of CONFIDENTIAL well samples for the above referenced well, as described below Box # Depth To Depth 1 5350 5800 2 5800 6250 3 6250 6650 4 6650 7060 5 7060 7440 Please review the enclosed data, sign and return one copy of this transmittal. Thank you, J<í;<. t) {'() ~I t(Ji~flIJ1LV:'~~7f~ Kaynell Zeman (J ' Technical Assistant Attached (4 boxes) Received by: 1LJ D jJj Date: Äf) ~~ ftD d ó~- (74 S ""'fiL ~ # ) ( t) ~-.. ........-.. .~..'......... _. Environmentally aware for the long run. ~ÞCANNED JUL 2 1 2004 \j/~U f:~/.L ) STATE OF ALASKA ) ALA0r\.Ä OIL AND GAS CONSERVATION COMIVII~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well olLD GASŒ] SUSPENDEDD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface t··c...'--.......-;:-;-1 42' FNL, 4283' FWL, Sec. 7, T4N, R11W, S.M. f COMPLETION ~ ¡ DATE ~ At top of Producing Interval ~ -4' 5:' q ~ i 873' FSL, 4643' FWL, Sec. 6, T4N, R11W, S.M). VEI)A1I. ED I' At Total Depth ~. '/' ~~ .. ... 878' FSL, 4643' FWL, Sec. 6, T4N, R11W, S.M. L.. .. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 21.00' DF-GL A-028142 ABANDONEDD SERVICED Classification of Service Well 12. Date Spudded 1/31/2002 17. Total Depth (MD+ TVD) 7440' MD, 7308' TVD 13. Date TD. Reached 2/18/2002 18. Plug Back Depth (MD+TVD) 7323' MD, 7191' TVD 14. Date C~P:.L Susp. or Aban.d. 15. Water Depth, if offshore .dL S 2.4'Oc,? ''''&u:~ '" ,g D N/A feet MSL one 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost Yes~No D N/A feet MD N/A 22. Type Electric or Other Logs Run PEXlNGT - CMR 23 7. Permit Number 200-179 8. API Number 50-133-20498-00 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KBU 44-6 11. Field and Pool Kenai Beluga Pool Kenai Gas Field 16. No. of Completions CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. GRADE 20" 133 K-55 0 114 13-3/8" 68 L-80 0 1509 9-518" 40 L-80 0 5437 3-1/2" 9.3 L-80 0 7388 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 6 spf, 2.5" Excape guns MD: 5910'-20', 5948'-58', 6027'-37', 6111'-21', 6151'-61', 6291'-6301',6424'-34',6492'-6502', 6563'-73', 6630'-40', 6722'-32',6874'-84',6982'-92',7050'-60',7198'-7208', 7242'-52' TVD: 5778'-88', 5816'-26', 5895'-5905', 5979'-89', 6019'-29', 6159'-69',6292'-6302',6360'-70', 6431'-41', 6498'-6508', 6590'-6600',6742'-52',6850'-60',6918'-28',7066'-76', 7110'·20' 27. Date First Production 19-Jul-02 Date of Test 7/22/2002 Flow Tubing Pres. 1500 Driven 17 -112" 12-1/4" 8-1/2" 25. SIZE N/A Driven N/A 650 sks (to surface) N/A 608 sks N/A 930 sks N/A TUBING RECORD DEPTH SET (MD) PACKER SET (MD) N~ N~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All perfd intervals 1,002,800 Ibs of 20/40 Econoprop 5910' - 7252' PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) flowing PRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD --. 0 5300 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE--. 0 5300 Hours Tested 24 Casing Pressure o WATER-BBL CHOKE SIZE GAS-OIL RATIO 130 N/A WATER-BBL OIL GRAVITY-API (corr) 130 N/ A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. O D ¡ ~ ~ f\1 f, L ' I' ~ì ' ~ '.0 P i \~ l~ 'I] ~ ~~f ß S ~ f sc~e.fYE~ ~11E~~1DE Interbedded sandstone, siltstone, shale, and coal Form 10-407 Rev. 7-1-80 N:\drlg\kgf\wells\KBU33-6\AOGCOMPL.xls RECEI\IED JUL 25 2002 Alaska Oil & Gas Gons. Gommlsslor! Anchorage Submit in Triplicate RBDMS 8FL JUL 2 9 2002 ) ) 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS"DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Sterling 3659 3596 N/A Top Beluga 4813 4697 Top Beluga 7315 7183 RE(:E I\/E[) JUI ') ¡:::' (ìOlì2 _ eJ t... IJ.. Alaska Oil & Gas Gons. liOlillHlSSlort Anchorage 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. Signed Gary Eller Production Engineer Date 7/24/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. - ..~.- .-_..~.. Item 28: If no cores taken, indicate "none". 't Form 10-407 ORiGINAL N :\drlg\sterl ing\su32-9\AOGCOMPL .xls SCANNED JUL 2 1 2004 API: 50-133-20498-00 AOGCC: 200-179 RT -GL: 20.50' 42' FNL, 4283' FWL, Sec. 7, T4N, R11W, S.M. Tree cxn = 4-3/4" Otis Tree/wellhead drawinq Promore downhole sensor @ 5344' MD (5217' TVD) w/7/16" electric cable (dual- armored, 7-strand conductor) to surface one 10K pressure sensors one temperature sensor KOP: 1500' Build: 1.5 deg per 100' Hold AnQle: 18 deg at 2715' DOP: 4200' Droc: 1.5 deg per 100' Final AnQle: 0 deg at 5415' Directional survey Slickline tagged fill @ 7219' MD (7/18/02) Well Name & Number: County or Parish: Perforations (MD) Angle/Perfs BHP: Dated Completed: Prepared By: ) KBU 44-6 ~ W u ~ ~ : r: I' t ., iiI' "~ ~r ~~ Ij:":. i II ,,1,1,:,1(1 ~"'j'i ~ I~ " ,i ~¡Yi ~ ¡i .~ ;~':',I I',',',,',',., .Iµ,ii"'",'"I,,,,',"I',I',.".' · ,'0:' I. I ~~ ~. ~im I ~'i Ii! ~ ~,~ 4,1 , ~ ~, .~ I,·~,.·'.·.. 11, '1,',\',..' I ~ lî!lí~lï & ¡llfI.1 ~ ~ 1;I,~i ':I.~. ~¡r';; ~* '~I ',', '~."iJ.I 'It\.~ I~ ,);; ~: ~~} I~ i'~ ~ ~ L..~ . ~, ~"= t~ ) M MAIATHO. IDrive Pipe: 20",133 ppf, K-55 to 114' Surface CasinQ: 13-3/8",68 ppf, L-80, BTC @ 1509' Cmt w/ 650 sks of class G to surface Int. CasinQ: 9-5/8", 40 ppf, L-80, BTC @ 5437' Cmt w/ 608 sks of class G Prod. CasinQ: 3-1/2", 9.3 ppf, L- 80, EUE 8rd with 5.25" 00 slotted couplings to 7388' Cmt w/ 930 sks of class G 3-1/2" Casi PBTD - 7323' TO - 7440' KBU 44-6 Kenai Lease: State/Prov. Excape System Details - 16 Excape modules run - Module 1 fired using RFID tag (3/5/02) - Both control lines open for methanol injection (7/9/02) - Ceramic flappers removed with coil (7/9/02) Perfs: Module 16 - 5910' - 5920' (frac'd 7/9/02) Module 15 - 5948' - 5958' (frac'd 7/9102) Module 14 - 6027' - 6037' (frac'd 7/9/02) Module 13 - 6111' - 6121' (frac'd 7/9/02) Module 12 - 6151' - 6161' (frac'd 7/9/02) Module 11 - 6291' - 6301' (frac'd 7/9/02) Module 10 - 6424' - 6434' (frac'd 7/9/02) Module 9 - 6492' - 6502' (frac'd 7/9/02) Module 8 - 6563' - 6573' (frac'd 7/8/02) Module 7 - 6630' - 6640' (frac'd 7/8102) Module 6 - 6722' - 6732' (frac'd 7/8/02) Module 5 - 6874' - 6884' (frac'd 7/8102) Module 4 - 6982' - 6992' (frac'd 7/8/02) Module 3 - 7050' - 7060' (frac'd 7/8/02) Module 2 - 7198' - 7208' (frac'd 7/8/02) Module 1 - 7242' - 7252' (frac'd 7/8/02) Excape module details Frac details Alaska Kenai Gas Field I Country: (TVD) Angle @ KOP and Depth BHT: I Completion Fluid: 2/22/2002 J.G. Eller I Last Revison Date: 7/23/2002 SCANNED JUL 2 1 2004 ) ) Survey Report _~~___~___~_'___~'_'__~_~__'~~'_R_'_~"__h _·_·____·h'__hh~._R__._____._._._____..__~ ___,___..·_·____·_~n_·_~n____·..___._n"__._____n__ Company: Field: Site: Well: Wellpath: Marathon Oil Company Kenai Gas Field Pad 41-7 KBU 44:.6 OH Original hole Date: 3/7/2002 Time: 09:08:30 Page: Co-ordinate(NE) Reference: Well: KBU 44-6, True North Vertical (TVD) Reference: SITE 87.0 Section (VS) Reference: Well (0.00N,O.00E,21.56Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Field: Kenai Gas Field Kenai, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NA027 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre Wmm_95 Site: Pad 41-7 Section 7 Centered on KU 13-5 Site Position: From: Map Position Uncertainty: 0.00 ft Ground Level: 66.00 ft Northing: Easting: 2361844.31 ft 275073.22 ft Latitude: Longitude: North Reference: Grid Convergence: 60 27 32.631 N 151 14 45.826 W True -1.08 deg Well: KBU 44-6 Slot Name: Well Position: +N/-S 125.14 ft Northing: 2361967.24 ft Latitude: 60 27 33.863 N +E/-W 115.60 ft Easting : 275191.17 ft Longitude: 151 14 43.521 W Position Uncertainty: 0.00 ft Wellpath: OH Original hole Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: SITE Height 87.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/16/2002 Declination: 21.15 deg Field Strength: 55182 nT Mag Dip Angle: 73.46 deg Vertical Section: Depth From (TVD) +N/-S +E/- W Direction ft ft ft deg 0.00 0.00 0.00 21.56 Survey Program for Definitive Wellpath Date: 2/18/2002 Validated: No Version: Actual From To Survey Toolcode Tool Name ft ft 165.00 7440.00 Original Survey MWO/GYRO Survey -,--_..._._-~-~~--~_-........,--- MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft ..----..-.- -----.......---.. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 165.00 0.40 50.90 165.00 0.36 0.45 0.50 0.24 0.24 0.00 MWO/GYRO 225.00 0.80 68.20 225.00 0.65 1.00 0.97 0.72 0.67 28.83 MWO/GYRO 286.00 0.60 52.70 285.99 1.00 1.65 1.54 0.45 -0.33 -25.41 MWO/GYRO 347.00 0.70 60.40 346.99 1.38 2.23 2.10 0.22 0.16 12.62 MWO/GYRO 408.00 1.10 36.50 407.98 2.03 2.90 2.96 0.89 0.66 -39.18 MWO/GYRO 438.00 0.90 50.90 437.97 2.41 3.25 3.44 1.07 -0.67 48.00 MWO/GYRO 500.00 1.80 42.10 499.96 3.44 4.28 4.78 1.49 1.45 -14.19 MWO/GYRO 563.00 3.00 43.90 562.90 5.37 6.09 7.23 1.91 1.90 2.86 MWO/GYRO 591.00 3.40 43.90 590.86 6.49 7.17 8.67 1.43 1.43 0.00 MWO/GYRO 651.00 4.90 44.20 650.70 9.61 10.19 12.69 2.50 2.50 0.50 MWO/GYRO 710.00 5.30 41 .40 709.46 13.46 13.75 17.57 0.80 0.68 -4.75 MWO/GYRO 741.00 5.90 41 .40 740.32 15.73 15.75 20.42 1.94 1.94 0.00 MWO/GYRO 801.00 5.50 40.00 800.02 20.25 19.64 26.05 0.71 -0.67 -2.33 MWO/GYRO 864.00 4.80 34.40 862.77 24.74 23.07 31.48 1.37 -1.11 -8.89 MWO/GYRO 927.00 4.30 33.00 925.57 28.89 25.85 36.37 0.81 -0.79 -2.22 MWO/GYRO 990.00 3.10 34.40 988.43 32.28 28.09 40.34 1.91 -1.90 2.22 MWO/GYRO 1053.00 1.90 36.90 1051.37 34.52 29.68 43.01 1.91 -1.90 3.97 MWO/GYRO 1117.00 1.60 29.50 1115.34 36.14 30.76 44.92 0.59 -0.47 -11.56 MWO/GYRO 1180.00 1.10 6.60 1178.33 37.51 31.26 46.38 1.15 -0.79 -36.35 MWO/GYRO 1243.00 0.90 16.80 1241.32 38.59 31 .48 47.45 0.42 -0.32 16.19 MWO/GYRO 1306.00 0.40 220.00 1304.31 38.89 31.48 47.74 2.03 -0.79 -248.89 MWO/GYRO I 1371.00 0.70 235.50 1369.31 38.49 31.01 47.19 0.51 0.46 23.85 MWO/GYRO --- - - j -----.----..-----.----.----.-.-..-- ---,-,_...._-,-----------------_.._---_._._._----~ ----.- SCANNED JUL 2 1 200~ ) ) Survey Report ",":--"...,.",-:-:"',"'":',.-:':':':':',.,..".,...".....":'-';'",_~~~,;.,...-...,.."_.___W"_" ~'-~'-"---'-' -"---..-..-.-. Company: Marathon Oil Company Date: 3/7/2002 Time: 09:08:30 Page: 2 Field: Kenai Gas Field Co-ordinate(NE) Reference: Well: KBU 44-6, True North Site: Pad41-7 Vertical (TVD) Reference: SITE87.0 Well: KBU 44.;6 Section (VS) Reference: Well (0.00N,O.00E,21.56Azi) Wellpath: OH Original hole Survey Calculation Method: Minimum Curvature Db: Sybase Survey '---"---.-"---'-'-'"' ~"-_.._"._".""---"-~-" MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft ----- 1435.00 1.10 203.20 1433.30 37.71 30.44 46.25 0.99 0.62 -50.4 7 MWD/GYRO 1459.00 0.90 230.20 1457.30 37.37 30.21 45.86 2.11 -0.83 112.50 MWD/GYRO 1512.00 1.01 231.36 1510.29 36.82 29.52 45.09 0.20 0.20 2.19 133/8" 1559.00 1.10 232.20 1557.28 36.28 28.84 44.34 0.20 0.20 1.79 MWD/GYRO 1622.00 1.10 233.40 1620.27 35.55 27.88 43.31 0.04 0.00 1.90 MWD/GYRO 1686.00 0.80 224.60 1684.26 34.87 27.07 42.38 0.52 -0.47 -13.75 MWD/GYRO 1750.00 1.10 247.50 1748.26 34.31 26.19 41.54 0.75 0.47 35.78 MWD/GYRO 1813.00 0.40 342.40 1811 .25 34.29 25.57 41.29 1.91 -1.11 150.63 MWD/GYRO 1876.00 0.80 22.10 1874.25 34.91 25.67 41.90 0.88 0.63 63.02 MWD/GYRO 1940.00 2.10 20.30 1938.23 36.42 26.24 43.52 2.03 2.03 -2.81 MWD/GYRO 2002.00 2.90 27.00 2000.17 38.89 27.35 46.21 1.37 1.29 10.81 MWD/GYRO 2064.00 3.40 32.30 2062.07 41.84 29.04 49.58 0.93 0.81 8.55 MWD/GYRO 2127.00 4.90 31.60 2124.91 45.71 31 .45 54.07 2.38 2.38 -1.11 MWD/GYRO 2192.00 6.00 29.10 2189.61 51.04 34.56 60.17 1.73 1.69 -3.85 MWD/GYRO 2255.00 6.90 26.70 2252.21 57.30 37.86 67.20 1.49 1.43 -3.81 MWD/GYRO 2317.00 7.60 26.30 2313.72 64.30 41.35 75.00 1.13 1.13 -0.65 MWD/GYRO 2380.00 8.90 25.60 2376.06 72.43 45.30 84.01 2.07 2.06 -1.11 MWD/GYRO 2442.00 9.70 25.60 2437.25 81.47 49.63 94.00 1.29 1.29 0.00 MWD/GYRO 2505.00 10.60 23.20 2499.26 91.58 54.21 105.09 1.58 1.43 -3.81 MWD/GYRO 2568.00 11.70 21.40 2561.07 102.85 58.82 117.27 1.83 1.75 -2.86 MWD/GYRO 2631.00 12.80 20.70 2622.64 115.33 63.62 130.64 1.76 1.75 -1.11 MWD/GYRO 2692.00 13.90 21.00 2681.99 128.49 68.63 144.72 1.81 1.80 0.49 MWD/GYRO 2754.00 15.30 20.00 2741.98 143.13 74.10 160.35 2.29 2.26 -1.61 MWD/GYRO 2816.00 16.90 18.90 2801.55 159.35 79.82 177.53 2.63 2.58 -1.77 MWD/GYRO 2880.00 17.80 19.30 2862.64 177 .38 86.06 196.59 1.42 1.41 0.62 MWD/GYRO 2944.00 18.90 18.60 2923.38 196.44 92.60 216.72 1.75 1.72 -1.09 MWD/GYRO 3007.00 19.70 18.20 2982.84 216.19 99.17 237.51 1.29 1.27 -0.63 MWD/GYRO 3070.00 20.20 17.50 3042.06 236.65 105.76 258.96 0.88 0.79 -1.11 MWD/GYRO 3133.00 20.00 17.90 3101.22 257.28 112.34 280.56 0.39 -0.32 0.63 MWD/GYRO 3194.00 19.90 17.70 3158.56 277.10 118.70 301.33 0.20 -0.16 -0.33 MWD/GYRO 3257.00 20.00 17.50 3217.78 297.59 125.20 322.77 0.19 0.16 -0.32 MWD/GYRO 3320.00 19.80 17.20 3277.02 318.05 131.60 344.16 0.36 -0.32 -0.48 MWD/GYRO 3383.00 19.50 18.90 3336.35 338.20 138.16 365.30 1.02 -0.48 2.70 MWD/GYRO 3445.00 19.40 20.30 3394.81 357.64 145.08 385.94 0.77 -0.16 2.26 MWD/GYRO 3508.00 19.20 20.70 3454.27 377.15 152.38 406.75 0.38 -0.32 0.63 MWD/GYRO 3571.00 18.90 20.00 3513.82 396.43 159.53 427.31 0.60 -0.48 -1.11 MWD/GYRO 3633.00 19.30 21.80 3572.41 415.38 166.77 447.60 1.15 0.65 2.90 MWD/GYRO 3653.76 19.43 22.50 3592.00 421.75 169.36 454.48 1.28 0.62 3.38 Sterling 3696.00 19.70 23.90 3631.80 434.75 174.94 468.62 1.28 0.64 3.31 MWD/GYRO 3758.00 19.30 23.90 3690.24 453.67 183.32 489.30 0.65 -0.65 0.00 MWD/GYRO 3821.00 19.20 23.90 3749.72 472.66 191.74 510.05 0.16 -0.16 0.00 MWD/GYRO 3884.00 18.80 23.20 3809.29 491.46 199.93 530.55 0.73 -0.63 -1.11 MWD/GYRO 3947.00 18.50 23.20 3868.98 509.98 207.87 550.69 0.48 -0.48 0.00 MWD/GYRO 4009.00 18.60 22.80 3927.76 528.14 215.57 570.40 0.26 0.16 -0.65 MWD/GYRO 4072.00 18.60 21.80 3987.4 7 546.73 223.20 590.50 0.51 0.00 -1.59 MWD/GYRO 4135.00 18.50 21.80 4047.19 565.34 230.64 610.54 0.16 -0.16 0.00 MWD/GYRO 4197.00 18.30 21.00 4106.02 583.56 237.78 630.11 0.52 -0.32 -1.29 MWD/GYRO 4260.00 18.10 21.00 4165.87 601.93 244.84 649.78 0.32 -0.32 0.00 MWD/GYRO 4324.00 17.70 20.30 4226.77 620.33 251.77 669.45 0.71 -0.62 -1.09 MWD/GYRO 4387.00 17.60 20.00 4286.81 638.27 258.35 688.55 0.21 -0.16 -0.48 MWD/GYRO 4450.00 17.20 19.60 4346.93 655.99 264.74 707.38 0.66 -0.63 -0.63 MWD/GYRO 4512.00 16.90 18.90 4406.20 673.15 270.73 725.54 0.59 -0.48 -1.13 MWD/GYRO L_ 4576.00 15.60 18.20 4467.64 690.13 276.43 743.43 2.05 -2.03 -1.09 MWD/GYR~ __._...___..____ J -~-,-,--_. SCANNED JUL 2 1 2004 ) ) Survey Report -~~------.~~--_.~--- _._--_._-----_."----~-"--_.~~_.. _.________~..___"_"w"_~_ Company: Marathon Oil Company Date: 3/7/2002 Time: 09:08:30 Page: 3 Field: Kenai Gas Field Co~ordinate(NE) Reference: Well: KBU 44-6, True North Site: Pad 41-7 Vertical (TVD) Reference: SITE 87.0 Well: KBU 44-6 Section (VS) Reference: Well (0.00N,O.00E,21.56Azi) Wellpatb: OH Original hole Survey Calculation Metbod: Minimum Curvature Db: Sybase Survey _.___n.n___._._.-___..__.____"__·_"~·. _.__.___._____·n'_n___ MD Jnel Azim TVD +N/-S +E/- W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/1 OOft· deg/1 OOft --- 4640.00 15.30 17.90 4529.33 706.34 281.71 760.44 0.49 -0.4 7 -0.4 7 MWD/GYRO 4705.00 14.50 17.50 4592.14 722.26 286.80 777.12 1.24 -1.23 -0.62 MWD/GYRO 4768.00 14.20 18.20 4653.18 737.12 291.58 792.70 0.55 -0.48 1.11 MWD/GYRO 4813.13 13.46 18.49 4697.00 747.36 294.98 803.47 1.65 -1.64 0.64 Upper Beluga 4829.00 13.20 18.60 4712.44 750.83 296.14 807.12 1.65 -1.64 0.69 MWD/GYRO 4892.00 12.50 19.60 4773.86 764.07 300.72 821 .12 1.17 -1.11 1.59 MWD/GYRO 4928.00 12.50 19.30 4809.01 771.42 303.32 828.91 0.18 0.00 -0.83 MWD/GYRO 4955.00 11.90 19.60 4835.40 776.80 305.22 834.61 2.23 -2.22 1.11 MWD/GYRO 4990.00 11.90 20.30 4869.65 783.58 307.68 841.82 0.41 0.00 2.00 MWD/GYRO 5018.00 11.90 20.00 4897.05 789.00 309.67 847.60 0.22 0.00 -1.07 MWD/GYRO 5050.00 11.60 21.00 4928.38 795.11 311.95 854.11 1.13 -0.94 3.12 MWD/GYRO 5081.00 11.50 21.00 4958.75 800.90 314.17 860.32 0.32 -0.32 0.00 MWD/GYRO 5116.00 11.30 21.40 4993.06 807.35 316.68 867.24 0.61 -0.57 1.14 MWD/GYRO 5144.00 11.20 21.00 5020.52 812.45 318.65 872.70 0.45 -0.36 -1.43 MWD/GYRO 5179.00 10.90 21.40 5054.87 818.70 321.08 879.41 0.88 -0.86 1.14 MWD/GYRO 5207.00 11.10 21.80 5082.36 823.67 323.04 884.75 0.76 0.71 1.43 MWD/GYRO 5242.00 10.90 22.10 5116.71 829.86 325.54 891.43 0.59 -0.57 0.86 MWD/GYRO 5271.00 10.60 22.10 5145.20 834.87 327.57 896.84 1.03 -1.03 0.00 MWD/GYRO 5306.00 10.50 22.10 5179.61 840.81 329.99 903.24 0.29 -0.29 0.00 MWD/GYRO 5333.00 10.30 22.80 5206.17 845.32 331.85 908.12 0.88 -0.74 2.59 MWD/GYRO 5399.00 10.00 23.20 5271.14 856.02 336.39 919.74 0.47 -0.45 0.61 MWD/GYRO 5428.30 9.71 22.87 5300.00 860.64 338.35 924.76 1.02 -1.00 -1.13 Target 1 5437.00 9.62 22.77 5308.58 861.98 338.92 926.22 1.02 -1.00 -1.17 95/8" 5459.00 9.40 22.50 5330.28 865.34 340.32 929.85 1.02 -1.00 -1.21 MWD/GYRO 5469.87 9.40 22.50 5341.00 866.98 341.00 931.63 0.00 0.00 0.00 Middle Beluga 5491.00 9.40 22.50 5361.85 870.17 342.32 935.08 0.00 0.00 0.00 MWD/GYRO 5523.00 9.20 20.70 5393.43 874.97 344.22 940.25 1.10 -0.62 -5.62 MWD/GYRO 5554.00 9.10 20.30 5424.03 879.59 345.95 945.18 0.38 -0.32 -1.29 MWD/GYRO 5586.00 9.00 20.30 5455.63 884.31 347.69 950.21 0.31 -0.31 0.00 MWD/GYRO 5618.00 8.70 19.60 5487.25 888.94 349.37 955.13 1.00 -0.94 -2.19 MWD/GYRO 5647.00 8.10 20.70 5515.94 892.92 350.83 959.36 2.14 -2.07 3.79 MWD/GYRO 5710.00 7.30 21.40 5578.37 900.79 353.86 967.80 1.28 -1.27 1.11 MWD/GYRO 5773.00 5.90 22.80 5640.95 907.51 356.58 975.04 2.24 -2.22 2.22 MWD/GYRO 5836.00 3.40 27.70 5703.74 912.15 358.70 980.14 4.01 -3.97 7.78 MWD/GYRO 5899.00 2.10 19.60 5766.67 914.89 359.96 983.15 2.15 -2.06 -12.86 MWD/GYRO 5961.00 1.90 21.40 5828.63 916.92 360.71 985.31 0.34 -0.32 2.90 MWD/GYRO 6023.00 1.10 35.80 5890.61 918.35 361 .44 986.92 1.42 -1.29 23.23 MWD/GYRO 6084.00 1.00 49.50 5951.60 919.18 362.18 987.96 0.44 -0.16 22.46 MWD/GYRO 6151.00 0.90 68.30 6018.59 919.75 363.12 988.83 0.49 -0.15 28.06 MWD/GYRO 6208.42 0.80 64.49 6076.00 920.09 363.90 989.44 0.19 -0.17 -6.63 Lower Beluga 6211.00 0.80 64.30 6078.58 920.11 363.93 989.46 0.19 -0.16 -7.46 MWD/GYRO 6274.00 0.50 78.70 6141.58 920.35 364.60 989.94 0.54 -0.48 22.86 MWD/GYRO 6337.00 0.40 10.90 6204.58 920.62 364.91 990.30 0.81 -0.16 -107.62 MWD/GYRO 6400.00 0.40 75.40 6267.58 920.89 365.16 990.65 0.68 0.00 102.38 MWD/GYRO 6465.00 0.40 52.70 6332.58 921.09 365.56 990.98 0.24 0.00 -34.92 MWD/GYRO 6529.00 0.20 299.10 6396.57 921.28 365.64 991.18 0.80 -0.31 -177.50 MWD/GYRO 6592.00 0.20 103.00 6459.57 921.30 365.65 991.21 0.63 0.00 260.16 MWD/GYRO 6653.00 0.40 14.00 6520.57 921.49 365.81 991.44 0.73 0.33 -145.90 MWD/GYRO 6716.00 0.30 307.20 6583.57 921 .80 365.73 991.70 0.63 -0.16 -106.03 MWD/GYRO 6781.00 0.30 267.80 6648.57 921.90 365.43 991.68 0.31 0.00 -60.62 MWD/GYRO 6845.00 0.20 9.10 6712.57 922.00 365.28 991.72 0.61 -0.16 158.28 MWD/GYRO 6909.00 0.40 227.80 6776.57 921.96 365.13 991.63 0.89 0.31 -220.78 MWD/GYRO 6972.00 0.20 303.70 6839.57 921.87 364.87 991.46 0.64 -0.32 120.48 MWD/GYRO 7035.00 0.60 231 .60 6902.57 921.73 364.52 991.19 0.91 0.63 -114.44 MWD/GYRO --------.----.-- -------.--------- :ANNED JUL 2 1 200~ Company: Marathon Oil Company Field: Kenai Gas Field Site: Pad 41-7 Well: KBU 44;.6 Wellpath: OH Original hole Survey ~_R_~_'_~___"~" MD lnel Azim ft deg deg 7098.00 0.60 226.40 7160.00 0.40 228.50 7222.00 0.40 246.80 7285.00 0.90 256.20 7309.45 0.90 256.20 7332.45 0.90 256.20 7346.00 0.90 256.90 7383.00 0.80 242.50 7388.46 0.80 242.50 7440.00 0.80 242.50 Targets Name Description Target 1 Target 2 -Circle (Radius: 250) Casing Points ) ) Survey Report ___'___"_'__'__'_R~__"__ Date: 3/7/2002 Time: 09:08:30 Page: 4 Co-ordinate(NE) Reference: Well: KBU 44-6, True North Vertical (TVD) Reference: SITE 87.0 Section (VS) Reference: Well (0.00N,O.00E,21.56Azi) Survey Calculation Method: Minimum Curvature Db: Sybase ..----.--.-----.-.- TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft ft ft ft deg/100ft deg/100ft deg/100ft 6965.57 921.30 364.03 990.61 0.09 0.00 -8.25 MWD/GYRO 7027.56 920.93 363.63 990.12 0.32 -0.32 3.39 MWD/GYRO 7089.56 920.70 363.27 989.78 0.21 0.00 29.52 MWD/GYRO 7152.56 920.50 362.59 989.33 0.81 0.79 14.92 MWD/GYRO 7177.00 920.41 362.21 989.11 0.00 0.00 0.00 Tyonek 7200.00 920.32 361.86 988.91 0.00 0.00 0.00 Target 2 7213.55 920.27 361.65 988.78 0.08 0.00 5.17 MWD/GYRO 7250.55 920.09 361.14 988.42 0.64 -0.27 -38.92 MWD/GYRO 7256.01 920.05 361.07 988.37 0.00 0.00 0.00 31/2" 7307.54 919.72 360.44 987.82 0.00 0.00 0.00 MWD/GYRO Map Map <- Latitude --> <~- Longitude --> TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft ft ft ft ft 5300.00 791.75 312.86 2362752.93 275518.95 60 27 41.661 N 151 14 37.281 W 7200.00 791.75 312.86 2362752.93 275518.95 60 27 41.661 N 151 14 37.281 W MD TVD Diameter Hole Size Name ft ft in in 1512.00 1510.29 13.375 17.500 13 3/8" 5437.00 5308.58 9.625 12.250 95/8" 7388.46 7256.01 3.500 8.500 3 1/2" Formations f'~"'-'MD __..______.__,___~__.___._._.R_.___~_hn___ TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 3653.76 3592.00 Sterling SANDSTONE 0.00 0.00 4813.13 4697.00 Upper Beluga SANDSTONE 0.00 0.00 5469.87 5341.00 Middle Beluga SANDSTONE 0.00 0.00 6208.42 6076.00 Lower Beluga SANDSTONE 0.00 0.00 7309.45 7177.00 Tyonek SANDSTONE 0.00 0.00 .... SCANNED JUL 2 1 2004 WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS Rigging down from KBU 43-6RD 24 HR FORECAST FIELD NAME Kenai ') ) Page 1 of 1 TVD DFS REPT NO. I DATE 1 1/29/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 14,177.00 14,177.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST I NEXT CASING LEAKOFF PPG (ft) (in) @ (ft) I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ 24 HR SUMMARY: Rigging down FI KBU 43-6RD FROM TO HRS DEPTH FM DEPTH TO 12:00 06:00 18.00 OPERATIONS SUMMARY SUB PHASE DESCRIPTION· MIRU Set mats, prepare location F/ rig. Rigging down FI KBU 43-6RD on same pad. COMPANY Marathon SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 18.00 Inlet Drilling Alaska HOURS 216.00 SERVICE NO. 18 SCANNED ". Jl n - 2 1 200~ Printed: 2/8/2002 2:36:29 PM ) ) FIELD NAME Kenai I STATE/PROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ I KB TMD TVD I DFS REPT NO. I DATE 87.00 66.00 2 1/30/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 20,326.00 34,503.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST I NEXT CASING LEAKOFF PPG (ft) (in) @ (ft) WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS Rigging up. 24 HR FORECAST 24 HR SUMMARY: Move rig off KU 43-6RD. Move to KU 44-6. Rigging up. FROM TO HRS DEPTH FM DEPTH TO 06:00 06:00 24.00 OPERATIONS SUMMARY SUB PHASE DESCRIPTION MIRU Move rig off KU 43-6RD. Move on same pad to KU 44-6 and rig up. Rig move +1- 60% complete. Weld on 20" SOW X 21-1/4" 2M starting head on 20" conductor drive pipe. COMPANY Marathon Inlet Drilling Alaska Steam On Wheels SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 S&R Enterprises 18 216.00 Alaska Oil Sales 1 6.00 Weaver Brothers SERVICE NO. 2 1 3 HOURS· 7.00 1.00 48.00 .......".-..-............ "l\' SCANNED JUL 2 1 20Q4 Printed: 2/8/2002 2:36:31 PM ) ) WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS N/U Diverter System. 24 HR FORECAST Daily Drilling Report I KB I GL 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 87.00 66.00 3 1/31/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 30,170.00 64,673.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None I NEXT CASING (ft) (in) @ FIELD NAME Kenai I STATE/PROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ (ft) LEAKOFF PPG 24 HR SUMMARY: Continue rigging up rig & top drive. N/U diverter system. FROM TO HRS DEPTH FM DEPTH TO 06:00 00:00 18.00 00:00 06:00 6.00 COMPANY Marathon Inlet Drilling Alaska Weaver Brothers SERVICE OPERATIONS SUMMARY SUB PHASE DESCRIPTION MIRU Continue rigging up rig & top drive, R/U 95% complete. Install 5-1/2" liners in mud pumps. MIRU Accept rig on day work @ 00:00 hours 1-31-02. N/U diverter on starting head. Mix spud mud. PERSONNEL DATA· NO. HOURS COMPANY 1 24.00 Alaska Petroleum Contra 18 216.00 R&K Industrial 1 12.00 BJ Services NO. 3 1 3 HOURS 18.00 8.00 9.00 SERVICE " - ,.....,....~-.......,.....-."'_......."'¡~,.. ~ SCANNED JUL 212004 Printed: 2/8/2002 2:36:32 PM . ... . . . . . . . . .. ... . . . . , ....... . . . .. .. ... . .. . . . . ..... . , .. . · . ... . ""0. ............... .. .... ",. ...... ....... . ........ · ,;.",' :... ..:....:: ...... "::,":":"::. ....: :... ":..:" :..:'. . . .::..: :':.." '.: '.'. :",::."' .. .. ........ .... ... . .... ..... .... 0.. .. . ... . . . . .. .. . . . . . . '.. . .. .., ... . .. ... . .. . . .. . .. . . . .. .... . . .... . ..... . ... . . .. . . .... ..... .... . . ... ......... · ",.... . ....... . ..... .. . .", ... ... . .. .... · .. .. ... . . ",. ". ........ . ... . ...... ... ......... ...... ..... .... . ...... ," .",", . . . ",. ................ ...... ... .. "' .. ... .. . .... . ...... .... ... . . .... ............. . .. .... ...... ........ .... .. ..... ··;;·:..·.·:.irv1A~~~~()Ni:¡~I.~g()IVI!~~~;N..·i.}¡·.·.: .·1 /·¡:iØ~ilyll)rUnpg Report I KB I GL 124 HRS PROG TMD TVD I DFS 1 REPT NO. I DATE 87.00 66.00 550.0 550 550 4 2/1/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 29,258.00 93,931.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 1/31/2002 I NEXT CASING (ft) (in) @ (ft) ) ) WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS Rotary drilling @ 550'. 24 HR FORECAST FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ 24 HR SUMMARY: Finish rigging up rig. Function test diverter system. Spud, slide & rotary drill F/42' to 550'. LEAKOFF PPG FROM 06:00 16:30 17:00 21:30 23:30 TO HRS 16:30 10.50 17:00 0.50 21 :30 4.50 23:30 2.00 06:00 6.50 OPERATIONS SUMMARY PHASE DESCRIPTION MIRU Finish rigging up rig. Finish N/U diverter. MIRU Function test diverter system. MIRU P/U and stand back 25 stands 4" drill pipe in derrick. DRLSUR P/U steerable drilling assembly. Surface test MWD tool. DRLSUR Spud @ 23:30 hours 1/31/2002. Slide & rotary drill F/42' to 550'. DEPTH FM DEPTH TO SUB 42 550 DENSITY(ppg) FV PVNP 84 16/44 8.80 I PP I GELS WUHTHP 33/42 16.01 IECDI IMUD DATAl DAILY COST I OIUWAT "IoSand/MBT Ph/pM 195 0.50/20.0 9.4010.2 2,038.00 pf/Mf 0.3/ FClr.SOL 3.0/5.0 I CUM· COST I 2,038.00 CI Ca H2S LIME 200 60 ES BITS BIT / RUN SIZE MANUF. TYPE SERIA!-NO. JETS OR TFA DEPTH IN DATE IN I-()-D-L-B-G-O-R 1/1 17.500 Smith MSDGHQC LK 1 029 12/18/18/18/1 42.0 1/31/2002 2-2-NO-A-E- 1-NO-TD BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 1 / 1 10 I 20 132/190 490 800 266 3.00 508.0 169.33 3.00 508.0 169.33 BHA NO. I LENGTH 1 857.35 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF*ROT WT. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS MTR HRS 55 HRS o 40 40 I 40 5,000 I 4,000 Bit, 8" 1.2 DEG M-1C Motor, 17" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (In) LINER (In) SPM Q(gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 8.000 5.500 105 246.22 800 492.44 8.000 5.500 105 246.22 800 492.44 M;D; . SURVEY DATA······· I.V.D. N/S CUM EJW CUM SECTION M.D. 0.00 0.00 0.00 0.00 347 165.00 0.36 0.45 0.50 408 225.00 0.65 1.00 0.97 438 285.99 1.00 1.65 1.54 INCL. 0.70 1.10 0.90 AZI 60.40 36.50 50.90 o 165 225 286 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch Well Services 18 216.00 Alaska Petroleum Contra 1 24.00 R&K Industrial 2 48.00 T.V.D. N/S CUM EJW CUM SECTION 346.99 1.38 2.23 2.10 407.98 2.03 2.90 2.96 437.97 2.41 3.25 3.44 SERVICE NO. HOURS 3 36.00 2 4.00 1 6.00 ~ SCf4.NNED JUL 2. 1 2004 Printed: 2/8/2002 2:36:33 PM ') ) Daily Drilling Report IGL \24 HRS PROG TMD TVD IDFS 2 REPTNO. I DATE 87.00 66.00 962.0 1,512 1,510 5 2/2/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI CAlLY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 82,234.00 176,165.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 1/31/2002 I NEXT CASING (ft) (in) @ (ft) WELL NAME KB U 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS RlU to run surface casing. 24 HR FORECAST F'ªg~,J ,,91,2, FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ LEAKOFF PPG 24 HR SUMMARY: Drill surface hole F/550' to 1512'. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 09:00 3.00 550 853 09:00 09:30 0.50 853 853 09:30 17:30 8.00 853 1,512 17:30 18:30 1.00 1,512 1,512 18:30 22:30 4.00 1,512 1,512 22:30 23:00 0.50 1,512 1,512 23:00 00:00 1.00 1,512 1,512 00:00 03:00 3.00 1,512 1,512 03:00 03:30 0.50 1,512 1,512 03:30 06:00 2.50 1,512 1,512 DENSITY(ppg) FV PVIYP 45 14/22 9.00 I pp GELS WUHTHP 8/14 9.2/ FCIT.SOL 2.0/5.0 OPERATIONS SUMMARY PHASE DESCRIPTION DRLSUR Slide & rotary drill F/550' to 853'. DRLSUR Change out top drive wear sub. DRLSUR Slide & rotary drill F/853' to surface casing depth @ 1512' MD 11510' TVD. DRLSUR Circulate bottoms up. DRLSUR Wiper trip, SLM. DRLSUR Wash 154' F/1358' to bottom @ 1512'. DRLSUR Circulate around 50 BBL HI-VIS sweep. DRLSUR TOOH to run surface casing. DRLSUR UD steerable drilling assembly. DRLSUR R/U to run casing. IECD IMUD DATAl DAILY COST I OIUWAT %SandlMBT Ph/pM /95 0.25/20.0 9.20/0.2 4,311.00 Pf/Mf 0.2/0.6 I CUM COST I 6,349.00 CI Ca H2S LIME ES 300 20 BITS BIT / RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R 1 /1 17.500 Smith MSDGHQC LK 1 029 12/18/18/18// 42.0 1/31/2002 2-2-NO-A-E- 1-NO- TO BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 1/1 10/20 152/212 564 1,600 360 8.00 962.0 120.25 11.00 1,470.0 1 33.64 BHA NO. I LENGTH 1 857.35 BHA DESCRIPTION BH~ I EFF wr. I PICK UP I SLACK OF~ ROT wr. I TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS o 65 65 I 65 10 / 4 Bit, 8" 1.2 DEG M-1C Motor, 17" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q KILL SPM / PRESSURE 8.000 5.500 120 281.40 1,600 562.80 8.000 5.500 120 281.40 1,600 562.80 SURVEY DATA M.D. INCL. AZI T.V.D. NIS CUM EIW CUM SECTION M.D. INCL. All T.V.D. NIS CUM EIW CUM SECTION 500 1.80 42.10 499.96 3.44 4.28 4.78 990 3.10 34.40 988.43 32.28 28.09 40.34 563 3.00 43.90 562.90 5.37 6.09 7.23 1,053 1.90 36.90 1,051.37 34.52 29.68 43.01 591 3.40 43.90 590.86 6.49 7.17 8.67 1,117 1.60 29.50 1,115.34 36.14 30.76 44.92 651 4.90 44.20 650.70 9.61 10.19 12.69 1 180 1.10 6.60 1,178.33 37.51 31.26 46.38 710 5.30 41.40 709.46 13.46 13.75 17.57 1,243 0.90 16.80 1 ,241.32 38.59 31 .48 47.45 741 5.90 41.40 740.32 15.73 15.75 20.42 1,30S''' -.. 0.40 "220.00 -W"t;304.31 38.89 31.48 47.74 801 5.50 40.00 800.02 20.25 19.64 26.05 1,371 0.70 235.~ 1,369.31 38.49 31.01 47.19 864 4.80 34.40 862.77 24.74 23.07 31 .48 1 ,435 1.10 203.20 1,433.30 37.71 30.44 46.25 927 4.30 33.00 925.57 28.89 25.85 36.37 1 ,459 0.90 230.20 1,457.30 37.37 30.21 45.86 SCANNED JUL 2 1 2004 Printed: 2/8/2002 2:36:35 PM ) ) COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids Baker Hughes Inteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch Well Services 18 216.00 R&K Industrial 1 24.00 Weatherford 2 48.00 SERVICE NO. HOURS 3 36.00 1 24.00 3 9.00 .. SCANNED JUL 2 1 'l004 Printed: 2/8/2002 2:36:35 PM ) ) Daily Drilling Report I KB I GL 124 HRS PROG TMD TVD I DFS 3 REPT NO. I DATE 87.00 66.00 1,512 1,510 6 2/3/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 169,779.00 345,944.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None VV2002 I STATE/PROV I COUNTY/OTHER I LAST CASING I NEXT CASING Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) <i,420.0 (ft) WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS N/D diverter. 24 HR FORECAST FIELD NAME Kenai MARATHON OIL COMPANY Page 1 of 1 LEAKOFF PPG 24 HR SUMMARY: Run & cement surface casing WI 650 sx. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 06:30 0.50 1,512 1,512 06:30 11:30 5.00 1,512 1,512 11 :30 14:00 2.50 1,512 1,512 14:00 16:00 2.00 1,512 1,512 16:00 17:00 1.00 1,512 1,512 17:00 18:00 1.00 1,512 1,512 18:00 20:30 2.50 1,512 1,512 20:30 22:00 1.50 1,512 1,512 22:00 02:30 4.50 1,512 1,512 02:30 03:30 1.00 1,512 1,512 03:30 06:00 2.50 1,512 1,512 DENSITY(ppg) FV PVNP 41 13/10 9.00 Ij~pl GELS> WLlHTHP ·.·FCrr.SOL 4/6 10.V 2.0/5.0 COMPANY Marathon In let Drilling Alaska M-I Drilling Fluids Baker Hughes Inteq Epoch Well Services SERVICE OPERATIONS SUMMARY PHASE DESCRIPTION CSGSUR Finish RlU to run casing. Hold safety meeting. CSGSUR P/U & run 37 JTS 13-3/8" 68# L-80 BTC surface casing to 1509' MD 11507' TVD, WI stab in float collar @ 1464'. CSGSUR Circulate & condition. RID casing running tools. Change bails, R/U false rotary table. CSGSUR M/U stabing sub and centralizer. TIH WI same WI 4" drill pipe FI inner string cement job. CSGSUR M/U Cement head, & space out WI drill pipe subs. CSGSUR Land stabbing sub seals in float collar. Circulate & displace drill pipe. Hold safety meeting. CSGSUR Cement surface casing as follows. Pump 20 BBLS 8.4 PPG mud clean II, followed by 650 sx (1625 ft/3) Type I cement WI 1.5% bwoc Calcium Chloride + 20% bwoc LW-6 + 0.3% bwoc CD-32 + 1 gal/100 sack FP-6L + 1% bwoc Sodium Metasilicate + 20% bwoc MPA-1 + 96.2% Fresh Water, mixed @ 12.0 PPG. Displace Plug W/5 BBLS fresh water + 10 BBLS 9.0 PPG mud WI 300 psi final circulating pressure. Bump plug 1 BBL early WI 900 psi, pump 1.5 additional BBLS. CIP @ 19:50 hours 2-2-02. Cement design F/50% excess WI +1- 40 BBLS cement circulated to surface. Bo Brown, BLM representative on location to witness cement job. CSGSUR Release pressure WI floats holding. Sting out of float collar. TOOH WI inner string. CSGSUR WOC. UD cement head, dump & clean pits. RID Diverter line & knife valve. CSGSUR Make rough cut on surface casing. UD cut off joint. CSGSUR NID diverter. ¡ECD I MUD DATAl DAILY COST I .OIUWAT %SandlMBT PhlpM 195 0.25/20.0 8.301 ICµMÇqST I CI Ca 300 40 2,217.00 Pr/Mf 10.9 8,566.00 H2S LIME ES PERSONNEL DATA NO. HOURS COMPANY 1 24.00 R&K Industrial 18 216.00 Weatherford 1 24.00 ABB Vetco GraY___J. .. 2 48.00 BJ Services 3 36.00 SERVICE NO. 2 3 1 4 HOURS 24.00 21.00 3.00 72.00 ...-.--..-......-. '!' SCANNED JUL 2 1 2004 Printed: 2/8/2002 2:36:36 PM ) ) MARATHON OIL COMPANY Page 1 of 1 Daily Drilling Report WELL NAME I GL 124 HRS PROG TMD TVD I DFS 4 REPT NO. I DATE KBU44-6 87.00 66.00 1,512 1,510 7 2/4/2002 SUPERVISOR I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST Randy Ratliff GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 CURRENT STATUS I MaC WI INRI DAILY WELL COST CUM WELL COST P/U drill pipe & standing back in derrick for next hole section. 100.00 (%) 92.20 (%) 61,529.00 407,473.00 24 HR FORECAST I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/2/2002 2/4/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) @,420.0 (ft) FIELD NAME Kenai 24 HR SUMMARY: N/U & test wellhead & BOPE. P/U BHA & drill pipe. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 08:30 2.50 1,512 1,512 08:30 10:00 1.50 1,512 1,512 10:00 19:30 9.50 1,512 1,512 19:30 00:30 5.00 1,512 1,512 OPERATIONS SUMMARY PHASE DESCRIPTION DRLlN1 Cut 20" conductor pipe, remove 21-1/4" 2M starting head. Make final cut on 13-3/8" surface casing. DRLlN1 Install ABB Vetco Gray MB-199 13-5/8" 5M multi-bowl wellhead W/ 13-3/8" slip lock connection and base plate. Energize packoff, and test to 1800 psi. RKB to top of flange is 19.37'. DRLlN1 N/U BOP stack. Finish changing pump liners to 5" DRLlN1 Test upper VBR rams, lower 4" pipe rams, blind rams, annular, stack manual & HCR valves & check valve, choke manifold valves 1 thru 12, IBOP & surface safety valves, and top drive manual & automatic safety valves to 250 /3000 psi F/ 10 minute intervals. AOGCC representative Lou Grimaldi on location for test. BLM representative declined to witness test. 00:30 01:30 1.00 1,512 1,512 DRLlN1 Set wear bushing. Purge lines. 01:30 02:30 1.00 1,512 1,512 DRLlN1 Service rig & top drive. Replace top drive gripper dies. 02:30 04:30 2.00 1,512 1,512 DRLlN1 P/U steerable drilling assembly. TIH W/5" HWDP. 04:30 06:00 1.50 1,512 1,512 DRLlN1 P/U additional drill pipe & stand in derrick for next hole section. DENSITY(ppg) FV PVNP 82 20/20 8.70 I PP I GELS WUHTHP 5/9 11.2/ FCIT.SOL 2.0/4.0 IECD IMUD DATAl DAILY COST I OIUWAT %Sand/MBT PhlpM 196 /22.5 9.2010.2 4,757.00 Pf/Mf 0.1/0.6 I CUM COST I 13,323.00 CI Ca H2S LIME 400 20 ES BIT! RUN 2/1 size 12.250 MANUF. Hughes BITS TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B:"G-O-R MX-1C G19JP 15/18/18/18// 1,512.0 2/4/2002 2-2-NO-A-E-I-NO-RR GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BIT I RUN WOB RPM BHA BHA~O: L~~~~O~ EFF WT PICK UP I SLACK OF1ROT WT. TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I S8 HRS BHA DESCRIPTION Bit, 8" 1.2 DEG M-1 C Motor, 12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-114" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub PERSONNEL. DATA NO. HOUASCÓMPANY 1 24.00 Epoch Well Services 18 216.00 ABB Vetco Gray 1 24.00 Weaver Brothers 2 48.00 Marathon Inlet Drilling Alaska M-I Drilling Fluids Baker Hughes Inteq ~ H (jURS 36.00 8.00 4.00 SCANNED JUL 2 1 2G04 Printed: 2/8/2002 2:36:38 PM ) ) MARATHON OIL COMPANY Page 1 of 2 FIELD NAME Kenai Daily Drilling Report I KB I GL 124 HRS PROG TMD TVD I DFS 5 REPT NO. I DATE 87.00 66.00 949.0 2,461 2,456 8 2/5/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 64,156.00 471,629.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/4/2002 I STATE/PROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) @,420.0 (ft) 19.32 WELL NAME KBU 44-6 SUPERVISOR Randy Ratliff CURRENT STATUS SID @ shoe for mud pump repair. 24 HR FORECAST 24 HR SUMMARY: Test surface casing. Drill out & test shoe to leakoff. Slide & rotary drill F/1512' to 2461'. OPERATIONS SUMMARY' FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 10:30 4.50 1,512 1,512 DRLlN1 Finish P/U 4" drill pipe & stand in derrick FI intermediate hole section. Finish in hole P/U drill pipe FI 857' to 1300'. 10:30 11:00 0.50 1,512 1,512 DRLlN1 Wash in hole F/1300' to 1360'. 11 :00 11:30 0.50 1,512 1,512 DRLlN1 COT: Repair flowline leak. 11 :30 12:00 0.50 1,512 1,512 DRLlN1 Continue washing in hole F/1360' to top of surface casing float collar @ 1464'. 12:00 12:30 0.50 1,512 1,512 DRLlN 1 Test surface casing to 1500 psi W/9.1 PPG mud F/30 minutes. Monitor 20 psi. pressure loss during test. 12:30 14:00 1.50 1,512 1,512 DRLlN1 Drill hard cement & float equipment. Drill 20' below casing shoe FI 1509' to 1529'. 14:00 14:30 0.50 1,512 1,512 DRLlN1 Circulate bottoms up. 14:30 15:00 0.50 1,512 1,512 DRLlN1 Test 13-3/8" casing shoe @ 1509' MD 11507' TVD. Took formation to leakoff @ 19.3 PPG EMW (800 psi WI 9.1 PPG mud) 15:00 01 :00 10.00 1,512 2,461 DRLlN1 Slide & rotary drill F/1529' to 2461 '. ART 5 hours, AST 3 hours. Displace new gel mud into hole. Dump 210 BBLS spud mud. Add sized calcium carbonate to system to controllosss. 01 :00 02:00 1.00 2,461 2,461 DRLlN 1 CDT: SID drilling due to loss of #1 mud pump. Circulate bottoms up. 02:00 03:00 1.00 2,461 2,461 DRLlN 1 COT: TOOH to casing shoe. 03:00 06:00 3.00 2,461 2,461 DRLlN 1 CDT: #1 mud pump repair. DENSITY(ppg) FV PVIYP 53 13/19 9.00 I PP I GELS WLJHTHP 5/11 9.2/ I ECD I I MUD DATAl DAILY COST I FCrr.SOL OIUWAT %SandlMBT Ph/pM 2.0/6.0 /94 0.50/20.0 9.00/0.3 5,513.00 Pf/Mf 0.2/1.7 I CUM COST I 18,836.00 CI Ça H2S LIME ES 400 20 BIT / RUN SIZE MANUF. TYPE 2/1 12.250 Hughes MX-1C BIT / RUN WOB RPM GPM 2/1 10/15 130/210 485 BITS SERIAL NO. JETS OR TFA G19JP 15/18/18/18// DEPTH IN DATE IN 1,512.0 2/4/2002 I-O-D-L-B-G-Q-R 2-2-NO-A-E- I-NO-RR PRESS 1,300 PBIT 231 HRS 8.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 949.0 118.63 8.00 949.0 118.63 BHA NO. LENGTH 2 857.02 BHA DESCRIPTION BHA EFF WT. PICK UP SLACK OF1ROT WT. TORQUE (maximin) I BHA HRS JAR HRS MWD HRS MTR HRS SS HRS o 75 75 75 6,000 / 4,000 Bit, 8" 1.2 DEG M-1C Motor, 12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP, 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. 1 .2 MARE OF PUMP PUMP 1 HYDRAULIC DATA STROKE (in) LINER (ill) SPM Q(gprn) 8.000 5.000 125 242.25 8.000 5.000 125 242.25 PRESS>(psi) TOTALQ 1,300 484.50 1,300 484.50 KILLSPM J ·ÞRESSORE OILWELL OILWELL M.D. INCL. 1 ,559 1 .10 AZI 232.20 SURVEY· DATA T.V.D. NlS CUM EIW CUM SECTION M.D. INCL. 1,557.28 36.28 28.84 44.34 1,622 1.10 AZI 233.40 T.V;D. NISCUM EIWCUM SECTION 1,620.27 35.55 27.88 43.31 SCANNED JUL 2 1 2004 Printed: 2/8/2002 2:36:39 PM ) ) WELL NAME KBU 44-6 MARATHON OIL COMPANY Page 2 of: 2 Daily Drilling Report IGL 124 HRS PROG TMD 66.00 949.0 2,461 ITVD IDFS 2,456 5 I REPT NO. I DATE 8 2/5/2002 IKB 87.00 SURVEY DATA M.D. INCL. All T.V.D. NIS CUM EIW CUM SECTION M.D. INCL. All T.V.D. NIS CUM EIW CUM SECTION 1,686 0.80 224.60 1,684.26 34.87 27.07 42.38 2,064 3.40 32.30 2,062.07 41.84 29.04 49.58 1,750 1.10 247.50 1,748.26 34.31 26.19 41.54 2,127 4.90 31.60 2,124.91 45.71 31 .45 54.07 1,813 0.40 342.40 1,811.25 34.29 25.57 41.29 2,192 6.00 29.10 2,189.61 51.04 34.56 60.17 1,876 0.80 22.10 1,874.25 34.91 25.67 41.90 2,255 6.90 26.70 2,252.21 57.30 37.86 67.20 1,940 2.10 20.30 1,938.23 36.42 26.24 43.52 2,317 7.60 26.30 2,313.72 64.30 41.35 75.00 2,002 2.90 27.00 2,000.17 38.89 27.35 46.21 2,380 8.90 25.60 2,376.06 72.43 45.30 84.01 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids Baker Hughes lriteq SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch Well Services 18 216.00 Weaver Brothers 1 24.00 R&K Industrial 2 48.00 SERVICE NO. 3 1 2 HOURS 36.00 4.00 15.00 ... SCANNED JUL 2 1 2004 Printed: 2/8/2002 2:36:39 PM WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS Repairing pump controls 24 HR FORECAST Drill to casing point FIELD NAME Kenai ) ) MARATHON OIL COMPANY Page 1 of 2 Daily Drilling Report IKB GL 24HRSPROG TMD TVD IDFS 6 REPTNO. DATE 87.00 66.00 1,200.0 3,661 3,603 9 2/6/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 37,342.00 508,971.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 214/2002 I STATE/PROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) ~,420.0 (ft) 19.32 24 HR SUMMARY: Drill 2461' to 3661' I repairing pump controls OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 08:00 2.00 2,461 2,461 DRLlN1 CDT : #1 pump repair 08:00 09:00 1.00 2,461 2,461 DRLlN1 R.I.H. to 2310' I Wash to bottom @2461' (151') 09:00 02:30 17.50 2,461 3,661 DRLlN1 Drill Open Hole (Directional) from 2461' to 3661' (1200') 02:30 04:30 2.00 3,661 3,661 DRLlN1 Trouble shoot #1 pump hydraulics VFD 04:30 06:00 1.50 3,661 3,661 DRLlN1 P.O.H. to shoe DENSITY(ppg) I 9.35 I pp I :FV PVNP GELS WUHTHP 48 14/17 519 8.81 Fcrr.SOL 2.0/5.0 IEeD IMUD DATAl DAILY COST I OIUWAT %Sand/MBT Ph/pM /94 0.75120.0 9.20/0.3 4,929.00 Pr/Mf 0.2/2.8 I CUM COST I 23,765.00 CI Ca H2S LIME 300 20 ES' BITS MANUF. TYPE SERIAL NO. JETS OR TFA DEPTHIN DATE IN I-O-D-L-B-G-O-R Hughes MX-1C G19JP 15/18/18/18/1 1,512.0 2/4/2002 2-2-NO-A-E- I-NO-RR WOB RPM GPM PRESS PBIT HRS 24Hr DlST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 10/12 75 I 80 485 14,500 240 12.00 1,200.0 100.00 20.00 2,149.0 1 07.45 BIT I RUN SIZE 2 /1 12.250 BIT I RUN 2/1 BHA NO. \ LENGTH 2 857.02 BHA DESCRIPTION BHA. '. . EFF WT. I PICK UP I SLACK OF1 ROT WT. TORQUE (maximin) BHA HRS \ JAR HRS I MWD HRS MTR HRS S8 HRS 39 95 70 80 10 I 8 Bit, 8" 1.2 DEG M-1 C Motor, 12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LINER (In) . SPM Q (gpm) PRESS. (p$l) TOTAL Q 8.000 5.000 133 255.04 1,450 485.15 8.000 5.000 120 230.11 14,500 485.15 KILL SPM I PRESSURE 50 150 50 150 ···..···M.tt 2,442 2,505 2,568 2,631 2,692 2,754 2,816 2,880 2,944 3,007 .INCL.'· 9.70 10.60 11.70 12.80 13.90 15.30 16.90 17.80 18.90 19.70 COMPANY Marathon Inlet Drilling Alaska / .··SUFîVEypATA . . ····.t-V.tf t#'scuME:iWCÚ~$~ªT(~NM.j;·· 2,437.25 81.47 49.63 94.00 3,070 2,499.26 91.58 54.21 105.09 3,133 2,561.07 102.85 58.82 117.27 3,194 2,622.64 115.33 63.62 130.64 3,257 2,681.99 128.49 68.63 144.72 3,320 2,741.98 143.13 74.10 160.35 3,383 2,801.55 159.35 79.82 177.53 3,445 2,862.64 177.38 86.06 196.59 3,508 2,923.38 196.44 92.60 216.72 3,571 2,982.84 216.19 99.17 237.51 ···ÄZi. 25.60 23.20 21.40 20.70 21.00 20.00 18.90 19.30 18.60 18.20 I~CL.. 20.20 20.00 19.90 20.00 19.80 19.50 19.40 19.20 18.90 T.V.D. NIS CUM ElW CUM SECTION 3,042.06 236.65 105.76 258.96 3,101.22 257.28 112.34 280.56 3,158.56 277.10 118.70 301.33 3,217.78 297.59 125.20 322.77 3,277.02 318.05 131.60 344.16 3,336.35 338.20 138.16 365.30 3,394.81 357.64 145.08 385.94 3,454.27 377.15 152.38 406.75 3,513.82 396.43 159.53 427.31 17.50 17.90 17.70 17.50 17.20 18.90 20.30 20.70 20.00 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 M-I Drilling Fluids 18 216.00 Baker Hughes Inteq SERVICE SERVICE NO. 1 2 HOURS 24.00 48.00 Printed: 2/8/2002 2:36:41 PM ~~^NNl=n .1\ It 2 1 2004 ) ) ............ ...... ..... .... ....... ......... .....""0·.... ....." .. ............ .. . .... . '"' ...... . . '"' . . ........ .... . MARATHON OIL COMPANY Page 2 of 2 Daily Drilling Report IGL 124 HAS PAOG ITMD 66.00 1,200.0 3,661 WELL NAME KBU 44-6 KB 87.00 COMPANY Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY 3 36.00 IrvD IDFS 3,603 6 SERVICE I AEPT ~. ¡DATE 2/6/2002 NO. HOURS. SCANNED JUL 2 1 2004ed: 2/8/20022:36:41 PM ) ) WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS RIH. 24 HR FORECAST RIH. Drill ahead to CSG point. AELD NAME I STATElPROV Kenai Alaska OIL COMPANY Page 1 of 2 Drilling Report 124 HRS PROG TMD TVD IDFS 7 REPTNO. DATE 87.00 66.00 433.0 4,094 4,009 10 2/7/2002 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 46,515.00 555,486.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/4/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) ~,420.0 (ft) 19.32 24 HR SUMMARY: Drill to 4094' / Trip for washpipe and new bit OPERATIONS SUMMARY FROM TO HRS DEPTH' FM DEPTH TO SUB PHASE DESCRIPTION 06:00 06:30 0.50 3,661 3,661 DRLlN1 P.O.H. to shoe 06:30 10:30 4.00 3,661 3,661 DRLlN 1 Trouble shoot and repair #1 pump hydraulic fan and repair I Service rig and top drive 10:30 12:00 1.50 3,661 3,661 DRLlN1 R.I.H. to 3122' / tagged up on fill 12:00 13:00 1.00 3,661 3,661 DRLlN1 Wash/Ream from 3122' to 3661' 13:00 21:00 8.00 3,661 4,094 DRLlN1 Drill Open Hole (Directional) from 3661' to 4094' (blew out washpipe packing ) 21 :00 02:00 5.00 4,094 4,094 DRLlN1 P.O.H. to change packing and bit / (Tight hole 3110' to 2800' ) 02:00 03:30 1.50 4,094 4,094 DRLlN1 Change bits I RJ.H. to shoe 03:30 04:30 1.00 4,094 4,094 DRLlN 1 Change out wash pipe packing I Service rig and top drive 04:30 06:00 1.50 4,094 4,094 DRLlN1 Test MWD and R.I.H. DENSITY(ppg) I 9.20 'FV PVNP GELS 51 15/19 6114 I PP I WUHTHP 7.21 IECDI ¡MUD DATAl DAILY COST I FCrr.SOL OIUWAT %Sand/MBT' Ph/pM 2.0/5.0 /94 0.25/17.5 9.10/0.2 7,132.00 Pf/Mf 0.2/1.6 I CUM COST I 30,897.00 CI Ca H2S LIME ES 300 60 BITS BIT I RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN D~TEIN I-O-D-L-B-G-Q-R 2/1 12.250 Hughes MX-1C G19JP 15/18/18/18// 1,512.0 2/4/2002 2-2-NO-A-E- I-NO-RR 3/1 12.250 Hughes GTX-G3 R45DP 20/20/20//1 4,094.0 2/7/2002 0-0------ BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/1 12/12 75 175 518 2,000 269 6.55 433.0 66.11 26.55 2,582.0 97.25 3 BHA DESCRIPTION i' ;:: :':¡,;';¡Y'::::,:' ¡ >¡, ,/',,'/' ,", "'i ":" ,/ :¡:SliA"¡" ','" IPlbl<lJP¡\;SLAéKOF~ROT WT. TORQUE (maximin) IBHA HRS ¡JAR HRS MWD HRS MTR HRS IS8 HRS 39 110 80 I 93 8 / 5 Bit, 8" 1.2 DEG M-1C Motor ,12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (In) LINER (in) SPM Q (gpm) PRESS. (psi) TOTAL Q 8.000 5.000 135 258.88 2,000 517.76 8.000 5.000 135 258.88 2,000 517.76 KILL SPM I PRESSURE 60 310 60 300 3,633 3,696 3,758 3,821 3,572.41 3,631.80 3,690.24 3,749.72 SURVEY DATA NlS CUM E1w CUM SECTION M.D. 415.38 166.77 447.60 3,884 434.75 174.94 468.62 3,947 453.67 183.32 489.30 4,009 " 472.66 191.74 510.05 T;V;D. N/SCUI\II EJWëUMSÊCTION 3,809.29 491.46 199.93 530.55 3,868.98 509.98 207.87 550.69 3,927.76 528.14 215.57 570.40 2 1 LGG~ SC~NNEO JUl Printed: 2/8/2002 2:36:43 PM ) ) MARATHON OIL COMPANY Page 2 of; 2 Daily Drilling Report GL \24 HRS PROG ITMD 66.00 433.0 4,094 WELL NAME KBU 44-6 KB 87.00 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 rvD I DFS 4,009 7 SERVICE ..--.......-.....-.. SCANNED JUL 2 1 2004 I REPT NO. 10 -t' Printed: 2/8/2002 2:36:43 PM \ DATE 2/7/2002 NO. 2 3 -HÖURS 48.00 36.00 ) ) WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 4625'. 24 HR FORECAST Drill ahead. FIELD NAME Kenai TVD 4,514 I RIG NAME & NO. I RIG # AUTH MD AFE NO. AFE COST GLACIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.DRL 5,027,000 I MOC WI INRI DAIL V WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 50,279.00 605,765.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/412002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) @,420.0 (ft) 19.32 24 HR SUMMARY: Wash and ream to bottom @ 4091'. Drill 1/4095' to 4625'. DENSITY(ppg) I 9.10 I PP I : FV PVNP GELS WUHTHP 55 19/21 9117 7.81 FROM TO HRS 06:00 06:30 0.50 06:30 06:00 23.50 BIT I RUN 3/1 SIZE 12.250 BIT I RUN 3/1 BHA NO. LENGTH 3 857.02 BHA DESCRIPTION "NO. 1 2 OILWELL OILWELL Mol:>; .. 4,072 4,135 4,197 4,260 ,"INCLi 18.60 18.50 18.30 18.10 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids DEPTH FM DEPTH TO OPERATIONS SUMMARY SUB PHASE DESCRIPTION DRLlN1 Wash and ream 1/3940' to 4091'. DRLlN1 Dir drill and survey 114094' to 4625'(ART=14.0hrs AST=7hrs)(Very slow sliding. Intermittent excessive torque on bottom sometimes stalling motor and topdrive in rotary mode) 4,095 4,625 FClr.SOL 2.0/5.0 I ECD I I MUD DATAl DAILY COST OIUWAT %SandlMBT Ph/pM /95 0.25/25.0 9.1010.2 I CUM COST I 38,046.00 CI " Ca" H2S LIME 300 60 ES" 7,149.00 Pr/Mf 0.2/1.2 MANUF. Hughes TYPE GTX-G3 BITS SERIAL NO. JETS OR TFA R45DP 20/20/20111 I-O-D-L-B-G-O-R 0-0------ DEPTH IN DATE IN 4,094.0 2/7/2002 WOB 20 I 35 GPM 480 PRESS 1,850 HRS 21.00 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 531.0 25.29 21.00 531.0 25.29 PBIT 228 RPM 751 .. I ,. " I aHA.. ,. I I I I' I I EFF WT. I PICK UP .SLACK OF ROT WT. TORQUE (maximin) BHA HRS JAR HRS MWD HRS MTR HRS SS HRS 39 112 90 102 13 / 6 Bit, 8" 1.2 DEG M-1C Motor, 12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub "'AZ:I 21.80 21.80 21.00 21.00 PUMP} HYDRAULIC DATA STROKE ,(in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 5.000 135 258.88 2,200 8.000 5.000 118 226.28 2,200 '. ....... ....,'. ,',.,' ..".'.... ....',. ,...'..... .·..SÜRVEYDATÄ 't\dj;. ··.·,tW$CÙM,E1W:C.l)M¡~EêTIQN . "'M.D, " "," INCL 3,987.47 546.73 223.20 590.50 4,324 17.70 4,047.19 565.34 230.64 610.54 4,387 17.60 4,106.02 583.56 237.78 630.11 4,450 17.20 4,165.87 601.93 244.84 649.78 4,512 16.90 KILL SPM I PRESS,URE 60 220 60 220 TOTAL Q 485.16 485.16 MAKE OF PUMP AZI" 20.30 20.00 19.60 18.90 ,".. .. .' . ... .... .", "' ........... ......···""0· ... .... ...... . .. .... . ..... .... ... ....... ....:..:... ;;,: . ":." :....:, , '.. .... ........ ........... ,..., .. .......... ..,. " .., .. ..... .,.. , ., ,.... .... , , ... "lW~J:); '; .NI~ GUM, @ÇµM§~Ç"tïÔN,I 4,226.77 620.33 251.77 669.45 4,286.81 638.27 258.35 688.55 4,346.93 655.99 264.74 707.38 4,406.20 673.15 270.73 725.54 SERVICE PERS,ONNEL..DATA NO; HOURS COMPANy 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 SCANNED JUL 2 1 2004 Printed: 2/8/2002 2:36:45 PM ) ) OIL COMPANY Page 1 01"2 WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 4700'. 24 HR FORECAST Drill ahead to CSG point. FIELD NAME Kenai 124 HRS PROG TMD TVD I DFS 9 REPT NO. I DATE 75.0 4,700 4,587 12 2/9/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 MOCWI INRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 44,974.00 650,739.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/4/2002 I STATElPROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) @ 5,420.0 (ft) 19.32 ST OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling Report IGL 66.00 OP COMMENTS: Drill F/4625' to 4667'. CBU. POOH. C/O motor and bit. RIH. Drill F/4667' to 4700'. OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 13:00 7.00 4,625 4,667 DRLlN1 Dir drill and survey F/4625' to 4667' (AST =4hrs ART =1.67hrs)(Very difficult to slide. Intermittent excessive torque while drilling in rotary mode or reaming causing rotary and motor to stall) 13:00 14:00 1.00 4,667 4,667 DRLlN 1 CBU @ 4667'. 14:00 14:30 0.50 4,667 4,667 DRLlN1 POOH to 4120'. 14:30 16:30 2.00 4,667 4,667 DRLlN1 Pump out F/4120' to 3120'(tight trying to pull wlo pumps, pulled easiest wlpumps and no rotation). 16:30 18:30 2.00 4,667 4,667 DRLlN1 POOH F/3120 to 1509'. 18:30 19:30 1.00 4,667 4,667 DRLlN 1 Circ. shakers clean @ 1509'(large volumes of loose sand across shakers). 19:30 21:00 1.50 4,667 4,667 DRLlN1 Slug pipe. POOH. 21:00 23:00 2.00 4,667 4,667 DRLlN 1 B/O bit. UD motor(motor checked OK). Check MWD. P/U new motor and BIO motor stab. M/U bit#4. Orient MWD. 23:00 00:00 1.00 4,667 4,667 DRLlN1 RIH to 1500'. 00:00 00:30 0.50 4,667 4,667 DRLlN1 Test MWD and Motor. 00:30 01:00 0.50 4,667 4,667 DRLlN1 Service rig. 01:00 02:00 1.00 4,667 4,667 DRLlN1 Slip and cut drill line. 02:00 04:30 2.50 4,667 4,667 DRLlN 1 RIH(tight spot @ 3970'). 04:30 06:00 1.50 4,667 4,700 DRLlN 1 Dir drill and survey F/4667' to 4700'(ART=.3hrs AST=.5hrs) DENSITY(ppg) FV PVNP 53 15/15 9.00 I PP I GELS WUHTHP 8/17 7.61 FeIT.SOL 2.0/5.0 I EeDI I MUD DATAl DAILyeOST I OIUWAT %SandlMBT Ph/pM /95 0.10/17.5 8.5010.3 3,935.00 Pf/Mf 0.1/1.1 I CUM COST I 41,981.00 CI Ca H2S LIME 400 80 ES 3/1 12.250 Hughes GTX-G3 R45DP 20/20/2011/ 4,094.0 2(1/2002 4-2-WT-A-F- 1-SD-TQ 4/1 12.250 HTC MXC09D S83DR 18/18/18/15/1 4,667.0 2/8/2002 0-0------ BIT 1 RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP eUM HRS CUM DEPTH CUM ROP 3/1 20 / 35 75 175 480 1,850 228 5.67 42.0 7.41 26.67 573.0 21.48 4/1 15/15 75 175 470 2,000 217 0.80 33.0 41.25 0.80 33.0 41.25 BHA NO. LENGTH 4 857.02 BHA DESCRIPTION BHA EFF WT. PICK UP SLACK OFFROT WT. TORQUE (maximin) BHA HRS JAR HRS MWD HRS MTR HRS SS HRS 39 117 90 102 130 / 6 Bit, 8"M1C MOTOR 1.2AKO SLICK UBS ,12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub ...____,.,. ' NO. MAKE OF PUMP 1 OILWELL 2 OILWELL PUMP I HYDRAULIC DATA STROKE (in) LlNER(in) SPM a (gpm) PRESS;(psi) TOTAL Q 8.000 5.000 126 241.62 2,000 467.90 8.000 5.000 118 226.28 2,000 467.90 ,~ KILL SPM 'I. PRESSURE 60 250 60 250 SCANNED JUL 2, 1 2004 Printed: 2/9/2002 9:45:22 AM ') ) M.D. 4,576 INCL. 15.60 SURVEY DATA AZI T.V.D. NIS CUM EIW CUM SECTION M.D. 18.20 4,467.64 690.13 276.43 743.43 4,640 INCL. 15.30 AZI 17.90 T.V.D. NIS CUM EIW CUM SECTION. 4,529.33 706.34 281.71 760.44 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 SERVICE NO. 2 3 . HOURS .. 48.00 36.00 .-......_.........., ·"1' .---,...."'--.---...-...." .~ ~ SCANNED JUL 2 1 2004 Printed: 2/9/2002 9:45:22 AM WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 5300'. 24 HR FORECAST Drill to 5416'. Short trip. POOH. Run CSG. FIELD NAME I STATElPROV Kenai Alaska OP COMMENTS: Drill F/4700' to 5300'. i.=ROM TO, : HRS 06:00 12:00 6.00 DEPTH FM DEPTH-TO 4,700 5,300 :,DENSITY(ppg) I 9.20 I pp I ,:" FV, ,PVNP : ,GELS WL.lHTHP 50 15/14 7/16 8.9/ :ØIT f RlJN SIZE, , 4/1 12.250 BIT f RUN 4/1 MANUE HTC WOB 10/30 RPM 75 175 ) I MARATHON OIL COMPANY Daily"Drilling Report IGL 66.00 ') , , "Page:1 of 1::' 124HRSPROG TMD TVD IDFS REPTNO. DATE , 600.0 5,300 5,173 10 13 2/10/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 46,918.00 697,657.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/4/2002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 13.375 (in) @ 1,509.0 (ft) 9.625 (in) @ 5,420.0 (ft) 19.32 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OPERATIONS SUMMARY,' ' SUS" PHASE ' , DESCRIPTION:<:'::, DRLlN1 Dir drill and survey F/4700' to 5300'(ART=13.4 AST=5.4hrs)(could not get angle to drop w/o bottom stab). IEeD I MUD'DATAI'DAILY COST I FCrr.SOL, :OIUWAT' .:%San.cUMBT',' : Ph/pM. ' 2.0/6.0 /95 0.25/17.5 9.00/0.3 ::TYPE MXC09D BITS' . ','1', ': .' ."" "',. . . SERIAL NO. ' .. JETSOfl:TFA S83DR 18/18/18/15/1 4,202.00 PffMf 0.1/1.2 ,'. . .. . I CUM, COST. 46,183.00 ., ,(;1: :c~<~· H2S .". ::Li"ME'r "> ES,,· 400 80 . ' , . ,. . . . '" "':1. ..:, DEPTHIN DATE :IN" ::: ,,:; I~O~Ð~L..~S-G-()·R 4,667.0 2/8/2002 0-0------ 24Hr ROP CUM HRS CUM DEPTH CUM ROP 31.58 19.80 633.0 31.97 ~HÄ ~O:I L~~:O~:.' BHA DESCRIPTION IEFF;r.· :lpic~ 2r· SlAc; Of1RÖ;~:I;-~~~~ö;n) ·····1 ~HÂ.HRS ··..IJARHRS ··I"\'Í~HRSI M!R~RS·ISSHRS Bit, 8"M1C MOTOR 1.2AKO SLICK UBS, 12-1/8" String Stabilizer, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP I 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP, Cross-Over Sub ':,'NÖ. 1 2 OILWELL OIL WELL M.D. 4,640 4,705 4,768 4,829 4,892 4,928 4,955 4,990 INCL. 15.30 14.50 14.20 13.20 12.50 12.50 11.90 11.90 COMPANY Marathon Inlet Drilling Alaska _M-I Drilling Fluids MAKE; OF PUMP , AZI ' 17.90 17.50 18.20 18.60 19.60 19.30 19.60 20.30 ,T.V.p. 4,529.33 4,592.14 4,653.18 4,712.44 4,773.86 4,809.01 4,835.40 4,869.65 SERVICE GPM 465 PRESS 2,000 HRS 19.00 24Hr DIST 600.0 PSIT 217 "PUMP I HYDRAULIC DATA , 'STROkE:1 (111) :' LlN~R, (In.) SPM' , Q (gpm) P~ESS;'(p~i) 8.000 5.000 126 241.62 2,000 8.000 5.000 118 226.28 2,000 SURVEY DATA NlSCUM Eiw CUM .sECTION M.D.,' 706.34 281.71 760.44 5,018 722.26 286.80 777.12 5,050 737.12 291.58 792.70 5,081 750.83 296.14 807.12 5,116 764.07 300.72 821.12 5,144 771.42 303.32 828.91 5,179 776.80 305.22 834.61 5,207 783.58 307.68 841.82 5,242 ,INCL. 11.90 11.60 11.50 11.30 11.20 10.90 11.10 10.90 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 AZI 20.00 21.00 20.30 21.40 21.00 21 .40 21.80 22.10 .. , ,', ",... TOrAt: Q 467.90 467.90 ',KILLSPM /' P~I;S$U~~::':, 60 300 60 300 T.V.D. NfSCUJIJI ElW CUM ,SECTioN', 4,897.05 789.00 309.67 847.60 4,928.38 795.11 311.95 854.11 4,958.75 800.92 314.14 860.32 4,993.06 807.38 316.60 867.23 5,020.52 812.47 318.58 872.70 5,054.87 818.73 321.00 879.40 5,082.36 823.70 322.97 884.75 5,116.71 829.89 325.46 891.43 SERVICE NO. 2 3 HOURS 48.00 36.00 ......,.~_......_'-_..-..- .. ~ SCANNED JUL 2 1 2004 Printed: 2/10/2002 8:49:10 AM ) ) MARATHON Ol~ COMPANY Page 1 of 2 WELL NAME KSU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS POOH ~ 5000'. 24 HR FORECAST POOH. Run 9 5/8"CSG. FIELD NAME Kenai I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Sorough 13.375 (in) (â2 Daily Drilling Report ST I KB I GL 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE OH 87.00 66.00 151.0 5,451 5,322 11 14 2/11/2002 RIG NAME & NO. I RIG PHONE AUTH MD AFE NO. I AFE COST GLACIER DRILLING 1 907-283-1312 7,32<DD.02.06038.CAP.dRL 1,924,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 46,184.00 743,841.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/4/2002 2/4/2002 I NEXT CASING LEAKOFF PPG 1,509 (ft) 9.625 (in) (â2 5,420 (ft) 19.32 OP COMMENTS: Drill F/5300' to 5452'. W/R out to the CSG shoe. RIH. Circ. POOH. 22:30 23:30 1.00 5,451 23:30 00:30 1.00 5,451 00:30 02:30 2.00 5,451 02:30 05:00 2.50 5,451 05:00 06:00 1.00 5,451 5,451 AF DESCRIPTION DRLlN1 Dir drill and survey F/5300' to 5451'(ART=4.0). DRLlN1 Circ. shakers clean. DRLlN1 Pump out F/5451' to 5225'. SIR F/5225' to 5195'. Pump out F/5195'-5095'. SIR 5095' to 5070'. Pump out F/5070' to 4911'. SIR F/4911' to 4881'. Pump out F/4881, to 4820'. SIR 4820' t04761'. Pump out 4761' to 4699'. SIR 4699' to 4376'(had to SIR very slowly hole very tight). Pump out 4376' to 4345'. SIR out F/4345' to 4312'. Pump out F/4312' to 4281'. SIR F/4281, to 4061'. Pump out 4061' to 1509. DRLlN1 Circ. shakers clean(large amount of angular shale with some coal and mud cake across shakers). 5,451 AF DRLlN1 Service rig. 5,451 AF DRLlN1 RIH to 5452'(wash and ream F/5391' to 5452'). 5,451 AF DRLlN1 Circ. and condition mud. 5,451 AF DRLlN1 POOH(5000'@06:00hrs). ECD I I MUD DATAl DAILYCOST I OILIWAT o/aSandlMBT PhlpM 193 0.40/18.8 9/0.3 OPERATIONS SUMMARY PHASE FROM TO HRS "DEPTH FM DEPTH TO SUB 06:00 10:30 4.50 5,300 5,451 AF 10:30 12:30 2.00 5,451 5,452 AF 12:30 22:30 10.00 5,451 5,451 AF DENSITY(ppg) FV PVIYP 78 26/29 9.50 I pp I GELS WLlHTHP 11/24 6.01 FCfT .SOL 2.0/8.5 6,800.00 PflMf I CUM COST I CI Ca 400 80 52,983.00 H2S LIME ES 0.1/1.2 BITS BIT I RUN SIZE MANUF. TYPE SERIAL NO. JETS·OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 4/1 12.250 HTC MXC09D S83DR 18/18/18/1511 4,667.0 2/8/2002 0-0------ BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr ClST 24Hr Rap CUM HRS CUM DEPTH CUM Rap 4/1 5/25 75 I 75 483 2,000 242 4.00 151.0 37.75 23.80 784.0 32.94 BHA NO. I LENGTH 4 857.02 BHA DESCRIPTION BHA I EFF WT. I PICK UP I SLACK OF~ ROT WT. [TORQUE (maximin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS 39 128 95 I 113 6 I 8 Sit 8"M1C MOTOR 1.2AKO SLICK USS 12-1/8" String Stabilizer MWD Tool, Hang-Off Sub Cross-Over Sub, 4 JTS 5" HWDP ,6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub NO. 1 2 MAKE OF PUMP PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) PRESS. (psi) 8.000 5.000 126 241.62 2,000 8.000 5.000 118 226.28 2,000 TOTAL Q 467.90 467.90 KILL SPM I PRESSURE 60 300 60 300 OILWELL OILWELL MD INCL 5,271 10.60 5,306 10.50 5,145.20 5,179.61 SURVEY DATA N/SCUM EfW CUM DOGLE~ MD 834.87 327.57 1.03 5,333 840.81 329.99 0.29 5,399 N/$CUM ElWCUM DO<3LEG 845.32 331.85 0.88 856.02 336.39 0.47 ~. --~..- ....-- .-~-' COMPANY Marathon SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Inlet Drilling Alaska "~ SERVICE POS @06:0Q: NO. HOURS 18 216.00 Printed: 2/11/2002 11:10:36 AM SCANNED JUL. 2 1. 2004 ) ) WELL NAME KBU 44-6 COMPANY M-I Drilling Fluids Baker Hughes Inteq SERVICE LAST BOP TEST: 2/4/2002 SIZE (in) ID (in) LOT (ppg) 13.375 12.415 19.32 MARATHON OIL COMPANY Page 2 of 2 Daily Drilling Report I GL 124 HRS PROG 66.00 151.0 1ST IKB OH 87.00 ITMD 5,451 PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Epoch Well Services 2 48.00 MD (ft) 1,509 CASING SUMMARY LAST CASING TEST: 2/5/2002 TVD (ft) WT (Ib/ft) 1,507 68 ITVD I DFS 5,322 11 SERVICE NEXT BOP TEST: GRADE L-80 I REPT NO. I DATE 14 2/11/2002 POB @·06:00: NO. . HOURS 3 36.00 2/11/2002 BURST (psi) Printed: 2/11/2002 11:10:36 AM SCANNED JUL 2 1 2004 ST ATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 13.375 (in) @ WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Running 9 5/8" CSG. 24 HR FORECAST Run 9 5/8"CSG and cement. FIELD NAME I Kenai ) ) ,Page toft· 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE 5,451 5,322 12 15 2/12/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 7,3200D.02.06038.CAP.QRL 1,924,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%) 42,604.00 786,445.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/412002 I NEXT CASING LEAKOFF PPG 1,509 (ft) 9.625 (in) (Q2 5,420 eft) 19.32 ST OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: POOH. cIa to 9 5/8" CSG rams and test door seals. RlU CSG tools. Run 9 5/8" CSG. OPERATIONS SUMMARY PHASE' DESCRIPTION DRLlN1 POOH(SLM)(bit and stab very balled up with clay). LID motor. CSGIN1 Pull wear bushing. CSGIN1 C/O variable rams to 9 5/8" rams. CSGIN1 Install test plug. Test door seals to 1500psi. Pull test plug and RID test joint. cSGIN1 RlU Weatherford CSG tools. CSGIN1 PJSM prior to running CSG. CSGIN1 M/U Vetco 135/8" X 95/8" CSG hanger to the 9 5/8" landing joint. LID hanger assy. AF CSGIN1 RlU Weatherford CSG spiders. AF CSGIN1 Modify Weatherford equipment. AF CSGIN1 P/U and Baker lok shoe tract{two shoe joints). Test floats. AF CSGIN1 Run 3 joints 9 5/8" CSG. AF CSGIN1 PJSM with crew coming on. Run 9 5/8" CSG to 2800'{loosing some returns ove' last hour)üoints run 69 out of 132). AF CSGIN1 CBU{displace 9.6ppg mud in csg annulus with 9.3ppg from pits). fROM TO HRS DEPTH FM DEPTH TO SUB 06:00 '12:30 6.50 AF 12:30 13:00 0.50 AF 13:00 15:00 2.00 AF 15:00 16:00 1.00 AF 16:00 19:00 3.00 AF 19:00 19:30 0.50 AF 19:30 20:00 0.50 AF 20:00 20:30 0.50 20:30 22:00 1.50 22:00 23:00 1.00 23:00 23:30 0.50 23:30 05:00 5.50 05:00 06:00 1.00 DENSITY{ppg) 9.30 I PP I FV 'PVNP GELS. Wl/HTHP 68 20/22 9120 5.81 BIT I RUN SIZE MANUF~ 4/1 12.250 HTC BIT / RUN WOB RPM FCIT .SOL 2.0/8.5 I ECD I I MUD DATAl DAILYCOST I OILJWAT %Sand/MBT. Ph/pM 193 0.05118.8 9/0.3 ES I CUM COST I 59,783.00 CI Ca. . H2S' LIME 400 80 6,800.00 Pf/Mf 0.1/1.2 BITS TYPE SERIAL NO. JETS OR TFA ' DEPTH IN DATE IN I-O·D-L·B~G·O·R MXC09D S83DR 18/18/18/15// 4,667.0 2/8/2002 1-1-WT-Ä-E-I-BU-TD GPM I PRESS I P BIT HRS I 24Hr DlST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM Rap '>::BHA' .EFFwr ·'lplq~:l.JF=' ··ISÏ-A¢KOF'~OTW:r;1 TqR.QqE(¡åXÎmin)IBHAH8$'IJ.A~HR~ ··Ifv1W[)HRS'IM"tRH~$I$SHI3S·· Bit, 8"M1C MOTOR 1.2AKO SLICK UBS , 12-1/8" String Stabilizer. MWD Tool, Hang-Off Sub. Cross-Over Sub. 4 JTS 5" HWDP , 6-114" HYD Drilling Jar, 21 JTS 5" HWDP . Cross-Over Sub E38~Z6;···lh~~~62 BHA DESCRIPTION PERSONNEL DATA POB @ 06:00: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Marathon 1 24.00 Baker Hughes Inteq 2 48.00 Inlet Drilling Alaska 18 216.00 Epoch Well Services 3 36.00 M-I Drilling Fluids 1 24.00 CASING SUMMARY LAST BOP TEST: 2/4/2002 LAST CASING TEST: 2/5/2002 NEXT BOP TEST: 2/11/2002 SIZE (in) ID (in) LOT (ppg) MD{ft) TVD eft) WT (Ibltt) '. ·GRA8E . BURST (psi) 13.375 12.415 19.32 1,509 1,507 68 b--80 Printed: 2/12/2002 9:39:51 AM SCANNED JUL 2 1 2004 ) ') WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS NID BOP. 24 HR FORECAST NID N/U BOP. Test BOPE. FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 IGL 66.00 124 HRS PROG ITMD TVD DFS REPT NO. DATE 5,451 5,322 13 16 2/13/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 7,32(l)D.02.06038.CAP.QRL 1,924,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%J 245,830.00 1,042,275.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/412002 1 NEXT CASING LEAKOFF PPG 5,437 (ft) 3.500 (in) ~ 7,320 (ft) P/U 8.5" BHA. RIH. Drill out. LOT 1ST ATE/PROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) ~ OP COMMENTS: Run CSG. Attempt to stop lost circulation. Cement CSG. FROM TO HRS DEPTH FM DEPTH TO SUB 06:00 08:00 2.00 AF 08:00 08:30 0.50 AF 08:30 11:30 3.00 AF 11:30 12:30 1.00 AF OPERATIONS SUMMARY PHASE 01:00 02:30 1.50 AF CSGIN1 DESCRIPTION . Cont. RIH w/9 5/8" CSG to 4310'(very little returns @ 4310'). Partial returns circulating @ 5BPM. Cont. RIH. P/U vetco 135/8" X 95/8" hanger assy w/landing joint. Land hanger w/130k down wt. CSG shoe @ 5437' float collar @ 5351 '(total 132Jnts 9 5/8" 40PPF L-80 Butt CSG). Attempt to circ. without success. Mix 60BBL LCM pill(36#/BBL Med, 12#/BBL Course Safecarb). Mix 400bbls 8.9ppg mud. Pump pill and chase w/250bbls mud (no returns). Mix 200bbls 8.9ppg mud. PJSM prior to cementing. Pump 2bbls water ahead. Test BJ lines to 3500psi. Mix and pump 40bbls 10ppg spacer. Drop bottom plug. Mix and pump 93sxs "G" cement w/.4%CD-32, 5#/sx Kol seal, 18% LW-6, 20% MPA-1, .1% ASA-301, .2% R-3, 19/100sxs FP-6L, and 10.72g/sxs fresh water to yield 42bbls 12.0ppg slurry. Tail in with 515sxs "G" cement w/10%BA-90, 2% CaCI2, 2.5% BA-56, .1 % ASA-301, 19/sxs FP-6L, .5% SMS and 9.25g/sxs fresh water to yield 168bbls 13.5ppg slurry. Drop top plug and chase out of the head w/10bbls from the BJ unit. Switch to the rig mud pumps and displace w/396bbls 8.9ppg mud. Bump plug w/1200psi, 500psi over displacement pressure. Very good lift pressures but no returns to surface during the entire job. Displaced cement @ 4BPM due to losses. CIP @ 02:30hr. Release pressure floats held OK. RID BJ head. LID landing joint. Install and test 9 5/8" pack-off to 3000psi/10min. N/D BOP. CSGIN1 CSGIN1 CSGIN1 CSGIN1 12:30 13:00 0.50 AF CSGIN1 13:00 17:30 4.50 AF CSGIN1 17:30 19:00 1.50 AF CSGIN1 19:00 22:30 3.50 AF CSGIN1 22:30 23:00 0.50 AF CSG I N 1 23:00 01:00 2.00 AF CSGIN1 02:30 05:00 2.50 05:00 06:00 1.00 DENSITY(ppg) 8.90 I PP I FV PVfYP GELS WLlHTHP 57 13/8 419 8.3/ AF AF CSGIN1 CSGIN1 I ECD I I MUD DATAl DAILY COST I FCIT.SOL OILIWAT %Sand/MBT Ph/pM 2.0/4.0 /96 /12.5 9/0.7 11,602.00 PflMf 0.1/0.8 I CUM COST I CI Ca 400 40 71,385.00 H2S LIME ES PERSONNEL DATA POB @ 06:00: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Marathon 1 24.00 Epoch Well Services 3 36.00 Inlet Drilling Alaska 18 216.00 Vetco 1 12.00 M-I Drilling Fluids 1 24.00 Weatherford Completion 8 32.00 Baker Hughes Inteq 2 48.00 BJ Services 4 40.00 LAST BOP TEST: SIZE (in) 13.375 9.625 2/4/2002 ID (in) LOT(ppç¡) 12.415 19.32 8.835 MD· (ft) 1,509 5,437 CASING··SUM~Aß'V.:.. . LAST CASING TEST: 2/5/2002 -.....---. --"NEXT BOP TEST: TVD(ft) WT (Ib/ft) "'I' GRADE 1,507 68 L-80 5,309 40 L-80 2/11/2002 BURST(psi) 5,750 Printed: 2/13/2002 9:43:56 AM SCANNED JUL 2 1 in04 ) ) MARATHON OIL COMPANY 'P~g'e 1:of2:.· WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Displace hole to new mud. 24 HR FORECAST Perfor LOT. Drill·ahead. FIELD NAME Kenai ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 D~ily Drilling Report IGL 66.00 124 HRS PROG TMD TVD DFS REPT NO. I DATE 20.0 5,471 5,342 14 17 2/14/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 44,271.00 1,087,641.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) I STATElPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: N/D BOP. Drop out single gate. N/U BOP and test BOPE. P/U 8.5" bit and BHA. RIH. Test CSG. Drill out shoe tract. Drill 20' new hole. CBU. Displace hole to new mud. . ,. . . . , . . . ,:OPERATIONS SUMMARY .. . FROM TO HRS DEPTMFM DEPTH TO SUB· '. 'PHAS~ ·DESCRIPTION:. ... . ."' . 06:00 07:00 1.00 DRLPRO N/D BOP. N/D 135/8" 5K single ram. 07:00 15:00 8.00 DRLPRO N/U BOP. CIO 9 5/8" CSG rams to 2 7/8" X 51/2" variable rams. 15:00 18:30 3.50 DRLPRO M/U 4" test joint and test plug. Land test plug. Test annular, upper variable rams, upper and lower TO valves, IBOP, TIW, choke line HCR valve, choke line manual valve. Inside and outside kill line valves, 12-choke manifold valves and blind rams to 250/3000psi 5min. Perform accumulator test. Pull test plug. Install wear bushing. 18:30 20:30 2.00 DRLPRO P/U 8.5" PDC bit and directional assy. 20:30 21:00 0.50 DRLPRO Test Motor and MWD. 21:00 22:00 1.00 DRLPRO P/U 26jnts 4" DP while RIH. 22:00 00:00 2.00 DRLPRO Cont. RIH to to 3562'. Fill DP and blow down lines. 00:00 00:30 0.50 DRLPRO Service rig. 00:30 01:00 0.50 DRLPRO Test 9 5/8" CSG to 2500psi/30min. 01:00 02:00 1.00 DRLPRO Cont. RIH. 02:00 02:30 0.50 DRLPRO Wash F/5200' to 5351' 02:30 03:30 1.00 DRLPRO Drill float collar @ 5351'. Drill shoe tract and shoe to 5437'. Clean old hole to 5451' 03:30 04:00 0.50 5,451 5,471 DRLPRO Drill 8.5" hole F/5451, to 5471'(ART.3hrs). 04:00 05:30 1.50 DRLPRO Circ.shakers clean @ 5471'. 05:30 06:00 0.50 DRLPRO Displace hole to flopro mud. DENSITY(ppg) FV . ÞVIYP 63 7/18 8.90 I pp I GELS WUHTHP 9/12 9.51 JECD IMOODATAI DAILYCOST FCIT.SOL : OIUWAT . %Sand/MBT Ph/pM 1.014.0 196 11.8 12.00/2.0 2,840.00 pf/Mf . 0.4/1.5 I'CUM,COST I 74,225.00 CI . ·Ca H2S LIME 21,000 440 .ES:: BITS, .. ::"V'" BIT f RUN SIZE MANUF. TYPE SERIAL NO. 'JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-Q-R 5/1 8.500 HTC DP0622 7100095 12/12/12/12/12/12 5,451.0 2/13/2002 0-0------ BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 5 11 2/5 75 I 75 441 2,000 267 0.30 20.0 66.67 0.30 20.0 66.67 BHA NO LENGTH 5 857.11 BHA DESCRIPTION BHA EFF WT. PICK UP I SLACK OFFROT wr. TORQUE (maximin) 37 137 95 115 70 I 5 Bit, 63/4" Motor w/.8AKO 8 3/8"UBHS , 8 3/8" Stab, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub, 4" 14PPF S-135 DP BHA HRS JAR HRS MWD HRS MTR HRS SS HRS NO. 1 2 MAKE OF PUMP ÞUMPIHVDRÄULICDÀTA STROKE (in) LINER (in) SPM Q (gpm) 8.000 5.000 115 220.52 8.000 5.000 115 220.52 OILWELL OILWELL PRESS. (psi) TOTAL Q 2,000 441.04 2,000 441.04 KILL SPM I PRESSURE SCANNFI) JUL ? 1 2004 Printed: 2/14/2002 6:52:50 AM WELL NAME KB U 44-6 COMPANY Marathon Inlet Drilling Alaska M- Drilling Fluids Baker Hughes Inteq SERVICE ') MARATHÖN:OIL COMPANY 1sT IKB OH 87.00 . Daily Drilling Report GL 66.00 TMD 5,471 124 HRS PROG 20.0 ·PERSONNEL. DATA · ,·NO. . ·iioÚÄs: :... ..... '. COMPANY 1 24.00 Epoch Well Services 18 216.00 Vetco 1 24.00 Weatherford Completion 2 48.00 BJ Services SCANNED JUL 2 1 2004 ) TVD I DFS 5,342 14 SERVICE' . .";" . . . . . . . Page':2' of::2<. . .. ... . " . .'. .. . . . I REPT ~~. ., ~~~:/2002 . . ", . . N~L. ..... i-tb.úfis'!i:::, 4 48.00 1 12.00 1 5.00 4 24.00 Printed: 2/14/2002 6:52:50 AM WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS RIH 24 HR FORECAST RIH. Drill ahead. FIELD NAME Kenai ) i ) MARATHON· OIL .COMPANY. . . . . . ... . .. . . . . . . ' . ..' . . . .. . . . .. . ...Pag~.· fof t ,"., , ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 DaHy Drilling. Report IGL 66.00 . ,". 1ST A TE/PROV Alaska 124 HRS PROG TMD TVD DFS REPT NO. I DATE 5,471 5,342 15 18 2/15/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 79,850.00 1,167,491.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 I COUNTY/OTHER I LAST CASING Kenai Borough 9.625 (in) @ DEPTH,FM .DEPTHf6' SUB 5,471 5,676 5,676 5,676 5,676 5,676 5,676 5,676 5,676 5,676 5,676, 5,676 i en" RON: 5/1 6/1 ,. II ., . SIZE' ,::.':' ··MAN'UF.: 8.500 HTC 8.500 HTC . ,;~l"YPE" DP0622 MX-RS18DD WOB 4/35 RPM 75 / 75 GPM 441 OP COMMENTS: Displace to flopro mud. Perform LOT. Drill F/5471' to 5676. POOH. cIa bit and increase AKO to 1.0. RIH. FROM 06:00 07:30 08:30 22:00 23:00 03:00 04:30 05:30 TO: .HRS 07:30 1.50 08:30 1.00 22:00 13.50 23:00 1.00 03:00 4.00 04:30 1.50 05:30 1.00 06:00 0.50 OPERATIONS SUMMARY' . . ""''''''''''''''.. ' . ",,,. , , ., ... PI:t~SE: DRLPRODisplace hole to flopro mud. DRLPRO Perform LOT to 16.2ppg EMW(1899psi, 9.3ppg MW). DRLPRO Dir drill and survey F/5471' to 5676(ART = 3.81 hrs, AST =5.16hrs). DRLPRO CBU. Pump dry job. DRLPRO POOH. DRLPRO C/O bit. Increase AKO of motor to 1.0. Check MWD and orient. DRLPRO RIH w/BHA. Test motor and MWD DRLPRO Cant. RIH. .". .. .. DE~CRIPTld(\.f:·' .' . :' r "I: : DENSITY(ppg). I 9.40 PP: I I ~CD I I MOD DATA:DAILYCOST I 18,552.00 FV. PVNþ GELS.. WUHTHP,. ·.FCfT;SOL. . 'OII./VVAT:· o/oS~~dIMEt(i ..' 'Ph/pM" ..": :Pf/Mf:'/ 48 10/31 12/16 7.0/ 1.0/8.0 192 0.10/2.5 10.0010.7 0.5/4.8 BIT I RUN 5 11 1"culVI'cos-r:! .. 92,777.00 Cf ::" ·"Ca:..:: "'H~S": ::L'M~ ·:·~S\ 31,000 320 ,; ,',;:.:..' BIT~', . r " ' ',." .. .. .' . SERIAL NO. ; . .~ETS:OR;TF~'. ..::··:6~PTti.iN¡;DATE'JN::. >:';:::I~å~~L,"~~ö~å~R""'" 7100095 12/12/12/12/12/12 5,451.0 2/13/2002 O-O-NO-A-D- I-NO-BHA V50DF 18/18/18111 5,676.0 2/15/2002 0-0------ PRESS 1,600 PBIT 282 HRS 8.96 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 205.0 22.88 9.26 225.0 24.30 sHANd, .LENGTH 6 857.11 BHA DESCRIPTION .'" '.. 'sHA' . . " EFFwrIPIÓKUp· ISlA';KOF1R~iwr·I~ORQÚe(~min)·· .. aHAHflSJAR HRSMWO HRS MTR HRSSSHR$ Bit, 6 3/4" motor w/1.0AKO 8 3/8" UBHS , 8 3/8" Stab, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub, 4" 14PPF S-135 DP ,: . NO. 1 2 OILWELL OIL WELL MAKE' 01= PUMP PUMP I HYDRAULIC. DATA ' STROKE (in) . LINER (in) . SPM .....Q (gpm) PRESS. (psi) 8.000 5.000 110 210.94 1,600 8.000 5.000 110 210.94 1,600 TOTAL:Q:· KILL SPM r PRf;SSURE' . 421.88 60 320 421.88 60 320 SURVEY DATA M.D. .INCL. AZI T.V.D. NIS CUM EJW CUM SECTION ·M;D. INCL. AZI T.V.D. NIS CUM E/W CUM SECTION 5,459 9.40 22.50 5,330.28 865.34 340.32 929.85 5,554 9.10 20.30 5,424.03 879.59 345.95 945.18 5,491 9.40 22.50 5,361.85 870.17 342.32 935.08 5,586 9.00 20.30 5,455.63 884.31 347.69 950.21 5,523 9.20 20.70 5,393.43 874.97 344.22 940.25 5,618 8.70 19.60 5,487.25 888.94 349.37 955.13 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE ,~~~~-~".~.'.''". PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 SCANNED jllL 2. 120M SERVICE NO. HOURS 2 48.00 4 48.00 Printed: 2/15/2002 6:42:04 AM ... . . . . 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 6,500 6,368 16 19 2/16/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 47,652.00 1,216,343.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None V1V2002 V1~2002 I STATE/PROV I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Alaska Kenai Borough 9.625 (in) @ 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 ) . . '.. MARATHON Oll.COMPANY WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 6500'. 24 HR FORECAST Short trip. Drill to TD. FIELD NAME Kenai "t>al"ly Dri'lIing Repo'rt": . GL 66.00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 OP COMMENTS: RIH. Drill F/5676' to 6500'. ) . . . . . . ....·'·:·:.:,Page:-:-1· ot':1 . '. .' '. ·.'1 ',' I " ':'::()~i:RATrøN$ SUMIVIA~)'·· :': FROM TO : HRS.. . 'DEPTH FM :DE~tHTÖ " : ,:-:SUB:·· . PHAS,~.· . . , '.' 06:00 07:30 1.50 DRLPRO Test MWD. RIH. 07:30 06:00 22.50 5,676 6,500 DRLPRO Dir drill and survey F/5676' to 6500'(ART =11.8hrs AST = 5.1 hrs). );)ENSITY(ppg).1 9.60 I:pp, . :FV .'. PVNP:·. G.E~S WuHT~P 49 11/33 1V18 6.8/ I ~c"r;». I MUD DATAI'DAILY CO~T I FOrt.SOL:" OILIWAT:.' . o/~~ntVMBT"; . ..' Pf¡lPI\,1 '. .' 1.0/8.0 /92 0.10/3.1 9.00/0.3 BITIRUN 6 11 8.500 . ,',', , . . .. . ." . I ,:' ' '~'" I:' " MANlJE' HTC BITS,:, .':. ,...... S·EFtIALNO..:. "': J(~TS 'OFï TFA. V50DF 1~1~18m .:TYPE· MX-RS18DD BIT l RUN 6/1 GPM 440 PRESS 2,100 HRS 16.90 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 824.0 48.76 16.90 824.0 48.76 PBIT 308 WOB 15/30 RPM 75 I 75 , " ," "1"-'· .... . . . . ... ·:DEŠCRIPfïöN.'., :"., 6,201.00 I :-;COM c?sy.::1 98,978.00 . PflMf:' '. '. ::Ci'.:,..: :', ,·.'Ca-"· ...)i2S· LiME "'::'~$'/ 0.3/6.8 31,000 240 " :- .'".: I,. :' .. ....:. .,," :. ':,:.. :"".. . DEPTtiIN-:ÐÅT.E· ,~. ...... ··:.:i-~~:D~L'B"G~çÄ~:. ::. :.,' 5,676.0 2/15/2002 0-0------ ". .1··:. .' ': BHA ~Ò.:· '::I:L~;~1~ BHA DESCRIPTION I ËFF:: "I pkn:" '"I~~::~~1Å()~=: ·1~6~~;~ir;n)":IBÄA~ÅS:P:~'i1ÅSIMW¿H~i'·IMJ'F!fiÅSI ~$H~~,:H. Bit, 6 3/4" motor w/1.0AKO 8 3/8" UBHS , 8 3/8" Stab, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub, 4" 14PPF S-135 DP '.·NO. . 1 2 . . .". . . ". , . " I' .' ,', '," . ," . ,tJiA~E' OF'ÞUMÞ' .:,.: , " PUMPIHyDRAOLI¢[)ATA',. ... STROK'e (In) :,: LINER' (In): ,::;: SPM'¡" ':IQlgpi'n)' PRESS: (psi) ,·....OTAL. a:·: 'I 8.000 5.000 115 220.52 2,000 441.04 8.000 5.000 115 220.52 2,100 441.04 :. K.ILL:~ÞM.;: I ' ·~~.Ë.S~lJ~~· :, 60 460 60 460 OIL WELL OILWELL SURVEY DATA I.. I' l\V.D. r I I . . I . "". I I . . M.D. . ·INCL.. AZI . NlS :CUM E/W CUM SECTION M:D. . 'INCL;: , "! . I 5,647 8.10 20.70 5,515.94 892.92 350.83 959.36 6,084 1.00 5,710 7.30 21.40 5,578.37 900.79 353.86 967.80 6,151 0.90 5,773 5.90 22.80 5,640.95 907.51 356.58 975.04 6,211 0.80 5,836 3.40 27.70 5,703.74 912.15 358.70 980.14 6,274 0.50 5,899 2.10 19.60 5,766.67 914.89 359.96 983.15 6,337 0.40 5,961 1.90 21.40 5,828.63 916.92 360.71 985.31 6,400 0.40 6,023 1.10 35.80 5,890.61 918.35 361.44 986.92 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 24.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 1 24.00 SCANNED JUL 2 1 200~ , .' . "I' AZI "'T,V~D;':';" ~s CUIVI' EIW;CUM 'SE;GTIQN::: 49.50 5,951.60 919.18 362.18 987.96 68.30 6,018.59 919.75 363.12 988.83 64.30 6,078.58 920.11 363.93 989.46 78.70 6,141.58 920.35 364.60 989.94 10.90 6,204.58 920.62 364.91 990.30 75.40 6,267.58 920.89 365.16 990.65 SERVICE NO. 2 4 HOURS 48.00 48.00 Printed: 2/16/2002 12:27: 18 PM ) MARATHON· Oil COMPANY Daily. Drilli.ng RepQrt. IGL 66.00 ') . . page 1. .pt: t . WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 7130. 24 HR FORECAST Drill ahead to TD. Wiper trip. POOH. R/U Loggers. Log. FIELD NAME I STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 9.625 (in) @ .. . . .. . . . . . .. .. . . . . . . . . ,. ... . ... . .. .. . . . . . . . . . . . . . TMD TVD I DFS REPT NO. I DATE 7,130 6,998 17 20 2/17/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 1 MaC WI 1 NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 49,820.00 1,266,163.00 1 ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG OP COMMENTS: Drill F/6500' to 6519'. CBU X 2. POOH to CSG shoe. CBU. Service rig. RIH. Drill F/6519' to 7130'. . Q~I:RATIONS'SUMMARY . ,...:;.;:::...... :.:.....:.....,..; .' PHASE ·DES·CRIPTI.QN. :.'. DRLPRO Dir drill and survey F/6500' to 6519'(ART=.5 AST=O) DRLPRO CBU X 2 @ 6519'. DRLPRO POOH(pull first two stands to 6391', due to tight hole SIR to csg shoe). DRLPRO CBU @ 5437'. DRLPRO Service Rig DRLPRO RIH. DRLPRO Dir drill and survey F/6519' to 7130(ART=14.03 AST=O). I eCD I I MÜO"[)ATA II, DAIL'(CaST I ~Crr:SOL' 'OILJWAT I ·"':::%Sand/Nl~T:··· '>':Ph/pM' 1.0/8.0 192 0.10/3.8 9.50/0.3 : . .:..aIT~il .... .' '~ERfA!-; NO~:. :,:::, JET,SOR Tp'A V50DF 1W1W18m .. . . . TO . . '..SUB: FROM . HRS': DEPTH FM' DEPTH TO 06:00 06:30 0.50 6,500 6,519 06:30 08:00 1.50 6,519 6,519 08:00 10:30 2.50 6,519 6,519 10:30 11:30 1.00 6,519 6,519 11:30 12:00 0.50 6,519 6,519 12:00 13:00 1.00 6,519 6,519 13:00 06:00 17.00 6,519 7,130 'DENSITY(PP9)" I 9.70 .PP· FV '.' ·,pviyP GeLS ..WUHTHP 48 12/30 13/22 7.2/ :BIT i RUN . 6/1 SIZE'" 8.500 IVIANUF.. .' HTC ·:TY.F':E MX-RS18DD BIT I RUN 6 11 RPM 75 I 75 GPM 440 WOB 20 I 30 PRESS 2,200 PBIT 311 HRS 14.53 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 630.0 43.36 31.43 1,454.0 46.26 11,000.00 Pl/Mf:.· 0.3/4.4 I..:CUM qÓST: I 109,978.00 'CI' :'. . 'Cå·; ·..2S :.. :L(ME: : ES;l: 31,000 320 ,': .: ':DËPTHI~'·':DAtE:¡N!'::' 5,676.0 2/15/2002 ., . !.;::. I~Ø-Q-L~!=J;'G~º-~::':.:; '.' 0-0------ ~HA NQ.'. I· LENGTH 6 857.11 BHA DESCRIPTION . . .. . . .. , ~, .. '.. '..: '. ':::,BHA:¡ . '.. .... ',.' "." j EFF:;; :I'ÞIÇ~~;,>' rs~~~ OF1RO~':r" : ITÔRÖUE~7~Xlrhin)::' 13HJ\'HRS ·I·JAR'HRS. ·1 Mwb HRS I MTR :H~S $S;:HRst:::~ Bit, 6 3/4" motor w/1.0AKO 8 3/8" UBHS , 83/8" Stab, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP . 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP, Cross-Over Sub, 4" 14PPF S-135 DP NO. . 1 2 PUMPI HYDRAULIC DATA . STROKE (in) LINEFHi.n) SPM . Q t~PI'n).. .PRESS. (psi) . 8.000 5.000 115 220.52 2,200 8.000 5.000 118 226.28 2,200 TOTAL'Q 446.80 446.80 KILL SPM I PRESSURE.":. 60 500 60 480 MAKE OF PUMP. OILWELL OILWELL M.D. 6,465 6,529 6,592 6,653 6,716 INCL. . 0.40 0.20 0.20 0.40 0.30 AZI· 52.70 299.10 103.00 14.00 307.20 SURVEY DATA T;V.D. NlS CUM EIW CUM SEÇTION·· . M.D. 6,332.58 921.09 365.56 990.98 6,781 6,396.57 921.28 365.64 991.18 6,845 6,459.57 921.30 365.65 991.21 6,909 6,520.57 921.49 365.81 991.44 6,972 6,583.57 921.80 365.73 991.70 7,035 INCL. 0.30 0.20 0.40 0.20 0.60 COMPANY Marathon .Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 3 48.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 3 72.00 AZI 267.80 9.10 227.80 303.70 231.60 T.V.D. . N/S' CUM EIW CUM SEQTION' 6,648.57 921.90 365.43 991.68 6,712.57 922.00 365.28 991.72 6,776.57 921.96 365.13 991.63 6,839.57 921.87 364.87 991.46 6,902.57 921.73 364.52 991.19 SERVICE NO. I HOURS --.--. 2 48.00 4 48.00 SCANNED JUL 2 1 2004 Printed: 2/18/2002 6:48:56 A.M WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS POOH @ 6950'. 24 HR FORECAST POOH. Run logs. FIELD NAME Kenai ) RIH. UD DP. 1ST A TElPROV Alaska ) .MARA THONOIL COMPANY· . Page:,Lof."1· Daily Drill.ing Report ..' IGL 66.00 .. .. . . . 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 310.0 7,440 7,308 18 21 2/18/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00(%) 92.20(%) 53,409.00 1,319,572.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/12/2002 2/1312002 I COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF PPG Kenai Borough 9.625 (in) @ 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 I·t" OP COMMENTS: Drill F17130' to 7440'. CBU. B/R F17440' to 5437'. CBU. RIH. 10 stand short trip. CBU. POOH. . D~Nsrty(ppg) Î 9.90 I :pp I I.~CD I IIV UDPATAI DAILY,CQST I 9,351.00 L.qUM·CPST- 119,329.00 :iFV . PV1YP:.~ :-:~EL$:WUHr~'p FCrr;~OL. . 0lUWAT":, ;·%Sând/l\n~T:::. . ph/PM:" ;. . :Pf/~t:· . cr . .:·ça,·:;: .,' ft2~:; ·:LlM~· :'ES;': 46 12/26 10/22 8.11 1.0/10.0 191 0.10/5.6 9.00/0.3 0.313.6 31,000 320 , . ,. " , .:BITS, , ·MANt,./F; " ". TYF;"E.· ", ',SERIA~;NO~ . JETS ORTFA'; HTC MX-RS18DD V50DF 18/18/18//1 FROM 06:00 15:30 18:00 21:00 23:00 00:30 01:00 02:00 03:30 04:30 05:30 TO,." HRS' 15:30 9.50 18:00 2.50 21 :00 3.00 23:00 2.00 00:30 1.50 01 :00 0.50 02:00 1.00 03:30 1.50 04:30 1.00 05:30 1.00 06:00 0.50 ·.BIT / RU~ 6/1 'A' J ,':SIZE 8.500 BIT / RUN 6/1 .. . DEPTH F=M DEPTH TO 7,130 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 7,440 wos 20/30 RPM 75 I 75 ·OPERATIONS SUMM'ÄR'Y ......... ;, . sus·.·.····· . PHASE ' . ...:,. .D.ESCRIP11Ô,i( ... DRLPRO Dir drill and survey F17130' to 7440'(ART=7.8, AST=O). DRLPRO CBU X3 until shakers clean. DRLPRO B/R F17440' to 6519'(could not pull wlo rotation). DRLPRO B/R F/6519' to 5437'. DRLPRO CBUX2 until shakers clean(large quantity of clay across shakers). DRLPRO Service rig. DRLPRO RIH. W/R tight hole F17340' to 7440'. DRLPRO CBUX2 and condition mud (Max gas 295units)(lncrease MW to 10.0ppg). DRLPRO 10 Stand short trip to 6835'(hole slick). DRLPRO CBU @7440' and mix dry job. DRLPRO Pump dry job and POOH. . \ ';',DEP:rH I~ DAT'E1N '.' '!;·,:.'·'I-O-D-L-B:':G-O-R:·:i 5,676.0 2/15/2002 0-0------ GPM 420 PRESS 2,200 PBIT 286 HRS 7.82 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROp 310.0 39.64 39.25 1,764.0 44.94 8HA NO; I LENGTH 6 857.11 8HA DESCRIPTION ': ,.' :.., . .'.., "BHA " ....:.' . 'EFFWT. PICKUP ·ISLACKOF~ROTwr. TORQUE(maxlmin> ,SHAHRS 'JARHRS·MWbHRS:MTRHRS·.:SSHRS:·,' 37 167 110 I 135 7 I 6 Bit, 63/4" motor w/1.0AKO 8 3/8" UBHS , 83/8" Stab, MWD Tool, Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP , Cross-Over Sub, 4" 14PPF S-135 DP NO. . MAKE OF PUMP 1 OILWELL 2 OILWELL M.D. 7,098 7,160 7,222 INCL. 0.60 0.40 0.40 COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM .Q (gpm) PRESS~ (psi)' TOTALQ· 8.000 5.000 115 220.52 2,300 443.39 8.000 5.000 115 222.87 2,300 443.39 KILL SPM I PRESSURE'. 60 480 60 480 All 226.40 228.50 246.80 SURVEY DATA T.V.D. N/S CUM E/W CUM SECTION M.D. 6,965.57 921.30 364.03 990.61 7,285 7,027.56 920.93 363.63 990.12 7,346 7,089.56 920.70 363.27 989.78 7,383 T.V.D. N/S CUM EIW CUM SECTION 7,152.56 920.50 362.59 989.33 7,213.55 920.27 361.65 988.78 7,250.55 920.09 361.14 988.42 SERVICE INCL. 0.90 0.90 0.80 All 256.20 256.90 242.50 PERSONNEL DATA NO. HOURS .. .COMPA~.Y,....__._ _~__ o' SERVICE 4 60.00 Baker Hughes Inteq .. 18 216.00 Epoch Well Services 3 72.00 NO. HOURS 2 48.00 4 48.00 Printed: 2/18/2002 6:46:43 AM SCANNED JUL 2 1 2004 ) ') MARATHON OIL COMPANY Page 1 of 1 WELL NAME KBU 44-6 SUPERVISOR R.C. Lawson CURRENT STATUS Loç¡çinç¡ W /Schlumberç¡er. 24 HR FORECAST Complete logging. RIH. POOH LID DP. Run completion. FIELD NAME STATElPROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 9.625 (in) ~ ST KB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 Daily Drilling Report IGL 66.00 124 HRS PROG I TMD TVD DFS I REPT NO. I DATE 7,440 7,308 19 . 22 2/19/2002 I RIG PHONE AUTH MD AFE NO. JAFE COST 907-283-1312 7,32<DD.02.06038.CAP. RL 1,924,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%1 33,695.00 1,365,607.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/18/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437 (ft) 3.500 (in) ~ 7,320 (ft) 16.14 OP COMMENTS: POOH. RIU Schlumberger. Run logs. DENSITY(ppg) FV PVIYP 44 12/22 9.95 GELS 9/17 I PP I WLlHTHP 9.6/ OPERATIONS SUMMARY PHASE DESCRIPTION DRLPRO POOH(SLM, no correction} Break and LID Motor and MWD. EVALPR RIU Schlumberger. PJSM prior to running logs. EVALPR While wait on Schlumberger to trouble shoot system. Load 3.5" wiper plug in plug dropping assy. Check out completion tools. De-ice around rig. Clean and organize rig. C/O swab on #3 cylinder pump#2. Change oil in #2 generator anc #1 pump motor. AF EVALPR Run Schlumberger PEX(loggers TO 7440'). AF EVALPR RIH w/CMR to +/-1900' could not pass. POOH add weight to tool. RIH to 7440' AF EVALPR Log CMR. I ECD I I MUD .DATAI DAILY COST I OILIWAT %Sand/MBT Ph/pM /90 0.25/5.0 9/0.3 2,431.00 Pf/Mf 0.3/3.3 I CUM-COST. I CI Ca. 31,000 280 121,760.00 H2S LIME ES FROM TO HRS 06:00 12:00 6.00 12:00 12:30 0.50 12:30 23:00 10.50 DEPTH FM DEPTH TO SUB AF AF TA 23:00 01 :00 2.00 01:00 04:30 3.50 04:30 06:00 1.50 FCIT .SOL 2.0/10.0 BIT I RUN 6/1 SIZE 8.500 MANUF. HTC BITS TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I.O~D-L.B.G.O.R MX-RS18DD V50DF 18/18/18/1/ 5,676.0 2/15/2002 1-1-WT-A-E- 1-NO-TD GPM I PRESS I P BIT HRS I 24Hr DIST I 24Hr Rap I CUM HRS I CUM DEPTH I CUM ROP BIT I RUN WOB RPM BHA NO. I LENGTH 6 857.11 BHA DESCRIPTION BHA IEFF WT. PICK UP ISLACKOF1 ROTWT. ITORQUE(~ax/min) IBHA HRSJAR HRS[MWDHRSIMTR HRSlss HRS Bit. 6 3/4" motor w/1.0AKO 83/8" UBHS , 83/8" Stab. MWD Tool. Hang-Off Sub, Cross-Over Sub, 4 JTS 5" HWDP , 6-1/4" HYD Drilling Jar, 21 JTS 5" HWDP . Cross-Over Sub, 4" 14PPF S-135 DP COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 4 60.00 Baker Hughes Inteq 18 216.00 Epoch Well Services 3 72.00 Schlumberger SERVICE POB @ 06:00: NO. HOURS 2 48.00 4 48.00 4 72.00 LAST BOP TEST: SIZE (in) 13.375 9.625 2/13/2002 10 (in) LOF(ppg} 12.415 19.32 8.835 16.14 MD{ft) 1,509 5,437 CASING SUMMARY LAST CASING TEST: 2/5/2002 T\lÖ{ft} "" ."WT{lb/ft} 1,507 68 5,309 40 NEXT BOP TEST: GRADE L-80 L-80 2/20/2002 BURST(psi} 5,750 SCANNED JUL 2 1 20U~ Printed: 2/19/2002 9:29:20 AM ) ') . ..... . . . . . ... ..", .. . .. .......... . . .. . ..... .. ... '. . . ".. .... . . .... . ..... .. ..... . .. . . . . . . ... . . .... . .... . .. . . ... ........ . · fv1ARAtHÔNOILCOJVt:(?ÅNY ¡ · ... ...... .. . ........ ..... ......... ...... ...... . . "' .. . .", ........... ". . ... ... .......... . . ... .....",........ .. . ...... . . . . ... . . . .. .. .. .. . . .. .... ... ... ..... r~(1ily:~rHliô;~~~pºr(' · IGL 66.00 124 HRS PROG TMD TVD I DFS REPT NO. I DATE 7,440 7,308 20 23 2/20/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.DRL 1,924,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 29,987.00 1,395,594.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/18/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 Page 1 of 1 WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS Rigging up to run casing 24 HR FORECAST Rig up / run completion FIELD NAME Kenai ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 I STATE/PROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 9.625 (in) @ OP COMMENTS: Condition mud I lay down drillpipe / rig up to run casing OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 09:30 3.50 7,440 7,440 EV ALPR Log CMR / Rig down Schlumberger 09:30 11:00 1.50 7,440 7,440 EVALPR P~kup BHA 11 :00 16:00 5.00 7,440 7,440 EVALPR R.I.H. to 7390' I Wash and ream 50' to bottom 16:00 19:30 3.50 7,440 7,440 EV ALPR Circulate and Condition Hole 19:30 03:00 7.50 7,440 7,440 EV ALPR Lay down drillpipe and BHA 03:00 06:00 3.00 7,440 7,440 EV ALPR Pull wear ring I rigging up to run "Escape" completion . DENSITY(ppg) FV PVIYP 44 14/23 10.00 I PP I GELS WUHTHP 10/15 7.41 FC/T-SOL 2.0/10.0 IECDI IMUD DATAl DAILY COST I OIUWAT %SandlMBT Ph/pM /90 0.25/5.0 9.00/0.3 5,628.00 Pf/Mf 0.3/3.2 I CUM COST I 127,388.00 CI Ca H2S LIME 30,500 280 ES' COMPANY Marathon Inlet Drilling Alaska SERVICE PERSONNEL DATA NO. HOURS COMPANY 4 60.00 M-I Drilling Fluids 18 216.00 Epoch Well Services SERVICE NO. 1 4 HOURS 72.00 48.00 ..- ~ ....-..--.-. ~ SCANNED JUL 2 1 2004 Printed: 2/22/2002 7:21 :48 AM ) ) ... . . . . ........ . . '" .. . . . . . . .. .. . . .. . ...... . ... .... ,"",. ... .", .. .."..... . .. ............... "' ..... ",. ........ .. . .... ",". .... .... . .. ..", . . .. .. .. ..... "' . "' ... . ... .. ....... .. ...... . . .. "' . .... .. . . ,.... .... ... .". ... . ..... ... .. ..... "' ... .. ...... . . ,". .... . . "' .. .".... ... . . . .. .."... .. . ........ .. . ..... .. ...... ...", . ........ ... ,",........ . . .... ...... ..' ... .... .. .... .. ... ....... "' ;MÄRATHONiOll}:COIVIPAÎ'J¥ . WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS Running Excape completion 24 HR FORECAST Finish running pipe / log / cement I WOC / nipple down FIELD NAME I STATE/PROV I COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 9.625 (in) @ ..... ......"...",", .. . ... ......... ........ ....... .........,.. ...... .. 0"" . .... .. .... . .. ..... ,. "' . ... .. ....", ........ .. ... .... . .... .",. ... . ....... ,",. . . . . . .. ",. .. . ...... .... .. . ",. ... ..... . ..... .. . .... ... .. ...... ..... ... ... .. .. .. . .. .. .. .. ". .... '. .. . ... ... . . ......... . ..... .. .... .. . .... ... .. ................. ...... :····D:·· :~·I····· .. ·0· . ·,;·:I··I·······:···:::·::··::·R·····::··:··.,· ::t':'::"· ,..' ...... ..: . al Y : tllngepof ..... IGL 66.00 ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD TVD I DFS 1 REPT NO. I DATE 7,440 7,308 2 2/21/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.CMP 2,853,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 122,947.00 122,947.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/18/2002 2/13/2002 I NEXT CASING LEAKOFF PPG 5,437.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 OP COMMENTS: Run 3 1/2" casing and 16 Excape perforating modules OPERATIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE DESCRIPTION 06:00 10:30 4.50 7,440 7,440 RCMP RU equipment to run completion string. Held PJSM. 10:30 12:00 1.50 7,440 7,440 RCMP Begin to TIH with 3.5", 9.3 ppf, L-80, EUE 8rd casing. 12:00 21:00 9.00 7,440 7,440 RCMP PU and TIH with 16 Excape perforating modules. All modules are equipped with 10' perforating guns, and all but the bottom two modules are equipped with ceramic flapper assemblies. The bottom module is fired by RFID tag, and the remainder are fired by control line pressure. 21:00 05:00 8.00 7,440 7,440 RCMP Continue to TIH with 3.5" casing. to shoe @ 5437 05:00 06:00 1.00 7,440 7,440 RCMP Circ. hole @ shoe DENSITY(ppg) I 10.05 I PP I FV PVIYP GELS WLJHTHP 43 12/19 8/14 7.8/ IECDI IMUD DATAl DAILY COST I FCrr.SOL OIUWAT %Sand/MBT Ph/pM 2.0/11.0 /90 0.25/5.0 9.0010.2 625.00 Pf/Mf 0.2/3.0 I CUM COST I CI Ca H2S 2,800 240 625.00 LIME ES. COMPANY Marathon Inlet Drilling Alaska M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 4 60.00 Epoch Well Services 18 216.00 Tri - Point 1 72.00 Pro-More SERV,CE NO. 4 5 4 HOURS 48.00 60.00 48.00 .~_.- '-"-' ........ ...,.,.....---.--............,.. .,. SCANNED JUL 2 1 2004 Printed: 2/22/2002 7:20:08 AM ) ) MARATHON OIL'COMPANY .. .. , , , , ... .. . .... ... .. Pag,e"~ ;:'()f.1 : .. ' ST IKB OH 87.00 RIG NAME & NO. GLACIER DRILLING 1 ,Daily Drilling, Report' IGL 66.00 I COUNTY/OTHER I LAST CASING Kenai Borough 3.500 (in) @ WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS Wait on cement 24 HR FORECAST NO BOPE, NU tree, demob rig. FIELD NAME I STATElPROV Kenai Alaska , , . . . ... ... . . 124 HRS PROG TMD TVD I DFS 2 REPT NO. I DATE 7,440 7,308 3 2/22/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 7,320 DD.02.06038.CAP.CMP 2,853,000 I MOC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 438,391.00 561,338.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/18/2002 2/1312002 I NEXT CASING LEAKOFF PPG 7,393.0 (ft) 3.500 (in) @ 7,320.0 (ft) 16.14 OP COMMENTS: Finish running 3.5" casing. Correlate Excape guns on depth. Cement casing string. Wait on cement. ",;: b~N~IT)'(PP~) 'I 10.00 1 ~p 'I I:Ep~ I , I' MUD"PÄ TJ\r'~~'L'f."b~~t I :¡. 'þv , PViYp:' ~ELS : ¡WuHTHP" 'Fqrr.50L ,OIUWAT : ,%SandJMBT":, ';.:,:'p~/pM': 42 12/20 8/13 9.41 2.0/11.0 190 0.25/7.0 9.00/0.2 "PERSqNNEL,DATA,:,::" ":::," "NO. ,:', ::HOI..J~S:" ",:,',GP~PA~Y' 4 96.00 Epoch Well Services 18 216.00 Tri - Point 1 24.00 Pro-More FROM ':"TO': , :': HRS' "DEPTH:FM ,QEPJ'H .to 'SUB, 06:00 07:00 1.00 7,440 7,440 07:00 09:00 2.00 7,440 7,440 09:00 12:00 3.00 7,440 7,440 12:00 16:00 4.00 7,440 7,440 16:00 21:30 5.50 7,440 7,440 21 :30 06:00 8.50 7,440 7,440 , :CQ!'v1PANV, ,: Marathon Inlet Drilling Alaska M-I Drilling Fluids ." ~ERVICE ' OPEAATIONS'SUMMARY,' " I :, PHÁS:E:: " '" , , i.": ' 'DESCRII?TI9'N:"', RCMP Circulate hole at 9-5/8" shoe at 5437' RCMP Resume running 3.5" casing with Excape modules to 7393'. RCMP Circulate and condition hole. RCMP MIRU Schlumberger. Conduct prejob safety meeting. RIH with GRlCCL log to correlate depth on perforating modules. POOH, RDMO Schlumberger. RCMP MIRU BJ cementers and cementing head. Circulate hole while batch mixing class G cement with 0.9% BA-10 + 0.35% R-3 + 2% KCI + 0.2% FL-63 + 0.6% CD-32 + 1 gal/100 sk FP-6L + 0.15% sodium metasilicate. Held prejob safety meeting and test lines to 3400 psi. Pump 50 bbl of weight spacer, 930 sacks of cement, and displace with 64.5 bbl of 6% KC!. Plug bumped at 2110 hrs with 600 psi over pump pressure. Floats held, and maintained full returns during job. RCMP Wait on cement. Clean pits, begin demob operations. 1,154.00 Pf/Mf\~ 0.2/3.1 ICUMqÖ$T:1 1,779.00 : : C,I: , ; Ca':,:, ;.;' H2$' LIME: ,: 'E$::' 27,000 280 , , , , ",' " , . " . . L I" I' . '.' ¡SERVICE :: 'NCk 4 5 4 ..: .', .,p". ' "I . "I,: .... '".' '". .............. ·"'..·..·\'·IJ· ,;: H:OUfJ~f::: 48.00 60.00 48.00 SCANNED JUL 2 1 20D~ Printed: 2/22/2002 7: 15:02 AM ) ) WELL NAME KBU 44-6 SUPERVISOR Jerry Lorenzen CURRENT STATUS rig released @ 2100 hrs. /prepare to move 24 HR FORECAST Move rig to KU 41-7x location FIELD NAME I STATE/PROV COUNTY/OTHER I LAST CASING Kenai Alaska Kenai Borough 3.500 (in) @ '. MA~ATHON.OII~:C9Ivrp·ANY:.: Daily Drilling ~~P9rt . KB GL 124 HRS PROG TMD TVD DFS 3 REPT NO. I DATE 87.00 66.00 7,440 7,308 4 2/23/2002 I RIG NAME & NO. RIG # AUTH MD AFE NO. AFE COST GLAÇIER DRILLING 1 907-283-1312 7,320 DD.02.06038.CAP.CMP 5,027,000 I MaC WI I NRI DAILY WELL COST CUM WELL COST 100.00 (%) 92.20 (%) 98,595.00 687,282.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 2/18/2002 2/13/2002 NEXT CASING LEAKOFF PPG 7,393.0 (ft) 3.500 (in) ({j ,320.0 (ft) 16.14 ... . ... ::. Pág.~· t:'öf .1:: .', : . . :. ".' 24 HR SUMMARY: WOC INipple down BOPs/nipple up tree Irun controllinesl test tree to 5000 Ire lease rig ,,' ':J:ROM ,to" , H.RS·: :DI:;P,TH FM PEPTH TQ 06:00 09:30 3.50 7,440 7,440 09:30 15:00 5.50 7,440 7,440 . . :" OPERATIONS::SUMMARY . . . ·sua:.· ·.PHASE;· . , "DESCRIPTION';":': RCMP Wait on cement. Clean pits, clear floor, RD control line sheaves. Prepare for rig move. XMBO Pull 120K Ibs on 3.5" casing (50K Ibs over pipe weight). PU BOPE stack. Run two 1/4" control lines and electric cable through tubing head side outlet. Set slips, make rough cut, pull stub. Lay down BOPE. Make final casing cut, set tubing packoff, NU tubing head adaptor and 3-1/8", 5M tree. Set 2-way check, test void and tree to 5000 psi. Tree is loaded with methanol. Promore ._- -- finished rigging up packoff for control lines and electric line. Release rig at _2100_ hrs on 2/22/01. .. . ::; DI;NSITy(PP9)':.I I :PP: 'I I "EqD I I MUD· DA TÄ I :: Q"I.~Y POST ~., FV:··,:PVlVP:,: :GELS '.WLlHTHP, .,:Forr.SOL:::, OIUWAT %SaiüUMBT'~::; ,::'PIiJpM:: / I I / 190 I 0.00, .I:·::ç~~:.c,o~t: I . 6,563.00 '::Pf/Mf: ,,:,.1.:01:::1;:>' <.C~'~,:;,,: '::;·1"I2S;,::" ':UM~; :'. :t;~!,:, I ) '<¡¡~ '.Ç()M~ANY: Marathon ',.,¡: . ,:.:·,PE:~~6tiNEL.:,DArr~::"!:·' ,:" : ,:. N().. ;·t-JOURS: '.~':-:':··,.:coMÞANY.::' 1 96.00 Inlet Drilling Alaska /:"'j',r:; ,);.' ::';::: ::.:,:~~~:¡.:: :'1:::~:6~~;::::": 18 216.00 se~VÎCEi :":s~tlvlce ' .-._,,-.._~- '!' SCANNED JUL 2 1 200~ Printed: 2/25/2002 9:09:13 AM ) ) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT DATE: 3/5/2002 FILL DEPTH/DA TE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: NIA FIELD: TUBING: Kenai Gas Field NIA WELL #: KBU 44-6 3-1/2" New CASING: TREE CONDITION: WIRE TEST: WBS # DD.02.06038.CAP.CMP HRS PROD: X DRILL: SUMMARY OF OPERATIONS Ticket #: 3/1/02 Pressured up on well with methanol to 3000 psi. Well bore is loaded with 6% KCI from the displacement of the cement job of 2/21/02. 3/5/02 0800 Hooked up recording device onto Promore downhole pressure sensor. SITP = 2700 psi, Promore = 5019 psi. Turned on RFID tag (sIn #FCA-002, 00 = 2.004",12' long, fishing neck = 1.000") and placed the RFID tag inside swab valve. Released the RFID tag to fall downhole at 0952 hrs. At 1033 hrs had - positive indication of module #1 firing (7242' - 7252' MD). At 1100 hrs, SITP = 1250 psi, Promore = 1200 3526 psi añd dropping. -- ~ Vendor Equipment Daily Cost Cumulative Cost Misc $200.00 DAILY COST: $200.00 CUM: REPORTED BY: Gary Eller SCANNED JUL 2 1 2004 ) ) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT DATE: 5/22/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: TUBING: Kenai Gas Field N/A WELL #: KBU 44-6 3-1/2" New CASING: TREE CONDITION: WIRE TEST: fire Excape module #2 WBS # DD.02.06038.CAP.CMP HRS PROD: X DRILL: SUMMARY OF OPERATIONS Ticket #: Arrive on location, conduct safety discussion. Connect hydraulic hand pump to green control line. Position listening devices on tree. SITP = 290 psi. Pressure up green control line to 2600 psi, fired Excape module #2 (7050' - 7060' MD). Obvious indications that guns fired successfully. Tubing pressure dropped to 240 psi within 1 minute. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: Gary Eller SCANNED JUL 2 1 2004 DATE: 7/2/2002 FILL DEPTH/DA TE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELlNE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS 07:30 Travel to KGF Office 08:00 Arrived @ KGF, checked in, discussed job procedure wI Wayne, safety meeting 08:15 Moved equipment to Pad 41-7, spotted on well 09:00 Assist VECO in removing Cross Flange from well 09:30 RIU W IL, twist test - 23, 22 & 22 10:15 Pressure test to SITP 250 # - good 10:35 Ran 2X1 GG Pulling Tool to 7265' WLM, worked several times, unable to latch, POOH 11 :30 Ran 1 3/8" JDC to same, worked, no latch, POOH 12:30 Ran modified 2X1 GG, cut off bottom bowl, added shims to top of Grapples, ran to same, latched and pulled Electronic Firing Bar RID WIL, moved to KTU 32-7 MARATHON OIL COMPANY 13:30 Vendor Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. DAILY COST: $1,302.00 ') ) DAILY WELL OPERATIONS REPOR. FIELD: TUBING: New well Pull Electronic Firing Bar Complete Kenai Gas Field 3 1/2" WELL #: KBU 44-6 9 5/8" New 23, 22 & 22 CASING: TREE CONDITION: WIRE TEST: (1 3/4"TS) RS, KJ, 10' Stem, KJ, OJ, SJ Biggs/Ti. Doherty WBS# Hrs. PROD: CC20284500 6 X DRILL: Ticket #: P-184 Equipment 6of12hrmin 2X1 GG Graples 2X 1 Bottom Bowl 1 3/8" JDC Daily Cost $915.00 $188.50 $123.50 $75.00 Cumulative Cost $915.00 $1,103.50 $1,227.00 $f,302.00 CUM: SCÞiNNeE1EQ ßY:2 Wayne Cissell JUl 1 2004 ) ) 02070a.xLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/8/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Frac OTHER: WBS DD.02.06038.CAP.CMP FIELD: Kenai Gas Field TUBING: N/A WELL # KBU 44-6 CASING: 3-1/2",9.3#, L-80 TREE CONDITION: good BENCHES OPEN: Tyonek SUMMARY OF OPERATIONS 7/6/02 & 7/7/02 MIRU Stinger tree saver and 1.5" coil tubing. Coil BOPs are mounted on top of tree saver. Pressure test (PT) coil tubing BOPE 250/4500 psi. MIRU frac iron, attempt to PT. Stinger spool piece failed PT. NO coil BOPs and faulty spool. NU frac iron directly to tree saver. PT frac iron to 8500 psi. SOFN 7/8/02 0600 Held prejob safety meeting. Wellhead gas bled through to the suction manifold overnight, blew out some a-rings. SO waiting on a-rings. SITP = 280 psi, Promore = 2588 psi. Modules 1 & 2 0850 Finally ready to pump. Load hole with diesel, perform step-rate test. Pump tubing volume of 3/3 of Super Rheogel frac gel, perform another step-rate test. Frac'd modules 1 & 2 (7198' - 7252' gross) at 15 bpm with 179 pad and 118,000 Ibs of 20/40 Econoprop proppant in 581 bbl of gelled fluid. Proppant concentration stepped up from 2 ppa to 7 ppa. Flush with gelled fluid. Placed 97% of design. ISIP = 4000 psi, Promore = 5974 psi. Total load to recover (this stage) = 988 bbl. 1135 Module 3 Pressure up control line to fire module #3 (7050' - 7060'). Saw surface pressure drop when guns fired. Frac stimulate module 3 at 15 bpm with an additional 38 bbl of pad and 60,600 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 3060 psi, Promore = 5045 psi. Total load to recover (this stage) = 451 bbl. 1230 Module 4 Pressure up control line to fire module #4 (6982' - 6992'). Observed firing event on Promore gauge. Frac stimulate module 4 at 15 bpm with an additional 39 bbl of pad and 62,000 Ibs of proppant (100% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 2900 psi, Promore = 4869 psi. Total load to recover (this stage) = 440 bbl. continued on next page) Vendor Equipment Previous WBS Total (as per SAP rpt of 7/5/02) Alaska Oil Sales Diesel fuel BJ Coiltech Coil tbg, nitrogen BJ Services Frac stimulation Mise misc Onsite Fire protection Promore BHP measurement R&K Rental storage tanks Rain for Rent Frac tanks Stinger Tree saver Tesoro Diesel Veco Crane, vac trucks Weaver Bros. Fluid hauling Daily Cost N/A $836 $8,337 $979,904 $10,000 $7,547 $4,360 $6,840 $25,600 $5,500 $302,400 $3,210 Cumulative Cost $2,4 74,657 $3,236 $8,337 $979,904 $10,000 $7,547 $4,360 $6,840 $25,600 $5,500 $302,400 $0 $42,045 DAILY COST: $1,354,534 CUM: $3,870,426 REPORTED BY: ·-'·G'''EHêr------..---,-. ~ SCANNED JUl 21 ?nnA ) ) 020708.XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/8/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Frac OTHER: WBS DD.02.06038.CAP.CMP FIELD: Kenai Gas Field TUBING: N/A WELL # KBU 44-6 CASING: 3-1/2",9.3#, L-80 TREE CONDITION: good BENCHES OPEN: Tyonek SUMMARY OF OPERATIONS (continued from previous page) Module 5 1320 Pressure up control line to fire module #5 (6874' - 6884'). Observed firing event on Promore gauge. Frac stimulate module 5 at 15 bpm with an additional 39 bbl of pad and 61,000 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 3070 psi, Promore = 4986 psi. Total load to recover (this stage) = 453 bbl. (Module 6 1425 Pressure up control line to fire module #6 (6722' - 6732'). Observed firing event on Promore gauge. Frac stimulate module 6 at 15 bpm with an additional 40 bbl of pad and 62,500 Ibs of proppant (101 % of design) in 333 bbl of gel. Picked up some residual proppant in the lines when we began pumping pad, causing a small proppant slug to hit the perfs. Saw 150 psi increase in treating pressure, but the slug cleared the perfs successfully. Treating pressure returned to it's normal trend. Flushed with gelled fluid. ISIP = 2430 psi, Promore = 4400 psi. Total load to recover (this stage) = 453 bbl. 1530 Module 7 Pressure up control line to fire module #7 (6630' - 6640'). Unable to detect firing event on Promore gauge, but heard it with acoustic sensor. Frac stimulate module 7 at 15 bpm with an additional 42 bbl of pad and 61,500 Ibs of proppant (99% of design) in 333 bbl of gel. Flushed with gelled fluid. Promore gauge useless this time due to pressure pulses from problem frac pump. ISIP = 2650 psi, Promore = 4461 psi. Total load to recover (this stage) = 445 bbl. Module 8 1625 Pressure up control line to fire module #8 (6563' - 6573'). Control line pressure dropped after firing module 8 since this was the last module on this control line. Frac stimulate module 8 at 15 bpm with an additional 43 bbl of pad and 62,000 Ibs of proppant (100% of design) in 333 bbl of gel. Flushed with weak gelled fluid (3/3 gel). ISIP = 2755 psi, Promore = 4583 psi. Total load to recover (this stage) = 458 bbl. 1800 SDFN. Unable to continue because we're out of proppant. During the night reload proppant and diesel. Frac crews made minor repairs to one pump. REPORTED BY: G. Eller SCANNED JUL 2 1 2004 ) ) 020709.XLS MARATHON Oil COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/9/2002 Fill DEPTH/DATE: DATE lAST Wl WORK: WORK DONE: PRESENT OPERATION: Frac OTHER: WBS DD.02.06038.CAP.CMP FIELD: Kenai Gas Field TUBING: N/A WEll # KBU 44-6 CASING: 3-1/2",9.3#, l-80 TREE CONDITION: good BENCHES OPEN: Tyonek SUMMARY OF OPERATIONS 0600 Held prejob safety meeting. Tie in pressure transducer to original control line for deadstring pressure. Prepare to resume fracturing operations. Module 9 0730 Pressure up control line to fire module #9 (6492' - 6502'). Observed firing event on Promore gauge. Frac stimulate module 9 at 15 bpm with 99 bbl of 5/5 Super Rheogel pad and 74,000 Ibs of proppant (119% of original design) in 381 bbl of gel. Did not credit any gel in the we II bore from previous night as pad. Extended the 6 ppa stage by 60 bbl over original design. Flushed with gelled fluid. ISIP = 2896 psi, Promore = 4825 psi. Total load to recover (this stage) = 563 bbl. Attempted to monitor deadstring control line, but unable to capture signal. Module 10 0835 Got deadstring transducer working. Pressure up control line to fire module #10 (6424' - 6434'). Observed firing event on Promore gauge. Frac stimulate module 10 at 15 bpm with an additional 44 bbl of pad and 61,000 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 3067 psi, Promore = 5004 psi. Total load to recover (this stage) = 452 bbl. Module 11 0925 Pressure up control line to fire module #11 (6291' - 6301'). Observed firing event on Promore gauge. Frac stimulate module 11 at 15 bpm with an additional 33 bbl of pad (18% pad instead of originally planned 20%) and 60,500 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 2066 psi, Promore = 3943 psi. Total load to recover (this stage) = 436 bbl. Module 12 1015 Pressure up control line to fire module #12 (6151' - 6161'). Observed firing event on Promore gauge. Frac stimulate module 12 at 15 bpm with an additional 35 bbl of pad (18% pad) and 61,000 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 2500 psi, Promore = 4349 psi. Total load to recover (this stage) = 435 bbl. (continued on next page) Vendor Equipment Daily Cost Cumulative Cost Previous WBS Total (as per SAP rpt of 7/5/02) N/A $2,474,657 Alaska Oil Sales Diesel fuel $0 $3,236 BJ Coiltech Coil tbg, nitrogen $40,000 $48,337 BJ Services Frac stimulation $905,167 $1,885,071 Misc misc $10,000 $20,000 Onsite Fire protection $4,680 $12,227 Promore BHP measurement $2,136 $6,496 PTS Flowback hands $4,500 $4,500 R&K Rental storage tanks $0 $6,840 Rain for Rent Frac tanks $0 $25,600 Stinger Tree saver $7,500 $13,000 Tesoro Diesel $0 $302,400 Veco Crane, vac trucks $7,704 $7,704 Weaver Bros. Fluid hauling $0 $42,045 DAll Y COST: $981,687 CUM: $4,852,113 REPORTED BY: G. Eller SCANNED JUL 2 1 2004 020709.XLS ) ) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/9/2002 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Frac OTHER: WBS DD.02.06038.CAP.CMP FIELD: Kenai Gas Field TUBING: N/A WELL # KBU 44-6 CASING: 3-1/2", 9.3#, L-80 TREE CONDITION: good BENCHES OPEN: Tyonek SUMMARY OF OPERATIONS (continued from previous page) Module 13 Pressure up control line to fire module #13 (6111' - 6121'). Observed firing event on Promore gauge. Frac stimulate module 13 at 15 bpm with an additional 35 bbl of pad and 61,000 Ibs of proppant (98% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 2345 psi, Promore = 4283 psi. Total load to recover (this stage) = 430 bbl. 1105 1155 1230 1315 1405 1445 2100 2330 0330 (7/10) Module 14 Pressure up control line to fire module #14 (6027' - 6037'). Observed firing event on Promore gauge. Frac stimulate module 14 at 15 bpm with an additional 24 bbl of pad (16% pad instead of 20%) and 62,700 Ibs of proppant (101% of design) in 333 bbl of gel. Flushed with gelled fluid. ISIP = 1990 psi, Promore = 3914 psi. Total load to recover (this stage) = 426 bbl. SO 30 minutes for lunch Module 15 Pressure up control line to fire module #15 (5948' - 5958'). Observed firing event on Promore gauge. Frac stimulate module 15 at 15 bpm with an additional 24 bbl of pad (15% pad) and 68,800 Ibs of proppant (111 % of design) in 357 bbl of gel. Added a 31 bbl stage of 7 ppa proppant. Flushed with gelled fluid. ISIP = 2030 psi, Promore = 3957 psi. Total load to recover (this stage) = 456 bbl. Module 16 Pressure up control line to fire module #16 (5910' - 5920'). Observed firing event on Promore gauge, and control line pressure dropped fllowing perforating. Frac stimulate module 16 at 15 bpm with an additional 25 bbl of pad (15% pad) and 66,200 Ibs of proppant (107% of design) in 353 bbl of gel. Added a stage of 7 ppa proppant until we ran out of proppant. Flushed with weak gelled fluid. ISIP = 2051 psi, Promore = 3999 psi. Total load to recover (this stage) = 447 bbl. Total load to recover (all stages) = 7332 bbl diesel. RD tree saver and frac iron. RU 1.5" coil tubing. Attempt to pressure test coil tubing, but studs & nuts on tree are loose. Tighten nuts on tree flanges. Pressure test coil to 500/3500 psi. Open up well. SITP = 60 psi, Promore = 1974 psi. Bled off wellhead pressure; well flowing slightly. RIH with coil without circulating. At 800' begin circulating nitrogen at 500 scfm. Strong returns of broken diesel gel. Tag and break through first glass flapper disks at 5918' CTM (5928' MD)'. RIH continuing to break flapper disks. Surface pressure has gradually increased to 1100 psi, Promore = 2380 psi, returns are strong. Well is definitely coming around on it's own. Cease pumping nitrogen at 6280'. Continue breaking disks at 5956',6035',6120',6156',6430',6569',6727', 6879', and 6986' CTM. Questionable whether we successfully broke the disks at 6309',6510',6648, and 7068' MD. Tag hard at 7232' CTM. Unable to work past. Attempt to pump KCI fluid to wash fill. Coil nozzle is plugged. Well producing on it's own through the diffuser tank. POOH with coil. Reach surface, close swab valve (allows coil to be isolated but well can continue to flow through wing valve). Sever nozzle from coil with cutter rams. Bleed off trapped pressure in coil. RD coil tubing injector head and BOPE. SDFN with coil. Well producing calculated 3.0 MMCFD with 1600 psi FTP on an 18/64" positive choke. Promore = 2380 psi. Fluid rate = 240 bpd (unable to determine percentage of water versus diesel). Sand production appears light. Continue to produce with PTS flowback hands supervising. REPORTED BY: G. Eller SCANNED JUL 2 1 2004- MARATHON OIL COMPANY ') DAILY WELL OPERATIONS REPOR'I ) DATE: 7/18/2002 FILL DEPTH/DA TE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRELlNE CREW: RSO #: 455-864 SUMMARY OF OPERATIONS 07:00 Drive from Pollard Shop to KGF, safety meeting, job meeting 08:00 Move W/L equipment to well site, RIU, P. T. Lub to 2000 PSI - good 09:45 RIH wi 2.25" DD Bailer, set down @ 7198' WLM, couldn't work past, POOH to check tool, OOH wi full Bailer of Frac Sand 7219' MD, RID Move to KBU 41-7X FIELD: TUBING: Kenai Gas Field 3 1/2" #9.3 CASING: TREE CONDITION: WIRE TEST: WELL #: KBU 44-6 9 5/8" Good 4 3/4" Otis 21 Tag bottom and sample off bottom Complete RS, KJ, 10' x 1/5" Stem, KJ, OJ, LSS Howarth/J. BalllSmith WBS# Hrs. PROD: DD.02.06038.CAP.CMP 5 DRILL: x Ticket #: P-197 12:00 Tool Cost: 2.25" DD Bailer $150.00 Vendor Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Equipment 50f12hrmin Tools Fuel Daily Cost $866.65 $150.00 $57.65 Cumulative Cost $866.65 $1,016.65 $1,074.30 DAILY COST: $1,074.30 CUM: REPORTED BY: Wayne Cissell SCANNED JUL 2 1 2004 BOP Contiguration Change tor Glacier 1 specific"to KBU 44-6 ,) ) Subject: BOP Configuration Change for Glacier 1 specific to KBU 44-6 Date: Tue, 12 Feb 2002 14:21 :33 -0900 From: "Tank, W J (Will) " <WJTank@MarathonOil.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Titus, Denise M." <DMTitus@MarathonOil.com>, "Berga, P K (Pete) " <PKBerga@MarathonOil.com> Winton, As per our conversation the proposed BOP configuration change would result in a stack that consists of (from top to bottom): 135/8", 5M Annular Preventer 135/8", 5M Double Ram Preventer with Variable Bore Pipe Rams (closing on 2 7/811 - 5 1/211) on top and Blind Rams on bottom. 135/8", 5M Mud Cross for Kill and Choke lines (Two - 3 1/811, 5M valves per side) Please note that the Maximum Anticipated Surface Pressure is 2,542 psi, several hundred psi below the test pressure of 3,000 psi. If you require any additional information, please let me know. Thank you, Willard J. Tank Senior Drilling Engineer Marathon Oil Company (907) 564-631 0 SCANNED JUL 2 I 2004 1 of 1 2/13/20029:47 AM ) Alaski:. )g¡on DomeS~ic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER DATE: 1. J I L / 0 2- PLEASE DELIVER THE FOllOWING TO: Name: Mr. W6~f1+0Þ'1 Aub~(t Company: A 0 ('; (~G Fax No.: Z 7(, - 7 5'42 Number of Pages (including cover page): S- FROM: Name: vJ ~ J (To '1 k Location/Extension: A n c. ho r 4J e. ) A Ie Fax No.: 907/564-6489 1ó 7 - ~04 - G s 10 NOTE: . I / Jlq( hfV'(~-k W ;1)+0 Ill) IN ,-r"l t.; 11 ') Aitt<ch(J an t~t. 5U/)Jf1 +01'" Búf Cú"i+iJUI4+toll cht/''7j'<- q S Wi II () 5 H ( ~u I'?J I( fc)( ~ð("! {¡'ð/) ~ ('æ M t"f mod ;.f,IC'" +,'0"1 S+a·k ..(¿'ýrY/. PI~qs.£. COI)-J.qct- ;-y,( df(r ,/ouF ,eV;U-J 4+ your L~fl:{s+ (O(l\¡I/itt~(L. tJ.,t14t. '(ou wi If ~~k. If transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation Environmentally aware for the long run. SCANNED JUL 2 1 2004 , ~ ) ) ¡,J GA-· 2-/1 3/ () '"L ~ t7 s/ /, /0 L Alaska Region Domestic Production ~ , M MARATHON ~ Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 4,2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission ,333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KBU 44·6 Permit No.: 200-179 R~CI2II1~D FES] AlaSkaa~ ~ 2002 Z &Gaseoa Anchofarr. s. Co"'I11iC1ð' ~'e ~/On Dear Mr. Maunder Enclosed please find the APPLICATION FOR SUNDRY APPROVALS and cementing program. The sundry documents two items that have changed since the well was permitted for drilling. None are a major change. These two items are explained below. Suñace Location: The original surface location recorded on the drilling permit was from .I l the initial staking. A small change was made to accommodate the rig footprint on the drilling 3 '$J I IE" location in relation to the other wells on Pad 41-7. Th~ directional plan was unchanged, resulting in a small difference in bottom hole location. /' 2. At} IN Cementina proaram: Because of the low pore pressure and higlJ)?ermeability inJhe intermediate section, the cementing program was changed to 12.0 ppg. lead and 13.5 ppg. tail cement instead of 12.8 ppg. lead and 15.8 ppg. tail. This change reflects a cementing program we have used successfully on the three Kenai Gas Field sidetracks in 2001; KU 21- 6 RD, KU 24-5RD, and KU 43-6RD. The height 9! the lead and tail have been adjusted to minimize hydrostatic while still providing over 500 feet of cement above the top hydrocarbon bearing zone. The height of the production zone cement has been raised 200 feet to provide additional tie- back between the 3 1/2" casing and the 9 5/8" casing shoe. A detailed copy of the cementing program is attached. If you require further information, I can be reached at 907-564-6310 or bye-mail at wjtank@marathon.com. Sincerely, þ;&J )kk Willard J. Tank Senior Drilling Engineer Enclosure o RIG I N A \.sCANNED JUl 2 1 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .:ft^\~ \ ù1/ 1;;\\ n:\drlg\kgf\43-6xrÔlKBU 44-6 AOGCC Sundry.xls £;q .7/ \0 ') ) 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Repair Well X Pull Tubing 5. Type of Well: DevelopmentL Exploratory _ Stratigraphic _ Service Operation Shutdown Plugging Re-enter Suspended Well_ Time Extensior Stimulate Variance Perforate 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 6. Datum Elevation (OF or KB) 87' KB above MSL 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 44-6 9. Permit Number 200-179 10. API Number 50-133-20498-00 11. Field/Pool Kenai Gas Field/Beluga 42'FNL, 4283'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. At Effective Depth Change in Surface and Bottom Hole At Total Depth Locations, Change in Cement Program 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 4625 4514 feet feet Currently Drilling Casing Structural Conductor Surface Length 114 Size 20" Cemented Driven Measu red Depth 135 True Vertical Depth 135 13-3/8" 1491 650 sx 1512 1510 RECEIVED FEa 1 2 2002 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description Summary of Proposa~ BOP Sketch Detailed Operations Program_ 14. Estimated Date for Commencing Operation 1/29/2002 16. If Proposal was Verbally Approved 15. Status of Well Classification as: Oil Gas X Suspended Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :# d ð~ 0_ An J Willard J, Tank Tjije Senior Drilling Engineer ~ FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Tes~ -Subsequent Form Required 10--4 CJl Date Approval No. ':2 F"\. I l ~:)-tlO C\...S "O'-""'..(l \. Other feet 2/8/2002 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By CCUIUIIY Ot:cta~1i Commissioner Date3 J) )()~ S\ ~mit. Triplicate SCANNED JUL 2 1 2004 n n, , t f""",,,\, I r, ~, f\' , l' , ,\ ' 1\ I " I I ,\-r 1'-'"' ~.j ! ~ Lj, I \J, ¡ \ -. ') " , M MARATHON - Marathon Oil Company February 11,2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KBU 44-6 Permit No.: 200-179 Dear Mr. Maunder ) Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Enclosed please find the APPLICATION FOR SUNDRY APPROVALS form, program, and BOP sketch. The proposed change is to remove the lower single gate preventer from the BOP stack. This change is requested as it will be necessary to pick up the BOP stack to run the control lines through the side outlet on the tubing spool. Elimination of the single gate will provide the room necessary to install the control line system. If you need any additional information, I can be reached at 907-564-6317 or bye-mail at dmtitus@marathonoil.com. St:1Y~/Jw Denise M. Titus Production Engineer Enclosure SCANNED . JUl 2 1 2004 ) ) n:\drlg\kgf\43-6xrd\AOG C~~2.Xls \lJ4-A- 2-/, Sf O'L .f:t 2h~ Q 7::J 2-11S .J\\;\t\" .ybs 1(;(1/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Repair Well X Pull Tubing 5. Type of Well: Developmen~ Exploratory _ Stratigraphic _ Service Operation Shutdown Plugging Re-enter Suspended Well_ Time Extensior Stimulate Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface Change in BOP configuration 6. Datum Elevation (OF or KB) 87' KB above MSL 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 44-6 9 Permit Number ~:'.. .. ~ ~i~;t::j~;:.;'::'T' :"':r 10. Aþf Ñum'l5êf ,.. 50-133-20498-00 11. Field/Pool Kenai Gas Field/Beluga feet 42'FNL, 4283'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. At Effective Depth At Total Depth 750'FSL, 4596'FWL, Sec. 6, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 5451 feet 5322 feet Currently Drilling Casing Structural Conductor Surface Length 114 Size 20" Cemented Driven Measured Depth 135 True Vertical Depth 135 1491 13-3/8 " 650 sx 1512 1510 13. Attachments Description Summary of Proposa~ Detailed Operations Program_ BOP Sketch X 14. Estimated Date for Commencing Operation 1/29/2002 16. If Proposal was Verbally Approved 15. Status of Well Classification as: Oil Gas X Suspended _ Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~rWß Date 2/11/2002 Denise M. Titus Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity_ BOP TestX Location Clearance_ Mechanical Integrity Tes~ Subsequent Form Required 10- Approval No. ~ -Cft)O Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By Cammy nechsl¡ Commissioner ~ /1 .J l Date (7-/) ~ S mi~ Triplicate SCANNED JUL 2 1 ?On4. ) ') J Marathon Oil Well KBU 44-6 BOP Stack I Flow Line I I I Flow Nipple I -. 13 5/8" 5M Annular v" Preventer ~ "> / 1 1 I 1 ) < '2. -1/r ,I t 5 -' /2, 'f VB ( 135/8" 5M Double Ram Preventer I ~ I I Pipe Ram I I Blind Ram I 3 1/8" 5M Hydraulically Operated Valve 3 1/8" 5M Manually Operated Valves ) ~~ :~ IXlIXl)KiII I I I~:/) 13 5/8" 5M Cross I '\ ( I /1 ,¡ IChoke(J0[I Xl t "'- 1 1 ( 3 1/8" 5M Manually Operated Valve 1 í .,.................... .." .~ SCANNED JUL 2 1 2004· ) Alask "\'ion Dome::.. J,production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER DATE: ~wtJ~ PLEASE DELIVER THE FOLLOWING TO: Name: ~ AI\. lVi Av AJ uf:it.. Company: A-Ot7 Cc. Fax No.: Number of Pages (including cover page): f 'f ~ FROM: Name: btNl~t= ~rus Location/Extension: Fax No.: 907 /564-6489 NOTE: -- J-- l/1JI \.,v HI: (1lJ JCfN'tt /ò Mo/2.~(flA) e~L(~ 'i~7-0S-~~ Pqt¿ ~f-7d-<:ïJ If transmission is not complete, please call 907/561-5311·,);:0 J U L 2 1 2004: A subsidiary of USX Corporation Environmentally aware for the long run. .' ) ') Wj January 29, 2002 Will tank Marathon Oil Co P. O. Box 196168 Anchorage, Alaska 99519 Subject: Well Proposal The following is BJ Services' proposal for the KBU 44-6/ Pad 41-7 in the Kenai Gas Field in Kenai County, Alaska. This proposal includes fluid specifications and price estimate. The Cementing Services Proposal for the KBU 44-6 has been generated based on the well data provided by and discussed with Marathon engineering. Special consideration has been given to the intermediate casing operation to offset the potential for massive losses across the upper Beluga and Sterling zones where low pressure and high permeability are anticipated. In line with this concern we propose a 12.0 ppg lead and 13.5 ppg tail slurry to minimize ECD effects with Celloflake and KolSeal additives blended in the pre-flush and lead slurry only. Top of cement for the intermediate lead and tail cement is 3,000'MD and 3,500'MD respectfully. Specific to the cementing of the EXcape casing string extensive laboratory testing, computer simulation design optimization discussions with Marathon drilling engineering are required. As noted in the procedure section cementing of EXcape strings is complex and requires special consideration be given to nearly every aspect of the operation. I would welcome the opportunity to present our EXcape string cementing standard practices to Marathon engineering to enhance what we consider to be job critical. This presentation will be scheduled at your convenience. Services will be performed by our Kenai District Operations team with support from our Corporate Technology Center cementing specialists (for the EXcape string). BJ Services looks forward to working together with Marathon Oil Company on the KBU 44-6 well. I look forward to meeting with you to discuss all in detail when convenient. Thank you for giving BJ Services the opportunity to submit this proposal. If you have any questions or require additional information, please contact me. Sincerely, J. Jay Garner Manager, City Sales (907) 349-6518, Anchorage (Bus Phone) BJ Services Company cc: Gr4103 SCANNED JUL 2 1 2004 Prepared for: Will tank Senior Drilling Engineer Marathon Oil Co. Service Point: Kenai Bus Phone: ) Marathon Oil CO KBU 44-6 I Pad 41-7 Glacier no. 1 Rig Kenai Gas Field Kenai County, Alaska January 29, 2002 Well Recommendation ) (£j Proposal No: 100169741B Prepared by: J. Jay Garner Manager, City Sales Kenai, Alaska Bus Phone: (907) 349-6518, Anchorage Email: jgarner@bjservices.com ....... POWE R V I S I ON~ (907) 776-8182 (907) 659-2329 Service Representatives: J. Jay Garner Manager, City Sales Kenai, Alaska Bus Phone: (907) 349-6518, Anchorage Email: jgarner@bjservices.com Gr4105 SCANNED JUL 2 1 2004 Operator Name: Marathon Oil Co Well Name: KBU 44-6 I Pad 41-7 Job Description: Surface Casing Date: January 29,2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via Total Mix Water Required Spacer Mud Clean II Density Cement Slurry Suñace Cement Density Yield Displacement Drilling Mud Density Report Printed on: January 29, 2002 6:06 PM ) ) Wj Proposal No: 100169741B 1,500 ft 1,501 ft 17.5 in Casino 133/8" 0.0. (12.515" .1.0) 61 # 133/8in, 61 Ibs/ft Page 1 7,025 gals 40 bbls 8.4 ppg 648 sacks 12.0 ppg 2.50 cf/sack 216 bbls 9.0 ppg Gr4109 SCANNED JUL 2 1 2004 ) ) Operator Name: Marathon Oil Co Well Name: KBU 44-6 I Pad 41-7 Job Description: Surface Casing Date: January 29, 2002 Wj Proposal No: 100169741B WELL DATA ANNULAR GEOMETRY ANNULARl.D. (in) 18.730 CASING 17.500 HOLE DEPTHCft) MEASURED I TRUE VERTICAL 116 I 116 1,501 I 1,500 SUSPENDED PIPES DIAMETER .. (in) O.D. I 13.375 I I.D. 12.515 WEIGHT (Ibs/ft) 61 DEPTH(ft) MEASURED I TRUEVERTICAL 1,501 I 1,500 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 1,421 ft 9.00 ppg Water Based 850 F 800 F VOLUME CALCULATIONS 116 ft x 0.9377 cf/ft 1,385 ft x 0.6946 cf/ft 80 ft x 0.8543 cf/ft with 0 % excess = with 50 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 108.8 cf 1443.1 cf 68.3 cf (inside pipe) 1620.2 cf 289 bbls = Report Printed on: January 29, 2002 6:06 PM Page 2 Gr4115 SCANNED JUL 2 1 2004 ) Operator Name: Marathon Oil Co Well Name: KBU 44-6/ Pad 41-7 Job Description: Surface Casing Date: January 29, 2002 FLUID SPECIFICATIONS Spacer ) Wj Proposal No: 100169741B 40.0 bbls Mud Clean II @ 8.4 ppg FLUID VOLUME VOLUME CU-FT FACTOR AMOUNT ANn TYPF OF CFMFNT 1620 2.5 = 648 sacks Type I Cement + 1.5% bwoc Calcium Chloride + 20% bwoc LW-6 + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 1 % bwoc Sodium Metasilicate + 20% bwoc MPA-1 + 96.2% Fresh Water 216.2 bbls Drilling Mud @ 9 ppg Cement Slurry Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Estimated Pumping Time - 100 BC (HH:MM) Free Water (mls) @ 90 0 F @ 90 0 angle Fluid Loss (cc/30min) at 1000 psi and 900 F COMPRESSIVE STRENGTH 8 hrs @ 90 0 F (psi) RHEOLOGIES FLUID Cement Slurry TEMP @ 85 0 F Report Printed on: January 29, 2002 6:06 PM SLURRY NO.1 12.00 2.50 10.84 10.85 5:30 6:00 0.0 812.0 500 600 116 100 55 3 26 6 32 300 78 200 68 Page 3 Gr4129 SCANNED JUL 2 1 2004 0p,erator Name: Marathon Oil Co Well Name: K8U 44-6 / Pad 41-7 Job Description: Intermediate Casing Date: January 29,2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via Total Mix Water Required Weighted Spacer MCS-4D Density 1 st Lead Slurry Lead Cement Density Yield Tail Slurry Intermediate Tail Density Yield Displacement Drilling Mud Density Report Printed on: January 29, 2002 6:07 PM ) 5,300 ft 5,420 ft 12.25 in Casina 95/8" O.D. (8.835" .I.D) 40 # 95/8 in, 40 Ibs/ft Page 6 6,703 gals 40 bbls 10.0 ppg 93 sacks 12.0 ppg 2.53 cf/sack 616 sacks 13.5 ppg 1.84 cf/sack 405 bbls 9.2 ppg ) [£j Proposal No: 1001697418 ., '._.~.---"'---................. ,.... ,. Gr41 09 SCANNED JUL 2 1 2004 ) ') " Operator Name: Marathon Oil Co Well Name: KBU 44-6/ Pad 41-7 Job Description: Intermediate Casing Date: January 29, 2002 !£j Proposal No: 100169741B WELL DATA ANNULAR GEOMETRY ANNULARI.D. (in) 12.515 CASING 12.250 HOLE DEPTHlft) MEASURED I TRUEVERTICAL 1,501 I 1,500 5,420 I 5,300 SUSPENDED PIPES DIAMETER (in) 0.0. I 9.625 I 1.0. 8.835 WEIGHT (Ibs/ft) 40 DEPTH(ft) MEASURED I TRUE VERTICAL 5,420 I 5,300 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 5,340 ft 9.20 ppg Water Based 110 0 F 105 0 F VOLUME CALCULATIONS 500 ft x 0.3132 cf/ft 1,920 ft x 0.3132 cf/ft 80 ft x 0.4257 cf/ft with 50 % excess = with 83 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 234.9 cf 1098.4 cf 34.1 cf (inside pipe) 1367.3 cf 244 bbls = Top of Lead Cement estimated to be 3,OOO'MD Top of Tail Cement estimated to be 3,500'MD ........:--.......-.... Report Printed on: January 29, 2002 6:07 PM Page 7 Gr4115 ---'.'---"':._ -!- SCANNED .1l1I 2 1 2004 ) Operator Name: Marathon Oil Co Well Name: KBU 44-61 Pad 41-7 Job Description: Intermediate Casing Date: January 29,2002 FLU ID SPECIFICATIONS Weighted Spacer FLUID VOLUME CU-FT 15t Lead Slurry 235 Tail Slurry 1132 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Estimated Pumping Time - 100 BC (HH:MM) Free Water (mls) @ 1000 F @ 90 0 angle Free Water (mls) @ 100 0 F @ 45 0 angle Fluid Loss (cc/30min) at 1000 psi and 100 0 F COMPRESSIVE STRENGTH 8 hrs @ 1000 F (psi) 16 hrs @ 100 0 F (psi) 24 hrs @ 100 0 F (psi) 48 hrs @ 100 0 F (psi) 72 hrs @ 1000 F (psi) 96 hrs @ 1000 F (psi) RHEOLOGIES FLUID Tail Slurry TEMP @ 90 0 F Report Printed on: January 29, 2002 6:08 PM VOLUME FACTOR /' 2.53 ) Wj Proposal No: 100169741B 40.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 1 Ibs/bbl Cello Flake + 20 Ibs/bbl Kol Seal + 30.8 Ibs/bbl Bentonite + 92 Ibs/bbl Barite, Bulk @ 10 ppg J 1.84 AMOUNT ANn TYPF OF CFMFNT ../ = 93 sacks Class G Cement + 0.75% bwoc Calcium Chloride + 20% bwoc LW-6 + 0.25 Ibs/sack Cello Flake + 0.4% bwoc CD-32 + 5 Ibs/sack Kol Seal + 1 % bwoc Sodium Metasilicate + 20% bwoc MPA-1 + 94.3% Fresh Water ,/ = 616 sacks Class G Cement + 10% bwoc BA-90 + 2% bwoc Calcium Chloride + 2.5% bwoc BA- 56 + 0.1% bwocASA-301 + 1 gals/100 sack FP- 6L + 0.5% bwoc Sodium Metasilicate + 82.3% Fresh Water 404.9 bbls Drilling Mud @ 9.2 ppg SLURRY SLURRY NO. 1 NO.2. J / 12.00 13.50 2.53 1.84 10.63 9.28 10.63 9.29 7:30 7:31 0.0 0.0 10.0 60 500 820 1410 1925 2203 600 216 300 134 200 98 100 58 6 13 3 12 Page 8 Gr4129 SCANNED JUL 2 1 2D04 ) ) Operator Name: Marathon Oil Co Wèll Name: KBU 44-6 / Pad 41-7 Job Description: Intermediate Casing Date: January 29, 2002 f£j Proposal No: 100169741B FLUID SPECIFICATIONS (Continued) Slight additive adjustments should be expected to achieve the desired slurry properties. Lost Circulation while drilling this section is anticipated. Use of Lost Circulation material in the MCS-4D Spacer system and the lead cement is recommended to aid in maintaining circulation during the cement job. Report Printed on: January 29. 20026:08 PM Page 9 "':' Gr4129 SCANNED JUl 2 1 2004 Operator Name: Marathon Oil Co Well Name: KBU 44-6/ Pad 41-7 Job Description: EXcape String Date: January 29, 2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via Total Mix Water Required Weighted Spacer MCS-4D Density Cement Slurry EXcape String Slurry Density Yield Displacement 3% KCL Water Density Report Printed on: January 29, 2002 6:08 PM ') 7,200 ft 7,320 ft 8.5 in Casina 3 1/2" O.D. (2.922" .I.D) 9.3 # 3 1/2 in, 9.3 Ibs/ft Page 12 3,887 gals 50 bbls 10.5 ppg 772 sacks 15.7 ppg 1 .18 cf/sack 60 bbls 8.4 ppg ) Wj Proposal No: 100169741B Gr4109' . SCANNED JUL 2 1 2004 ') ) Operator Name: Marathon Oil Co wèll Name: KBU 44-6/ Pad 41-7 Job Description: EXcape String Date: January 29, 2002 (£j Proposal No: 100169741B WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 8.835 CASING 8.500 HOLE DEPTHlft) MEASURED I TRUE VERTICAL 5,420 I 5,300 7,320 I 7,200 SUSPENDED PIPES DIAMETER (in) O.D. 3.500 I I.D. 2.922 WEIGHT (Ibs/ft) I 9.3 DEPTH(ft) MEASURED ·TRUEVERTICAL 7,320 I 7,200 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 7,240 ft 9.50 ppg Water Based 133 0 F 120 0 F VOLUME CALCULATIONS 220 ft x 0.3589 cf/ft 1,877 ft x 0.3272 cf/ft 80 ft x 0.0466 cf/ft with 0 % excess = with 35 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 79.0 cf 829.2 cf 3.7 cf (inside pipe) 911.9 cf 163 bbls = Report Printed on: January 29, 2002 6:09 PM Page 13 Gr4115 SCANNED JUl 2 1 2004 ) Operator Name: Marathon Oil Co Wèll Name: KBU 44-61 Pad 41-7 Job Description: EXcape String Date: January 29, 2002 FLU ID SPECIFICATIONS Weighted Spacer ) !£j Proposal No: 100169741B 50.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 9 Ibs/bbl Potassium Chloride + 30.15 Ibs/bbl Bentonite + 119 Ibs/bbl Barite, Bulk @ 10.5 ppg FLUID VOLUME VOLUME CU-FT FACTOR AMOUNT AND TYPF OF CFMFNT Cement Slurry 912 1.18 = 772 sacks Class G Cement + 0.9% bwoc BA-10 + 0.1 % bwoc R-3 + 2% bwow Potassium Chloride + 0.2% bwoc FL-63 + 0.6% bwoc CD- 32 + 1 gals/100 sack FP-6L + 0.15% bwoc Sodium Metasilicate + 44.7% Fresh Water Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Estimated Pumping Time -100 BC (HH:MM) Free Water (mls) @ 1050 F @ 90 0 angle Fluid Loss (cc/30min) at 1000 psi and 1050 F COMPRESSIVE STRENGTH 5 hrs @ 130 0 F (psi) 6 hrs @ 130 0 F (psi) 24 hrs @ 1300 F (psi) RHEOLOGIES FLUID Cement Slurry TEMP @ 105 0 F 59.9 bbls 3% KCL Water @ 8.4 ppg SLURRY NO.1 15.70 1.18 5.03 5.04 4:22 4:32 0.0 24.0 50 500 2431 600 231 300 145 200 104 100 60 6 15 3 14 Slight additive adjustments should be expected to achieve the desired slurry properties based on pilot blend and Gas Flow Model testina conducted at PRTC and TTC resDectfullv. Report Printed on: January 29, 2002 6:09 PM Page 14 Gr4129 SCANNED JUL 2 1 2004 ) Operator Name: Marathon Oil Co Well Name: KBU 44-6 / Pad 41-7 Job Description: EXcape String Date: January 29,2002 ) Wj Proposal No: 100169741B PROCEDURE Cementing Procedure for: KBU 44-6 EXcape Casing String Pre-Job QAlQC and Simulation Requirements: 1. EXcape cementing system to pilot blend tested @ PRTC to establish preliminary performance properties. 2. Results of pilot blend testing to be forwarded to TTC for use in gas flow modeling. Final slurry to be modified as required to yield anti-gas migration properties 3. CEMFACTS and SURGE simulations to be run well in advance of moving onto the EXcape operation to confirm casing rih speeds and appropriate cement pump rates. Concerns Associated with EXcape String Cementing: 1. Effective wellbore cleaning 2. Centralization of eccentric casing string with turbolizers is critical to enhance mud mobility 3. Effective drilling mud managemenUconditioning; PV & YP values lowered before job. Longer rih times can yield an increase in mud gel strength, therefore, extra hole circulations during running and once pipe is on bottom are required. 4. Friction pressure and ECD effects. 5. Reciprocation during cementing operations OK based on risk assessment of sticking pipe 6. Long rih times can yield increased gel strength of mud, therefore, extra hole circulations during running and once on-bottom are recommended. 7. Remedial cementing is not 'an option, plan, communicate, test, evaluate risks and execute the job correctly the first time. Operational Procedure: 1. BJ Services Service Supervisor to meet with Marathon drilling / field personnel to discuss equipment rig up and job requirements in detail. 2. All equipment to be inspected and function tested at the Kenai District to confirm ready status prior to mobilizing to location. 3. MIRU to cement the KBU 44-6 3 11" EXcape casing string to a depth of 7,320'MD /7,200'TVD. 4. All cementing fluids to be batch mixed according to BJS EXcape cementing standard practices. Based on preliminary cement design 2 batch mixing units will be required unless a variance to standard is agreed to by Marathon engineering. 5. RU to electronics to facilitate enhanced data acquisition during cementing operations. 6. RU to monitor / display Promore gauge data in treating van. 7 Perform all location QC tests on mix waters. 8. Batch mix EXcape slurry performing QAlQC tests to confirm integrity. 9. Conduct safety and operations meeting with all location personnel. 10. Pressure treating lines to operator's specifications. 11. Pump / displace cementing job according to the attached program at a rate consistent with CEMFACTS simulation or as agreed upon with Marathon engineering. 12. Reduce rate prior to bumping plug. 13. Bump plug and hold pressure as per Marathon's specifications. 14. Release pressure and test float. 15. RDMO 16. Post job meeting to be conducted with Marathon engineering / operations to discuss Lessons Learned Report Printed on: January 29, 2002 6:09 PM Page 15 Gr4135 SCANNED JUL 2 1 2004 ) )' aöb Y/7¡ ~~!Æ~E :} !Æ:!Æ~~~!Æ ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 October 15,2001 Robert Watkins State of Alaska Department of Environmental Conservation 555 Cordova St. Anchorage, AK. 99501 Dear Robert: Marathon continues to perform the periodic inspections of the Spark and Spur Platforms as conditioned in the initial exemption from the oil spill contingency plan for these facilities. Jeff Jones, one of our inspectors accompanied the last inspection and found no problems. Tom Maunder and I both recommend these facilities remain exemptible from an oil spill contingency plan. The KBD 44-6 and KD 24-5 wells are Kenai Gas Field wells. There is no oil in the Kenai structure and never has been. We consider the Kenai Field as a gas only field; all wells within it are gas wells. If you have any questions or concerns, please contact Tom Maunder or myself at 279-1433. Sincerely ~dllil Senior Petroleum Geologist SCANNED JUL 2 1 2004 ~=~=E ~ ) F ~~~~~~~ ) ~ TONY KNOWLES, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Peter K. Berga . Drilling Superintendent Marathon Oil Company P.O. Box 196168 i\nchorage,AJ( 99519-6168 RE: Kenai Unit KBU 44-6 Marathon Oil Company Permit No: 200-179 Sur. Loc. 39' FNL, 4282' FWL, Sec. 7, T4N, R11W, SM Btmhole Loc. 748' FSL, 4597' FWL, Sec. 6, T4N, R11 W, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Exception to 20 ACC 25.035(c)(1)(b) to drill 17-l/2" hole using a 16" diverter line is approved. Annular disposal has not been requested as part of the Permit to Drill application for Kenai Unit KBU 44-6. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of diverter and BOPE tests must be given so that a representative of the Commission may witness or waive witnessing the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, '" ff iel T.Zunt, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this13th day of September 2001 . jjc/Enc1osures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. \ dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. SCANNED JUL 2 1 2004 gøg;l~;~~~I",,09,optdki· ORIGINAL"f0 DP::P ~ //210 í Type of well. ExploratoryD Stratigraphic TestD Development oilD ServiceD Development Gas0 Single ZoneD Multiple Zone0 5. Datum Elevation (DF or KB) 10. Field and Pool 87' KB feet Kenai Gas Field/Beluga '} ) i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 210 MC 25.005 Re-DrillD DeepenD 1a. Type of Work Drill0 Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 39'FNL, 4282'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 748'FSL, 4597'FWL, Sec. 6, T4N, R11W, S.M. At Total Depth 748'FSL, 4597'FWL, Sec. 6, T4N, R11W, S.M. 1b. 6, Property Designation A-028142 7. Unit or Property Name Kenai Unit 8. Well Number KBU 44-6 9. Approximate Spud Date 2/1/2001 14. Number of Acres in Property 13. Distance to Nearest Well 12. Distance to Nearest Property Line(unit boundary) 1 0, 1 00 feet 16. To be Completed for Deviated Wells Kickoff Depth 1500 feet Maximum Hole Angle 18. Casing Program Size 800 feet 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) 7315' MD/7200' TVD feet 18 0 6000 17. Anticipated Pressure (see 20 MC 25.035 (e) (2)) Maximum Surface 2542 pslg at Total Depth (TVD) Setting Depth 7200' Hole Casing Weight Driven 20" 133 17-1/2" 133/8" 61 121/4" 9 5/8" 40 8 1/2" 3 1/2" 9.2 Specifications Grade Coupling K-55 PE K-55 BTC L-80 BTC L-80 EUE 8rd Top Bottom Quantity of Cement Length MD TVD MD TVD (including stage data) 80-100' 0' 0' 80-100' 80-100' 1500' 0' 0' 1500' 1500' 656 sx 5415' 0' 0' 5415' 5300' 945 sx 7315' 0' 0' 7315' 7200' 685 sx R F' (.~. ![~. ~ ·V· W"""'" D - n ,"IJ I::IL m' [:':1 - 1" '\ f 1", í) (' {' '" " ~.J. t..l L ,-vVJ Alaska Oil & Gas Cons. Commission Kenai Unit well KBU 44-6 will be direction ally drilled to an estimated total depth of 73151 Mlä\1otœmt.1erVD from the existing Kenai Gas Field pad 41-7.The production interval will be cased with 3.5", cemented in place and run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing Fee0 Property P1at0 BOP Sketch 0 Drilling Fluid Program0 Time vs Depth PlotD Refraction AnalysisD 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Phone: 564-6319 Craig Young 564-6310 Title Drilling Superintendent Diverter Sketch 0 Seabed ReportD Signed ~ P. K. Berga Drilling Program 0 20 AAC 25.050 RequirementsD Date: 10/25/2000 Commission Use Only Permit Number '/ f-Y~) _ I '7CJ API Number . ',,' Approval Date () \ fJ.. h \ ~L--t_ j 50-- /33 - .2.-6 ý<:jC; - ¿).) '-J\. \:.J · V Conditions of Approval Samples Required DYes IZJNo Mud Log Required DYes [g]No Hydrogen Sulfide Measures DYes [R]No , Directional Survey Required [K]Yes DNo Required Working Pressure for BOPE D2M ~3M D5M D10M D15M Other: Approved by Form 10-401 Rev. 12-1-85 ORIGINAL SIGNED B'Y o Taylor Seamount by order of (\ \[,b 0 \ Commissioner eCI ANN~ cOJmUmlissi02n 1 2DOD4ate "'\ " tU ~ubm in· Triplicate See Cover Letter For Other Requirements Re: Diverter Exception 24-6144-6 -Reply ) ) Subject: Re: Diverter Exception 24·6/44-6 -Reply Date: Mon, 29 Jan 2001 16:34:22 -0600 From: "Craig E Young" <ceyoung@marathonoil.com> To: torn_maunder@admin.state.ak.us Tom, These wens are set up like KBU 42..7, with a single string of 3 1/2" tubing cemented in place as the production casing. No tubing will be run as the well will flow up the 3 1/2" production casing. The reason for the large hole(8 1/2") is that the perforating guns will be run on the outside of the 3 1/2" production casing and cemented in place. The guns will be activated with a control line to the surface. Marathon is requesting a waiver so that a 16" diverter line may be used while drilling the 17 1/2" surface hole. Both wells are drilled off pads with recent wells that did not encounter any gas in the surface hole. A geologic review indicates that no gas is expected in the surface hole section. Attached is a revised Potential Hazard section for KBU 24..6. The one for KBU 44-6 looks OK. Let me know if you need any additional information. Craig »> Tom Maunder <tom_maunder@admln.state.ak.us> 01/27/01 10:04am »> Craig, After reviewing the application, I have a few other questions. Will this well be set up for annular flow like 31..7X?? It is proposed to set dual strings, one 1uIl3-1/2" and the other 3-1/2" x 2-7/8". Is this still the plan?? If so do you have dual rams available for the stack?? The heading for you potential hazards on page 10 is labeled 33-6. You will need to provide the "postable" hazard sheet. I think you submitted one for the other wells. Thanks for you attention to these questions. Tom T om Maunder wrote: :> Craig, > I am working on the applications for these wells. I will need a request > for diverter exception for both of them. Other items / understand that > may have changed are still having the 2 ram/annular stack and running > the escape system. Please get back to me on these items and the permits > will issue. Thanks. > Tom ,_..__.__.__.'____________________________0__0..__._____~_____.~__'. __..._._____.~____.__...___.._.,_.__..,.______._____.,__.__.__.___~__.___.._______.__._..._________._.___,_,.___ __, _____ _____L_~__._.. ---..~-~-L."~.~-..'~~.r _".,_._ _~____.~_~__..~___~._.~.__"'__,~____~~__M ___.. ._ ~,__..__~_._.,.~"_.w_~,___,_ '~L_~_.~~~._, ,______~.,,~~.__._,____"......__,_____.__ Name: 246HAZ.XLS I [J246HAZ.XLS! Type: Microsoft Excel Worksheet (application/vnd.ms-excel) I ,_.._~_..._~...._.___.____..J~_f!~~~!~~.:_.~~~~.~~___..___...........__.. ......___._..__...__..._____._. ..__..._..__...._...._.._..~....._._......__.._~_....._.' 1of2 1/29/011:58 PM Re:DNerter~ion24-6f44~.Rep~ ) ) SUbject: Re: Diverter Exception 24-6144..6 -Reply Date: Mon, 29 Jan 2001 16:36:40 -0600 From: "Craig E Young" <ceyoung@marathonoil.com> To: tom_maunder@admin.state.ak.us Tom, The BOP system will include the 2 ram/annular system that was approved for KBU 42..7. Since MASP is under 3000 psi this should be sufficient. Let me know if you need any additional information. Craig »> Tom Maunder <tom_maunder@admin.state.ak.us> 01/27/01 10:04am »> Craig, After reviewing the application, I have a few other questions. Wilt this well be set up for annular flow like 31-7X?? It is proposed to set dual strings, one full 3..1/2" and the other 3...1/2" x 2... 7/811. Is this still the plan?? If so do you have dual rams available for the stack?? The heading for you potential hazards on page 10 is labeled 33..6. You will need to provide the "postable" hazard sheet. I think you submitted one for the other wells. Thanks for you attention to these questions. Tom Tom Maunder wrote: > Craig, > I am working on the applications for these wells. I will need a request ;> for diverter exception for both of them. Other items I understand that > may have changed are still having the 2 ram/annular stack and running > the escape system. Please get back to me on these items and the permits > wíIJ issue. Thanks. > Tom 1 of 1 1/29/01 1:59 PM .) ) Alaska Region Domestic Production / M \ Marathon \IAARATHo~1 Oil Company P.O. Box 196168 Anchorage, AK 99519:.6168 Telephone 907/561-5311 Fax 907/564-6489 November 1, 2000 Mr. Robert N. Christianson Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KBU 44-6 Dear Mr. Christianson: Enclosed is the application for permit fo,drill the referenced well and a check for $100.00. Please feel free to contacfeither myself at 564-9319, pkberga@marthonoil.com or Craig Young at 564-6310, ceyoung@marathonoil.com. Sincerely, Ç7~ P. K. Berga Drilling Superintendent PKB:bjv N:\DRLG\KGF\WELLS\KBU 44-6\aogccclt.doc Enclosure RE' '("i·"·i'.l'·'·""" "; ,,, " " , 1,: ') :y,:¡¡,,,,,,,," ", ~ )t1 ~ \LI!,'¡ ~i. ..,:t. '. ,,- ~ ~\I,r( ~/~ L~ )10, '-= J¡ pJ // '" ''''''/''' .. ' : ,/ . ,r", "".. ( .' "') ~.' '"" ,"' '..... '- :";v.) Alaska Oil & Gas An Cons. CommiQfþ' chorage ~lOn ORIGINAL SCANNED JUL 2 1 200~ (Other Instructions on reverse side) \RM APPROVED )AB NO. 1004-0136 Form 3160-3 (July 1992) UNITE )ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUBMIT IN TRIPLICATE" Expires: February 28, 1995 5. Lease Designation and Serial No. APPLICATION FOR PERMIT TO DRILL OR DEEPEN 1 a. TYPE OF WORK A-028142 6. If Indian, Allottee or Tribe Name DRILL EJ b. TYPE OF WELL Oil Gas Well 0 Well 0 Other 2. Name of Operator Marathon Oil Company 3. Address and Telephone No. P.O> Box 196168, Anchorage AK 99519-6168 4. Location of Well (Report location clearly and in accordance with any State requirements,") At surface 39' FNL, 4282'FWL, Sec.7 T4N, R11W, S.M. At proposed prod. zone 748'FSL, 4597'FWL, See 6, T4N, R11W, S.M. 14. Distance in Miles and Direction from Nearest Town or Post Office" 6.5 miles south of Kenai, Alaska DEEPEN D Single Multiple Zone D Zone [8] 7. Unit Agreement Name Kenai Beluga Unit 8. Farm or Lease Name, Well No. KBU 44-6 9. API Well No. 10. Field and Pool, or Wildcat Kenai Gas Field 11. Sec., T., R., M., or BLK. and Surveyor Area See 7, T4N, R11W, S.M. 12. County or Parish Kenai Peninsula 13. State AK 15. Distance from Proposed" Location to Nearest Property or Lease Line, ft. 10,100 (Also to nearest drig. unit line, if any) 18. Distance from Proposed Location" to Nearest Well, Drilling, Completed, or Applied for, on this Lease, Ft. 800 21. Elevations (Show whether DF, RT, GR, etc.) 87' KB 16. No. of Acres in Lease 17. No. of Acres Assigned to this Well 6000 19. Proposed Depth 640. 20. Rotary or Cable Tools 7315' MD,7200' TVD Rotary 22. Approx. Date Work Will Start" 2/1/01 23. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE 80-100' 0' 0' 80-1 00' 80-100'1 17-1/2" 13 3/8" 61 K-55 BTC 1500' 0' 0' 1500' 1500' 656 sx 12 1/4" 95/8" 40 L-80 BTC 5415' 0' 0' 5415' 5300' 945 sx 81/2" 3 1/2" 9.2 L-80 EUE 8rd 7315' 0' 0' 7315' 7200' 685 sx IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. SIGNED Ø(~ (This space for Feder~1 or Stare office use) Phone: 564-6319 TITLE Drilling Superintendent DATE/¢~O PERMIT NO. APPROVAL DATE Application approval does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon. CONDITIONS OF APPROVAL, IF ANY: "See Instruction on Reverse Side . .~".:.,.. Title 18 U.S.C. Section 1001, makes It a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. R·'· ,"-"",,'",.",~:, :;"''''-,'' . ~f '-,~= b. \").', ~\"""'" ,;<""">., ;'j 9 fJ.~. (,'.:' / l2 ~0v) P(~h ~:JNED JUL 2 1 20041 "~aska Oil &. Gas Coos. Commission Anchorage O:IEXCELIBLMAPPL.XLS 6/96 ) RECEIVED ) hÌ14/ l0'fo " . ;~, ',,' ')' ? f''' "': " ¡: J \) ( '- L ',) U J /,Cb;,:::,~ka UII & G1;:!~ Cum~. Cön'H'hb5¡ü¡' Coastal Pr8J~o~~eQuestionnaire and Certification Statement Please answer all questions. To avoid a delay in processing, please call the department if YOU answer "yes" to any of the questions related to that department. Maps and plan drawings must be included with your packet. An incomplete packet will be returned. · APPLICANT INFORMATION 1. Marathon Oil Company Name of Applicant P.O. Box 196168 Address Anchorage Alaska City/State 907-561-5311 Daytime Phone 907-564-6489 Fax Number 99519-6168 Zip Code 2. Robert J. Menzie, Jr. Agent (or responsible party if other than applicant) P.O. Box 196168 Address Anchorage City/State State 907 -564-6372 Daytime Phone 907 -564-6489 Fax Number Alaska Zip Code 99519-6168 Zip Code E-mail Address rjmenzie@marathonoi1.com E-mail Address · PROJECT INFORMATION Yes No 1. This activity is a: X new project 0 modification or addition to an existing project If a modification, do you currently have any State, federal or local approvals related to this activity? ......................... ................................................................................................. 0 0 Note: Approval means any form of authorization. If "yes," please list below: Approval Type Approval # Issuance Date Expiration Date 2. If a modification, has this project ever been reviewed by the State of Alaska under the ACMP?.......... 0 0 Previous State I.D. Number: AK Previous Project Name: · PROJECT DESCRIPTION 1. Provide a brief description of your entire project and ALL associated facilities and land use conversions. Attach additional sheet(s) as needed. Marathon Oil Company is proposing to drill and complete a directionally drilled natural gas development well, KBU 44-6, at the surface location described as 39 ft from the north line, 4282 ft from the west line of Sec. 7, T4N, R11W, Seward Meridian from existing gravel pad 41-7 in the Kenai Gas Field. The bottom hole location is 748 ft from the south line, 4597 ft from the west line of Sec. 6, T4N, R11W, Seward Meridian. Pad 41-7 is located 6.5 miles south of Kenai, Alaska. This project consists of drilling, groundwater use, and temporary waste storage. In order to protect surrounding wetlands and avoid potential hydrocarbon impacts from-the project, Marathon intends to take the following four precautions: 1) place a double liner beneath thè drilling rig, diesel Revised 1/99 Page 1 SCANNED JUL 2 1 2004 REC[1ED ~ ,....~;,' 0 2 ~'r.~\r'\ \ ,; \) ''¡ ¡;.. " ... ,) ) iè':igt~~a on & Gas Coos. Cormni5$ion ¡!\m;horage storage tank, and mud system; 2) use a double-walled diesel storage tank that has an annulus capable of containing 1100/0 of the volume of the inner tank; 3) place the diesel storage tank at least 100 feet away from the edge of the existing pad; and 4) store adequate spill response equipment on site to handle accidental leaks or spills of oil, gas, or other toxic materials. The liner consists of a bottom layer of geotextile felt overlain by a 20- mil-thick polyethylene liner. The edges of the liner are bermed using timbers that result in a freeboard of six inches. The total capacity of the lined area under the rig, diesel tank, and mud system is greater than the equivalent volume of 110% of the volume of the diesel tank plus 12 inches of freeboard. Proposed starting date for project: January 1,2001 Proposed ending date for project: December 31,2002 2. Attach the following: . a detailed description of the project, all associated facilities, and land use conversions, etc. (Be specific, including access roads, caretaker facilities, waste disposal sites, etc.); . a project timeline for completion of all major activities in the proposal; . a site plan depicting property boundary with all proposed actions; · other supporting documentation that would facilitate review of the project. Note: If the project is a modification, identify existing facilities as well as proposed changes on the site plan. . PROJECT LOCATION 1. Attach a copy of the topographical and vicinity map clearly indicating the location of the project. Please include a map title and scale. 2. The project is located in which region (see attached map): D Northern X Southcentral D Southeast D within or associated with the Trans-Alaska Pipeline corridor 3. Location of project (Include the name of the nearest land feature or body of water.)9 miles north of Ninilchik, Alaska Township: IN Range:13W Section: 23 Meridian: S Latitude/Longitude N 60og'/Wl5lo USGS Quad Map Kenai (A-4) 4. Is the project located in a coastal district? Yes X No D If yes, identify: Zone 17 Kenai Peninsula Borough (Coastal districts are a municipality or borough, home rule or first class city, second class with planning, or coastal resource seTi'ice area.) Note: A coastal district is a participant in the State's consistency review process. It is possiblefor the State review to be adjusted to accommodate a local permitting public hearing. Early interaction with the district is important; please contact the district representative listed on the attached contact list. 5. Identify the communities closest to your project location: Kenai, Alaska 6. The project is on: 0 State land or water* 0 Federal land X Private land o Municipal land 0 Mental Health Trust land *State land can be uplands, tidelands, or submerged lands to 3 miles offshore. See Question #1 in DNR section. Contact the applicable landowner(s) to obtain necessary authorizations. . DEPARTMENT OF ENVIRONMENTAL CONSERVATION (DEC) APPROVALS Yes No 1. Will a discharge of wastewater from industrial or cormnercial operations occur? .................................. 0 X Will the discharge be connected to an already approved sewer system? ................................................. 0 X Revised 1/99 Page 2 , ¡ ) RECEIVED ) t:·J·",\;, ju", 2 ~t\~" ¡. .. I.-.J ,,' 'J . .. /\!i::¡5Ka Oil & Gas Cons. COíl'!lm¡5~ion . ? WIll the project mc1ude a st~r;m.\Y.aœr co lectlOnldlscharge system. ....................................................... 0 X ¡¡",,,m;nUl 4:11JC:; 2. Do you intend to construct, install, modify, or use any part of a wastewater (sewage or greywater) disposal system? ...................... ........................ ................................................................ 0 X a) If so, will the discharge be 500 gallons per day or greater? .............................................................. 0 0 b) If constructing a domestic wastewater treatment or disposal system, will the system be located within fill material requiring a COE pennit? ....................................................... 0 0 If you answered yes to a) or b), answer the following: 1) What is the distance from the bottom of the system to the top of the subsurface water table? 2) How far is any part of the wastewater disposal system from the nearest surface water? Yes No 3) Is the surrounding area inundated with water at any time of the year? ............................................. 0 D 4) How big is the fill area to be used for the absorption system? (Questions 1 & 2 will be used by DEC to determine whether separation distances are being met; Questions 3 & 4 relate to the required size of the fill ifwetlands are involved.) 3. Do you expect to request a mixing zone for your proposed project? .................................................... 0 X (If your wastewater discharge will exceed Alaska water quality standards, you may apply for a mixing zone. If so, please contact DEC to discuss information required under 18 AAC 70.032.) 4. a) Will your project result in the construction, operation, or closure of a facility for the disposal of solid waste? ............ ...................................................................................................... 0 X (Note: Solid waste means drilling wastes, household garbage, refuse, sludge, construction or demolition wastes, industrial solid waste, asbestos, and other discarded, abandoned, or unwanted solid or semi-solid material, whether or not subject to decomposition, originating from any source. Disposal means placement of solid waste on land.) b) Will your project result in the treatment of solid waste at the site?................................................. 0 X (Examples of treatment methods include, but are not limited to: incineration, open burning, baling, and composting.) C) Will your project result in the storage or transfer of solid waste at the site? ....................................X 0 d) Will the project result in the storage of more than 50 tons of materials for reuse, recycling, or resource recovery? ...................................................................................................................... 0 X e) Will any sewage solids or biosolids be disposed of or land-applied to the site? ............................. 0 X (Sewage solids include wastes that have been removedfrom a wastewater treatment plant system, such as a septic tank, lagoon dredge, or wastewater treatment sludge that contain no free liquids. Biosolids are the solid, semi-solid, or liquid residues produced during the treatment of domestic septage in a treatment works which are land applied for beneficial use.) 5. Win your project require the application of oil, pesticides, and/or any other broadcast chemicals? ......................................... ................................................................................. ................... 0 X 6. a) Will you have a facility with industrial processes that are designed to process no less than five tons per hour and needs air pollution controls to comply with State emission standards? ........................................................................................................................ 0 X b) Will you have stationary or transportable fuel burning equipment, including flares, with a total fuel consumption capacity no less than 50 million Btu/hour? ...................................... 0 X c) Will you have a facility with incinerators having a total charging capacity of no less than 1,000 pounds per hour?....... ......... ...... ..... ........................................... ............. ........ ............... 0 X d) Will you have a facility with equipment or processes that are subject to Federal New Source Performance Standards or National Emission Standards for hazardous air pollutants? ...... 0 X i) Will you propose exhaust stack injection? ................. .......... ............... ........ .... ...... ..... .............. 0 X Revised 1/99 Page 3 RE:JE'VED ) , .. ~ 'I r.? 1""1".... "\ ì ': .) '} \) '- L Ij ì,J ) I\'ì:u':5ka on & Gas Cons. Comm~ssion e) Win you have a facility~lffio[RQepotential to emit no less than 100 tons per year of any regulated air con taminan t? .............................................................................................................. 0 X f) Win you have a facility with the potential to emit no less than 10 tons per year of any hazardous air contaminant or 25 tons per year of all hazardous air contaminants? ......................... 0 X g) Win you construct or add stationary or transportable fuel burning equipment of no less than 10 million Btu/hour in the City of Un alaska or the City of St. Paul? .....................'................. 0 X h) Win you construct or modify in the Port of Anchorage a volatile liquid storage tank with a volume no less than 9,000 barrels, or a volatile liquid loading rack with a design throughput no less than 15 million gallons? ...................................................................................0 X i) Will you be requesting operational or physical limits designed to reduce emissions from an existing facility in an air quality non attainment area to offset an emission increase Yes No from another new of modified facility? ................................................................................................... 0 X 7. Will you be developing, constructing, installing, or altering a public water system? .............................. 0 X 8. a) Will your project involve the operation of waterborne tank vessels or oil barges that carry crude or non-crude oil as bulk cargo, or the transfer of oil or other petroleum products to or from such a vessel or a pipeline system?................................................. 0 X b) Will your project require or include onshore or offshore oil facilities with an effective aggregate storage capacity of greater than 5,000 barrels of crude oil or greater than 10,000 barrels of non-crude oil? ............................................................................. 0 X c) Will you be operating facilities on the land or water for the exploration or production of hydrocarbons?.............................................................................................................................X 0 If you answered "NO" to ALL questions in this section, continue to next section. If you answered "YES" to ANY of these questions, contact the DEC office nearest you for information and application forms. Please be advised that all new DEC permits and approvals require a 30-day public notice period. DEC Pesticide permits take effect no sooner than 40 days after the permit is issued. Based on your discussion with DEC, please complete the following: Types of project approvals or pennits needed Date application submitted 9. Does your project qualify for a general permit for wastewater or solid waste? ....................................... 0 X Note: A general permit is an approval issued by DEC for certain types of routine activities. If you answered "YES" to any questions in this section and are not applying for DEC permits, indicate reason: o (DEC contact) told me on that no DEC approvals are required on this project because X Other: ADEC permits are not required for this project. . DEPARTMENT OF FISH & GAME (DFG) APPROVALS 1. Will you be working in, removing water or material from, or placing anything in, a stream, river or lake? (This includes work or activities below the ordinary high water mark or on ice, in the active flood plain, on islands, Revised 1/99 Page 4 Rf:JEIVED ) ~, ',-' r i~) ',r' /"', 2 r r ::. !\ I, ..J" U L,,¡'lj,J (,>c¡:5ka Oil 8. Gas Coos. Commisßion in or on the face of the banks, or, for ~it~~M!"ing or flowing through tidelands, above the level of mean lower low tide.) Note: If the proposed project is located within a special flood hazard area, afloodplain development permit may be required. Contact the affected city or borough planning department for additional information and a floodplain determination.) ................. 0 X Name of waterbody: 2. Will you do any of the following: ...........................................................................................................0 X Please indicate below: o Build a dam, river training structure, other 0 Build a bridge (including an ice ,instream impoundment, or weir bridge) o Use the water 0 . Use the stream, lake or waterbody as a o Pump water into or out of stream or lake road (even when frozen), or cross the (including dry channels) stream with tracked or wheeled o Divert or alter the natural stream channel vehicles, log-dragging or excavation o Change the water flow or the stream channel equipment (backhoes, bulldozers, etc.) o Introduce silt, gravel, rock, petroleum 0 Install a culvert or other drainage structure products, debris, brush, trees, chemicals, or 0 Construct, place, excavate, dispose or remove other organic/inorganic material, including any material below the ordinary high water of a waste of any type, into the water waterbody o Alter, stabilize or restore the banks of a river, 0 Construct a storm water discharge or drain into stream or lake (provide number of linear feet the waterbody affected along the bank( s) 0 Place pilings or anchors o Mine, dig in, or remove material, including 0 Construct a dock woody debris, from the beds or banks of a 0 Construct a utility line crossing waterbody 0 Maintain or repair an existing structure o Use explosives in or near a waterbody 0 Use an instream in-water structure not mentioned here Yes No 3. Is your project located in a designated State Game Refuge, Critical Habitat Area or State Game Sanctuary? .... ........ ...... ....... .... .................................... .............,'.... ... ...... ........ ............ ........... 0 X 4. Does your project include the construction/operation of a salmon hatchery? ......................................... 0 X 5. Does your project affect, or is it related to, a previously permitted salmon hatchery? ............................ 0 X 6. Does your project include the construction of an aquatic farm? ............................................................. 0 X If you answered "No" to ALL questions in this section, continue to next section. If you answered "Yes" to ANY questions under 1-3, contact the Regional or Area DFG Habitat and Restoration Division Office for information and application forms. If you answered "Yes" to ANY questions under 4-6, contact the DFG Commercial Fisheries Division headquarters for information and application forms. Based on your discussion with DFG, please complete the following: Types of project approvals or pennits needed Date application submitted If you answered "YES" to any questions in this section and are not applying for DFG permits, indicate reason: o (DFG contact) told me on that no DFG approvals are required on this project because Revised 1/99 Page 5 It- RE:"lEIVED ) t . '. ., (', 2 r.." ~ J I " \,' ~ ,) LL \ :' \', ..1., IJ ""', o Other: "\~::lska Oil & Gas Cons. Commission ¡:\iì:chorage . DEPARTMENT OF NATURAL RESOURCES (DNR) APPRO V ALS 1. Is the proposed project on State-owned land or water or will you need to cross State-owned land for access? ("Access" includes temporary access for construction purposes. Note: In addition to State-owned uplands, the State owns almost all land below the ordinary high water line of navigable streams, rivers and lakes, and below the mean high tide line seaward for three miles.) ......................................................................................................... 0 X a) Is this project for a commercial activity? ...........................................................................................X 0 2. Is the project on Alaska Mental Health Trust land (AMHT) or will you need to cross AMHT land? Note: Alaska Mental Health Trust land is not considered State landfor the purpose of ACMP reviews. ...................................0 X 3. Do you plan to dredge or otherwise excavate/remove materials on State-owned land? .......................... 0 X Location of dredging site if different than the project site: Township Range Section Meridian USGS Quad Map 4. Do you plan to place fill or dredged material on State-owned land?...................................................... 0 X Location of fill disposal site if other than the project site: Township Range Section Meridian USGS Quad Map Source is on: 0 State Land 0 Federal Land 0 Private Land 0 Municipal Land 5. Do you plan to use any of the following State-owned resources: ............................................................ 0 X o Timber: Will you be harvesting timber? Amount: o Materials such as rock, sand or gravel, peat, soil, overburden, etc.: ............................................... Which material? Amount: Location of source: 0 Project site 0 Other, describe: Township Range Section Meridian USGS Quad Map Yes No 6. Are you planning to divert, impound, withdraw, or use any fresh water, except from an existing public water system or roof rain catchment system (regardless of land ownership)? ...............................X 0 Amount (maximum daily, not average, in gallons per day): 42.000 Source: existing water well Intended Use: drilling mud maintenance If yes, will your project affect the availability of water to anyone holding water rights to that water? ... 0 X 7. Will you be building or altering a dam (regardless of land ownership)?................................................ 0 X 8. Do you plan to drill a geothermal well (regardless of land ownership)? ................................................. 0 X 9. At anyone site (regardless of land ownership), do you plan to do any of the following? .......................0 X o Mine five or more acres over a year's time o Mine 50,000 cubic yards or more of materials (rock, sand or gravel, soil, peat, overburden, etc.) over a year's time o Have a cumulative unreclaimed mined area of five or more acres If yes to any of the above, contact DNR about a reclamation plan. If you plan to mine less than the acreage/amount stated above and have a cumulative unreclaimed mined area of less than five acres, do you intend to file a voluntary reclamation plan for approval? ..... 0 0 10. Will you be exploring for or extracting coal?......................................................................................... 0 X Revised 1199 Page 6 RE('~'VED ) ¡ . ~. . , ¡"? J" """'",\ :,)} \1 "- L'JUJ :»)!¿i~~~(a Oil & Gas Cons. Commission .'¡:;~\TithoK'age 11. a) Win you be exploring for or producing oil and gas? .........................................................................X 0 b) Win you be conducting surface use activities on an oil and gas lease or within an oil and gas unit? X 0 12. Win you be investigating, removing, or impacting historical or archaeological or paleontological resources (anything over 50 years old) on State-owned land?................................................................. 0 X 13. Is the proposed project located within a known geophysical hazard area?............................................. 0 X Note: 6 AAC 80.900(9) defines geophysical hazard areas as "those areas which present a threat to life or property from geophysical or geological hazards, including flooding, tsunami run-up, storm surge run-up, landslides, snowslides, faults, ice hazards, erosion, and littoral beach process." "known geophysical hazard area" means any area identified in a report or map published by a federal, state, or local agency, or by a geological or engineering consulting firm, or generally known by local knowledge, as having known or potential hazards from geologic, seismic, or hydrologic processes. 14. Is the proposed project located in a unit of the Alaska State Park System? ............................................ 0 X If you answered "No" to ALL questions in this section, continue to Federal Approvals section. If you answered "Yes" to ANY questions in this section, contact DNR for information. Based on your discussion with DNR, please complete the following: Types of project approvals or pennits needed Date application submitted If you answered "YES" to any questions in this section and are not applying for DNR permits, indicate reason: o (DNR contact) told me on that no DNR approvals are required on this project because,. X Other: Temporary Water Use Permit (TWUP A99-20) is in effect for the existine; water well. Other DNR permits are not required for this project. . FEDERAL APPROVALS Yes No U.S. Army Corps of Engineers (COE) 1. Will you be dredging or placing structures or fills in any of the following: tidal (ocean) waters? streams? lakes? wetlands*? ................................................................................... 0 X If yes, have you applied for a COE permit? ............ ........................................................... ................ 0 0 Date of submittal: (Note: Your application for this activity to the COE also serves as application for DEC Water Quality Certification.) *lfyou are not certain whether your proposed project is in a wetlands (wetlands include muskegs), contact the COE, Regulatory Branch at (907) 753-2720 for a wetlands determination (outside the Anchorage area call toUfree 1-800-478-2712). Bureau of Land Management (BLM) 2. Is the proposed project located on BLM land, or will you need to cross BLM land for access? .............0 X If yes, have you applied for a BLM permit or approval? ...................................................................X 0 Date of submittal: Pennit to Drill KBU 44-6, approximately 11/2/00 (pending) U.S. Coast Guard (USCG) 3. a) Will you be constructing a bridge or causeway over tidal (ocean) waters, or navigable rivers, streams or lakes?.............................................................................................................................. 0 X b) Does your project involve building an access to an island? ..............................................................0 X c) Will you be siting, constructing, or operating a deepwater port? ...................................................... 0 X Revised 1/99 Page 7 ~ R~\,EIVED ) r· .; / 0·, 2 "¡:(',,", I ,j ~ L'oi\)_) /Y:ii:1s!<a Oil & Gas Cons. Commission ffi t- If yes, have you appligl:ffQf:PffUSCG permit?............................................................................. 0 Date of submittal: u.s. Environmental Protection Agency (EPA) 4. a) Will the proposed project have a discharge to any waters? .............................................................. 0 b) Will you be disposing of sewage sludge (contact EPA at 206-553-1941)? ...................................... 0 If you answered yes to a) or b), have you applied for an EP A National Pollution Discharge Elimination System (NPDES) permit? ....................................................................................... 0 Date of submittal: (Note: For information regarding the needfor an NPDES permit, contact EPA at (800) 424-4372.) C) Will construction of your project expose 5 or more acres of soil? (This applies to the total amount of land disturbed, even if disturbance is distributed over more than one season, and also applies to areas that are part of Yes a larger common plan of development or sale.) ........ ................... ..... ............. ....... .......................... ............ ............. 0 d) Is your project an industrial facility which will have stormwater discharge which is directly related to manufacturing, processing, or raw materials storage areas at an industrial plant? ............0 If you answered yes to c) or d), your project may require an NPDES Stormwater permit. Contact EPA at 206-553-8399. Federal Aviation Administration (FAA) 5. a) Is your project located within five miles of any public airport? ........................................................0 b) Will you have a waste discharge that is likely to decay within 5,000 feet of any public airport?............ 0 If yes, please contact the Airports Division of the FAA at (907) 271-5444. Federal Energy Regulatory Commission (FERC) 6. a) Does the project include any of the following: 1) a non-federal hydroelectric project on any navigable body of water .......................................... 0 2) a location on federal land (including transmission lines) ........................................................... 0 3) utilization of surplus water from any federal government dam.................................................. 0 b) Does the project include construction and operation, or abandonment of natural gas pipeline facilities under sections (b) and (c) of the Federal Power Act (FP A)? ............................................. 0 c) Does the project include construction for physical interconnection of electric transmission facilities under section 202 (b) of the FP A? ..................................................................................... 0 If you answered yes to any questions under number 6, have you applied for a permit from FERC? ....................................................................................................................................... 0 Date of submittal: (Note: For information, contact FERC, Office of Hydropower Licensing (202) 219-2668; Office of Pipeline Regulation (202) 208-0700; Office of Electric Power Regulation (202) 208-1200.) u.s. Forest Service (USFS) 7. a) Does the proposed project involve construction on USFS land? ...................................................... 0 b) Does the proposed project involve the crossing of USFS land with a water line? ............................ 0 If the answer to either question is yes, have you applied for a USFS permit or approval?......... 0 Date of submittal: 8. Have you applied for any other federal permits or authorizations? ......................................................... 0 AGENCY APPROVAL TYPE DATE SUBMITTED Revised 1/99 Page 8 o x X o No X X X X X X X X X o X X o x R~'l::EIVED J .,1 Ü"\ 2' 1":'\1"'.",\ Ie .) .. £''';'1);} l\I:E1~ka 0i18! Gas Cons. Commission ,/\iI1choraJ;¡e Please be advised that the CPQ identifies permits subject to a consistency review. You may need additional permits from other agencies or the affected city and/or borough government to proceed with your activity. Certification Statement The information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alaska Coastal Management Prþ41. ' ~. ~;U- 1/ ~ Signature of A'JC;"~ I Date Note: Federal agencies conducting an activity that will affect the coastal zone are required to submit a federal consistency determination, per 15 CFR 930, Subpart C, rather than this certification statement. DGC has developed a guide to assist federal agencies with this requirement. Contact DGC to obtain a copy. This certification statement will not. be complete until all required State and federal authorization requests have been submitted to the appropriate agencies. . To complete your packet, please attach your State permit applications and copies of your federal permit applications to this questionnaire. Revised 1/99 Page 9 ) ) DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: PAD: SLOT: KBU 44-6 41-7 NA FIELD: AFE No.: TYPE: Kenai Gas Field Development. REVISION NO.: DATE: 1 0/23/2000 SURFACE LOCATION: 391 FNL, 42821 FWL, Sec. 7, T4N, R11W, S.M. TARGET: Middle Beluga 7481 FSL, 4597' FWL, Sec. 6 , T4N, R11W, S.M. BOTTOMHOLE LOCATION: 7481 FSL, 4597' FWL, Sec. 6, T4N, R11W, S.M. KB ELEVATION: GL ELEVATION: 87 ft. mean S.L. (est.) 66 ft. mean S. L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 3660 3592 Upper Beluga 4810 4697 Middle Beluga 5456 5341 Lower Beluga 6191 6076 Tyonek 7292 7177 R""""E"^""'J ! ,'.~' .r¡", !l~: .0 ~I"""" r· ,( C, r) t" "'" ~ . .' (. (-~vJ A~aska Oil &\ Gas Coos. Commission Anchorage II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) \ sO () 'S.\,)~c:.e: 3660 3592 481054 \S" '~~~¿"<4!.?: 4697 5456 5341 6191 6076 7292 7177 7315 7200 POTENTIAL CONTENT Sterling Upper Beluga Middle Beluga Lower Beluga Tyonek TO gas/water gas/water gas/water gas/water gas/water gas/water SCANNED JUL 2 1 2004 page 1 n:\drlg\kgf\wells\kbu 44-6\446prog.xls ) ) III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 21 1/4" X 2000 psi annular preventer and a 16" 0.0. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 751 from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/811 x 5000 psi drilling spool (mud cross) with 3-1/811 x 5000 psi outlets, and a 13-5/811 x 5000 psi single gate ram 1ype preventer with pipe rams. The choke manifold will be rated 3-1/811 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 wi II be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 21 1/411 2M Flange top x 2011 weld on bottom. R (;~~ ,,/Y W,' '!~, If ~F''' D" , ~ ~ ¡;j I""''' I 'Ii! """""",' ~, CASING HEAD: [" . r.~)';·':;"\J \~ ..... ',...,J t! " 13 5/811 3000 psi top x 13 3/811 sow bottom with base plate for 2011. Alaska Oif & Gas Cons. C,ommission Anchorage CASING SPOOL: 13 5/811 3M bottom X 1111 3M top TUBING HEAD: 1111·3M psi top x11" - 5M psi bottom. CHRISTMAS TREE: 3 1/8" - 5000 psi christmas tree including two master valves, one flow tee, one wing valve and one swab valve. SCANNED JUL 2 1 2004 page 2 n :\drlg\kgf\wells\kbu 44-6\446prog. xis ') ') IV. CASING PROGRAM: CASING DESCRIPTION SET SET HOLE TYPE SIZE WT. GRADE THREAD FROM TO (md/tvd) SIZE CONDUCTOR: 20" 133 ppf K-55 PE Surf 80-1 00/80- Driven 100 SURFACE: 13 3/8" 61 ppf K-55 BTC Surf 1500'/15001 17 1/2" INTERMEDIATE 9 5/8" 40 ppf L-80 BTC Surf 54151/53001 12 1/4" PRODUCTION: 31/2" 9.3 ppf L-80 EUE 8rd Surf 73151/72001 81/2" CASING DESIGN SETTING FRAC GRD FORM PRSS DESIGN FACTORS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP TENS COLL BURST 13 3/8" 61 ppf K-55 15001 11.5 686 802 4.18 2.20 1.99 95/811 40 ppf L-80 5300' 14.0 2350 2589 3.19 1.21 2.17 31/211 9.3 ppf L-80 72001 15.2 3370 2542 1.67 2.93 3.62 All tubulars are new. ~'") ~.:: ·'\;":'\;f:~ r\ ,6,,,, \"l' ~~'"':' I'D"' l:' r ',f r'" r; ,...."".. ! , .¡. I ,r .' 'l' J \J ........ I.- v ~. ,.t\!aska Oil & Gas Cons. Commission Anchorage ~. , -- SCANNED JUl 2 1 2004 page 3 n:\drlg\kgf\wells\kbu 44-6\446prog. xis v. CEMENTING PROGRAM SURFACE: 13 3/8" 15001/1500' SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: ') SURFACE 12 ppg. 2.38 cu. ft./sk 8.06 gal/sk hrs:min 50 % in open hole. 656 sks. ) RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. 3. M/U stabin float collar. (Baker-Iok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Run inner cementing string with stabing sub and centralizer. Baker has false rotary and slips. 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. 11. Displace cement. Sting out. 12. Check floats. 13. POOH with inner string. WOC 14. NID diverter. Weld on casing head and N/U blowout preventers. 15. Test BOPE. Run wear bushing. page 4 r~ fl:: {"\ r\ b,,,, ~"l' f!.:'J;;::r\ ~ )\ l",!i r _..' .' C 2 ~~ ~ ~_;,.) "í.\j@ska Oil & Gas Coos. Commission Anchorage n :\drlg\kgf\wells\kbu 44-6\446prog. xis ') v. CEMENTING PROGRAM (continued) PRODUCTION 9 5/8" @ 54151/5300' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 2500 ft. 12.8 ppg. 2.00 cu. ft./sk 11 .04 gal/sk hrs:min 50 % 570 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 4500 ft. 15.8 ppg. 1 .15 cu. fUsk 5.143 gal/sk hrs:min 50 % 375 sks. " RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-Iok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug wI 500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 15. Test BOPE. ~~,c~) f;~ :C _~, ill \..c"".., ~.". [,. ./ L 2 ~~::~.;) ÞJsska Oil & Gas Coos. Commìssion ¡.\nchorage page 5 n :\drlg\kgf\wells\kbu 44-6\446prog. xis ) ) v. CEMENTING PROGRAM (continued) PRODUCTION 3 1/211 @ 73151/7200' lEAD SLURRY: Class IIGII + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: ft. ppg. cu. ft'!sk gal/sk hrs:min %(use 25% over caliper log.) sks. TAil SLURRY: Class IIGII + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REO.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 5400 ft. 15.8 ppg. 1.15 cu. fUsk gal/sk hrs:min 25 % over caliper log. 685 sks. RUNNING AND CEMENTING DETAilS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. MIU float collar. (Baker-Iok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. MIU cementing head and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug. 10. Displace cement with water. Reciprocate as long as possible. land tubing hanger. 11. Bump plug wi a minimum of 500 psi over displacement pressure. Check floats. 12. WOC ;,:,C:)I, "::~,,. ,.(:',_ ~~' t== -: tj ~ ;:L",,,,, \(-.ß [) J ;" .': ~.~ : ,., .'~ . '..' ~ '-~-I..:) Alaska Oil & Gas Coos. Commission Anchorage page 6 n:\drlg\kgf\wells\kbu 44-6\446prog.xls VI. MUD PROGRAM DEPTH FROM 01 15001 53001 ) ) MUD PROPERTIES DEPTH TO TVD 15001 53001 7200' WEIGHT ppg 8.6-9.0 8.6-9.0 9.0-9.5 MUD TYPE Freshwater gel FLO PRO/KCL FLO PRO/KCL VISCOSITY sec/qt 80-250 42-80 50-70 WATER LOSS 1 5-30 <12 <8 MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS CONDUCTOR: SURFACE: PRODUCTION: COMPLETION: LOGGING PROGRAM No logging is planned for this interval. No logging is planned for this interval. RUN #1: AIT/MSFUDSI/LDT/CNUGR. RUN #3: RUN #2: RUN #4: Gammaray/CCL. MUD LOGGING The well will be mud logged from 54151 md(casing point) to TD at 7315' md. None Planned CORING PROGRAM TESTING PROGRAM ~""··''.\:f=·'''',<·'':· ~I~ ¡~=' ~'" ¡¡¡ ~ ,=.:. \.~"c:.: [) No open hole tests are planned for this well. ~,:.f c: 2 ~'=C~J page 7 i\it1Ska Oil & Gas Coos. Commission Anchorage n :\drlg\kgf\wells\kbu 44-6\446prog. xis n:\drlg\kgf\wells\kbu 44-6\446prog.xls page 8 ~\i.m:;ka Oil 8: Gas Cons. Commission f.\nchorage r '(,: ~= ~.~~:) ~~'::~ V;;' l~c''':: d ~& J=" ~", VIII. OTHER INFORMATION DIRECTIONAL PLAN NORTH East VERT DESC MD TVD INCL AZIM COORD COORD SECTION RKB 0 0 0 0 0 0 0 KICKOFF 1500 1500 0.0 0.0 0 0 0 build @ 1.5 deg/10Oft HOLD 2715 2695 18.2 21.9 178 71 192 DROP 4200 4105 18.2 21.9 609 244 656 END of DROP 5415 5300 0.0 21.9 787 316 848 Total Depth 7315 7200 0.0 21.9 787 316 848 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) No serious interference exists. ) ) ) ') IX. DRilliNG PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 21 1/4" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1500' md/1500' tvd per the directional plan. Run and cement 133/8" casing. wac. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 3M wellhead. N/U 13 5/8" 5M BOP'S. Test BOp·S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE Drill out float equipment and make 20' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" directional hole to 54151 md/5300' tvd as per directional plan. Lost circulation is possible through this entire interval. Make wiper trip. Run and cement 9 5/8" casing. wac. N/U 135/8" 5M x 11" 3M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 2600 psi. PRODUCTION: Drill float equipment and 20' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" hole to 7415' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run 3 1/2" casing string and land hanger in tubing head. Cement. Bump plug with 500 psi over displacement pressure. wac. 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. «,~<:..o..?~ <:;'\ s-\~ ~ COMPLETION: Set BPV's in hanger. N/D BOPE and N/U tree. Test tree to 5000 psi. Rig down and move out drilling rig. Completion will be done without a rig. - - '" 2 ,~.~\ ~; J ¡L\h18ka OJ¡ & Gas Cons. Commission Imchorage page 9 n :\drlg\kgf\wells\kbu 44-6\446prog. xis ) ) x. POTENTIAL HAZARDS Well KBU 44-6 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 break(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 +/- 3660' tvd/35921 md to total depth of the well. These sands will run from normal pressured to severly depleted and lost circulation and differential sticking are protential hazards. The Flopro 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. . . _ ~ J (, 2 ~~ t~~ ~~" J !::d¡}5¡Œ! O¡I g~ Gas Cons. Commission t~nchorage page 10 n:\drlg\kgf\wells\kbu 44-6\446prog. xis ) XI. NOTES MASP CALCULATIONS: Surface casing: 13 3/811 MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x .052 X 1500' - (.115 x 15001) MASP = 975 psi - 173 psi MAS P = 802 psi. Intermediate casing: 9 5/811. ) MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column - Hydrostatic pressure of mud COil MASP = (14.0 ppg + 1.0 ppg) x .052 X 53001 - (.115 X 26501) - (.052 x 9.0 x 2650) MASP = 4134 psi - 305 psi - 1240 psi MASP = 2589 psi. Production casing: 3 1/211 MASP = Formation pressure - Hydrostatic pressure of gas column. MASP = 9.0 ppg x .052 X 72001 - (.115 X 72001) MASP = 3370 psi - 828 psi MASP = 2542 psi. Tubulars All tubulars are new. page 11 ~:~\ ~:;ç';\o W \U!.",,,,\,,,:;0! t' '.r C' .~;... "". î \.. ~ C..il:\.,! l'\]~$ka Oil & Gas Coos. Commission Anchorage n:\drlg\kgf\wells\kbu 44-6\446prog.xls ~ o o (,) (?}Ji '\)\\ I >\ \ . \ .. \ .. .. \ It .. . \ ~ .... .. '. .*. '.. '. , \ \ \ 6\\i \ \. .. .,. v 100/ T 5 N .. .. " .~___oI i \ 6709000m. N -- - -0 - '" 60"3CJ 25 rt= i~ J ~~ / í I I } / / $ / / ! i ~ Strip.;:, - ~ I~· 0o:.~""" j'; - i I i T 4 N '-' I : ~::ì It\..: q: :¡; ::~ 0- Q~ ...,<: 0'" VI:':: ." ...... MARATHON OIL COMPANY . . . .\..... . . .., . . ....... -.:"' :.:...:~':'.:>' :<~ \ ~ ( ê - w ê .. w ~ ~i 8 ~ z ......... V 5,89' 11'33- E .~ 1/4 7 ' :t »-273;289.82 V-2.3tl2.036.7:5 . ~ . . 18 8~ 6 z/ S 89" 11' 33- E ~di&lNJR X-27Q,8O&~ V-2,382.07o.01 ...t 2361.56 ~81~a POINT, Y-oJ...1I81,767.24I <'"' REBAR) 51'11 EMERGENCY -..:::s ::.u¡.DC*4 \---r TO 14-6 - ··~Q.H.r'· ( '-' - :- .~'~..' J r;~~ 'i! r:.~.~: g'l n ":.~'\ J' (""t ..." I .. "'-'¡ c. \.:;.,J;;,) \JC;¡;:¡. JO!ìim!SSIOn .~¡..,.,";'.r':l'~"e j"'l, ~'~,¡ ;\1'6 o.~ ,h.. ,h. ,h. , ,h.' r--------------- , ---~-,- _~DlK£ I=- f I ' " 1806.13 '" - +tl +" I - . KTU 24-6H KTU 32-7 DIKE:,? _:. " . (=-+ N~.;~.!... KØJ·42-7 " ~1 . .-:--t .....,........, N23&1874.31 '.. · \ .- E 274873;22 '.E 27SØ2122 .. KBU 44-6 i ~ , ;::-- !.; \~ L SECTION 6 y - 2.362.000.00 SECTION 7 ~~-------------- / ~ / METAL CO'ÆIWI ~; &rw: " \ ;/ ='fX~::.. ~¡¡ ~ ., 15.~' ~ r(...~.~P,':.,rt \ ( "'":õ:;¡i' - .. '. '.".. ",; ~,~ ., ~ .. '~. \ , ' . . ". .~ "...... PAD . "-' "Iá.~ ) , ~, , ., I ~·.I I ' J D;H.P¡W ,. I I ~ ~ ~ ~ , ~... ..'. 24.ao Jf~ 2402' II '--' I.~~'¡ I HEA1ER ~~~ ~ ~ARATOR BlDC. :5 ME'IER ~..:f.:iJí ME1ER I I ..... · ....., ~ ..... I ~ I l :u~jf~fÐ~~~ J~ \ ~~~ ¡ '\,;r:l1NUE$ UP 4" . o,tI. PIPE CS; \ ~~ 12" iI O,tJ. PIPE! .¡ 16" ;. PIPE I ~ \ ~TlNVE$ UP '- DETAIL "'6" tPlPE / ø '- 1"=20' DUD ENDS / )( ~---------------~ ..:æl ·1 1 ,I ~'I ~I ~~' ..., =afaa: . Y-i2,3St,&K.3'r:1f -1<;tJ. 1J..o(i'r;J'" r ' 1ò"E.L HOUSE.1M ,Qtll!!3QJMD )(,2"1 .. .' +~. .Fi .... =.~. l'. +Ya2,3'íI"m;1. .. y..2.~~G4 2-4-'~ELÐRA1E ~ : 11 K.U.41-7' PlPDSTQRAGt . . . !ot~W/!l.:J K;U. 43-6 8I.þO.'1J ~ K.U. 43-6X ~1!D ~ ~ '¡e,-t i , 1....1I~ . p.P£ . ,GCØ~ -~= '- - ~ .... - . Y -2,381.800.00 ~PAD UMITS ~ . K.Ð.U. NO.4 =~~84 K..U. 43-6A . »-2:1e".,9I Y",2,¡3ðI.72t,Ot , - .==- X-m1'78.411 V-2¡3e1.MI.SS . K.D;U.NO. 2 _2-3', FLARE PIPES ..... - . 'I'!' !- 't y - 2.381.600.00 K.U. 43~ 7 10' .. YÆU. HOOSE: X-27&.t!O.5t 'Y-t,38t,6è&.80 E\.£ClR1C PIoNE\. r--'FØR DRtWNG ~.t _.. _.. _ 4- ~OP£RA'11CNS ~ Ò.H.E. .._.._..~. PAD UMITS . stJRVEY WORK POINT x-t~S2&æ l;Jêw~M wI Ai. CAP) \ .ð- (() I ~, g 8 d o ~ N II )( 8 ~ Id ~ II )( McLANE' : '\ 01)NSUL llNGGROUP . sr.1J)O~A. H.ASIC" aew (liP?) ~~a· ' 1 ~O<'ð~Q. AD~ STmtI ~'!E Cf' SUlMY:1'{!8(~ Nt.. DAlE _BY "'6.CID ~ 1..0CA1IOtf -- ~ .8.. 42....1. 24-6 ~;1( NO.1 It.(f fit:.ti .,Y:' · -". \ REWG ';:::::07 .. M~rathon ~... ::.:,w {!.!e~ 011 Company ENGINEER ~VAL ~~""'\\\\" . ~'~OF~'tf: ~4-~1 . I~ i* 49It!* *~ ~. , jj!, ill' ,\ ..M. -.xm IIILMII J.' '~ '~.~ I..... ,~: 'ti~/........_ .,¡Þ, ~ ..,;""QII~ . ~.. ~\\,\,'\.",,,, Ëf:OI£CT !!~. , f!,OCEss ~lMlCKN4. §!'£,CT. !r!:PRuw- A:;cH- ' . '='1- - cay 'QA'I! ( f tt!:F ~ 32 T5N . ·:-:-:-:,1, 1~:C T<IN . ::~;I:: >:. . ::~:::)/ . Jr :6':::: 12 Løeotlcri ,iil:r 13 "-",. 17 33 KENAI GAS 5 8 SCALE ,- - 1..... VICINITY MAP .FGEND ·tIe GLO/BLM rnonul1'Ientfound thl9 SUM o Found rebQr .(It as IndlCoted) "FOU~d 2 1/2- brass capped monume o<Þ Power Pclè .;. light Pole . Existing woll christmas tree . MonltQr Well Þ4 wive -0 Piping CCIIItlnueaundergrqund. g Eleçtrlc ,Junctlän bDX . , , AI.;lBREVlA lIONS o.H.t. OVEIIIfEAD ELEC1RIC' O.M. p/W OI.ØH£AD ·PlPEW4V HQItS. 1) Eløvotlona at the t^'" of I ....- with covet ,off 'or 'opei"r P pit ...... monitoring wells "...taken 2) Reference dotum IS meon .aeolével- ~OO· for eI , ovations shown. ~) All bearlngà are grid unlœa noted otherwlee. ~¿'~II~o~: ¡C:,ij)'t:;)!sA U.S..CO ðeG.S. Trl station AUDRY I.n -01'05'O.:s- wrage convørgønce, of ,point. shDwn: 5) AUDRY locatIon: Lot.: eD'30~SO.!1,S9-N Long.: 15",S'37.44ð-W X-289.8S1S.75 "'-2.382;045.42 6) TI8.M. 81-31-18 spike InP;P. 'QS 3210 elev. &5.88 ....s.L. ,,11\ Alcmø Region K~NA' GAS FIE~D PAP ,AS-BUILT SURVEY KENAI GAS FIELD PAD 41-7 SCALE ,D~. AAR I)A1'E !/lJ/tII ~ ,._~~ ":-~ · 1·1:: t:1-= I ":.. ~ r,1 · i~ ) ) .,.,1 'I \» I' " I (' r" ",. f .." .1· '"\"") '" .', C L ¡:'JV,_ Qjj & Gas Cons. Commission ,Anchorage MARATHON Oil Company Pad 41-7 KBU 44-6 slot #KBU44-6 Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref : KBU 44-6 Version #1 Our ref : prop4214 License: Date printed : 2S·0ct-2000 Date created : 25-0ct-2000 Last revised : 25-0ct-2000 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000,N Slot location is n60 27 33.909,w151 14 43.569 Slot Grid coordinates are N 2361971.880, E 275188.819 Slot local coordinates are 15.62 S 4281.79 E Projection type: alaska· Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ) MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7.KBU 44-6 Your ref : KBU 44-6 Version #1 Kenai Gas Field.Kenai Peninsula. Alaska Last revised : 25-0ct-2000 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 0.00 0.00 21.85 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 21. 85 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 21. 85 1000.00 0.00 N 0.00 E 0.00 0.00 1500.00 0.00 21. 85 1500.00 0.00 N 0.00 E 0.00 0.00 1600.00 1.50 21. 85 1599.99 1. 21 N 0.49 E 1.50 1.31 1700.00 3.00 21.85 1699.91 4.86 N 1.95 E 1.50 5.23 1800.00 4.50 21. 85 1799.69 10.93 N 4.38 E 1.50 11.77 1900.00 6.00 21.85 1899.27 19.42 N 7.79 E 1.50 20.92 2000.00 7.50 21. 85 1998.57 30.33 N 12.16 E 1.50 32.68 2100 .00 9.00 21. 85 2097.54 43.65 N 17.50 E 1.50 47.03 2200.00 10.50 21. 85 2196.09 59.37 N 23.81 E 1.50 63.96 2300.00 12.00 21.85 2294.16 77 .47 N 31. 07 E 1.50 83.47 2400.00 13.50 21.85 2391.70 97.96 N 39.28 E 1.50 105.54 2500.00 15.00 21. 8.5 2488.62 120.80 N 48.44 E 1.50 130.15 2600.00 16.50 21. 85 2584.86 146.00 N 58.55 E 1.50 157.30 2700.00 18.00 21.85 2680.36 173.52 N 69.58 E 1.50 186.95 2715 .43 18.23 21. 85 2695.02 177.97 N , 71.37 E 1.50 191.75 3000.00 18.23 21. 85 2965.31 260.60 N 104.51 E 0.00 280.78 3500.00 18.23 21. 85 3440.21 405.79 N 162.73 E 0.00 437.21 4000.00 18.23 21. 85 3915.11 550.98 N 220.95 E 0.00 593.63 4199.91 18.23 21.85 4104.98 609.03 N 244.23 E 0.00 656.17 4215.33 18.00 21.85 4119.64 613.48 N 246.02 E 1.50 660.97 4315.33 16.50 21.85 4215.14 641. 00 N 257.05 E 1.50 690.63 4415.33 15.00 21.85 4311.38 666.20 N 267.16 E 1.50 717.77 4515.33 13.50 21.85 4408.30 689.04 N 276.32 E 1.50 742.38 4615.33 12.00 21. 85 4505.84 709.53 N 284.53 E 1.50 764.45 4715.33 10.50 21. 85 4603.91 727.63 N 291. 79 E 1.50 783.96 4815.33 9.00 21.85 4702 .46 743.35 N 298.10 E 1.50 800.90 4915.33 .7.50 21. 85 4801.43 756.67 N 303.44 E 1.50 815.24 5015.33 6.00 21. 85 4900.73 767.58 N 307.81 E 1.50 827.00 5115.33 4.50 21.85 5000.31 776.07 N 311. 22 E 1.50 836.15 5215.33 3.00 21. 85 5100.09 782.14 N 313.65 E 1.50 842.69 5315.33 1.50 21. 85 5200.01 785.79 N 315.11 E 1.50 846.61 5415.33 0.00 21.85 5300.00 787.00 N 315.60 E 1.50 847.92 KBU446 - Tgt 1 - 25 Oct 00 5500.00 0.00 21.85 5384.67 787.00 N 315.60 E 0.00 847.92 6000.00 0.00 21.85 5884.67 787.00 N 315.60 E 0.00 847.92 6500.00 0.00 21.85 6384.67 787.00 N 315.60 E 0.00 847. 92 7000.00 0.00 21. 85 6884.67 787.00 N 315.60 E 0.00 847.92 7315.33 0.00 21. 85 7200.00 787.00 N 315.60 E 0.00 847.92 KBU446 - Tgt 2 - 25 Oct 00 l._:·J C 2 ~~:2(;·] )dS;;\Œ Oil & Gas Cons. Commission cÄ\1Imorage All data is in feet unless otherwise stated. Coordinates from slot #KBU44-6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 847.92 on azimuth 21.85 degrees from wellhead. Total Dogleg for wellpath is 36.46 degrees. Vertical section is from wellhead on azimuth 21.85 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) MARATHON Oil Company Pad 41·7,KBU 44·6 Kenai Gas Field,Kenai Penlnsula. Alaska PROPOSAL LISTING Page 2 Your ref : KBU 44·6 Version #1 Last revised: 25-0ct-2000 MD TVD Rectangular Coords. Comments in wellpath Comment ---.. --........ --...................................... --.................. --............................................... --.................... --....................................... --......-.... 5415.33 5300.00 7315.33 7200.00 787.00 N 787.00 N 315.60 E KBU446· Tgt 1 . 25 Oct 00 315.60 E KBU446· Tgt 2 . 25 Oct 00 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised --.............. --.................. -................................................................................................... --........................................ "'......... -..-...... --.... KBU446 - Tgt 1 - 25 KBU446 - Tgt 2 - 25 5300.00 7200.00 787.00N 787.00N 315.60E 25-0ct-2000 315.60E 25-0ct-2000 !_.~ / c~ 2 ;~ .,~ ~:J Aiaska Oi; & Gas CnJlt' COfl'!m' . V1.... II !SSlon . Anchorage ) ) r' I (, ,,,¡ (:' ,,\,r, "\ \ . ~' U::::. t.:.; 1.\..1 '\¡ ., P~.~:~$ka OU ~~ Gas Coos. CommiSSIon Anchorage MARATHON Oil Company Pad 41-7 KBU 44-6 slot #KBU44-6 Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref : KBU 44-6 Version #1 Our ref : prop4214 License: Date printed : 25-0ct-2000 Date created : 25-0ct-2000 Last revised : 25-0ct-2000 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000,N Slot location is n60 27 33.909,wI51 14 43.569 Slot Grid coordinates are N 2361971.880, E 275188.819 Slot local coordinates are 15.62 S 4281.79 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North " ) ) MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KBU 44-6 Your ref : KBU 44-6 Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 25-0ct-2000 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees . Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 0.00 0.00 21.85 0.00 O.OON O.OOE 0.00 0.00 275188.82 2361971.88 500.00 0.00 21.85 500.00 O.OON O.OOE 0.00 0.00 275188.82 2361971.88 1000.00 0.00 21. 85 1000.00 O.OON O.OOE 0.00 0.00 275188.82 2361971.88 1500.00 0.00 21.85 1500.00 O.OON O.OOE 0.00 0.00 275188.82 2361971. 88 1600.00 1. 50 21. 85 1599.99 1.21N o .49E 1.50 1.31 275189.33 2361973.09 1700.00 3.00 21. 85 1699.91 4.86N 1.95E 1.50 5.23 275190.86 2361976.70 1800.00 4.50 21. 85 1799.69 10.93N 4.38E 1.50 11.77 275193.41 2361982.72 1900.00 6.00 21. 85 1899.27 19.42N 7.79E 1.50 20.92 275196.98 2361991.15 2000.00 7.50 21. 85 1998.57 30.33N 12.16E 1.50 32.68 275201.56 2362001.97 2100.00 9.00 21. 85 2097.54 43.65N 17.50E 1.50 47.03 275207.16 2362015.18 2200.00 10.50 21.85 2196.09 59.37N 23.81E 1.50 63.96 275213.76 2362030.77 2300.00 12.00 21. 85 2294.16 77 .47N 31.07E 1.50 83 .4 7 275221. 37 2362048.74 2400.00 13.50 21. 85 2391.70 . 97. 96N 39.28E 1.50 105.54 275229.98 2362069.06 2500.00 15.00 21. 85 2488.62 120.80N 48.44E 1.50 130.15 275239.58 2362091.72 2600.00 16.50 21. 85 2584.86 146.00N 58.55E 1.50 157.30 275250.17 2362116.71 2700.00 18.00 21..85 2680.36 173.52N 69.58E 1.50 186.95 275261.73 2362144.02 2715 .43 18.23 21.85 2695.02 177.97N 71. 37E 1.50 191. 75 275263.60 2362148.44 3000.00 18.23 21. 85 2965.31 260.60N 104.51E 0.00 280.78 275298.32 2362230.41 3500.00 18.23 21.85 3440.21 405.79N 162.73E 0.00 437.21 275359.33 2362374.45 4000.00 18.23 21. 85 3915.11 550.98N 220.95E 0.00 593.63 275420.34 2362518.48 4199.91 18.23 21.85 4104.98 609.03N 244.23E 0.00 656.17 275444.73 2362576.07 4215.33 18.00 21. 85 4119.64 613.48N 246.02E 1.50 660.97 275446.60 2362580.48 4315.33 16.50 21. 85 4215.14 641.00N 257.05E 1.50 690.63 275458.17 2362607.79 4415.33 15.00 21. 85 4311.38 666.20N 267.16E 1.50 717.77 275468.75 2362632.78 4515.33 13.50 21. 85 4408.30 689.04N· 276.32E 1.50 742.38 275478.35 2362655.44 4615.33 12.00 21.85 4505.84 709.53N 284.53E 1.50 764.45 275486.96 2362675.76 4715.33 10.50 21. 85 4603.91 727.63N 291.79E 1.50 783.96 275494.57 2362693.73 4815.33 9.00 21. 85 4702.46 743.35N 298.10E 1.50 800.90 275501.17 2362709.32 4915.33 7.50 21. 85 4801.43 756.67N 303.44E 1.50 815.24 275506.77 2362722.53 5015.33 6.00 21. 85 4900.73 767.58N 307.81E 1.50 827.00 275511.35 2362733.35 5115 .33 4.50 21.85 5000.31 776.07N 311.22E 1.50 836.15 275514.92 2362741. 78 5215.33 3.00 21.85 5100.09 782.14N 313.65E 1.50 842.69 275517.47 2362747.80 5315.33 1.50 21.85 5200.01 785.79N 315.11E 1.50 846.61 275519.00 2362751.42 5415.33 0.00 21. 85 5300.00 787.00N 315.60E 1.50 847.92 275519.51 2362752.62 5500.00 0.00 21. 85 5384.67 787.00N 315.60E 0.00 847.92 275519.51 2362752.62 6000.00 0.00 21. 85 5884.67 787.00N 315.60E 0.00 847.92 275519.51 2362752.62 6500.00 0.00 21.85 6384.67 787.00N 315.60E 0.00 847.92 275519.51 2362752.62 7000.00 0.00 21.85 6884.67 787.00N 315.60E 0.00 847.92 275519.51 2362752.62 7315.33 0.00 21. 85 7200.00 787.00N 315.60E 0.00 847.92 275519.51 2362752.62 L.>J C =~ ;~'~0") (:>'·,¡:Jt~j n;¡ 'Íì. G'3S Cons. Commission " ~. '\. ~...~ ~ 'o'.¡"t\ \..~ J ~ \r... Anchorage All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU44-6 and TVD from Est. RKB (87.00 Ft above mean sealevel). Bottom hole distance is 847.92 on azimuth 21.85 degrees from wellhead. Total Dogleg for wellpath is 36.46 degrees. Vertical section is from wellhead on azimuth 21.85 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 41-7,KBU 44-6 Kenai Gas Field.Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref : KBU 44-6 Version #1 Last revised: 25-0ct-2000 MD TVD Rectangular Coords. Comments in wellpath Comment ........ --..........................................................................-................................................ ---............ --...... --.. --............................................. 5415.33 5300.00 7315.33 7200.00 787.00N 787.00N 315.60E KBU446 - Tgt 1 . 25 Oct 00 315.60E KBU446· Tgt 2 - 25 Oct 00 Targets associated with this wellpath ---------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ..-.......- --......................................-........................................................ --.............. --.. ----.......................................................... --............ KBU446 . Tgt 1 . 25 KBU446 - Tgt 2 - 25 5300.00 7200.00 787.00N 787.00N 315.60E 25·0ct·2000 315.60E 25-0ct-2000 II , .~ ( . ~ r' .~, :. ,- ,. C 2 ¡~')C;J };ì,¡aSj\"a 0;: I:i '.. II (f Gas 1'.. .. wns Cor!" . A.nChcrag~ lumission ) ) MARATHON Oil Company Created by Sutherland For: C. Young Date plotted: 25-Oc:t-2DOO Plot Rere",nce is KBU 44-6 Version ". Coordinates 0'" In feet ",Ference olot IKBU44-6. True Verticol Deptho ore rllferenCð Eot. RKB. _I. ..... INTEQ 0 I 400 - 800 - 1200 - 1 600 - 2000 - ........... 2400 - - Q) Q) ..... 2800 - '-" ...c - c.. Q) 3200- Q 0 .3600 - 0 t Q) > 4000 - Q) ::J I.... 4400 - l- I V 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - structure : Pad 41-7 Field : Kenai Gas Field l ~ - 1 ¡' t:) t",., A .'\ . C ~.. c..') \} ) Ilt\~~~~~;8I Oil 11 Gas Coos. Commission Anchorage 0.00 KOP 1.50 3.00 4.50 6.00 0lS: 1.50 dIg per 100 ,t 7.50 9.00 10.50 12.00 13.50 15.00 16.50 18.00 18.23 End of Build TANGENT ANGLE 18.23 DEG 18.23 18.00 16.50 15.00 13.50 12.00 10.50 9.00 7.50 6.00 4.50 3.00 1.50 0.00 End of Hold ---- OLS: 1.50 deg per 100ft ----- Point ----- KBU4-46 - Tgt 1 - 2:i Oct 00 Tie on KOP End of Build End of Hold Well : KBU 44-6 Location: Kenol Peninsula. Alaska East (feet) -> 100 100 o 200 JOO KBU446 - Tgt 2 - 25 Oct 00 KBU446 - Tgt 1 - 25 Oct 00 ~ ~ ~ ~ WELL PROFILE DATA 400 900 - 800 - 700 - 600 ^ - 500 I z - 400 0 ...., - ;:r- ...-.. - 300 ~ CD CD - ......... - 200 - 100 - 0 - 100 ---- MO Oir TVO Inc North Eoot 0.00 0.00 21.85 0.00 0.00 0.00 1500.00 0.00 21.85 1500.00 0.00 0.00 0.00 2715.43 18.23 21.85 2695.02 177.97 71.37 191.75 4199.91 18.2.3 21.85 4104.98 609.03 244.23 656.17 D KBU446 - Tgt 2 - 25 Oct 00 Torget KBU446 - Tgt 1 541 5.33 0.00 21.85 5300.00 787.00 315.60 847.92 T.D. & Target KBU446 - 7.315.33 0.00 270.00 7200:00 787.00 315.60 847.92 o 1200 400 800 Vertical Section (feet) -> AzImuth 21.85 wIth reference 0.00 N. 0.00 E from slot HKBU4.4-6 v. Sect Oe9/1OO 0.00 0.00 0.00 1..50 0.00 1.50 0.00 I~ f ) ) ~ ( '~r. 'I f ¡ MARATHON Oil Company Created by Sutherland For: C. Young Date plotted : 25-O<;t-2ooo Plot Ror.renœ io I<SU 44-6 V....ion 111. Structure : Pad 41-7 Well : KBU 44-6 CoordinatDo ore in rCl.t refClr.ne. alot II<SU44-6. True Vertical Depthe ore referenœ Eat. RKS. 11I.\1 fIeld : KenaI Gas fIeld Location : Kenai Peninsula. Alaska ..,.. INTEQ (feet) East -> 200 150 100 50 0 50 100 150 200 250 300 350 400 450 500 550 I 850 - œ -850 2500" .$'~ 800- .$'),:Vop 3700 -800 :I7.s;!°o ...... 2400.. :I7<9go j 3600 :Ii".>. v 750 - 1(. 00 I' -750 1(. 6'00 , ( , i' ,.''') ,,0,,\ _') ~oo' 3400 I :171(. , 700 - ~ ., C, c.. c ',) ",~ , :I7,j: Vo J 3300 -700 1& Gas Cons. Commission Vo / 650- ~ ¡' -650 .Ml~10rage 001 :17)': I 2200 00' 31 00 600- :l7Q I -600 Vo, OCO "& I 550- Vo 2900.. 2100 -550 .1; íj)0o ¿ 2800 500- -500 ^ 7 u".> 2000 ^ I 2600 00 I 450- I ,,~ -450 ........... Vo Z ...... ¿ <D I ".$'Q 0 <D 400 - 2400 ~ V -400 =1- 'to- :::r ........... I ..?':I7Q ..í: V ,......." ~..J .... +- CD L J50 - I \.too -J50 0 CD Z ~..J: -+ I ~oo '-'" JOO - ~" -JOO 1600 I .1'00 '..?'Q 250- I Vo -250 1500 ,. ~& I Vo 200- I' ~<9; -200 1400 I Vo ,. ~.>. I 00 150 - , .?6: -150 , Vo I ~.5'a 100 - ,. -2 V -100 1 500 ,:1700 , ~ "Q 50 - I ~..a v - 50 140~ ~? 00 1300" I.?Q'b 4-. VO f<9Q - 0 .. 1 000 VOD 50 - ill - 50 I 200 150 100 50 0 50 100 150 200 250 300 350 400 450 500 550 East (feet) -> ) ) Created by Sutherland For: C. Young Dote plattod : 25-Oc:t-20D0 Plat Rafe....nea ia KBU 44-6 Va...ian , 1 . Caardinatee a.... in fa..t ....far..ne.. alat IKBU44-6. Tru.. V..rtical Depths 0.... rDf......nce Eet. RKB. 8.. .... MARATHON Oil Company Structure : Pad 41-7 Well : KBU 44-6 Field : Kenol Gas Field Location : Kenai Peninsula, Alaska INTEQ 300 330 TRUE NORTH ffi ~ I::::J 350 0 10 340 1500" 2'0 180 I ¡" {) ;"' :'~ "I " ¡,! '..J V ,) ,¡ \.J' __... 1.- & Gas Coos. Commis$\9~ 0 An~~hofage 310 50 60 290 70 280 80 270 90 260 100 250 110 240 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Wel: ) ,~ <' ..~,.. ) MARATHON Oil Company Pad 41-7 KBU 44-6 slot #!<BU44-6 Kenai Gas Field Kenai Peninsula. Alaska 3-D M I N I MUM D 1ST A N C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ t, ¡ i', '), ,"'\'~) l ~...../... \...i.:..... .....v~....' Your ref : KBU 44-6 Version #1 Our ref : prop4214 License: Date printed.: 25-0ct-2000 Date created : 25-0ct-2000 Last revised : 25-0ct-2000 & (::a5 Cons Comm~5$ion ,~ .' ~ Fi e 1 d is centred on n60 27 33.151. w151 16 7.223 ,Ancho~age Structure ;s centred on 270908.300.2362070.010.999.QOOOO.N Slot location is ri60 27 33.909.wI51 14 43.569 Slot Grid coordinates are N 2361971.880. E 275188.819 Slot local coordinates are 15.62 S 4281.79 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North Report ;s limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk. e.g. 487.4* Object we"J.lpath KU 31-7 Version #2..KU 31-7.Pad 14-6 GMS<0-7375'>..KBU31-7.Pad 14-6 PMSS <5814 - 7575'>..31-7Rd.Pad 14-6 WD-2 Version #1..WO-2.Pad 14-6 INCLINATION ONLY..KU14-6.Pad 14-6 GMS <0-6950'>,.KBU23X-6.Pad 14-6 MSS <0-5500'>..KU13-6.Pad 14-6 MSS <0-9895'>..KDU-1.Pad 14-6 GMS <0-10225'>..KDU-8.Pad 14-6 MSS <0-6530'>..KU43-12.Pad 14-6 MSS <0-4453'>..KU21-7.Pad 14-6 MMS <0-7910'>..KBU33-7.Pad #11 GMS <0-5820'>..KU24-7.Pad #11 MSS <0-4459'>..KUll-6.Pad #1 MSS <0-5682'>..KU21-6.Pad #1 Incl. only <0-5809'>..KU34-31.Pad #1 PGMS <0-3300'>..WD-1.Pad #1 GMS <0-10502'>..KDU5.Pad #1 PGMS <0-5700'>..KU14-32.Pad #1 GMS <0-11095'>..KOU6.Pad #1 KBU42-7 Version #3..KBU42-7.Pad 41-7 PMSS <8846 - 10960>..KTU24-6H,Pad 41-7 KTU43-6XRd Ver.7..43-6X Rd.Pad 41-7 PGMS <0-8370'>..43-6.Pad 41-7 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 12-Sep-2000 1827.3 3660.0 3660.0 14-Sep-1995 2587.8 3000.0 3000.0 28-Sep-1995 2587.8 3000.0 7300.0 26-Mar-1999 3413.8 1500.0 1500.0 26-Mar-1999 3329.8 180.0 180.0 12-May-1995 3087.4 2185.7 2185.7 12-May-1995 3024.3 320.0 360.0 12-May-1995 2782.9 7315.3 7315.3 12-May-1995 3164.9 1657.1 5800.0 12-May-1995 3310.6 0.0 0.0 12-May-1995 2929.2 3440.0 3440.0 31-May-1995 4169.6 7100.0 7100.0 31-May-1995 5769.1 1900.0 19bo.0 30-May-1995 5761.8 4743.9 4743.9 30-May-1995 4727.3 5172.5 5172.5 30-May-1995 7239.0 5301.0 5301.0 30-May-1995 7238.5 4315.3 4315.3 30-May-1995 4480.7 7315.3 7315.3 30-May-1995 5846.9 5229.6 5229.6' 30-May-1995 7571.9 600.0 4901.0 3-0ct-2000 164.6 1400.0 7315.3 1-Aug-2000 115.6 0.0 7315.3 20-Apr-1999 2037.0 7315.3 7315.3 23-Jul-1995 188.5 1728.6 1728.6 1728.6 1040.0 1220.0 400.0 1120 .0 640.0 180.0 140.0 140.0 4258.2 7100.0 0.0 320.0 'I) 1728. 6 1040.0 1220.0 400.0 1120 .0 640.0 180.0 140.0 140.0 1320.0 1514.3 0.0 320.0 188.5 33.3 104.5 307.3 264.9 348.7 379.0 241.9 241. 9 37.0 160.0 215.6 49.4 16-Aug-1995 20-Jan-1994 20-Jan-1994 21-Jan-1994 21-Jan-1994 21-Jan-1994 21-Jan-1994 S-May-199S S-May-1995 21-Jan-1994 21-Jan-1994 22-Jun-200Q 31-Aug-2000 & Gas Cons. Commission j~nchorage 1 "~I, ,I (", ';J "V;) ~ ~ ."J.. \) '-0._.. ¡;......; I.., , , ,¡~~ ') PMSS <7670·9464'>..43-6X ,,\,I, Pad 41- 7 MSS <O-S706'>"KU43-6,Pad 41·7 MSS <O-S300'>,,43-6A.Pad 41-7 MSS <O-10522'>"KDU#2,Pad 41-7 GMS <O-S900'>"KU24-S,Pad 41-7 GMS <O-5350'>"KU11-8,Pad 41-1 MSS <O-5707'>"KU 43·7,Pad 41-7 GMS <O-S549'>.,KDU4,Pad 41-7 MSS <4320 - 10810'>"KDU4Rd,Pad 41-7 GMS <O-8120'>"KU13-S,Pad 41-7 GMS <O_7010'>"KBU41-7,Pad 41-7 GMS <O_7902'>"KBU33-6,Pad 41-7 PMSS <O-SS64>"KTU32-7,Pad 41-7 I:' ¡ I¡~, 121 1/4" 2M Diverter I ~ I Diverter Spool ~, I " ", ~ I . ~ w....} " C: ?::_.~ ;.:. ") 'n I' '. C .\. ,.. Comm~ss\on .i['}c.~~:jla Oi.¡ & Gas (Jln~. i~ncilon3ge ) "> I" ~ ) Marathon Oil Well KBU 44-6 Diverter 1 Flow line / I ", ./ I 1\ ....... I I í 11611 Automatic Hydraulic Valve ¡ \~::0: 116" Diverter Line I Flow Nipple I 135/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves 13 5/8" 5M Single Ram Preventer '~'.:'. -' .', ,,' '\ ;",;' ----- :- ~ '" '.. ) ,._ t"O"'ùt!ÙS$\on ¡:¡. r:~5 Cc\\;;;· \; ~ \.. ....~ ì\ ~ '"'\-: ì'-r':'!.l'l.e i""U ,\i~.v ~~~ ) Marathon Oil Well KBU 44-6 BOP Stack I Flow Line I I I ~ I ~ "> I) / 1 < I Pipe Ram 1 I Blind Ram I ) 3 1/8" 5M Hydraulically Operated Valve ( I /' I ,¡ rChoke(J0[I Xl 'I t < I Pipe Ram 1 ) I 1,\ ( I I í ) .~ ~" IXlIXl)Kill I 13518'5MCross I ~I: I ~ 3 1/8" 5M Manually Operated Valve ) ) Marathon Oil Well KBU 44-6 Choke Manifold ~ I , =ø=~- ~ I , -=øc Bleed off Line to Shakers ~ ,1 To Gas Buster To Blooey Line ~ ~ "--J ( I l----.J ( 'I l J rl ~ ( ) ~ ]@[]@[ 0 ]@[J®l. '\ I ~_J I I 13" 5M Valves I i 1 t 2 9/16" 10M Swaco Hydraulically Operated Choke ~ I From BOP Stack 3 1/8" 5M Manually Adjustable Choke , r '2_ "~.~.;~,") .. Co\'"ùroV3S\On <",:' ~,., .r:'l1'::' Cens. " "" ,.:::'~.... i',Ò:~""~¡:"~ U.\ :!. ..' ,.~1.e i " ,.._n - t~\)v.:~'r¡O{ o~ ') J "~A : .' I"~, ',) I"~ "'"') ... ..... ", " "". . .,J ....... ...... 'I.' "".~ f.\la5ka Oil & Gas Cons. Comm~ssiOI1 . ; ,: ¿:~ ;':J~¡) SURF~~~ft1ŠE PLAN FOR KENAI UNIT KBU 44-6 ,,'.. ¡":'.,~~: C~NM~ "'''''mm\ssion '1;)1. ~)t:;u", 1¡,j711.;J. \.IV Anchoravge Surface Location: NE 1/4 of NE 1/4, Sec. 7, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KBU 44-6 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 KBU 44-6~ 3. Location of Existing ,Wells Well KBU 44-6 will be drilled on pad 41-7. A pad drawing is attached that shows existing wells and the proposed location for KBU 44-6. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. These facilities will be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method 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). N :\0 RLG\KG F\W ELLS\KBU44-6\SU RFUSE.doc ) ) Surface Use Plan Kenai Unit KBU 44-6 Page 2 I', " i',) '~' ;~,'";,) ¡ .~" \) -~ (.. ..I 'v . b) Garbage ,,~ I O'!&G C Co .. §.lw(6:~Ma Ii ·'as 005. mmlSSlon All household and approv~~~~r~estrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be 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 vendor who provided them. EffQrts 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. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Kenai Unit KBU 44-6 will be drilled from an existing pad. Reclamation of the pad will occur after abandonment of KBU 44-6 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CI RI Native Corporation prior to any reclamation work beginning. 10. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. 11. Operator's Representative and Certification ) ) Su rface Use Plan Kenai Unit KBU 44-6 Page 3 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: /v50 t:1 .. .. . Name & Title: Ø(,~ íJ,.,I;;~/ 5'yeÞ',,,,A~""c~r ~rathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 ) ) 8U 44-6 ESTIMATED TOPS AND PRESSURES" 10/23/2000 'it LOWEST HIGHEST PRESSURE LOWEST PRESSURE HIGHEST TOP SSTVD TVD GRAD. PRESSURE GRAD. PRESSURE NEARBY BELUGA COMPLETIONS CONTROL STERLING KBU 41·7 KBU 13-8 KBU 31-7RD KBU 31·7 KDU 4RD KTU 13·5 AS 3505 3592 0.08 287 Used this horizons structure A9 3538 3625 0.08 290 A10 35789 35876 0.08 2870 A11 3642 3729 0.08 298 81 3705 3792 0.08 303 82 3780 3867 0.08 309 83 3843 3930 0.08 314 84 3913 4000 0.08 320 0.25 1000 85 4110 4197 0.31 1301 C1 4390 4477 0.08 358 C2 4580 4667 0.08 373 Used U. Beluga midpoint 8ELUGA structure and KBU 41-7 well U1 4610 4697 0.08 376 0.11 517 X X U2 4658 4745 0.08. 380 0.11 522 X U3 4706 4793 0.08 383 0.11 527 X X U4 4723 4810 0.08 385 0.11 529 U5 4771 4858 0.08 389 0.11 534 X U6 4809 4896 0.44 2154 U7 4857 4944 0.08 396 0.11 544 U8 4916 5003 0.08 400 0.11 550 X X U9 4946 5033 0.08 403 0.11 554 X X X Used M. Belugastructure U10 5012 5099 0.08 408 0.11 561 X X X and KBU 41-7 well U11 5136 5223 0.08 418 0.11 575 X U12 5206 5293 0.08 423 0.11 582 X U13 5233 5320 0.44 2341 CASING POINT M1 5254 5341 0.2 1068 0.44 2350 X M2 5291 5378 0.44 2366 M3 532 619 0.2 124 0.44 272 X M4 5292 5379 0.44 2367 M5 5525 5612 0.2 1122 0.44 2469 X M6 5619 5706 0.2 1141 0.44 2511 X M7 5648 5735 0.44 2523 Used L. Beluga Stucture M8 5669 5756 0.2 1151 0.44 2533 X and KBU 41·7 well M9 5692 5779 0.44 2543 M10 5742 5829 0.44 2565 M11 5759 5846 0.44 2572 M12 5773 5860 0.44 2578 M13 5788 5875 0.2 1175 0.44 2585 X M14 5864 5951 0.2 1190 0.44 2618 X M15 5974 6061 0.44 2667 L1 5989 6076 0.46 2795 L2 5997 6084 0.46 2799 L3 6037 6124 0.18 1102 0.46 2817 X X X X L4 6119 6206 0.18 1117 0.46 2855 X X L5/6 6229 6316 0.46 2905 L7 6298 6385 0.46 2937 L8 6364 6451 0.46 2967 X L9 6387 6474 0.18 1165 0.46 2978 X X X L10 6451 6538 0.18 1177 0.46 3007 X X X X L11 6640 6727 0.18 1211 0.46 3094 X X L12 6685 6772 0.18 1219 0.46 3115 X X L13 6761 6848 0.18 1233 0.46 3150 X X X L14 6821 6908 0.18 1243 0.46 3178 X X L15 6838 6925 0.46 3186 L16 6900 6987 0.18 1258 0.46 3214 X L17 6943 7030 0.18 1265 0.46 3234 X X L18 7019 7106 0.18 1279 0.46 3269 X TYONEK 7090 7177 0.46 3301 72-8 7125 7212 0.37 2668 0.46 3318 X X Total Depth 7163 7250 "Middle and Lower 8eluga depletions possible In zones Identified by "X" In the nearby wells. Sterling and Upper Beluga depletions expected across the field. ¡i···.:·::·;~ ~~'I·..;;.;..j·' (:."-"'~ ":4 r<b= : c,.. 1,1') r' rk..,..." ~:"/:> \u.:'Y r r .-\; , (' (', ¿;:~;J i . ,.' . ~, ¿ i\)2ska Oil & Gas Coos. Commission Anchorage o:\kenai gas fieldlKBU 44-6\44-6tops.xls OLB 10/23/2000 ''I' File: 44-6.sck WELL SCHEMATIC ii~~~\~ i}::" li 'it....",. ¡ " ~: ,I ;'.1 2 ~.~ ~:) i::Jm>Ka Oil & Gas Cons. Commission An chm age KBU 44-6 ') ) Date: October 25, 2000 Page: 1 ~ ~ RKB 1 500 ft .. 5415 ft .. 7315 ft .. 13 3/8" Surface Casing .. 9 5/8" Intermediate Casing ... 3 1/2" Production Casing StressCheck 1998.5 Build 3 I:' ) ') 8U 44-6 ESTIMATED TOPS AND PRESSURES· 10/23/2000 : t LOWEST HIGHEST PRESSURE LOWEST PRESSURE HIGHEST TOP SSTVD TVD GRAD. PRESSURE GRAD. PRESSURE NEARBY BELUGA COMPLETIONS CONTROL STERLING KBU 41-7 KBU 13-8 KBU 31-7RD KBU 31-7 KDU 4RD KTU 13-5 AS 3505 3592 0.08 287 Used this horizons structure A9 3538 3625 0.08 290 A10 35789 35876 0.08 2870 A11 3642 3729 0.08 298 81 3705 3792 0.08 303 82 3780 3867 0.08 309 83 3843 3930 0.08 314 84 3913 4000 0.08 320 0.25 1000 85 4110 4197 0.31 1301 C1 4390 4477 0.08 358 C2 4580 4667 0.08 373 Used U. Beluga midpoint 8ELUGA structure and KBU 41-7 well U1 4610 4697 0.08 376 0.11 517 X X U2 4658 4745 0.08 380 0.11 522 X U3 4706 4793 0.08 383 0.11 527 X X U4 4723 4810 0.08 385 0.11 529 U5 4771 4858 0.08 389 0.11 534 X U6 4809 4896 0.44 2154 U7 4857 4944 0.08 396 0.11 544 U8 4916 5003 0.08 400 0.11 550 X X U9 4946 5033 0.08 403 0.11 554 X X X Used M. Belugastructure U10 5012 5099 0.08 408 0.11 561 X X X and KBU 41-7 well U11 5136 5223 0.08 418 0.11 575 X U12 5200 5293 0.08 423 0.11 582 X U13 5233 5320 0.44 2341 CASING POINT M1 5254 5341 0.2 1068 0.44 2350 X M2 5291 5378 0.44 2366 M3 532 619 0.2 124 0.44 272 X M4 5292 5379 0.44 2367 M5 5525 5612 0.2 1122 0.44 2469 X M6 5619 5706 0.2 1141 0.44 2511 X M7 5648 5735 0.44 2523 Used L. Beluga Stucture M8 5669 5756 0.2 1151 0.44 2533 X and KBU 41-7 well M9 5692 5779 0.44 2543 M10 5742 5829 0.44 2565 M11 5759 5846 0.44 2572 M12 5773 5860 0.44 2578 M13 5788 5875 0.2 1175 0.44 2585 X M14 5864 5951 0.2 1190 0.44 2618 X M15 5974 6061 0.44 2667 L1 5989 6076 0.46 2795 L2 5997 6084 0.46 2799 L3 6037 6124 0.18 1102 0.46 2817 X X X X L4 6119 6206 0.18 1117 0.46 2855 X X L5/6 6229 6316 0.46 2905 L7 6298 6385 0.46 2937 L8 6364 6451 0.46 2967 X L9 6387 6474 0.18 1165 0.46 2978 X X X L10 6451 6538 0.18 1177 0.46 3007 X X X X L11 6640 6727 0.18 1211 0.46 3094 X X L12 6685 6772 0.18 1219 0.46 3115 X X L13 6761 6848 0.18 1233 0.46 3150 X X X L14 6821 6908 0.18 1243 0.46 3178 X X L15 6838 6925 0.46 3186 L16 6900 6987 0.18 1258 0.46 3214 X L17 6943 7030 0.18 1265 0.46 3234 X X L18 7019 7106 0.18 1279 0.46 3269 X TYONEK 7090 7177 0.46 3301 72-8 7125 7212 0.37 2668 0.46 3318 X X Total Depth 7163 7250 "Middle and Lower 8eluga depletions possible In zones Identified by "X" In the nearby wells. Sterling and Upper 8eluga depletions expected across the field. . ' I I ~,~:~ ~,~:~) r-:~:::3\iŒ)' OJ¡ & Gas Cons. Commission l\nchorage o:\kenai gas field/KBU 44-6\44-6tops.xls OLB 10/23/2000 File: 44-6.sck WELL SCHEMATIC :t~::;::" , ~.' ~ i. ') .: ,-, ", \, \ _ ~).. \..,., ........ _...... I.. .J :\~:\;:;;¡-:!.f (1;'j' 11. Gas Cens. Ccmmi3sion ":,I~'.\I.\..;¡;¡' ...,.~ o¡ .r-\1'1Ct¡or~e KBU 44-6 ) ) Date: October 25, 2000 Page: 1 '~ ~- uRKB 1500 ft .. .. 13 3/8" Surface Casing 5415 ft 7315 ft . 9 5/8" Intermediate Casing .. .. .. 3 1/2" Production Casing Stress Check 1998.5 Build 3 ') ) --.. + + L" T5N-R~W L,~ UNIT I BOUNDARY. ._1' / .. 1.../ . -'--- I --II . L._ . I I I ., 114 -R11W' KDU-7 X ; I Ó ;'+ e iii x , ~ '/ j- ... ''', .' L :.? ;~ ,~~ ;~:\) Oi¡8~ G~~s Cons. Commis$ion Þ¡rd~(wage A' -r . I +/ /+ r-I" +- I 1_. I + 11-. . íl-'~I MIDDLE BELUG:l{ i-- FORMATION o C.I. : 100' 1 I I MILE _I_I' MARATHON OIL COMPANY ALASKA REGION KENAI FIELD COOK INLET, ALASKA KBU 44-6 ~, October 2000 HM4094 0: \free ha nd\kbu44-6Ioc. fh 7 .~_________~.______.___.....__-~-=---~~=,"-=,--=-r.....-"""--______ --~-== - --- ---------- ~=~._--------~_.~-~.- --==-~-~~--=----=--..--~~= ------==--- ~--~~~~~~~-~-~-~- ---~- - -~---------~ ----_._----~--=-"'~~=-~~ ~~_=__===__~=--_~~_ ___ ___._.______u___._. .___~ _ ___ _ __ __ ._._ ____~=~_~~~~___~_____~_..__~_____ _.~---~ --- --~--~_. --. -. ------ - - ~--_._---~----~---- ~. Pe_@J,J;_t~- d:ril1,,-~]Ç61LA~-=~_~_ r~ ('l!l!I:\::I¡¡.]:t.I~[";'.!."il~~ NON-REPORTING 1000/0 REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT NON-EMPLOYEE CaMP. PRIZES, AWARDS. OR DAMAGES --- -- OR ...... ~~}iB~ OPiõRATQR . ... . .. .. .. . ." nOlll:'':!..' f $100.0 Q CITÝ o.",no]1 STATE - '-, .-- -. - _ _. ~ r~ ___ ~-._ _ _ _ ..~ _ __ ~__.. ~_-c_-___ ~_ _ .~. ç_. ~ ~ ____ __ __ ~_ _ ~ "_.~ _ __ _.~ /lIDO ~S J.2111 I:~ 2 5200D5 rl:D111·O?ßS¡;gll'. Pay: :.: VOID AFTER 180 DAYS '.. ,._ ... " 1?~~__.~~~!?WZ:f!;f~~~ . NATioNAL BANK OF ALASKA B /~~ II . ANCHORAGE ALASKA t&----- - ---- .' . , . A 0 0 SIGNATU . . '. . .:I::I:'.!.{Ij~.:I~.I.Iellll'¡::I~~Ie[·]~~'.!."~~.!.':t.Iaœ.r4S'¿'I.!.".::I:~I'j''!'':~~ . . ' '. . . . . ~ "" . ,. ~. ,., .. .. .. ...-' Vl: > ~; '.-'-::::. '. .:. '-. .:;;~L~ .. ,.... If"-'57 ~ ':: "0'1;; 't 12 v.. ,,~'.- :J-'l¡llE;2^ - .:, ··J.t:u. ~.': , 'J.~.¡~: .~','~ ,·..:~:·'~\~t~O... ~!~!~~:. ::;;j,~t}j MATCH:AMOUN1;JN":, /~fi.. " ~iif~~~:;~·; ;".:......;" .. .:. ...': ,- .~" '4· . .. ..-.: ~.. --..,=.;::;¡ -:¡';l,~::~~:~:·V"~:-"-·-- _= ___.,...-:-.-_n__ __ - - - -.:'-- "_.. ---"" _.: -- - _._ __ - _n _ __ _u_ .____.. un_ - ---- --. .--- .-...,.--_. ---=- -..... --. --. -.. .jt,;,~o:z:~e~:~~~h:~;-9;~~~ m. . - - ___ __...___ '--=-_-=-_-=-_......_-_--- -'" r __ . - -------. - - ---_.-.=-.-=---=--=---. ~- -,--_.- --.- ~ .-. -- --- - -- - ... -~-"'''--'- -'----"'- -- ,- .. . - . .-- - ...----....--'="-..... -"-...- .." - ." '. .' . ;:'.·:···<Aï"ak~::· of! & Gas Conservation Commission . .,. . . , . li.foÞ~.I..1t1'1'JI'JI"~I.t'-__'.i.J...I"¡1....tI'I.J..J¡.¡~·\.h.''''¡1..J'J~I..foÞ""·'¡IoÞ-'¡n'l .,~~.~~·_~A/~. ':,'<: ,.... : .'. . ... Marathon Oil Comoany . : 0 ... '.: h . : r¡"4;'" ;,,;~;,:- ANCHORAGE ALAsKÂ ··~~_lt~¡~~lf~~¥~~~~~~?f~~~ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER l.\ \..\- C¿ ~~\j WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. . Production should continue to be reported as a fUD.ctionof the original API number stated above. . (If api number last two (2). digits are between 60-69) -/ DEVELOPMENT REDRILL PILOT. HOLE (PH) In accordance with 20 AAC 25.005(t), all records, data and. logs acquired for the pilot hole must be· clearly differentiated in both name (name . on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). EXPLORATION Annular disposal has n~t been requested. . . . ANNULAR D~POSAL . C::LJNO INJECTION WELL Annular Disposal of drilling wastes will not be approved. . . ANNULAR DISPOSAL <--> YES INJECTION WELL REDRILL Annular Disposal of drilling wastes will not be approved. . . ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-.> YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved· 'subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY /b{cLI---q_·-fz:..O,,1 WELL NAME KBd :/Ý -(PROGRAM: exp _ dev --L- redrll_ serv _ wellbore seg _ann. disposal para req_ FIELD & POOL '¡1¡8~¿:~1 INIT CLASS .:¡:;;.et-·· /./(;.;¿L""5. GEOL AREA 82L; UNIT# 0.-51/ ZC;, ON/OFF SHORE Q;} '" -/",' ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . l?:',,)N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . (X-<'. N 3. Unique well name and number. .. . . . . . . . . . . . . . . . (Y J~ ' .f !. . /l I /. - . 4. Well located in a defined pool7Ý.::. . . . . . . . . . . . . . . . l(l!-.¥'-)(é,;,¿¿¿ ~ .~ C:;~ / 60 ,~ f.-.I.A·v:i¿j-¡ ,~ ~:l. 5. Well located proper distance from drilling unit boundary. Cf-'» N. .., ()h ,', I ._. .,- _" : <. I I '/'11.' ,/) / 6. Well located proper distance from other wells.~*. . . C1. N .~* C/.. rï ~(:.. r ¡"~' F<;Y'j·, t..._i '..::J.¿. f' / / ~ - x.. C rJ<-t:' yo;: ~J ,¿' Ie- I ~ L)'.:.:( '5- (ið/,$" 7. Sufficient acreage available in drilling unit.. . . . . . . . (Y) N i':?iA!e 7./ I{.;\:~II ~~ô,c/"11":: ù -r A.e ~-<~_ ~ "Æa/I hL ÞJC-- f.:'C-"5.1r-¡'c....-h~6 '~'ie;·1b 8. If deviated, is wellbore plat included.. . . . . . . . . . . (f)N Po) e.// 6/1':;;"c¿-c. c'ul Lx. c,ef?/r-l7ft4..!-- 120 -""{?C. 5- ¡::?-""! :5/\.4./( 6..::.. D·:?é!F\ýd ) ~ é-L 9. Operator only affected party.. . . . . . . . . . . . . . . . . . (Y,¿N ttx;"'--II ~':/6.:Sc-r- ..~,tV~""-;'l/¡ /...çX~'·,{: -I~~ v:,.¡.fJ ¿:,'--;,,:"L-,/-¡<,~_-';~?-..!r·-/Ã/~ 10. Operator has appropriate bond in force. . . . . . . . . . . . . ex-,SN f"/:t:~/~. aQf/;;~e~s. 7"Ò ¿j1/';;rLS t'::.:)..::-c/=::., i-Þ~ ~'/~-,,(C"j~'-i'::' ,-¡Aft.. ¿.l:I·r.dé.f~'''·l~.J 4/-\C,·.l.· 11. Permit can be issued without conservation order. . . . . . . . ~: N ~ e I ôo( /r...... - ./--b,_" I, \.J / /oj APPR DATE _. 12. Permit can be issued without administrative approval.. . . . . (y) N ,..1 Sf) if " :3 -;.uCJ 13. Can permit be approved before 15-day wait.. . . . . . . . . . (!)N ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . ® N 't-. 15. Surface casing protects all known USDWs. . . . . . . (3) N ~c..f\~~~ Q'lQ~~¡;) ~1Z.\o~ \ ~~C)( b'l ~ p~ '--\CJ ~~~ \'-\'ì.,$)~.\.\>')\.$(\.\\) 16. CMT vol adequate to circulate on conductor & surf csg. . 0Þ N I 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y <&> \ (Jc.. ~ \. (:)0(:) b~\'t>~~\.-.c~ ~ \~G \ú. ~~e- ~~~~~~. 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . (c.\..,,,;:>\-\c-.t,. &~ ~ ~ ~ ~~ ~~: ~::;~~~~I:e~~~r~~~~;~~ro~b:~~~~~:.n.tbe.enapproved.. .. .. ~ ~ ~~"-~\~~ ~~~~. ?\c-h \'\f-\~' 23. If diverter required, does it meet regulations. . . . . . . . . . ~N'~ ¿;, '-.)It~ ~~~c:.!tD\-~t--.... \~ \t\<t.e:~~c0 24. Drilling fluid program schematic & equip list adequate. . . . . N \ 25. BOPEs, do they meet regulation . . . . . . . . . ',,' .. . . . Y N \:\ . _ 26. BOPE press rating appropriate; test to ~DÐCJpsig. - NN "'~~~ ~~\~~~~cJ Q ~ ~. <ß~ t.\t-\W<:' ~~ 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . Y ~ 29. Is presence of H2S gas probable.. . . . . . . . . . '.' . . . . Y ® 30. Permit can be issued w/o hydrogen sulfide measures. . . . . (j) N 31. Data presented on potential overpressure zones . . . . . . . Y~ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . ;/ ^~ k Ý N Ap,PR DATE 33. Seabed condItIon survey (If off-shore). . . . . . . . ./.....--;. Y N ;)1; II ' ;3 r.)":; 34. Contact namelphone for weekly progress reports [~/oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIOfAn,nular COMMISSION: ~~8 ~ðW WM ~ 8~s ~. - TEM~2?1Y)S7~~\ JMH CI) ~ ~ m 'W,~IX Dl}TE o Atj IIY{ 5/~-<:, \ c.... c: r- ~ r--t ~ c::::3 c:::» -.þ,. GEOLOGY APPR DATE Y N Y N ~~~~~~~~'\~ \ ~\ù5'~. \\j'"\ \.. \ \.J~<è ClG.<:>s " . ~ \ \J0è\ \ \.<>\ / --- ./ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01//00) c o z o -I ~ ;tI -I m ( Z -I J: en :Þ XI m :Þ (