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Home My WebLink About208-160Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' From:Rixse, Melvin G (OGC) To:Scott Warner Cc:McLellan, Bryan J (OGC) Subject:20250801 1412 APPROVAL SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Date:Friday, August 1, 2025 2:13:08 PM Scott, Approved to proceed as requested below with setting a plug, squeeze cement, and milling. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, August 1, 2025 1:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Mel, Agree they are typically easier to mill up. I just didn’t know what I was going to be able to get my hands in short order so was mainly requesting approval for the plug set in prep for the squeeze. I plan to set a composite unless one isn’t readily available. We have milled up CIBPs recently without issue and I wasn’t aware of CIO’s recent issues with them. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, August 1, 2025 11:14 AM To: Scott Warner <Scott.Warner@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] RE: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Scott, Wouldn’t the composite plug be the better option if you are going to drill it out? My recent experience in Cook Inlet has been a lot of problems milling CIBPs. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, August 1, 2025 10:45 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: FW: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Bryan/Mel, We recently perforated SD-6 and unfortunately encountered water in BEL 58a, BEL 58, and BEL 56. I’m currently evaluating remediation options and leaning toward a cement squeeze using coil tubing, given the distance involved in patching all affected perforations. I’m requesting approval to set either a CIBP or CBP below the BEL 58a perforations at approximately 4,220’ MD. This will position us for a hesitation cement squeeze via coil. I’d like to set the plug over the weekend to minimize potential water crossflow and preserve production from zones below the water-bearing intervals. Once the plug is in place, I’ll schedule coil operations to perform the squeeze followed by milling out the cement and plug as soon as the unit becomes available. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:43 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com 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. 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 the onward 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. From:Rixse, Melvin G (OGC) To:Scott Warner Cc:McLellan, Bryan J (OGC) Subject:20250801 1412 APPROVAL SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Date:Friday, August 1, 2025 2:13:13 PM Scott, Approved to proceed as requested below with setting a plug, squeeze cement, and milling. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, August 1, 2025 1:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Mel, Agree they are typically easier to mill up. I just didn’t know what I was going to be able to get my hands in short order so was mainly requesting approval for the plug set in prep for the squeeze. I plan to set a composite unless one isn’t readily available. We have milled up CIBPs recently without issue and I wasn’t aware of CIO’s recent issues with them. Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, August 1, 2025 11:14 AM To: Scott Warner <Scott.Warner@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] RE: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Scott, Wouldn’t the composite plug be the better option if you are going to drill it out? My recent experience in Cook Inlet has been a lot of problems milling CIBPs. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, August 1, 2025 10:45 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: FW: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Bryan/Mel, We recently perforated SD-6 and unfortunately encountered water in BEL 58a, BEL 58, and BEL 56. I’m currently evaluating remediation options and leaning toward a cement squeeze using coil tubing, given the distance involved in patching all affected perforations. I’m requesting approval to set either a CIBP or CBP below the BEL 58a perforations at approximately 4,220’ MD. This will position us for a hesitation cement squeeze via coil. I’d like to set the plug over the weekend to minimize potential water crossflow and preserve production from zones below the water-bearing intervals. Once the plug is in place, I’ll schedule coil operations to perform the squeeze followed by milling out the cement and plug as soon as the unit becomes available. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, June 25, 2025 1:43 PM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: SD-06 AOGCC 10-403 325-365 PTD 208-160 Approved 06-25-25 Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com 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. 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 the onward 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: N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,737'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production Liner 7,500psi 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 scott.warner@hilcorp.com 907-564-4506 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 Scott Warner, Operations Engineer AOGCC USE ONLY 8,430psi 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 ADL0359242 / ADL0384372 / FEE-CIRI / FEE-Private 208-160 50-133-20582-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6 / L-80 / Hydril 563 TVD Burst 1,794' 1,580' Size 101' 2,031' MD 4-1/2" See Attached Schematic 5,750psi 101'101' 2,031' July 1, 2025 6,735'4,941' 4-1/2" 4,519' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit S Dionne 6CO 701C Same ~1,177 psi 5,630 & 5,780 Length Baker ZXP Pkr; N/A 1,794 MD / 1,488 TVD & N/A 4,520'5,630'3,558' Ninilchik Beluga-Tyonek Gas 20" 9-5/8" See Attached Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:03 pm, Jun 17, 2025 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2025.06.17 11:27:01 -08'00' 325-365 A.Dewhurst 23JUN25 10-404 BJM 6/24/25 DSR-6/18/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:05:51 -08'00'06/25/25 RBDMS JSB 062625 Well Prognosis Well Name: Susan Dionne 6 API Number: 50-133-20582-00-00 Current Status: Producing Gas Well Permit to Drill Number: 208-160 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 1523 psi @ 3462’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1177 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.78 psi/ft using 15 ppg EMW FIT at the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.78-0.1) = 1177 psi / 0.68 = 1731‘ TVD Top of Applicable Gas Pool: 1833’ MD/ 1505’ TVD Well Status: Online Gas Producer flowing at 427 mcfd, 8 bwpd, 41 psi FTP Brief Well Summary SD-06 was drilled and completed in Decemeber 2008. It has been on steady decline since perfs were last added in February 2024. A capillary string was run quickly after the perf adds to assist with unloading and rate. Additional Beluga perforations will be added to increase production. Notes Regarding Wellbore Condition x Inclination o Max deviation of 69.7° @ 1970’ MD Sail angle of 68° from 1900’ – 3800’ MD x Min ID o 3.858” @ 1507’ MD – Chemical Injection Mandrel x Recent Tags/Fish o 4/10/25 Cap string ran to 4650’ MD o 2/20/24 EL tagged @ 5414’ MD while running in hole with perf guns. Perforated sands while flowing from BEL 70-BEL 97 (4468’- 5404’) w/ 2-3/4” guns on switch o 11/21/23 SL drift w/ 2.8” GR to 5477’ KB Pre-Sundry Steps: 1. MIRU Cap string truck 2. Pull 3/8” cap string from 4650’ MD 3. RD cap string truck 4. RU slickline 5. PT lubricator to 250 psi low/ 2,000 psi high 6. D&T to TD to find updated tag. Last tag with SL was 5477’ KB in November 2023 a. EL tagged at 5414’ MD when running in with perf guns 3 months later b. Drift with ~2.8” GR. Plan to use 2-3/4” perf guns 7. RDMO slickline Well Prognosis Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and perforate Beluga 40 – BEL 91 sands from bottom up with 2-3/4” 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Interval BEL 40 ±2,660' ±2,674' ±1,808' ±1,813' ±14' BEL 40 ±2,713' ±2,719' ±1,827' ±1,829' ±6' BEL 49 ±3,347' ±3,357' ±2,057' ±2,060' ±10' BEL 49 ±3,386' ±3,392' ±2,071' ±2,073' ±6' BEL 50 ±3,420' ±3,426' ±2,083' ±2,085' ±6' BEL 50 ±3,454' ±3,474' ±2,095' ±2,102' ±20' BEL 50 ±3,474' ±3,488' ±2,102' ±2,107' ±14' BEL 50 ±3,497' ±3,508' ±2,111' ±2,115' ±11' BEL 51 ±3,541' ±3,561' ±2,127' ±2,134' ±20' BEL 51 ±3,561' ±3,570' ±2,134' ±2,137' ±9' BEL 52 ±3,585' ±3,605' ±2,143' ±2,150' ±20' BEL 52 ±3,605' ±3,615' ±2,150' ±2,154' ±10' BEL 53 ±3,684' ±3,690' ±2,178' ±2,181' ±6' BEL 53 ±3,697' ±3,703' ±2,183' ±2,185' ±6' BEL 53 ±3,723' ±3,729' ±2,193' ±2,195' ±6' BEL 53 ±3,745' ±3,759' ±2,201' ±2,206' ±14' BEL 54 ±3,765' ±3,771' ±2,208' ±2,210' ±6' BEL 54 ±3,817' ±3,830' ±2,227' ±2,232' ±13' BEL 54 ±3,834' ±3,854' ±2,233' ±2,241' ±20' BEL 54 ±3,854' ±3,893' ±2,241' ±2,256' ±39' BEL 54 ±3,901' ±3,915' ±2,259' ±2,265' ±14' BEL 55 ±3,940' ±3,950' ±2,275' ±2,279' ±10' BEL 56 ±3,986' ±4,005' ±2,295' ±2,304' ±19' BEL 56 ±4,005' ±4,015' ±2,304' ±2,308' ±10' BEL 56 ±4,015' ±4,035' ±2,308' ±2,318' ±20' BEL 56 ±4,035' ±4,039' ±2,318' ±2,320' ±4' BEL 56 ±4,049' ±4,059' ±2,324' ±2,329' ±10' BEL 58 ±4,150' ±4,156' ±2,375' ±2,379' ±6' BEL 58A ±4,187' ±4,193' ±2,396' ±2,399' ±6' BEL 58A ±4,205' ±4,209' ±2,406' ±2,408' ±4' BEL 59 ±4,272' ±4,278' ±2,445' ±2,449' ±6' BEL 59 ±4,281' ±4,301' ±2,451' ±2,463' ±20' BEL 59 ±4,301' ±4,311' ±2,463' ±2,470' ±10' BEL 60 ±4,350' ±4,356' ±2,495' ±2,499' ±6' Well Prognosis BEL 60 ±4,364' ±4,384' ±2,504' ±2,518' ±20' BEL 60 ±4,384' ±4,392' ±2,518' ±2,523' ±8' BEL 91 ±4,895' ±4,905' ±2,921' ±2,930' ±10' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. i. Patch will most likely be used to avoid shutting off current production. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. If necessary, re- run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 04-11-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Bel 70 4,454'4,468'2,565'2,576'14'2/21/24 Open Bel 70 4,477'4,497'2,581'2,597'20'2/21/24 Open Bel 73 4,521'4,533'2,615'2,624'12'2/21/24 Open Bel 74 4,547'4,556'2,635'2,641'9'2/21/24 Open Bel 74 4,587'4,593'2,665'2,670'6'2/21/24 Open Bel 75 4,602'4,620'2,677'2,691'18'2/21/24 Open Bel 78 4,639'4,646'2,706'2,711'7'2/21/24 Open Bel 80 4,658'4,675'2,721'2,735'18'2/21/24 Open Bel 80 4,678'4,684'2,737'2,742'6'2/21/24 Open BEL_82U 4,709’4,728’2,762’2,778’19’09/12/22 Open BEL_83 4,755’4,766’2,801’2,810’11’09/12/22 Open BEL_88 4,772’4,776’2,815’2,818’4’09/12/22 Open BEL_90 4,800’4,806’2,839’2,844’6’09/12/22 Open BEL_90AU 4,810’4,817’2,847’2,853’7’09/12/22 Open BEL_90AL 4,822’4,837’2,858’2,871’15’09/12/22 Open BEL_90B 4,841’4,856’2,874’2,887’15’3/17/22 Open BEL_91L 4,880’4,885’2,908’2,913’5’3/16/22 Open Bel 92 4,958'4,966'2,976'2,983'8'2/20/24 Open BEL_92-6 4,997’5,009’3,010’3,020’12’3/16/22 Open Bel 93 5,023'5,038'3,032'3,045'14'2/20/24 Open Bel 93 5,045'5,049'3,051'3,055'4'2/20/24 Open BEL_94 5,065’5,077’3,069’3,079’12’3/16/22 Open Bel 95 5,094'5,100'3,094'3,099'7'2/20/24 Open BEL_95L 5,116’5,132’3,112’3,127’16’3/16/22 Open Bel 96 5,166'5,170'3,156'3,160'4'2/20/24 Open Bel 97 5,184'5,188'3,172'3,175'4'2/20/24 Open BEL-97M 5,189’5,192’3,177’3,179’3‘02/11/22 Open BEL-97L 5,201’5,205’3,187’3,190’4‘02/11/22 Open BEL_98u 5,220’5,234’3,203’3,216’14’3/16/22 Open BEL-98L 5,245’5,249’3,225’3,228’4‘02/11/22 Open PERFORATION DETAIL-continued on following page OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’ 3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) _____________________________________________________________________________________ Updated by DMA 04-11-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL – continued from previous page Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL-99U 5,259’ 5,263’ 3,236’ 3,240’ 4‘ 02/11/22 Open BEL-99L 5,267’ 5,271’ 3,244’ 3,247’ 4’ 02/11/22 Open BEL-99A 5,285’ 5,292’ 3,259’ 3,266’ 7’ 02/11/22 Open BEL-99B 5,301’ 5,313’ 3,273’ 3,284’ 12 02/11/22 Open BLG- 99BL 5,315’ 5,320’ 3,286’ 3,290’ 5’ 8/21/21 Open BLG-100 5,323’ 5,333’ 3,292’ 3,301’ 10’ 8/21/21 Open BLG-105u 5,347’ 5,356’ 3,313’ 3,321’ 9’ 8/21/21 Open BLG-105m 5,367’ 5,374’ 3,331’ 3,336’ 7’ 8/21/21 Open BLG-105L 5,377’ 5,383’ 3,339’ 3,345’ 6’ 8/21/21 Open Bel 110 5,404' 5,407' 3,363' 3,365' 3' 2/20/24 Open BLG-110m 5,413’ 5,418’ 3,370’ 3,375’ 5’ 8/21/21 Open BLG-115 5,454’ 5,463’ 3,406’ 3,414’ 9‘ 8/16/21 Open BLG-120 5,519’ 5,549’ 3,462’ 3,489’ 30’ 8/31/16 Open BLG-130 5,659’ 5,668’ 3,584’ 3,592’ 9’ 2/23/13 Isolated (8/26/16) BLG-135 5,734’ 5,737’ 3,649 3,652’ 3’ 2/23/13 Isolated (8/26/16) BLG-135 5,740’ 5,744’ 3,654’ 3,658’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,747’ 5,751’ 3,660’ 3,664’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,756’ 5,768’ 3,668 3,678’ 12’ 2/23/13 Isolated (8/26/16) BLG-135 5,791' 5,809' 3,698' 3,714' 18' 12/21/08 Isolated (10/13/14) _____________________________________________________________________________________ Updated by SRW 6-16-25 PROPOSED Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL- cont on pg 2 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL 40 ±2,660'±2,674'±1,808'±1,813'±14'TBD Proposed BEL 40 ±2,713'±2,719'±1,827'±1,829'±6'TBD Proposed BEL 49 ±3,347'±3,357'±2,057'±2,060'±10'TBD Proposed BEL 49 ±3,386'±3,392'±2,071'±2,073'±6'TBD Proposed BEL 50 ±3,420'±3,426'±2,083'±2,085'±6'TBD Proposed BEL 50 ±3,454'±3,474'±2,095'±2,102'±20'TBD Proposed BEL 50 ±3,474'±3,488'±2,102'±2,107'±14'TBD Proposed BEL 50 ±3,497'±3,508'±2,111'±2,115'±11'TBD Proposed BEL 51 ±3,541'±3,561'±2,127'±2,134'±20'TBD Proposed BEL 51 ±3,561'±3,570'±2,134'±2,137'±9'TBD Proposed BEL 52 ±3,585'±3,605'±2,143'±2,150'±20'TBD Proposed BEL 52 ±3,605'±3,615'±2,150'±2,154'±10'TBD Proposed BEL 53 ±3,684'±3,690'±2,178'±2,181'±6'TBD Proposed BEL 53 ±3,697'±3,703'±2,183'±2,185'±6'TBD Proposed BEL 53 ±3,723'±3,729'±2,193'±2,195'±6'TBD Proposed BEL 53 ±3,745'±3,759'±2,201'±2,206'±14'TBD Proposed BEL 54 ±3,765'±3,771'±2,208'±2,210'±6'TBD Proposed BEL 54 ±3,817'±3,830'±2,227'±2,232'±13'TBD Proposed BEL 54 ±3,834'±3,854'±2,233'±2,241'±20'TBD Proposed BEL 54 ±3,854'±3,893'±2,241'±2,256'±39'TBD Proposed BEL 54 ±3,901'±3,915'±2,259'±2,265'±14'TBD Proposed BEL 55 ±3,940'±3,950'±2,275'±2,279'±10'TBD Proposed BEL 56 ±3,986'±4,005'±2,295'±2,304'±19'TBD Proposed BEL 56 ±4,005'±4,015'±2,304'±2,308'±10'TBD Proposed BEL 56 ±4,015'±4,035'±2,308'±2,318'±20'TBD Proposed BEL 56 ±4,035'±4,039'±2,318'±2,320'±4'TBD Proposed BEL 56 ±4,049'±4,059'±2,324'±2,329'±10'TBD Proposed BEL 58 ±4,150'±4,156'±2,375'±2,379'±6'TBD Proposed BEL 58A ±4,187'±4,193'±2,396'±2,399'±6'TBD Proposed BEL 58A ±4,205'±4,209'±2,406'±2,408'±4'TBD Proposed BEL 59 ±4,272'±4,278'±2,445'±2,449'±6'TBD Proposed BEL 59 ±4,281'±4,301'±2,451'±2,463'±20'TBD Proposed BEL 59 ±4,301'±4,311'±2,463'±2,470'±10'TBD Proposed BEL 60 ±4,350'±4,356'±2,495'±2,499'±6'TBD Proposed BEL 60 ±4,364'±4,384'±2,504'±2,518'±20'TBD Proposed BEL 60 ±4,384'±4,392'±2,518'±2,523'±8'TBD Proposed OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’ 3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) _____________________________________________________________________________________ Updated by SRW 6-16-25 PROPOSED Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL – continued from previous page Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Bel 70 4,454' 4,468' 2,565' 2,576' 14' 2/21/24 Open Bel 70 4,477' 4,497' 2,581' 2,597' 20' 2/21/24 Open Bel 73 4,521' 4,533' 2,615' 2,624' 12' 2/21/24 Open Bel 74 4,547' 4,556' 2,635' 2,641' 9' 2/21/24 Open Bel 74 4,587' 4,593' 2,665' 2,670' 6' 2/21/24 Open Bel 75 4,602' 4,620' 2,677' 2,691' 18' 2/21/24 Open Bel 78 4,639' 4,646' 2,706' 2,711' 7' 2/21/24 Open Bel 80 4,658' 4,675' 2,721' 2,735' 18' 2/21/24 Open Bel 80 4,678' 4,684' 2,737' 2,742' 6' 2/21/24 Open BEL_82U 4,709’ 4,728’ 2,762’ 2,778’ 19’ 09/12/22 Open BEL_83 4,755’ 4,766’ 2,801’ 2,810’ 11’ 09/12/22 Open BEL_88 4,772’ 4,776’ 2,815’ 2,818’ 4’ 09/12/22 Open BEL_90 4,800’ 4,806’ 2,839’ 2,844’ 6’ 09/12/22 Open BEL_90AU 4,810’ 4,817’ 2,847’ 2,853’ 7’ 09/12/22 Open BEL_90AL 4,822’ 4,837’ 2,858’ 2,871’ 15’ 09/12/22 Open BEL_90B 4,841’ 4,856’ 2,874’ 2,887’ 15’ 3/17/22 Open BEL_91L 4,880’ 4,885’ 2,908’ 2,913’ 5’ 3/16/22 Open BEL 91 ±4,895' ±4,905' ±2,921' ±2,930' ±10' TBD Proposed Bel 92 4,958' 4,966' 2,976' 2,983' 8' 2/20/24 Open BEL_92-6 4,997’ 5,009’ 3,010’ 3,020’ 12’ 3/16/22 Open Bel 93 5,023' 5,038' 3,032' 3,045' 14' 2/20/24 Open Bel 93 5,045' 5,049' 3,051' 3,055' 4' 2/20/24 Open BEL_94 5,065’ 5,077’ 3,069’ 3,079’ 12’ 3/16/22 Open Bel 95 5,094' 5,100' 3,094' 3,099' 7' 2/20/24 Open BEL_95L 5,116’ 5,132’ 3,112’ 3,127’ 16’ 3/16/22 Open Bel 96 5,166' 5,170' 3,156' 3,160' 4' 2/20/24 Open Bel 97 5,184' 5,188' 3,172' 3,175' 4' 2/20/24 Open BEL-97M 5,189’ 5,192’ 3,177’ 3,179’ 3‘ 02/11/22 Open BEL-97L 5,201’ 5,205’ 3,187’ 3,190’ 4‘ 02/11/22 Open BEL_98u 5,220’ 5,234’ 3,203’ 3,216’ 14’ 3/16/22 Open BEL-98L 5,245’ 5,249’ 3,225’ 3,228’ 4‘ 02/11/22 Open BEL-99U 5,259’ 5,263’ 3,236’ 3,240’ 4‘ 02/11/22 Open BEL-99L 5,267’ 5,271’ 3,244’ 3,247’ 4’ 02/11/22 Open BEL-99A 5,285’ 5,292’ 3,259’ 3,266’ 7’ 02/11/22 Open BEL-99B 5,301’ 5,313’ 3,273’ 3,284’ 12 02/11/22 Open BLG- 99BL 5,315’ 5,320’ 3,286’ 3,290’ 5’ 8/21/21 Open BLG-100 5,323’ 5,333’ 3,292’ 3,301’ 10’ 8/21/21 Open BLG-105u 5,347’ 5,356’ 3,313’ 3,321’ 9’ 8/21/21 Open BLG-105m 5,367’ 5,374’ 3,331’ 3,336’ 7’ 8/21/21 Open BLG-105L 5,377’ 5,383’ 3,339’ 3,345’ 6’ 8/21/21 Open Bel 110 5,404' 5,407' 3,363' 3,365' 3' 2/20/24 Open BLG-110m 5,413’ 5,418’ 3,370’ 3,375’ 5’ 8/21/21 Open BLG-115 5,454’ 5,463’ 3,406’ 3,414’ 9‘ 8/16/21 Open BLG-120 5,519’ 5,549’ 3,462’ 3,489’ 30’ 8/31/16 Open BLG-130 5,659’ 5,668’ 3,584’ 3,592’ 9’ 2/23/13 Isolated (8/26/16) BLG-135 5,734’ 5,737’ 3,649 3,652’ 3’ 2/23/13 Isolated (8/26/16) BLG-135 5,740’ 5,744’ 3,654’ 3,658’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,747’ 5,751’ 3,660’ 3,664’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,756’ 5,768’ 3,668 3,678’ 12’ 2/23/13 Isolated (8/26/16) BLG-135 5,791' 5,809' 3,698' 3,714' 18' 12/21/08 Isolated (10/13/14) 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. 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: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,737 feet 5,630 & 5,780 feet true vertical 4,520 feet N/A feet Effective Depth measured 5,630 feet 1,794 feet true vertical 3,558 feet 1,488 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 1,794' MD 1,488' TVD 1,794 MD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr 1,488 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Scott Warner, Operations Engineer 324-056 Sr Pet Eng: 7,500psi Sr Pet Geo:Sr Res Eng: WINJ WAG 523 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 101' 24 0523 0 4438 47 measured TVD 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-160 50-133-20582-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0359242 / ADL0384372 / FEE CIRI / FEE-PRIVATE Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit S Dionne 6 Plugs Junk measured Length Production Liner 4,941' Casing Structural 4-1/2"6,735'4,519' 101'Conductor Surface Intermediate 20" 9-5/8" 101' 2,031'5,750psi2,031'1,580' Burst Collapse 3,090psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:13 am, Apr 12, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.04.12 09:40:33 -08'00' RBDMS JSB 041824 DSR-4/12/24 Page 1/1 Well Name: NINU SD 06 Report Printed: 4/11/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:2/20/2024 End Date: Report Number 1 Report Start Date 2/20/2024 Report End Date 2/21/2024 Last 24hr Summary PJSM, Spot in & rig up on location, PIck up 3 x guns on switches, Stab onto wellhead & pressure test 250/2000-good, Run in hole to tag @ 5418, Pull out of hole & drop BEL 110 5434-5443 gun, Run in hole with guns for BEL 110 & BEL 97 run in hole to tag @ 5418', Send in correlation (no adjustments), Pull out and lay down gun #3 (9 ft Bel 110), Run in hole & get on depth CCL to TS-16', Shoot (BEL 110 5404-5407) (Gun data: 2-3/4", 15 gram, 60 deg., 6 spf) OG rate: 480 , OG psi: 54, 5- 54 psi, 10-54 psi, Post rate: 480 mcf, Pull up hole to perf (BEL 97 5184-5188 TS-CCL=9', OG rate: 480 , OG psi: 54, 5- 54 psi, 10-51 psi, Post rate: 471 mcf, Pull out of the hole, Pick up guns for BEL 96(4'), BEL 95(6'), BEL 93(4'), Run in hole, Perform correlation pass (no correction), CCL to TS=27.5", (BEL 96 5166-5170) OG rate: 502 , OG psi: 53, 5-53 psi, 10-53 psi, Post rate: 503 mcf, Pull up to shoot (BEL 95 5094-5100) CCL-TS=16', OG rate: 503 , OG psi: 53, 5- 53psi, 10-53 psi, Post rate: 512 mcf, Pull up to shoot (BEL 93 5045-5049) CCL to TS=9', OG rate: 512 , OG psi: 53, 5- 53psi, 10-53 psi, Post rate: 560 mcf, Pull out of hole Lay down spent guns, Pick up guns for BEL 93 (15)', BEL 92 (9'), Run in hole & correlate (No adjustment), Get depth CCL-TS=20.5', Perf (BEL 93 5023-5038), OG rate: 544, OG psi: 53, 5- 53psi, 10-53 psi, Post rate: 514 mcf, Pull up hole to perf CCL-TS=9', (BEL 92 4958-4966) OG rate: 560 , OG psi: 53, 5- 53psi, 10-53 psi, Post rate: 514 mcf, Report Number 2 Report Start Date 2/21/2024 Report End Date 2/22/2024 Last 24hr Summary PJSM, Start & warm equipment, Pressure test 250/2000-good, Perf the following formations: BEL 80 (4678-4684) OG psi: 53/End psi: 53 , BEL 80 (4658-4675) OG psi: 53/End psi: 53, BEL78 (4639-4646) OG psi: 54/End psi: 56, BEL 75 (4601-4620) OG psi: 60/End psi: 54, BEL 74 (4587-4593) OG psi: 56/End psi: 58, BEL 73 (4521-4533) OG psi: 57/End psi: 56 , BEL 70 (4477-4497 OG psi: 58/End psi: 78), BEL 70 (4454-4468)OG psi: 57 /End psi: 75 , Pull out of the hole, Shut in & secure well, Rig down & release Yellowjacket Eline Services. Report Number 3 Report Start Date 4/10/2024 Report End Date 4/11/2024 Last 24hr Summary MIRU Capillary tubing truck. Load 3/8" cap string reel. Make up pack off assembly and 3/4" OD foot valve. Stab on well. PT pack off connection 250/3500 psi. Run Capillary string to 4650' and set in tension 800 lbs up. Install Hanger and set static packoff lock downs. Rig down injector head. Hand over to production to setup soap skid. Field: Ninilchik Sundry #: 324-056 State: ALASKA Rig/Service:Permit to Drill (PTD) #:208-160Permit to Drill (PTD) #:208-160 Wellbore API/UWI:50-133-20582-00-00 _____________________________________________________________________________________ Updated by DMA 04-11-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Bel 70 4,454'4,468'2,565'2,576'14'2/21/24 Open Bel 70 4,477'4,497'2,581'2,597'20'2/21/24 Open Bel 73 4,521'4,533'2,615'2,624'12'2/21/24 Open Bel 74 4,547'4,556'2,635'2,641'9'2/21/24 Open Bel 74 4,587'4,593'2,665'2,670'6'2/21/24 Open Bel 75 4,602'4,620'2,677'2,691'18'2/21/24 Open Bel 78 4,639'4,646'2,706'2,711'7'2/21/24 Open Bel 80 4,658'4,675'2,721'2,735'18'2/21/24 Open Bel 80 4,678'4,684'2,737'2,742'6'2/21/24 Open BEL_82U 4,709’4,728’2,762’2,778’19’09/12/22 Open BEL_83 4,755’4,766’2,801’2,810’11’09/12/22 Open BEL_88 4,772’4,776’2,815’2,818’4’09/12/22 Open BEL_90 4,800’4,806’2,839’2,844’6’09/12/22 Open BEL_90AU 4,810’4,817’2,847’2,853’7’09/12/22 Open BEL_90AL 4,822’4,837’2,858’2,871’15’09/12/22 Open BEL_90B 4,841’4,856’2,874’2,887’15’3/17/22 Open BEL_91L 4,880’4,885’2,908’2,913’5’3/16/22 Open Bel 92 4,958'4,966'2,976'2,983'8'2/20/24 Open BEL_92-6 4,997’5,009’3,010’3,020’12’3/16/22 Open Bel 93 5,023'5,038'3,032'3,045'14'2/20/24 Open Bel 93 5,045'5,049'3,051'3,055'4'2/20/24 Open BEL_94 5,065’5,077’3,069’3,079’12’3/16/22 Open Bel 95 5,094'5,100'3,094'3,099'7'2/20/24 Open BEL_95L 5,116’5,132’3,112’3,127’16’3/16/22 Open Bel 96 5,166'5,170'3,156'3,160'4'2/20/24 Open Bel 97 5,184'5,188'3,172'3,175'4'2/20/24 Open BEL-97M 5,189’5,192’3,177’3,179’3‘02/11/22 Open BEL-97L 5,201’5,205’3,187’3,190’4‘02/11/22 Open BEL_98u 5,220’5,234’3,203’3,216’14’3/16/22 Open BEL-98L 5,245’5,249’3,225’3,228’4‘02/11/22 Open PERFORATION DETAIL-continued on following page OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’ 3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) _____________________________________________________________________________________ Updated by DMA 04-11-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL – continued from previous page Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL-99U 5,259’ 5,263’ 3,236’ 3,240’ 4‘ 02/11/22 Open BEL-99L 5,267’ 5,271’ 3,244’ 3,247’ 4’ 02/11/22 Open BEL-99A 5,285’ 5,292’ 3,259’ 3,266’ 7’ 02/11/22 Open BEL-99B 5,301’ 5,313’ 3,273’ 3,284’ 12 02/11/22 Open BLG- 99BL 5,315’ 5,320’ 3,286’ 3,290’ 5’ 8/21/21 Open BLG-100 5,323’ 5,333’ 3,292’ 3,301’ 10’ 8/21/21 Open BLG-105u 5,347’ 5,356’ 3,313’ 3,321’ 9’ 8/21/21 Open BLG-105m 5,367’ 5,374’ 3,331’ 3,336’ 7’ 8/21/21 Open BLG-105L 5,377’ 5,383’ 3,339’ 3,345’ 6’ 8/21/21 Open Bel 110 5,404' 5,407' 3,363' 3,365' 3' 2/20/24 Open BLG-110m 5,413’ 5,418’ 3,370’ 3,375’ 5’ 8/21/21 Open BLG-115 5,454’ 5,463’ 3,406’ 3,414’ 9‘ 8/16/21 Open BLG-120 5,519’ 5,549’ 3,462’ 3,489’ 30’ 8/31/16 Open BLG-130 5,659’ 5,668’ 3,584’ 3,592’ 9’ 2/23/13 Isolated (8/26/16) BLG-135 5,734’ 5,737’ 3,649 3,652’ 3’ 2/23/13 Isolated (8/26/16) BLG-135 5,740’ 5,744’ 3,654’ 3,658’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,747’ 5,751’ 3,660’ 3,664’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,756’ 5,768’ 3,668 3,678’ 12’ 2/23/13 Isolated (8/26/16) BLG-135 5,791' 5,809' 3,698' 3,714' 18' 12/21/08 Isolated (10/13/14) 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Remove Cap String Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,737 feet 5,630 & 5,780 feet true vertical 4,520 feet N/A feet Effective Depth measured 5,630 feet 1,794 feet true vertical 3,558 feet 1,488 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 1,794' MD 1,488' TVD 1,794 MD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr 1,488 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Scott Warner, Operations Engineer N/A Sr Pet Eng: 7,500psi Sr Pet Geo:Sr Res Eng: WINJ WAG 569 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 101' 12 0561 0 558 47 measured TVD 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-160 50-133-20582-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0359242 / ADL0384372 / FEE CIRI / FEE-PRIVATE Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit S Dionne 6 Plugs Junk measured Length Production Liner 4,941' Casing Structural 4-1/2"6,735'4,519' 101'Conductor Surface Intermediate 20" 9-5/8" 101' 2,031'5,750psi2,031'1,580' Burst Collapse 3,090psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Coldiron at 10:19 am, Feb 09, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.09 10:09:48 - 09'00' Noel Nocas (4361) RBDMS JSB 021324 DSR-2/13/24 Page 1/1 Well Name: NINU SD 06 Report Printed: 2/9/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:11/10/2023 End Date: Report Number 1 Report Start Date 11/21/2023 Report End Date 11/22/2023 Last 24hr Summary MIRU Capillary string truck. Pull 4650' of 3/8" SS capillary tubing. Pollard SL RU for drift/tag Report Number 2 Report Start Date 2/2/2024 Report End Date 2/2/2024 Last 24hr Summary Complete production review, no change in rate. Field: Ninilchik Sundry #: State: ALASKA Rig/Service:Permit to Drill (PTD) #:208-160Permit to Drill (PTD) #:208-160 Wellbore API/UWI:50-133-20582-00-00 _____________________________________________________________________________________ Updated by DMA 02-01-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL_82U 4,709’4,728’2,762’2,778’19’09/12/22 Open BEL_83 4,755’4,766’2,801’2,810’11’09/12/22 Open BEL_88 4,772’4,776’2,815’2,818’4’09/12/22 Open BEL_90 4,800’4,806’2,839’2,844’6’09/12/22 Open BEL_90AU 4,810’4,817’2,847’2,853’7’09/12/22 Open BEL_90AL 4,822’4,837’2,858’2,871’15’09/12/22 Open BEL_90B 4,841’4,856’2,874’2,887’15’3/17/22 Open BEL_91L 4,880’4,885’2,908’2,913’5’3/16/22 Open BEL_92-6 4,997’5,009’3,010’3,020’12’3/16/22 Open BEL_94 5,065’5,077’3,069’3,079’12’3/16/22 Open BEL_95L 5,116’5,132’3,112’3,127’16’3/16/22 Open BEL-97M 5,189’5,192’3,177’3,179’3‘02/11/22 Open BEL-97L 5,201’5,205’3,187’3,190’4‘02/11/22 Open BEL_98u 5,220’5,234’3,203’3,216’14’3/16/22 Open BEL-98L 5,245’5,249’3,225’3,228’4‘02/11/22 Open BEL-99U 5,259’5,263’3,236’3,240’4‘02/11/22 Open BEL-99L 5,267’5,271’3,244’3,247’4’02/11/22 Open BEL-99A 5,285’5,292’3,259’3,266’7’02/11/22 Open BEL-99B 5,301’5,313’3,273’3,284’12 02/11/22 Open BLG- 99BL 5,315’5,320’3,286’3,290’5’8/21/21 Open BLG-100 5,323’5,333’3,292’3,301’10’8/21/21 Open BLG-105u 5,347’5,356’3,313’3,321’9’8/21/21 Open BLG-105m 5,367’5,374’3,331’3,336’7’8/21/21 Open BLG-105L 5,377’5,383’3,339’3,345’6’8/21/21 Open BLG-110m 5,413’5,418’3,370’3,375’5’8/21/21 Open BLG-115 5,454’5,463’3,406’3,414’9‘8/16/21 Open BLG-120 5,519’5,549’3,462’3,489’30’8/31/16 Open BLG-130 5,659’5,668’3,584’3,592’9’2/23/13 Isolated (8/26/16) BLG-135 5,734’5,737’3,649 3,652’3’2/23/13 Isolated (8/26/16) BLG-135 5,740’5,744’3,654’3,658’4’2/23/13 Isolated (8/26/16) BLG-135 5,747’5,751’3,660’3,664’4’2/23/13 Isolated (8/26/16) BLG-135 5,756’5,768’3,668 3,678’12’2/23/13 Isolated (8/26/16) BLG-135 5,791'5,809'3,698'3,714'18'12/21/08 Isolated (10/13/14) INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) 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: Install Cap String, N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,737'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production Liner 7,500psi 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 ZXP Packer & N/A 1,794 MD / 1,488 TVD & N/A 4,520'5,630'3,558' Ninilchik Beluga-Tyonek Gas 20" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit S Dionne 6CO 701C Same ~1,186psi 5,630 & 5,780 Length February 15, 2024 6,735'4,941' 4-1/2" 4,519' Perforation Depth MD (ft): 4-1/2" See Attached Schematic 5,750psi 101'101' 2,031' Size 101' 2,031' MD Hilcorp Alaska, LLC Proposed Pools: 12.6 / L-80 / Hydril 563 TVD Burst 1,794' 1,580' 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 ADL0359242 / ADL0384372 / FEE-CIRI / FEE-Private 208-160 50-133-20582-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY 8,430psi Tubing Grade: scott.warner@hilcorp.com 907-564-4506 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: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 2:21 pm, Feb 07, 2024 324-056 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.06 18:06:02 - 09'00' Noel Nocas (4361) 10-404 SFD 2/8/2024 DSR-2/13/24BJM 2/14/24 Perforate *&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:26:45 -06'00' RBDMS JSB 021524 Well Prognosis Well: SD-06 Date: 1/31/24 Well Name: SD-06 API Number: 50-133-20582-00-00 Current Status: Producing Gas Well Permit to Drill Number: 208-160 Regulatory Contact: Donna Ambruz 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Max. Expected BHP: ~ 1535 psi @ 3,489’ TVD Based on .44 psi/ft Max. Potential Surface Pressure ~ 1186 psi Based on 0.1 psi/ft gas gradient to surface Well Status: Online Gas Producer flowing at ~530 -mcfd, 10-20 bwpd, FTP: 47 psi Well Summary SD-06 has been on steady decline since perfs were last added in September 2022. A capillary string was run quickly after the perf adds to assist with unloading and rate has continued to decline since. The cap string was pulled in November 2023 prior to a Slickline D&T and the well has stayed online with the assist of daily soap sticks. Additional Beluga perforations will be added to increase production and assist with unloading. Notes Regarding Wellbore Condition **68 degree sail angle from 1900’ – 3800’ 3/15/22 Drift with 3.5” DDB to 5565’ 3/17/22 Perforate 4841-56’ w 2-7/8 gun 9/11/22 Perforate multiple intervals with 2-7/8” guns 11/21/23 Cap string pulled. Drift with 2.8” GR to 5477’ kb Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and perforate BEL 70-110 sands while flowing from bottom up: Sand Top MD Btm MD Top TVD Btm TVD Interval Bel 70 ±4,453' ±4,468' ±2,565' ±2,576' ±15' Bel 70 ±4,476' ±4,498' ±2,582' ±2,598' ±22' Bel 73 ±4,522' ±4,533' ±2,616' ±2,624' ±11' Bel 74 ±4,547' ±4,556' ±2,635' ±2,641' ±9' Bel 74 ±4,587' ±4,593' ±2,665' ±2,670' ±6' Bel 75 ±4,601' ±4,620' ±2,676' ±2,691' ±18' Bel 78 ±4,639' ±4,646' ±2,706' ±2,711' ±7' Bel 80 ±4,658' ±4,675' ±2,721' ±2,735' ±18' Bel 80 ±4,678' ±4,684' ±2,737' ±2,742' ±6' Bel 92 ±4,958' ±4,966' ±2,976' ±2,983' ±8' Bel 93 ±5,023' ±5,038' ±3,032' ±3,045' ±14' Bel 93 ±5,045' ±5,049' ±3,051' ±3,055' ±4' Bel 95 ±5,094' ±5,100' ±3,094' ±3,099' ±7' Well Prognosis Well: SD-06 Date: 1/31/24 Bel 96 ±5,166' ±5,170' ±3,156' ±3,160' ±4' Bel 97 ±5,184' ±5,188' ±3,172' ±3,175' ±4' Bel 110 ±5,404' ±5,407' ±3,363' ±3,365' ±3' Bel 110 ±5,434' ±5,443' ±3,389' ±3,397' ±9' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, re run cap string to aid with water production if encountered post perforating Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 02-01-24 SCHEMATIC Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL_82U 4,709’4,728’2,762’2,778’19’09/12/22 Open BEL_83 4,755’4,766’2,801’2,810’11’09/12/22 Open BEL_88 4,772’4,776’2,815’2,818’4’09/12/22 Open BEL_90 4,800’4,806’2,839’2,844’6’09/12/22 Open BEL_90AU 4,810’4,817’2,847’2,853’7’09/12/22 Open BEL_90AL 4,822’4,837’2,858’2,871’15’09/12/22 Open BEL_90B 4,841’4,856’2,874’2,887’15’3/17/22 Open BEL_91L 4,880’4,885’2,908’2,913’5’3/16/22 Open BEL_92-6 4,997’5,009’3,010’3,020’12’3/16/22 Open BEL_94 5,065’5,077’3,069’3,079’12’3/16/22 Open BEL_95L 5,116’5,132’3,112’3,127’16’3/16/22 Open BEL-97M 5,189’5,192’3,177’3,179’3‘02/11/22 Open BEL-97L 5,201’5,205’3,187’3,190’4‘02/11/22 Open BEL_98u 5,220’5,234’3,203’3,216’14’3/16/22 Open BEL-98L 5,245’5,249’3,225’3,228’4‘02/11/22 Open BEL-99U 5,259’5,263’3,236’3,240’4‘02/11/22 Open BEL-99L 5,267’5,271’3,244’3,247’4’02/11/22 Open BEL-99A 5,285’5,292’3,259’3,266’7’02/11/22 Open BEL-99B 5,301’5,313’3,273’3,284’12 02/11/22 Open BLG- 99BL 5,315’5,320’3,286’3,290’5’8/21/21 Open BLG-100 5,323’5,333’3,292’3,301’10’8/21/21 Open BLG-105u 5,347’5,356’3,313’3,321’9’8/21/21 Open BLG-105m 5,367’5,374’3,331’3,336’7’8/21/21 Open BLG-105L 5,377’5,383’3,339’3,345’6’8/21/21 Open BLG-110m 5,413’5,418’3,370’3,375’5’8/21/21 Open BLG-115 5,454’5,463’3,406’3,414’9‘8/16/21 Open BLG-120 5,519’5,549’3,462’3,489’30’8/31/16 Open BLG-130 5,659’5,668’3,584’3,592’9’2/23/13 Isolated (8/26/16) BLG-135 5,734’5,737’3,649 3,652’3’2/23/13 Isolated (8/26/16) BLG-135 5,740’5,744’3,654’3,658’4’2/23/13 Isolated (8/26/16) BLG-135 5,747’5,751’3,660’3,664’4’2/23/13 Isolated (8/26/16) BLG-135 5,756’5,768’3,668 3,678’12’2/23/13 Isolated (8/26/16) BLG-135 5,791'5,809'3,698'3,714'18'12/21/08 Isolated (10/13/14) INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) _____________________________________________________________________________________ Updated by DMA 01-31-24 PROPOSED Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Bel 70 ±4,453'±4,468'±2,565'±2,576'±15'Proposed TBD Bel 70 ±4,476'±4,498'±2,582'±2,598'±22'Proposed TBD Bel 73 ±4,522'±4,533'±2,616'±2,624'±11'Proposed TBD Bel 74 ±4,547'±4,556'±2,635'±2,641'±9'Proposed TBD Bel 74 ±4,587'±4,593'±2,665'±2,670'±6'Proposed TBD Bel 75 ±4,601'±4,620'±2,676'±2,691'±18'Proposed TBD Bel 78 ±4,639'±4,646'±2,706'±2,711'±7'Proposed TBD Bel 80 ±4,658'±4,675'±2,721'±2,735'±18'Proposed TBD Bel 80 ±4,678'±4,684'±2,737'±2,742'±6'Proposed TBD Bel 92 ±4,958'±4,966'±2,976'±2,983'±8'Proposed TBD BEL_82U 4,709’4,728’2,762’2,778’19’09/12/22 Open BEL_83 4,755’4,766’2,801’2,810’11’09/12/22 Open BEL_88 4,772’4,776’2,815’2,818’4’09/12/22 Open BEL_90 4,800’4,806’2,839’2,844’6’09/12/22 Open BEL_90AU 4,810’4,817’2,847’2,853’7’09/12/22 Open BEL_90AL 4,822’4,837’2,858’2,871’15’09/12/22 Open BEL_90B 4,841’4,856’2,874’2,887’15’3/17/22 Open BEL_91L 4,880’4,885’2,908’2,913’5’3/16/22 Open BEL_92-6 4,997’5,009’3,010’3,020’12’3/16/22 Open Bel 93 ±5,023'±5,038'±3,032'±3,045'±14'Proposed TBD Bel 93 ±5,045'±5,049'±3,051'±3,055'±4'Proposed TBD BEL_94 5,065’5,077’3,069’3,079’12’3/16/22 Open Bel 95 ±5,094'±5,100'±3,094'±3,099'±7'Proposed TBD BEL_95L 5,116’5,132’3,112’3,127’16’3/16/22 Open Bel 96 ±5,166'±5,170'±3,156'±3,160'±4'Proposed TBD Bel 97 ±5,184'±5,188'±3,172'±3,175'±4'Proposed TBD BEL-97M 5,189’5,192’3,177’3,179’3‘02/11/22 Open BEL-97L 5,201’5,205’3,187’3,190’4‘02/11/22 Open BEL_98u 5,220’5,234’3,203’3,216’14’3/16/22 Open BEL-98L 5,245’5,249’3,225’3,228’4‘02/11/22 Open PERFORATION DETAIL-continued on following page OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ 3/8”Capillary String Surf 4,650’ JEWELRY DETAIL No.Depth MD Depth TVD ID Item 1 1,507’1,331’3.858 Baker Chemical Injection Mandrel 2 1,794'1,488’3.958 Liner Hanger and ZXP Packer 3 5,630’ 3,559’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’3,689’n/a CIBP (10/13/14) _____________________________________________________________________________________ Updated by DMA 01-31-24 PROPOSED Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL – continued from previous page Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL-99U 5,259’ 5,263’ 3,236’ 3,240’ 4‘ 02/11/22 Open BEL-99L 5,267’ 5,271’ 3,244’ 3,247’ 4’ 02/11/22 Open BEL-99A 5,285’ 5,292’ 3,259’ 3,266’ 7’ 02/11/22 Open BEL-99B 5,301’ 5,313’ 3,273’ 3,284’ 12 02/11/22 Open BLG- 99BL 5,315’ 5,320’ 3,286’ 3,290’ 5’ 8/21/21 Open BLG-100 5,323’ 5,333’ 3,292’ 3,301’ 10’ 8/21/21 Open BLG-105u 5,347’ 5,356’ 3,313’ 3,321’ 9’ 8/21/21 Open BLG-105m 5,367’ 5,374’ 3,331’ 3,336’ 7’ 8/21/21 Open BLG-105L 5,377’ 5,383’ 3,339’ 3,345’ 6’ 8/21/21 Open Bel 110 ±5,404' ±5,407' ±3,363' ±3,365' ±3' Proposed TBD BLG-110m 5,413’ 5,418’ 3,370’ 3,375’ 5’ 8/21/21 Open Bel 110 ±5,434' ±5,443' ±3,389' ±3,397' ±9' Proposed TBD BLG-115 5,454’ 5,463’ 3,406’ 3,414’ 9‘ 8/16/21 Open BLG-120 5,519’ 5,549’ 3,462’ 3,489’ 30’ 8/31/16 Open BLG-130 5,659’ 5,668’ 3,584’ 3,592’ 9’ 2/23/13 Isolated (8/26/16) BLG-135 5,734’ 5,737’ 3,649 3,652’ 3’ 2/23/13 Isolated (8/26/16) BLG-135 5,740’ 5,744’ 3,654’ 3,658’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,747’ 5,751’ 3,660’ 3,664’ 4’ 2/23/13 Isolated (8/26/16) BLG-135 5,756’ 5,768’ 3,668 3,678’ 12’ 2/23/13 Isolated (8/26/16) BLG-135 5,791' 5,809' 3,698' 3,714' 18' 12/21/08 Isolated (10/13/14) 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. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SD-06 50133205820000 208160 9/12/2022 Yellowjacket PERF SRU 32A-33 50133101640100 191014 9/21/2022 Yellowjacket PERF KBU 42-06Y 50133206340000 214089 9/26/2022 Yellowjacket GPT-PERF CLU 05RD2 50133204740200 222092 9/29/2022 Yellowjacket PERF SCU 344-33 50133202930100 218054 10/8/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. 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^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮϵ͘ϱͬyͲϱϲͬW ^ƵƌĨ ϭϬϭΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬEͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨ Ϯ͕ϬϯϭΖ ϰͲϭͬϮΗ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϲϯ ϯ͘ϵϱϴ ϭ͕ϳϵϰ͛ ϲ͕ϳϯϱ͛ dh/E'd/> ϰͲϭͬϮΗ dŝĞͲĂĐŬdƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϲϯ ϯ͘ϵϱϴ ^ƵƌĨ ϭ͕ϳϵϰ͛ EŽ ĞƉƚŚ D ĞƉƚŚ ds/ /ƚĞŵ ϭ ϭ͕ϱϬϳ͛ ϭ͕ϯϯϭ͛ ϯ͘ϴϱϴ ĂŬĞƌŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶDĂŶĚƌĞů Ϯ ϭ͕ϳϵϰΖ ϭ͕ϰϴϴ͛ ϯ͘ϵϱϴ >ŝŶĞƌ,ĂŶŐĞƌĂŶĚyWWĂĐŬĞƌ ϯ ϱ͕ϲϯϬ͛ ϯ͕ϱϱϵ͛ ŶͬĂ /WǁͬϭϬ͛ĐĞŵĞŶƚ͘dŽсϱϲϯϬ͛D;ϴͬϮϲͬϭϲͿ ϰ ϱ͕ϳϴϬ͛ ϯ͕ϲϴϵ͛ ŶͬĂ /W;ϭϬͬϭϯͬϭϰͿ KWE,K>ͬDEdd/> ϵͲϱͬϴΗ ϭϮͲϭͬϰ͟,ŽůĞ͗ϮϭϳďďůƐϭϮƉƉŐdǇƉĞ/ĐĞŵĞŶƚƉƵŵƉĞĚ͘ϳϭďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮΗ >ŝŶĞƌ ϴͲϭͬϮΗ,ŽůĞ͗ϭϬϱďďůƐϭϮ͘ϱƉƉŐĐůĂƐƐ'ůĞĂĚĂŶĚϭϵϲďďůƐĐůĂƐƐ'ϭϱ͘ϴƉƉŐƚĂŝůƉƵŵƉĞĚ͘EŽůŽƐƐĞƐ͘ ϮϬнďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘ϭϮͬϭϱͬϬϴ>ƐŚŽǁƐdŽĂƚdŽ>͘ /E>/Ed/KEd/> ϲϵĚĞŐƌĞĞƐĂŝůĂŶŐůĞĨƌŽŵϭ͕ϵϳϬΖͲϯ͕ϴϮϱΖD ϭͬϰΗKϬ͘ϬϰϵΗǁĂůů ŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞ ƚŝĞĚŝŶƚŽŵĂŶĚƌĞůĂƚ ϭ͕ϱϬϳΖǁͬĐŚĞĐŬǀĂůǀĞ ĞŵĞŶƚĂƚ ϲϮϱϬ͛dD ŝŶƐŝĚĞϰͲϭͬϮ͟ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ͗:>>ϬϴͬϭϭͬϮϮ WZKWK^ ^ƵƐĂŶŝŽŶŶĞϬϲ W/͗ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ Wd͗ϮϬϴͲϭϲϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ Ğůϳϱʹ ĞůϵϬ>цϰ͕ϲϬϮ цϰ͕ϴϯϳ цϮ͕ϲϳϲ цϮ͕ϴϳϭ цϮϯϱ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϵϬ ϰ͕ϴϰϭ͛ ϰ͕ϴϱϲ͛ Ϯ͕ϴϳϰ͛ Ϯ͕ϴϴϳ͛ ϭϱ͛ ϯͬϭϳͬϮϮ KƉĞŶ >ͺϵϭ> ϰ͕ϴϴϬ͛ ϰ͕ϴϴϱ͛ Ϯ͕ϵϬϴ͛ Ϯ͕ϵϭϯ͛ ϱ͛ ϯͬϭϲͬϮϮ KƉĞŶ >ͺϵϮͲϲ ϰ͕ϵϵϳ͛ ϱ͕ϬϬϵ͛ ϯ͕ϬϭϬ͛ ϯ͕ϬϮϬ͛ ϭϮ͛ ϯͬϭϲͬϮϮ KƉĞŶ >ͺϵϰ ϱ͕Ϭϲϱ͛ ϱ͕Ϭϳϳ͛ ϯ͕Ϭϲϵ͛ ϯ͕Ϭϳϵ͛ ϭϮ͛ ϯͬϭϲͬϮϮ KƉĞŶ >ͺϵϱ> ϱ͕ϭϭϲ͛ ϱ͕ϭϯϮ͛ ϯ͕ϭϭϮ͛ ϯ͕ϭϮϳ͛ ϭϲ͛ ϯͬϭϲͬϮϮ KƉĞŶ >ͲϵϳD ϱ͕ϭϴϵ͛ ϱ͕ϭϵϮ͛ ϯ͕ϭϳϳ͛ ϯ͕ϭϳϵ͛ ϯ͚ ϬϮͬϭϭͬϮϮ KƉĞŶ >Ͳϵϳ> ϱ͕ϮϬϭ͛ ϱ͕ϮϬϱ͛ ϯ͕ϭϴϳ͛ ϯ͕ϭϵϬ͛ ϰ͚ ϬϮͬϭϭͬϮϮ KƉĞŶ >ͺϵϴƵ ϱ͕ϮϮϬ͛ ϱ͕Ϯϯϰ͛ ϯ͕ϮϬϯ͛ ϯ͕Ϯϭϲ͛ ϭϰ͛ ϯͬϭϲͬϮϮ KƉĞŶ >Ͳϵϴ> ϱ͕Ϯϰϱ͛ ϱ͕Ϯϰϵ͛ ϯ͕ϮϮϱ͛ ϯ͕ϮϮϴ͛ ϰ͚ ϬϮͬϭϭͬϮϮ KƉĞŶ >Ͳϵϵh ϱ͕Ϯϱϵ͛ ϱ͕Ϯϲϯ͛ ϯ͕Ϯϯϲ͛ ϯ͕ϮϰϬ͛ ϰ͚ ϬϮͬϭϭͬϮϮ KƉĞŶ >Ͳϵϵ> ϱ͕Ϯϲϳ͛ ϱ͕Ϯϳϭ͛ ϯ͕Ϯϰϰ͛ ϯ͕Ϯϰϳ͛ ϰ͛ ϬϮͬϭϭͬϮϮ KƉĞŶ >Ͳϵϵ ϱ͕Ϯϴϱ͛ ϱ͕ϮϵϮ͛ ϯ͕Ϯϱϵ͛ ϯ͕Ϯϲϲ͛ ϳ͛ ϬϮͬϭϭͬϮϮ KƉĞŶ >Ͳϵϵ ϱ͕ϯϬϭ͛ ϱ͕ϯϭϯ͛ ϯ͕Ϯϳϯ͛ ϯ͕Ϯϴϰ͛ ϭϮ ϬϮͬϭϭͬϮϮ KƉĞŶ >'Ͳϵϵ> ϱ͕ϯϭϱ͛ ϱ͕ϯϮϬ͛ ϯ͕Ϯϴϲ͛ ϯ͕ϮϵϬ͛ ϱ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϬ ϱ͕ϯϮϯ͛ ϱ͕ϯϯϯ͛ ϯ͕ϮϵϮ͛ ϯ͕ϯϬϭ͛ ϭϬ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱƵ ϱ͕ϯϰϳ͛ ϱ͕ϯϱϲ͛ ϯ͕ϯϭϯ͛ ϯ͕ϯϮϭ͛ ϵ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱŵ ϱ͕ϯϲϳ͛ ϱ͕ϯϳϰ͛ ϯ͕ϯϯϭ͛ ϯ͕ϯϯϲ͛ ϳ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱ> ϱ͕ϯϳϳ͛ ϱ͕ϯϴϯ͛ ϯ͕ϯϯϵ͛ ϯ͕ϯϰϱ͛ ϲ͛ 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ƚŽŽůƐƚƌŝŶŐĂŶĚƌĞŵŽǀĞϳĨƚǁĞŝŐŚƚďĂƌ͘DĂŬĞƵƉůƵďƌŝĐĂƚŽƌ͕ĚƌŽƉƐŽĂƉƐƚŝĐŬƐŝŶƚƌĞĞ͕ůĞƚƐĂŵĞƐŽĂŬ͘ŽŶƚŝŶƵĞŐŽŝŶŐŝŶ ŚŽůĞǁŝƚŚƉĞƌĨŐƵŶĂƐƐĞŵďůǇηϮͲϯͬϴǆϭΖĐĂďůĞŚĞĂĚ͕'ĂŵŵĂZĂǇϮͲϯͬϰǆϳΖ͕^ŚŽĐŬƐƵďϮͲϯͬϰǆϮΖ͕ŐƵŶĂƐƐĞŵďůǇϮͲϳͬϴ 'K,^Wϲ^W&yϮϵ͘ϱ&d͘dŽŽůƐƚƌŝŶŐůĞŶŐƚŚϯϵ͘ϱĨƚ͘ƚŽϱϯϭϬΖ͘ZƵŶĐŽƌƌĞůĂƚŝŽŶůŽŐĨͬϱ͕ϯϭϬĨƚ͘ƚŽϱ͕ϬϴϬĨƚ͘ƐĞŶĚůŽŐƐ ŝŶƚŽƚŽǁŶƐƉŽƚŐƵŶƐĂŶĚƉĞƌĨĂƚ;>ϵϵ>ϱ͕ϮϲϳΖƚŽϱ͕ϮϳϭΖͿ͕ŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞĨŽƌϱŵŝŶƵƚĞƐƚďŐƉƌĞƐƐƵƌĞϲϴƉƐŝ͘WĞƌĨƚŚĞ ;>ϵϵhĨͬϱ͕ϮϱϵΖƚŽϱ͕ϮϲϯΖͿŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞϱŵŝŶƵƚĞƐƚďŐϲϳ͘ϵϴƉƐŝ͘WĞƌĨƚŚĞ;>ϵϴůϱ͕ϮϰϱΖƚŽϱ͕ϮϰϵΖͿŵŽŶŝƚŽƌ ƉƌĞƐƐƵƌĞϱŵŝŶƵƚĞƐ͕ƚďŐƉƌĞƐƐƵƌĞϲϴ͘ϵϯƉƐŝ͘WĞƌĨƚŚĞ;>ϵϳůϱ͕ϮϬϭΖƚŽϱ͕ϮϬϱΖͿŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞϱŵŝŶƵƚĞƐ͕ƚďŐƉƌĞƐƐƵƌĞ ϲϴ͘ϵϯƉƐŝ͘WĞƌĨƚŚĞ;>ϵϳŵϱ͕ϭϴϵΖdKϱ͕ϭϵϮΖͿŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞϱŵŝŶƵƚĞƐƉƌĞƐƐƵƌĞϲϴ͘ϵϯƉƐŝ͘WŽŽŚŚŽůĞǁŝƚŚƚŽŽůƐ͘ >ĂǇŽƵƚŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚŚĂĚƚƌĂĐĞŽĨƐĂŶĚŽŶŐƵŶƐ͘ZŝŐĚŽǁŶůŝŶĞĨŽƌƚŚĞŶŝŐŚƚ͘ ƌƌŝǀĞĂƚůŽĐĂƚŝŽŶĨŝůůŽƵƚĂŶĚƐŝŐŶƉĞƌŵŝƚƐŚĞůĚW:^D͘^ƚĂƌƚƵƉĞƋƵŝƉŵĞŶƚ͕ŵĂŬĞƵƉƉĞƌĨŐƵŶƌƵŶηϯϭͲϯͬϴǆϭΖĐĂďůĞŚĞĂĚ͕ ϮͲϯͬϰǆϳΖŐĂŵŵĂƌĂǇ͕ϮͲϯͬϰǆϮΖƐŚŽĐŬƐƵď͕ϮͲϳͬϴ'K,^Wϲ^W&yϮϴ͘ϱ&d'hEĂƐƐĞŵďůǇ͕ϯϴ͘ϱƚŽŽůƐƚŝŶŐ͘WŝĐŬƵƉ ŐƵŶƐΘƐƚĂďŽŶůƵďƌŝĐĂƚŽƌƚĞƐƚŝŶŐƐĂŵĞƚŽϮϱϬƉƐŝĂŶĚϮϱϬϬƉƐŝŚŝ͘Z/,ŐŽƚƚŽϭϴϳϬ&d͘ǁŽƌŬŝŶŐƚŽŽůƐ͕ŵĂĚĞŝƚƚŽϭϵϮϮĨƚ͘ ^ŚƵƚǁĞůůŝŶ͕ƉŽŽŚ͕ĚƌŽƉϱŵŽƌĞƐŽĂƉƐƚŝĐŬƐĂŶĚƵŶůŽĂĚǁĞůů͘Z/,ŵĂĚĞŝƚĚŽǁŶƚŽϮϱϯϬĨƚĂƚƚĞŵƉƚĞĚƚŽǁŽƌŬĚŽǁŶ ŚŽůĞŬĞĞƉůŽƐŝŶŐŚŽůĞ͕ƚƌŝĞĚĨůŽǁŝŶŐƚŚĞǁĞůů͕ŵĂĚĞŶŽĚŝĨĨĞƌĞŶĐĞ͕ƉƵůůĞĚƵƉƚŽϭϰϬϬĨƚ͘^ŚƵƚǁĞůůŝŶ͕ƉƵŵƉĞĚϰϮŐĂůůŽŶƐ ŽĨŵĞƚŚĂŶŽů͕ĂƚƚĞŵƉƚƚŽZ/,ŵĂĚĞĚŽǁŶƚŽϭϵϴϱ͘WŽŽŚƉƵŵƉƚǁŽďďůƐŽĨĚŝĞƐĞů͕ǁŝƚŚƚƌŝƉůĞǆ͕ĂƚƚĞŵƉƚƚŽZ/,ŐŽƚƚŽ ϭϵϴϲĨƚ͘WŽŽŚƚŽƐƵƌĨĂĐĞĚƌŽƉϱŵŽƌĞƐŽĂƉƐƚŝĐŬƐ͘KƉĞŶǁĞůůĂŶĚůĞƚĨůŽǁ͘hŶůŽĂĚǁĞůů͘Z/,ŵĂĚĞŝƚĚŽǁŶƚŽϭϵϮϮΖ ƵŶĂďůĞƚŽŵĂŬĞĂŶǇŚŽůĞ͘WKK,ǁŝƚŚƚŽŽůƐƚƌŝŶŐ͘KK,ƌŝŐĚŽǁŶͲůŝŶĞĂŶĚŵĂŬĞƌĞĂĚǇƚŽŵŽďƚŽ<ĞŶĂŝ'ĂƐ&ŝĞůĚ͘ ϬϮͬϭϭͬϮϬϮϮͲ&ƌŝĚĂǇ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ƵƐĂŶŝŽŶŶĞϲ ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ ϮϬϴͲϭϲϬ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ > ϮͬϭϭͬϮϮ ϯͬϭϳͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ƵƐĂŶŝŽŶŶĞϲ ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ ϮϬϴͲϭϲϬ ϬϯͬϭϲͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ƌƌŝǀĞĂƚůŽĐĂƚŝŽŶĨŝůůŽƵƚĂŶĚƐŝŐŶƉĞƌŵŝƚƐ͘,ĞůĚW:^DǁͬzĞůůŽǁ:ĂĐŬĞƚ͘ZŝŐͲƵƉĞƋƵŝƉŵĞŶƚ͘DĂŬĞƵƉƉĞƌĨŐƵŶηϭ͘;ϭϰΖ ŝŶƚĞƌǀĂůǆϮͲϳͬϴΗǁͬƌǌƌĐŚĂƌŐĞƐͿ͘^ƚĂďŽŶĂŶĚWdƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚƚŽϭϱϬϬƉƐŝ͘Z/,ǁͬϮͲϳͬϴΗǆϭϰΖƉĞƌĨŐƵŶǁͬƌǌƌ ĐŚĂƌŐĞƐ;ϲƐƉĨϲϬĚĞŐƉŚĂƐŝŶŐͿ͘EŽŝƐƐƵĞƐŵĂŬŝŶŐŝƚĚŽǁŶŚŽůĞ͘Z/,ƚŽϱϯϬϬΖĂŶĚƉƵůůĐŽƌƌĞůĂƚŝŽŶƉĂƐƐ͘^ĞŶĚƚŽƚŽǁŶĂŶĚ ǁĂŝƚĨŽƌĂƉƉƌŽǀĂů͘ƉƉƌŽǀĞĚďǇƚŽǁŶƚŽƐŚŝĨƚůŽŐнϭΖĂŶĚƐŚŽŽƚ͘^ŚŝĨƚĞĚůŽŐĂŶĚƉƵůůŝŶƚŽƐƚŽƉĚĞƉƚŚŽĨϱϮϬϳ͘ϱΖĂŶĚ ƉĞƌĨŽƌĂƚĞĚϭϰΖŝŶƚĞƌǀĂůΛϱϮϮϬΖͲϱϮϯϰΖ;>ͺϵϴƵƐĂŶĚͿ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƐŚŽŽƚŝŶŐ͘ϱϬϬƉƐŝƉƌŝŽƌƚŽƉĞƌĨŝŶŐĂŶĚƐƚŝůů ϱϬϬƉƐŝĂĨƚĞƌƐŚŽƚ͘WKK,͖KK,͘ůĞĞĚŽĨĨĂŶĚĐŽŶĨŝƌŵĞĚŐƵŶĨŝƌĞĚ͘>ĂǇĚŽǁŶŐƵŶ͘'ƵŶĚƌǇŶŽǀŝƐŝďůĞĨůƵŝĚŽŶƚŚĞŵ͘ZŝŐ ƵƉŐƵŶηϮ͖Z/,ǁͬŐƵŶηϮ;ϮͲϳͬϴΗǆϭϲΖͬϲƐƉĨͲϲϬĚĞŐƉŚĂƐŝŶŐͲZZĐŚƌŐƐͿDŽƌĞŝƐƐƵĞƐƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞŽŶƚŚŝƐƉĂƐƐ͘ ŽƌƌĞůĂƚŝŽŶƉĂƐƐηϮƐĞŶƚƚŽƚŽǁŶ͘dŽǁŶĂƉƉƌŽǀĞƐĐŽƌƌĞůĂƚŝŽŶƉĂƐƐŽŶĚĞƉƚŚ͘WƵůůŝŶƚŽƉŽƐŝƚŝŽŶ͘>ƐƚŽƉĚĞƉƚŚΛ ϱϭϬϱΖ͘WĞƌĨŽƌĂƚĞĚϭϲΖ͕ŐƵŶηϮ͕/ŶƚĞƌǀĂůΛϱϭϭϲΖͲϱϭϯϮΖ;>ͺϵϱ>ƐĂŶĚͿ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƉĞƌĨ͘WKK,ϱϬϬƉƐŝƉƌŝŽƌƚŽ ƐŚŽŽƚŝŶŐĂŶĚƐƚŝůůĂƚϱϬϬƉƐŝǁŚĞŶŽƵƚŽĨƚŚĞŚŽůĞ͘KK,͕ďůĞĞĚŽĨĨĂŶĚůĂǇĚŽǁŶŐƵŶηϮ͘ůůƉĞƌĨƐƐŚŽƚ͘'ƵŶĚƌǇ͕ŶŽ ǀŝƐŝďůĞĨůƵŝĚ͕DĂŬĞƵƉŐƵŶηϯ͖Z/,ǁͬŐƵŶηϯ;ϮͲϳͬϴΗǆϭϮΖͬϲƐƉĨͲϲϬĚĞŐƉŚĂƐŝŶŐͲZZĐŚƌŐͿdŽŽůƐŚĂǀŝŶŐŵŽƌĞŝƐƐƵĞƐ ƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞďƵƚĂďůĞƚŽŵĂŬĞŝƚĚŽǁŶ͘ŽƌƌĞůĂƚŝŽŶƉĂƐƐηϯƐĞŶƚƚŽƚŽǁŶ͘dŽǁŶĂŐƌĞĞĚŽŶƚŝĞŝŶƉĂƐƐ͘WƵůůŝŶƚŽ ƉŽƐŝƚŝŽŶ͘>ƐƚŽƉĚĞƉƚŚϱϬϱϬ͘ϱΖ͕WĞƌĨŽƌĂƚĞĚŝŶƚĞƌǀĂůηϯΛϱϬϲϱΖͲϱϬϳϳΖ;>ͺϵϰƐĂŶĚͿ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƉĞƌĨ͘WKK,͘ W^/ĐůŝŵďĞĚϭϲƉƐŝĂĨƚĞƌƐŚŽŽƚŝŶŐ͘/ŶŝƚŝĂůƉƐŝϱϬϬηĂŶĚĂĨƚĞƌϭϱŵŝŶηϱϭϲ͘KK,͕ďůĞĞĚŽĨĨĂŶĚůĂǇĚŽǁŶŐƵŶηϯ͘ůůƉĞƌĨƐ ƐŚŽƚ͘'ƵŶĚƌǇ͕ŶŽǀŝƐŝďůĞĨůƵŝĚ͕DĂŬĞƵƉŐƵŶηϰ͖Z/,ǁͬŐƵŶηϰΘϱǁͬƐǁŝƚĐŚ;ͲϳͬϴΗǆϭϮΖΘϱΖŐƵŶƐϲƐƉĨZZĐŚƌŐƐͿ͘WƵůů ĐŽƌƌĞůĂƚŝŽŶƉĂƐƐηϰĂŶĚƐĞŶĚƚŽƚŽǁŶ͘dŽǁŶĂƉƉƌŽǀĞĚ͘WƵůůŝŶƚŽƉŽƐŝƚŝŽŶĂŶĚƉĞƌĨŽƌĂƚĞĚηϰŝŶƚĞƌǀĂůΛϰϵϵϳΖͲϱϬϬϵΖ ;>ͺϵϮͲϲͿ'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌŝŶŐ͘ZƵŶďĂĐŬŝŶĂŶĚƉƵůůĐŽƌƌĞůĂƚŝŽŶƉĂƐƐηϱ͘^ĞŶĚƚŽƚŽǁŶ͘dŽǁŶĂƉƉƌŽǀĞĚ ĐŽƌƌĞůĂƚŝŽŶ͘WĞƌĨŽƌĂƚĞĚηϱŝŶƚĞƌǀĂůϰϴϴϬΖͲϰϴϴϱ;>ͺϵϭ>Ϳ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƉĞƌĨ͘WKK,͘dďŐƉƐŝƌĞŵĂŝŶƐΛϱϭϲƉƐŝ͖ KK,͘ůĞĞĚŽĨĨĂŶĚůĂǇĚŽǁŶŐƵŶƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶĚƌǇ͘>ĂǇĚŽǁŶĞƋƵŝƉŵĞŶƚĂŶĚŝŶƐƚĂůůŶŝŐŚƚĐĂƉƚŽĨůŽǁŽǀĞƌ ŶŝŐŚƚ͘ĞƉĂƌƚůŽĐĂƚŝŽŶ͘WůĂŶƚŽƌĞƚƵƌŶƚŽŵŽƌƌŽǁƚŽĐŽŶƚŝŶƵĞƉĞƌĨŝŶŐ͘ ϬϯͬϭϱͬϮϬϮϮͲdƵĞƐĚĂǇ ƌƌŝǀĞŽŶůŽĐĂƚŝŽŶŵĞĞƚǁͬ:ĂŬĞũƐĂƉĞƌŵŝƚ͘ZŝŐƵƉƐůŝĐŬůŝŶĞƉͬƚůƵď͘dŽϮϬϬϬƉƐŝŐŽŽĚƚĞƐƚ͘ZŝŚǁͬϯ͘ϱΖΖǆϭϭΖĚĚďĂŝůĞƌƚŽ ϱϱϲϱΖŬďƚĂŐǁͬƚŽŽůƉŽŽŚĞŵƉƚǇ͘ZŝŚǁͬϮϳͬϴΖΖǆϮϬΖƐƉĞŶƚĚƵŵŵǇŐƵŶƐϮϱϬĨƉŵƚŽнͬͲϭϵϬϬΖƐůŽǁĚŽǁŶƚŽϭϱϬĨƉŵƚŽ нͬϰϯϬϬΖŶŽŽďƐƚƌƵĐƚŝŽŶ͘ŽŶƚ͘ƚŽϱϱϲϱΖŬďƚĂŐƉŽŽŚǁͬŶŽŝƐƐƵĞƐĚŝƐĐƵƐƐƉůĂŶĨŽƌǁĂƌĚ͘ZŝŐĚŽǁŶƐůŝĐŬůŝŶĞĐůĞĂŶΘƐĞĐƵƌĞ ĂƌĞĂ͘dƵƌŶŝŶƉĞƌŵŝƚŵŽďƚŽƉǁůƐŚŽƉ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ > ϮͬϭϭͬϮϮ ϯͬϭϳͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ƵƐĂŶŝŽŶŶĞϲ ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ ϮϬϴͲϭϲϬ ϬϯͬϭϳͬϮϬϮϮͲdŚƵƌƐĚĂǇ ƌƌŝǀĞĂƚůŽĐĂƚŝŽŶĨŝůůŽƵƚĂŶĚƐŝŐŶƉĞƌŵŝƚƐŚĞůĚW:^DǁͬzĞůůŽǁ:ĂĐŬĞƚ͕ƌŝŐͲƵƉĞƋƵŝƉŵĞŶƚ͘DĂŬĞƵƉƉĞƌĨŐƵŶηϲ͘;ϭϱΖ ŝŶƚĞƌǀĂůǆϮͲϳͬϴΗΗǁͬƌǌƌĐŚĂƌŐĞƐͿ͕Z/,ǁͬϮͲϳͬϴΗΗǆϭϱΖŐƵŶǁͬZZĐŚĂƌŐĞƐ;ϲ^W&ͬϲϬĚĞŐƉŚĂƐŝŶŐ͘WƵůůĐŽƌƌĞůĂƚŝŽŶƉĂƐƐ ĂŶĚƐĞŶĚƚŽƚŽǁŶ͘ƉƉƌŽǀĞĚďǇƚŽǁŶ͘WƵůůŝŶƚŽƉŽƐŝƚŝŽŶĂŶĚƉĞƌĨŝŶƚĞƌǀĂůηϲΛϰϴϰϭΖͲϰϴϲϱΖ;>ͺϵϬƐĂŶĚͿ͘'ŽŽĚ ŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌŝŶŐ͘WKK,͘W^/ΛƐƚĂƌƚсϰϴη͕ǁŚĞŶĨŝƌŝŶŐƚŽŽůƐũƵŵƉĞĚĂŶĚƉƐŝƌŽƐĞƋƵŝĐŬůǇƚŽϮϬϬηͬϱŵŝŶΛϮϬϴηͬ ϭϬŵŝŶΛϮϯϬη͘tĞůůĨůŽǁŝŶŐĂƚϭ͘ϮŵŝůůŐĂƐŶŽǁĂŶĚƌŝƐŝŶŐ͕KK,ĂƚƚĞŵƉƚƚŽďůĞĞĚŽĨĨďƵƚĐƌŽǁŶǀĂůǀĞůĞĂŬŝŶŐďǇƚŽ ďĂĚ͘KWƐŚƵƚŝŶǁĞůů͘ůĞĞĚŽĨĨĂŶĚďƌĞĂŬĚŽǁŶƚŽŽůƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ĞĐŝƐŝŽŶŵĂĚĞƚŽƌŝŐĚŽǁŶ͘ZŝŐĚŽǁŶĞƋƵŝƉŵĞŶƚ ĂŶĚĚĞƉĂƌƚůŽĐĂƚŝŽŶ͘ KƉƚŽƉƵƚǁĞůůďĂĐŬŽŶůŝŶĞ͘ :KKDW>d tĞůů͗^ͲϬϲ tĞůůEĂŵĞ͗^ͲϬϲW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϴͲϭϲϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ĂŬĞ&ůŽƌĂ;ϵϬϳͿϳϳϳͲϴϰϰϮ;KͿ;ϳϮϬͿϵϴϴͲϱϯϳϱ;Ϳ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ DĂǆ͘ǆƉĞĐƚĞĚ,W͗ΕϭϱϭϱƉƐŝΛϯ͕Ϯϯϲ͛dsĂƐĞĚŽŶZd&ĚĂƚĂŝŶWĂǆƚŽŶϭϬ DĂǆ͘WŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞΕϭϭϵϮƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚƚŽƐƵƌĨĂĐĞͿ tĞůů^ƚĂƚƵƐ͗KŶůŝŶĞ'ĂƐWƌŽĚƵĐĞƌĨůŽǁŝŶŐĂƚϲϬϬͲϵϬϬϬŵĐĨĚ͕ϱͲϮϬďǁƉĚ͕&dW͗ϱϮƉƐŝ tĞůů^ƵŵŵĂƌǇ ^ƵƐĂŶŝŽŶŶĞϲŝƐƐŚŽǁŝŶŐŝŶĐƌĞĂƐŝŶŐƐůƵŐĨůŽǁƚŽƵŶůŽĂĚǁĂƚĞƌƌĞůǇŝŶŐŽŶƐŽĂƉĚƌŽƉƐƚŽƵŶůŽĂĚǁĂƚĞƌ͘/ŶĞĨĨŽƌƚ ƚŽƐŵŽŽƚŚŽƵƚƉƌŽĚƵĐƚŝŽŶĂŶĚƌĞĚƵĐĞƐƵƌŐŝŶŐƚŚĞǁĞůů͕ĂĐĂƉŝůůĂƌǇƐŽĂƉƐƚƌŝŶŐǁŝůůďĞƌƵŶƚŽƚŚĞƚŽƉŽĨƚŚĞ ƉĞƌĨŽƌĂƚŝŽŶƐ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ ΎΎϲϴĚĞŐƌĞĞƐĂŝůĂŶŐůĞĨƌŽŵϭϵϬϬ͛ʹϯϴϬϬ͛ ϯͬϭϱͬϮϮ ƌŝĨƚǁŝƚŚϯ͘ϱ͟ƚŽϱϱϲϱ͛ ϯͬϭϳͬϮϮ WĞƌĨŽƌĂƚĞϰϴϰϭͲϱϲ͛ǁϮͲϳͬϴŐƵŶ WƌŽĐĞĚƵƌĞ͗ ϭ͘ZhĂƉ^ƚƌŝŶŐdƌƵĐŬ͘ Ϯ͘^ƚĂďϯͬϴ͟ĐĂƉŝůůĂƌǇůŝŶĞŝŶƚŽǁĞůůŚĞĂĚƉĂĐŬͲŽĨĨĂƐƐĞŵďůǇ͘DĂŬĞƵƉ,ĐŽŵƉŽŶĞŶƚƐ͘/ŶƐƚĂůůƉĂĐŬͲŽĨĨ ĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚĂŐĂŝŶƐƚƐǁĂďǀĂůǀĞϮϱϬƉƐŝůŽǁͬϮ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϯ͘Z/,ǁŝƚŚϯͬϴ͟ĐĂƉŝůůĂƌǇƐƚƌŝŶŐƚŽцϰϴϱϬ͛D͘ 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>ŝŶĞƌ,ĂŶŐĞƌĂŶĚyWWĂĐŬĞƌ ϯ ϱ͕ϲϯϬ͛ ϯ͕ϱϱϵ͛ ŶͬĂ /WǁͬϭϬ͛ĐĞŵĞŶƚ͘dŽсϱϲϯϬ͛D;ϴͬϮϲͬϭϲͿ ϰ ϱ͕ϳϴϬ͛ ϯ͕ϲϴϵ͛ ŶͬĂ /W;ϭϬͬϭϯͬϭϰͿ KWE,K>ͬDEdd/> ϵͲϱͬϴΗ ϭϮͲϭͬϰ͟,ŽůĞ͗ϮϭϳďďůƐϭϮƉƉŐdǇƉĞ/ĐĞŵĞŶƚƉƵŵƉĞĚ͘ϳϭďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘ ϰͲϭͬϮΗ >ŝŶĞƌ ϴͲϭͬϮΗ,ŽůĞ͗ϭϬϱďďůƐϭϮ͘ϱƉƉŐĐůĂƐƐ'ůĞĂĚĂŶĚϭϵϲďďůƐĐůĂƐƐ'ϭϱ͘ϴƉƉŐƚĂŝůƉƵŵƉĞĚ͘EŽůŽƐƐĞƐ͘ ϮϬнďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘ϭϮͬϭϱͬϬϴ>ƐŚŽǁƐdŽĂƚdŽ>͘ /E>/Ed/KEd/> ϲϵĚĞŐƌĞĞƐĂŝůĂŶŐůĞĨƌŽŵϭ͕ϵϳϬΖͲϯ͕ϴϮϱΖD ϭͬϰΗKϬ͘ϬϰϵΗǁĂůů ŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞ ƚŝĞĚŝŶƚŽŵĂŶĚƌĞůĂƚ ϭ͕ϱϬϳΖǁͬĐŚĞĐŬǀĂůǀĞ ĞŵĞŶƚĂƚ ϲϮϱϬ͛dD ŝŶƐŝĚĞϰͲϭͬϮ͟ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SD-06 (PTD 208-160) PERF 3/16/2022 Please include current contact information if different from above. 208-160 T36428 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.29 09:47:44 -08'00' 1Guhl, Meredith D (OGC)From:McLellan, Bryan J (OGC)Sent:Friday, March 11, 2022 2:59 PMTo:Jacob FloraCc:Roby, David S (OGC); Boyer, David L (OGC)Subject:RE: 10-403 Susan Dionne 6 - Sundry_322-047_020722 - Approved (PTD 208-160)Jake, you have approval to add the perfs below. Please submit a “Change of Approved Program” sundry within 3 days and put my name in box 16. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, March 11, 2022 2:04 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: 10‐403 Susan Dionne 6 ‐ Sundry_322‐047_020722 ‐ Approved (PTD 208‐160) Hi Bryan, We would like to add the below perforations up to the Beluga 80, which lie just above what is currently approved, and within the same pool: Susan Dionne 6 Perforation Table – 2.11.22 Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage Expected Bottom Hole Pressure (MD) (MD) (TVD) (TVD) (MD) (psi) 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. 2BEL_80 ±4,662’ ±4,675’ ±2,724’ ±2,735’ 13‘ 1250 (RFT in Paxton 10 ‐ 2020) BEL_81 ±4,688’ ±4,698’ ±2,745’ ±2,754’ 10’ 1150 (RFT in Kalotsa 7 ‐ 2020) BEL_83 ±4,756’ ±4,766’ ±2,801’ ±2,810’ 10’ 1253 (RFT in Kalotsa 7 ‐ 2020) BEL_90 ±4,800’ ±4,806’ ±2,838’ ±2,844’ 6‘ 1284 (calculated via 0.452 psi./ft. gradient) BEL_90Au ±4,809’ ±4,817’ ±2,847’ ±2,853’ 8‘ 1285 (RFT in Kalotsa 7 ‐ 2020) BEL_90AL ±4,822’ ±4,837’ ±2,858’ ±2,871’ 15‘ BEL_90B ±4,841’ ±4,856’ ±2,874’ ±2,887’ 15‘ 1505 (RFT in Paxton 10 ‐ 2020) BEL_91L ±4,880’ ±4,885’ ±2,908’ ±2,913’ 5‘ 1315 (calculated via 0.452 psi./ft. gradient) The original Sundry did not have a table and had the below zones approved: Thanks, Jake 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. 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Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SD-06 (PTD 208-160) Gamma Ray Correlation 2/11/2022 Please include current contact information if different from above. 208-160 T36388 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:32:30 -09'00' 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2SHUDWRU1DPH&XUUHQW:HOO&ODVV3HUPLWWR'ULOO1XPEHU ([SORUDWRU\'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU 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ϮϬнďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ͘ϭϮͬϭϱͬϬϴ>ƐŚŽǁƐdŽĂƚdŽ>͘ /E>/Ed/KEd/> ϲϵĚĞŐƌĞĞƐĂŝůĂŶŐůĞĨƌŽŵϭ͕ϵϳϬΖͲϯ͕ϴϮϱΖD ϭͬϰΗKϬ͘ϬϰϵΗǁĂůů ŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶůŝŶĞ ƚŝĞĚŝŶƚŽŵĂŶĚƌĞůĂƚ ϭ͕ϱϬϳΖǁͬĐŚĞĐŬǀĂůǀĞ ĞŵĞŶƚĂƚ ϲϮϱϬ͛dD ŝŶƐŝĚĞϰͲϭͬϮ͟ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ͗:>>ϭͬϯϭͬϮϮ WZKWK^ ^ƵƐĂŶŝŽŶŶĞϬϲ W/͗ϱϬͲϭϯϯͲϮϬϱϴϮͲϬϬͲϬϬ Wd͗ϮϬϴͲϭϲϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ >ϵϮʹ Ğůϵϵцϰ͕ϵϮϲ͛ цϱ͕ϯϭϯ͛ цϮ͕ϵϰϴ͛ цϯ͕Ϯϴϰ͛ цϯϴϳ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >'Ͳϵϵ> ϱ͕ϯϭϱ͛ ϱ͕ϯϮϬ͛ ϯ͕Ϯϴϲ͛ ϯ͕ϮϵϬ͛ ϱ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϬ ϱ͕ϯϮϯ͛ ϱ͕ϯϯϯ͛ ϯ͕ϮϵϮ͛ ϯ͕ϯϬϭ͛ ϭϬ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱƵ ϱ͕ϯϰϳ͛ ϱ͕ϯϱϲ͛ ϯ͕ϯϭϯ͛ ϯ͕ϯϮϭ͛ ϵ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱŵ ϱ͕ϯϲϳ͛ ϱ͕ϯϳϰ͛ ϯ͕ϯϯϭ͛ ϯ͕ϯϯϲ͛ ϳ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϬϱ> ϱ͕ϯϳϳ͛ ϱ͕ϯϴϯ͛ ϯ͕ϯϯϵ͛ ϯ͕ϯϰϱ͛ ϲ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'ͲϭϭϬŵ ϱ͕ϰϭϯ͛ ϱ͕ϰϭϴ͛ ϯ͕ϯϳϬ͛ ϯ͕ϯϳϱ͛ ϱ͛ ϴͬϮϭͬϮϭ KƉĞŶ >'Ͳϭϭϱ ϱ͕ϰϱϰ͛ ϱ͕ϰϲϯ͛ ϯ͕ϰϬϲ͛ ϯ͕ϰϭϰ͛ ϵ͚ ϴͬϭϲͬϮϭ KƉĞŶ >'ͲϭϮϬ ϱ͕ϱϭϵ͛ ϱ͕ϱϰϵ͛ ϯ͕ϰϲϮ͛ ϯ͕ϰϴϵ͛ ϯϬ͛ ϴͬϯϭͬϭϲ KƉĞŶ >'ͲϭϯϬ ϱ͕ϲϱϵ͛ ϱ͕ϲϲϴ͛ ϯ͕ϱϴϰ͛ ϯ͕ϱϵϮ͛ ϵ͛ ϮͬϮϯͬϭϯ /ƐŽůĂƚĞĚ;ϴͬϮϲͬϭϲͿ >'Ͳϭϯϱ ϱ͕ϳϯϰ͛ ϱ͕ϳϯϳ͛ ϯ͕ϲϰϵ ϯ͕ϲϱϮ͛ ϯ͛ 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Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SD-06 (PTD 208-160) Correlation 08/16/2021 Please include current contact information if different from above. 11/02/2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SD-06 (PTD 208-160) GPT/PERF 08/21/2021 Please include current contact information if different from above. 11/01/2021 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: ____Patch & 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): 6,737'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production Liner 7,500 psi 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: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 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 ryan.rupert @hilcorp.com 4,520'5,630'3,558'~1229 psi 5,630' & 5,780' Baker ZXP ; N/A 1,794' (MD) / 1,488' (TVD) ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 8,430 psi 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 ADL0359242 / ADL0384372 / FEE-CIRI / FEE-PRIVATE 208-160 50-133-20582-00-00 Susan Dionne 6 Ninilchik / Beluga-Tyonek Gas Pool Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L-80 TVD Burst 1,794' MD 5,750 psi 101" 1,580' 101' 2,031' 20" 9-5/8" 101' 2,031' Perforation Depth MD (ft): See Attached Schematic 4-1/2" 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: August 13, 2021 6,735'4,941' 4-1/2" 4,519' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:49 am, Aug 04, 2021 321-386 anageranager Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.03 16:01:52 -08'00' Taylor Wellman (2143) 10-404 DLB 08/04/2021 X BJM 8/5/21 DSR-8/4/21 dts 8/9/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.09 10:13:57 -08'00' RBDMS HEW 8/11/2021 Well: SD-06 Date: 7/30/2021 Well Name:SD-06 API Number:50-133-20582-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:208-160 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Max. Expected BHP:~ 1578 psi @ 3,489’ TVD Based on 0.452 psi/ft to lowest sand (BEL-120) Max. Potential Surface Pressure ~ 1229 psi (Based on 0.1 psi/ft to surface) Well Summary Susan Dionne 6 has fallen in rate over the past few years. The well is now producing ~550 MCFD and 0-2 bwpd. The well has a lot of potential pay in the lower and middle Beluga. Furthermore, there are a lot of lower Beluga sands that have not been seen, or produced, in offset wells. The goal of this project is to perforate additional uphole sands and add production to the well Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Inclination o Max = 69 degrees at 2496’ MD o Sail angle of 69 degrees from 1970 – 3825’ MD o 30-degree inclination through all proposed perfs x Drifts o 5/12/18: SL tagged at 5624’ SLMD with a 3.6” gauge ring o 5/9/18: CT washed sand bridge from 2500-2550. Broke through and ran down to 5400’ CTMD (no tag) o 8/31/16: EL made it down to 5549’ with a 20’ x 2-7/8” perf gun (no tag, no issues) o 8/26/16: CIBP set at 5640’ MD. 10’ cement dump bailed on top. (ToC at 5630’ MD) o 6/4/16: V-string removed from well Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect, and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority Well: SD-06 Date: 7/30/2021 Non-Sundried Activity 1. MIRU SL 2. D&T well. Note if a FL is encountered 3. Drift to 5475’ MD mimic a 30’ casing patch (3.60” OD) 4. RDMO E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,000 psi High. 3. Consult with OE to determine if Nitrogen is needed to pressure up wellbore 4. RU Nitrogen Truck 5. Pressure up wellbore per OE 6. Rig up perf gun (Likely 2-7/8” 4-6 spf) 7. RIH and perforate the sand listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) BEL_98u ±5,220’±5,235’±3,203’±3,216’15‘ BEL_98L ±5,245’±5,250’±3,225’±3,229’5’ BEL_99u ±5,258’±5,262’±3,236’±3,240’4’ BEL_99L ±5,267’±5,271’±3,244’±3,247’4’ BEL_99A ±5,285’±5,293’±3,259’±3,266’8’ BEL_99Bu ±5,300’±5,313’±3,273’±3,284’13’ BEL_99BL ±5,315’±5,320’±3,286’±3,290’5’ BEL_100 ±5,323’±5,333’±3,292’±3,301’10’ BEL_105u ±5,347’±5,356’±3,313’±3,321’9’ BEL_105m ±5,367’±5,374’±3,331’±3,336’7’ BEL_105L ±5,377’±5,383’±3,339’±3,345’6’ BEL_108 ±5,392’±5,395’±3,352’±3,355’3’ BEL_110u ±5,404’±5,407’±3,363’±3,366’3’ BEL_110m ±5,413’±5,418’±3,370’±3,375’5’ BEL_110L ±5,435’±5,439’±3,389’±3,393’4’ BEL_115 ±5,454’±5,463’±3,406’±3,414’9‘ Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer, and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Matt Petrowsky (Geo): 814-421-6753 ii. Anthony McConkey (RE): 529-6199 8. RD E-Line Unit and turn well over to production. Well: SD-06 Date: 7/30/2021 Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,000 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations _____________________________________________________________________________________ Updated by CRR 7-29-21 SCHEMATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BLG-120 5,519’5,549’3,462’3,489’30’8/31/16 Open BLG-130 5,659’5,668’3,584’3,592’9’2/23/13 Isolated (8/26/16) BLG-135 5,734’5,737’3,649 3,652’3’2/23/13 Isolated (8/26/16) BLG-135 5,740’5,744’3,654’3,658’4’2/23/13 Isolated (8/26/16) BLG-135 5,747’5,751’3,660’3,664’4’2/23/13 Isolated (8/26/16) BLG-135 5,756’5,768’3,668 3,678’12’2/23/13 Isolated (8/26/16) BLG-135 5,791'5,809'3,698'3,714'18'12/21/08 Isolated (10/13/14) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ No Depth ID Item 1 1,507’3.858 Baker Chemical Injection Mandrel 2 1,794'3.958 Liner Hanger and ZXP Packer 3 5,630’n/a CIBP w/ 10’ cement (8/26/16) 4 5,780’n/a CIBP (10/13/14) OPEN HOLE / CEMENT DETAIL 9-5/8"12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD 1/4" OD 0.049" wall Chemical injection line tied into mandrel at 1,507' w/ check valve Cement at 6250’CTMD inside 4-1/2” _____________________________________________________________________________________ Updated by CRR 7-29-21 PROPOSED SCHEM ATIC Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 02-28-1992 Oil Well ->Water injector -> Gas producer for Platform Susan Dionne 06 API: 50-133-20582-00-00 PTD: 208-160 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Adperfs per Sundry BLG-120 5,519’5,549’3,462’3,489’30’8/31/16 Open BLG-130 5,659’5,668’3,584’3,592’9’2/23/13 Isolated (8/26/16) BLG-135 5,734’5,737’3,649 3,652’3’2/23/13 Isolated (8/26/16) BLG-135 5,740’5,744’3,654’3,658’4’2/23/13 Isolated (8/26/16) BLG-135 5,747’5,751’3,660’3,664’4’2/23/13 Isolated (8/26/16) BLG-135 5,756’5,768’3,668 3,678’12’2/23/13 Isolated (8/26/16) BLG-135 5,791'5,809'3,698'3,714'18'12/21/08 Isolated (10/13/14) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 129.5 / X-56 / PE Surf 101' 9-5/8"Surface 40 / N-80 / BTC 8.835 Surf 2,031' 4-1/2"Liner 12.6 / L-80 / Hydril 563 3.958 1,794’6,735’ TUBING DETAIL 4-1/2"Tie-Back Tubing 12.6 /L-80 / Hydril 563 3.958 Surf 1,794’ No Depth ID Item 1 1,507’3.858 Baker Chemical Injection Mandrel 2 1,794'3.958 Liner Hanger and ZXP Packer 3 5,630’n/a CIBP w/ 10’ cement. ToC = 5630’ MD (8/26/16) 4 5,780’n/a CIBP (10/13/14) OPEN HOLE / CEMENT DETAIL 9-5/8"12-1/4” Hole: 217bbls 12ppg Type I cement pumped. 71bbls back to surface. 4-1/2" Liner 8-1/2" Hole: 105bbls 12.5ppg class G lead and 196bbls class G 15.8ppg tail pumped. No losses. 20+bbls back to surface. 12/15/08 CBL shows ToC at ToL. INCLINATION DETAIL 69 degree sail angle from 1,970' - 3,825' MD 1/4" OD 0.049" wall Chemical injection line tied into mandrel at 1,507' w/ check valve Cement at 6250’CTMD inside 4-1/2” 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. STATE OF ALASKA a"%7 . ilkKA OIL AND GAS CONSERVATION COOSSION REPORT OF SUNDRY WELL OPERATIONS MAY 30 2 ; s 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U c. iylowih U Performed: Suspend 1:1Perforate 9" Other Stimulate ❑ Alter Casing ❑ Chan 4r8hrn ❑ Plug for Redrill ❑ srforate New Pool LI Repair Well ❑ Re-enter Susp Well❑ Other: CTCO-N2 FCO LI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development DExploratory 111208-160 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20582-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0359242/ADL0384372/FEE CIRI/FEE-PRIVATE Ninilchik Unit S Dionne 6 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ninilchik/Beluga-Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 6,737 feet Plugs measured 5,630&5,780 feet true vertical 4,520 feet Junk measured N/A feet Effective Depth measured 5,630 feet Packer measured 1,794 feet true vertical 3,559 feet true vertical 1,488 feet Casing Length Size MD TVD Burst Collapse I Structural Conductor 101' 20" 101' 101' Surface 2,031' 9-5/8" 2,031' 1,580' 5,750 psi 3,090 psi Intermediate Production Liner 4,941' 4-1/2" 6,735' 4,519' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematicc SCANt 'JUN 2 1 t li' True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 1,794'MD 1,488'TVD Packers and SSSV(type,measured and true vertical depth) Baker ZXP Pkr;N/A 1,794'MD 1,488'TVD 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 62 Subsequent to operation: 0 1391 0 5 77 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory Developments Service ❑ Stratigraphic [] Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-168 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramercOi.hilcorp.com. 4 '!. Authorized Signature: 00:&/.. Date: 573 'f Contact Phone: 777-8420 1 Form 10-404 Revised 4/2017 RBDMS MAY 3 12018 ) 6.y''e /,o,, Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Susan Dionne 6 CTU 50-133-20582-00 208-160 5/7/18 5/10/18 Daily Operations: 05/07/2018- Monday Inspect location w/Schlumberger crew and move in water and kcl tanks f/coiled tubing unit prep electrician to disconnect well house for removal.Jim Regg with AOGCC witness is waived for CTB BOP test by e-mail 5/8/2018 @ 9:20 AM for 5/9/18. 05/09/2018-Wednesday R/U coil tubing adapter flange and rolled KCL water in tank. R/U PT 4,000#, ok. RIH w/ BHA#1 w/WFT C.C, XO, DHCV, 2 MBT, and D.Jet. TOT 12.25' coil t/2,500' and tag bridge wash through f/2,500' t/2,550' with no issue. Continue RIH t/5,400' w/ no fill no issue, pump 22 BBL. Vis sweep around clean 3% KCL water. Blow down well w/ nitrogen and POOH. RID SBL, shut well in w/ 1,000psi on well. RID SLB and hook up bleed tank for production. 05/10/2018-Thursday PJSM w/ production crew. Discussed well performance and standby for flow and loaded out coil tubing. Equipment pumped out fluids in R.R tanks and haul rental equipment off pad. . . . • H H . • Ninilchik Field SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 Hilcorp Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 129.5/X-56/PE Surf 101' I}' "' 9-5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' 4 1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' it u„ TUBING DETAIL 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 20" ,. t. ) i"' JEWELRY DETAIL 0 ; No Depth Length ID Item -` 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel i 2 1,794' 35' 3.958 Liner Hanger and ZXP Packer 1/4"OD 0.049"wall 3 5,630' 11' CIBP w/10'cement e.k', Chemical injection line 4 5,780 1' CIBP k- tied into mandrel at #; 1,507'w/check valve , 1'1 -I` t= �- PERFORATION DETAIL I2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status c i ,,, BLG-100 5,519' 5,549' 3,462' 3,489' 31' 8/31/16 Open 111 i1 9_50 . BLG-130 5,659' 5,668' 3,584' 3,592' 9' 2/23/13 Isolated BLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Isolated 4-1/2"Hvdril 563 Short BLG-135 5,740' 5,744' 3,654' 3,658' 4' 2/23/13 Isolated Joint Locations: 3,664' 3,038.1'-3,057.9'MD BLG-135 5,747' 5,751' 3,660' 4' 2/23/13 Isolated 3,626.8'-3,646.6'MD BLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Isolated BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Isolated SL tagged fill @ 5,624' 05/12/18 ,.�' BLG100 OPEN HOLE/CEMENT DETAIL Ow' 9 5/8„ 12-1/4" hole, Cmt w/490 sks(217 bbls)12 ppg, BLG130 Type 1 cmt with 160 sks(71 bbls)to surface. 4-1/2" Seal Assembly stung into SBE @ 1,840 MD. BLG135 TB (4.75"OD Bullet Seal Assembly) - ►.: '" 4 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed t. BLG-135 4-1/2" w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) Liner NOTE: DID NOT Bump Plug,stopped cement displacement 8 bbls short of total displacement. • Tagged at 6,238'with 3.5"GR on 10/04/14 '• INCLINATION DETAIL KOP @ 244'MD/TVD 4-1/2" f i _''.+'I,W. Build"'3.35 deg/100'from 244'-1,970'MD Hold 68.75 deg from 1,970'-3,825'MD TD=6,737 PBTD=5,630' Drop-3.45 deg/100'to 4,970'MD MAX HOLE ANGLE=68.75°@ 1,970' Hold 29.75 deg from 4,970'to TD at 6,737'MD Azimuth:251.5 deg. Updated by DMA 04-16-18 • 41) Martin, Teddy J (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, May 30, 2018 4:09 PM To: Martin, Teddy J (DOA) Subject: Re: PTD 208-160 Report of Sundry Well Operations Mr Martin, The SD#6 filled up with solids(sand) and died. I III By cleaning out the fill with the nitrogen and coil cleanout,we were able to re-establish a 1.5 MMSCFD rate. Hilcorp has decided to delay adding anymore perforations until the rate declines. There is a risk of hitting water when one adds perforations in these very fresh intervals. Too much water may kill what we already have. I hope this helps, Ted Kramer Sent from my iPhone On May 30,2018,at 3:51 PM, Martin,Teddy J (DOA)<teddy.martin@alaska.gov<mailto:teddy.martin@alaska.gov>> wrote: Good afternoon Ted, We received your report of sundry well operations for PTD 208-160/Ninilchik Unit S Dionne 6 showing that you guys perforated and performed a nitrogen blowdown. Based on the well schematic diagram and operations summary submitted I am not showing any new perforations done.Am I missing something by chance?Or were these perforatio is going to be submitted in a separate report? Teddy Martin Statistical Technician II Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Suite 100 Anchorage,AK 99501 (907) 793-1241 teddy.martin@alaska.gov<mailto:teddy.martin@alaska.gov> 1 P� OF T � • (0)"\ �j, 0 THE STATE Alaska Oil and Gas 4.41 f e Conservation Commission 1 � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFALAS� ain: 907.279.1433 � MFax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANS Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga-Tyonek Gas Pool,Ninilchik Unit S Dionne 6 Permit to Drill Number: 208-160 Sundry Number: 318-168 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tA23 Hollis S. French Chair DATED this 16 day of April, 2018. 00 OPMs , - V • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR1 6 2013 Q' v rs. ¢ 8 i 11 APPLICATION FOR SUNDRY APPROVALS AOGCU 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well D Operations shutdown 0 Suspend 0 Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: CTCO-N2 Q' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cc. Hilcorp Alaska, LLC Exploratory 0 Development ❑✓ . 208-160 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20582-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701C Ninilchik Unit S Dionne 6 ' ❑ Will planned perforations require a spacing exception? Yes 0 No 0 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0359242/ADL0384372/FEE-CIRI/FEE-PRIVATE Ninilchik/Beluga-Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,737, 4,520' . 5,630' 3,559' 1,213psi 5,630'&5,780' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101" Surface 2,031' 9-5/8" 2,031' 1,580' 5,750 psi 3,090 psi Intermediate Production Liner 4,941' 4-1/2" 6,735' 4,519' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 1,794' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer-Baker ZXP and SSSV-N/A Baker ZXP 1,794'(MD)1,488'(TVD)and SSSV-N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Q• Service 0 14.Estimated Date for 15.Well Status after proposed work: April 23,2018 Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑✓ ' WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcora.com Contact Phone: 777-8420 Authorized Signature: t `j� /�' Date: Ll/I G/I if COMMISSION USE ONLY Conditions of approval: Notify Commission fV� so that a representative may witness Sundry Number: A 1, litz Plug Integrity ❑ BOP Test [ Mechanical Integrity Test 0 Location Clearance 0 Other: ''" t' �I/C.c ' , ` 1 G'`p ;;;I- Cc.-i-hl. ) Post Initial Injection MIT Req'd? Yes ElNo 0 • ,PR L �� Spacing Exception Required? Yes ❑ No Subsequent Form Required: I C; -(l(?,Li RBDM ( t -- N l APPROVED BY Approved by: 'WI�e� / COMMISSIONER THE COMMISSION Date: Li 40 e) (0e) l/19 ye ,� f4%8' ‘mit Formm and i°:f4 I (/= Form 10-403 Revised 4/2017 Approved ap is t �V f�r om the date of approval. Attachments in Duplicate ' t • Well Prognosis Well: SD-6 Hllcoru Alaska,LU Date:04/16/2018 Well Name: SD-6 API Number: 50-133-20582-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 04/23/18 Rig: CTU Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 208-160 First Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: 700 psi SI for Bailing Work Flowing BHP: — 395 psi @ 3,643' TVD (Flowing survey on 4/16/16) Maximum Expected BHP: — 1,581 psi @ 3,678' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 1,213 psi (Assumed 0.10 psi/ft gas gradient) Brief Well Summary Susan Dionne#6 was drilled and completed as a gas well in 2008. During the initial perforating of the well,the gun got stuck and was fished with slickline. Subsequently the well flowed gas at significant rates and the entire interval was not perforated. In 2013 the well was perforated in the Beluga 135,which increased both the gas and water rates.A plug was set in the lower perforations in 2014 in an attempt to isolate the water with marginal results. In 2016,the Beluga (BLG) 135 and 130 sands were isolated with a CIBP and the Beluga 130 sand was perforated. This interval flowed gas until recently when a compressor shut down for maintenance caused the well to be shut in. When the well was brought back on line,the well sanded up and quit producing. • The purpose of this Sundry is to clean out the well with coil,jet the well dry with Nitrogen and bring the well on line. If water production is an issue, or if the BLG 100 refuses to flow,then additional Beluga perfs will be " added in the 83 to 90 sands in order to help lift the well. A plug between the BLG-100 may be set in order to establish flow rate from the upper interval. Notes Regarding Wellbore Condition • Top of fill at 2,450' recovering thick mud with 700 psig surface pressure on 4/10/18. • Well is deviated to 68 degrees by 1,924'and drops back to 29 degrees at 4,840'. Safety Concerns v/ • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Nitrogen will be used during this job. • Consider tank placement based on wind direction and current weather forecast(if venting methane and nitrogen during this job) • Ensure all crews are aware of stop job authority Coiled Tubing Procedure: 1. Submit 24 hr.witness notification to AOGCC via web base notification. 2. MIRU Coiled Tubing, PT BOPE to 4,000 psi high/250 psi low. 3. RIH W/Coil jetting with 3% KCL water and jetting fill/fluid back to a tank down to 5,600'. • 4. Switch to Nitrogen and blow well dry leaving 1,000 psi on the tubing. • • Well Prognosis Well: SD-6 FIilcoru Alaska,LL' Date:04/16/2018 5. RDMO Coil Tubing. Turn well over to production to flow. 6. Gradually bleed down nitrogen from tubing pressure while checking for Methane with an LEL meter. Once methane is established,turn well into compression suction and establish a stable rate. If stable rate is not established,go to step 7.Otherwise job is complete. 7. RU Slickline and tag for fill. If fill is above 5,500', consult with the Operations Engineer. Rig down Slickline. 8. Clean out fill either by Slickline or coil depending on the amount down to at least 5,410'. E-Line Procedure: 9. MIRU E-line. Pressure test Lubricator to 3,000 psi. Note:Steps 10 through 15 will be done if the well makes sand or a large amount of water. Therefore these steps may be moved (or repeated)during or after Step 16. 10. RIG Up Nitrogen, RIH with GPT Tool on E-line and Pressure up with N2 to push water away. Confirm water is below 5,470'W/GPT tool. POOH. �5 V 11. PU, RIH W/ Plug to 5470' (+/-) and set same. AL1--1.1)✓ 12. MU dump bailer and fill w/cement. 13. RIH and dump cement on top of CIBP (10' = 6 gallons). POOH w/dump bailer. 14. Wait 24 hours for cement to set. 15. Bleed pressure down as requested by the OE to establish desired drawdown on the formation. 16. PU, RIH with 2-7/8" 6 SPF 60 deg phased perf guns (up to 12 SPF with 2 perf runs). Perforate the following intervals: (Note: well surface pressure may need to be adjusted to achieve desired underbalance.)• Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt F 5'/le Beluga 83 ±4,757' ±4,766' ±2,802 ±2,810 9 Beluga 90 ±4,800' ±4,815' ±2,839' ±2,852' 15 Beluga 90 ±4,825' ±4,831' ±2,860' ±2,865' 6 Beluga 90 ±4,841' ±4,855' ±2,874' ±2,886' 14 a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,480' in the Paxton #5 well and 9,600' in the Paxton#1 well. Contingency: If the fill returns after step#7 a plug will be needed above the existing perforations. The following procedure will be used in that case: Coiled Tubing Procedure: 1. Submit 24 hr.witness notification to AOGCC via web base notification. 2. MIRU Coiled Tubing, PT BOPE to 250psi low/3,000 psi. 3. Clean out well down to 5,500'. Hold pressure on well to prevent fill re-entry. • • Well Prognosis Well: SD-6 Hilcorp Alaska,LL1 Date:04/16/2018 4. PU CIBP and RIH to top of fill. PU to 5,470' and set CIBP. 5. Jet well dry and leave 1,400 psi of N2 on the well for perforating. 6. POOH with coiled tubing. NDMO CTU. 7. Flow well to see if production is restored. 8. Rig Up E-line, pressure test Lubricator to 3,000 psi.,and Go to step# 12. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram 4. CT BOPE Schematic 5. CT Schematic(forward jetting) 6. Standard Well Procedure—Nitrogen Operations H . •Ninilchik Field SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 llilcorp Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm •'1 20" Conductor 129.5/X-56/PE Surf 101' 9-5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' 4-1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' TUBING DETAIL 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 2d' JEWELRY DETAIL `,d No Depth Length ID Item to kt 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel 2 1,794' 35' 3.958 Liner Hanger and ZXP Packer ir ' rl 1/4"OD 0.049"wall 3 5,630' 11' CIBP w/10'cement Chemical injection line 4 5,780' 1' CIBP tied into mandrel at I 1,507'w/check valve ,t 1 Ot 2 PERFORATION DETAIL *ItZone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status I 1:f, BLG-100 5,519' 5,549' 3,462' 3,489' 31' 8/31/16 Open 9-5/s '` * »+" Tagged fill w/Bailer @ BLG-130 5,659' 5,668' 3,584' 3,592' 9' 2/23/13 Isolated A ,tw'Jo z,aso'D4/10/18 BLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Isolated ;' A 4-1/2"Hvdril 563 Short BLG-135 5,740' 5,744' 3,654' 3,658' 4' 2/23/13 Isolated ' Joint Locations: 23 BLG-135 5,747' 5,751' 3,660' 3,664' 4' 2 13 Isolated *, : .-,`' 3,038.1'-3,057.9'MD / / 3,626.8'-3,646.6'MD BLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Isolated ° BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Isolated 1" *1 k BLG-100 OPEN HOLE/CEMENT DETAIL - 39-5/8" 12-1/4" hole, Cmt w/490 sks(217 bbls)12 ppg, BLG130 Type 1 cmt with 160 sks(71 bbls)to surface. ,1.,..* 4-1/2" Seal Assembly stung into SBE @ 1,840 MD. 4: BLG-135 TB (4.75"OD Bullet Seal Assembly) I 4. f,t 4 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed r ' BLG-135 4-1/2" w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) "'. -r- .'`.', 0" Liner NOTE: DID NOT BumpPlug,stopped cement displacement 8 bbls short of total displacement. Tagged at 6,238'with ` * 3.5"GR on 10/04/14 If 4-,/ (; , INCLINATION DETAIL KOP @ 244'MD/TVD 4-1/2 `-'1,4`...:1Build"'3.35 deg/100'from 244'-1,970'MD Hold 68.75 deg from 1,970'-3,825'MD TD=6,737' PBTD=5,630' Drop-3.45 deg/100'to 4,970'MD MAX HOLE ANGLE=68.75°@1,970' Hold 29.75 deg from 4,970'to TD at 6,737'MD Azimuth:251.5 deg. Updated by DMA 04-16-18 • Ninilchik Field ini0 PROPOSED SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 Hilcorp Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm r l 20" Conductor 129.5/X-56/PE Surf 101' y' aA 9-5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' 4-1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' ., `, TUBING DETAIL 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 2O yy I'•' JEWELRY DETAIL 4 No Depth Length ID Item 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel 2 1,794' 35' 3.958 Liner Hanger and ZXP Packer r`; 1/a"OD 0.049"wall 2A ±5,470' CIBP w/10'cement(if necessary) Chemical injection line 3 5,630' 11' CIBP w/10'cement tied into mandrel at 4 5,780' 1' CIBP x 1,507'w/check valve '11 "' PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status E I tBLG-83 ±4,757' ±4,766' ±2,802 ±2,810 ±9' Proposed TBD r i 5 c i ' ±4,800' ±4,815' ±2,839' ±2,852' ±15' Proposed TBD a-1/2"Hvdril 563 Short BLG-90 ±4,825' ±4,831' ±2,860' ±2,865' ±6' Proposed TBD • Joint Locations: ±4,841' ±4,855' ±2,874' ±2,886' ±4' Proposed TBD " , 3,038.1'-3,057.9'MD 3,626.8'-3,646.6'MD BLG-100 5,519' 5,549' 3,462' 3,489' 31' 8/31/16 Isolated BLG-83• BLG-130 5,659' 5,668' 3,584' 3,592' 9' 2/23/13 Isolated IBLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Isolated BLG90 r 3,658' �" BLG-135 5,740' 5,744' 3,654' 4' 2/23/13 Isolated 2A l�"5 BLG-135 5,747' 5,751' 3,660' 3,664' 4' 2/23/13 Isolated BLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Isolated �BLG-100 a 3 BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Isolated -=BLG-130 BLG135 OPEN HOLE/CEMENT DETAIL 4 12-1/4" hole, Cmt w/490 sks(217 bbls)12 Via' BLG135 9-5/8" ppg, Type 1 cmt with 160 sks(71 bbls)to surface. 4-1/2" Seal Assembly stung into SBE @ 1,840 MD. ' TB (4.75"OD Bullet Seal Assembly) 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed / w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) Tagged at 6,238'with 4-1/2" 3.5"GR on 10/04/14 Liner NOTE: DID NOT Bump Plug,stopped cement displacement 8 bbls short of total displacement. .k ,". 1-1 INCLINATION DETAIL KOP @ 244'MD/TVD Build^'3.35 deg/100'from 244'-1,970'MD Hold 68.75 deg from 1,970'-3,825'MD TD ,737' PBTD=5,630' Drop-3.45 deg/100'to 4,970'MD MAX HOLE ANGLE=68.75°@ 1,970' Hold 29.75 deg from 4,970'to TD at 6,737'MD Azimuth:251.5 deg. Updated by DMA 04-16-18 • • Ninilchik Unit SD #6 05/09/2016 INikorp U,.{,:1.1.11: Ninilchik Unit Tubing hanger,MB-235,11 X Susan Dionne#6 4.909 MCA lift X4'A IBT susp, 20 X 9 5/8 X 41/2 w/4"Type H BPV profile 2- A continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 5M FE X 6'A Otis Quick Union �44O' <c%0'- Valve,Swab, a��e gh• �� `�e�%< VGM,41/16SMFE,HWO, IIJ 6,�O�c Ja n, o� DD trim •� 600 OOO��P r J JCS oc ems TNIII!/ 4 Tee,stdd,4 1/16 5M X ii t 0 3 1/8 5M ‘3711 .4 gir Valve,upper master, II 411 VG-M,4 1/16 5M FE,HWO, DD trim DSA,41/16 10M X 4 1/8 SM Y < ren. To Valve,master,CIW-FC, 1�J 4 1/16 10M FE,HWO,DD ,C 6Lr1 trim Adapter,Vetco,11 5M stdd X 41/16 10M stdd top, prepped f/6.5''extended neck hanger Multibowl,Vetco MB-150, ' ' •16 " 11 3M stdd bottom X �1 I 11 5M FE top,w/ ) �, 11.1 2-2 1/16 5M SSO,1-control { ' I k re' °) - line exit — EP n_;j{ 4 ,11r — 7'hanger and packoff in Starting head, . wellhead for space out only Vetco MB-150, I 11 3M X 9 5/8 VG-Loc , bottom,w/2-2"LPO gr; 20" 9 5/8" • ,. , • [ 8j ...._. cn D e o ! a g ,1 C Hw D Q x Y 7 o9 ,3 z Q m o 8 1 7 : ]]J] O Z • I J E 0 w C + e I LI, Aitt (i) E. 0 o II: A ACDc 1w_I ya cu • N • • Z A A a L 0 U- o V U • A o d O H -:- it -:- '_:_'' I III I I ', i IA p mu al Ili ini —7 — i 0 ■ ■ i,1 �! h ISI il,ll N YJ' iIi ill ki o) • o • =Z s c 0 H a H 1 c v n b • v •A • I 1 D r, O : g 1 1 g 8 h C C 12 D Om C 01 Ai 0 OU N Z O Rg Wtl O 6 w a i • • STANDARD WELL PROCEDURE IliIcorp.1Ia ka.1.iA. NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL v1 Page 1 of 1 • 1110 Davies, Stephen F (DOA) From: Cody Terrell <cterrell@hilcorp.com> Sent: Tuesday,April 17, 2018 2:44 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: S Dionne 6 (PTD#208-160; Sundry 318-168) - Proposed Perfs Steve, The perfs do not lie within 1,500 feet of an uncommitted tract. This perf add does not require a spacing exception according to CO 701C. Regards, Cody T. Terrell Landman Nilcorp Alaska, LLC Direct: 907-777-8432 Cell: 713-870-4532 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent:Tuesday,April 17, 2018 11:52 AM To:Cody Terrell<cterrell@hilcorp.com> Cc:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject:S Dionne 6(PTD#208-160;Sundry 318-168)- Proposed Perfs Cody, I'm reviewing Hilcorp's sundry application to potentially add perfs to the S Dionne 6 well that are roughly 670'to 770' shallower than existing perfs in the well. Are there any uncommitted tracts within the Ninilchik Unit that lie within 1500' of these proposed perfs? (See CO 701C, Rule 36). Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 Zo`6 - 0 Seth Nolan Hilcorp Alaska, LLC 2'� GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 RECEIVED Tele: 907 777-8308 iriie��ri, ai:A.�,:,.>Lfi.t. Fax: 907 777-8510 E-mail: snolan@hilcorp.com NOV 22 2016 n/-��+ DATA LOGGED DATE 11/18/16 K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SD 06s Op APR 2 42017, O Prints Prints: Perforation Record 5" CD : SD-06 PERF_31AUG 16.pdf 10/24/2016 8:47 AM PDF Document 753 KB SD-06_PERF_31AUG16_img.tif 10/24/2016 8:47 AM TIF File 2,249 KB SD-06_PERF_31AUG16 LAS.zip 10/24/2016 8:58 AM Compressed(zippe... 42 KB Thumbs.db 11/18/2016 2:27 PM Data Base File 12 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: , Date: STATE OF ALASKA • • AleKA OIL AND GAS CONSERVATION COMMISSION , REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LI Fracture Stimulate LI Pull Tubing U Operations shutdown LI Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Pull CT V-strino+N2 displacePL 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 208-160 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20582-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0359242/ADL0384372/FEE CIRI/FEE-PRIVATE Ninilchik Unit S Dionne 6 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ninilchik/Beluga-Tyonek Gas Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 6,737 feet Plugs measured 5,630&5,780 feet true vertical 4,520 feet Junk measured N/A feet OCT 0 6 2016 Effective Depth measured 5,630 feet Packer measured 1,794 feet CC true vertical 3,559 feet true vertical 1,488 feet �I4� Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101' Surface 2,031' 9-5/8" 2,031' 1,580' 5,750 psi 3,090 psi Intermediate Production Liner 4,941' 4-1/2" 6,735' 4,519' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic FEBf` a r,r:� True Vertical depth See Attached Schematic SCANNED E'B S 3 Lu t. Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 1,794'MD 1,488'TVD Packers and SSSV(type,measured and true vertical depth) Baker ZXP Pkr;N/A 1,794'MD 1,488'ND 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: 0 215 23 72 47 Subsequent to operation: 0 1416 0 45 801 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development[1] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-268 Contact Taylor Nasse-777-8354 Email tnasse(c�hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature VA"/`� Phone 907-777-8405 Date , tr.f s/r� h -((-Ic- Form 10-404 Revised 5/2015Submit Original Only 7;e41,,4 RBDMS LL—OCT 1 0 2016 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Susan Dionne 6 CTU 50-133-20582-00 208-160 6/3/16 8/31/16 Daily Operations: 06/03/2016- Friday Obtain PTW. Hold safety meeting. Discuss JSA and review job procedure. Review concerns with working on 2.375" CT velocit.strings and associated hazards. MIRU. Lay pit liner. Spot tanks. Rig up iron, choke skid. Auxiliary spooler. Set 180 drum inside spooler with 2.375" CT whip. 24 hr BOPE test witness notification sent to state on 6/3/16 @ 0823 hrs. If inspector is not on locaton at notification start time as indicated witness is waived by Jim Regg. Continue RU. Pressure test choke skid valves. Good test. Pick injector head. Make up dimple connector. Pull test 25K. Stack back for the night. 06/04/2016-Saturday Obtain PTW. Discuss JSA and review job procedures. New crane operator. Discuss stripping lubricator. Remove night cap. Pick injector head. Stab 10' lubricator. Stab on well. Start BOPE test. Test all rams and valves to 250/3,500 psi. Accumulator draw down test. All tests passed. Pop off well, make up BHA as follows: 2.375" OD CC, 2.375" DFCV, 2.375" straight bar, 2" x over 1.5" MT box x 5/8" sucker rod box, 3.5" GS spear with 1/8" steel sheer stock. Total BHA 11.654 '. Stab on well. Pressure test stack 250/3,500 psi. Measured distance from coil zero to hanger 10.5'. Open well. Pump .6 bbls CT V-string pressuring up. Hold 2,500 psi for 5 minutes. Good PT. RIH, latch CT hanger. Pull test to 22K. Slack off. Back off hanger, lock down bolts to 3-7/8". Pull on V-string. Moving and weight break over at 36K. Pick up to-14'. Close pipe rams and slips. Push pull to ensure slips are holding. Manually lock in slip/pipe rams. Bleed off above rams. Drop pack off pressure and chain tension. Slip chains. Collar up and pick up with crane exposing CT pipe. Cut V-string below hanger and break down pulling tools, GS spear and BHA. Dress both ends of CT. Install double dimple connector. Scope back down over pipe. Collar up lubricator to BOPE. Pull test connector to 35K. Hold up weight of 28K. PT stack 250/3,500 psi. Back off manual lock downs. Open pipe and slip rams. Spool CT string OOH. Spool OOH. CT string looks clean. At surface. Tag up, close swab and upper master 23.5 turns. 0 psi on well when SI. Open bleed screw and catch fluid draining from V-string BHA. Cut off V-string BHA. Remove plug and prong to be returned to Pollard. Stab on well and blow CT V-string dry with N2. Rig down SLB CTU. SLB will remove equipment Monday. N2 pump and transport will stay on location to assist in E-line operations in days to follow. 08/25/2016-Thursday SIMOPS,JSA and PTW for PEST and SLB N/2. Rig up lubricator and N-2 Lines. PT lubricator to 250 psi low and 3,000 psi high. RIH with GPT tool, 3.6" GR/junk basket and set down on velocity string spool in tree. Could not get past. Checked and it has a 3.46" ID. Called town and discussed. Called Clint Chanley and he will come out and take spool out of tree. Will be back in am to continue pushing fluid back and setting CIBP (3.5" OD plug). • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Susan Dionne 6 CTU 50-133-20582-00 208-160 6/3/16 8/31/16 Daily Operations: 08/26/2016- Friday SIMOPS, PTW and JSA. PT lubricator 250 psi low and 3,000 psi high. PT tree to 4,000 psi. RIH w/GPT/JB-3.6" GR and tie into Expro CBL log dated 12-14-08 and tagged at 5,665' and fluid level at 4,802'. POOH. Start pumping N/2 at 1,450 psi. Pressure broke over at 2,150 psi and is steady going down. RIH with GPT tool with 1,700 psi on tubing. Found no fluid in well.TP was down to 800 psi. POOH. Pumped 110,090 SCF N/2. RIH with 3-1/2" plug and tie into Expro CBL log. Run correlation log and send to town. Get ok to set plug at 5,640'. Spot plug and set plug with 600 psi on tubing. Lost 50 lbs of line wt. Pick up 30' and go back down and tag plug lightly. POOH. Good set. MU 3" x 20' dump bailer. RIH w/3" x 20' dump bailer full of cement and dump bail 10' of cement on top of plug at 5,640'. EST TOC at 5,630' and cement in place at 1430 hrs. POOH. Good dump. Pressure tubing up to approx 1,000 psi with N/2. Rig down N/2 and Pollard lubricator. WOC. 08/31/2016-Wednesday PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. RIH with GPT tool and tagged TOC at 5,632'. Found no fluid in well. POOH. RIH w/2-7/8" x 20' HC, 6 spf, 60 deg phase perf gun and tied into Expro CBL log. Ran correlation and sent to town.Jacob said log off by 1' so shoot from 5,529' to 5,549'. Bled well down to 815 and spotted shot. Fired gun and psi went to 823 psi and to 845 psi after 5 min. Up in lubricator with 917 psi.All shots fired. Gun was dry. RIH w/2-7/8" x 10' HC, 6 spf, 60 deg phase perf gun and tied into Expro CBL log. Ran correlation and sent to town. Got ok to perf(log off by 1') from 5,519' to 5,529'. Fired gun with 1,143 psi and psi went to 1,146 psi and to 1,147 psi after 5 min. POOH.All shots fired. Gun was dry. Rig down lubricator and turn well over to field. • 11111 Ninilchik Field .# 11 SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 HiIcor')Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm 4 20" Conductor 129.5/X-56/PE Surf 101' 9-5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' rd 1 4-1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' TUBING DETAIL 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 207 � t0 43 JEWELRY DETAIL No Depth Length ID Item 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel ' 2 1,794' 35' 3.958 Liner Hanger and ZXP Packer 3 5,630' 11' 10'cement 1 1/4"OD 0.049"wall CIBP w/ 4y * Chemical injection line 4 5,780' 1' CIBP X y,^ tied into mandrel at ;: 1,507'w/check valve A '_ Cg `YPERFORATION DETAIL 2 t,. it;' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5.4 Y BLG-100 5,519' 5,549' 3,462' 3,489' 31' 8/31/16 Open 9-5/8 °` BLG-130 5,659' 5,668' 3,584' 3,592' 9' 2/23/13 Isolated 1 11 1- .7) :' �" BLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Isolated 4-1/2"Hydril 563 Short BLG-135 5,740' 5,744' 3,654' 3,658' 4' 2/23/13 Isolated r Joint Locations: BLG-135 5,747' 5,751' 3,660' 3,664' 4' 2/23/13 Isolated :4. 3,038.1'-3,057.9'MD ''° , ,' 3,626.8'-3,646.6'MD BLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Isolated BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Isolated 1 . a 1 a• 3 1a, W; 4.1 yIF =., BLG-100 OPEN HOLE/CEMENT DETAIL ' fi 4 u 7,49 3 9-5/8" 12-1/4" hole, Cmt w/490 sks(217 bbls)12 ppg, ‘-' ," Type 1 cmt with 160 sks(71 bbls)to surface. y=1 BLG-130 0 ?4 4-1/2" Seal Assembly stung into SBE @ 1,840 MD. .° BLG-135 TB (4.75"OD Bullet Seal Assembly) 11,.. 'iF 1 mo t 4 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed '+yy,, 4-1/2" w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) 4 BLG-135 )' Liner NOTE: DID NOT Bump Plug,stopped cement displacement 8 bbls short of total displacement. >?. p Tagged at 6,238'with ` 3.5"GR on 10/04/14 r } '' INCLINATION DETAIL �k+ , t v1' KOP @ 244'MD/TVD 4-1/2 ° .' Build 3.35 deg/100'from 244'-1,970'MD Hold 68.75 deg from 1,970'-3,825'MD TD=6,737 PBTD=6,606' Drop-3.45 deg/100'to 4,970'MD MAX HOLE ANGLE=68.75°@ 1,970' Hold 29.75 deg from 4,970'to TD at 6,737'MD Azimuth:251.5 deg. Updated by DMA 10-05-16 • • OF TFJ • w\��y/�SA THE STATE Alaska Oil and Gas of T c Conservation Commission ALAS SfFt__�_ 333 West Seventh Avenue " C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 U *h'' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson SCANNED SEP 2: 8 2U16 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Oil Pool,Ninilchik Unit S Dionne 6 Permit to Drill Number: 208-160 Sundry Number: 316-268 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1, p Cathy . Foerster Chair DATED this 2A-ay of May, 2016. RBDMS I/L- MAY 3 1 2016 STATE OF ALASKA MAY 1 0 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 11.Type of Request: Abandon ❑ Plug Perforations ❑✓ • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ i Suspend ❑ Perforate 0 ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Pull CT velocity string Q. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. 1. L p.,,„/,.......... Exploratory ❑ Development ❑✓ . 208-160 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20582-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 607 ' Ninilchik Unit S Dionne 6 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0359242/ADL0384372/FEE-CIRI/FEE-PRIVATE Ninilchik/Beluga-Tyonek Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 6,737' 4,520' 6,238' 4,086' 1,213psi 5,780' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101" Surface 2,031' 9-5/8" 2,031' 1,580' 5,750 psi - 3,090 psi Intermediate Production Liner 4,941' 4-1/2" 6,735' 4,519' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.61E I L-80 6,735 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Packer-Baker ZXP and SSSV-N/A Baker ZXP 1,794'(MD)1,488'(ND)and SSSV-N/A 12.Attachments: Proposal Summary ElWellbore schematic ❑� X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development III • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: May 24,2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑, ' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasseathilcoracom Printed Name Chad Helgeson Title Operations Manager Signature ,✓�� Phone 907-777-8405 Date 51(0/I(2 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test K Mechanical Integrity Test CI ❑ Location Clearance Other: , -393c, tea• . /h P �, „j/-` Cc-r-') Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS L V MAY 3 1 2016 Spacing Exception Required? Yes ❑ No ' Subsequent Form Required: )® 1 o 1 APPROVED BY rt� Approved by:1( 1647 COMMISSIONER �� THE(COMMISSION Date:J �/ I G NA y"" '1 '��' SubmitForm and Form 10-403 Revised 11/2015 Ap v p ti r3 li 2 m nths from the date of approval. Attachments in Duplicate A r/-e76 . 6 -5 //k / ,,r . 111 . • Well Prognosis Well: SD-6 Hilcorp Alaska,LL Date:05/9/2016 Well Name: SD-6 API Number: 50-133-20582-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 05/24/16 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 208-160 First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Surface Pressure: 60 psi Current BHP: — 395 psi @ 3,643' TVD (Flowing survey on 4/16/16) Maximum Expected BHP: — 1,581 psi @ 3,678' ND (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: — 1,213 psi (Assumed 0.10 psi/ft gas gradient) Brief Well Summary Susan Dionne#6 was drilled and completed as a gas well in 2008. During the initial perforating of the well,the gun got stuck and was fished with slickline.Subsequently the well flowed gas at significant rates and the entire interval was not perforated. In 2013 the well was perforated in the Beluga 135,which increased both the gas and water rates.A plug was set in the lower perforations in 2014 in an attempt to isolate the water with ' marginal results. In order to help keep the well unloaded, a velocity string was installed in 2014. The purpose of this work/sundry is to remove the velocity string, push away the water (if above plug setting . depth) and plugback the open intervals, and add perforations in the Beluga sands. Notes Regarding Wellbore Condition • Fluid level at 5,676' MD with 60 psig surface pressure on 4/16/16. • Plug will be set in R landing nipple of v-string prior to starting work. . • Blow down v-string to production after setting plug to perform negative pressure test. • Pump and bleed 20 bbls of water into velocity string, pressure test plug to 1,000 psig. . ^ �8 t • If lu won't ho wi produced water: . ttr,' " els Safety Concerns s-it-tc • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and eople could enter(if nitrogen used during this job) • Consider tank placement based on wind direction and current weather forecast(if venting methane and nitrogen during this job) • Ensure all crews are aware of stop job authority Coiled Tubing Procedure: U �/ S"tom� $5 i sem,/4.-67Z2 . 1. Submit 24 hr.witness notification to AOGCC via web base notification. 2. MIRU Coiled Tubing, PT BOPE to 250090 psi. 350 p5 f' --r;51-- 3. ;>13. Make up MHA with disconnect and GS spear. Stab on well and PT lubricator to 250/4,500 psi. 4. RIH to latch hanger profile. Pick up to confirm latch. Slack off to neutral weight. Back off top lock down screws. Pull V string into lubricator. • Well Prognosis Well: SD-6 Hilcorp Alaska,LLQ Date:05/9/2016 5. Set CT in BOPE pipe/slip rams. Mechanically lock in rams. Bleed pressure to 0 psig. 6. Raise injector head and lubricator up enough to expose CT hanger and GS profile. 7. Cut off CT connectors from both V string and CT retrieval whip. MU double dimple cold roll connector with slick 2.375" OD. 8. Stab lubricator back onto BOPE. 9. Pull test connector. Slack to neutral weight. Unlock rams and open BOP. 10. POOH with 2.375" coiled tubing and BHA. 11. Rig back Coiled Tubing. 12. ND coiled tubing hanger. 13. Rig down CT unit. E-Line Procedure: 14. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 15. RIH with Pressure/Temperature tool and check for fluid level. POOH. 16. If fluid level is above 5,640' MD: '- a. RU nitrogen pumping unit and connecting hoses. PT equipment 250/3,000 psig. b. Pressure up well with nitrogen to push water away; Injection pressure should be around 1,300 psig. Once injection pressure has stabilized, stop pumping and SI well. c. RD nitrogen pumping unit. 17. MU 4-1/2" CIBP and setting tool. :710-1- 18. RIH and set CIBP at+/-5,640'. POOH w/setting tool. 19. MU dump bailer and fill w/cement. 20. RIH and dump cement on top of CIBP(10' =6 gallons). POOH w/dump bailer. 21. Wait 24 hours for cement to set. 22. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 23. Perforate the Beluga sands with 2-7/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each zone may be shot twice. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Gross Proposed Perforated Intervals Sands Top(MD) Btm (MD) FT Beluga BLG 100 ±5,518 ±5,549 ±31 Beluga BLG 80 ±5,455 ±5,461 ±6 Beluga BLG 80 ±4,895 ±4,902 ±7 Beluga BLG 70 ±4,842 ±4,854 ±12 Beluga BLG 70 ±4,758 ±4,765 ±7 Beluga BLG 70 ±4,711 ±4,724 ±13 Beluga BLG 70 ±4,662 ±4,673 ±11 Beluga BLG 60 ±4,366 ±4,390 ±24 24. POOH. 25. Flow through test separator and record water and gas rates. 26. RD e-line. 27. Turn well over to production. . Well Prognosis Well: SD-6 Hilcorp Alaska,LLQ Date:05/9/2016 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram (Current and Proposed) 4. CT BOPE Schematic H . • Ninilchik Field • SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 Ilileorp Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm '7 z L. A 20" Conductor 129.5/X-56/PE Surf 101' N 9 5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' } 4-1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' z& TUBING DETAIL 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 20" u 2-3/8" Coil tubing 1.88 Surf 5,702' JEWELRY DETAIL t. r No Depth Length ID Item ti• 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel 2 1,794' 35' 3.958 Liner Hanger and ZXP Packer 1/4"00 0.049"wall 3 5,780' 1' CIBP kis '. Chemical injection line SA x;° tied into mandrel at VELOCITY STRING DETAIL(2-3/8") !k 9 1,507'w/check valve 1� No Depth Length ID Item killi 1i !A A Surface 3.858 CT Hanger B 5,759' 1.5 1.875 CTC,pup joint w/drain port,R profile nipple, r &shear sub a t ta1 t 54(vL) , 1 9-5/8" 'iFi4wik kv ). -. `1. ry Pis PERFORATION DETAIL 4,11 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status '") ✓1 '* r. , BLG-130 5,659' 5,668 3,584' 3,592' 9' 2/23/13 Open '! 4 }2' ` iT BLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Open k 1., 4-1/2"Hvdril 563 Short � 11 Joint Locations:' BLG-135 5,740' 5,744' 3,654' 3,658' 4' 2/23/13 Open 1 4.01 :t 3,038.1'-3,057.9 MD ii 3,626.8'-3,646.6'MD BLG-135 5,747' 5,751' 3,660' 3,664' 4' 2/23/13 Open .) r,>- , BLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Open 1 �' BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Closed i ee,a 'ci eta, _ BLG-130 'z' B ' ` OPEN HOLE/CEMENT DETAIL BLG135 3 9 5/8„ 12-1/4" hole, Cmt w/490 sks(217 bbls)12 ppg, Type 1 cmt with 160 sks(71 bbls)to surface. 1 BLG-135 4-1/2" Seal Assembly stung into SBE @ 1,840 MD. ,t s' TB (4.75"OD Bullet Seal Assembly) ,7 "ri' #` 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed ▪w• t k 44/2" w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) i • PROPOSED Ninilchik Field SCHEMATIC Well #: Susan Dionne 06 Last Completed: 12/21/2008 Hilcoru Alaska,LLC CASING DETAIL RKB:MSL=156' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 129.5/X-56/PE _ Surf 101' I` ' 9-5/8" Surface 40/N-80/BTC 8.835 Surf 2,031' 4-1/2" Liner 12.6/L-80/Hydril 563 3.958 1,794' 6,735' ' '' TUBING DETAIL y* 19 M; 4-1/2" Tie-Back Tubing 12.6/L-80/Hydril 563 3.958 Surf 1,794' 20" ar 2-3/8" Coil tubing 1.88 Surf 5,702' 4" VI JEWELRY DETAIL 44 ieN '; No Depth Length ID Item 1 1,507' 3' 3.858 Baker Chemical Injection Mandrel 2 _ 1,794' 35' 3.958 Liner Hanger and ZXP Packer 1/4"OD 0.049"wall 3 5,460' 11' CIBP w/10'cement Chemical injection line 4 5,780' 1' CIBP :, tied into mandrel at (`"° ie 1,507'w/check valve PERFORATION DETAIL \S 1 Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status III BLG-60 ±4,366' ±4,390' ±2,506' ±2,522' 24' TBD Proposed { 1 i, c. BLG-70 ±4,662' ±4,673' ±2,724' ±2,733' 11' TBD Proposed $2 [I PI BLG-70 ±4,711' ±4,724' ±2,764' ±2,775' 13' TBD Proposed „, i i'' BLG-70 ±4,758' ±4,765' ±2,803' ±2,809' 7' TBD Proposed := y * BLG-70 ±4,842' ±4,854' ±2,875' ±2,885' 12' TBD Proposed 9-5/8' F, .4 ' a BLG-80 ±4,895' ±4,902' ±2,921' ±2,927' 7' TBD Proposed 'nf " BLG-80 ±5,455' ±5,461' ±3,407' ±3,412' 6' TBD Proposed ' 4-1/2"Hydril 563 Short 41 a Joint Locations: BLG-100 ±5,518' ±5,549' ±3,462' ±3,489' 31' TBD Proposed x 4 3,038.1'-3,057.9'MD '‘;:l.tr"", 3,626.8'-3,646.6'MD BLG-130 5,659' 5,668' 3,584' 3,592' 9' 2/23/13 Isolated : 1„%T.,, BLG-135 5,734' 5,737' 3,649 3,652' 3' 2/23/13 Isolated ill! BLG60 BLG-135 5,740' 5,744' 3,654' 3,658' 4' 2/23/13 Isolated fi BLG70 3,664' h'd ytz M, BLG80 BLG-135 5,747' 5,751' 3,660' 4' 2/23/13 Isolated SBLG100 �) pBLG-135 5,756' 5,768' 3,668 3,678' 12' 2/23/13 Isolated BLG-135 5,791' 5,809' 3,698' 3,714' 18' 10/13/14 Isolated '..:4r4 BLG130 }4 BLG135 OPEN HOLE/CEMENT DETAIL 4 9-5/8" 12-1/4" hole, Cmt w/490 sks(217 bbls)12 ppg, , Type 1 cmt with 160 sks(71 bbls)to surface. yea :: BLG135 41/2" Seal Assembly stung into SBE @ 1,840 MD. ' TB (4.75"OD Bullet Seal Assembly) tj u } 8-1/2"hole,Cmt w/270 sks(105 bbls)12.5 ppg Class G Lead cmt followed `fir3 4-1/2" w/970 sks(196 bbls)15.8 ppg Class G Tail cmt. (20-25 bbls cmt to surface) ,4,. s,, .°tx Liner 0; 1 Tagged at 6,238'with NOTE: DID NOT Bump Plug,stopped cement displacement 8 bbls short 3.5"GR on 10/04/14 of total displacement. i L 614 ' INCLINATION DETAIL '�;' 41 KOP @ 244'MD/TVD � 1 Build"3.35 deg/100'from 244'-1,970'MD Hold 68.75 deg from 1,970'-3,825'MD 1D=6,737' PBTD=6,606 Drop"'3.45 deg/100'to 4,970'MD MAX HOLE ANGLE=68.75°@ 1,970' Hold 29.75 deg from 4,970'to TD at 6,737'MD Azimuth:251.5 deg. Updated by TWN 05-09-16 Ninilchik Unit .11 SD#6 05/09/2016 Hilrorp 11.44.1,1.1.1: Ninilchik Unit Tubing hanger,MB-235,11 X Susan Dionne#6 4.909 MCA lift X4'A IBT susp, 20 X9 5/8 X 4%x2 3/8 w/4"Type H BPV profile 2- 'A continuous control lines 6.5"Extended neck Coiled tubing hanger,VG- CTM,4"nominal X2 3/8 EUE susp X 3"GS Baker Fish Neck Tree cap,Otis,4 1/16 5M FE Lift w/2"Type H BPV and X 6'A Otis Quick Union grapple for 2 3/8"coil > o e Valve,Swab, C O 3�.,tsF`? VG-M,41/165M FE,HWO l 4a N\ DD trim t U� , o, , O ® nil, �� -- /i e ss Tee,stdd,4 1/16 SM X Ix:,- 4..,„., ®-�°k 3 1/8 5M " t i lit JJ _ _U01 00 Valve,upper master, � - VG-M,4 1/16 5M FE,HWO, IF a DD trim U mite=we l� i' 2 1/16 SM Wing section r 4, E,...».;m.. ' 11 ,j41 I . .. DSA,4 1/16 10M X - 4 1/8 5M also! .B.iwl Valve,master,CIW-FC, . �. 41/1610M FE,HWO,DD i°� trim ,v *Yaw Adapter,Vetco,11 SM stdd X . - 4 1/16 10M stdd top, °y�. preppedf/6.5"extended II neck hanger !�.- Multibowl,Vetco MB-150, 'fl-1' "��ti �'. . 11 3M stdd bottom X 11 SM FE top,w/ 2-2 1/16 5M SSO,1-control ! = C ' �_1e : = n , line exit �L.Gi 1- r � r 1', 7"hanger and packoff in Starting head, I i wellhead for space out only Vetco MB-150, ' ',��. 11 3M X 9 5/8 VG-Loc �- ! 1I ��1111 bottom,w/2-2"LPO iHi ._' A. „____ , 20, 1 - I9 5/8., 4.5" • • Ninilchik Unit 11 SD#6 05/09/2016 Ililrurh 11.:4�:.Iii Ninilchik Unit Tubing hanger,MB-235,11 X Susan Dionne#6 4.909 MCA lift X4''/:IBT susp, 20 X 9 5/8 X 4 1/2 w/4"Type H BPV profile,2- '/.continuous control lines 6.5"Extended neck Tree cap,Otis,4 1/16 5M FE X 6%:Otis Quick Union 0 <,,e' �O \ F mum ., 44, Valve,Swab, 11,--„_.O� , ,a\,e`9,��.`� \,eS1�<1�`OVG-M,4 1/16 SM FE,HWO, �,\ .1a b, o- DD trim U U ,e, O 'V4O,„,Z,P -(.5 -1 oc ,-i-'4' Tee,stdd,4 1/16 SM X �JC ' `w vie, , O 3 1/8 5M Il , )_ / L _ ui Valve,upper master, VG-M,4 1/16 5M FE,HWO, 111*_ �� DD trim 0.511r U DSA, DSA,4 1/16 10M X 4 1/8 5M Valve,master,CIW-FC, J 4 1/16 10M FE,HWO,DD trim w O Adapter,Vetco,11 5M stdd X i it 4 1/16 10M stdd top, '33"411•110.”{ prepped f/6.5"extended I t neck hanger 'll Multibowl,Vetco MB-150, ''-°'ice''--� ''mar �'- "'*rF:a, 11 3M stdd bottom X 11 5M FE top,w/ 2-2 1/16 SM SSO,1-control 1 i I , �4 r �' line exit 11 �_ a �� ,4 t' i z 1 �� , r i s 7"hanger and packoff in Starting head, ill-1 Ilhead for space out only Vetco MB-150, — ',11 3M X 9 S/8 VG-Loc I, = bottom,w/2-2"LPO ■ 1 1 �1 20" 9 5/8" 4.5'1 0 • Ninilchik Gas Field GO-6 05/09/2016 1111.,q, U.,4,.,.1.11 GO-6 Coil Tubing BOP Lubricator to injection head I l 1.75" Tandem Stripper 4 1/16 10 I CI= Blind/Shear Blind/Shear : 3 l -- - - - \ _/- 47 — _Blind/Shear i_ Blind/Shear : J _—— I ®® —_- 90. ® SNI C Slip Slip *Ill Mud Cross JIuIuI !Mill •• Pipe IPipe 11114 4 1/16 10M X 4 1/16 10M ili Outlet w/ 2- 2 1/16 10M full 1.1 Outlet FMC valves MINI ° l !bu i 0 i I _ n i '0 1111 Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spool rrn Jr) 4 1/16 10M X 4 1/16 5M • • STANDARD WELL PROCEDURE h k NITROGEN OPERATIONS 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/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 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. 12/08/2015 FINAL v1 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 4,(,3),„- DATE: 4/10/2015 P. I. Supervisor H FROM: Matt Herrera SUBJECT: Follow-up Inspection Petroleum Inspector Flowline Issue SusanDionne #6 Hilcorp Alaska PTD 2081600 - Background: AOGCC Inspector Jeff Turkington observed significant subsidence at Ninilchik Unit well Susan Dionne #6 on April 16, 2014 while at the pad to witness SVS tests. Refer to his Inspection Report. 4/10/2015: I traveled to Susan Dionne #6 for a follow-up inspection at the request of Inspection Supervisor Jim Regg. I met with Hilcorp representative Dean Gardner and we went to inspect the well. He indicated that Hilcorp did address the subsidence-related stresses in the production piping on June 15, 2014. See attached photos. Attachments: Photos (2) - SOAK° MAY22 `.01t 2015-0410_Flowline_SusanDionne-6_follow-up_mh.docx Page 1 of 2 Flowline Issue- Ninilchik Unit Susan Dionne#6 (PTD 2081600) Follow-up Inspection Photos by AOGCC Inspector M. Herrera 4/10/2015 si '� 1. V' 'it V -' ,, ,...ll mak,. Ili 0 11 — . 4 , . . . , , ,,,..- ,„, , „.......,,, . , -_, II ._..., s,. ! ,i:-:::,.... - ,:,,, „.• , ,,,, ..,,,,:-! .; ,, , , ;I ... • - iir 4-1. _- , `''- iii i Previous stress i; e point on this ;-. iF ;' targeted flow tee i_ '� .4„ .., . .., 'i \\� i�• a ti :,# �._ L i, `` m' Production piping _-- downstream of outlet from 1" `" .,,,,,, tree has been adjusted and reconfigured to eliminate the stress on targeted tee due to • subsidence around the tree. — ...... ,--. ,, i i i. kms.. AA''``f11111141r. ; S Ail,l 2015-0410_Flowline_SusanD ionne-6_follow-up_mh.docx Page 2 of 2 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cR O 8 - J 0 Well History File Identifier Organizing (done) ❑ Two -sided 1 ❑ Rescan Needed 111 1111111111 R AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. t ❑ [�Greyscale Items: ❑ Other, No/Type: r Items Scann ble by v a Large Scanner '7.—(9&5 ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 4D l /s/ YVIP_ Project Proofing 1 BY: Date: 5 `a, l / /s/ Y4P ___ Scanning Preparation 5 x 30 = / 6?) + = TOTAL PAGES 1 5 7 (Count does not include cover sheet) BY: Date: /s/ Production Scanning III IIIIIII 1111111 Stage 1 Page Count from Scanned File: 1 (OD (Count does include cover eet) Page Count Matches Number in Scanni 9 p Pre aration: YES NO BY: Mb Date: 6 (9.,, `/ /s/ 141 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111 1 1111 ReScanned 11 1111111 II IIIU BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc a . 7 7 ;E y! ire 8.8.x`` STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION ... REPORT OF SUNDRY WELL OPERATIONS A0 7 1. Operations Abandon U Repair Well [J Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Op.erat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2.'Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ ,. 208 -160 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: �� Anchorage, Alaska 99504 — 50- 133 -20582 1 7. Property Designation (Lease Number): 8. Well Name and Number: ADL035924 / ADL0384372 J Ninilchik Unit S Dionne 6 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Ninilchik / SD Undefined Beluga Gas 1 1 . Present Well Condition Summary: Total Depth measured 6,737 feet Plugs measured N/A feet true vertical 4,520 feet Junk measured 6,279 (Fish) feet Effective Depth measured 6,279 feet Packer measured 1,794 feet true vertical 4,079 feet true vertical 1,488 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 2C" 101' 101' Surface 2,031' 9 -5/8" 2,031' 1,580' 5,750psi 3,090psi Intermediate Production Liner 4,941' 4 -1/2" 6,735' 4,519' � o 83q�i ? 7,500psi . APR LUU lldd Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# / L -80 6,735'MD 4,519'TVD I Packers and SSSV (type, measured and true vertical depth) Baker ZXP N/A 1,794'MD 1,488'TVD 12. Stimulation or cement squeeze summary: N/A Irrervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A + Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,972 4 0 255 Subsequent to operation: 0 3,276 4 0 434 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory El Development © Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ ,. Gas isi WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ IT 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: 313 -068 • Contact Shane Bennett Email sbennett . Printed Name Chris Kanyer Title Reservoir Engineer L Signature,,, Phone 907-777 -8377 Date 3/20/2013 Form 10 -404 Revised 16 /�87.JMS 'APR 0 2 2013 z" ' � ei Submit Original Only 11 Ninilchik Field SCHEMATIC Well #:Susan Dionne 06 Ililcorp Alaska, LLC Last Comnleted:12 /21/2008 CASING DETAIL RKB: MSL = 156' Size Type Wt/ Grade/ Conn ID Top Btm ?: 20" Conductor 129.5 / X -56 / PE Surf 101' t" 9-5/8" Surface 40 / N BTC 8.835 Surf 2,031' 4 -1/2" Liner 12.6 / L -80 / Hydril 563 3.640 1,794' 6,735' £4 TUBING DETAIL 4 -1/2" 1 Tie -Back Tubing I 12.6 /L - / Hydril 563 3.640 I Surf I 1,794' 20" '° JEWELRY DETAIL ki No Depth Length ID Item t': 1 1,507' 3.858 Baker Chemical Injection Nipple V 2 1,794' 9 -5/8" Baker Packer Top 3 1,829' 4 -1/2" Baker Liner / Hanger Top 4 6,984' PAC Valve 1/4" OD 0.049" wall 5 9,467' Landing Collar Chemical injection line 6 9,509' Float Collar 4. tied into mandrel at 7 9,593' Float Collar 7 1,507' w/ check valve 1 , PERFORATION DETAIL . d ■ ,. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 11 BLG -130 5,659' 5,668 3,584' 3,592' 9' 3/23/13 Open ' 2 f ; P NI BLG -135 5,734' 5,737' 3 ,649 3,652' 3' 3/23/13 Open 1 : BLG -135 5 5 3 3,658' 4' 3 Open # " 3 BLG -135 5,747' 5,751' 3,660' 3,664' 4' 3/23/13 Open • BLG -135 5,756' 5,768' 3,668 3,678' 12' 3/23/13 Open • BLG -135 5,791' 5,809' 3,698' 3,714' 18' 12/20/08 Open ' 1- OPEN HOLE / CEMENT DETAIL >y ,' 4-1/2" Hydril 563 Short , � " 12 - 1/4" hole, Cmt w/ 490 sks (217 bbls) 12 ppg, Joint Locations: 9-5/8" Type 1 cmt with 160 sks (71 bbls) to surface. 3,038.1' 3,057.9' MD 3,626.8' - 3,646.6' MD 4 - 1/2" Seal Assembly stung into SBE @ 1,840 MD. TB (4.75" OD Bullet Seal Assembly) „ i ,I 8 - 1/2" hole, Cmt w/ 270 sks (105 bbls) 12.5 ppg Class G Lead cmt followed , w/970 sks (196 bbls) 15.8 ppg Class G Tail cmt. (20 -25 bbls cmt to surface) ': k,''' 4 - 1/2 " V "4 Liner NOTE: DID NOT Bump Plug, stopped cement displacement 8 bbls short . BLG130 or total displacement. Liner Wiper Plug may be located @ 6,080' MD. " , BLG -135 BLG-135 INCLINATION DETAIL T ' a KOP @ 244' MD/TVD Build "'3.35 deg / 100' from 244' - 1,970' MD •° Hold 68.75 deg from 1,970' - 3,825' MD Drop "'3.45 deg / 100' to 4,970' MD Tagged @ 6,279' MD 41 &.. Hold 29.75 deg from 4,970' to TD at 6,737' RKB 8/31/2010 2.75" ' ,, MD + GR on a - line. t4 4 Azimuth: 251.5 deg. i Cement plug did not , ii,.. bump, may be located t '" high @ 6,230' MD. i i V ,.! (T Tagged on 12 /14/2008 41/2°' i TD 6,737 PBTD= 6,606' MAX HOLE ANGLE = 68.75 @ 1,970' Revised By: TDF 3 -19 -2013 Hilcor p Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SD -06 50- 133 - 20582 -00 208 -160 2/23/13 2/23/13 ( LE 1,0 10III '11,111 111 " 1,11111 _ _ n 2/20 /2013 „ - , Wednesday No operations to report 2/21 /2013 -Thursday No operations to report 2/22/2013 Friday f No operations to report 2/23/2013 - Saturday iN Cut line and run thru grease tubes. Put new rope socket on. Build 2' gun. Pressure test lubricator to 250psi low/ 2,500psi high. RIH w/ 2 -1/8” x2', 6 spf, 0 deg phase strip gun. Tie into Expro Dual Radial CBL, GR /CCL dated 14- Dec -08 for all runs. Spot gun from 5,760' to 5,763' per Final Approved Perf Request Form dated 2/4/13. TP 330 psi. Fired gun and tubing slowly started climbing to 340 psi after about 40 min. All shots fired. Tubing pressure went to 340 psi and then dropped off to 339 psi. RIH w/ 3 -3/8 "x12' HC, 6 spf, 60 deg phase (loaded with 3 -1/8" charges). Spot gun from 5,756' to 5,768'. TP 337 psi. POOH All shots fired. Tubing pressure went to 340 psi right away and still climbing. RIH w/ 3 -3/8 "x20' HC, 6 spf, 60 deg phase (loaded with 3 -1/8" charges). Spot gun from 5,747' to 5,751, 5740' to 5744 and 5734' to 5737'. 368 psi. Fired shots POOH All shots fired. TP creeping on up. RIH w/ 3- 3/8 "x9' HC, 6 spf, 60 deg phase (loaded with 3 -1/8" charges). Spot gun from 5659' to 5659' to 5,668 per. 368 psi. tP. Tubing press 391 psi, and when we fired gun TP went to 436 PSI and was clibing . POOH, tools stopped at 39'. Could not come up but could go down. Tubing pressure peaked at 931psi and then fell back 713 psi. Wait on Pollard to get line clamp out to location. Pollard got parts and cut line and tie line back together until tools are above master. Got all tools back. Rig down lubricator. 2/24/2013 - Sundays ° r N; r ��nd , s No operations to report 2/25/2013 Monday t '= ., No operations to report 2/26 /2013- Tuesday �,�� ,I ' No operations to report • • , � \ \� % s . THE STATE Alaska Oil and Gas ® f Conservation Commission outt O ' F a ,A11:- GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS E® LIAR 0 6 am Main: 907.279.1433 S �� Fax: 907.276.7542 Shane Bennett Operations Engineer Hilcorp Alaska, LLC Q_CYZ - 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Ninilchik Field, SD Undefined Beluga Gas Pool, S Dionne 6 Sundry Number: 313 -068 Dear Mr. Bennett: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, /� 7 Cathy P. "s erster Chair DATED this 11' d f February, 2013. Encl. RECEIVED STATE OF ALASKA FEB 0 8 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 Zf ' • APPLICATION FOR SUNDRY APPROVALS AOG CC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ID , Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Gass: 5. Permit to DriN Number. Hilcorp Alaska, LLC Exploratory ❑ Development p ' 208 -160 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 13320582-00 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 607 • Will planned perforations require a spacing exception? Yes ❑ No 0 Ninilchik Unit S Dionne 6 • 9. Property D signation (Lease Number): 10. Field /Pool(s): ADLL4 ` �Z y / y ADL0384372 Ninilchik / SD Undefined Beluga Gas • � 11. 2 _' "` i 3 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,737 - 4,520 • 6,230' 4,079' 6,230' (cement plug) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 101' 20" 101' 101" Surface 2,031' 9 -5/8" 2,031' 1,580' 5,750 psi 3,090 psi Intermediate Production Liner 4,941' 4 -1/2" 6,735' 4,519' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4 -1/2" 12.6# / L -80 1,794' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Packer - Baker ZXPand SSSV - N/A Packer 1,794' (MD) 1,488' (ND) and SSSV - N/A 12. Attachments: Description Summary of Proposal CI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 12 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/13/2013 Commencing Operations: Oil ❑ Gas 0 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Myers Email cmyersghilcorp.com Printed Name Shane Bennett Title Operations Engineer Signature Me V .. 4.0 .---- Phone 907 777 -8425 Date 2/8/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 513 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RSDMS FEB 15 2013 Spacing Exception Required? Yes ❑ No BO Subsequent Form Required: /v — [Mt( APPROVED BY Approved by: C OMMISSIONER THE COMMISSION Date: 2. "/ iL - /-3 n ;��/ Approved application is valid for 12 months from the date of approval. At�chments in Duplicate �T l • • Well Prognosis Well: SD -6 Hikorp Alaska, LL Date: 2/7/2013 Well Name: Ninilchik Unit S Dionne 6 . API Number: 50- 133 - 20582 -00 -00 Current Status: Flowing gas completion Leg: N/A Estimated Start Date: February 13, 2013 Rig: N/A Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 208 -160 First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: Current Bottom Hole Pressure: —625 psi Maximum Expected BHP: —1,568 psi @ 3,620' TVD Calculated using .433psi /ft gradient Max. Allowable Surface Pressure: —1,434 psi (Based on 0.037 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as a gas well in 2008. During the initial perforating of the well, the gun got stuck and was fished with slickline. Subsequently the well flowed gas a significant rates and the entire interval was not perforated. The well is currently flowing and is producing "3bwpd. The proposed completion plan is to add the remaining perforations of the currently perforated interval in the Beluga 135. NOTE: As discussed in the attached email about well SD -5, the original Well Completion Report (form 10 -407) was incorrect, listing the pool as Undefined Tyonek. The original produced interval is the Beluga 135 sand and the pool should be labeled as Undefined Beluga. Summary Procedure 1. RU E -line and test lubricator to 250psi low /2,500psi. 2. Perforate the Beluga 130 &135 sands at +/- 5,659' to +/- 5,668', +1- 5,734' to +/- 5,737', +/- 5,740' to +/- 5,744', +/- 5,747' to +/- 5,751', and +/- 5,756' to +/- 5,768'. 3. RD Eline. 4. Turn well over to production & flow test well. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. Email Correspondence with AOGCC Guy Schwartz • Ninilchik Field SCHEMATIC Well #:Susan Dionne 06 Ililcorp Alaska, LLC Last Comnleted:12 /21/2008 CASING DETAIL RKB: MSL =156' Size Type Wt/ Grade/ Conn ID Top Btm t " 20" Conductor 129.5 / X -56 / PE Surf 101' 9 -5/8" Surface 40 / N -80 / BTC 8.835 Surf 2,031' 4 -1/2" Liner 12.6 / L -80 / Hydril 563 3.640 1,794' 6,735' TUBING DETAIL 4 -1/2" Tie -Back Tubing 12.6 /L -80 / Hydril 563 3.640 I Surf 1,794' 2a' JEWELRY DETAIL • No Depth Length ID Item 1 1,507' 3.858 Baker Chemical Injection Nipple 2 1,794' 9 -5/8" Baker Packer Top 3 1,829' 4 -1/2" Baker Liner/ Hanger Top 4 6,984' PAC Valve 1/4" OD 0.049" wall 5 9,467' Landing Collar Chemical injection line 6 9,509' Float Collar tied into mandrel at 7 9,593' Float Collar 1,507' w/ check valve 1 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ■ * *I BLG -135 5,791' 5,809' 3,698' 3,714' 18' 12/20/08 Open ■ I i L OPEN HOLE / CEMENT DETAIL ■ 3 12 -1/4" hole, Cmt w/ 490 sks (217 bbls) 12 ppg, 9 -5 /8' 4 , 9 5/8" Type 1 cmt with 160 sks (71 bbls) to surface. 4 -1/2" Seal Assembly stung into SBE @ 1,840 MD. TB (4.75" OD Bullet Seal Assembly) 8 -1/2" hole, Cmt w/ 270 sks (105 bbls) 12.5 ppg Class G Lead cmt followed 4 -1/2" w/970 sks (196 bbls) 15.8 ppg Class G Tail cmt. (20 -25 bbls cmt to surface) 4 -1/2" Hydril 563 Short Liner NOTE: DID NOT Bump Plug, stopped cement displacement 8 bbls short , Joint Locations: «, 3,038.1' - 3,057.9' MD or total displacement. Liner Wiper Plug may be located @ 6,080' MD. 3,626.8'- 3,646.6' MD INCLINATION DETAIL KOP @ 244' MD /TVD Build '3.35 deg / 100' from 244' - 1,970' MD Hold 68.75 deg from 1,970' - 3,825' MD Drop deg / 100' to 4,970' MD Hold 29.75 deg from 4,970' to TD at 6,737' MD p Azimuth: 251.5 deg. BLG-135 )?I /- SOOr Tagged @ 6,279' MD RKB 8/31/2010 2.75" GR on e-line. Cement plug did not bump, may be located high @ 6,230' MD. Tagged on 12/14/2008 4-1/2" TD =6,7337' PBTD = 6,606' MAX HOLE ANGLE = 68.75 @ 1,97d Revised By: ILL 02 -08 -2013 • • • Ninilchik Field Proposed Well #:Susan Dionne 06 Hilcorp Alaska, LLC Last Comnleted:12 /21/2008 CASING DETAIL RKB: M5L- Size Type Wt/ Grade/ Conn ID Top Btm li 20" Conductor 129.5 / X -56 / PE Surf 101' 1 9 -5/8" Surface 40 / N -80 / BTC 8.835 Surf 2,031' i rc i j 4 -1/2" Liner 12.6 / L-80 / Hydril 563 3.640 1,794' 6,735' 4 TUBING DETAIL 4 -1/2" Tie -Back Tubing 1 12.6 /L -80 / Hydril 563 I 3.640 1 Surf 1,794' 20" ? ; ',` JEWELRY DETAIL No Depth Length ID Item ''.:1 1 1,507' 3.858 Baker Chemical Injection Nipple 2 1,794' 9 -5/8" Baker Packer Top 3 1,829' 4 -1/2" Baker Liner / Hanger Top "+ 4 6,984' PAC Valve s 1/4" 00 0.049" wall 5 9,467' Landing Collar Chemical injection line 6 9,509' Float Collar t ied into mandrel at r w 7 9,593' Float Collar 1,507' w/ check valve 1 "111111 1 4 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ,, _1 IL IC; 2 BLG -130 ±5,659' ±5,668 ±3,584' ±3,592' 9' Future ,) Ili PI .?' BLG -135 ±5,734' ±5,737' ±3,649 ±3,652' 3' Future BLG -135 ±5,740 ±5,744' 13,654' ±3,658' 4' Future )+ ,r '' ±3,664' 3 BLG -135 ±5,747' ±5,751' ±3,660' ±3,664 4' Future 9 .. t. s i. L ` t BLG -135 15,756' 15,768' 13,668 13,678' 12' Future .a '*4 BLG -135 5,791' 5,809' 3,698' 3,714' 18' 12/20/08 Open r '4 jr4 , ti OPEN HOLE / CEMENT DETAIL 4 - 1/2" Hvdril 563 Short 12 -1/4" hole, Cmt w/ 490 sks (217 bbls) 12 ppg, Joint Locations: 9 -5 Type 1 cmt with 160 sks (71 bbls) to surface. ;+: 3,038.1'- 3,057.9' MD A 3,626.8' - 3,646.6' MD 4 -1/2" Seal Assembly stung into SBE @ 1,840 MD. t TB (4.75" OD Bullet Seal Assembly) °.r 8 -1/2" hole, Cmt w/ 270 sks (105 bbls) 12.5 ppg Class G Lead cmt followed try+ R. 4 -1/2" w/970 sks (196 bbls) 15.8 ppg Class G Tail cmt. (20 -25 bbls cmt to surface) Y 14 B O Liner NOTE: DID NOT Bump Plug, stopped cement displacement 8 bbls short j 7'. ' or total displacement. Liner Wiper Plug may be located @ 6,080' MD. 11 BLG-135 = i BLG-135 INCLINATION DETAIL KOP @ 244' MD/TVD >,,# Build "3.35 deg / 100' from 244' - 1,970' MD -I Hold 68.75 deg from 1,970' - 3,825' MD Drop - 3.45 deg / 100' to 4,970' MD s ; ' Hold 29.75 deg from 4,970' to TD at 6,737' Tagged @ 6,279' MD .r RKB 8/31/2010 2.75" i = ' : '1' MD GR on a -line. t Azimuth: 251.5 deg. A s Cement plug did not bump, may be located 1 high @ 6,230' MD. ,y (y r Tagged on 12/14/2008 41/2" 4 ".I:: TD 737• PBTD = 6,606' MAX HOLE ANGLE = 68.75 @ 1,970' Revised By: JLL 02 -07 -2013 • • Juanita Lovett From: Tom Fouts Sent: Wednesday, January 09, 2013 10:01 AM To: Chris Kanyer; David Buthman Subject: FW: Susanne Dionne #5 - PTD# 206 -088 From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz@aalaska.gov] Sent: Wednesday, January 09, 2013 9:52 AM To: Tom Fouts - (C) Subject: RE: Susanne Dionne #5 - PTD# 206 -088 Tom, It would be best to submit a 10 -403 requesting the perforations. As part of the application explain the issue with the Tyonek pool mistake on the original 10 -407 page. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Tom Fouts - (C) [mailto:tfouts@ hilcorp.com] Sent: Wednesday, January 09, 2013 9:33 AM To: Schwartz, Guy L (DOA) Cc: Chris Kanyer; David Buthman Subject: Susanne Dionne #5 - PTD# 206 -088 Guy, We are looking at adding perforations to the Beluga -135 zone above the existing perfs for Susan Dionne #5. On the 10- 407 (See Attached) box # 15 states the field as Ninilchik and the pool as Tyonek. The pool listing is incorrect and should be listed as Beluga. How should I proceed forward with my sundry submittal for this well? My intent was to file a 10 -404 but due to this discrepancy I would like some clarification. Thanks, Tom Fouts 1 Construction Manager Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351 -5749 DATA SUBMITTAL COMPLIANCE REPORT 4/25/2011 Permit to Drill 2081600 Well Name /No. NINILCHIK UNIT S DIONNE 6 Operator MARATHON OIL CO API No. 50- 133 - 20582 -00 -00 MD 6737 TVD 4520 Completion Date 12/21/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION / - Mud Log No Samples No Directional Survey Yes - - - - - - -- — DATA INFORMATION Types Electric or Other Logs Run: Cement Bond Log, Quad Combo, CCL, Gamma Ray, and Multi Format (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval 011 / T�e Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt Report: Final Well R 1/16/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Detail, Geo Data, Drilling Data, Daily Report ED C Las 17480 Report: Final Well R Open 1/16/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Detail, Geo Data, Drilling Data, Daily Report, OH data Aog Mud Log 2 Col 101 6737 Open 1/16/2009 MD Formation Log Log Mud Log 2 Col 101 6737 Open 1/16/2009 TVD Formation Log " Mud Log 2 Col 101 6737 Open 1/16/2009 MD Drilling Dynamics I Log Mud Log 2 Col 101 6737 Open 1/16/2009 TVD Drilling Dynamics Log Cement Evaluation 5 Blu 1700 6230 Case 1/16/2009 Dual Radial CBL, GR, CCL 17- Dec -2008 Formation Tester 5 Blu 2030 6392 Case 1/16/2009 MD, Form tester III Neutron 5 Blu 2030 6636 Open 1/16/2009 Dens Neutron, Sonic, Wat Sat 16- Nov -2008 'tog Induction /Resistivity 25 Blu 2030 6648 Open 1/16/2009 MD Compact Quad Combo Quicklook 16- Nov -2008 wog Caliper log 5 Blu 2030 6602 Open 1/16/2009 MD Hole Volume Caliper 16 -Nov -2008 '{og Sonic 25 Blu 2030 6636 Open 1/16/2009 MD Comp Sonic 16 -Nov- 2008 Log Neutron 25 Blu 2030 6602 Open 1/16/2009 MD Photo Dens Dual Spaced Nuetron 16 -Nov- 2008 DATA SUBMITTAL COMPLIANCE REPORT 4/25/2011 Permit to Drill 2081600 Well Name/No. NINILCHIK UNIT S DIONNE 6 Operator MARATHON OIL CO API No. 50-133-20682-00-00 MD 6737 TVD 4520 Completion Date 12121/2008 Completion Status 1-GAS Current Status 1-GAS UIC N :(d Induction/Resistivity 25 Blu 2030 6648 Open 1/16/2009 MD Array Induct Vectar - Pro 16-Nov-2008 Log Induction/Resistivity 25 Blu 2030 6648 Open 1/16/2009 MD Array Induct 16-Nov- 2008 t"r Log Induction/Resistivity 25 Blu 1580 4480 Open 1/16/2009 TVD Array Induct 16-Nov- 1 2008 Well Cores/Samples Information: Sample Interval Set • Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION rti i‘ Well Cored? YO Daily History Received? — N - Chips Received? ---Y-114 Formation Tops 6)/ N Analysis Received? Comments: Compliance Reviewed By: ....--I "' Date: S _ _ 41j 1 • , Page 1 of 1 11110 $ Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba @marathonoil.com] Sent: Monday, February 09, 2009 9:08 AM To: Maunder, Thomas E (DOA) Subject: RE: Susan Dionne #6 (208 -160) Attachments: Susan Dionne 6 - MFT FINAL.pdf Tom, Here is a copy of the SD -6 Multi Formation Test with the color highlights removed. Thanks for bringing this issue to my attention. I will try to remember to remove the highlighting on future submissions. Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283 -1371 Cell (907) 394 -1332 Fax (907) 283 -1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, February 09, 2009 8:10 AM I To: Skiba, Kevin J. Subject: Susan Dionne #6 (208 -160) Kevin, I have reviewed the completion report submitted for this well. You have included 2 pages detailing the formation pressure tests. A large portion of the data has a dark green background which will copy darkly in our on -line well file system. Could you please send in revised sheets with a different color? Email is fine. By the way, nice well!! I planned to send a copy to Craig, however our computer systems got "migrated" and a lot of email links I have got toasted. Thanks much. Tom Maunder, PE AOGCC 2/9/2009 Marathon - Susan Dionne #6 FORMATION TESTER TEST SUMMARY Test Hyd Pres Hyd Pres Tool Flow Drawdown Final Shut - No. Depth TVD Before After Volume Rate Press in Press Remarks 1 6034.00 3909.18 2005.76 1996.26 5.0 0.5 LOST SEAL 2 6032.00 3907.44 1997.24 1997.97 5.0 0.5 LOST SEAL 6032.00 3907.44 1997.24 1997.97 5.0 0.5 LOST SEAL 3 6015.00 3892.68 1988.45 1988.08 5.0 0.5 105.68 1766.00 GOOD 6015.00 3892.68 1988.45 1988.08 15.0 1.0 130.99 1766.00 GOOD • 4 5994.00 3874.45 1976.79 1977.60 5.0 0.5 185.96 1734.00 GOOD 5 5980.00 3862.29 1969.91 1970.95 5.0 0.5 378.85 1659.00 GOOD 6 5955.00 3840.59 1958.24 1959.68 5.0 0.5 377.76 1407.00 GOOD 7 5945.00 3831.91 1954.23 1955.39 5.0 0.5 LOST SEAL 8 5944.00 3831.04 1954.47 1954.27 5.0 0.5 349.60 1416.00 GOOD 9 5938.00 3825.83 1950.83 1951.59 5.0 0.5 317.48 1403.00 GOOD 10 5931.00 3819.75 1947.48 1948.12 5.0 0.5 851.78 1398.00 GOOD 11 5924.00 3813.68 1944.29 1944.84 5.0 0.5 339.55 1396.00 GOOD 12 5916.00 3806.74 1940.44 1940.96 5.0 0.5 368.62 1394.00 GOOD 13 5904.00 3796.33 1934.43 1934.65 5.0 0.5 938.95 1388.00 GOOD 5904.00 3796.33 1934.43 1934.65 15.0 1.0 LOST SEAL 14 5906.00 3798.06 1936.91 1936.10 5.0 0.5 822.88 1388.00 GOOD 5906.00 3798.06 1936.91 1936.10 15.0 1.0 1110.44 1388.00 GOOD 15 5907.00 3798.93 1937.09 1936.65 5.0 0.5 801.80 1389.00 GOOD 16 5890.00 3784.18 1927.39 1928.40 5.0 0.5 1018.34 1381.00 GOOD 5890.00 3784.18 1927.39 1928.40 15.0 1.0 938.54 1374.00 GOOD 17 5868.00 3765.11 1917.39 1919.18 5.0 0.5 1212.07 1239.00 GOOD 5868.00 3765.11 1917.39 1919.18 15.0 1.0 946.07 1344.00 GOOD 18 5866.00 3763.37 1917.96 1919.34 5.0 0.5 1292.84 1322.00 GOOD ill■ 5866.00 3763.37 1917.96 1919.34 15.0 1.0 745.64 1333.00 GOOD 19 5860.00 3758.16 1916.08 1916.69 5.0 0.5 1265.63 1288.00 GOOD 5860.00 3758.16 1916.08 1916.69 15.0 1.0 1000.50 1329.00 GOOD 20 5858.00 3756.44 1915.66 1915.58 5.0 0.5 1304.67 1336.00 GOOD 5858.00 3756.44 1915.66 1915.58 15.0 1.0 978.56 1341.00 GOOD 21 5850.00 3749.49 1911.64 1911.94 5.0 0.5 1327.37 1351.00 GOOD 5850.00 3749.49 1911.64 1911.94 15.0 1.0 839.25 1330.00 GOOD 22 5842.00 3742.56 1908.15 1906.04 5.0 0.5 1290.75 1317.00 GOOD 5842.00 3742.56 1908.15 1906.04 15.0 1.0 907.68 1331.00 GOOD 23 5831.00 3733.03 1902.45 1903.10 5.0 0.5 1036.75 1064.00 GOOD 5831.00 3733.03 1902.45 1903.10 15.0 1.0 531.17 1330.00 GOOD 24 5829.00 3731.29 1902.85 1902.02 5.0 0.5 1099.30 1328.00 GOOD 25 5820.00 3723.50 1897.86 1897.91 5.0 0.5 1119.37 1301.00 GOOD 5820.00 3723.50 1897.86 1897.91 15.0 1.0 1004.13 1329.00 GOOD 26 5810.00 3714.83 1893.60 1893.46 5.0 0.5 1193.56 1211.00 GOOD 5810.00 3714.83 1893.60 1893.46 15.0 1.0 1053.62 1329.00 GOOD 27 5800.00 3706.16 1888.37 1888.75 4.0 0.5 1314.29 1336.00 GOOD 5800.00 3706.16 1888.37 1888.75 5.0 1.0 1187.93 1230.00 GOOD 5800.00 3706.16 1888.37 1888.75 15.0 1.0 913.66 1329.00 GOOD 5800.00 3706.16 1888.37 1888.75 30.0 1.0 LOST SEAL 28 5800.00 3706.16 1902.06 1894.24 5.0 0.5 1193.70 1317.00 GOOD 5800.00 3706.16 1902.06 1894.24 15.0 1.0 1149.61 1327.00 GOOD • 5800.00 3706.16 1902.06 1894.24 30.0 1.0 1213.98 1328.00 GOOD 29 5792.00 3699.23 1889.81 1890.05 5.0 0.5 1300.32 1332.00 GOOD 5792.00 3699.23 1889.81 1890.05 15.0 1.0 922.75 1326.00 GOOD 30 5775.00 3684.50 1881.40 1881.45 5.0 0.5 1335.44 1361.00 GOOD 5775.00 3684.50 1881.40 1881.45 15.0 1.0 819.66 1307.00 GOOD 5775.00 3684.50 1881.40 1881.45 5.0 0.5 LOST SEAL 31 5773.00 3682.76 1880.55 1880.00 5.0 0.5 1303.18 1328.00 GOOD 5773.00 3682.76 1880.55 1880.00 15.0 1.0 1100.94 1323.00 GOOD 32 5765.00 3675.83 1875.09 1875.57 5.0 0.5 1330.20 1354.00 GOOD 5765.00 3675.83 1875.09 1875.57 15.0 1.0 1016.53 1324.00 GOOD 33 5760.00 3671.49 1872.88 1872.12 5.0 0.5 1342.83 1368.00 GOOD 5760.00 3671.49 1872.88 1872.12 15.0 1.0 982.49 1324.00 GOOD 5760.00 3671.49 1872.88 1872.12 15.0 1.0 1203.69 1324.00 GOOD 5760.00 3671.49 1872.88 1872.12 5.0 0.5 1557.66 1589.00 GOOD 34 5750.00 3662.83 1867.02 1869.80 15.0 1.0 1324.00 GOOD 5750.00 3662.83 1867.02 1869.80 15.0 1.0 1324.00 GOOD 5750.00 3662.83 1867.02 1869.80 5.0 0.5 LOST SEAL 35 5743.00 3656.76 1863.77 1866.31 15.0 1.0 1012.80 1324.00 GOOD 5743.00 3656.76 1863.77 1866.31 15.0 1.0 1245.74 1324.00 GOOD 36 5736.00 3650.69 1860.57 1861.04 15.0 1.0 937.00 1323.00 GOOD 5736.00 3650.69 1860.57 1861.04 15.0 1.0 LOST SEAL 37 5735.00 3649.83 1860.28 1858.28 2.0 0.3 1493.81 1522.00 GOOD 5735.00 3649.83 1860.28 1858.28 15.0 1.0 699.37 1322.00 GOOD 38 5722.00 3638.56 1853.28 1854.36 15.0 1.0 LOST SEAL 5722.00 3638.56 1853.28 1854.36 15.0 1.0 LOST SEAL 39 5723.00 3639.42 1854.88 1854.78 15.0 1.0 LOST SEAL 40 5666.00 3590.00 1827.44 1829.15 15.0 1.0 LOST SEAL 41 5665.00 3589.14 1828.84 1828.44 15.0 1.0 764.49 1554.00 GOOD 5665.00 3589.14 1828.84 1828.44 15.0 1.0 1240.91 1554.00 GOOD 64 5542.00 3482.45 1773.19 1772.97 5.0 0.5 1267.40 1306.12 GOOD 5542.00 3482.45 1773.19 1772.97 15.0 1.0 775.00 1525.72 GOOD 65 5522.00 3465.10 1763.23 1763.81 5.0 0.5 1255.98 1292.88 GOOD 5522.00 3465.10 1763.23 1763.81 15.0 1.0 788.80 1498.12 GOOD 66 5514.00 3458.16 1759.66 1759.63 5.0 0.5 1281.09 1326.89 GOOD 5514.00 3458.16 1759.66 1759.63 15.0 1.0 LOST SEAL 5514.00 3458.16 1759.66 1759.63 15.0 1.0 477.35 1135.36 ?GOOD? 67 5512.00 3456.42 1758.37 1757.84 5.0 0.5 972.98 1001.31 GOOD 5512.00 3456.42 1758.37 1757.84 15.0 1.0 479.15 1657.93 GOOD 68 5455.00 3406.97 1732.86 1732.10 5.0 0.5 908.62 1476.14 GOOD 5455.00 3406.97 1732.86 1732.10 15.0 1.0 488.05 1475.29 GOOD 69 5327.00 3295.90 1677.00 1676.00 5.0 0.5 821.85 1489.46 GOOD • 70 5287.00 3261.18 1656.00 1657.00 5.0 0.5 821.85 1487.13 GOOD 5287.00 3261.18 1656.00 1657.00 15.0 1.0 435.74 1482.85 GOOD 71 5232.00 3213.45 1631.00 1632.00 5.0 0.5 797.35 LOST SEAL 5232.00 3213.45 1631.00 1632.00 5.0 0.5 781.29 1474.60 GOOD 72 5217.00 3200.44 1624.00 1623.00 5.0 0.5 845.98 1355.67 GOOD 73 5188.00 3175.29 1615.00 1619.00 5.0 0.5 756.58 790.19 GOOD 5188.00 3175.29 1615.00 1619.00 15.0 1.0 353.91 370.59 GOOD 74 5191.00 3177.89 1621.00 1619.00 5.0 0.5 755.00 1527.00 GOOD • 42 5660.00 3584.80 1825.87 1826.08 15.0 1.0 865.72 1554.00 GOOD 5660.00 3584.80 1825.87 1826.08 15.0 1.0 1090.30 1554.00 GOOD 43 5640.00 3567.45 1816.16 1817.30 15.0 1.0 842.40 1554.00 GOOD 5640.00 3567.45 1816.16 1817.30 15.0 1.0 933.49 1551.00 GOOD 44 6392.00 4220.24 2156.48 2150.88 5.0 0.5 1450.52 2037.00 GOOD 6392.00 4220.24 2156.48 2150.88 15.0 1.0 LOST SEAL 45 6390.00 4218.50 2149.88 2149.75 15.0 1.0 812.40 TIGHT TEST 6390.00 4218.50 2149.88 2149.75 5.0 0.5 LOST SEAL 46 6385.00 4214.15 2147.34 2146.72 5.0 0.5 1406.57 TIGHT TEST 6385.00 4214.15 2147.34 2146.72 15.0 1.0 784.28 TIGHT TEST 47 6374.00 4204.58 2141.50 2142.51 2.0 0.5 1750.69 TIGHT TEST 6374.00 4204.58 2141.50 2142.51 5.0 0.5 1367.65 TIGHT TEST • 6374.00 4204.58 2141.50 2142.51 15.0 1.0 764.14 TIGHT TEST 48 6392.00 4220.24 2157.95 2157.56 5.0 0.5 153.15 2065.84 GOOD 49 6385.00 4214.15 2153.57 2152.65 5.0 0.5 126.84 219.35 TIGHT TEST 50 6374.00 4204.58 2146.43 2145.54 5.0 0.5 112.97 2129.98 LOST SEAL LATE 51 6356.00 4188.93 2136.86 2137.61 5.0 0.5 92.96 125.01 LOST SEAL 6356.00 4188.93 2136.86 2137.61 5.0 0.5 87.87 99.13 TIGHT TEST 52 6358.00 4190.67 2138.86 2138.25 5.0 0.5 685.43 1968.11 GOOD 53 6336.00 4171.55 2127.16 2128.26 5.0 0.5 165.70 2027.98 GOOD 6336.00 4171.55 2127.16 2128.26 5.0 0.5 LOST SEAL 54 5904.00 3796.33 1943.78 1939.61 5.0 0.5 534.68 1398.58 GOOD 5904.00 3796.33 1943.78 1939.61 15.0 1.0 846.08 1398.50 GOOD 55 5895.00 3788.52 1932.40 1932.92 5.0 0.5 203.79 1383.64 GOOD 56 5887.00 3781.58 1928.64 1928.71 5.0 0.5 390.88 1379.46 GOOD 5887.00 3781.58 1928.64 1928.71 15.0 1.0 503.68 1374.95 GOOD 57 5876.00 3772.04 1923.19 1923.37 5.0 0.5 971.19 1361.81 GOOD 5876.00 3772.04 1923.19 1923.37 5.0 0.5 1212.29 1290.21 GOOD 5876.00 3772.04 1923.19 1923.37 15.0 1.0 924.74 1356.75 GOOD 58 5869.00 3765.97 1919.95 1920.16 5.0 0.5 1294.30 1333.53 GOOD 5869.00 3765.97 1919.95 1920.16 15.0 1.0 972.77 1344.68 GOOD 59 5865.00 3762.50 1918.05 1917.43 5.0 0.5 1319.92 1359.06 GOOD 5865.00 3762.50 1918.05 1917.43 15.0 1.0 994.62 1343.37 GOOD 60 5860.00 3758.16 1915.22 1915.77 5.0 0.5 1264.55 1309.34 GOOD 5860.00 3758.16 1915.22 1915.77 15.0 1.0 719.57 1340.81 GOOD 61 5722.00 3638.56 1852.18 1855.02 5.0 0.5 1283.89 1320.76 GOOD 5722.00 3638.56 1852.18 1855.02 15.0 1.0 774.43 806.35 GOOD 62 5723.00 3639.41 1855.22 1852.80 5.0 0.5 1301.17 1339.79 GOOD 5723.00 3639.41 1855.22 1852.80 15.0 1.0 784.45 966.88 GOOD 63 5549.00 3488.52 1778.57 1776.81 5.0 0.5 1251.45 1289.17 GOOD 5549.00 3488.52 1778.57 1776.81 15.0 1.0 773.36 1528.08 GOOD • 0 Marathon - Susan Dionne #6 FORMATION TESTER TEST SUMMARY Test Hyd Pres Hyd Pres Tool Flow Drawdown Final Shut - No. Depth TVD Before After Volume Rate Press in Press Remarks 1 6034.00 3909.18 2005.76 1996.26 5.0 0.5 LOST SEAL 2 6032.00 '907.44 1997.24 1997.97 5.0 0.5 LOST SEAL 6032.00 47.44 1997.24 1997.97 5.0 0.5 LOST SEAL © 601 601 - Mil 4 5994.00 3874.- . 1976.79 1977.60 5.0 0.5 185.96 1734.00 GOOD 5 5980.00 3862.2 1969.91 1970.95 5.0 0.5 378.85 1659.00 GOOD 6 5955.00 3840.59 1958.24 1959.68 5.0 0.5 377.76 1407.00 GOOD 7 5945.00 3831.91 ' 954.23 1955.39 5.0 0.5 LOST SEAL 8 5944.00 3831.04 '.4.47 1954.27 5.0 0.5 349.60 1416.00 GOOD 9 5938.00 3825.83 19 0.83 1951.59 5.0 0.5 317.48 1403.00 GOOD 10 5931.00 3819.75 194 •8 1948.12 5.0 0.5 851.78 1398.00 GOOD 11 5924.00 3813.68 1944..: 1944.84 5.0 0.5 339.55 1396.00 GOOD 12 5916.00 3806.74 1940.4• 1940.96 5.0 0.5 368.62 1394.00 GOOD 5904.00 3796.33 934.43 ' • 934.65 15.0 1.0 LOST SEAL 14 5906.00 3798.06 1936.91 '36.10 5.0 0.5 822.88 1388.00 GOOD 5906.00 3798.06 1936.91 19 ..10 15.0 1.0 1110.44 1388.00 GOOD 15 5907.00 3798.93 1937.09 193:65 5.0 0.5 801.80 1389.00 GOOD 16 5890.00 3784.18 1927.39 1928. I 5.0 0.5 1018.34 1381.00 GOOD , 5890.00 3784.18 1927.39 1928.4t, 15.0 1.0 938.54 1374.00 GOOD 17 5868.00 3765.11 1917.39 1919.18. 5.0 0.5 1212.07 1239.00 GOOD 5868.00 3765.11 1917.39 1919.18 15.0 1.0 946.07 1344.00 GOOD 18 5866.00 3763.37 1917.96 1919.34 5.0 0.5 1292.84 1322.00 GOOD 5866.00 3763.37 1917.96 1919.34 ..0 1.0 745.64 1333.00 GOOD 19 5860.00 3758.16 1916.08 1916.69 . 4 0.5 1265.63 1288.00 GOOD 5860.00 3758.16 1916.08 1916.69 15.4, 1.0 1000.50 1329.00 GOOD CA 20 5858.00 3756.44 1915.66 1915.58 5.0 0.5 1304.67 1336.00 GOOD 5858.00 3756.44 1915.66 1915.58 15.0 1.0 978.56 1341.00 GOOD 21 5850.00 3749.49 1911.64 1911.94 5.0 0.5 1327.37 1351.00 GOOD W ' . 5850.00 3749.49 1911.64 1911.94 15.0 1.0 839.25 1330.00 GOOD �"j; 22 5842.00 3742.56 1908.15 1906.04 5.0 '.5 1290.75 1317.00 GOOD O 1, 5842.00 3742.56 1908.15 1906.04 15.0 0 907.68 1331.00 GOOD 1 23 5831.00 3733.03 1902.45 1903.10 5.0 0: ` 1036.75 1064.00 GOOD 24 5829.00 3731.29 1902.85 1902.02 5.0 0.5 1 1099.30 1328.00 GOOD 5820.00 3723.50 1897.86 1897.91 15.0 1.0 ' 004.13 1329.00 GOOD 26 5810.00 3714.83 1893.60 1893.46 5.0 0.5 1 •3.56 1211.00 GOOD 5810.00 3714.83 1893.60 1893.46 15.0 1.0 10 .62 1329.00 GOOD 27 5800.00 3706.16 1888.37 1888.75 4.0 0.5 131 9 1336.00 GOOD 5800.00 3706.16 1888.37 1888.75 5.0 1.0 1187.- 1230.00 GOOD 5800.00 3706.16 1888.37 1888.75 15.0 1.0 913.6. 1329.00 GOOD 5800.00 3706.16 1888.37 1888.75 30.0 1.0 LOST SEAL 28 5800.00 3706.16 1902.06 1894.24 5.0 0.5 1193.70 1317.00 GOOD 5800.00 3706.16 1902.06 1894.24 15.0 1.0 1149.61 27.00 GOOD 5800.00 3706.16 1902.06 1894.24 30.0 1.0 1213.98 1 '8.00 GOOD 29 5792.00 3699.23 1889.81 1890.05 5.0 0.5 1300.32 13 '.00 GOOD 5792.00 3699.23 1889.81 1890.05 15.0 1.0 922.75 1326. 40 GOOD 30 5775.00 3684.50 1881.40 1881.45 5.0 0.5 1335.44 1361.0' GOOD 5775.00 3684.50 1881.40 1881.45 15.0 1.0 819.66 1307.00'. GOOD 5775.00 3684.50 1881.40 1881.45 5.0 0.5 LOST SEAL 31 5773.00 3682.76 1880.55 1880.00 5.0 0.5 1303.18 1328.00 \ GOOD 5773.00 3682.76 1880.55 1880.00 15.0 1.0 1100.94 1323.00 4 •, GOOD 32 5765.00 3675.83 1875.09 1875.57 5.0 0.5 1330.20 1354.00 GOOD 5765.00 3675.83 1875.09 1875.57 15.0 1.0 1016.53 1324.00 GOOD 33 5760.00 3671.49 1872.88 1872.12 5.0 0.5 1342.83 1368.00 GOOD f 5760.00 3671.49 1872.88 1872.12 15.0 1.0 982.49 1324.00 GOOD l 5760.00 3671.49 1872.88 1872.12 15.0 1.0 1203.69 1324.00 GOOD • 42 5660.00 584.80 1825.87 1826.08 15.0 1.0 865.72 1554.00 GOOD 5660.00 84.80 1825.87 1826.08 15.0 1.0 1090.30 1554.00 GOOD 43 5640.00 .7.45 1816.16 1817.30 15.0 1.0 842.40 1554.00 GOOD 5640.00 35: .45 1816.16 1817.30 15.0 1.0 933.49 1551.00 GOOD 44 6392.00 422* 4 2156.48 2150.88 5.0 0.5 1450.52 2037.00 GOOD 6392.00 4220..+ 2156.48 2150.88 15.0 1.0 LOST SEAL 45 6390.00 4218.51\ 2149.88 2149.75 15.0 1.0 812.40 TIGHT TEST 6390.00 4218.50 ', 2149.88 2149.75 5.0 0.5 LOST SEAL 46 6385.00 4214.15 \' 147.34 2146.72 5.0 0.5 1406.57 TIGHT TEST 6385.00 4214.15 ' , 7.34 2146.72 15.0 1.0 784.28 TIGHT TEST 47 6374.00 4204.58 `. .50 2142.51 2.0 0.5 1750.69 TIGHT TEST 6374.00 4204.58 0 2142.51 5.0 0.5 1367.65 TIGHT TEST 48 6392.00 4220.24 2157.9 1 2157.56 5.0 0.5 153.15 2065.84 GOOD 49 6385.00 4214.15 2153.57 2152.65 5.0 0.5 126.84 219.35 TIGHT TEST 50 6374.00 4204.58 2146.43 •145.54 5.0 0.5 112.97 2129.98 LOST SEAL LATE 51 6356.00 4188.93 2136.86 , 37.61 5.0 0.5 92.96 125.01 LOST SEAL 6356.00 4188.93 2136.86 21 \7.61 5.0 0.5 87.87 99.13 TIGHT TEST 52 6358.00 4190.67 2138.86 2138.25 5.0 0.5 685.43 1968.11 GOOD 53 6336.00 4171.55 2127.16 2128... 5.0 0.5 165.70 2027.98 GOOD 6336.00 4171.55 2127.16 2128.2. 5.0 0.5 LOST SEAL 54 5904.00 3796.33 1943.78 1939.61 5.0 0.5 534.68 1398.58 GOOD �_ . �_:_ u �� __ _ � .. � � , ._ mat. Y om..___ , _ _ _ ` GOOD. 55 5895.00 3788.52 1932.40 1932.92 , 5.0 0.5 203.79 1383.64 GOOD O GOOD 5887.00 3781.58 1928.64 1928.71 1 1 1.0 503.68 1374.95 GOOD 57 5876.00 3772.04 1923.19 1923.37 5.1 0.5 971.19 1361.81 GOOD re 5876.00 3772.04 1923.19 1923.37 5.0 0.5 1212.29 1290.21 GOOD W 5876.00 3772.04 1923.19 1923.37 15.0 1.0 924.74 1356.75 GOOD O 58 5869.00 3765.97 1919.95 1920.16 5.0 0.5 1294.30 1333.53 GOOD M , 5869.00 3765.97 1919.95 1920.16 15.0 1.0 972.77 1344.68 GOOD _".. ,. f 59 5865.00 3762.50 1918.05 1917.43 5.0 1.5 1319.92 1359.06 GOOD 5865.00 3762.50 1918.05 1917.43 15.0 1.1 994.62 1343.37 GOOD 60 5860.00 3758.16 1915.22 1915.77 5.0 0. 1264.55 1309.34 GOOD 5860.00 3758.16 1915.22 1915.77 15.0 1.0 719.57 1340.81 GOOD 61 5722.00 3638.56 1852.18 1855.02 5.0 0.5 1283.89 1320.76 GOOD 5722.00 3638.56 1852.18 1855.02 15.0 1.0 774.43 806.35 GOOD 62 5723.00 3639.41 1855.22 1852.80 5.0 0.5 ' 301.17 1339.79 GOOD 5723.00 3639.41 1855.22 1852.80 15.0 1.0 :4.45 966.88 GOOD 63 5549.00 3488.52 1778.57 1776.81 5.0 0.5 12' 1.45 1289.17 GOOD 5549.00 3488.52 1778.57 1776.81 15.0 1.0 773.16 1528.08 GOOD 64 5542.00 3482.45 1773.19 1772.97 5.0 0.5 1267. , 1 1306.12 GOOD 5542.00 3482.45 1773.19 1772.97 15.0 1.0 775.00 1525.72 GOOD 65 5522.00 3465.10 1763.23 1763.81 5.0 0.5 1255.98 1292.88 GOOD 5522.00 3465.10 1763.23 1763.81 15.0 1.0 788.80 k1498.12 GOOD 66 5514.00 3458.16 1759.66 1759.63 5.0 0.5 1281.09 n 26.89 GOOD 5514.00 3458.16 1759.66 1759.63 15.0 1.0 LOST SEAL 5514.00 3458.16 1759.66 1759.63 15.0 1.0 477.35 11 •.36 ?GOOD? 67 5512.00 3456.42 1758.37 1757.84 5.0 0.5 972.98 1001. 1 GOOD 5512.00 3456.42 1758.37 1757.84 15.0 1.0 479.15 1657.• GOOD 68 5455.00 3406.97 1732.86 1732.10 5.0 0.5 908.62 1476.14\ GOOD 5455.00 3406.97 1732.86 1732.10 15.0 1.0 488.05 1475.29 GOOD 69 5327.00 3295.90 1677.00 1676.00 5.0 0.5 821.85 1489.46 GOOD 70 5287.00 3261.18 1656.00 1657.00 5.0 0.5 821.85 1487.13 \ GOOD 5287.00 3261.18 1656.00 1657.00 15.0 1.0 435.74 1482.85 , GOOD 71 5232.00 3213.45 1631.00 1632.00 5.0 0.5 797.35 LcST SEAL 72 5217.00 3200.44 1624.00 1623.00 5.0 0.5 845.98 1355.67 GOD e • 15,00 x la ;N _` ' 000 74 5191.00 3177.89 1621.00 1619.00 5.0 0.5 755.00 1527.00 GOOD • ( A#1 1 Marathon Operations Summary Report ) Oil Company Well Name: SUSAN DIONNE 6 otr1Qtr,Akck, Sec, TODUi,Raige FpgName Lie No. Stap/Prculice Conti SEC 6, T 1S, R 13W NINILCHIK - SUSAN DIONNE 208 -160 ALASKA USA Caalig Ftaige Eieatim pp G col idEkletbi (7ti KB-Cashg Flaig4 Dbstaice (rg KB-Growl istabce ® Spud Dap Rlg Release Dap 135.00 21.00 1116/2006 Daily Operations Report Date: 11/3/2008 Job Category: DRILLING 24 H r Summary MIRU GD -1 opa Slartrme Eid Tine Our a rfl opaCate &ILI/Cale Stada Trouble Cock Came it 00:00 06:00 6.00 MOB RIG AF MIRU GD -1 , PJSM; Cont. to MOB rig, Remove walkways between camps, set mats for pit trailer, set down boards for trucks to get onto mats, put wings up on sub base, preb inside of sub for road, prep parts house, mech. shop to move. Report Date: 111442008 Job Category: DRILLING 24Hr Simmary MIRU GD -1 ova - L— StartTme EsdTrne D ¢ra) opaCOle Actlirkf Cock Sods Trouble Cale Come it 06:00 12:00 6.00 MOB RIG AF PJSM; Move pits, and load out, Gen. and boiler house, Prep rig camp to move.Load out welding shop. 12:00 00:00 12.00 MOB RIG AF PJSM; Spot Gen. house, boiler, water house, hanson tank, and rig up,PJSM: Set Fuel tank with crane. Move in spot and scope up sub base, and mud boat, Move in and spot, pump and pit houses, pull pits together, pull wires, to pump, and pit house, Put lights around rig, Set up yard lights, put carrier on mud boat, set carrier on pedistals,level carrier to raise derrick. 00:00 06:00 6.00 MOB RIG AF PJSM; Raise mast to sub. pull wires to carrier and plug in, set in trip tank, PJSM: For Crane Operations set landings and stairs to pits and carrier, set drillers side gray iron. Doghouse and Choke house. Set windwalls. Report Date: 11'5/2008 Job Category: DRILLING 24 H r Summary MIRU GD -1 Mipple up divertor opa L— StartTine EidTine Dur(I rsr oppcOde AcajIVCO/e Soda Troube Came it 06:00 14:00 6.00 RURD RIG AF Continue Rig up GD -1 , RN HP mud lines. Scope up mast. Set guy wires. Set #3 mud pump and cuttings tank. Rig up pits. Set catwalk. and stairs from conex to rig floor. Run water I, electrical and steam lines. Set Beaver Slide. 14:00 14:30 0.50 SAFETY MTG AF Hold safety stand down with Tom Kloberdanz I CH2m Hill and #1 production operator . Discuss safety issues with Construction operations and Drilling operations on same pad. 14:30 00:00 9.50 RURD RIG AF Set stand by generator, MWD cabin and Epoch unit.PJSM: RAJ torque tube and install in mast, bring on freshwater, fire boiler, drop steam hose in cellar ,to melt ice, close up cellar and warm it up ,rig up pump #3, mud line, shock hoses. 00:00 06:00 6.00 NUND DOPE AF PJSM; With vetco grey service hand, Cut 20" conductor and dress off, set in 20" X 21 114" SLC, 2M flanged starting head and test to 340 psi for 10 min. no leaks, Rig up derrick board.Rigging up floor while working on divertor. Report Date: 11/6/2008 Job Category: DRILLING 24 H r Summary NN diverter system. Install flow nipple & flow line. Mix spud mud. RN Epoch & MdVD cabins. Install stand pipe manifold. CIO top drive saver sub. C1O grabber dies & bell guide. Check C.O.M. Test diverter system. (Witness waived by Jim Regg - AOGCC on 1114.2008 @ 09:29 hrs). Test gas, PVT & flow alarms. Perform rig audit. Test run mud pumps & top drive. Set pipe racks & load w/ 5" dp & hwdp. Strap, drift, pick up & stand back 5" dp & hwdp. PN directional BHA #1. ops L— Start EidTine Dur (bra) ops Code AottirWCMe Slat's Troubie Cole Commit 06:00 16:00 12.00 NUND DOPE AF PJSM: Continue to NM diverter system. Install 16" knife valve and 75' of 16" diverter line. Install flow nipple and flow line. run lines to trip tank. 18:00 22:00 4.00 RURD PIPE AF PJSM: Mix spud mud, RNLI epoch ,MWD cabin and run lines. Install stand pipe manifold. Change out top drive saver sub from HT -38 to 4 1/2 if. C/O grabber dies & bell guide. Check C.O.M. 22:00 23:00 1 .00 TEST ROPE AF PJSM: Function test diverter system. Test gas alarms, PVT & flow.Preform Accumulator draw down test.Test witness waived by Jim Regg (AOGCC) on 11/412008 09:29 hrs. 23:00 00:00 1 .00 INSPCT RIG AF PJSM: Perform general rig condition audit. Test run mud pumps & top drive. Troubleshoot throttle on #2 carrier engine. 00:00 05:00 5.00 PULD DP AF PJSM: Set & load pipe racks w/ 42 jts 5" dp, 21 jts 5" hwdp & 6-1/4" jars. Strap, drift, m/u & stand back total 32 stds. 05:00 06:00 1 .00 PULD BHA AF PJSM: PN 12-1/4" bit, mud motor, string stab, pony collar & MWD. www.peloton.com Report Printed: 12/31/2008 l • O T Marathon Operations Summary Report t Oil Company Well Name: SUSAN DIONNE 6 Cat lig Fblge Eklaiti (p GrouliEle a (p KBGaslig FLoge Dlabice ® KO-Growl 0Atm* (1p Spill Oak Rig Release Dap 135.00 21.00 11/6/2008 Caslig Fmlge Eklatbl (p Grould Elelatbl (lp KB- Caslig Ftaige 0Mc* in I43 -G roUId DL Ice Op Spud Dap Rg Re lease Dap 135.00 21.00 11/6/2008 Daily Operations Report Date: 111712008 Job Category: DRILLING 24 H r Summary M1J 12 -114" directional BHA. Fill hole & check for leaks. Spud well 08:00 hrs. Drill 12 -114" hole fi 101' -112'. Clean out packed off flowline. Drill f1112' -129'. Clean out packed off flowline. Drill f1129' -131'. Troubleshoot fuel problem on carrier. Drill 131' -421'. O p t StartTiae EldTine Durprs) Ops Code A,c1LIF,(COde Scads TroubkCaie Come it 06:00 08:00 2.00 PULD BHA AF Cony picking up 12 -114" bit, mud motor, string stab, pony collar & MdVD. 08:00 09:00 1 .00 DRILL ROT AF PJSM: Fill hole & check for leaks. Spud 12 -114" hole Cca 08:00 hrs.. Drill f1 101' -112' @ 385 gpm w1390 psi, 50 rpm, wob 0 -5 klbs. Flowline plugged up with .ravel. ART: 0.5 hrs. 09:00 12:00 3.00 CIRC MUD TA MSFL PJSM: Circulate slow in attempt to clean out flowline. No go. Stop pumping to clean out flowline & extention. 12:00 14:00 2.00 DRILL ROT AF Drill 12 -114" vertical hole fl 112' -129'. Flowline plugged up with gravel. ART: 0.4 hrs. 14:00 17:30 3.50 PULL EQIP TA MSFL PJSM: Remove flowline & extention. Suck out gravel w1 2" vac truck hose. Replace extention & put flowline back together. Replaced rosemount throttle control on carrier #2 engine while working on flowline. 17:30 18:00 0.50 DRILL ROT AF Drill 12 -114" vertical hole f1129' -131'. ART: 0.1 hrs. Lost power from carrier. 18:00 19:30 1.50 REPAIR RIG TA MSPW Troubleshoot fuel system on carrier. Found valve partially closed from rig fuel tank to carrier day tank. Reprime engines. 19:30 00:00 4.50 DRILL ROT AF Drill 12 114 vertical hole f/131'- 1,94'. Beqinkick -off w /S00psi,S0rpm, wob 5- 10klbs tq 1- 2kft- Ibs,plu45klbs slo 40klbs, rot wt. 42klbs. ART =1 .70hrs, AST = 0.4hrs. No gains or losses 00:00 06:00 6.00 DRILL ROT AF PJSM: Drill 12 114 build section ff224- 421'@rn 414gpm w1600psi, 50rpm, wob 0 -5 klbs tq 1- 2kft -Ibs, plu 45klbs, sib 40klbs, rot wt.42klbs, ART:1.0hrs AST 1 .4hrs. No pains or losses Report Date: 11/812008 Job Category: DRILLING 24 H r Summary Drill 12 -114" directional hole ft 421'- 1673'. Repair leak in standpipe. Opt StartTlne EidTlne our Ops Code A,ctillfcoda St-rhs Trouble Cole Come lit 06:00 12:00 6.00 DRILL ROT AF Drill 12 114 hole f1421' -740' S60gpm 1000psi 50rpm wob 1 -6klbs tq -1 -2 kft-lbs S4klbs,slo 48klbs rt wt.S1 klbs. AR.T =1 .0hrs AST= 2.6hrs. No gain losses. Mud wt. 8.8. Vis 95. Pump #3 on line at 0900hrs. 12:00 18:00 6.00 DRILL ROT AF Drill 12 114 hole ff740'- 1158' S60gpm 1125psi 50rpm wob 5 -1 Oklbs tq 3 -4kft -Ibs p1u 64klbs sbo 55k1;bs,rt.wt.57klbs. AST =1 .6hrs ART= 2.3hrs No Gain losses 18:00 00:00 6.00 DRILL ROT AF PJSM: Drill 12 -114" build section f11158' -1455' @ 555 gpm, 1250 psi, wob 5 -25 klbs, 55 rpm, tq 3 -6 kft-Ibs, p1u 65 klbs, ski 56 klbs, rot wt 61 klbs. ART: 1 .3 hrs., AST: 2.6 hrs. No gains or losses. 00:00 05:30 5.50 DRILL ROT AF PJSM: Drill 12 -114" build section f11455' -1673' ( 555 gpm, 1550 psi, wob 10 -25 klbs, 50 rpm, tq 5 -6 kft -Ibs, plu 66 klbs, ski 57 klbs, rot wt 61 klbs. ART: 1 .0 hrs., AST: 2.3 hrs. No gains or losses. 05:30 06:00 0.50 RURD PIPE TA MSFL Repair leaking 4" seal in 1002 union at bottom of standpipe. Report Date: 11/912008 Job Category: DRILLING 24 H r Summary Repair leak in standpipe. Drill 12 -114" hole f11673'- 2031'. Circulate hole clean. Make wiper trip f12031' -303'. RIH to 1975'. Wash down f11975'- 2031'. Circ hi -vis nut plug pill to caliper hole & can't circ until clean. POOH 8, lay down directional BHA. Clear rig floor. RIU & run 9 -518" casing to 525'. o p s StartTVe EldTine Ourprs) opa Cale AuMplycode aids Trouble Cock Commit 06:00 07:00 1 .00 RURD PIPE TA MSFL Repair leaking 4" seal in 1 002 union at bottom of standpipe. 07:00 12:30 5.50 DRILL ROT AF Drill 12 -114" hole fl 1673'- 2031' S60gpm 16S0psi 50rpm wob 1535kIbs tq 5-6kft-lbs. plu 70klbs ski S8klbs rt. wt. 62klbs ART =1.5 AST= 1 .8 No gain ! loss. max gas 46units. TAD of surface section 2031' at 12:30hrs 11 -8 -06. 23.Shrs drilling time for surface hole section 86.42fph avq. 12:30 13:30 1 .00 CIRC MUD AF Circulate and condition mud for wiper trip t S6Sgpm 1450psi. rotary 50rpm. Circulate BJU. continue circulating untill shakers clean up 13:30 1 7:30 4.00 TRIP WNPR AF Monitor well Orient motor to high side of hole POH SLM( wiper Trip) ff2031' -303' no over pulls or tight spots up to 456'. work bha through boulders and clean up. rih F- 303' TO 1975" Hole slick Precautionary wash f -1976 to 2031' Tag bottom, no fill Note: no correction to SLM www.peloton.com Report Printed: 1213112008 I • SA Marathon Operations Summary Report " t Oil Company Well Name: SUSAN DIONNE 6 °pis L_ SOrtTrne Erd Tine Drr(1rs) Opt Code Ac1LiVCc. Ana Trouble Cock Ccemert 17:30 19:00 1.50 CIRC MUD AF Circ. Pump30bbl nut plug/hi vis sweep for hole volume fluid caliper Pump at 565gpm 1450psi . Sweep returned at 5950stks calculated hole volume. Continue circulating until shakers clean up. 19:00 21:30 2.50 TRIP DP AF Monitor well, POH f 2031' to run 9 518 casing. Hole slick. No overpull. No gains or losses. 21:30 00:00 2.50 PULD BHA AF PJSM: Lay down shock sub, (3) crossover subs, (3) NMDC's, MAD, pony collar, string stab, mud motor & 12 -114" bit. 00:00 00:30 0.50 BAIL FILL AF PJSM: Clear & clean rig floor. 00:30 04:00 3.50 RURD CSG AF PJSM: Rig up to run 9 -518" casing. C/O elevators, bails & tongs. Make up EZ turn on swedge & function (OK). Rig up stabbing board & Weatherford power tongs. 04:00 06:00 2.00 RUN CSG AF PJSM w/ Weatherford casing crew: NU 9 -518" casing and Baker loc shoe track(3 jts) & check floats (ok). Cont RIH w19 -5/8 ", 40 ppf, L -80, BTC casing to 525'. Ran 13 of 50 total jts @ 06:00 hrs. Daily Operations Report Date: 1111012008 Job Category: DRILLING 24 HrSlmmav Run 9 -518" csg to 1130'. Wash down to 1172'. CBU. Cont run csg to 2030.5'. Ciro while reciprocate pipe. Conduct PJSM for cmt job. Pump 20 spacer. Test cmt lines to 2000 psi. Pump 217 bbls cmt. Pull pin on plug dropping assembly to manually drop upper wiper plug. Displace cmt w1148 bbls mud & bump plug as calculated. RAD cmt head. Blow down mud lines & cmt line. Flush stack. NrD diverter line & knife valve. Hot bolt stack. Empty & clean pits. Make rough cut on 9 -5/8" csg & lay down stump. NOD diverter stack. Retrieve starter head. Make final cut & dress 9 -518" csg. ops L_ sartTtne Ertl Time Drr(1rs) Ops cc.e MUM/Cock Stalls Troth* Cock Canmeit 06:00 10:30 4.50 RUN CSG AF Cont RIH w19- 518 ", 40 ppt. L -80, BTC casing to 1130' Wash down and clean up bridge to 1170' Continue running 9 513 casing to 2030.5'. for a total of 50jts and 1- 18' casing pup jt. Total of 16ea. 9 5/8 bow spring centrailzers installed. 10:30 12:00 1 .50 CIRC MUD AF Rig up cmt head. Circulate & condition mud for cmt job @ 4.4 bpm wi 285 psi. Rig down stabbing board & casing tongs. 12:00 13:00 1 .00 PUMP CMT AF PJSM w1 BJ services: Break circ & pump 20 bbls Mud Clean II preflush w1 rig pump. Switch to BJ unit, pump 5 bbls water & test cmt lines to 2000 psi (ok). Drop bottom wiper plug. Mix & pump 490 sks Type 1 cmt wi 22% LW -6, 20% MPA -1 , 2% CaCl2, 1 % SMS, 0.3% CD -32, 0.05% Static Free, 1 ga11100 sks FP -6L, 12.0 ppg, 2.483 cu.ft.isk yield (217 bbls total cmt slurry), 10.328 gal waterlsk (120 bbls mixing water), 4:05 hrs thickening time. Attempt to kick out upper wiper plug. Valve to pin assembly stuck. 13:00 14:00 1 .00 REPAIR EQIP TA CPPL Pull upper plug dropping assembly from cmt head. Install 2" bull plug. 14:00 14:30 0.50 PUMP CMT AF Kick out upper wiper plug w15 bbls water. Switch to rig pumps & displace w1142.6 bbls drilling mud. Bumped plug @ calculated strokes w/ 800 psi over displacement pressure. Bleed off pressure & check floats (ok). Cement in place @ 14:30 hrs on 1119/2008. Float shoe set @ 2030.5, top of float collar set @ 1945.5. Pumped total of 217 bbls cmt & got 71 bbls excess back to surface. 100% returns. Note: reciprocated pipe until 89 bbls displaced. 14:30 15:00 0.50 CLEAN TANK AF PJSM: RID cmt head. Blow down cmt & mud lines. Flush stack. 15:00 00:00 9.00 NUND BOPE AF PJSM: NaD diverter line & knife valve. Hotbolt diverter stack. Empty & clean pits. Heat mix water. Clean up cellar. WOC 00:00 06:00 6.00 NUND BOPE AF Ri1J & make rough cut on 9 -518" csg. Lay down stump. RAD diverter stack & set in rack. Retrieve starter head. Make final cut on 9 -518" csg to install wellhead. Report Date: 1111112008 Job Category: DRILLING 24 H r Summary Install multibowl wellhead & test to 2400 psi ff10 min. Mix new 9.0 ppg fio -pro mud system. NM & test BOPE to 250/2000 psi ff 5 min (test witness waived by Bob Noble -AOGCC on 1119/88 @ 1530 hrs). Test 9 -518" csg to 1500 psi f130 min. NU 8-1/2" slick rotary drill out assy. RIH while plu 40 jts 5" dp. DID cmt & float equip f/ 1945- 2031'. Drill 20' new hole f/ 2031'- 2051'. ore SartTtne Ertl Time DIr(1rs) CpsCc.e A.ctlllycOtle Stills TrorbkCock Came it 06:00 07:00 1 .00 NUND WLHD AF Set MB 235 well head and nipple up. Test void to 2400psi f110min. test good. Mix new Flow -pro mud 07:00 16:00 9.00 NUND EQIP AF Nipple up BOP. Set 11" X 13 5/5 DSA. Set in BOP stack and nipple up. Rig up trip tank lines,Riser, choke and Kill lines. Install turn buckles and drip pan. Make up accumulator lines. Continue to mix 9.0ppq flow pro mud www.peloton.com Report Printed: 11212009 • • Marathon Operations Summary Report r� rnnla�, Oil Company Well Name: SUSAN DIONNE 6 Ops I_ SbrtTlne EndTlne Our Ors) Ops Code ActlurIveode Status TrorbleCode Comment 16:00 23:30 7.50 TEST BOPE AF Pe1J test joint set test plug. Test and all related components 250/2000 5min. Test Flow and system.Test LEL H2S alarms. Perform accumulator drawn test. Pull test plug lay down test joint. Called AOGCC ( Bob Noble 11 -9 -2008 15:30hrs VM tness waved). Note: Check valve leaked, replaced w1 new valve, retested (ok). CMV #7 leaked thru grease port, greased, retested (ok). Functioned lower pipe rams, no seal, refunction & retest (ok). 23:30 00:30 1.00 TEST CSG AF PJSM: Rig up & perform 9 -5/8" casing test to 1500 psi f130 min (ok). All while load pipe racks w1 5" drill pipe. 00:30 01:30 1 .00 PULD BHA AF PJSM: Make up & RIH w1 8 -1 /2" slick rotary cleanout assy & hwdp. 01:30 04:00 2.50 PULD DP AF PJSM: RIH wi picking up 40 its 5" drill pipe. Tag float collar @ 1945'. 04:00 05:30 1 .50 DRILL CMT AF Drill out float collar, cmt & float shoe f11945' -2031' @ 400 gpm & 85 rpm. 05:30 06:00 0.50 DRILL ROT AF Drill 20' new 8-1/2" hole f12031' -2051' @ 400 gpm WI 300 psi, 85 rpm, tq 5 kft-Ibs, wob 12 -20 klbs, plu 65 klbs, ski 45 klbs, rot wt 55 klbs. ART: 0.5 hrs. Daily Operations Report Date: 11/1212008 Job Category: DRILLING 24 H r Srmmary Ciro & displace hole w1 new 9.0 ppg flo -pro mud system. Perform FIT @ 1580' tvd (2031' md), w19.0 ppg mud & 490 psi. EMdV = 15.0 ppg. Monitor well. Pump dry job. POOH & rack back 20 stds 5" dp. RIH while p/u 40 its 5" dp. POOH & rack back 20 stds 5" dp. PN 26 jts 5" dp & stand back. POOH w111 stds 5" hwdp. LiD 8-1/2" bit & bit sub. RN BHI AutoTrak BPA unit. PN 8-1/2" ATK assy. Plug into ATK & verify coms. RIH wi 5" hwdp. Shallow test ATK (ok). Check interlocks on pumps 1, 2 & 3. Check grabber interlock. Blowdown mud lines. RIH while phi 34 its 5" dp. Break circ & wash down last std to btrn fl 1989'- 2051'. Drill 8-1/2' tangent hole w/ ATK Ti 2051' - 2295'. Ops - I_ St3rtTlne EldTlne D Ira rs) Ops Cole RcttirliCode Stads Trolble Cale Cement 06:00 07:00 1.00 CIRC MUD AF Circulate, Pump spacer sweep Displace hole with 9.0ppg Flow pro Mud. 800psi 400gpm 07:00 07:30 0.50 TEST LOT AF Perform Fit Test 9.0mw 493psi (a. 2031 MD/1580'TVD = 15ppq EM /V_ 07:30 08:30 1.00 TRIP DP AF Monitor well, Pump dry job, Blow down mud lines. POH (- 2051'- 08:30 15:00 6.50 PULD DP AF PJSM : PN its 140ts 5" drillpipe and stand back in mast . Stand back I-MDP 15:00 16:30 1.50 RURD OTHR AF PJSM: RN Autotrack bypass actuator unit (BPA), flow and bleed off lines 16:30 20:00 3.50 PULD BHA AF PJSM: PN 8-1/2" PDC bit & 6 -314" AutoTrak. Plug into AutoTrak tool to verify communication & initialize memory. PN filter sub, (2) crossover subs, float sub, string stab & (3) NMDC's. RIH will stds 5" hwdp & jars to 838'. 20:00 21:00 1.00 REPAIR RIG TA MSFL Check interlocks on mud pumps 1, 2 & 3. Check grabber interlock. 21:00 21:30 0.50 TEST EQIP AF Shallow test AutoTrak tool & bypass actuator unit (ok). 21:30 23:30 2.00 PULD DP AF RIH with AutoTrak assy while p/u 34 its 5" drill pipe f1838'- 1989'. 23:30 00:00 0.50 CIRC MUD AF Wash last std to bottom IT 1989' -2051' @ 328 gpm & 30 rpm. No fill. 00:00 06:00 6.00 DRILL ROT AF PJSM: Drill 8-1/2" tangent section wi ATK f12051' -2295' @ 457 gpm, 1000 psi, wob 10 -12 klbs, 60 rpm, tq 3 -4 kft -Ibs, OA 70 klbs, sic 49 klbs, rot wt 56 klbs. ART: 4.6 hrs. No gains or losses. Report Date: 111312008 Job Category: DRILLING 24 H r Sunman' Drill 8-1/2" hole f/ 2295'- 3498'. Ciro hole clean. Monitor well. POOH to 9 -5/88" csg shoe @ 2031'. Service rig. RIH to 3436'. Washdown f/ 3436'- 3498'. ops L_ STartTme ad Tine Du (its) ops Co k Actlirlvccde Slags Trouble Cale Comme 06:00 12:00 6.00 DRILL ROT AF Drill 8 -1 tangent hole w1 ATK (12295' -2675' ART =3.7 Pump =261 stks. flovv= 506gpm, 75 RPM, Bit wt.= 10 -12K, Gas =8 -10 units. Plu 70 klbs, sic' 45 klbs, rot wt 45 klbs. 12:00 18:00 6.00 DRILL ROT AF PJSM: Drill 8 -1/2" tangent section vv1 ATK f12675' -3055' @ 510 gpm, 1200 psi, wob 8 -12 klbs, 75 rpm, tq 5 -6 kft -Ibs, pfu 77 klbs, sic 47 klbs, rot wt 57 klbs. ART: 4.2 hrs. Max gas: 35 units, avg bkgnd gas: 12 units. No gains or losses. 18:00 00:00 6.00 DRILL ROT AF PJSM: Drill 8 -112" tangent section w/ ATK f/ 3055' -3498' @ 510 gpm, 1350 psi, wob 10 -12 klbs, 75 rpm, tq 5 -7 kft -Ibs, piU 77 klbs, sic 47 klbs, rot wt 58 klbs. ART: 4.3 hrs. Max gas: 237 units, avg bkgnd gas: 6 units. No gains or losses. 00:00 01:00 1 .00 CIRC MUD AF PJSM: CBU & cont circ until hole clean @ 530 gpm & 89 rpm. Plu 70 klbs, s/o 50 klbs, rot wt 58 klbs. Monitor well (static). Avg gas: 17 units. Note: Downlink AutoTrak to ribs -off mode (close ribs). 01:00 03:00 2.00 TRIP VV1PR AF PJSM: VM1per trip. POOH f13498'- 2031'. No tight spots. Hole slick. No gains or losses. 03:00 04:00 1.00 SERVIC RIG AF PJSM: Service rig, top drive & carrier. www.peloton.com Report Printed: 1/2/2009 • • • 't Marathon Operations Summary Report Oil Company Well Name: SUSAN DIONNE 6 ops Start Tine EldTtne Drr (Yrs) Ops Code ANIIIVCc. 4 Sbtts Trorble Code Canmeit 04:00 06:00 2.00 TRIP VNPR AF PJSM: RIH f/ 2031'- 3436'. Downlink AutoTrak to hold mode (turn ribs on). Wash last std down fI 3436'- 3498'. No ledges encountered. Hole slick. No gains or losses. Daily Operations Report Date: 11/1412008 Job Category: DRILLING 24 H r Summary Drill 8 -112" production hole section w/ AutoTrak assy 113498'- 5084'. ops L. SlartTne EYdTioe 1) 1r(irs) OW Cock AMLIwCade Slaps TroubleCc4 Commeit 06:00 12:00 6.00 DRILL ROT AF Drill 8 112 hole w /ATK f13498' -3906' @ 510gpm, 1400 psi, wob =8 -10, 75rpm, tq. =, Up wt. =87K Dn. wt =50K Rt. wt. =63K ART 4.4 Max. gas= 50, bkgd. gas =49 No gains, No losses 12:00 18:00 6.00 DRILL ROT AF PJSM: Drill 8 -112" drop section w/ ATK f13906' -4280' @ 506 gpm, 1300 psi, wob 10 -15 klbs, 75 rpm, tq 5 -7 kft -Ibs, p/u 93 klbs, sic 50 klbs, rot wt 67 klbs. ART: 3.7 hrs. Max gas: 91 units, avg bkgnd gas: 13 units, No connection gas. No gains or losses. 18:00 00:00 6.00 DRILL ROT AF Drill 8 -112" drop section w/ ATK f14280' -4720' @ 510 gpm, 1450 psi, wob 10 -15 klbs, 75 rpm, tq 5 -8 kft-Ibs, p1u 110 klbs, sic) 64 klbs, rot wt 74 klbs. ART: 3.7 hrs. Max gas: 76 units, avg bkgnd gas: 12 units, No connection gas. No gains or losses. 00:00 05:30 5.50 DRILL ROT AF PJSM: Drill 8 -1 tangent section w/ ATK f/ 4720' -5084' @ 510 gpm, 1700 psi, wob 10 -15 klbs, 75 rpm, tq 5 -8 kft -Ibs, p/u 120 klbs, s/o 68 klbs, rot wt 85 klbs. ART: 3.8 hrs. Max gas: 209 units, avg bkgnd gas: 16 units, No connection gas. No gains or losses. 05:30 06:00 0.50 CIRC MUD AF CBU & con/ circ until hole clean @ 530 gpm & 89 rpm. Note: Downlink AutoTrak to ribs -off mode (close ribs). Monitor well (static). Report Date: 11.1512008 Job Category: DRILLING 24 H r Summary Circ hole clean. POOH f15084'- 4583'. Work tight hole f/ 4583'- 4147'. Circ hole clean @ 4147'. Backream out of hole f/ 4147'- 3400'. RIH (13400'- 5022'. Wash last std to bottom f/ 5022'- 5084'. Drill ahead 8 -112" hole f/ 5084'- 6162'. ops L_ S1artTine Tine DorOrs) Op4Code A'Kllttrcode Slats Trouble Code Come it 06:00 07:00 1 .00 CIRC MUD AF Circ until hole clean 3 X btms. up @ 530 gpm & 89 rpm. Monitor well (static). 07:00 08:00 1.00 TRIP DP AF PJSM;POOH to 4583' start working tight hole to 4147'. Pulling 25 -50K over string wt. 08:00 09:00 1.00 CIRC MUD AF Circ. 2X bottoms up at 4147', @520 gpm., rt.pipe 80 rpm. until hole cleaned up. 09:00 11:00 2.00 REAM OH AF PJSM; POOH backreaming from 4147'- 3400', 520 gpm, rt.pipe at 65 rpm. 11:00 13:00 2.00 TRIP DP AF PJSM; RIH f/ 3400' to 5084' tagged tight spat and reamed at 4740', wash last 60' to bottom @ 5084'. Trip gas: 60 units. 13:00 18:00 5.00 DRILL ROT AF PJSM: Drill 8 -112" tangent section w/ ATK f/ 5084' -5440' @ 510 gpm, 1700 psi, wob 10 -15 klbs, 75 rpm, tq 6 -9 kft -Ibs, p/u 128 klbs, s/o 73 klbs, rot wt 90 klbs. ART: 4.0 hrs. Max gas: 103 units, avg bkgnd gas: 20 units, No connection gas. No gains or losses. 18:00 00:00 6.00 DRILL ROT AF Drill 8 -1t2" tangent section w/ ATK fi 5440' -5844' @ 510 gpm, 1800 psi, wob 10 -15 klbs, 75 rpm, tq 6 -11 kft-lbs, p/u 143 klbs, sio 75 klbs, rot wt 98 klbs. ART: 4.6 hrs. Max gas: 204 units, avg bkgnd gas: 30 units, No connection gas. No gains or losses. 00:00 06:00 6.00 DRILL ROT AF PJSM: Drill 8 -1 /2" tangent section w/ ATK f15844' -6162' @ 510 gpm, 1650 psi, wob 10 -15 klbs, 75 rpm, tq 10 -12 kft -Ibs, p/u 148 klbs, ski 75 klbs, rot wt 100 klbs. ART: 4.5 hrs. Max gas: 171 units, avg bkgnd gas: 20 units, No connection gas. No gains or losses. Report Date: 11/1612008 Job Category: DRILLING 24 H r Summary Drill 8-1/2" production hole f/ 6162- 6737'. Circ bottoms up sample for geology. Make short trip to 4830'. RIH. Circ hole clean. POOH & lay down 8-1/2" AutoTrak assy. Reached T.D. @ 17:00 hrs on 11/15/2008. ops L_ SOrtTine EldThe Dtr(Irfl OpaCode ActiirtiCacie S47ps Troeble Cale Camme 06:00 12:00 6.00 DRILL ROT AF Drill 8 1/2 tangent section w/ ATK fI 6162' -6463' @ 510gpm 1675psi wob 10- 17klbs.tq 10 -11 kft -Ibs 75rpm. p/u 156klbs,sfo 80klbs rot wt.108klbs. ART= 4.3hrs Max gas 112units . No gain/loss www.peloton.com Report Printed: 1/212009 • • (AK) Marathon Operations Summary Report Oil Company Well Name: SUSAN DIONNE 6 Opc - L_ StartTine Eld TFe Dur rs Ops Code MUM/Cale Stabs Trouble Code Comment 12:00 17:00 5.00 DRILL ROT AF Drill 8-1/2" tangent section w/ ATK ft 6463'- 6737' @ 510 gpm, 1675 psi, wob 10 -15 klbs. 75 rpm, tq 11 -13 ft-klbs, plu 163 klbs, ski 87 klbs, rot wt 114 klbs. Max gas: 108, avg bkgnd gas: 12 units. No connection gas. ART: 3.9 hrs. No gain/ losses. Mud weight 9.6 ppg, Vis 56. T.D. reached @ 17:00 hrs on 11- 15/2008. 17:00 18:30 1 .50 CIRC MUD AF Circulate BN for samples to confirm TD of 6737' nnntinue circulating untill shakers clean up for wiper trip 18:30 20:30 2.00 TRIP V' 1PR AF ' PJSM: Short POOH f/ 6737'- 4830'. No tight spots. Hole slick. Monitor well (static). Note: Blow down top drive & AutoTrak BPA unit. 20:30 22:00 1 .50 TRIP WPR AF RIH ft 4830'- 6737'. No fill on bottom. No ledges or tight spots encountered. No gains or losses. 22:00 23:30 1 .50 CIRC MUD AF CBU & con/ circ until hole clean @ 530 gpm & 85 rpm. Monitor well (static). 23:30 05:00 5.50 TRIP DP AF PJSM: POOH wI 5" dp fI 6737' -6422' (SLM). Pump dry job. Drop 2 -114" rabbit. Blow down top drive. Con/ POOH ft' 6422' -838'. Hole slick. No tight spots. 05:00 06:00 1 .00_PULD BHA AF POOH wI rack back 10 stds 5" hwdp. Lay down jars & 1 jt hwdp. Daily Operations Report Date: 1117,2008 Job Category: DRILLING 24 H r Summary LID 8-1/2" AutoTrak assy. Clear rig floor. NU quad -combo logging tools on shuttle assy. RIH WI shuttle assy while taking pressure readings to 6675'. CBU. Drop messenger & deploy logs. POOH while logging ft 6675' - 1893'. Cony POOH & LiD shuttle assembly. Service rig. PN muleshoe & RIH to 9 -5/8" csg shoe. Slip & cut drilling line. Opt StartTtne ErdTtne Drr(re) Op6Code Aaiun /Code States TrosbleCcde Came it 06:00 08:30 2.50 PULD BHA. AF PJSM: Lay down non mag collars, Stabilizers ,Float sub and crossovers. Link up and down load LV D data. Lay down on trak MV D. Break out bit and lay down motor 08:30 09:00 0.50 CLEAN RIG AF Clean clear rig floor, 09:00 11:30 2.50 PULD LOG AF PJSM : PM Shuttle logging assy. 6 5/8 reamer shoe, Circulating sub 4 Jts 3 1/2 drill pipe Lower latch, and upper latch. Load Quad- Combo logging tools. Load source. PL 1 jt 3 1/2 if drillpipe and Float 11:30 16:00 4.50 TRIP DP AF PJSM: Con/ RIH wt shuttle assy to 6675' while taking pressure readings: @ 782' (2 bpm = 158 psi, 4 bpm = 360 psi, 6 bpm = 700 psi), @1922' (2 bpm = 181 psi, 4 bpm = 400 psi, 6 bpm = 725 psi), @ 3950' (2 bpm = 233 psi, 4 bpm = 467 psi, 6 bpm = 810 psi). 16:00 17:30 1.50 CIRC MUD AF CBU @ 6 bpm wI 238 psi, plu 142 klbs, sto 82 klbs, trip gas 36 units. 17:30 18:30 1.00 LOG OH AF Rack back 2stds 5" dp to 6651'. Drop messenger & pump down @ 6 bpm wI 865 psi. At 2700 total stks, reduce flow to 2 bpm until dart seated @ 2770 stks. Pressure dropped ft 285 psi to 165 psi. Increase flow back to 6 bpm, pressure increased to 900 psi, rupture disc sheared & pressure dropped to 165 psi to confirm shuttle tool deployed. wait 10 min for caliper arm to open. 18:30 23:00 4.50 LOG OH AF PJSM wl Weatherford: Log out of hole wi shuttle assy ft 6651' -1898' @ 2 min per std. 23:00 00:30 1 .50 LOG OH AF PJSM: POOH wi shuttle assy ft 1898' -0'. 00:30 02:30 2.00 LOG OH AF Retrieve quad -combo logging probe & lay down shuttle assembly. Successful logging run. 02:30 03:30 1.00 SERVIC RIG AF PJSM: Service rig. Service top drive, crown, blocks & carrier. Locktight & retighten drive line coupling to cotta box on carrier. 03:30 05:00 1 .50 LOG CSG AF PLI 5" muleshoe & RIH wI 5" dp to 9 -5/8" csg shoe. 05:00 06:00 1.00 SERVIC RIG AF PJSM: Slip & cut drilling line. Report Date: 1118/2008 Job Category: DRILLING 24. HrS,mmary Cut & slip drilling line. Wait on pressure picks from geologist. RIH wI 5" drill pipe ft 2031' -4580. Circ. Con/ RIH to 6680'. Wash to bottom @ 6737'. Circ hole clean. Pull up & park 5" drill pipe @ 5547'. R/U & RIH wI MFT logs on wireline. Take pressure logs ft 6034' - 5800'. Tool giving eroneous readings. POOH to inspect & clean logging tools. Work drill pipe. RIH wI MFT wireline tool to 1600'. Logging tool stuck. Work tool free. POOH to inspect tool for problem. Make repair. Work drill pipe. RIH wI MFT logging tools on wireline to 5800'. Loci pressure points ft 5800 5640'. opa - L_ SartTrne ErdThe MINIM Ops Cade ActItlVCOde Stalls TrosbleCol? Come it 06:00 06:30 0.50 SERVIC EQIP AF PJSM: Slip and cut Drilling line 06:30 08:30 2.00 WAITON ORDR AF Wait on pick points for MFT pressure points www.peloton.com Report Printed: 1/2/2009 • • Marathon Operations Summary Report 1° t l Ian Company Well Name: SUSAN DIONNE 6 apa StirtTtne EidTine Drrllrs) OpsCock ActlitIvCaie States Trolble Cale CammeIt 08:30 10:30 2.00 TRIP DP AF PJSM: RIH 1- 2031'- 4580 Circ and clear out mule shoe. Continue running in hole to 6680' Wash last stand to bottom at 6737' Tag 2' of fill 10:30 12:00 1 .50 CIRC MUD AF Circulate and condition mud at 6737' Circulate 1.5X BN ( 580psi 384gpm . No gain /Lossess 12:00 13:00 1 .00 TRIP DP AF _ Pull up to 5547' and park drill pipe for MFT logging 13:00 14:00 1.00 RURD ELEC AF PJSM : Rig up Weatherford wire line Pack off and pump in sub. Make up MFT pressure logging tools. 14:00 20:00 6.00 TEST PBU AF RIH with MFT tools on E -line. Note Pump tools down at 125psi to 3000' increase pump down pressure to 300psi at 4900'. Stop pumping down tools at 5000' Tools running tAi/0 pumping to First pressure point at 6034'. Continue taking pressures & attaining 23 of 27 total attempts 116034'-5800'. Tool begin taking eroneous measurements. Decide to POOH to inspect tool. 20:00 22:00 2.00 RUNPUL ELEC AF POOH wi MFT tool on wireline 1/ 5800' to surface. Inspect pads & clean quartzdyne sensors. Move 5" drill pipe w/ 25k overpull. 22:00 01:00 3.00 RUNPUL ELEC TA MDLG PJSM: RIH wi MFT tool on wireline to 1600'. Tool stopped going down. Rig up & pump on tool [rn 300 psi. Tool still not going down. Attempt to work with wireline. Tool stuck. Continue work tool wi 3500 lbs tension on wireline. No ga. Rig up & reverse circ [rn 12 spm. Tool becomes free. POOH to inspect tool. Found rubber on cup disk at very bottom on tool severely damaged & partially missing. Remove disk. Move drill pipe wi 25k overpull. Pump 1 drill string volume to clear any possible rubber debris from drill pipe. 01:00 03:00 2.00 RUNPUL ELEC TA MDLG RN & RIH w1 MFT tool on wireline 11 surface to 2000'. Pump tool down 250 psi 1/ 2000'- 5547'. Con't RIH wio pumping to 5800'. 03:00 06:00 3.00 TEST PBU AF Run MFT pressure logs fi 5800'- 5640'. Attained 14 of 16 total attempts. RIH wi wireline tool to 6392 to attempt additional tests as per geologist. Daily Operations Report Date: 11/18/2008 Job Category: DRILLING 24 H r Srmmary Continue running MFT logs fi 6392'- 6374'. POOH wi wireline tool & RAD. POOH w/ 5" drill pipe 11 5547' - 5105'. RN & RIH wi MFT logging tool on wireline & log 116392-5191'. POOH wi wireline tool & POOH wi 5" drill pipe 1/ 5191' & lay down mule shoe. Moved to completion phase on 11/1812008 [m 23:00 hrs. ops SOrtT[e EidThe Dur(I rs) OpsCOk A,ctWVC■de Scads Trouble Code Canmeit 06:00 08:00 2.00 TEST PBU AF Continue running MFT testing 116392'-6374'. Attained 4 pressure pts of 4 total attempts. POH with mft tools on e- line. Rig down E -line tools. 08:00 08:30 0.50 TRIP DP AF PJSM: Move Drillpipe up hole 1/ 5547' -5105' and park. No excessive over pull to move pipe 08:30 17:00 8.50 TEST PBU AF PJSM: RAJ weatherford MFT tools set pack off. RIH with tools on E -line and run mft test fi 6392' to 5191'. Attained 27 pressure pts of 27 total attempts. 17:00 19:00 2.00 RUNPUL ELEC AF PJSM: POOH w/ MFT logging tools on wireline. Lay down tools & rig down Weatherford wireline equipment. 19:00 23:00 4.00 PULD DP AF PJSM: POOH wi 5" drill pipe & lay down muleshoe sub. Move to completion phase a 23:00 hrs. on 1111812008.. No gainiloss Report Date: 11/19/2008 Job Category: DRILLING 24 H r Simmary Move to completion phase on 11/1812008 @ 23:00 hrs. MN & RIH wi 8-1/2" cleanout assy to 6737'. CBU & cont circ until hole clean. Monitor well. Blowdown top drive. POOH & stand back 30 stds 5" drill pipe. Con't POOH wi laying down 5" drill pipe singles. ops - St3rtTine BO Tine Dar (I rs) Ops code ActlJit ccde Stalls Trouble Cale Canmeat 23:00 03:30 4.50 TRIP DP AF PJSM: PN & MN 8-1/2" cleanout assy. RIH to 6737'. Tag bottom. No fill. Hole slick. No gains or losses. 03:30 05:00 1 .50 CIRC MUD AF CBU & can't circ until hole clean. Circ @ 455 gpm & 85 rpm. P/u 150 klbs, sio 81 klbs, rot wt 110 klbs, tq 10 kft-Ibs. Monitor well (static). 05:00 06:00 1 .00 TRIP DP AF PJSM: POOH & stand back 5" drill pipe l 6303' (06:00 hrs). Report Date: 11/20/2008 Job Category: DRILLING 24 H r Summary Lay down 5 " drill pipe, RN run 4 1/2 liner ops L_ Start Tine EidTtne DirOrs7 Ops cc.e ActlitliCoie Stills Trouble Cade Cammelt 06:00 07:00 1 .00 TRIP DP AF Continue POH and stand back drillpipe to 4913'. No Gaintoss 07:00 13:00 6.00 PULD DP AF PJSM : POH and lay down drill pipe F- 4913'- 663'. Lay down -W DP ,Jars and 8 112 bit 13:00 13:30 0.50 RUNPUL VYBSH AF PJSM: Pull wear bushing . www.peloton.com Report Printed: 1/2/2009 L I (MAIM ,) Marathon Operations Summary Report I s oil Company Well Name: SUSAN DIONNE 6 °p StirtTtne Eld Tine Our gr Ops Code A,c1blvCode Slats Trimble Code Canme 13:30 15:00 1.50 TEST CSG AF PJSM: Set test plug MN 4 1/2 casing test ioint. Test 4 1t2 Casing rams, 250/2000 fl 5min test good . Pull test plug set wear bushing, lay down test Joint. 15:00 18:00 3.00 RURD CSG AF PJSM: Change out Bails. Move spinners and tongs. PN weatherfords tongs slips and elevators and rig up 18:00 22:00 4.00 RUN CSG AF PJSM; Pick up bakerlock,and make up 128' shoe track,and check floats,RIH to 9 518 csg . shoe at 2031'. 22:00 22:30 0.50 CIRC MUD AF Circ.30 bbls. liner volume, at 100 spm, 220 psi. 22:30 02:00 3.50 RUN CSG AF Cont. run 4 112" -12.6# L -80 csg. from 2031' to 3679'. 02:00 02:30 0.50 CIRC MUD AF Circ. bottoms up at 3679',Pump 100 stks =290 psi 02:30 04:00 1.50 RUN CSG AF Cont. run 4 112" -12.6# L -80 csg. from 3679' to 4884' Up wt. =55K Dn wt. =40K Ran total of 119 Jts. (2 -20' marker jts.) No gains No losses. Note: Jam casing to 6000ftlbs make up torque 04:00 06:00 2.00 CHANGE EQIP AF PJSM; Change out bales and elevators.To run 4 112" liner on 5" drill pipe. Daily Operations Report Date: 1112112008 Job Category: DRILLING 24 H r Summary !, P1J Baker liner hanger, RIH w14 112" liner on 5" DAP, Tag btm @6737', Circ. hole clean, Pump Crrit. in place @0200 hrs, set hanger , release tool, circ., out cmt, TOL liner at 1814.24', btm @6735 "POOH, L/D running tool, plu polish mill, RIH polish tie back, POOH, PrLI ZXP packer, RIH tol 814', set ZXP wi 3500 psi , blow ball seat at 4825 psi. ZXP liner top packer set at 1793.89' ops S6rtTlne Eid The Drr(1rs) Ops Code A.a irryccde Slaps Trouble Code Commit 06:00 07:00 1 .00 PULD PKR AF PJSM: PN Baker oil tool 7X 9 518 Flexlock liner hanger. Fill liner tie -back with pal mix up to top of liner tie -back sleeve. Set dust cover to top of liner sleeve and lock down. Break circulation and Ck flow. 07:00 08:30 1.50 RUN CSG AF Continue running 4 112 Hydrill 563 casing/ liner. to 6674' Precautionary wash liner to botton at 6737' tag up with no fill. No gainAoss. 08:30 10:30 2.00 CIRC MUD AF Circulate, Rotate and Reciprocate liner Up wt 95klbs Dn wt 65klbs @ 395gpm 485psi at 6737 up to 6720' . Max torque 5500 ftAbs. prior to cementing 10:30 11:00 0.50 PULD EQIP AF PJSM: NU Baker oil tool td cement head 11:00 12:00 1 .00 CIRC MUD AF PJSM; wl BJ services, Circ. condition mud. 12:00 14:00 2.00 PUMP CMT AF Pump 2 bbls. water, test lines to 3600 psi, Mix and pump 40 bbls. Sealbond sweep @ 1 Oppg.,Mix and pump Lead cmt. 270 sks. Class G + 1% FL -62, 25% R -3, 2% SMS, .05% Static Free, 1 ghs FP -6L, 12.SPPG, Yield 2.100 cuftlsk, 11 .887galIsk,Thickening time 3:30,105 bbls., Mix and pump 970sks.Tail Class G_+ 1 .2% BA- 56,.4% CD -32, .5% EC-1, .25 SMS, 1 % CaCl2, 3 %KCL, .05% Static Free, 1 ghs FP -6L, 15.8ppg, Yield 1 .183 cuftlsk, 4.959 gallsk, 4:56 Thickening time 196 bbls. slurry, cement in place @02:00 hrs. Top of liner @1814.24 Bottom of 4 112' shoe @6735' (Got 20 -25 bbls. cmt. to surface) Note ; Rotate and reciprocate liner. Stop reciprocation of liner after 21 Sbbls of cement pumped due to torque. Continue to rotate liner until last 1 Obbis of cement displaced. Max torque 10klbfp 100% returns. No losses. 14:00 1 5:30 1.50 SETREL LNR AF Flush lines drop 4 112' liner dart, Pumped 8 bbls.dart did not deploy, Break off cement head and drop second dart in drill pipe, displaced cement stop 8 bbls., short of total displacement, 105bbls. pumped. Did not bump plug. Bleed off and check floats.OK, Pressure up , Set liner hanger by surging pressure, set down wt. on hanger, put 112 turn in drill pipe to release HR tool, pressure drill pipe to 500 psi and pull out running tool, with 650 psi on tool. start circ. out cement.20 -25 bbls to surface. Due to failure of plug to launch, wiper plug at 6061' +1- MD 15:30 16:00 0.50 RURD CMT AF PJSM; Lay down TD head, blow down lines. 16:00 17:30 1 .50 TRIP DP AF PJSM; POOH with 5" drill pipe,lay down running tool. 17:30 18:00 0.50 SERVIC EQIP AF PJSM; Flush cement from stack. 18:00 18:30 0.50 SERVIC RIG AF PJSM; Service rig and change out grabber dies. 18:30 19:00 0.50 PULD PKR AF PJSM; Pick up and break down cement head.Lay back down. 19:00 20:00 1 .00 TRIP DP AF PJSM; Pick up polish mill for 7.50" tie back sleeve,RIH to 1814' polish tie back. 20:00 22:00 2.00 TRIP DP AF PJSM; Polish Tie back sleeve, POOH with polish mill.and lay down. 22:00 00:30 2.50 TRIP DP AF PJSM; Pick up and make up ZXP packer, RIH with 5" drill pipe. www.peloton.com Report Printed: 1/212009 • • M A) Marathon Operations Summary Report miutsTlIOR s Oil C:ornpany Well Name: SUSAN DIONNE 6 Ops L_ SUrtTine Eta The Oir(l Om Cale Aktimeocie Sods TrorbleCede Canine it 00:30 04:00 3.50 dVAITON CMT AF Wait on cement, Clean pipe rack, Band mud products,Build brine 04:00 06:00 2.00 SETREL PKR AF PJSM; RIH f11685' to 1814', space out to rig up BJ, drop 1 7116 ball, pump ball on seat with rig pump,Line up BJ to pressure up to 2000 psi hold 5 min. pressure to 2400 psi, press. to 3500 psi set packer, cont. to press. to 4952 sip blo Ar ball seat. ZXP packer top at. 1793.89' Daily Operations Report Date: 1112212008 Job Category: DRILLING 24 H r SImmary Test liner t1500 psi 10 min.,L/D DAP, Pull Wear bushing, RN to run 4 112, RAJ 4 1/2 tie back, Space out hanger, CIO to 3% KCL,Land hanger,test t15000 psi, Clear rig floor, Nipple down BOP ops L_ sartThe Eed The DIr (i rs) Ops Cock Actltiveccle Stalls Trogbie Cock Comme 06:00 07:00 1 .00 TEST CSG AF Test Liner and casing 1 500psi1 Omin test good 07:00 09:00 2.00 TRIP DP AF PJSM: POH lay down 5" drill pipe from 1793' - 0 09:00 09:30 0.50 PULD EQIP AF Make service breaks on baker zxp packer running tool and lay down 09:30 10:00 0.50 CLEAN RIG AF WU wear bushing puller, Pull wear bushing 10:00 10:30 0.50 RURD OTHR AF PJSM: Clear rig floor of all drillpipe handling tools, tongs and spinners. 10:30 12:30 2.00 SETREL TOOL AF Set multi bowl 11x7" Hanger Bushing 1 Pack off. Test to 5000psi1 Omin. Test Good . Make gauge run with 4 1/2 Tubing Hanger 12:30 14:30 2.00 RURD OTHR AF Change out elevators and bails. Rig up weatherford Tubing tongs ,slips and tools 14:30 18:00 3.50 RUN CSG AF Hold PJSM: PAJ Baker 4 1/2 located seal assy Run 8jts 4 1/2 L -80 12.60ppf hydril 563 Tubing. Install Baker Oil tool chemical injection nipple placed at 1507' with stainless steel 114 control line. Test control line to 2000psi .1 hold 500 psi on line. Continue running in hole with 2 steel bands per joint. total of 44 joints ran. placed 81 bands two per joint. 18:00 20:00 2.00 RUN CSG AF Stab in seal assy. into monobore, pressure up backside 200 psi to insure seals engaged, land locator, space out for tubing hanger-, rig up circ. lines, Rig down Weatherford. 20:00 21:00 1 .00 CIRC CFLD AF PJSM; Change over mud,Pump 30 bbl. Hi vise. sweep, 94 bbls. 3% KCL, 40 bbls. of inhibited KCL. 21:00 23:00 2.00 RUN CSG AF PJSM; Land tubing hanger, test hanger seals to 5000 psi for 10 min., Test down 4 1 I2 liner string to 1500 psi for 30 min., test annulas to 1500 psi for 10 min.Lay down landing joint, install BPV, rig down Pollard control line sheaves. 23:00 00:30 1 .50 CLEAN RIG AF Clear rig floor, lay down subs, handling equip., valves, slips, cross avers .Clean pits 00:30 02:00 1 .50 CLEAN RIG AF Flush cmt. line, choke manifold, poor boy, rinse stack, Flush #1,2,3 pumps, 02:00 06:00 4.00 NUND DOPE AF PJSM; Nipple down BOP Report Date: 1112312008 Job Category: DRILLING 24 Hr5rmmary RD GD -1 ops L_ StartTtne EidThe Our(I rs) OpsCok ,a'ajt Cc a Stalls TrolbkCock Commit 06:00 06:30 0.50 NUND ROPE AF Complete nipple down BOPE. Flow and trip tank lines. Move stack out of cellar. 06:30 10:00 3.50 NUND TREE AF Set Tree and nipple up. Set TVVC. Test void to 50001 Omin. Test Tree 50001 Omin. Pull TWC and set Back pressure valve. Freeze protect wellhead 10:00 18:00 8.00 RURD RIG AF Rig down mud lines from rig floor. Pull service lines from sub. Rig Down service loop and top drive. Rig down torque tube. Rig down cement silos. Move out all mud products and ship to MI yard. Load out Epoch and Md4D cabin. 18:00 00:00 6.00 RURD RIG AF PJSM: Prep derrick to scope down, rig down derrick board, scope down derrick, prep to lay down derrick, Rig down pump #3, Pickle draworks, Rig down drillers console, load out cuttings tank, Rig down catwalk and "V" door, remove trip tank from subbase,riq down choke lines. 00:00 06:00 6.00 RURD RIG AF PJSM; Unplug and roll up gaitronics, rig down cylinder tarps in cellar, change oil in vacum degasser, rebuild mud pump valves, fuel camp genarator, rig down exterior lights on choke house, dog house, remove #2 steam heater in pits, organize part house, blow down water to rig , rig down poor boy U -tube, prep pallets. www.peloton.com Report Printed: 1/2/2009 • 1 M Marathon Operations Summary Report maim rr .s Oil Company Well Name: SUSAN DIONNE 6 Daily Operations Report Date: 11/24(2008 Job Category DRILLING 24 H r Simmary op` L_ StartTine Eld Tine DIr(irr) OpsCaie A,c1lJF Code Stalls Dui ble Coie Came it 06:00 15:00 9.00 RURD RIG AF PJSM: Crane operations, Crane down back wind walls on rig floor. Lower mast to carrier. Crane and load out bop conex. Remove dog house and frount windwalls and gray iron. crane down house fron board. Crane down choke lines choke house and gray iron. Remove flow line Scope gas buster down into pits. Crane down fuel tank. 15:00 18:00 3.00 RURD RIG AF MSOT Move Carrier off mud boat. ( cotta box air lines frozen thaw out. Mud boat sumps full of oi11 water wait on production vacuum truck to clean up. Move mud boat Set Gooseneck. Move sub off well center. Scope down sub. Release rig to BC-19@ 1800hrs. 11 -23 -2008 Report Date: 121212008 Job Category COMPLETION 24 H r Stmmary MIRI Vetco -Gray to pull BPCV. ops _ L✓ StartTine EidTine DR (Yr5} Ops Cale Ac11MCale state Tro!bleCale Canmelt 14:00 14:30 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Vetco JSA and job hazards. Obtain SAP. 14:30 15:00 0.50 PULL EQIP AF Check for pressure under Check Valve. None. Pull BPCV. 15:00 15:15 0.25 SECURE WELL AF Remove Pvsignage trom wellhead. - Lase valves on tree and secure. Reinstall tree cap. Report Date: 12/4/2008 Job Category COMPLETION 24 H r Summary MIRU Expro to run GR and CBL. RIH w/ 2.82" GR. Set down @1840'. Worlked tools to 1902'. Could not run CBL. opa S1artTine EId Tine Du Ors) Opt Cccle Aotirli/Caie Stalls Trouble Cale Canmeit 08:00 09:00 1 .00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss Expro JSA and job hazards. Obtain SO/P. Fresh snow has made footing very slick. Sand location. 09:00 10:21 1 .35 RURD ELEC AF Spot equipment. MU lubricator. MU tool string -rs, rb, 7' x 1 -11116" wt. bar, rb, 1- 11116" CCLKGamma Ray, sj, 2.82" GR. 10:21 10:36 0.25 RURD ELEC AF Carry lubricator to VVH. PTest lub. 10:36 11:36 1.00 RUNPUL ELEC AF RIH (1) w12.82" GR. Set down in liner 1840' wlm. Work tools down to 1898' wlm. ( Did not make into liner to Open hole log depth - 1900'. So could not correlate to get on depth). POOH. OOH. Recovered two small, very light, thumb sized pink rocks in GR. 11:36 12:36 1 .00 RUNPUL ELEC AF RIH (2) w13.50" GRljunk basket. Work tools down to 1902' wlm. ( Did not make into liner to Open hole log depth - 1900'. POOH. OOH. Recovered gallon of gray mudlcement containing more small pink rocks, coal, and many chunks of gelatinous material ( SealBond -- Sodium Silicate ? ? ?). 12:35 13:18 0.70 RURD ELEC AF RD Expro. 13:18 13:33 0.25 SECURE WELL AF Close valves and secure well head. Turn in permit and sign out. Report Date: 12113/2008 Job Category: COMPLETION 2411 r Strnmary Rig up BJ Coil, Test BOP's, prepare for Motor 1 Mill cleanout on Saturday ops L_ Sian-Me ErdThe Der nrd) Ops Cale Actuticede St t $ Troibk Code Canmert 06:00 07:00 1 .00 MOB RIG AF Mobilize in Coil Tubing unit and associated equipment, flowback tanks, source tanks, methanol tank, heaters, light plants, cranes. Spot equipment on containment barriers. 07:00 08:00 1.00 SAFETY MTG AF PJSM - Active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, review JSA, assign jobs, slips, trips, falls, icy conditions, cold conditions (SUBZERO). proper PPE, injuries to hands, STOP THE JOB drill - assigned to Phillips (green hat) with BJ Services. Reviewed the drill, reasoning for the drill and debriefing tomorrow morning. 08:00 15:00 7.00 RURD COIL AF Rig up BOP's on tree, lay out flowline, lay down containment, spot tanks on containment, fill methanol tank, transfer KCL water, prepare for BOP test www.peloton.com Report Printed: 1/212009 • • Marathon Operations Summary Report (mumps ms M oil COrripany Well Name: SUSAN DIONNE 6 opt StartTine EldThe Der¢rt} Ops Cole Actin/cam Stalls Troin: Cak Caomeit 15:00 15:30 0.50 SAFETY MTG AF STOP THE JOB DRILL - Phillip with BJ Services stopped the job because he did not understand the configuration of the flowback iron to circulate and mill the plug to bottom, reversing the water out of the hole with N2. Gathered the crews after stopping the job, worked through the issue so Phillip has a full understanding of the job and then went back to work. 15:30 17:00 1.50 RURD COIL AF Finish rigging up coil flowlines, flowlback lines to methanol tank, flowback lives to water flowback tank, choke skid, gas buster. 17:00 18:30 1.50 TEST WLHD AF Pressure test BOP's 250 low, 4500 high. passed 18:30 04:00 9.50 SECURE WELL AF secure wellhead tor evening, firewatch to keep equipment warm through the evening. Daily Operations Report Date: 1211412008 Job Category: COMPLETION 24 H r Summary Rig up BJ Coil, bridge at packer, restriction in inlet flow line due to freezing, rig down, bring out Steam on Wheels to heat tank Opa StartTine Eld The Our OM Opt Cock Ac1hltrCOk Stags TroebkCale Comma 06:00 07:00 1.00 SAFETY MTG AF PJSM - Topics - Extreme cold conditions, slips, trips, falls, active gas production pad, red lights for fire, blue lights for gas emission, audible siren, muster point, smoking area buddy rule, three second rule, STOP the Job DRill , Phillip reviewed why he stopped the job, results, assigned the Drill for the day to Andy 07:00 10:00 3.00 RURD COIL AF Check equipment, pickup basket , move to injection head, pick -up injection head, add 16' lubricator , make up coil connector, circulation sub, disconnect sub, pull test BHA to 20,000 #, make up motor and mill (OD - 3.80 ") 10:00 10:30 0.50 TEST dVLHD AF Shell test annulus to 1500 psi - good 10:30 11:30 1.00 RUNPUL COIL AF RIH with coil tubing assembly; motor and mill. pump test motor after filling coil with 27 BBL of KCL water. Pump rate 114 BPM at 142 psi. 11:30 12:15 0.75 RUNPUL COIL AF Tagged cement at 1926' measured coil depth, pump rate 1 1.12 BPM, pickup weight 4200 #, pump rate 1 BPM, Pressure 840 psi, Pump rate 1 .5 BPM, Pressure 1500 psi. 12:15 13:00 0.75 MILL PLUG AF Milling cement at packer, pump started losing prime after roughly 20 mimutes of milling. Water temp. in tank down to 44 degree F. Apparent ice problems. Space heater on inlet lines to pump. Start out of hole with Coil unit and call Steam on VVheels to reheat tank. 13:00 13:30 0.50 RUNPUL COIL TA AD POOH - icing problems 13:30 15:30 2.00 RUNPUL COIL TA WD Pump methanol through tubing, RIH to 500' , pump methanol back to surface, tree and flowlines to protect well for shutting down for evening 15:30 16:30 1.00 RURD COIL TA WD Rig down injector head, set back on cradle 16:30 17:00 0.50 SECURE WELL TA WD Secure wellhead, turn equipment over to nighwatch, turn in work permit, leave location Report Date: 1211512008 Job Category: COMPLETION 24 H r Summary Cleanout to 6250' coil depth, run CBLA3R Opt Sian - Me Ertl Tine Dorms? OptCWe ActLlyCole Stags Trouble Cade Camert 06:00 06:30 0.50 SAFETY MTG TA AD PJSM - TOPICS- active gas production pad, red lights for fires, blue lights for gas emission, sirens for audible, muster area, JSA job assignments, STOP the Job Drill, slips trips and falls, icy location, frigid weather, proper PPE, warming up every 45 minutes or as needed 06:30 09:00 2.50 RURD COIL TA WD Rig up coil unit, change stripper, remove Night cap, pick up injector head off cradle, makeup lubricator, makeup coil connector, make up motor and mill, Pull test to 20,000 - passed 09:00 09:30 0.50 PUMP WTR TA VVD Prepare to pump KCL water, Pump Rate .5 BBL Methanol, Pressure 850 #, Rate 1 BBL, Pressure 1645 #„ Pump methanol in coil and BOP's pump back to tank. www.peloton.com Report Printed: 112'2009 • • . Y Marathon Operations Summary Report :,. m Oil Well Name: SUSAN DIONNE 6 Ops L— StrrtTlne EudTtne DirOrs) Ops Code AoWlyCol Strds Trouble Code Comme 09:30 13:00 3.50 RUNPUL COIL AF RIH to 1100 feet coil depth. 12 pm depth 1750 feet, pump rate 1 .24 BPM, pressure 780 #, rate 1 .6 BPM, pressure 1380 #._ Wash from 1860' to 1920 feet. 13:50 pm hours - pickup at 5000" depth, weight 12,000 #, pump rate 112 BPM, pressure 384# 14:20 hours - depth 6245 feet, increase pump rate 1 BPM, Pressure 1400 psi 13:00 14:00 1 .00 MILL PLUG AF Depth - 6247 feet coil depth, motor and mill stalling at 6250 feet, Multiple attemps, BHA stalls at 6250 feet 14:00 15:00 1.00 RUNPUL COIL AF POOH with coil unit. 15:00 17:00 2.00 RURD COIL AF pump methanol through flow lines, well head to keep from freezing, Rig back injector head, set in cradle, Turn well over to Expro Wireline to run CBLIGR 17:00 18:00 1.00 SAFETY MTG AF PJSM - TOPICS - active gas production pad, red lights for fires, blue lights for gas emission, sirens for audible, muster area, JSA job assignments, STOP the Job Drill, slips trips and falls, icy location, frigid weather, proper PPE, warming up every 45 minutes or as needed 18:00 19:00 1.00 RURD ELEC AF Riq up Expro wireline, spot crane, wireline truck, make up tools, shieves 19:00 21:00 2.00 RUNPUL ELEC TA MDLG RIH with CBLIGR. Telemetry section failure, pull out of hole, change out tool, thaw frozen flowlines 21:00 00:30 3.50 RUNPUL ELEC AF RIH with CBL 1 GR. Correlated log to Weatherford open hole Density, Neutron, Sonic log dated 16 -Nov. 2008. Tagged bottom at 6230 feet wireline depth. Good cement to top of packer at 1840 feet wireline depth. Logged free pipe up to 1700 feet wireline depth. POOH 00:30 01:30 1 .00 RURD ELEC AF Rig down Expro Areline. 01:30 02:00 0.50 SECURE �" , )ELL AF Secure wellhead for evening, turn wet over to BJ Services night crew, sign out, turn in permit, leave location 02:00 02:00 SERVIC EQIP AF Maintain firwatch over BJ coiltech equipment, keep equipment warm, prepare for reversing fluid out of hole with N2 Daily Operations Report Date: 121512008 Job Category: COMPLETION 24 H r Summary Reverse H2O out of hole w1 N2, rig down, turn over to facilities ace L— St3rtTtne ErdTine 0 OM Opt Code ActbllrCcde Strt $ Trouble Code Commit 07:00 07:30 0.50 SAFETY MTG AF PJSM - Active gas production pad, red lights for fire, blue lights for gas emission, audible siren, muster area, buddy rule, three second rule, review JSA, assign jobs, clean up around area, proper PPE, cold, warming up, slips, trips, falls, pinch points, overhead loads etc. 07:30 11:30 4.00 RURD COIL AF Coil rig -up, tiff injector to make -up connector, pull test connector, set injector on wellhead BOP's, rig up N2 lines, transfer N2 11:30 12:00 0.50 TEST VVLHD AF Pressure test well head, BOP's, injector head - passed 12:00 16:00 4.00 PUMP N2 AF RIH with CTU, reverse out water with N2. Time Depth WH Pressure N2 Rate 1235 Surf 710 350 1325 930 975 500 1340 2400 1340 750 1348 3000 1500 750 1405 3000 1500 750 1430 5000 1830 750 1455 5000 1750 825 1510 5800 1850 825 1515 6240 1945 825 1543 6240 1776 825 1600 4200 1400 500 1635 0 850 300 1645 0 850 0 16:00 16:45 0.75 RURD COIL AF Rig down coil tubing unit, leave 950 # N2 on wellhead, set back inljector head onto cradle. 16:45 17:00 0.25 SECURE WELL AF Secure wellhead for evening, close out work permit, sign out, leave location www.peloton.com Report Printed: 11212009 III 4111 , Marathon Operations Summary Report MA RATaON s oil Company Well Name: SUSAN DIONNE 6 Daily Operations Report Date: 12/16/2008 Job Category: COMPLETION 24 H r Summary Rig down CTU, turn well over to facilities group to connect to prod. facilities ops SartTme EldTine DirOM Ops Code A+ctlultiCOde Stabs Trouble Code Ccmmekt 08:30 09:00 0.50 SAFETY MTG AF PJSM - slips, trips, falls, pinch points, overhead loads, safe rig down, review JSA- assign jobs, active gas production pad, red lights for fire, blue lights for gas emission, audible siren, buddy rule, three second rule, muster area 09:00 12:30 3.50 RURD COIL AF rig down CTU. Move to 14 -6 pad, well 22 -6 12:30 13:00 0.50 SECURE VVELL AF Secure wellhead, prepare well transfer paperwork, close out work permit, sign out, leave location Report Date: 12/2112008 Job Category: COMPLETION 24 H r Summary RU and perf 5791' - 5809'. 205 psi increase in 1 minute. Rate >10MM. Gun stuck in perfs and pulled out of rope socket. ors I_ StartTlne ErdThe Drr0rs) Ops Code ActlirVCode Slads TroubkCode Come rt 08:00 09:00 1 .00 SAFETY MTG AF Hold PJSM. Discuss Expro JSA and ASRC JSA. Assign tasks and issue permit. 09:00 12:00 3.00 RURD ELEC AF Spot and RU eline unit. 12:00 14:00 2.00 TEST EQIP AF Pressure test lubricator to 4500 psi. Had to replace oring and retest. 14:00 14:30 0.50 SAFETY MTG AF Hold explosives safety meeting.Shut down cell phones and block access to pad. 14:30 15:00 0.50 RURD ELEC AF Arm 3 -3/6" X 18' gun and stab on. 15:00 16:00 1.00 RUNPUL ELEC AF RIH gun #1 . Tie in to CBL. Perforate 5791' - 5809'. Gun stuck. Pressure increased from 825 psi to 1030 psi in 1 minute and stabilized at 1160 psi with a N2 column. 16:00 17:00 1 .00 WORK ELEC AF 1Vorked gun until rope socket pulled out. POH. 17:00 18:00 1.00 RURD ELEC AF Rig down eline and put well on production. V9111 fish gun in AM. Report Date: 12/22/2008 Job Category: COMPLETION 24 H r SImmary Fished perf gun out of well. ops I. StartTlne EldTlne Dir(I rs) Opt Code pen" Code Stabs Trouble Code Canmeit 09:00 09:45 0.75 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA and assign tasks. 09:45 12:30 2.75 RURD SLIK AF Spot and RU slickline using Expro crane. PU 2" JDC pulling tool. 12:30 13:00 0.50 TEST EQIP AF Test lubricator to 2500 ski. Shut in well. 13:00 14:00 1.00 RUNPUL SLIK AF RIH and Iata 3- per f gun tool string. Cama free with no jarring. Ran down through perf interval and POH with no overpull. 14:00 16:30 2.50 RURD SLIK AF Lay down perf gun. Rig down and release slickline unit. Put well back on production. Close permit and leave location. www.peloton.com Report Printed: 1/2/2009 • • Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON Oil Company Telephone 907/283 -1371 Fax 907/283 -1350 January 14, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 Ave 44 (14A, Al Anchorage, Alaska 99501 0/j 4,6) C hoy Reference: 10 -421 Gas Well Open Report Flow Potential Test Re ort i 1® ' Field: Ninilchik Unit Well: Susan Dionne #6 Dear Mr. Maunder: Enclosed is the Gas Well Open Flow Potential Test Report, 10 -421, for SD -6 well. This well was spud on November 6, 2008 and completed into the Tyonek formation. The information on this report was obtained from a one point test. If you have any questions or require additional information, please call me at (907) 283- 1371. Sincerely, ..eUv"� Kevin J. Ski a Engineering Technician Enclosures: 10 -421 Open Flow Report cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALASkOIL AND GAS CONSERVATION COMMI '1 C® GAS WELL OPEN FLOW POTENTIALIATESSTZ SPORT 1a. Test: U Initial H Annual U Special lb. Type Test: Stabbili U Non Stabilized U Multipoint ❑ Constant Time Alas s aP Cons. Cccf>Qission 2. Operator Name: 5. Date Completed: AI it,) IUt 11. Permit to Drill Number: Marathon Oil Company 12/20/2008 208 -160 3. Address: 6. Date TD Reached: 12. API Number: PO BOX 1949 Kenai, Alaska 99611 -1949 11/15/2008 50 -133- 20582 -00 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. 156' above MSL Susan Dionne #6 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 964' FNL, 284' FEL, Sec. 12, T1S, R13W, S.M. 6,606' MD 4,406' ND Total Depth: 9. Total Depth (MD + TVD): Ninilchik Unit / Tyonek Pool 1,099 FNL, 786 FEL, Sec.12, T1S, R13W, S.M. 6,737' MD 4,522' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 213,309.79 y- 2,236,795.84 Zone- 4 ADL - 359242 & ADL - 384372 TPI: x- 209,162.20 y- 2,235,523.20 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 208,658.40 y- 2,235,389.00 Zone- 4 Momobore, Single 17. Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19. Perforations: (MD) From To 4.500" 12.6 ppf, L -80 3.958" 6,735' 5,791' 5,809' 18. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 4.500" 12.6 ppf, L -80 3.958" 1,794' 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 1,794' - - 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): 0 Tubing ❑ Casing 91 F° 1,190 psia @ Datum 4,366' TVDSS 14.73 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H Prover: Meter Run: Taps: 5771' MD 3677' ND 0.56 0.36 0 Facility 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line )( Orifice psig Hw F psig F psig F Hr. Size (in.) Size (in.) 1. 3.826 X 1.250 1074 80.73 64 - - - - 96.00 2. X 0.00 3. X 0.00 4. X 0.00 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24-Hour) h Pm Factor F Factor Q Mcfd Fb or Fp Ft g Fpv 1. 143.1276 71.8799 1,088.73 1.00 1.3363 1.0783 10,288 2. 0 3. 0 4. 0 5. Temperature for Separator for Flowing No. Pr Tr z Gas Fluid T Gg G 1. 1.62 524 1.53 0.86 0.56 NA 2. 3. Critical Pressure 673.1 4. Critical Temperature 343.2 5. Form 10 -421 Revised 1/2004 I►IUS`L�A�V INU D N R V 2�149 ERSE SIDE Submit in Duplicate 2 O0 Pc 1,217 Pc 1,480,237 I Pf No. Pt Pt Pc Pw Pw Pc Ps Ps Pf -Ps 1. 1,089 1,185,159 2. 15 214.6225 3. 15 214.6225 4. 15 214.6225 5. 0 25. AOF (Mcfd) 51,601 n 1.000 Remarks: Well not Shut -in during test. SIWHP estimated from MFT pressure. I hereby certif that the foregoing is true and correct to the best of my knowledge. Signed I Title Engineering Technician Date 1/14/2009 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / -I hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor = dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air= 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10 -421 Revised 1/2004 Side 2 r ,_■• • • • Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON Oil Company Telephone 907/283 -1371 Fax 907/283 -1350 January 14, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 R C k ask a ''IV 61 Reference: 10 -407 Well Completion Report and Log 0�� G X 09 Field: Ninilchik Unit 'q„ iohor' /7i te i Well: Susan Dionne #6 Dear Mr. Maunder: Enclosed please find the 10 -407 Well Completion Report and Log for Ninilchik Unit well SD -6. Production was initiated from this well when it was completed into the Tyonek formation on December 20, 2008. Current gas production is 10,000 mcf at 845 psi. Please call me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, ‘6 Kevin J. Skib Engineering Technician Enclosures: 10 -407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS Directional Survey CLR RECUVty STATE OF ALASKA f // l ei 9 ALAS OIL AND GAS CONSERVATION COMM IONJAN 1 6 2009 WELL COMPLETION OR RECOMPLETION gr la. Oil ❑ Gas 0 Plugged 111 Abandoned 111 Suspended ❑ A Well C rage 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other III No. of Completions: 1 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill #: 208 - 160 Marathon Oil Company Aband.: 12/21/2008 Sundry #: NA 3. Address: PO Box 1949 6. Date Spudded: 13. API Number: Kenai Alaska, 99611 - 1949 11/6/2008 50 133 - 20582 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. 11/15/2008 Susan Dionne #6 Top of Productive Horizon: 8. KB (ft above MSL): 156' 15. Field /Pool(s): 964' FNL, 284' FEL, Sec. 12, T1S, R14W, S.M. Ground (ft MSL): 135' Total Depth: 9. Plug Back Depth(MD +TVD): Ninilchik Unit / Tyonek Pool 1,099' FNL, 786' FEL, Sec.12, T1S, R14W, S.M. 6,606' MD 4,406' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x - 213,309.79 y - 2,236,795.84 Zone 4 6,737' MD 4,520' TVD ADL - 359242 & ADL - 384372 TPI: x- 209,162.20 y- 2,235,523.20 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 208,658.40 y- 2,235,389.00 Zone- 4 NA 18. Directional Survey: Yes p No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Cement Bond Log, Quad Combo, CCL, Gamma Ray, and Multi Formation Test 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 129.25 X -56 0' 101' 0' 101' Driven NA NA 9 -5/8" 40 L -80 0' 2,031' 0' 1,580' 12 -1/4" 490 sks, Type 1 160 sks 4 -1/2" 12.6 L -80 1,794' 6,735' 1,488' 4,519' 8 -1/2" 1,240 sks, Class G —23 sks 23. Open to production or injection? Yes l0 No If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD Gun Type 4 -1/2" 1,794' 1,794' 5,791' - 5,809' 3,698' - 3,714' 3 -3/8" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: 12/21/2008 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 12/26/2008 24 Test Period . 0 10,137 0.5 80/80 100% gas Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 1,077 2 24 -Hour Rate 0 10,137 0.5 NA 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. bATE ;,1 BFL t E `E 0 9 2009 • . i , v _ Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE )41-2IS & 2$. GEOLOGIC MARKERS (List all formations and m encountered): 29. FORMATION TESTS NAME MD TVD Well tested? UYes UNo If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost - Top detailed test information per 20 AAC 25.071. Permafrost - Base Beluga B2 3,676' 2,176' Multi- Formation Test Beluga B3 4,799' 2,838' Information provided as an attachment Beluga B4 5,496' 3,443' Tyonek T1 5,687' 3,608' Tyonek T2 6,499' 4,313' Formation at total depth: Tyonek T2 6,737' 4,522' 30. List of Attachments: See Attachment List 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 - 1371 Printed Name: Craig L. Rang Title: Senior Completions Engineer Signature: Phone: (907) 283 -1372 Date: January 14, 2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • SD #6 Ninilchik Unit Attachment List End of Well Report Well Schematic Directional Survey Multi Formation Test Operations Summary Logs • Array Induction TVD • Array Induction MD • Array Induction Vector Processing MD • Photo Density Dual Spaced Neutron MD • Formation Tester MD • Hole Volume Caliper MD • Compensated Sonic MD • Density Neutron Sonic Water Saturation • Compact Quad Combo QuickLook MD • Dual Radial Cement Bond, Gamma Ray, CCL Compact Disc • Directional Survey • Wireline Log Data • Mud Log Data • SD -6 Permit #: 208 -160 Ninilchik Unit API #: 50- 133 - 20582 -00 -00 316' FSL, 1,132' FEL M Prop. Des: ADL - 359242 & ADL - 384372 Sec. 6, T1 S, R13W, S.M. KB elevation: 156' (21' AGL) - MARATHON WBS #: DD.08.17742.CAP Latitude: 60° 06' 46.17" N Longitude: 151 ° 34' 25.53" W Spud: 11/6/2008 @ 08:00 hrs 1/4" OD 0.049" wall Chemical TD: 11/15/2008 @ 17:00 h injection line tied into mandrel at Rig Released: 11/23/2008 @ 18:O0hrs 1,507' w/ check valve PA #: Conductor ntluctor 20" X -56 129.25 ppf PE Top Bottom MD 0' 101' 144 TVD 0' 101' IM lit Surface Casing 9 -5/8" L -80 40 ppf BTC ' 4 - f/ Top Bottom Baker 4 -1/2" x 9 -5/8" Liner Hanger and ZXP Packer - MD 0' 2,031' Liner /hanger top @ 1,829' MD. `` TVD 0' 1,580' Packer top @ 1,794' MD. L! ' ll!� ; 12 -1/4" hole, Cmt w/ 490 sks (217 bbls) 12 ppg, ♦ i ' Type 1 cmt with 160 sks (71 bbls) to surface. KOP @ 244' MD/TVD s 2 Tie -Back Tubing Build -3.35 deg / 100' from 244' - 1,970' MD Hold 68.75 deg from 1,970' - 3,825' MD 4 -1/2" L -80 12.60 ppf Hydril 563 Drop -3.45 deg / 100' to 4,970' MD Top Bottom Hold 29.75 deg from 4,970' to TD at 6,737' MD } TVD 0' 1,488' t Azimuth: 251.5 deg. i seal Assembly stung into SBE @ 1,840 MD. (4.75" OD Bullet Seal Assembly) u 1 Liner 4 -112" L -80 12.6 ppf Hydril 563 l:, Tyr Bottom MD 1,794' 6,735' t TVD 1,488' 4,519' 4 -1/2" Hydril 563 Short Joint Locations: o 8 -112" hole, Cmt w/ 270 sks (105 bbls) 12.5 ppg Class G Lead cmt followed 3,038.1' - 3,057.9' MD w/970 sks (196 bbls) 15.8 ppg Class G Tail cmt. (20 -25 bbls cmt to surface) 3,626.8' - 3,646.6' MD NOTE: DID NOT Bump Plug, stopped cement displacement 8 bbls short . or total displacement. Liner Wiper Plug may be located @ 6,080' MD. Proposed Tyonek Perfs: ' MD TVD Net Ft Gun Type Date T1 5,741'- 5,761' 3,655'- 3,672' 20 ---AI Tyonek Perfs: • • MD TVD Net Ft Gun Type Date Ti 5,791' 5,809' 3,698' - 3,714' 18 ft 3-3/8" (12/20/08) Cement plug did not bump, may be located high © 6,230' MD Tagged on 12/14/2008 IN • 1.1 TD: PBTD: 6,737' MD 6,606' MD 4,522' TVD 4,406' TVD Well Name & Number: Susan Dionne # 6 Lease: Ninilchik Unit / Susan Dionne County or Parish: Kenai Peninsula Borough State: Alaska 1 Country: I USA Perforations (MD): 5,791' - 5,809' Perforations (TVD): 3,698' - 3,714' Angle /Perfs: 29.95° Angle @ KOP & MD: -3.35° / 100' @ 244' Date Completed: 12/20/2008 I Ground Level:I 135' KB Height Above Ground Level: 21' I KB Elevation:I 156' Revised by: Mike Sulley Last Revision Date: 12/29/2008 .��■ Company: Marathon Oil Company Job Number: 2284256 Calculation Method: Minimum Curvature Maas Field: Ninilchik Magnetic Decl.: 18.94° Proposed Azimuth: 253.01° Borough Kenai Peninsula Grid Corr.: n/a Depth Reference: RKB / INTEQ Well Name: SD #6 Total Survey Corr.: 18.48 Tie Into: Surface Rig: Glacier#1 Target Info: Tool Survey Inc! Azimuth Course TVD VS Coordinates Closure DLS Build Rate Walk Rate No. Type Depth (ft) (°) ( Lgth (ft) (ft) (ft) N/S (ft) E/W (ft) Dist (ft) Ang ( ( °1100') ( °/100') ( °/100') 1 Tie in 0 0.00 0.00 0 0.00 2 MWD 135 0.50 205.60 135 135.00 0.40 0.53 S 0.25 W 0.59 205.60 0.37 0.37 152.30 3 MWD 183 1.05 229.52 48 182.99 0.94 1.01 S 0.68 W 1.21 214.05 1.31 1.15 49.83 4 MWD 244 4.02 256.71 61 243.93 3.59 1.86 S 3.19 W 3.69 239.72 5.12 4.87 44.57 5 MWD 305 8.26 259.98 61 304.57 10.08 3.11 S 9.59 W 10.08 252.00 6.97 6.95 5.36 6 MWD 363 10.06 259.21 58 361.82 19.25 4.79 S 18.66 W 19.27 255.61 3.11 3.10 -1.33 7 MWD 424 11.27 259.96 61 421.77 30.46 6.82 S 29.77 W 30.54 257.09 2.00 1.98 1.23 • 8 MWD 483 14.52 259.72 59 479.27 43.53 9.15 S 42.73 W 43.69 257.91 5.51 5.51 -0.41 9 MWD 544 17.53 260.13 61 537.90 60.25 12.09 S 59.30 W 60.52 258.48 4.94 4.93 0.67 10 MWD 604 20.66 259.24 60 594.59 79.74 15.62 S 78.61 W 80.15 258.76 5.24 5.22 -1.48 11 MWD 665 23.59 258.79 61 651.09 102.59 20.00 S 101.16 W 103.12 258.82 4.81 4.80 -0.74 12 MWD 725 25.53 258.82 60 705.66 127.40 24.84 S 125.62 W 128.06 258.81 3.23 3.23 0.05 13 MWD 784 26.47 257.57 59 758.69 153.16 30.14 S 150.94 W 153.92 258.71 1.84 1.59 -2.12 4 14 MWD 847 27.71 257.84 63 814.77 181.75 36.24 S 178.97 W 182.60 258.55 1.98 1.97 0.43 15 MWD 911 30.33 256.82 64 870.73 212.70 43.06 S 209.25 W 213.64 258.37 4.17 4.09 -1.59 '6 MWD 974 32.46 255.76 63 924.51 245.47 50.85 S 241.13 W 246.44 258.09 3.49 3.38 -1.68 17 MWD 1037 34.17 253.79 63 977.16 280.05 59.95 S 274.51 W 280.98 257.68 3.21 2.71 -3.13 18 MWD 1101 35.99 251.72 64 1029.53 316.82 70.87 S 309.63 W 317.64 257.11 3.40 2.84 -3.23 19 MWD 1164 37.89 250.98 63 1079.88 _ 354.67 82.98 S 345.50 W 355.32 256.50 3.10 3.02 -1.17 20 MWD 1228 39.08 247.77 64 1129.98 394.40 97.02 S 382.76 W 394.86 255.78 3.63 1.86 -5.02 21 MWD 1291 40.60 244.55 63 1178.36 434.46 113.34 S 419.66 W 434.69 254.89 4.07 2.41 -5.11 22 MWD 1355 42.91 244.30 64 1226.10 476.60 131.74 S 458.10 W 476.66 253.96 3.62 3.61 -0.39 23 MWD 1419 45.46 244.90 64 1271.99 520.72 150.87 S 498.39 W 520.72 253.16 4.04 3.98 0.94 24 MWD 1482 48.28 246.11 63 1315.06 566.30 169.92 S 540.23 W 566.32 252.54 4.69 I 4.48 1.92 25 MWD _ 1545 51.28 246.37 63 1355.73 614.07 189.29 S 584.25 W 614.15 252.05 4.77 4.76 0.41 26 MWD _ 1609 54.47 246.62 64 1394.36 664.76 209.64 S 631.04 W 664.95 251.62 4.99 4.98 0.39 27 MWD 1672 58.19 247.92 63 1429.28 716.92 229.88 S 679.40 W 717.23 251.31 6.15 5.90 2.06 2II MWD 1735 61.28 249.34 63 1461.03 771.16 249.70 S 730.06 W 771.58 251.12 5.28 4.90 2.25 29 MWD 1799 63.63 251.41 64 1490.63 827.84 268.74 S 783.51 W 828.32 251.07 4.66 3.67 3.23 30 MWD 1861 65.65 252.84 62 1517.18 883.86 285.93 S 836.83 W 884.33 251.14 3.87 3.26 2.31 31 MWD 1924 68.12 254.24 63 1541.91 941.79 302.34 S 892.39 W 942.22 251.28 4.42 3.92 2.22 32 MWD 1970 69.77 254.46 46 1558.44 984.70 313.92 S_ 933.73 W 985.09 251.42 3.61 3.59 0.48 1 of 4 Mk II Company: Marathon Oil Company Job Number: 2284256 Calculation Method: Minimum Curvature Van Ninilchik Magnetic Decl.: 18.94° Proposed Azimuth: 253.01° MIO�ES Borough Kenai Peninsula Grid Corr.: n/a Depth Reference: RKB � �'' Well Name: SD #6 Total Survey Corr.: 18.48 Tie Into: Surface MAIATHON /) Rig: Glacier#1 Target Info: Tool Survey Inc! Azimuth Course TVD VS Coordinates Closure DLS Build Rate Walk Rate No. Type Depth (ft) ( (°) Lgth (ft) (ft) (ft) N/S (ft) E/W (ft) Dist (ft) Ang ( ( °/100') (° /100') (° /100') 33 MWD 2052 68.16 254.96 82 1587.87 1061.20 334.11 S 1007.55 W 1061.50 251.65 2.04 -1.96 0.61 34 MWD 2115 68.73 255.13 63 1611.02 1119.76 349.23 S 1064.16 W 1120.00 251.83 0.94 0.90 0.27 35 MWD 2179 68.69 255.55 64 1634.25 1179.34 364.32 S 1121.85 W 1179.52 252.01 0.61 -0.06 0.66 36 MWD 2242 68.70 255.90 63 1657.14 1237.97 378.79 S 1178.73 W 1238.10 252.18 0.52 0.02 0.56 37 MWD 2307 68.88 254.62 65 1680.66 1298.52 394.21 S 1237.33 W 1298.61 252.33 1.86 0.28 -1.97 38 MWD 2369 68.94 255.23 62 1702.97 1356.33 409.26 S 1293.19 W 1356.40 252.44 0.92 0.10 0.98 39 MWD 2432 68.95 255.35 63 1725.60 1415.08 424.18 S 1350.06 W 1415.13 252.56 0.18 0.02 0.19 • 40 MWD 2496 69.05 255.46 64 1748.54 1474.78 439.24 S 1407.88 W 1474.80 252.67 0.22 0.16 0.17 41 MWD 2558 68.81 253.81 62 1770.83 1532.61 454.57 S 1463.66 W 1532.62 252.75 2.51 -0.39 -2.66 42 MWD 2621 68.75 254.34 63 1793.63 1591.33 470.68 S 1520.14 W 1591.34 252.80 0.79 -0.10 0.84 43 MWD 2687 68.81 253.68 66 1817.52 1652.84 487.63 S 1579.28 W 1652.85 252.84 0.94 0.09 -1.00 44 MWD 2751 68.77 253.16 64 1840.68 1712.50 504.66 S 1636.46 W 1712.51 252.86 0.76 -0.06 -0.81 45 MWD 2814 68.77 252.13 63 1863.49 1771.23 522.17 S 1692.51 W 1771.23 252.85 1.52 0.00 -1.63 46 MWD 2877 68.73 252.63 63 1886.32 1829.94 539.95 S 1748.48 W 1829.95 252.84 0.74 -0.06 0.79 47 MWD 2941 68.74 252.04 64 1909.54 1889.58 558.04 S 1805.30 W 1889.59 252.82 0.86 0.02 -0.92 48 MWD 3003 68.76 251.30 62 1932.01 1947.35 576.22 S 1860.16 W 1947.36 252.79 1.11 0.03 -1.19 49 MWD 3066 68.77 252.22 63 1954.83 2006.05 594.60 S 1915.93 W 2006.07 252.76 1.36 0.02 1.46 50 MWD 3128 68.79 252.73 62 1977.27 2063.85 612.00 S 1971.04 W 2063.87 252.75 0.77 0.03 0.82 51 MWD 3192 68.81 251.92 64 2000.41 2123.51 630.12 S 2027.89 W 2123.53 252.74 1.18 0.03 -1.27 52 MWD 3255 68.73 252.55 63 2023.22 2182.23 648.03 S 2083.82 W 2182.26 252.73 0.94 -0.13 1.00 53 MWD 3318 68.78 251.88 63 2046.05 2240.94 665.97 S 2139.73 W 2240.97 252.71 0.99 0.08 -1.06 54 MWD 3382 68.82 251.70 64 2069.20 2300.60 684.62 S 2196.41 W 2300.63 252.69 0.27 0.06 -0.28 • 55 MWD 3445 68.92 252.50 63 2091.91 2359.35 702.68 S 2252.33 W 2359.39 252.67 1.20 0.16 1.27 56 MWD 3508 68.66 252.16 63 2114.70 2418.08 720.50 S 2308.29 W 2418.12 252.66 0.65 -0.41 -0.54 57 MWD 3572 68.77 252.07 64 2137.93 2477.71 738.82 S 2365.04 W 2477.76 252.65 0.22 0.17 -0.14 58 MWD 3635 68.77 252.40 63 2160.75 2536.43 756.74 S 2420.97 W 2536.48 252.64 0.49 0.00 0.52 59 MWD 3698 68.84 252.91 63 2183.52 2595.16 774.25 S 2477.03 W 2595.22 252.64 0.76 0.11 0.81 60 MWD 3762 68.73 253.06 64 2206.68 2654.83 791.71 S 2534.08 W 2654.88 252.65 0.28 -0.17 0.23 61 MWD 3825 68.05 253.13 63 2229.88 2713.40 808.74 S 2590.12 W 2713.45 252.66 1.08 -1.08 0.11 62 MWD 3890 67.04 252.75 65 2254.71 2773.47 826.36 S 2647.55 W 2773.52 252.67 1.65 -1.55 0.58 63 MWD 3953 64.58 253.66 63 2280.53 2830.93 842.97 S 2702.56 W 2830.98 252.68 4.12 -3.90 1.44 64 MWD 4016 62.53 252.50 63 2308.58 2887.33 859.38 S 2756.53 W 2887.38 252.68 3.65 -3.25 -1.84 65 MWD 4080 60.27 252.58 64 2339.22 2943.52 876.24 S 2810.12 W 2943.57 252.68 3.53 -3.53 0.13 2 of 4 Company: Marathon Oil Company Job Number: 2284256 Calculation Method: Minimum Curvature BAKER HES Field: Ninilchik Magnetic Decl.: 18.94° Proposed Azimuth: 253.01° HUG Borough Kenai Peninsula Grid Corr.: n/a Depth Reference: RKB IN f'EQ Well Name: SD #6 Total Survey Corr.: 18.48 Tie Into: Surface MAIATNON Rig: Glacier#1 Target Info: Tool Survey Inc! Azimuth Course TVD VS Coordinates Closure DLS Build Rate Walk Rate No. Type Depth (ft) ( ( Lgth (ft) (ft) (ft) N/S (ft) ENV (ft) Dist (ft) Ang ( (° /100') ( °1100') (°1100) 66 MWD 4144 57.90 252.51 64 2372.09 2998.42 892.71 S 2862.50 W 2998.47 252.68 3.70 -3.70 -0.11 67 MWD 4207 55.28 252.52 63 2406.78 3051.00 908.51 S 2912.66 W 3051.06 252.68 4.16 -4.16 0.02 68 MWD 4270 52.40 252.35 63 2443.95 3101.86 923.85 S 2961.14 W 3101.91 252.67 4.58 -4.57 -0.27 69 MWD 4334 49.53 252.03 64 2484.25 3151.56 939.05 S 3008.47 W 3151.62 252.66 4.50 -4.48 -0.50 70 MWD 4397 46.81 252.09 63 2526.26 3198.50 953.51 S 3053.13 W 3198.56 252.66 4.32 -4.32 0.10 71 MWD 4460 44.47 252.29 63 2570.31 3243.53 967.29 S 3096.01 W 3243.59 252.65 3.72 -3.71 0.32 72 MWD 4523 41.82 252.62 63 2616.27 3286.61 980.28 S 3137.08 W 3286.67 252.65 4.22 -4.21 0.52 • 73 MWD 4586 39.31 253.41 63 2664.13 3327.57 992.25 S 3176.26 W 3327.64 252.65 4.07 -3.98 1.25 74 MWD 4650 36.87 252.88 64 2714.49 3367.05 1003.69 S 3214.04 W 3367.11 252.66 3.85 -3.81 -0.83 75 MWD 4713 34.56 253.07 63 2765.64 3403.82 1014.46 S 3249.20 W 3403.89 252.66 3.67 -3.67 0.30 76 MWD 4777 31.94 252.96 64 2819.16 3438.91 1024.71 S 3282.76 W 3438.97 252.66 4.09 -4.09 -0.17 77 MWD 4840 29.81 253.73 63 2873.23 3471.24 1033.98 S 3313.73 W 3471.30 252.67 3.44 -3.38 1.22 78 MWD 4904 29.82 254.18 64 2928.76 3503.05 1042.78 S 3344.31 W 3503.11 252.68 0.35 0.02 0.70 79 MWD 4967 29.68 255.08 63 2983.45 3534.30 1051.06 S 3374.45 W 3534.36 252.70 0.74 -0.22 1.43 80 MWD 5027 29.73 255.36 60 3035.57 3564.01 1058.65 S 3403.20 W 3564.06 252.72 0.25 0.08 0.47 81 MWD 5094 29.78 255.00 67 3093.74 3597.24 1067.16 S 3435.35 W 3597.28 252.74 0.28 0.07 -0.54 82 MWD 5158 29.84 254.69 64 3149.27 3629.04 1075.47 S 3466.06 W 3629.07 252.76 0.26 0.09 -0.48 83 MWD 5221 29.84 255.05 63 3203.91 3660.37 1083.65 S 3496.32 W 3660.40 252.78 0.28 0.00 0.57 84 MWD 5284 29.79 255.12 63 3258.58 3691.67 1091.72 S 3526.58 W 3691.70 252.80 0.10 -0.08 0.11 85 MWD 5348 29.81 254.97 64 3314.11 3723.46 1099.92 S 3557.31 W 3723.48 252.82 0.12 0.03 -0.23 86 MWD 5411 29.77 253.79 63 3368.79 3754.75 1108.35 S 3587.46 W 3754.77 252.83 0.93 -0.06 -1.87 87 MWD 5475 29.80 254.36 64 3424.33 3786.54 1117.07 S 3618.03 W 3786.55 252.84 0.44 0.05 0.89 88 MWD 5538 29.87 254.23 63 3478.98 3817.87 1125.56 S 3648.20 W 3817.88 252.85 0.15 0.11 -0.21 89 MWD 5601 29.83 254.57 63 3533.63 3849.22 1133.99 S 3678.40 W 3849.23 252.87 0.28 -0.06 0.54 90 MWD 5664 29.86 254.72 63 3588.27 3880.56 1142.29 S 3708.63 W 3880.57 252.88 0.13 0.05 0.24 91 MWD 5728 29.90 254.67 64 3643.76 3912.43 1150.71 S 3739.39 W 3912.44 252.90 0.07 0.06 -0.08 92 MWD 5790 29.92 254.76 62 3697.50 3943.33 1158.86 S 3769.21 W 3943.34 252.91 0.08 0.03 0.15 93 MWD 5852 29.96 254.68 62 3751.23 3974.26 1167.01 S 3799.06 W 3974.26 252.92 0.09 0.06 -0.13 94 MWD 5918 29.75 255.88 66 3808.47 4007.09 1175.36 S 3830.83 W 4007.09 252.94 0.96 -0.32 1.82 95 MWD 5982 29.79 255.20 64 3864.03 4038.83 1183.30 S 3861.60 W 4038.83 252.96 0.53 0.06 -1.06 96 MWD 6045 29.68 255.43 63 3918.73 4070.06 1191.22 S 3891.83 W 4070.06 252.98 0.25 -0.17 0.37 97 MWD 6110 29.77 255.33 65 3975.18 4102.26 1199.35 S 3923.02 W 4102.26 253.00 0.16 0.14 -0.15 98 MWD 6173 29.68 254.80 63 4029.89 4133.47 1207.41 S 3953.20 W 4133.47 253.02 0.44 -0.14 -0.84 3 of 4 Company: Marathon Oil Company Job Number: 2284256 Calculation Method: Minimum Curvature Mini • 46§11$ Field: Ninilchik Magnetic Decl.: 18.94° Proposed Azimuth: 253.01° Borough Kenai Peninsula Grid Corr.: n/a Depth Reference: RKB (m INTEQ Well Name: SD #6 Total Survey Corr.: 18.48 Tie Into: Surface Rig: Glacier#1 Target Info: Tool Survey Inc! Azimuth Course TVD VS Coordinates Closure DLS Build Rate Walk Rate No. Type Depth (ft) (°) ( Lgth (ft) (ft) (ft) N/S (ft) E/W (ft) Dist (ft) Ang ( ( °1100') (° /100') (° /100') 99 MWD 6234 29.61 254.64 61 4082.90 4163.63 1215.36 S 3982.31 W 4163.63 253.03 0.17 -0.11 -0.26 100 MWD 6298 29.67 254.69 64 4138.53 4195.27 1223.73 S 4012.83 W 4195.27 253.04 0.10 0.09 0.08 101 MWD 6362 29.62 254.07 64 4194.15 4226.92 1232.25 S 4043.32 W 4226.92 253.05 0.49 -0.08 -0.97 102 MWD 6426 29.56 251.77 64 4249.81 4258.52 1241.53 S 4073.52 W 4258.52 253.05 1.78 -0.09 -3.59 103 MWD 6489 29.54 251.62 63 4304.61 4289.58 1251.29 S 4103.02 W 4289.58 253.04 0.12 -0.03 -0.24 104 MWD 6551 29.55 251.39 62 4358.55 4320.14 1260.99 S 4132.01 W 4320.14 253.03 0.18 0.02 -0.37 105 MWD 6615 29.53 251.38 64 4414.23 4351.68 1271.06 S 4161.91 W 4351.68 253.02 0.03 -0.03 -0.02 106 MWD 6678 29.66 251.48 63 4469.01 4382.78 1280.97 S 4191.41 W 4382.78 253.01 0.22 0.21 0.16 107 Projected 6737 29.66 251.48 59 4520.28 4411.97 1290.24 S 4219.09 W 4411.97 253.00 0.00 0.00 0.00 • 4 of 4 Page 1 of 1 • 411 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 9:58 AM To: 'Tank, Will'; Berga, Pete Subject: RE: SD #6 Will, No issues with the test pressure. I just didn't find it mentioned in the program. Regards, Tom Maunder, PE AOGCC From: Tank, Will [mailto:wjtank @marathonoil.com] Sent: Monday, October 20, 2008 9:54 AM To: Maunder, Thomas E (DOA); Berga, Pete Subject: RE: SD #6 Tom, I have checked with our reservoir and geology folks. This well will only be perforated, no stimulation is planned now or in the future, due to the formation type involved. Therefore, a test pressure of 1,500 psi on the tie -back would be appropriate. If you are OK with this value I will make sure that the test information is included in the rig paperwork so that it gets tested at that pressure. Looking back at Paxton 2, the last Ninilchik well that was tied back with 4 1/2 ", 1,500 psi was the pressure it was tested to. Thanks, Will From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, October 16, 2008 3:21 PM To: Berga, Pete; Tank, Will Subject: SD #6 Pete and Will, I am reviewing the permit application for this well. I don't find anything in the procedure (page 8 and page 9) regarding pressure testing the 4 -1/2" liner /tieback and the 4/1/2" x 9 -5/8" annulus. I presume the test value would be 1500 psi, however 1 don't find that specifically mentioned. Thanks in advance, Tom Maunder, PE AOGCC 10/20/2008 1 SARAH PALIN, GOVERNOR �q ALAS OIL AND ASST 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Willard J. Tank Advanced Senior Drilling Engineer Marathon Oil Company 3201 C Street, Suite 800 Anchorage, AK 99503 Re: Ninilchik Unit, Beluga /Tyonek Pool, Susan Dionne 6 Marathon Oil Company Permit No: 208 -160 Surface Location: 316' FSL, 1132' FEL, Sec. 6, T1S, R13W, SM Bottomhole Location: 867' FNL, 347' FEL, Sec. 12, T1S, R14W, SM Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, Daniel T. Seamount, Jr. Chair DATED this of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED --4#41 i4 di,t r STATE OF ALASKA OCT 1. 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION PE TO DRILL Alaska oil & Gas Cons. Commission 20 AAC 25.005 ee la. Type of Work: lb. Current Well Class: Exploratory III Development Oil ❑ lc. Specify if well is proposed' Yhurdye Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas si Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone isi Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket SI Single Well ❑ 11. Well Name and Number: Marathon Oil Company Bond No. 5194234 Ninilchik Unit - Susan Dionne 6 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3201 C. Street, Suite 800, Anchorage, AK 99503 MD: 6,654 TVD: 4,436 Ninilchik Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Beluga/Tyonek Pool Surface: 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. ADL- 359242 &ADL- 384372 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 373' FNL, 1,268' FWL, Sec. 7, T1S, R13W, S.M. November 1, 2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 867' FNL, 347' FEL, Sec. 12, T1S, R14W, S.M. 852.00 & 3,507.84 Property: 1,220 ft 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. KB Elevation 15. Distance to Nearest Well Surface: x - 213,309.794 y - 2,236,795.841 Zone - 4 (Height above GL): (21' AGL) 156 feet Within Pool: 2,095 ft - SD 5 16. Deviated wells: Kickoff depth: 200 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 68.81 degrees Downhole: 2,030 Surface: 1,062 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 L -80 PE 99' 0' 0' 120' 120' 12 1/4" 9 5/8" 40 L -80 BTC 1,979' 0' 0' 2,000' 1,564' 497 sacks 8 1/2" 4 1/2" 12.6 L -80 Hydril 563 6,633' 1,800' 1,487' 6,654' 4,436' 370 sacks lead, 966 sacks tail 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural R Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee is BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Willard J. Tank Title Advanced Senior Drilling Engineer Signature • ? 69....4.-/e( 4 1ti 7 r Phone 713 - 296 -3273 Date October 9, 2008 Commission Use Only Permit to Drill API Number: Permit Approval + See cover letter for other Number: 0700 'f6O 50 - /33. 7O5fA0000 'Date: 1� g (requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ne, gas hydrates, or gas contained in shales: Ikr Other: Samples req'd: Yes❑ Noi71 Mud log req'd: Yes❑ NoRr �j � �Z(� H measures: Yes❑ No V Directional svy req'd: Yes' No❑ 1��( +:/ `�1 . , 9 ,, Val `� � V as „.., k /&: 2 DA TE APPROVED BY THE COMMISSION : , COMMISSIONER Form 10 -401 Revised 12/2005 Submit in Duplicate ,� E ',, „y I N • Worldwide Drilling North America M M arathon O Compa Houston, Box 3128 MARATHON Houston, TX 77253 -3128 Telephone 713 - 629 -6600 Fax 713 - 499 -6737 October 9, 2008 Daniel T. Seamount, Jr. Commissioner State of Alaska RECEIVED Alaska Oil & Gas Conservation Commission 333 West 7 Ave, Suite 100 OCT 1 0 2008 Anchorage, AK 99501 Alaska Oil & Gas Cons, CommissiorA Anchorage Reference: Drilling Permit Application Field: Ninilchik Field Well: Ninilchik Unit — Susan Dionne 6 Dear Mr. Seamount Enclosed please find the PERMIT TO DRILL application, along with the associated attachments. The intent is to drill a well in the Beluga and Tyonek Pools in the Ninilchik Unit. For the directional data we utilize the National Geodetic Survey conversion in the program CORPSCON to calculate the State Plane Coordinates in NAD 27 for the planned and actual wellpaths from the NAD 83 data and present both in our directional survey attachment for the 10 -401. We also provide the same data electronically, so that the AOGCC has this for data input into their database. If you require further information, I can be reached at 713 - 296 -3273 or by e-mail at wjtank @marathonoil.com. Sincerely, Willard J. Tank Advanced Senior Drilling Engineer Enclosures • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska MARATHON MARATHON OIL COMPANY DRILLING PROGRAM Ninilchik Field Susan Dionne 6 Originator: Will Tank October 9, 2008 Date Reviewed by: Pete Berga /�V /D-- -off'` Date Brian Roy Date 1 0/9/200 8 Page 1 of 18 1110 1 Susan Dionne 6 Marathon Oil Company Drilling Program Alaska TABLE OF CONTENTS 1. Emergency Response Information 4 1.1 Directions to Location 4 1.2 Rig Contact Numbers 4 1.3 Marathon Emergency Response Contacts 4 1.4 Outside Emergency Response 4 1.5 Marathon Contact List 5 2. Regulatory Agency Contacts 5 2.1.1. Internal Regulatory Contact 5 2.1.2. External Regulatory Contact 5 3. Regulatory Compliance 5 4. Drilling Program Summary 6 4.1 General Well Data 6 4.2 Working Interest Owners Information 6 4.3 Geologic Program Summary 6 4.4 Summary of Potential Drilling Hazards 7 4.5 Formation Evaluation Summary 7 4.6 Drilling Program Summary 8 4.7 Casing Program Summary 10 4.8 Casing Design 10 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) 10 4.10 Casing Test Pressure Calculations 11 4.11 Blowout Prevention Equipment, Testing and General Procedures 12 4.11.1. Function Testing 12 4.11.2. Pressure Testing 13 4.12 Wellhead Equipment Summary 13 4.13 Directional Program Summary 13 4.14 Directional Surveying Summary 14 4.15 Drilling Fluid Program Summary 15 4.16 Drilling Fluid Specifications 15 4.17 Solids Control Equipment 16 4.18 Cement Program Summary 17 4.19 Bit Summary 17 4.20 Hydraulics Summary 18 4.21 Formation Integrity Test Procedure 18 10/9/2008 Page 2 of 18 • 1 Susan Dionne 6 Marathon Oil Company Drilling Program Alaska Attachments Group Attachment Attached Commercial Information AFE Days /Cost vs. Depth Curves X Project Objectives and Scorecard RSO Coding Information X Requisitions Vendor List Bonus Program Drilling Contract Regulatory / HES Information Emergency Evacuation Plan X H2S Contingency Plan n/a Regulatory Permits X Regulatory Rules and Regulations Risk Analysis Miscellaneous Programs (Vendors) Bit Proposal X Cement Proposal X Directional Plan X Fluids Program X Wellhead Equipment — Description /Drawings Drill String and BHA Summary Rig Mobilization /Mooring Procedure n/a Geological Information Location Map w/ offsets X Offset Data Proposed Formation Pore Pressure, Mud Wt & Fracture Gradient X Temperature Curves Geologic Structure Maps Geologic Cross Section Bathymetry Map n/a Analysis Riser Analysis n/a Station Keeping Analysis — Mooring /DP n/a Stress Check Casing Design File X Maximum Allowable Overpull Miscellaneous Information Wel!bore Diagram n/a Rig Elevations X Well Location Diagram X BOP Schematic X BOP Well Control Bridging Document Detailed Casing Specifications X Detailed Drill Pipe Specifications 10/9/2008 Page 3 of 18 • • Susan Dionne 6 Marathon OH Company Drilling Program Alaska 1. Emergency Response Information 1.1 Directions to Location Method Directions Air Latitude - 60 °06'46.174 "N Longitude - 151°3425.526"W (NAD 83) From the Kenai airport, go 0.5 mile South on Willow Street. Turn East on Main Street Loop, go 0.3 miles. Continue East on Ground Bridge Access Road 3.2 miles. Turn West on Kalifornsky Beach Road. Go West and then South, go 16.9 miles. Turn South on Sterling Highway, go 18.8 miles. Turn West onto road to the pad (Sterling Highway milepost 128.6). 1.2 Rig Contact Numbers Contact Office Cell Glacier Drilling Rig 1 Inlet Drilling Tool Pusher 907 - 283 -1314 907 - 394 -1321 Marathon Supervisor 907 - 283 -1312 907 - 394 -1317 1.3 Marathon Emergency Response Contacts Individual Postion Main Phone Alternative Kenai Gas Field Emergency Number 907 - 283 -6465 CERT 24 hrs Notification 1- 800 -MOC -CERT CERT Crisis Center Houston 713 - 296 -4230 713 - 296 -4237 1.4 Outside Emergency Response Location Contact Phone Fire Kenai / Soldotna, Alaska 907 - 262 -4792 Ambulance Hospital Kenai / Soldotna, Alaska Central Peninsula Hospital 907 -262 -4404 Kenai Police 907- 283 -7879 Police Kenai / Soldotna, Alaska Soldotna Police 907 - 262 -4455 State Police 907- 262 -4453 Coast Guard 800 - 478 -5555 Spill and Contamination Alaska Alaska State Spill Reporting National Response Center Oil / Toxic Chemical Spills 800- 424 -8802 Best Practices: 1 Policy: Post emergency notification information on rig floor, company man's and tool pushers' office Comments: 10/9/2008 Page 4 of 18 • • , Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 1.5 Marathon Contact List Contact Title Office Mobile Facsimile Home Will Tank Drilling Engineer 713- 296 -3273 713 - 203 -8398 713 - 499 -6737 832- 934 -2617 Pete Berga Drilling Superintendent 907 - 565 -3032 907 - 529 -0551 907 - 565 -3076 907 - 346 -3763 Bryan Roy Drilling Manager 713- 296 -3256 832 - 444 -4772 713 - 499 -6707 281- 246 -4686 Scott Szalkowski Geologist 713 - 296 -3390 713 - 301 -9834 Clyde Scott Reservoir Engineer 713 - 296 -2336 Craig Rang Completion Engineer 907 - 283 -1372 907 - 394 -1824 Ken Walsh Production Engineer 907 - 283 -1311 907 - 394 -3060 907 - 283 -3050 Rowland Lawson Drilling Supervisor 907 - 283 -1312 907 - 394 -0953 907 - 283 -1313 John Nicholson Drilling Supervisor 907 - 283 -1312 907 - 394 -2641 907 - 283 -1313 Dan Byrd Drilling Supervisor 907 - 283 -1312 907 - 394 -2641 907 - 283 -1313 Mitch Burns Drilling Supervisor 907 - 283 -1312 907 - 394 -2641 907- 283 -1313 2. Regulatory Agency Contacts 2.1.1. Internal Regulatory Contact Contact Title Office Phone Cell Phone Home Phone Facsimile Chick Underwood Regulatory Compliance 713- 296 -3254 979 - 830 -7927 979 - 836 -9390 713- 499 -6748 2.1.2. External Regulatory Contact Contact Title Office Phone Facsimile 24 hr Emergency Pager AOGCC 907- 793 -1236 AOGCC North Slope Pager - 907 - 659 -3607 BLM 907- 267 -1442 3. Regulatory Compliance Regulation Requirement Prior to Rig Move Notify Alaska Department of Natural Resources 24 hours before moving the rig, if going to Ninilchik or Kasilof. BOP testing interval requirement is now 14 days (20 AAC 25.035 e 10 A). BOP Testing Requirement for a 24 hour notice to AOGCC (20 AAC 25.035 e 10 F). Prior to Spud Requirement for a 24 hour notice to AOGCC. Water Sampling Test the rig camp water for the Class C drinking water permit. Cuttings Tank Take picture of cutting tank in use and after cleaning for the ADEC. Comments 10/9/2008 Page 5 of 18 • 0 Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4. Drilling Program Summary 4.1 General Well Data Well Name Susan Dionne 6 Lease / License Surface Location 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. WBS Code DD.08.17742.CAP.DRL Slot/Pad Susan Dionne Pad Field Ninilchik Unit Spud Date 11/1/08 (est.) KB (above MSL) 156' County /Province Kenai Peninsula API No. GL (above MSL) 135' State / Country Alaska Permit No. Perm. Datum KB Total MD 6,654' Well Class Development Water Depth N/A Total TVD 4,436' Rig Contractor Glacier Drilling Water Protection Depth Rig Name Glacier Rig 1 Best Practices: 1 Comments: 4.2 Working Interest Owners Information Company Working Interest Address Phone Facsimile Marathon 60% P.O. Box 196168 907- 561 -5311 907 - 565 -3076 Anchorage, AK 99519 -6168 Chevron 40% 4.3 Geologic Program Summary Surface Location Coordinates — NAD 83 From Lease /Block Lines 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. Latitude 60° 06' 46.174" N Longitude 151° 34' 25.526" W UTM North (Y) 2,236,547.541' UTM East (x) 1,353,336.589' Tolerance Pore Pore MD - RKB TVD — RKB Pressure Pressure Possible Formation (ft) (ft) (psi) (ppg) Lithology Fluid Content Beluga B2 (Primary Target) 3,803 2,216 7.7 — 8.8 Sandstone Gas Beluga B3 (Primary Target) 4,830 2,856 7.7 - 8.8 Sandstone Gas Tyonek T1 Coal A (Not a Prod Target) 5,704 3,613 7.7 — 8.8 Sandstone Gas/Water 10/9/2008 Page 6 of 18 • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska Depth (KB) Horizontal Displacement (ft) MD TVD +N / -S +E / -W Tolerance Target (ft) (ft) Location (Y) (X) (ft) Beluga B2 3,803 2,216 373' FNL, 1,268' FWL, Sec. 7, T1S, R13W, S.M. -780 -2,553 Circle 100' radius Beluga B3 4,830 2,856 600' FNL, 526' FWL, Sec. 7, T1S, R13W, S.M. -1,007 -3,295 Circle 100' radius Tyonek T1 Coal A 5,704 3,613 728' FNL, 107' FWL, Sec. 7, T1S, R13W, S.M. -1,135 -3,714 Circle 100' radius TD 6,654 4,436 867' FNL, 347' FEL, Sec. 12, T1S, R14W, S.M. -1,274 -4,168 Circle 100' radius Comments: 1. There are no zones from surface to TD that have water with a TDS of 10,000 ppm or greater. 2. No zones above the Beluga B2 (3,803' MD, 2,216' TVD) contain oil or gas. 3. The proposed top of cement is greater than 500' above the Beluga B2, the highest known hydrocarbon bearing zone. 4.4 Summary of Potential Drilling Hazards Hazard Event De B Discussion Precautions Bit or BHA balling Surface Hole Maintain high pump rates to keep bit and BHA clean. Use extra circulation time if necessary. Excessive Torque Production Use good hole cleaning techniques with high pump Excessive pumping on bottom could Hole rates. Add lubricant where necessary. result in hole washout. Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut -in procedures must be posted in the driller's dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H is anticipated. Gas sands will be encountered from +/- 3,803' MD (2,216' TVD) to total depth of the well. These sands will run from s depleted aal d d sd im o t Beluga lightly sands. The to Flo -Pro bove mud norm system pressure. that Lost will be circulation used to an drill the ifferential well will help ticking reduce are potential these risks hazar and s no lst so circulation materials will be on location. Weighting material will available on location for proper well control. Best Practices: 1 Comments: 4.5 Formation Evaluation Summary Interval LWD Electric Logs Mud Logs Surface None None None 0' — 2,000' MD Production None Reeves Quad Combo, MFT Pressures on Basic with GCA, shale density, temperature in and 2,000' — 6,654' MD shuttle. Pull GR- Neutron to surface. out, sample collection (10' samples). Completion N/A GR, CCL, CBL N/A Comments: 10/9/2008 Page 7 of 18 • • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.6 Drilling Program Summary Drive Pipe: N/A Conductor: 20" set to approximately 120', prior to drilling rig move. MIRU drilling rig. NU BOP as diverter on conductor. 1. RU crane and hammer. Drive 20" conductor to +/ -120 ft. RKB. RD crane and hammer. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20" SLC x 21 1/4 ", 2M flanged. 4. Nipple up 21 1/4 ", 2M diverter, 16" diverter valve, and 16" diverter line. 5. Function test diverter and diverter valve. Best Practices: 1 Comments: Surface: Drill 12 1/4" hole to +/- 2,000' set 9 -5/8" casing. 1. Drill a 12 1/4" hole to 2,000' MD (1,564' TVD) per the directional plan. 2. At TD circulate hole clean. Make wiper trip. TOOH. 3. Run and cement 9 5/8" casing. 4. Cut off 9 5/8" casing. ND diverter. o') n,1 5. Install 9 5/8" slip lock connection X 11" 5M flanged multibowl wellhead. !� ,y 6. NU 11" 5M X 13 5/8" adapter spool. NU 13 5/8" 5M BOP'S. Test BOP's and choke manifold to 250/1, psi. lk 7. Set wear bushing. Test surface casing to 1,500 psi. / 'l So Best Practices: 1 During cementing operations, take returns in the cellar, instead of into the pits. Eliminates the clean up of pits from cement that circulated to surface. Vac trucks will pull from cellar. Comments: Production: Drill 8 1/2" hole to +/- 6,654' set 4 -1/2" liner. Tie back to surface with 4 1/2" tubing. 1. PU 8 1/2" PDC bit and rotary steerable directional BHA. Drill out float equipment and 20' of new formation. CBU. 2. Test shoe to an FIT of 15 ppg. Estimated Leak Off EMW is 18.0 ppg. 3. Drill 8 1/2" hole to an anticipated TD of 6,654' MD (4,436' TVD) as per the directional program, short tripping as required. 4. At TD circulate hole clean. Make OH 5. RU logging company for shuttle system. wiper PU trip. 3 TO 1/2 "d rill pipe and shuttle assembly. TIH on 5" drill pipe and run quad combo open hole logs as per plan on drill pipe shuttle. TOOH and lay down shuttle equipment and 3 1/2" drill pipe. TIH with 5" drill pipe and run MFT pressures through the drill pipe as per Geology testing depths. POOH with MFT log. 6. TIH w/ 8 1/2" bit to TD for wiper trip. TOOH and lay down BHA and drill pipe. Pull wear bushing. 7. RU and run 4 1/2" Hydril 563 casing liner with hanger on drill pipe. Run liner to TD with top of liner at approximately 1,800' MD. On bottom reciprocate and rotate liner while circulating the hole. 8. RU cementing company. Cement 4 1/2" while reciprocating and rotating pipe. Drop wiper plug and bump plug to pressure up and set the liner hanger. Release hanger running tool, pick up and clear seal area of any cement. Pick up out of liner. 9. Circulate hole clean. If cement circulates, TOOH. If cement doesn't circulate, WOC, then prepare and pump liner top job. 10. Once cement is either circulated or the liner top is squeezed, PU mill for 4 1/2" along with string mill for 9 5/8" casing. Make cleanout trip to top of 4 1/2" liner with mill combo on drill pipe. Polish 4 1/2" liner seal bore. 11. Run 4 1/2" liner hanger packer with hydraulic pusher tool. Stab into polish bore receptacle and set packer. TOOH laying down drill pipe. 12. Set 11" x 7" spacer bushing in lower multibowl section to allow the 4 1/2" tubing hanger to set in the upper multibowl section. 10/9/2008 Page 8 of 18 • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 13. Run 4 1/2" tubing with seal unit. Displace hole with 6 % KCL. Space out tubing and land hanger. ND BOP, NU tree and test to 5,000 psi. 14. Rig down and move out drilling rig. Best Practices: 1 Pre -heat mud mix water to help in early shaker screen blinding issues with the mud. 2 Drill all hole sections with 5" drillpipe to maximize hole cleaning hydraulics. 3 Do not circulate on bottom longer than 1 hour prior to moving pipe on a short trip to minimize hole washout. 4 Put lubricant in prior to drill out of intermediate shoe. 3 -5% LoTorq is normally required, possibly more depending on solids in the mud. Maintain a minimum of 3% throughout the hole section. Comments: Care must be taken on trips to minimize the possibility of surging the hole. Completion: Completion will be done without a rig. This will include perforating via wireline on targeted zones. Best Practices: 1 Comments: 10/9/2008 Page 9 of 18 • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.7 Casing Program Summary MD (ft) Connection API Ratings Casing Makeup Hole a . = o 6, Size Weight ID Drift O. D. Torque Size m - -of6 0. m Y (in) Top Bottom (Ibs /ft) (in) (in) Grade Type (in) (ft -Ibs) (in) U F- 9 5/8 0 2,000 40 8.835 8.679 L -80 BTC 10.625 N/A * 12 1/4 5,750 3,090 979 41/2 1,800 6,654 12.6 3.958 3.833 L -80 Hydril 563 5.200 10,080 81/2 8,430 7,500 288 Best Practices: 1 Have float equipment made up at Tubescope's yard prior to bringing casing to location. Buck on all equipment to the pin end and not make up to box below, due to rig height restrictions. 2 Make up torque shown for the Hydril 563 is 80% of yield. The final make up torque for the liner should exceed any potential torque that would be used to release the running tool from the hanger. * - Make up buttress connection to proper mark, not to a torque value. Comments: 1 ALL CASING WILL BE NEW CASING. 4.8 Casing Design Casing Shoe Safety Factors Setting Maximum y C Casing Depth Mud Wt Frac. Form Surface O. Size Weight TVD When Set Grad Press Pressure E o (in) (Ib /ft) Grade (ft) (lb/gal) (tb /gal) (lb/gal) (psi) m U H 9 5/8 40 L -80 1,564 9.2 18.0 8.3 1,062 2.75 4.04 3.67 41/2 12.6 L -80 4,436 9.5 16.5 8.8 1,062 1.11 3.43 1.99 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) Setting Casing Depth Size TVD MAWP * MASP ** Mud /Gas (in) (ft) (psi) (psi) Percentage 9 5/8 1,564 3,952 1,062 30/70 4 1/2 4,436 3,952 1,062 30/70 * MAWP = Maximum allowable working pressure ** MASP = Maximum anticipated surface pressure The calculation method for MASPBHP has been modified from the standard AOGCC use of a Bottom Hole Pressure — 0.1 psi /ft gas gradient to what Marathon considers a more accurate Bottom Hole Pressure — 30% Mud Column — 70% Gas Column. This method follows the MMS standard for any well with a TVD of 12,000' or less. Marathon believes that constant gas monitoring and proper rig supervisor well control training will prevent the possibility of a wellbore being completely evacuated with only a gas gradient remaining. 10/9/2008 Page 10 of 18 • • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska Surface casing: 95/8 " (2,000' MD, 1,564' TVD) MASP _ g a t s h oe ) x .052 x TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (18.0 ppg x .052 x 1,564') - (0.1 psi /ft x 1,564') MASPfrac = 1,464 psi - 156 psi MASPfrac = 1,308 psi. MASPbhP = BHP open hole td — Hydrostatic pressure of mud portion — Hydrostatic pressure of gas portion MASPbhP = (8.8 ppg x .052 x 4,436') — (0.3 x 9.5 ppg x .052 x 4,436') — (0.7 x 0.1 psi /ft x 4,436') MASPbhP = 2,030 psi — 657 psi — 311 psi MASPbh = 1,062 psi MASP = MASPbh = 1,062 psi MAWP = (0.7 x Casing Burst) — (Mud Wt. — Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 5,750) — (9.2 — 8.3) x .052 x 1,564' MAWP = 4,025 psi — 73 psi = 3,952 psi Production liner: 4 1/2" (Top — 1,800' MD, 1,487' TVD) (Bottom — 6,654' MD, 4,436' TVD) MASP = MASP9 = 1,062 psi MAWP = MAWP9 = 3,952 psi Best Practices: 1 Comments: 4.10 Casing Test Pressure Calculations Casing test pressure calculations are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back -up unless otherwise noted. AOGCC regulations state that casing pressures must be 50% of the BOP working pressure documented on the approved permit to drill. Best Practices: 1 Comments: 10/9/2008 Page 11 of 18 i Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.11 Blowout Prevention Equipment, Testing and General Procedures BOP PROGRAM Casing Test Test Casing Test Fluid Pressure Size MAWP MASP press Density BOPS Low /High Casing (in) (psi) (psi) (psi) (lb/gal) Size & Rating (psi) (1) 13 -5/8" 5M annular p� (1) 13 -5/8" 5M pipe ram 90 Surface 9 5/8 3,952 1,062 1,500 9.2 (1) 13 5/8" 5M blind ram 250/1,5/0 P (1) 13 -5/8" 5M drilling spool with 3 -1/8" 5M outlets (1) 13 -5/8" 5M pipe ram (1) 13 -5/8" 5M annular (1) 13 -5/8" 5M pipe ram itib Production 4 1/2 3,952 1,062 1,500 9.5 (1) 13 5/8" 5M blind ram 250/1, 10 (1) 13 -5/8" 5M drilling spool with 3 -1/8" 5M outlets (1) 13 -5/8" 5M pipe ram Blowout Preventers The blowout preventer stack will consist of a 13 -5/8" x 5000 psi annular preventer, a 13 -5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13 -5/8" x 5000 psi drilling spool (mud cross) with 3 -1/8" x 5000 psi outlets, and a 13 -5/8" x 5000 psi single pipe ram. The choke manifold will be rated 3 -1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor -boy gas buster, and a vacuum -type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. 4.11.1. Function Testing Function Regularly. 10/9/2008 Page 12 of 18 • • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.11.2. Dril Pressung Ssg The Marathon liupervisor re Te tin will verify all pressure tests of BOP's, surface lines, seals, casings and FIT or LOT tests. All tests are to be recorded on the IADC and daily drilling reports. Best Practices: 1 Comments: 4.12 Wellhead Equipment Summary Component Description Casing Hanger Type Casing Head 11" 5M X 9 -5/8" Slip Loc W/ 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL1, PR1 11" x 7" Fluted Mandrel Tubing Head 11" 5M Studded Bottom X 11" 5M Flg Top, W/ 2, 2- 1/16" 5M Studded Outlets, U,AA,PSL1,PR1 11" x 4 1/2" Fluted Mandrel Adapter Flange 11" 5M X 4- 1/16" 10M W/ Seal Pocket and 4" H BPV Threads Best Practices: 1 Comments: 4.13 Directional Program Summary Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N / -S +E/ -W VS No. Description (ft) (ft) ( °/100') ( °/100') ( °/100') (deg) (deg) (ft) (ft) ( 1 Tie On 0 0 0 0 0 0 253.009 0 0 0 2 KOP 200.00 200.00 0 0 0 0 253.009 0 0 0 3 Build up Section 4.00 0 4.00 253.009 4 End of Build 1,920.23 1,535.54 4.00 0 4.00 68.809 253.009 - 267.28 - 874.69 914.62 5 Hold Section 0 0 0 68.809 253.009 6 End of Hold 3,859.84 2,236.66 0 0 0 68.809 253.009 - 795.76 - 2,604.21 2,723.07 7 Drop Section -4.00 0 4.00 253.009 8 End of Drop 4,830.07 2,856.00 -4.00 0 4.00 30.000 253.009 - 1,006.96 - 3,295.37 3,445.79 9 TD 6,654.49 4,436.00 0 0 0 30.000 253.009 - 1,273.53 - 4,167.77 4,358.00 10/9/2008 Page 13 of 18 • • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska o I , -- 1 1 I I y laao 1000 SD 6 T onek T1 Coal A_ 1 - 6 Beluga B2 SD 6 Beluga B3 c 4 S 2000 95/8„ 0 0— - - -... f ....... - - -_ ._. I ........ -. t @ 3000 SD6 Beluga B2 I p U,' SD6TD Z 1000 A�� r I - • IF I L 4000 SD 6 Beluga 63 z � C -2000 I SD6TD SD 6 Tyonek T1 Coal A I I 1 I ' 4 1/Z' - , - 5000 _ -- i i i i - -- - _ -- 1 f - - -- r i i -.._ i i _.- -3000— L .......- i - -- I I ' .. i i i ........._ 11. 1 l i ....... i i .......... 1 1 I f 0 1000 2000 3000 4000 4000 -3000 -2000 -1000 0 Vertical Section at 253.01° (1500 ft /in) West( -) /East( +) (1500 ft /in) Comments: Vertical section calculated from a reference azimuth of 253.01° taken from surface location to bottom hole location. Potential Well Interference: Well Distance (ft) Depth (MD) Susan Dionne 4 62.97 2,036 Susan Dionne 1 60.78 1,283 Susan Dionne 2 204.07 907 Susan Dionne 5 210.61 145 Susan Dionne 3 256.11 1,319 No serious interference exists. See attached directional plan and anticollision analysis for more details. Best Practices: 1 Comments: 4.14 Directional Surveying Summary Other Survey Interval MD (ft) MWD Survey Magnetic Multishot Gyro Multishot Tool Remarks Surface 0 — 2,000' X Production 2,000' — 6,654' X Best Practices: 1 Comments: 10/9/2008 Page 14 of 18 • 0 Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.15 Drilling Fluid Program Summary Interval — TVD Minimum Inventory F rom To Density Gel (ft) (ft) (lb/gal) Fluid Description Additives Viscosifier Barite 0 1,564 8.8 — 9.2 Gel / Gelex Spud Mud Gel, Gelex, Caustic Flo -Vis, PolyPac UL, KCI, SafeCarb F &M, 1,564 4,436 8.9 — 9.5 6% Flo -Pro NT w/ Safecarb Asphasol Supreme, Lo Torq, Conqor 404, Sodium Meta Bisulfite, Klagard Best Practices: 1 Comments: 4.16 Drilling Fluid Specifications Interval — TVD LSRV Drill From To Density Vis 1 min PV YP Fluid Loss Solids (ft) (ft) (lb/gal) (sec/qt) (Ib. /100ft (cP) (lb/100 ft (cc) pH ( %) 0 1,564 8.8 -9.2 60 -100 N/A 15 -24 > 30 < 18 8.0- 9.0 <6 1,564 4,436 8.9 -9.5 30,000 — 10 -16 12 -8 5 -7 9 -9.5 <6 40,000 Best Practices: 1 As a standard practice for tie -back string completions, displace the drilling mud above top of liner with brine treated with corrosion inhibitor (Congor 303A) at a concentration of 1 drum per 100 barrels of fluid. Comments: See mud prognosis for details. Sized CaCO3 (SafeCarb) and graphite will be used to control leakoff. 10/9/2008 Page 15 of 18 • • Sn Dionne 6 Marathon Oil Company Drng usa Program Alaska 4.17 Solids Control Equipment o 0 2 N N Ol C O N N M 41 m c c 0 r 0 0 m > > Interval U U v N Comments 0 — 6,654' MD X X X X Closed Loop System, Full Containment, Run shakers with finest screens possible Equipment Specifications Item (quantity, design type, brand, model, flow capacity, etc) Shaker 2 — Swaco Mongoose PT Desander N/A Desilter 1 — Derrick Model 0522 Mud Cleaner N/A Centrifuge 2 — MI /Swaco units Cuttings Dryer N/A Cuttings Injection Marathon G &I Facility Zero Discharge N/A Best Practices: 1 Have vacuum trucks pull fluids from trough above slop pit to more efficiently pull fluids for disposal. This minimizes water added to the solids to suspend for pickup by the trucks, thus minimizing total volume to be disposed of. Comments: 10/9/2008 Page 16 of 18 0 • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.18 Cement Program Summary Depth Gauge Top of Cement Gauge Ann Vol Slurry Casin Hole Ann Vol With OH Density Open Hole Thickening Size MD TVD Size MD TVD To TOC Excess Lead/Tail Excess Time (in) (ft) (ft) (in) (ft) (ft) (ft (ft (PPg) ( %) (hrs) 20 120 120 Driven N/A 95/8 2,000 1,564 121/4 0 0 758 1,233 12.0 75 8 4 1/2 6,654 4,436 8 1/2 1,800 1,487 1,383 1,918 12.5 / 15.8 40 N/A Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (lb/gal) (sx) (ft /sx) (ft (ft) (gal /sx) Type (cc) ( %) 8 hr 24 hr 9 5/8 Tail Type I Cement 12.0 497 2.48 1,233 0 10.33 Fresh Lead Class "G" 12.5 370 2.10 778 1,800 11.91 Fresh 4 1/2 Tail Class "G" 15.8 966 1.18 1,140 3,800 4.97 Fresh Best Practices: 1 Pump several fluid calipers at TD to help with the hole volume determination from the open hole caliper log. Comments: 1. Cement volumes on the production hole are based on 40% over gauge hole. Once the caliper log is obtained the team will need to discuss final excess. 2. Volume calculations assume 80' of internal cement for the shoe tracks. See cement prognosis for details and spacer specifications. 3. Centralizers for the casing strings will include at least 1 per joint on the bottom 3 joints as per BLM regulations. 4.19 Bit Summary Interval — MD Type Recommended Estimated Expected From To Size WOB Rotating Minimum ROP (ft) (ft) (in) Manufacturer Model No. IADC (kips) RPM Hours (ft/hr) 0 2,000 12 1/4 Christensen MX -1 115 27.5 - 65 Motor 2,000 6,654 8 1/2 Christensen HCM 506Z M323 Up to 29 Motor Best Practices: 1 Comments: See bit prognosis for additional information. Back up bits for the 8 hole section will consist of an MXL- 18DX (IADC 447) bit. • 10/9/2008 Page 17 of 18 • • Susan Dionne 6 Marathon Oil Company Drilling Program Alaska 4.20 Hydraulics Summary Max Press @ Displacement @ Max Rate @ Liner ID Stroke 90% WP 95% Vol. eff 95% Vol. eff Hole Sections Used Qty Make Model (in) (in) (psi) (gal /stroke) (spm /gpm) On 5 8 2,597 2.04 125 / 255 Surface 3 National Oil Well A600PT 5 8 2,597 2.04 125 / 255 Intermediate 5 8 2,597 2.04 125 / 255 Production Est. Hole Pump Standpipe Openhole Nozzle AP at Depth -MD Size Rate Pressure Min AV MW ECD Size bit (ft) (in) (gpm) (psi) (fpm) (ppg) (ppg) (32 "s) (psi) Remarks (Drill string configuration) 0 — 2,000' 12 1/4 700 2,051 137 8.9 9.61 2 — 18 s MI Virtual Hydraulics (@ 2,000' MD) 1 -16 2,000' — 6,654' 8 1/2 500 1,492 259 9.2 9.98 5 — 15's MI Virtual Hydraulics (@ 6,654' MD) Best Practices: 1 Drill all hole sections with 5" drilipipe to maximize hole cleaning hydraulics. Comments: See separate hydraulics calculations. Annular velocities in the 12 1/4" and 8 1/2" holes were calculated using 5" drilipipe. 4.21 Formation Integrity Test Procedure The surface casing shoe will be tested to an FIT instead of Leak -off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak -off tests (LOT) are to be conducted as described below: 1 D 20' t 25' o f new f orma ti on b th cas s h o e and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drilipipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut -in for 10 minutes or until the shut -in pressure stabilizes. FIT tests are to be conducted the same as described by the LOT test above, except in step 4, where the pumping would stop at the specified pressure to achieve an FIT required. Note that leakoff is always possible, prior to the specified FIT, due to formation variations. Best Practices: 1 Comments: 10/9/2008 Page 18 of 18 • • Marathon Oil Well Susan Dionne 6 Diverter ‘41111 Flow line 21 1/4" 2M Diverter 16" Automatic Knife Valve Diverter Spool 11 1 1 1 o � • 16" Diverter Line . . Marathon Oil Well Susan Dionne 6 BOP Stack (Flow Nipple (Flow Line 1 1 i 13 5/8" 5M Annular Preventer 1 < 13 5/8" 5M Double Ram Preventer 'Pipe Ram 2 1/16" 5M (Blind Ram Ch Valve 2 1/16" 5M Manually 3 1/8" 5M Manually Operated Valves < Operated Valve 1 X J _ _ X I Kill I 'Choke lII\©III X 13 5/8" 5M Cross < 3 1/8" 5M Hydraulically (Pipe Ram I Operated Valve 13 5/8" 5M Single - Ram Preventer > < Bottom of Single gate must be 1 14 24 -45" from ground level for Glacier 1 rig placement. 135/8 "5Mx135 /8 "5M Drilling Spool I11 "5Mx135 /8 "5MDSA • Marathon O il Well Susan Dionne 6 Choke Manifold Bleed off Line to To Gas Buster To Blooey Line Shakers TIF INI■11 It 1 1 i 1 / I °p qQ 000 - 0°g 6 0 0 1 °6 0 °6 1 7 I I I ' I I ' I I I I 1 1 1 � I ( I I I 11 413 © r I I P6 u -1 r1 © u � II[OiIIII[OiII 0 11(0111 ii oiII 3" 5M Valves © 2 9/16" 10M Swaco 1 1 3 1/8" 5M Manually Hydraulically Operated Adjustable Choke Choke Gauge Block Choke Hose to HCR (from BOP Stack) 0 - 6,000 psi Choke Control Pressure Gauge Pressure Sensor ■ "Ktt" Mid N f;tmelora atisrafew Valais f.:hanti awamisaa 11. r wuf _ Gn u- U 'Its 3t- l I t } from 0-4500 nrx fhiF Urthrll rr1 minute i 1 I regulation %I e£ ii.g c a. ' • ricnrn y 14.90.0. Pr wre mules operating r .r ;_ " 8 Va lve- Normal sr low ti 4r!r*4 .. „ Y lxe by 1 i For ratlOOs river ar S ' 1600t. Move tv huh arrzuntl 3000 ,. i p reseure[r }ttt) positron i i j ( y j j . ` j Manifold pressure _mil �, r Gauge- 0.6000 ill normally 1500psr I g. )l ira rsmc tsr latt+sr � Vawe „ I gee 0 L pre5sure ' Screen Prsuna t 0 Fh tfle Pressure Sw4C£h - - waic punitnwtheri they reacts -:. t ..:. Il 3000 psi and Marts when a i3 the pleasure drops to �...,_ ,, lii ciftspird 6,. :' • la' to MOW U taplesion Prod Electric Motor E Air lu£xicator- ;Accumulator Reht Valve Use SAE10. set "POP Off -set at 3200PS1 . �. ° w. , , ` at 6 drops , _ "fi weeklyhee e w mm r - Isolation �� . � .. -,.,_ Belt Guard Triplex Galley I Air Pressure Switch Electric { Valve for , Bypass- Normally closed. Drain Valve Air Pumps - Motor Triplex 60 -1 Ratio but open with pressures Triplex Pump- Switch Pump- 13 above 3000 psi Check oil level KePP'r Normally It Suction Strainer i} y auto often For Air Pum ps Itf ti monthr lOw 4 positron I c for Suction Valve For Turn off , pressure Air operated when I, exceeding Pumps- reamians servicing li 3000 PSI open, close during fA ■ serveleing L Suction strainer for Tiplex pump clean every 30 days • • Surface Use Plan for Ninilchik Unit — Susan Dionne 6 Surface Location: 316' FSL, 1,132' FEL, Sec. 6, T1S, R13W, S.M. a. Existing Roads Existing roads which will be used for access to Susan Dionne 6 are shown on the attached map. Ninilchik, Alaska is the nearest town to the site and is also shown on the topographic map. 1. Marathon owns the existing road and will maintain the road in a proper manner before, during, and after drilling operations. Plans for maintaining the road would include grating and adding road materials to maintain road grade. This is an unpaved road. 2. Marathon will not use any roads under Forest Service jurisdiction. b. New or Reconstructed Access Roads No new roads will be required to access Susan Dionne 6. c. Location of Existing Wells Well Susan Dionne 6 will be drilled on Susan Dionne pad. A signed surveyor as -built drawing is enclosed that shows existing wells and the location of Susan Dionne 6. d. Location of Existing and /or Proposed Production Facilities The locations of existing production facilities in the Susan Dionne pad are shown on the signed surveyors as- built drawing. A flowline will be installed from the Susan Dionne 6 wellhead to the existing production facilities. e. Location and Types of Water Supply A water supply well exists on the pad that Susan Dionne 6 will be drilled from. This is shown on the as -built drawing. Marathon has a Temporary Use Water Permit (A2007 -89) from the Alaska Department of Natural Resources. The well is approved for potable use a Class C water system by the Alaska Department of Environmental Conservation. f. Construction Materials The existing pad will be expanded prior drilling operations. There are no topsoil or material stockpiles on the pad. g. Methods of Handling Waste; 1. Mud and Cuttings Cuttings will be dewatered on location. The drilling waste and fluids will be hauled via vacuum truck to Pad 41 -18 of the Kenai Gas Field for disposal into a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81 -176). Marathon obtains a temporary waste storage approval from the ADEC for temporary onsite storage. 2. Solid Waste All household and approved non - hazardous solid waste will be hauled to the Kenai Peninsula Borough Soldotna Landfill. Oily materials (rags and /or plastic liner) are disposed by a third party. 1 3. 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). 4. Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. 5. Sewage There is no discharge onsite and all waste water will be hauled to the Kenai sanitation facility by a qualified 3rd party. h. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately five mobile trailer house type structures will be utilized for this purpose. No camps, airstrips, or staging areas will be constructed. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. A qualified 3rd party will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. i. Well Site Layout Please see the attached plats identifying the pad and the location of drilling rig over Susan Dionne 6, with the approximately planned orientation. The Glacier rig utilizes a closed loop system, no earthen pits are utilized. All fluids are contained in steel tanks as part of the rig package. j. Plans for Surface Reclamation Susan Dionne 6 will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of Susan Dionne 6 and the other existing wells on the pad. k. Surface ownership The surface owner of the land for the Susan Dionne pad is Marathon Oil Corporation. I. Other Information 1. Marathon's Glacier drilling rig has multiple containment features including a timber -diked plastic liner laid on top of the drilling pad. Each rig component sitting on top of the plastic liner has it's own containment system. 2. All rig operations are preceded by a pre -job safety meeting. Marathon acknowledges that all personnel, contract or Marathon employee, can stop the job if there is a safety or environmental concern. • • • Operator Certification Field: Ninilchik Well: Ninilchik Unit - Susan Dionne 6 Surface Location: 316' FSL, 1,132' FEL, Section 6, Township 1S, Range 13W, SM AK I hereby certify that I, or someone under my direct supervision, have inspected the drill site and access route proposed herein; that I am familiar with the conditions which currently exist; that I have full knowledge of state and Federal laws applicable to this operation; that the statements made in this APD package are, to the best of my knowledge, true and correct; and that the work associated with the operations proposed herein will be performed in conformity with this APD package and the terms and conditions under which it is approved. I also certify that I, or the company I represent, am responsible for the operations conducted under this application. These statements are subject to the provisions of 18 U.S.C. 1001 for the filing of false statements. Executed this 9 day of October , 20 08 Name Willard J. Tank � W < )-74- Position Title Advanced Senior Drilling Engineer Address P.O. Box 3128, Houston, TX 77253 -3128 Telephone 713 - 296 -3273 Field Representative Pete Berga (Drilling Superintendent) (if not above signature) Address 3201 C Street, Suite 800, Anchorage, Alaska 99503 (if different from above) Telephone 907 - 565 -3032 (if different from above) E -mail witank(afmarathonoil.com (optional) • • r i d / RD I.i1 " iii. "`` :- / / 1 �� /. i� � / / �� 1976 /`�,�/ /:` 2 -12" BRASS CAP / / > ` � 02237772689 / Z\�. -"ta" CAIN -�� .� l , , ' r E 214462.077 �- / ,� � (S D NO. 6 AS- STAKED w/ / , / / NAD27 ASP ZONE 4 �' --� I / / N:2236795.841 7/ / / / E:213309.794 I /` ,��/� // LATITUDE : 60 °06'48.3841 i na / LONGITUDE: 151 °34`1' %.716"W �� / t ELEV. 142' PROPOSED PAD 4 (( � � NGVD29 �'' / "O / j 1132' F , � e o ��6 Q � 316' • L / 1132' FEL -- •�,_• 1 . r MANGATE r ■ GATE J ■ • ROPOSED SUSAN DIONNE PAD /!/ •-12'CMP • Ez�E rIN� • SECTION 6 T1 S R13W S.M., AK / SD -2 TO RELOCg Nc E • PORTION OF GOV'T LOT 2 1 ELEV-138.54' EO �.¢! • • PARCEL 2 KPB RES. 99-25 N 2236706.324 ® J _ • 0213021.890 EXISTING SUSAN DIONNE PAD CONTROL / 0/ BUILDING ® ®® * • ® SD -3 a!l WATER WELL j A ® H ELEV= 13A21' LL I/ I N 2236677.806 SO • . -5 - E 212976 691 ELEV =139.59' I N 2238631.451 • SO -1 E 213177.148 .y ELEV = 139.31' /y, N2236632.185 SO-4 A! '� 1 +. '' 2 E 212950.360 ELEV = 138.61' �W' 1 1. .1 �` 60 • 4 I • N 223658 / to ! / E 213102 ® / Q b ODUCTION 2 • 'CAUTION- / N 2236453.004 w I B UILDING {�p I 2 41011 PRESSU 0 214434.704 ® I Y LATERAL GAS Yl • .. 7.9' PIPELINE TO ICAP1 / GLO . / DIO 4 T19 R13W 6185 • ELEV.. 139.33' '`6 GATE 1` T • MAN GATE P9•� >> 8 57 SB ■ • ■ • - ■ 6�■6 • -- 4 • ■ 1919 1 E1I16 T am \ -- N 223115785. 33' SECTION LINE EASEMENT a_ t�, `Y J 1 E 213115.872 V. 135.73' , SECTION 6 SECTION 7 47265 1" T E 1/16 33' SECTION LINE EASEMENT + PAUL AND SUSAN DIONNE PROPERTY AURORA COMMUNICATIONS PROPERTY 1987 1. BASIS OF HORIZONTAL COORDINATES AND ELEVATIONS . ., ""111 IS NGS MONUMENT V82 AT MILE POST 127.8 OF THE * 'E ' A .. I .1,5 4- 1 1 STERLING HIGHWAY. THE ELEVATION OF V82 IS 283.59 - -Q •. 4 :-7 , FEET (NGVD 29). THE HORIZONTAL COORDINATES ARE 0 * 4 * / ALASKA STATE PLANE NAD 27 ZONE 4 AND ARE N H .., - 'C.... -, BASED ON PUBLISHED COORDINATES FROM THE STATE �( � SCOTT MCLAN i OF ALASKA DE OF TRANSPORTATION AND I " • 4928 —S PUBLIC FACILITIES GEOREFERENCING PROJECT PHASE i SCALE /III i 619 AND II GPS CONTROL POINTS N 2240672.397 E 218213.289 ASP ZONE 4 NAD27. 0 �I 1 2 0 0 1 1 11\ ° ; FEET I PROJECT REVISION: 0 MARATHON SD NO. ON SUSAN DIONNE PAD NINILCHIK DATE: 6 Q � ANY AS- STAKED SURFACE LOCATION DIAGRAM DRAWN BY: WM WARM= A >R>ec11ot1 NAD27 FOR INFORMATIONAL PURPOSES SCALE: 1.61 • ONLY PROJECT NO. 063073 BOOK NO. 08-03 ENGINEERING / MAPPING / SURVEYING /TESTING Consulting Inc VOIC ( 6 0 7) 28 3..4218 8OO F FAX FA 2634Z LOCATION SEC. 6 Ti S R13W SHEET EMAIL: SAMCLANE@MCL/WECG.COM SEWARD MERIDIAN, ALASKA 1 1 • • Ninilchik Unit — SD /PAX Area Well Path Basemap ' 1 35 � 36 31 32 2 1 5 4K9 11 12 °5 7 ' 14 13 18 17 ++ f 1 mile • • Marathon Oil Company Project: Susan 1)ionne No. 6 v , HA53. 4.1 1,, SW ' /s, SE '/s, 6, T1S, R13W Seward Meridian - z Y Project Location -s . Jacklnsky Ranch n NI A. .x No 4 g yy t N rn1 <hlk ,� 1 • o =n.cy 94 d a„. i .,,✓ a y2 za, • v � q � NinikMM \\ ,/ Undo y t �p \\ _ 9 N Yppgg ape C, E,53r, s�� 18 1 16 15 SELDOVlA 0 40 1 • 5 . •e.:n. . . . , , 5' _ . 1582o9nm.E, 151 °30 KENAI (A -5) QUADRANGLE ALASKA — KENAI PENINSULA 8OROUCH 1 SCALE 1 63360 t &3360 SERIES (TOPOGRAPHIC) � .,�: °; �_�_�.,,�_ u _-__ -- � __-- ______�__.__ �__._., _ 3090 0 3000 9300 3000 12Q® 15900 18030 21040', 4'FJ F-*- — r .5 0 1 2 3 4 5 •101,4(15705 GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT .err s,..v F ---- ' 1 1 46144 , • r -, KOOKY 3' x 12' ' '; ' rim I-- WA 3406 � 1 .,..,.. CENTRIFUGE i l; i :1. . MIT i . „ w • 4'X20' 5V 9L 5V 9L y A-600 PT A-600 PT x sater DUMP 75 HP 75 HP 75 HP 75 HP DITA 3406 ' 1 .r ! ^ Z i ' 6X5 6X5 6X5. 6 X5 L ...../ J t n• 11• 1r 11• ; L .fJ , ; • . • i - • 1 _ L ! E I a «u waist _ , it r ■ .. • 4 , L__J U r t • 1 • • ` •� 1 4 • • r • • r- -i q j 1} o ii e [ I is. 4;4-1 40" 1 my() age0 NIO Tai M >jN MIL PIT 1 E M M MA ATHON Oil Company DER■ L ocation: Cook Inlet, Alaska (Kenai Penninsula) Slot: SD #6 Field: Ninilchik Field (NAD83) Well: SD #6 HUGh ES MARATHON Facility: Susan Dionne Wellbore: SD #6 I7TEQ Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 Location Information Facility Name Grid East (USft) Grid North (USft) Latitude Longitude Susan Dionne 1354461.500 2236204.700 60 °06'43.062 "N 151 0 34'03.175 "W Slot Local N (ft) Local E (ft) Grid East (USft) Grid North (USft) Latitude Longitude SD #6 316.06 - 1132.74 1353336.590 2236547.540 60 °06'46.174 "N 151°3425.526"W Comment 22- Apr -08: Changed surface per P Berga email Glacier #1 (RKB) to Mud line (Facility: Susan Dionne) 156ft Mean Sea Level to Mud line (Facility: Susan Dionne) Oft Glacier #1 (RKB) to Mean Sea Level 156ft Well Profile Data Design Comment MD (ft) Inc ( °) Az ( TVD (ft) Local N (ft) Local E (ft) DLS ( °/100ft) VS (ft) RKB Elevation 156' 0.00 0.000 253.009 0.00 0.00 0.00 0.00 0.00 • KOP 200.00 0.000 253.009 200.00 0.00 0.00 0.00 0.00 EOB 1920.23 68.809 253.009 1535.54 - 267.28 - 874.69 4.00 914.62 Begin Angle Drop 3859.84 68.809 253.009 2236.66 - 795.76 - 2604.21 0.00 2723.07 EOD (Beluga B3) 4830.07 30.000 253.009 2856.00 - 1006.96 - 3295.37 4.00 3445.79 TD 6654.49 30.000 253.009 4436.00 - 1273.53 - 4167.77 0.00 4358.00 Targets Name MD (ft) TVD (ft) Local N (ft) Local E (ft) Grid East (USft) Grid North (USft) Latitude Longitude SD #6 Beluga B2 (NAD83) 1-Oct-08 2216.00 - 779.21 - 2555.59 1350763.19 2235829.41 60 °06'38.497 "N 151°35'15.949"W SD #6 Beluga B3 (NAD83) 1- Oct -08 2856.00 - 1006.96 - 3295.38 1350018.20 2235619.35 60 0 06'36.253 "N 151°35'30.544"W SD #6 T1 Coal A (NAD83) 1- Oct -08 3613.00 - 1135.99 - 3713.42 1349597.20 2235500.31 60 0 06'34.981 "N 151°35'38.791"W SD #6 TD (NAD83) 1- Oct -08 4436.00 - 1275.87 - 4167.21 1349140.21 2235371.28 60 °06'33.602 "N 151 Bottom Hole Location MD (ft) Inc ( Az ( °) TVD (ft) Local N (ft) Local E (ft) Grid East (sry ft) Grid North (sry ft) Latitude Longitude 6654.49 30.000 253.009 4436.00 - 1273.53 - 4167.77 1349139.71 2235373.63 60 °06'33.625 "N 151°35'47.754"W Hole and Ca sing Sections Start End Start End Start Start End End Name MD (ft) MD (ft) Interval (ft) ND (ft) TVD (ft) Local N (ft) Local E (ft) Local N (ft) Local E (ft) Wellbore 12 1/4" Open Hole 0.00 2000.00 2000.00 0.00 1564.37 0.00 0.00 - 289.01 ' - 945.82 SD #6 9 5/8" Casing Surface 0.00 2000.00 2000.00 0.00 _ 1564.37 0.00 0.00 - 289.01 - 945.82 SD #6 8 1/2" Open Hole 2000.00 6654.49 4654.49 1564.37 4436.00 - 289.01 - 945.82 - 1273.53 - 4167.77 SD #6 4 1/2" Casing Production 0.00 6654.49 6654.49 0.00 4436.00 0.00 0.00 - 1273.53 - 4167.77 SD #6 • I MARATHON Oil Company BAKER Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: SD #6 HUGHES tp �a Field: Ninilchik Field (NAD83) Well: SD #6 IN Q MARATHON Facility: Susan Dionne Wellbore: SD #6 Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 o -375 — r 0 — RKB Elevation 156' KOP 4.00° o 375 — 16.00° " 750 — 28.00° " 4.00 ° /100ft 1125 — 40.00° " 52.00° " 1500 — 64.80' c —i EOB 9 5/8" Casing Surface 1875 — t CD 2250 — SD #6 Beluga B2 (NAD83) 1- Oct - 08 88 . ; Begin Angle Drop f6 56.80' U r 2625 — 4.00 ° /100ft 44.80° 7 F' 32.80° SD #6 Beluga B3 (NAD83) 1 Oct - 08 EOD (Beluga B3) 3000 — 3375 — SD #6 T1 Coal A (NAD83) 1 Oct - 08 3750 — 4125 — (NAD83) 1 4500 — SD 1 Casinng Production , 4875 — 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -375 0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 Vertical Section (ft) Azimuth 253.01 with reference 0.00 N, 0.00 E M MARATHON Oil Company BA KER L ocation: Cook Inlet, Alaska (Kenai Penninsula) Fie (NAD83) Slot: SD #6 HUGHES Field: Ninilchik Field NAD83 Well: SD #6 MARATHON Facility: Susan Dionne Wellbore: SD #6 INTEQ Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 • • Scale inch =500fl Easting (ft) -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 I I I I I I I I I I I I I I I I I I I 250 — — 250 • SD #6 RKB Elevation 156' 0 — — 0 -250 — 9 5/8" Surface Casing t EOB — -250 t7 500 ■ — -500 z 0 0) M. c _ 7 t (Q 0 z 750 _ Begin Angle Drop SD #6 Beluga 62 (NAD83) 1 - Oct - O8 — -750 74' 4111 -1000 ■ EOD (Beluga B3) illS SD #6 Beluga B3 (NAD83) 1 - Oct - 08 ••• -1000 SD #6 T1 Coal A (NAD83) 1 Oct - 08 - 1250 — ',' — - 1250 So d6 SD #6 TD (NAD83) 1 Oct - O8 4 1/2 "Production Casing • -1500 — — -1500 I I I I I I I I I I I I 1 I I I I 1 I -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 Scale 1 inch =500ft Easting (ft) Planned Welipath Geographic Report Report Generated ' _' b 01- Oct -08 at 10:35:20 - - - - -- Projection System NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Operator All1111111111111111111.1W MARATHON Oil Company - - - - -- North Reference _ - _ - li/EM Area Cook Inlet, Alaska (Kenai Penninsula) - - - -- Scale _ - - -- 0.999994 - Field 1IIIIIIIIIIIIMIIIIIIII.M.IIIIIIrt Ninilchik Field (NAD83) - - - - -- Horizontal Reference Point ElrilliMill FactliMIMMIMMINIIIIIMM EME2EMMIMII Vertical Reference Point Glacier #1 (RKB) Slot EEIMIN111.11.1111111 MD Reference Point _ -- _ -- Glacier #1 (RKB) Well "®- - - - - -- Field Vertical Reference - - -- =- - Wetibore ®_ - - - - -- Glacier #1 (RKB) to Facility Vertical Datum -_ - -- 156.00 ft MIMMIIIMMMI Wellpath SD #6 Version #4 - - - --- Glacier #1 (RKB) to Mean Sea Level 156.00 ft Wellbore Last Revised" 08/07/2008 - -- - - -- Facility Vertical Datum to Mud Line (Facility _ -- 0.00 ft - MMIIMIIII Sidetrack from ,''- - -- --- Section Origin X E 0.00 ft MINI User EEMMMIIMMIMIIIMI111111. Section Origin V N 0.00 ft MIMIIIIMMIIIII Calculation method - - - - -- Section Azimuth EIZEIMI- ------ - - - - -_ - - -- Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft] _._ (USft] Slot Location 316.06 60 °06'46.174 "N Facility Reference Pt pR I - "o 1354461.50 2236204.70 60 °06'43.062 "N Field Reference Pt l W" 1371967.44 2251649.81 60 °09'19.105 "N 151 °2624.639"W - - -- TVD from MD Inclination Azimuth TVD Rd Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [1 [ "I [ft] [ft] [ft] [ft] [sry ft] [sry ft] [ft] [ft] [ ° /100ft) [°] [° /100ft] [ ° /100ft] [ft] 0.00 0.00 ®' 0. 00 - 156.00 0.00 0.00 INEMEIMEMEMMEMEMBEE 60 °06'46.174 "N lialiMEEEI 0.00 0.00 0.00 0.00 0.00 100.00 0. mom 100.00 -56.00 0.00 0.00 mEzEimmomammomm 60 °06'46.174 "N EMEMEMI 0.00 0.00 0.00 0.00 0.00 MIIIII 200.00 0.00 WM= 200. 1111MEM o.00 o.00 MEEMENEEMEMME= 60 °06'46. ^N = o.00 - 106.99 0.00 0.00 0.00 300.00 IMEMMEMEM 299.92 IIESIMMIIMMEEM® 2236546.60 MaMEEM 2236786.97 60 °06'46. "N EZIEMEMIMMIEM 0.00 MEICM 0.00 MiXEM 400.00 6.00 ®i MIMEMMEEM=3:L® ®MIEE= 60 °06'46.134 "N MEMEMIMEEM 0.00 MI= 0.00 Minl 500.00 IlliECIMEMMEMEESMELIEUEIMMECEMIMEESEMENEEEMEIMM=M 2238779.49 60 °06'46.084 "N MiligiMMEM 0.00 MEM 0.00 MallEM 600.00 16.00 ®'MEZIM®' MEMEMEMEEM 213264.00 MZEIDECAI 60 °06'46.015 "N EalliMMEIMEM 0.00 MEM 0.00 700.00 20.00 MEM= 689.91 MEEIMMIENIIIIIMM®' ' EEMEEMIEZEIM 60 °06'45.926"N Mi=IMEM 0.00 MEM 0.00 86.38 800.00 MEMMEMEMMEEM 626.61 ME3E111111111MEM® 213198.18 MEE=CM 60 °06'45.818 "N EliEEZIMMILEMI 0.00 MICIM 0.00 INEEMI 900.00 MIEMMEMEMMIESIMEZEM - 49.00 IffECEMEEMME 2236502.38 MED=MMEMIOM 60 °06'45.692 "N 151°34'28.690"W mom 0.00 maim 0.00 Effsm 1000.00 MEEEMMEMIMI 959.05 MIRMIIMMEMEEXIMEIMIME 2236488.91 ®" 2236729.30 60 °06'45.548 "N INSM=IMEICEM 0.00 MEM 0.00 1100.00 36.00 ®B I G 885. mEizmnamm '®' 213053.99 MEIEMEEM 60 °0645.387 "N 151°34'30.668v =UM 0.00 MEM 0.00 1200.00 40.00 ®' ®' mplimmom®' 1353013.86 WEEMZEGME=M 2236697.67 60 °0545.210 "N ®' r r 0.00 MEM 0.00 EMEMIIIIIIIIII 1300.00 MEMMEREEMMIEMEM 1 039. 02 E=EM®� 2236679.66 60 °0645.017"N ESEIRESIMCIEMI 0.00 in= 0.00 r 1400.00 MEEMIIMMIIIMIMME 1108.48 MEDIMMEMEM 1352880.18 2236419.88 60 °06'44.810 "N 151 °34'34.469"W 4.00 0.00 MEM 0.00 1500.00 macmgmanEcgmgazign - 160.88 MOEN 1352806.42 2236399.24 MEGMEEM=M 60 °0644.590 "N 151°34'35.914'W 4.00 0.00 • t t 0.00 1600.00 56.00 ®' ®IIIMEMEMMEMEIEMEEMMW=M 60 °06'44.357 "N 151 °34'37.441"W 4.00 0.00 4.00 0.00 1700.00 60. mgEmicrumEngEN - 209. - 684.93 EE=MIELIMEM®' ' 60 °06'44.113 "N 151 °34'39.041 "W 4.00 0. MEE= 0.00®' 1800.00 64.00 ®' MEMEM®'' - 769.36 11E=M 2236330.84 ®" 60 °06'43.859 "N 151°34'40.706'W 4.00 0.00 MEM 0.00 c r®' 1900.00 68.00 Elmo 1528.09 ®'' wmaimmizm®'' 2236306.24 2236546.69 60 °06'43.596 "N 151 °34'42.430 "W 4.00 0.00 • O 0.00 895.81 1920.23 68.81 ®' mionumErammamm EromammEmniunmmwsumcm 60 °06'43.542 "N 151 °34'42.785"W 4.00 0.00 MEM 0.00 2000.00 ®' "®'•mmuggs 212365.00 MEEMOME 60 °0643.328 "N 151 °34'44.188 "W 0.00 0.00 0.00 0.00 989.00 IIIIII 2100.00 1600.52 MEIZEMMISEEM - 1034.99 EMMEN 2236256.02 ® 2236496.48 60 °06'43.059 "N = 0.00 0.00 0.00 0.00 MEINIIIIII 2200.00 68.81 ®' 1636.67 1480.67 nammanamgmaKE 2236230.90 IEMEEMMEEIMEEMI 60 °06'42.791 "N = 0.00 0.00 0.00 0.00 2300.00 ®Egagnm 2236205.79 212095.63 MBECEME 60 ° 06'42.522 "N 151 °34'49.466"W 0.00 0.00 0.00 0.00 EISIE 2400.00 ®' 1708.96 MIME - 398.00 Maall. 1352025.00 2236180.67 MEEMEMEMEMEM 60 °06'42.254 "N I 0.00 0.00 0.00 0.00 MiEZEIEEN 2500. 68.81 ®' IGUMMEEZEIMMOMEMIM®' IEEMEM®• ' 2236396.05 60 °06'41. "N = 0.00 0.00 0.00 0.00 MIEME 2600.00 68.81 ®' Miii3EMEMIECIIIMEEEME®t "®' " 60 °06'41.717 "N MEE= 0.00 0.00 0.00 0.00 MEEEEMINIMIIM 2700.00 68.81 MBEEMMUMMEMMEM - 1570.00 MEEMEMOMEM:=M 60 °06'41.449 "N Il= 0.00 0.00 0.00 0.00 1641.66 IMIMINIlar 2800.00 68.81 ®' IIENIMMIEME - 506.99 METIMMEE=EN 2236080.21 211646.66 MIEDMEll 60 °06'41.180 "N = 0.00 0.00 0.00 0.00 ®"' 2900.00 $L8 0 ®' •' 2236055.09 MIEUMUEIIMIM 60 °06'40.912 "N 151 °35'00.022"W 0.00 0.00 0.00 0.00 3000.00 68 ®' 1769.85 MMECEMEMEMMEEMMEM 2236029.98®• ''• 60 °06'40.643 "N . '®• 0.00 0.00 0.00 0.00 MEEIMMIIMMII 3100.00 68.81 ®' 1962.00 1806.00 MEM. - 1926.67 1351396.46 2236004.86 MEIIEBKIMMMECEEM 60 °06'40.375 "N . '®' 0.00 0.00 0.00 0.00 MEMIEME 3200.00 68.81 ®' 1998.14 Mos= - 615.98 Warn. 1351306.67 EEEEMMEEI=M 2236220.29 60 °06'40.106 "N 151°35'05.300"W 0.00 0.00 0.00 0.00 Eirallilli ■ 3300.00 68.81 ®"®" • • 1351216.88 EEEMME®' ' 60 °06'39.838 "N 151 °3607.059'W 0.00 0.00 0.00 0.00 2201.09 3400.00 68.81 ®' • • ®'' ESEMEM®' ®" 60 °06'39.569 "N 151 °35'08.818"W 0.00 0.00 0.00 0.00 MEMEE 3500.00 68.81 weEim 2106.59 1950.59 IMEMEMMEMENEEMBEC. 2235904.40 'EI 60 °06'39.301 "N E 0.00 0.00 0.00 0.00 EIMEMI 3600.00 68. 81 EmEnEgam 1 986. 73 MEEME® 1350947. 2235879.28 60 °06'39.032 "N EIEMIES3 0.00 0.00 0.00 0.00 2480. 3700.00 68.81 MESICIMMIKEE 2022. ® EMZEME •'®'' 60 °06'38.764"N 151 °35'14.096"W 0.00 0.00 0.00 0.00 ®' •' 3800.00 68.81 WEIMMEIME 2059.03 illagiMMEEME 1350767.92 2235829.05 EMMEN 2236069.64 60 °06'38.495 "N 151 °35'15.855'W 0.00 0.00 0.00 0.00 2667. 3802.69 68.81 MEM 2216.00 2060.00 - 780.19 ®MEM.1 N 2235828.38 MEI=EM 2236068.97 60 °06'38.488 "N 151 °35'15.903'1 0.00 0.00 0.00 0.00 2669.79 Beluga B2 3859.84 68.81 WM= 2236.66 2080.66 mogamismEmimmammEgancil 210695.00 2236054.61 60 °06'38.334 "N 151 °35'16.900 W 0.00 180.00 0.00 0.00 ®' 3900.00 tMEMEM®' 2095.70 - 806.65 - 2639.82 1350678.33 2235803.99 MIMEM 2236044.59 60 ° 0618.227"N 151 °3517.611'W 4.00 180.00 -4.00 0.00 4000.00 WEEIM®' MEEMINEERMWEEHUMMI 1350590.93 '® 2236020.14 60 ° 06'37.966"N = 4.00 1 80.00 MEIEM 0.00 4100.00 weico®' maguicam 1350506.55 EISMEMMIE=M 2235996.55 60 ° 06'37.713"N 151°35'20.976'W Ma= 180.00 =CM 0.00 2938.69 4200.00 ®' ®' EEIZEMEELEM "®' ® 210406.42 MEMEMM 60°06 IMIEMEEMINCEM 180.00 MUM 0.00 '® 4300.00 ®' ®' 2299.84 - 906.73 NEEMENEEZEDEEMIZIEEMM 60 EINEMZEIMEM 180.00 11110CM 0 '®' 4400.00 ®' ®' MMEI '®' '®' '®• 60°06'37.0231N • • r • 180.00 -4 . 0.00 3178. 4500.00 5t ®' EEMEMEMEM - 949.58 MIME 1350207.30 EglaMINEEEKEEmommem 60 °06'36.818 "N 151 °35'26.839"W =CM 180.00 =KIM 0.00 4600.00 ®' 2666.83 MM. - 968.82 IISEM ®" 210124.69 60 °06'36.629 "N 151 °35'28.082'W =CM 180.00 -4 .00 0.00 4700.00 ®' MZ 2590.46 - 986.49 SEMEN 1350085.66 EMEDEEM 210066.46 MEMMEM 60 °06'36.455 "N =MEM 180.00 MT= 0.00 IIMEDI 4800.00 ®' ®' EEEIEUZIEM - 1002.49 MIME 1350032.94 4 l i 60 °06'36.297 "N EMEEMEIMMEM 80.00 MUM 0.00 ®' ' • 4830.07 30.00 illEglaM 2856.00 2700.00 - 1006.96 MEM. 1350018.20 MEEEEME 209999.00 2235860.00 60 °0616.253 "N ®' r • 0.00 =CM 0.00 EMEIEMIIIIIM 4900.00 30.00 WM= 2916.56 2760.56 BEEEENNEEmima=m 2235609.93 209965.32 WEE=EM 60 °06'36.152 "N ®'' 0.00 0.00. 0.00 0.00 ' 9 Page 1 of 2 Planned Wellpath Geographic Report Report Generated >" -- ' 111111- ' 11- ° "" ' 1 , . 01- Oct -08 at 10:35:20 Projection System NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Operator. MARATHON Oil Company North Reference True Area , - T 1,, Cook Inlet, Alaska (Kenai Penninsula) Scale 0.999994 Field -; � Ninilchik Field (NAD83) Horizontal Reference Point Slot acility Susan Dionne Vertical Reference Point Glacier #1 (RKB) -lot SD #6 _ MD Reference Point Glacier #1 (RKB) ell J SD #6 Field Vertical Reference Mean Sea Level ellbore SD #6 Glacier #1 (RKB) to Facility Vertical Datum - -_ -- 156.00 ft ellpath SD #6 Version #4 Glacier #1 (RKB) to Mean gea Level 156.00 ft ellbore Last Revised " 08/07/2008 Facility Vertical Datum to Mud Line (Facility 0.00 ft idetrack from (none) Section Origin X E 0.00 ft User Section Origin Y N 0.00 ft Calculation method ,. >w 11 ' Section Azimuth 253.01° IIIMI Local North Local East Grid East Grid North Latitude Longitude [t) [ft] [11Sft) [USft] Slot Location IIMOIMMIr 316.06 - 1132.74 1353336.59 2236547.54 60 °06'46.174 "N 151°34'25.526'W Facility Reference Pt s 60 °06'43.062 "N 151 °34'03.175"W Fi I. • • f r n - 1371967.44 2251649.81 60 °09'19.105 "N 151 °2824.639'W *NAD 83 coordinates are converted to NAD 27 using Corpscon 6.0.1 (US Army Corps of Engineers TVO from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [ °] ( °] [ft] [ft] [ft] [ft] [sry ft] [sry ft] [ft] [ft] [° /100ft] [°] [` 1100ft] [ ° /100ft] [ft] 5000.00 30.00 253.01 3003.17 2847.17 - 1031.79 - 3376.63 1349936.37 2235596.46 209917.17 2235837.12 60 °06'36.008"N 151 ° 35'32.147"W 0.00 0.00 0.00 0.00 3530.76 5100.00 30.00 253.01 3089.77 2933.77 - 1046.40 - 3424.45 1349888.22 2235582.99 209869.02 2235823.65 60 ° 06'35.864"N 151 °35'33.090"W 0.00 0.00 0.00 0.00 3580.76 5200.00 30.00 253.01 3176.37 3020.37 - 1061.01 - 3472.27 1349840.07 2235569.52 209820.87 2235810.19 60 °06'35.720"N 151 °3514.034"W 0.00 0.00 0.00 0.00 3630.76 5300.00 30.00 253.01 3262.97 3106.97 - 1075.62 - 3520.09 1349791.92 2235556.06 209772.72 2235796.73 60 °06'35.576"N 151°3634.977W 0.00 0. 0.00 0.00 3680.76 5400.00 30.00 253.01 3349.58 3193.58 - 1090.23 - 3567.90 1349743.77 2235542.59 209724.57 2235783.26 60 °06'35.432"N 151 °35'35.920"W 0.00 0.00 0.00 0.00 3730.76 5500.00 30.00 253.01 3436.18 3280.18 - 1104.84 - 3615.72 1349695.61 2235529. 209676.41 2235769.80 60 °06'35.288"N 151 °3636.864'W 0.00 0.00 0.00 0.00 3780.76 5600.00 30.00 253.01 3522.78 3366.78 - 1119.46 - 3663.54 1349647.46 2235515. 209628.26 2235756.33 60 °06'35.144 "N 151 °35'37.807'W 0.00 0.00 0.00 0.00 3830.76 5700.00 30.00 253.01 3609.38 3453.38 - 1134.07 - 3711.36 1349599.31 2235502.18 209580.11 2235742.87 60 °06'35.000 "N 151 °35'36.750"W 0.00 0.00 0.00 0.00 3880.76 5704.17 30.00 253.01 3613.00 3457.00 - 1134.68 - 3713.35 1349597.30 2235501.62 209578.10 2235742.31 60 °06'34.994 "N 151°35'38.790'W 0.00 0.00 0.00 0.00 3882.84 Tyonek T1 Coal A 5800.00 30.00 253.01 3695.99 3539.99 - 1148.68 - 3759.17 1349551.16 2235488.72 209531.96 2235729.41 60 °06'34.856 "N 151°3539.694W 0.00 0.00 0.00 0.00 3930.76 • 5900.00 30.00 253.01 3782.59 3626.59 - 1163.29 - 3806.99 1349503.01 2235475.25 209483.81 2235715.94 60 ° 06'34.712 "N 151 °35'40.637'W 0.00 0.00 0.00 0.00 3980.76 6000.00 30.00 253.01 3869.19 3713.19 - 1177.90 - 3854.81 1349454.86 2235461.78 209435.66 2235702.48 60 ° 06'34.568 "N 151 °35'41.580'W 0.00 0.00 0.00 0.00 4030.76 6100.00 30.00 253.01 3955.79 3799.79 - 1192.51 - 3902.63 1349406.71 2235448.31 209387.50 2235689.01 60 °06'34.424 "N 151 °35'42.524"W 0.00 0.00 0.00 0.00 4080.76 6200.00 30.00 253.01 4042.40 3886.40 - 1207.12 - 3950.44 1349358.55 2235434.84 209339.34 2235675.55 60 °06'34.279"N 151 °35'43.467"W 0.00 0.00 0.00 0.00 4130.76 6300.00 30.00 253.01 4129.00 3973.00 - 1221.73 - 3998.26 1349310.40 2235421.38 209291.19 2235662.09 60 °06'34.135 "N 151 °35'44.410"W 0.00 0.00 0.00 0.00 4180.76 6400.00 30.00 253.01 4215.60 4059.60 - 1236.34 -4046.08 1349262.25 2235407.91 209243.04 2235648.62 60 °06'33.991'N 151 °35'45.354"W 0.00 0.00 0.00 0.00 4230.76 6500.00 30.00 253.01 4302.20 4146.20 - 1250.96 - 4093.90 1349214.10 2235394.44 209194.89 2235635.16 60 °06'33.847"N 151°35'46.297W 0.00 0.00 0.00 0.00 4280.76 __ 6600.00 30.00 253.01 4388.81 4232.81 - 1265.57 -4141.71 1349165.95 2235380.97 209146.74 2235621.69 60 °06'33.703"N 151 °3547.240"W 0.00 0.00 0.00 0.00 4330.76 6654.49 30.00 253.01 4436.00 4280.00 - 1273.53 -4167.77 1349139.71 2235373.63 209120.50 2235614.35 60 °06'33.625"N 151 °35'47.754"W 0.00 0.00 0.00 0.00 4358.00 • Page 2 of 2 Planned Well path Report BAKER SD #6 Version #4 HUGHES MARATHON Page 1 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 Field Ninilchik Field (NADS3) Welibore SD #6 Facility Susan Dionne REPORT SETUP INFORMATION Projection System NADS3 / TM Alaska State Plane, Zone 4 (5004) US feet Software System WellArchitect® 2.0 ;North Reference 1True User Jonethoh Seale 0999994 Report Generated 01- Oct -08 at 10:32:37 Convergence at sl of 1.36° West Database /Source file WA_Anchorage /SD #6_.xml WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North East[ft] Easting[USft] Northing[USft] Latitude Longitude Slot Location 316.06 - 1132.74 1353336.59 2236547.54 60 °06'46.174 "N 151°34'25.526"W Facility Reference Pt 1354461.50 2236204.70 60 °06'43.062 "N J 151 °34'03.175 "W . ■ Field Reference Pt 1371967.44 2251649.81 60 °09'19.105 "N 151 °28'24.639 "W WELLPATH DATUM Calculation method Minimum curvature Glacier #1 (RKB) to Facility Vertical Datum 156.00ft ill =Horizontal Reference Pt Slot Glacier #1 (RKB) to Mean Sea Level 156.00ft Vertical Reference Pt Glacier #1 (RKB) Facility Vertical Datum to Mud Line (Facility) 0.00ft - MD Reference Pt Glacier #1 (RKB) Section Origin N 0.00, E 0.00 ft -Field Vertical Reference Mean Sea Level Section Azimuth 253.01° Planned Well path Report MRS p p SD #6 Version #4 BAKER MARATHON Page 2 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) 'Well SD #6 Field Ninilchik Field (NAD83) Wellbore SD #6 Facility Susan Dionne ELLPATH DATA (73 stations = inter 1 olated /extrapolated station ill MD Inclination Azimuth TVD Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate Comments eft ] ° ft ft ft ft sry ft sry ft ° /100ft] ° /100ft [ ° /100ft] 0.00 0.00 0.00 0.00 1353336.59 2236547.54 0.00 0.00 0.00" : Elevation 156' 0.00 I 0.000 253.009 100.00? 0.000 253.009 100.00 0.00 0.00 0.00 1353336.59 2236547.54 0.00 0.00 0.00 200.00 1 0.000 253.009 200.00 0.00 0.00 0.00 1353336.59 2236547.54 0.00 0.00 0.001 OP 300.00 8 4.000 T ( 253.009 299.92 3.49 1.02 3.34 1353333.23 2236546.60 4.00 4.00 0.00- ®` 1 I iY{l��l _,11J1111 .. a a '� U I� iIV �' �� ,4 . ; ._, ; .._. _..w..� ...a..,.:.a,.., - .,., t, 500.00 12.000 253.009 497.81 3 1.30 9.15 29.93 1353306.45 2236539.11 4.00 4:001 0.00 600.00 16.000r 253.009 594.82 55.49 -16.22 -53.07 1353283.15 2236532.59 4.00 4.00 0.00 700.00 20.000 253.009 689.91 86.38 -25.24 -82.61 1353253.40 2236524.27 4.00 4.00 0.00 800.00 24.000 253.009 782.61 123.84 -36.19 - 118.43 1353217.33 2236514.18 4.00 4.00 0.00 01 " 900.00t1 .. 28.0001 :1253.009 - _. 1 w ' 1 11 ' , 1000.00 - 3276 - 01:1F - 2 - 53.009 959.05 217.66 63.61 208.15 1353126.98 2236488.91 4.00 4.00 0.00 a 1100.00 t 36.000 253.009 1041.94 273.56 -79.94 - 261.62 1353073.14 2236473.85 4.00 4.00! 0.00 1 0 200.00? 40.000 253.009 1120.73 335.12 -97.93 - 320.49 1353013.86 2236457.27 4.00 4.00 0.00 1300.00 44.000 253.009 1195.02 402.2 117.48 384.47 1352949.44 2236439.25 4.00 4.00 0.00 �� ..t '., �d1 {ul Il� -. _ i " 1 19'II�IT�Gf, r .. j I IIr . gal lht 1500.00 52.000 253.009 1328.74 550.52 - 160.88 -526.49 1352806.42 2236399.24 4.00 4.00 0.00 1600.00 56.000 253.009 1387.51 631.41 -1 603.85 1352728.52 2236377.46 4.00 4.00 0.00 1700.00? 60.000 253.009 1440.49 716.20 209.29 684.93 1352646.87 2236354.62 4.00 4.00 0.00 1800.00f _ 64.000 253.009 1487.43 804.47 - 235.09 - 769.36 1352561.86 2236330.84 4.00 4.00 0.00 "' . d'. 11 - ; 1 .._, 01 ;.:w 1 1 1 ,0 6&00011, 11 1 1 �..:253. uuu 1tlIV 111 ^ 1 r 1.0 i , 1111 1 I , .. u`i 00 1920.23 ' 68.809 253.009 1535.54 914.62 - 267.28 - 874.69 1352455.79 2236301.17 4.00 4.00 0.00 EOB 2000.00 68.809 253.009' 1564.37 989.00 -289.01 945.82 1352384.16 2236281.13 0.00 0.00; 0.00 2100.00 fi 68.809. 253.009 1600.52 1082.23 -316.26 1034.99 1352294.37 2236256.02 0.00 0.00 0.00 2200.00 68.809 253.009 1636.67 1175.47 - 343.51 - 1124.16 ` 1352204.58 ! 2236230.90 0.00 0,00 0.00 .1r r , < N ._ _._. _ i.- , ! 1268.7 - 370.75. 111111j'1 2400.00? 68.809 253.009 1708.96 1361.95 - 398.00 - 1302.50 1352025.00 2236180.67 0.00 0.00 0.00 2500.00? 68.809 253.009 1745.11 1455.19 - 425.25 - 1391.67 ] 1351935.20 2236155.56 0.00 0.00 0.00 2600.00 68.809 253.009 1781.26 1548.42 - 452.50 - 1480.83 1351845.41 2236130.44 0.00 0 0.00 2700.00? 68.809 253.009 1817.41 1641.66 - 479.74 - 1570.00 1351755.62 2236105.32 0.00 0.00 0.00' 2800001 *J11 1TMa 1 IIIh Planned Well path Report p p BAKER SD #6 Version #4 HUGHES MARATHOM Page 3 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 Field Ninilchik Field (NAD83) Wellbore SD #6 Susan Dionne ELLPATH DATA (73 stations) t = interpolated /extra • olated station MD Inclination Azimuth TVD Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate Comments ft] [ ° [ft] [ft] ft [ft] Isry ft sry ft ° /100ft [ °/100ft 1 ° /100ft] 2900.001-' 68.809 253.009 1889.70 1828.14 - 534.24 - 1748.34 1351576.04 2236055.09 0.00 0.00 0.00 3000.00t 68.809 253.009 1925.85 1921.38 - 561.48 - 1837.51 1351486.25 2236029.98 0.00 0.00 0.00 3100.001- 68.809 253.009 1962.00 2014.62 - 588.73 - 1926.67 1351396.46 2236004.86 0.00 0.00 0.00 3200.001- 68.8091 253.009 1998.14 2107.85 - 615.98 - 2015.84 1351306.67 2235979.75 1 0.00 0.00 0.001 i 1Ihh V ly ° 6 is ll h� is -', _. ro , m •i :.nml .:. u II ,+ „h �. ,:. I,hl,. 01 ql a V '"'" f .. §, IV 1 :, i = +_ .1. 1. , l �u ,u la ��hl '�rr 1 . 1 4 ? W,� 1 _ nl9 , �, � I ka " n �ae� q, � 411 1111111111 1 I 1 e � d ;�� vl I lu � 1 N 1 kni ll Id1111IV� 3400.00 68.809 253.009 2070.44 2294.33 - 670.47 - 2194.18 1351127.09 2235929.51 1 0.00 0.00', 0.00 3500.001- 68.809 253.009 2106.59 2387.57 r - 697.72 - 2283.35 1351037.29 2235904.40 0.00 0.00 0.00 3600.00f 68.809 253.0091 2142.73 1 2480.81 _ - 724.97 - 2372.51 1350947.50 2235879.28 0.00 0.00 0.00 3700.001 68.809 253.0091 2178.88 2574.04 r -752.21 - 2461.68 1350857.71 2235854.17 0.00 0.00 0.00 1 . 9 M ». 6 ® 1 253.009 II III 1 1111111111 1 1 1 "1 j - 779.46 - ;: 5829.05:: 0.00 : 1'x: - w I IIj1I111IVIIIIVII'tia 3802.69 68.809 253.009 2216.00 2669.79 - 780.19 - 2553.25 1350765.51 2235828.38 0.00 0.00 0.006 eluga B2 3859.84 68.809 253.009 2236.66 2723.07 -795.76 -2604.21 1350714.19 2235814.02 0.00 0.00 0.00!i:egin Angle Drop 3900.00 67.203 253.009 2251.70 2760.31 - 806.65 - 2639.82 1350678.33 2235803.99 4.00 -4.00 0.00 400 63.203 253.009 2293.63 2851.07 - 833.17 - 2726.62 1350590.93 2235779.54 4.00 -4.00 0.00! 6 .. 1 -° I ,�I IIII iIU i ol Ii °u111,i" D1111 r 11 p U' �TM IVr4fulrlll l ` �'� 1 1 j 11 4200.00 55.203 253.009 2395.95 3022.73 -4.00 883.33 lll I 6 1 I 1 �1 I 1 - 1350425.611. 4.00 0.00 4300.00 51.203 253.009 2455.84 3102.79 - 906.73 - 2967.35 1350348.52 ! 2235711.74 ` 4.00 -4.00 0.00 4400.001- 47.203 253.009 2521.16 3178.48 - 928.85 - 3039.73 1350275.63 2235691.35 4.00 -4.00 0.00 4500.00t 43.203 253.009 2591.61 3249.42 - 949.58 - 3107.58 1350207.30 2235672.24 4.00 -4.00 0.00 11 11 111 11111 1 ,1-_l _ 235654.50 a: 4700.00 35.203r 253.009 2746.46 3375.73 - 986.49 - 3228.38 1350085.66 2235638.22 4.00 -4.00 0.00 4800.00 31.203 253.0091 2830.12 3430.48 - 1002.49 - 3280.74 1350032.94 2235623.47 4.00 -4.00 0.00 4830.07 30.0001 253.0091 2856.00 3445.79 - 1006.96 -3295.37 1350018.20 2235619.351 4.00 -4.00 0.00 OD (Beluga B3) 4900.00 30.000 253.009 2916.56 3480.76 r - 1017.18 - 3328.81 1349984.52 2235609.93 0 0.00 1 11 11 30.000 253.009 __ � 3089.77 3580.76 � � ' 11;1 0.0 _ 1 1 - - - - - � -- -- - , . 1 10.00 ;1 I � n11iU��I11111n11II1191,# _�!h'�''�"u 11131 79 3 . 1 ,,4 a (1 1 � 1 046.40 - 3424.45 1349888.22 2235582.99 0.00 0.00 0.00 5200.00 30.000 253.009 3176.37 3630.76 - 1061.01 - 3472.27 ! 1349840.07 2235569.52 0.00 0.00 0.00 5300.00 30.000 253.009 3262.97 3680.76 r - 1075.62 - 3520.09 1349791.92 2235556.06 0.00 1 0.00 0.00 5400.00 30.000, 253.009 3349.58 3730.76 - 1 - 3567.90 1349743.77 2235542.59 0.00 0.00 0.00 5 1 i 1 n 1 1 I ..:1i VIII 111Vh Ills VV '''0"11111111111111'Y, ` 1 1 r ,. I ll l..a IV ��a � 1 ' . 111 III III1Yo Planned Wellpath Report BAKER P SD #6 Version #4 HUGHES MARATHON Page 4 of 5 I , , 'REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 =IN Ninilchik Field (NAD83) Wellbore SD #6 Facility Susan Dionne WELLPATH DATA (73 stations) t = interpolated /extrapolated station Ilk MD Inclination Azimuth TVD Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate Comments [ft] 11 [°] [ft] [ft] [ft] [ft] [sry ft] [sry ft] [ ° /100ft] [ ° /100ft] [ ° /100ft] 5600.00j 30.000 253.009 3522.78 3830.76 - 1119.46 - 3663.54 1349647.46 _ 2235515.65 0.00 0.00 0.00 f 5700.00f 30.000 253.009 3609.38 3880.76 - 1134.07 - 3711.36 1349599.31 2235502.18 0.00 0.00 0.00 F 5704.17] 30.000 253.009 3613.00 3882.84 - 1134.68 - 3713.35 1349597.30 2235501.621 0.00 0.00 0.00I TI Coal A 1 5800.00f 30.000' 253.009 3695.99 3930.76 - 1148.68 - 3759.17 1349551.16 2235488.721 0.00 0.00 0.00 _ -'16:0011 ilmi #.00 0.0'1� If�B S � i i l t� '.,a.� il' ifli F k. . , , .; �° fir" 6000.00 f f 30.000 253.009 3869.19 4030.76 - 1177.90 - 3854.81 1349454.86 2235461.78 0.00 �_ i, 0.00 0.00 I 6100.00j 30.000 253.009 3955.79 4080.76 - 1192.51 - 3902.63 1349406.71 2235448.31 0.00 0.00 0.00 r 6200.00H 30.000 253.009 4042.40 4130.76 - 1207.12 - 3950.44 1349358.55 2235434.84 0.00 0.00 0.00 4 630 0O 30.000 253.009 4129.00 4180.76 - 1221.73 -3998.26 1349310.40 2235421.38 0.00 0.00 0.00 rill 6400 00 f 30 =,8 13492 0_.00 ti.00 DV 6500.00 30 f 30.000 253.009 4302.20 4280.76 - 1250.96 - 4093.90 1349214.10'.. 2235394.44. 0.00. 0.00 0.00 6600.00 ; 30.000, 253.009 4388.81 4330.76 - 1265.57 - 4141.71 1349165.95 2235380.97 0.00 0.00 0.00 6654.49 30.000' 253.009 4436.00 4358.00 - 1273.53 - 4167.77 1349139.71 2235373.63 0.00 0.00 0.00 TD HOLE & CASING SECTIONS Ref Wellbore: SD #6 4ef Well •ath: SD #6 Version #4 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] 12.25in Open Hole 0.00 2000.00 2000.00 0.00 1564.37 0.00 0.00 - 289.01 -945.82 9.625in Casing Surface 0.00 2000.00 2000.00 0.00 1564.37 0.00 0.00 -289.01 -945.82 8.5in Open Hole 2000.00 6654.49 4654.49 1564.37 4436.00 - 289.01 -945.82 - 1273.53 -4167.77 4.5in Casing Production 0.00 6654.49 6654.49 0.00 4436.001 0.00 0.00 - 1273.53 - 4167.77 Planned Wellpath Report BAKER SD #6 Version #4 HUGHES MARATHON Page 5 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION • • Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 Field Wellbore SD #6 Facility Susan Dionne TARGETS Name MD TVD North East Grid East Grid North Latitude Longitude Shape [ft] [ft] [ft] [ft] [sry ft] [sry ft] 2216.00 - 779.21 - 2555.59 1350763.19 2235829.41 60 °06'38.497 "N 151 °35'15.949 "W circle SD #6 Beluga B2 (NAD83) 1- Oct -08 2856.00 - 1006.96' - 3295.38 1350018.20] 2235619.351 60 151 °35'30.544 "WI circle 1) SD #6 Beluga B3 (NAD83) 1- Oct -08 3613.00 - 1135.99 - 3713.421 1349597.201 2235500.31 60 0 06'34.981 "N 151 °35'38.791 "W circle SD #6 T1 Coal A (NAD83) 1- Oct -08 SD #6 TD (NAD83) 1- Oct -08 I 4436.001 - 1275.87' -4167.21 1349140.211 2235371.281 60 °06'33.602 "N= 151 °35'47.743 "W1 circle SURVEY PROGRAM Ref Wellbore: SD #6 Ref Wellpath: SD #6 Version #4 Start MD End MD Positional Uncertainty Model Log Name /Comment Wellbore [ft] [ft] 0.00 2000.00 NaviTrak (Standard) SD #6 I 2000.00 6654.49 NaviTrak Standard) SD #6 I 1 Ali MARATHON Oil Company BAKER L ocation: Cook Inlet, Alaska (Kenai Penninsula) Slot: SD #6 N�� Field: Ninilchik Field (NAD83) Well: SD #6 MARATHON Facility: Susan Dionne Wellbore: SD #6 I NTEQ Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 Scale 1 inch = 10011 Easting (ft) -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 - 50 0 1 1 1 1 1. S0 3 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 50 — O — 50 a 800 2O0 SD #6 0 — 1100 64, — 0 III o00 -50 — ■ - 50 800 500 7 00 200 - 100 so SD #2 -100 • S S ° 500 W ° o ° 200 '- °o SD #3 -150 - vsr� SD #5 --150 os o °20 ?g00 2sO SD #1 200 0 O v7 0 S -200 — 74 ° 0 B O O 0 — - 200 Z 0 at B �& 500 1E 7 7 ° o ° SD#4 9' -C co o Z -250 — - — - 250 #4 79. Q o 0 90 -. • - 300 — 9 5/8" Casing Surface -300 800 -350 — — - 350 -400 — — - 400 -450 — — - 450 -500 ■ 1 1 1 1 1 1 1 1 1 1 1 5 , 1 1 1 1 1 1 1 1 1 —'500 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 - 450 -400 -350 -300 -250 -200 -150 -100 -50 0 Scale 1 inch =10011 Easting (ft) MARATHON Oil Company BAKE EU Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: #6 HUGHE Field: Ninilchik Field (NAD83) Well: SD #6 INTEQ MARATHON Facility: Susan Dionne Wellbore: SD #6 Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 Easting ft Scale ranch = 100 0 ( ) -1600 -1550 -1500 -1450 -1400 -1350 -1300 -1250 -1200 -1150 -1100 -1050 -1000 -950 -900 -850 -800 -750 -700 -650 1 1 1 i 1 1 1 1 1 'w A i 1 1 1 1 1 100 - °° co°° y ° o° y �o° 0 0 0 - -100 e 6 6a° 00 6° 00 6ti ^00 0 5 60 00 -150 — - p N`60 7 -150 a6 600 a 1400 -200 — — -200 7, 0 0 -250 — 1600 7000 -250 /6 42 u � 7 0 9 5/8" Casing Surface o oa -300 — o — -300 SD # Z 60 0 -350 — — -350 -400 — % — -400 -450 — — -450 T 0 gD #6. -500 - — -500 —L 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -1600 -1550 -1500 -1450 -1400 -1350 -1300 -1250 -1200 -1150 -1100 -1050 -1000 -950 -900 -850 -800 -750 -700 -650 Scale 1 inch = 100 0 Easting (ft) . • M 6_. la g MARATHON OiI Company BAKER L ocation: Cook Inlet, Alaska (Kenai Penninsula) Slot: SD #6 HUGHES MARATHON Field: Ninilchik Field (NAD83) Well: SD #6 Facility: Susan Dionne Wellbore: SD #6 INTEQ Plot reference wellpath is SD #6 Version #4 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to Mean Sea Level: 156 feet Scale: True distance Mean Sea Level to Mud line (Facility: Susan Dionne): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 01- Oct -08 Traveling Cylinder: Map North All depths are Measured Depths on Reference Wellpath p . h 33■ . , ..,., »_., 30' ..•3 60/1 -,... r 300' 1 , \ \ t t, 1, ; \ \„ 'I 270 „r / all, , : : : „010. \ , 2WI . ” / 10 j* , 7-- . 1 t 210' -- ., e, '..,, ..1" 150' 180' Scale 1 inch = 30 ft M Clearance Report Fizm SD #6 Version #4 BAKER Closest Approach MARATHON Page 1 of 21 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet Alaska (Kenai Penninsula) Well SD #6 Field Ninilchik Field (NAD83) Wellbore SD #6 Facility Susan Dionne RE•ORT SETUP INFORMATION Projection System NAD83 / TM Alaska State Plane, Zone 4 (5004), US feet Software System WellArchitect® 2.0 North Reference True User Jonethoh Scale 0.999994 Report Generated 01- Oct -08 at 09:47:17 :Convergence at slot 1.36° West Database /Source file WA_Anchorage/SD_#6_.xml WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[USft] Northing[USft] Latitude Longitude Slot Location 316.06 - 1132.74 1353336.59 2236547.54 60 °06'46.174 "N 151 °34'25.526 "W Facility Reference Pt IIIIIIIIIIIIIIIII 1354461.50 2236204.70 60 0 06'43.062 "N 1 151 °34'03.175 "W Field Reference Pt 1371967.44 2251649.81 60 °09'19.105 "N i 151 °28'24.639 "W WELLPATH DATUM Calculation method Minimum Curvature Glacier #1 (RKB) to Facility Vertical Datum 156.00ft 40 Horizontal Reference Pt Slot Glacier #1 (RKB) to Mean Sea Level 156.00ft :Vertical Reference Pt Glacier #1 (RKB) Facility Vertical Datum to Mud Line (Facility) 0.00ft 'MD Reference Pt Glacier #1 (RKB) Field Vertical Reference Mean Sea Level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start Depth , 0.00ft Surface Position Uncertainty included Declination 18.51° East of TN Dip Angle - 73.06° Magnetic Field Strength 155266 nT M Clearance Report imam SD #6 Version #4 BAKER Closest Approach NE+S MARATHON Page 2 of 21 INTEQ REFERENCE WELLPATII IDENTIFICATION MARATHON Oil Company Slot Operator MARA O SD #6 .. (Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 Field Ninilchik Field (NAD83) W ellbore SD #6 Facility Susan Dionne ANTI- COLLISION RULE • Rule Name ° E -type Closest Approach w/Hole &Csg Limit:0 StdDev:3.00 w /Surface Uncert Rule Based On Ellipsoid Separatio Plane of Rule Closest Approach Threshold Value 0.00ft Subtract Casing & Hole Size _ yes Apply Cone of Safety no HOLE & CASING SECTIONS Ref Wellbore: SD #6 Ref Wellpath: SD #6 Version #4 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] 12.25in Open Hole 0.00 2000.00 2000.00 0.00 1564.37 0.001 0.00 - 289.01 -945.82 9.625in Casing Surface 0.00 2000.00 2000.00 0.00 1564.37 0.00 0.00 -289.01 -945.82 8.5in Open Hole 2000.00 6654.49 4654.49 1564.37 4436.00 -289.01 -945.82 -1273.53 - 4167.77 4.5in Casing Production 0.00 6654.49 6654.49 0.00 4436.00 0.00, 0.00 -1273.53 -4167.77 SURVEY PRO GRAM Ref Wellbore: SD #6 Ref Wellpath SD #6 Version #4 Start MD End MD Positional Uncertainty Model Log Name /Comment Wellbore Iftl [ft)_. - 0.00 2000.00 aviTrak (Standard) SD #6 2000.00 6654.49 aviTrak (Standard) SD #6 M Clearance Report SD #6 Version #4 MARATHON Closest Approach HUGHES Page 3 of 21 INT 1 , Q - REFERENCE WELLPATH IDENTIFICATION Operator MARATHON Oil Company Slot SD #6 Area Cook Inlet, Alaska (Kenai Penninsula) Well SD #6 , =Field Ninilchik Field (NAD83) Wellbore SD #6 'Facility Susan Dionne IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIII CALCULATION RANGE & CUTOFF From: O.00ft MD To: 6654.49ft MD C -C Cutoff: (none) 1 1, OFFSET WELL CLEARANCE SUMMARY (5 Offset Wellpaths selected) Offset Offset Offset Offset Offset Ref Min C -C Diverging Ref MD of Mm C -C Mrn C -C ACR Facility Slot Well Wellbore Wellpath MD Clear Dist from MD Min C -C Ell Sep Ell Sep Status 1 [ft] [ft] [ft] Ell Sep [ [ft] Dvrg from [ft] [ft] Susan Dionne ISD #4 ISD #4 SD #4 MWD <0- 11953> 2036.48 62.97 2036.48 2172.56 1.21 2172.561PASS 'Susan Dionne 1f SD #1 ISD #1 SD #1 MSS <2498- 14931'> 1283.05 60.78 1283.05 1284.22 30.96 1284.22 PASS Susan Dionne SD #2 SD #2 SD #2 MWD <0- 11094> , 906.57 204.07 906.57 912.60 185.57 912.60 PASS Susan Dionne SD #5 SD #5 SD #5 NaviTrak <110 - 9600> 145.10 210.61 145.10 89.66 197.60 145.10 PASS E — � Iy� — b :, i "��Il l lml �n ',, i I I Ip 1 I VI I il IIII III i 1111I lull l u l 1 l 1 1 p p11 lil'�L'll I I I I II III i lw,�,p ill I 11 1 III � � �' .� IIII ' I I_. _ _�___�._._ I I4 I IIII �llll� I 111 � 1 II 11 41I�1 I I I11 1 I1 Il �1p�111 I I . � `. 1 1 1 11 1 S — � d. 9 . *-` �xnVYN uH 1 • Mt SWACO Section 1 — Objectives / Benchmarks / Goals Goal / Objective Achieve Health, Safety and Environmental Goals Benchmark No Accidents, No harm to people, No damage to environment Performance Days away from work, medical treatments, fluids discharge, spills Measure Goal / Objective No NPT on well Benchmark No NPT due to mud properties out of specification. Performance ' Daily review of mud properties with mud engineer and project Measure engineer Goal / Objective Minimal losses to formation Benchmark Control and /or minimize seepage losses in underpressured sands. Performance Verify losses per hole section on well with OneTrax Measure Goal / Objective No NPT on well Benchmark No hole cleaning issues upon following the program and /or rig site mud ensineers recommendations. Performance Monitor NPT on daily Marathon reports Measure • S CF 4111 WI 3 r 9 1 Mg SWACO i n) 1 Section 2 — Well Design Susan Dionne 6 Casing Hole Casing Depth ND Mud Mud Weight Cost Sum Size Size Program (MD -SS) (ND -SS) System (ppg) Days in in (ft) (ft) Conductor 100' 2000 1564 GEL SPUD 8.8 — 9.2 6 9.625" 12.25" 4.5" 8.5" LIi 6654 4436 FLOPRO 8.9 — 9.2 9 1 KCL Brine 8.6 3 Comp Cost does include engineering charges FORMATION TOPS ESTIMATED PORE PRESSURES Pore Pressure Formation Estimated Tops (TV t 1 g 1 11111 1 1 (PPg) Beluga B2 2216' 7.7 - 8.8 Beluga B3 2856' 7.7 - 8.8 Tyonek T1 Coal A 3613' 7.7 - 8.8 TD 4436' 7.7 - 8.8 F s 1 ° "Irv114 —,..-- - ,-, , _ ...1 • Me SWACO Section 4 -- Lessons Learned & Offset Mud Data Offset well #1: Susan Dionne 5 Depth of Mud Wt. TVD Description of Information concerning the Event or Problem Event/ (ppg) (Feet) Event / Problem Problem « °w�' 120' - 802" 8.7 0 Hole cleaning Boulders, tight connections below conductor 15 fill after wiper trip 1630 9.6 1299 Losses Lost circulation after 75 bbls away on surface cement job 4200' 9.6 2726' Sliding problem Difficulty sliding until 3% Lubetex added Offset well #2: Susan Dionne 4 Depth of Mud Wt. TVD Description of Information concerning t Event/ (ppg) (Feet) Event / Problem Problem 561 8.8 561 MEM. Loose boulder stuck •i•e at 200'. 3117 9.2 2100 Ti • ht hole Ti • ht hole on wiser tri • • 2673' 6116 9.7 3405 Tight Hole Pum • out of hole from 4590 - 4179 Offset well #3: Susan Dionne 3 Depth of Mud Wt. TVD Description of Information concerning the Event orProblem Event/ (ppg) (Feet) Event / Problem Problem 1875 9.1 Trip for motor 3100 9.3 Build new mud 4190 9.55 Clay issues Drilling ahead with lots of clay 4756 9.5 Wiper trip Hit bridge. Dump and dilute mud to reduce solids 5245 9.8 3434' Wiper trip Hit bridges, raised mud wt to 9.8, run 7" casing • • Mt SWACO Section 5 — Surface Interval (0' — 2000') Depth Interval 2000' MD (1564' TVD) (12.25" OH, 9 5/8" Casing) Drilling Fluid System Spud Mud Key Products MI GEL, Gelex, Caustic Solids Control Mongoose shakers, desilter, solids van Potential Problems Hole Cleaning, Hole Stability INTERVAL MUD PROPERTIES VIII 00;)t" " Yie I I tic ld / �!,IPIIIII L tenet III � fu lkl v � 'il Ru i t I i � 9� u p Viscos t Fluid Loss Viscos�I'' li III �l� _ 0Mh�I) G �o ,� : (ppj) l p) (b1100ft m1 /30min secs, t. H "d,i�'111111 �,�;�Il 1 �I �� I I�, li � c 1 ) ( ) ( Vii) p III 2000 8.8 — 9.2 15 -24 >30 <18 60 - 100 8.0 — 9.0 < 6 ➢ Treat drill water with Soda Ash to reduce hardness. ➢ Build spud mud with 20 — 25 PPB M -I Gel to +/- 100 sec.qt funnel viscosity. ➢ Lower funnel viscosity to +/- 60 after gravel zone has been drilled. ➢ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ➢ Increase funnel viscosity if fill on connections begins to occur. ➢ Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. ➢ Add 2 — 5 PPB of MIX II to mud system if seepage losses becomes a problem. ➢ Condition mud prior to cementing casing to reduce yield point and gel strengths. • 1 Mt SWACCl Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 2000' casing shoe and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT w�L � I ®1995.2008 M -ILl. 700 GPM MD:2000 fl Operator:Marathon Mi 1 �gpV 06 W c TVD:758d tt WalNema: Busan Dionnefi VIIIIIIIIIIAL HYDRAULICS* Snapp IUL} 81(8ba:1225 b Locatbn:KenaiPeninsula Date:1022008 Country Atasaa Depth Geometry Angle Density Va Hole Clean Pressure Distrbutbn (ft) MD7rvD CsgODAD ( °) (blg.I) (fthnin) Index (1) 6)) on) 0 45 00 2 28 y_ 100 0 40o w 0 1 0 Bh =18.8 Ann= 2.7 DS =80.6 55 . 1 L 11 2001 9 111 4081 4o 111 Dr / FLM Mud W alar -B assd 621.0 Mud Weight 8.9 bpal 1 1 11 1 1 Flow Rate syslem 70000a 9 Mob Teat eoo : iii Penetration Rate 150 flaw Rotary Speed 100 rpm • • • tooW _1 j Weight on Bit is 1000b 111 Bl N ht onB 1. b 1200 - . - - Pressure Losses � ', Modified Power Law OrMString 866 psi AN - - MWD 450 pal 1 1 1 i 111111 ' Motor 350 pal Bit 350 psi 0 _ ,. • 1111 Bh On1011 100 pal i Annulus 29 pal I I Surface Equip 54 pal ]a U -Tuba Effael 22 pal - 'L TotOBy•tem 2051 pal i ! BM) ECD *Cut 2000 2000 .. 12250 ,,, 111•11111111 CsgShoe 8.98 916 943 1554 - TD 8.99 9.34 9.61 0. _ wnb *8 .n ].1 fam ]] . J — � � FIN.tla.MOa II1 1 G s , .f , i 1 N� i w 4 ,Ift , u la 'VOA' 1 ( �� 1 4.1 illll I� l hh1 N V^ m�r '�" 'k i^�? ��1� �*�R To- t rIS 11 II 1 l � OMINIIME NM6010rte*;11! • • 5 . Mi SWACt] 5. VH HOLE CLEANING Mi 61995 -2006 M-IL.L.C. 700 GPM MD:2000 ft Operalor:Marathon -- _ -.--- nna " °ra�l'L. TVD :1564 ft WeIName: Susan D'anne6 Bit in Locatbn:NenaiPenbsula Date:10/2/2001 VIRTUAL HYDRAULICS* IIUIII* Country Aisska Hole Cleaning Marathon Susan Dionne 6 1.00 - — ROP 25 ft /Yu \`�.. — ROP 50 ft /hr �''',...,,,,,, — ROP 75 ft /hr Poor Hole Cleaning — ROP 100ftihr — ROP 125 ft /hr 0. 75 — ROP 150 ft/hr ----,_ X . — POP '75 fa'hr 7 C — air Hole Cleaning al C as 0.50 o —` �. — ,` •od Hale Cleaning -- - U o 2 0.25 4 Very Good Hole Cleaning 0 400 500 600 700 800 900 Flow Rate (gal /min) 1: T h4 w ' u' I1 my f" 1 l i l l p i I 'a, r �- v�'s'v ,f" yt ^ P ta k 41:1 3 Y ti q ! 1 k I k tau '�. I I I II ii yA; a V l0�0 yl i.a4t;i i5 1 111 1 4 1111 1 1 w , �p .,0 MI S , I l �� g MI SWACO Kr : - ,I [._�. Section 5 — Production Interval (2000 - 6654') Depth Interval 6654' MD (4436' TVD) (8.5" OH, 4.5" Casing) Drilling Fluid System FLOPRO Flo -Vis / PolyPac UL / KCI / SafeCarb F & M / Asphasol Supreme / Key Products LoTorq / Caustic Soda / Conqor 404 / Sodium Meta Bisulfate / Klagard Solids Control Mongoose shakers, desilter, solids van Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES t)cyf til 1 :tic: Yi ld 11 1 fig 'i`1 Simi Wt Visp;±sit > Poi pi Fluid i. ss l.. OHS 1 GS )19 itt129) {c.I IS (l!' 0011 ) olOtt ¢u it) 1 min Cp pH 0 / 0 6654 8.9 -9.5 10 -16 12 -18 5 -7 30 -40000 9 -9.5 <6 ➢ Use one rig pit for drilling out surface casing. In other rig pits, build new Flo - Pro fluid. ➢ NOTE: LoTorq additions at 3% minimum will be made after mud is sheared down so no losses over shakers. > If running coals become a problem, treat with a 2 -4 PPB addition of Asphasol Supreme. ➢ Periodic additions of LoTorq will be needed to maintain 3% minimal concentration. D Condition mud prior to running 4-1/2" casing. 1 1 * Irt P0 0-4 -0 0404140'00 I ,III • • b !1 (f ii fi ( l e. Mi SWACO 3I I I lulll . t 1 Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 6654' and moving cuttings concentration (MCC) in the annulus while drilling the section. ,, VH SNAPSHOT ma ©1995 -2006 M -IL.L. . 800 GPM MD:8854 ft Operator:Marath n '� ' ve4 ' TVD:4436 ft WeUNama: Susan Dbnne 8 HRl'UA N�R Y 1� H YDRAULICS * Snap( BB Sh•:8.5 In Locatbn:Ka Penbsula 411/1 d1w11 Date:1022008 Country Masks _. Depth Geometry Angb Density Va Hob Clean Pressure Dtstrbutbn (ft) MD/TVD Csg ODAD ( °) (UP 4 (ft/min) Index (%) (a) (in) 0 45 90 92 90 10.0 100 0 300 600 VG 5 F P 1311=27.7 Ann =13 130 =592 ■000 ,II ■ Mil 1500 ) Mil I — L .._ II 1111 ,,,111111 - - , "Mil Drilling Flub FLOPRO NT 0 2000 9.905 / 1 Mud Weght Fluid b/gal y 4 Y e.ea5 , E. Test Temp 120 °F System Data Flow Rate 500 gaYtnb 3000 ( 1 Penetration Rate 100 ft/hr Rotary Speed 80 rpm Weight on BR 10 1000b 3500 Bit Nozzles 0.902 in 000 ■ ! 111 P e88Yre Lasaea ■ , -- I ring d Power Law D rtll St ring 562 psi 4500 !-- 1 ��.. MWD 247 psi soon 11 ■ ,1,. Motor 263 psi ! Bit On /Off 100 psi 5500 Annulus 124 psi i - - , 1 11 Surface Equip 20 psi moo , , 1 ■ ,. ' Y-: t 29 psi I 1 Total System ystern 1492 psi II !! .- = I 3000 .5....... w - ® Fe.'D.Mee 17OLe 0 • MI SWAGO u,r VH HOLE CLEANING a at� �+��f A �" ®1895- 200fiMIL SOO GP MD:6656 ft ft OPe t r Loeatbn:K Marathon f RJ -( �c TVD: 4636 W Opert Susan Danne6 — p a,n ero N�III HY��WIRiVS� �O* Bt .te h l. nke nlnsua D 6.:8. RR006 Country Ala ,I Hole Cleaning Marathon Susan Dion 6 ioo R O P 25 ft /hr ? 1,17 ROP 50 ftlhr ROP 75 Tt /hr ROP 700 it /hr� e — ROP 125 ft/ is 1 0.75 ROP 750 ihi hr — ROP 7' X - ,e: \� A 1 1 rd ' der.. s«: non '' a ' a 'Y' ' , Fair Ho e C - t0 0 .50 -- ,— ... ...___._.._..�__ __ Goo Ho le Cleaning Q _.:._ . C ._— 0.25 : V ery Good Hole C leaning 400 420 440 460 480 500 520 540 560 580 600 620 640 660 Flow Rate (gal /min) Ct� ®I�1 6 — Solids Eq uipment Solids Removal Equipment Re commendations: The recommended SRE for this well are: Mongoose Shakers and Swaco Solids Van. Recommended shaker screens sizes are as follows: Interval Recommended Screen Sizes Reco mmende d Screen Sizes (S haker 1) (Shaker 2) 2000' (Surface) 165 200 me 165 — 200 mesh 200 6654 (Production) comp 200 — 230 mesh 200 — 230 mesh letion 230 — 275 m esh 230 — 275 mesh e ll <3 i Ili'' ...:.':,' • • Mi SWACO Section 6 — Summary of Cost and Product Usage 12.25 in Hole Sections (2000 ft.2 Product Unit Size I Units Required Cost / Product M - Gel 50 # Sx. 484 Caustic Soda 50 # Sx. 21 Gelex 2# Sx. 27 Polypac Supreme 50# Sx 21 Sodium Bicarb 50# Sx 21 CF Desco 25# Sx. 21 Soda Ash 50# Sx 15 Total Estimated Product Cost 8.5 in Hole Section (2000 ft. - 6654 ft.) Product 1 Unit Size Units Required Cost / Product M - WATE 50 # Sx. 275 Asphasol Supreme 50 # Sx. 73 SafeCarb 50 # Sx. 734 Soda Ash 50 # Sx. 9 Caustic 50 # Sx. 18 PolyPac UL 50 # Sx. 73 FloVis 50 # Sx. 147 Sodium Metabisulfite 50 # Sx. 37 Myacide 5 gal 20 Defoam X 5 gal 20 Conqor 404 55 gal 4 KlaGard 55 gal 16 LoTorq 55 gal 42 KCL 50# Sx. 770 Bicarb 50# Sx. 9 Total Estimated Product Cost • • 11/N SVI AC: Appendix 1 — Lost Circulation Recommendations The following proactive lost circulation decision tree can be modified to include any contingencies that Marathon requires. The flowchart allows for planning of lost circulation material needs. No LCM Restrictions Losing fluid while drilling I I Measure rate of loss Seepage losses Partial losses Severe losses 5 - 20 bbl /hr 20 -60 bbl /hr 60 — 200 bbl/hr or Total loss of returns 1 If fault related drill across fault If fault related drill across fault If fault related drill across fault 1 -1.5 times the length of the 1 -1.5 times the length of the 1 -1.5 times the length of the throw before treating losses throw before treating losses throw before treating losses 1 1 _ Spot 45 ppb pill *: Spot 80 ppb pill: Contact Drilling / G -SEAL Plus 10 ppb N11UCCeS G -SEAL 15 ppb _ N , eS _ Asset Engineer NI-IA II M 15 ppb ♦ M -I -X 11 C 20 pp for approval SAFE CARB 40 10 ppb M -I SEAL M 10 ppb SAFECARB 250 15 ppb NUTPLUG F 5 ppb NUTPLUG F 10 ppb Magma Fiber 5 ppb Magma Fiber 10 ppb Spot 80 ppb pill Pump thru BHA Circ sub required Circ sub required G -SEAL 15 ppb M -I -X II C 20 ppb M -I SEAL M 10 ppb SAFECARB 250 15 ppb NUTPLUG F 10 ppb Magma Fiber Reg 10 ppb 1 Squeeze high- fluid -loss pill *: FORM -A- SQUEEZE 80 ppb (2sx/bbl) in water`° Weighted up to desired density Pump thru BHA * The particle size of these products is smaller than Nut Plug M Spot plug: Gunk Squeeze or FORM -A -SET AK M4' 101 °I-40101111110 • • Mi SWACO 1 LCM Restrictions Losing fluid while drilling I Measure rate of loss • / IL.----- Seepage losses Partial losses Severe losses 60 5 - 20 bbl /hr 20 -60 bbl /hr 200 bbl /hr or Total loss of returns 1 1 v If fault related drill across fault If fault related drill across fault If fault related drill across fault 1 -1.5 times the length of the 1 -1.5 times the length of the 1 -1.5 times the length of the throw before treating losses throw before treating losses throw before treating losses • Spot 50 ppb pill *: Spot 80 ppb pill Contact Drilling / Asset Circ sub required 11 ' Engineer for approval SAFECARB 40 20 ppb SAFECARB 250 10 ppb No SAFECARB 40 10 ppb SAFECARB 500 15 ppb SAFECARB 250 15 ppb Magma Fiber Reg 5 ppb SAFECARB 500 30 ppb SAFECARB 1000 15 ppb Spot 80 ppb pill Pump thru BHA \ Magma Fiber Reg 10 ppb Circ sub required No succeti, I G -SEAL 15 ppb M -I -X II C 20 ppb No success M -I SEAL M 10 ppb • SAFECARB 250 15 ppb NUTPLUG F 10 ppb Contact Drilling /Asset Magma Fiber Reg 10 ppb Engineer for anaroval • Spot 80 ppb pill • Circ sub required Squeeze high- fluid -loss pill: G-SEAL 15 ppb No sueera, FOR -A -S UEEZE M -I -X H C 20 ppb Q M -I SEAL M 10 ppb 80 ppb (2 sx/bbls) in water SAFECARB 250 15 ppb Weighted up to NUTPLUG F 10 ppb desired density Magma Fiber Reg 10 ppb Pump thru BHA I • * The particle size is smaller than Nut Plug Medium Spot plug: Gunk Squeeze or FORM -A -SET AK • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF Marathon Oil ) Conservation Order No. 607 Company for an order granting an exception ) to the well spacing requirements of 20 AAC ) Ninilchik Unit Susan Dionne No. 6 25.055(a)(4) to allow drilling, completion, ) Gas Development Well testing, and regular production of the proposed ) Susan Dionne No. 6 gas development well ) within 3,000 feet of other wells (in the Ninilchik ) October 8, 2008 Unit of the proposed Dionne /Paxton ) Participating Area) that are producing from or capable ) of producing from the same intervals. ) IT APPEARING THAT: 1. Marathon Oil Company (MOC), by letter dated May 6, 2008, and received that same day by the Alaska Oil and Gas Conservation Commission (Commission), requests an order providing for an exception to the well spacing requirements of 20 AAC 25.055(a)(4) to allow drilling, completion, testing, and regular production of the Susan Dionne (SD) No. 6 gas development well within 3,000 feet of the SD No. 1, SD No. 2, SD No. 3, SD No. 4, and SD No. 5 wells: the proposed SD No. 6 well may be capable of producing from the same pools (i.e., the Tyonek and Beluga Formations) as the SD No. 1, SD No. 2, SD No. 3, SD No. 4, and SD No. 5 wells. The proposed well and other wells are within the Ninilchik Unit of the proposed Susan Dionne/Paxton Participating Area, Kenai Peninsula Borough, Alaska. 2. On May 9, 2008, pursuant to 20 AAC 25.540, the Commission published in the ANCHORAGE DAILY NEWS notice of the opportunity for a public hearing on June 12, 2008. 3. No protest to the application or request for a hearing was received. 4. The public hearing was vacated on June10, 2008. FINDINGS: 1. MOC will be the operator of the SD No. 6 well, which will be within the Ninilchik Unit of the proposed Susan Dionne /Paxton Participating Area, Kenai Peninsula Borough, Alaska. 2. The SD No. 6 well is proposed as a deviated gas delineation well with a surface location 1,145 feet from the east line (FEL) and 405 feet from the north line (FNL) of Section 6, TIS, R13 W, Seward Meridian (S.M.), and a projected bottom hole location 322 feet FEL, 875 feet FNL, of Section 12, T1 S, R14W, S.M. 3. The SD No. 6 well will target gas reservoirs that can be discontinuous in the Tyonek Formation Ti gas sands and the Beluga Formation gas sands. • 4. The SD No. 6 well is within 3,000 feet of the SD No. 1, SD No. 2, SD No. 3, SD No. 4, and SD No. 5 wells, which are also within the Ninilchik Unit of the proposed Susan Dionne /Paxton Participating Area. 5. The SD No. 1, SD No. 2, SD No. 3, SD No. 4, and SD No. 5 wells produce from the Tyonek Formation and penetrate Beluga Formation sands that are capable of producing gas. 6. By certified mail, MOC sent notice of the application for an order granting an exception to the well spacing requirements of 20 AAC 25.055 to all owners, landowners, and operators of all properties within 3,000 feet of the anticipated productive intervals of the proposed SD No. 6 well. CONCLUSIONS: 1. Exceptions to 20 AAC 20.25.055(a)(4) are necessary to allow drilling, completion, testing, and regular production of the SD No. 6 gas well. This well is needed to evaluate the Tynoek Formation T1 gas reservoirs and Beluga Formation gas reservoirs in the Ninilchik Unit of the proposed Susan Dionne /Paxton Participating Area. 2. Granting a spacing exception to allow drilling, completion, testing, and regular production of the SD No. 6 well will not result in waste or jeopardize the correlative rights of adjoining or nearby owners. NOW, THEREFORE, IT IS ORDERED: Pursuant to the Commission's authority under AS 31.05.030, and 20 AAC 25.055, the Commission approves MOC' s application for an order granting an exception to the well spacing provisions of 20 AAC 25.055(a)(4) to allow drilling, completion, testing, and regular production of the SD No. 6 well. Because the properties affected by this spacing exception are wholly within the Ninilchik Unit of the proposed Susan Dionne /Paxton Participating Area, MOC may proceed with regular production as long as it complies with the terms of the Ninilchik Unit and proposed Susan Dionne /Paxton Participating Area agreements and all other legal requirements. ENTERED at Anchorage, Alaska, and dated October 8, 2008. ri ,....-- - 7 l,,t],. r,„. x . ` _. "- �v, Daniel T. Seamount, Jr., Chair �' Alaska Oil and Gas Conservation Commission et. eir orman, Commissioner Alaska Oil and Gas Conservation Commission Conservation Order No. 607 Effective October 8, 2008 Page 2 of 3 • RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is tiled. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tike questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Conservation Order No. 607 Effective October 8, 2008 Page 3 of 3 • • TRANSMITTAL LETTER CHECKLIST WELL NAME A4i/ C»' /,C �iYir ��- PrD# 2of- 4c• /Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: /19 /,G POOL: . Ze,rGA 0 /7 - Vows • Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new weilbore segment of existing well (If last two digits in Permit No. , API No . 50- API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/1 12008 WELL PERMIT CHECKLIST Field & Pool NINILCHIK, SD BELUGA UNDEF GAS - 562562 Well Name: NINILCHIK UNIT SD-6 Program DEV Well bore seg ❑ PTD#: 2081600 Company MARATHON OIL CO Initial Class/Type DEV / PEND GeoArea 820 Unit 51432 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a definedpool Yes 5 Welllocated proper distance from drilling unit boundary Yes 6 Welliocated proper distance from other wells No Spacing Exception C0607 completed. 7 Sufficient acreage available in_driiling unit Yes 4360 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party No Marathon and Unocal. 10 Operator has_appropriate bond in force Yes Blanket Bond # 5194234. 11 Permit can be issued without conservation order No CO 607 issued. Appr Date 12 Per_mitcan be issued without administrativ_e_approval Yes ACS 10/15/2008 13 Can permit be approved before 15 -day wait Yes 14 _Well _located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1 /4mite area of review identified (For ser vice well only) NA 16 Pre - produced injector; duration_of pre production less than 3 months_ (For service well only) _ _ _NA. 17 Nonconven, gas conforms to AS31.05.03QU.l.A),(1_2.A -D) NA Engineering 18 Conductor string_provided Yes 19 Surface_casingprotects all known USDWs Yes Surface Casing set at 1564' tvd. 20 CMT vol adequate to circuiate_on conductor & surf csg Yes 21 CMTv_ol adequate to tie -in Jong string to surf csg Yes Production casing planned as a liner with a tieback. 22 CMTwiU cover_ all known_ productive horizons Yes 23 Casing designs adequate for C, T B & permafrost Yes 24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 If_a_ re- drill, has a 10-403 for abandonment been approved NA 26 Adequate_w_ellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated. 27 lf_diverter_required, does it _meet reg ulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 8.8 EMW. MW planned up to 9.5ppg. TEM 10/16/2008 29 BOPEs,_do they meet regulation Yes 30 BOP_press rating appropriate; test to_(put psig in comments) Yes MASP calculated at 1062 psi w/ 3Q % mud -7Q % gas. With gas only 1586 psi. 29Q0 _psi BOP test appropriate_ 31 Choke manifold complies w /API_ RP -53 (May 8 4) Yes 32 Work will occur without operation shutdown Yes • 33 Is presence of H28 gas probable No H2S is not known in CI gas welts. Rig has sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures Yes No H2S reported for Kenai area. 36 Data_presented on potential overpressure zones NA_ Appr Date 37 Seismic analysis of shallow gas zones NA ACS 10/15/2008 38 Seabed condition survey (ff off - shore) NA 39 Contact name /phone for weeklyprogress reports (exploratory only] Yes Will Tank - 713 - 296 -3273. Geologic - Engineering Public Commissioner: Date: Commissione : Date Commissioner Date , � l / - Z1) • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. • MA BATH N SUSAN DIONNE 6 SEC 6 T15N R13W SM November 6, 2008 — November 15, 2008 tt • E - It 4 :u r. • Craig Silva: Senior Logging Geologist Ralph Winkelman: Senior Logging Geologist E1 EPOCH • M MARATHON OIL COMPANY SD6 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 2 1.1. EQUIPMENT SUMMARY 2 1.2. PERSONNEL 2 2. GENERAL WELL DETAILS 3 2.1. OBJECTIVES 3 2.2. WELL RESUME 3 2.3. HOLE DATA 3 3. GEOLOGICAL DATA 4 3.1. SAMPLING PROGRAM AND DISTRIBUTION 11 4. DRILLING DATA 12 4.1. DAILY ACTIVITY SUMMARY 12 4.2. SURVEY RECORD 20 4.3. MUD RECORD 24 4.4. BIT RECORD 25 4.5. DRILLING PROGRESS CHART 26 5. DAILY REPORTS 27 ENCLOSURES: Formation Log MD 2" = 100' Formation Log TVD 2" = 100' Drilling Dynamics MD 2" = 100' Drilling Dynamics TVD 2" = 100' S EPOCH M MARATHON OIL COMPANY SD6 • 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime Low gas readings are pervasive due to the Standard Air Drive Trap Mounted In t urn mud. F 14" straight of p return mud. Falls 14" straight Ditch Gas Possum Belly; FID Total Hydrocarbon down through an air gap as it Analyzer And Chromatograph exits the flowline and impacts the fluid of a tiny possum belly in a wide splash, before reaching the gas trap. Rate of Penetration (ROP) Primary Drawworks Shaft Encoder On 0 Drum Shaft Pump stroke counters Externally Mounted Magnetic Proximity 0 Sensor Hookload / Weight on bit (WOB) Hydraulic Pressure Cell 0 Drill string torque Hydraulic Pressure Cell 0 Top drive rotary (RPM) Externally Mounted Magnetic Proximity 0 Sensor Standpipe Pressure Hydraulic Pressure Cell 0 Mud flow in / out (MFI / MFO) MFI Derived From SPM / MFO From 0 Flow Paddle Pit volumes Ball and probe sensor 0 • Driller's work station Explosion Proof Touch Screen 0 Casing Pressure Hydraulic Pressure Cell 0 Company man's work station HP COMPAQ 0 Mud Engineer's work station HP COMPAQ 0 Living quarter's work station HP COMPAQ 0 Pit's work station Explosion Proof Touch Screen 0 1.2. PERSONNEL SD6 Unit Number: ML006 Years Days Sample Catchers/ Days Days Mudloggers Experience at Trainees at Technician at well well well Craig Silva 31 20 Ryan Boothe 6 Steve Forrest 1 Ralph Winkelman 18 11 Dean Kekaualua 9 James Foradas 1 4 El EPOCH 2 " MARATHON OIL COMPANY SD6 2. GENERAL WELL DETAILS • 2.1. OBJECTIVES The objective of Susan Dionne 6 is to drill and log a Multi Zone Development Gas well in the Ninilchik Unit with a minimum of hole problems or other concerns. A standard completion will be performed. 2.2. WELL RESUME Operator: MARATHON OIL COMPANY Well Name: Susan Dionne 6 Field: Ninilchik Unit County: Kenai Borough State: Alaska Company Representatives: John Nicholson Mitch Burns Rowland Lawson Dan Byrd Location: 316' FSL, 1132' FEL, Sec 6 T1 S R13W SM, X= 1,353,336.589, Y= 2,236,547.541 Classification: Multi Zone Development Gas API #: 50 — 133 — 20582 — 00 — 00 Permit #: 208 - 160 Activity Code: (WBS #s) DD.08.17742.CAP.DRL Rig Name / Type: Glacier #1 / Land / Double Elevation: Ground, RKB 142.00'GL, 163.00' RT Primary Targets: / Target Depths: Beluga (3808', 2224' TVD), Beluga (4272', 2445' TVD) r mary Targets: /Target Depths Beluga (5495', 3442' TVD), Tyonek T1 (5730', 3645' TVD) lihd Date: November 6, 2008 Total Depth 6737' Total Depth Formation: Tyonek Total Depth Date: November 15, 2008 MWD Company: / Tools Run: Baker Hughes Inteq / Directional MWD Directional Drilling: Baker Hughes Inteq Drilling Fluids Company: M -I Drilling Fluids Logging Companies: Weatherford Wireline Services: Quad -Combo on shuttle, MFT on wireline. 2.3. HOLE DATA SD 6 Hole Maximum Depth T.D. Mud Deviation Shoe Depth F.I.T. g Casing Section MD SSTVD Formation Weight ( ° inc) MD SSTVD EMW 12 %4" 2031' 1417.33' Sterling 9.3 69.77 9 5 /" 2030.5' 1417.15' 15.00 8 '/" 6737' 4357.28' Tyonek 9.6 29.66 4 %2" 6735' 4355.54' Standard Completion • L I EPOCH 3 " MARATHON OIL COMPANY SD6 3. GEOLOGICAL DATA Sand /Sandstone /Conglomeratic Sand /Conglomerate/Tuffaceous Sandstone (2051'- 2500') = medium light gray to medium dark gray with faint to locally strong light olive gray to light brownish gray secondary hues; greenish coloration generally derived from greenstone lithics and associated minerals; brownish coloration from increased volume of tuffaceous matrix clays; very fine lower to granule (lower conglomerate); nearly all very fine are glass shards winnowed from volcanic ash; most abundant fraction is fine upper to medium upper; moderately sorted when fine, poorly sorted when coarser; evident fining upward; basal zones conglomeratic; sand fraction is angular to subangular with spotty subrounded; conglomeratic fraction is subangular to rounded; trace well rounded granules; abundantly disaggregated; very dominant clay matrix supported if consolidated; minor sandstone with abundant very light gray matrix of volcanic ash grading to tuffaceous claystone, and another minor sandstone group with more complex mix of intergrain material that includes tuffaceous clay- ash -silt, calcite and silica cements, devitrified ash, tightly "packed" microshards and various replacement mineralization and /or alteration products; very dominant compositional graywacke; minor lithic arenite in uppermost zones of massive sections; estimate 40 -75% quartz and volcanic glass, trace feldspar, 5 -15% cryptosilica (chalcedony, chert) and non - differentiated silica,25 -50% lithic fragments and mafic minerals; lithics dominated by medium gray to dark gray phyllite rock fragments and dark gray to grayish black closely associated argillite rock fragments; less dominant but very distinctive light -dark green to grayish green to variegated green low grade meta greenstone rock fragments; mafic minerals not differentiated except for augite, biotite and occasionally magnetite, but also other dark opaque to translucent "black- green- brown" minerals; 75 -80% of quartz is colorless to very pale gray and other very pale colors and translucent, 20 -25% of quartz and nearly all volcanic glass is colorless and transparent. Tuffaceous Claystone /Tuffaceous SiltstoneNolcanic Ash/Tuffaceous Shale (2051'- 2500') = redeposited, reworked sediments derived from volcanic ash; all closely gradational with many shared characteristics; microshards- shards discernible and often abundant to pervasive; light brownish gray to • medium gray; many subtle color gradient changes to other gray and brown primary colors and secondary hues. Sand (2400'- 2540') = medium gray with a strong "salt and pepper" appearance with individual grains dominantly light to medium translucent gray, dark gray to black, clear to translucent quartz and volcanic glass, white and trace pale greenish gray; very fine upper to trace very coarse upper with pebble fragments, dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; unconsolidated; trace dark brown to black carbonaceous material. Tuffaceous Claystone/Tuffaceous Siltstone (2480'- 2600') = medium light gray with light brown and light olive secondary hues; very soft and sticky; shapeless, globular, amorphous cuttings; silty to clayey to slightly gritty texture from suspended sands; dull earthy luster; moderate to very soluble; hydrophilic; moderately expansive when hydrated; poor cohesiveness; good adhesiveness; moderate to very calcareous; trace dark brown to black microthin carbonaceous laminations and particles in firm fragments. Sand /Conglomeratic Sand (2540'- 2660') = medium gray with salt and pepper appearance overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black, light greenish gray, white; fine lower to rare very coarse upper, dominantly medium upper to lower; angular to subangular; poor to fair sorting; disaggregated with common light gray clayey /ashy supporting matrix; slight to moderately calcareous. Coal (2620'- 2640') = black with dark brown secondary hues; blocky to platy; massive; planar fracture dominant with conchoidal and birdeye common; smooth to slightly gritty texture; resinous to earthy lustre; trace to common outgassing bubbles present. S El EPOCH 4 \"' MARATHON OIL COMPANY SD6 Sand /Conglomeratic Sand (2640'- 2760') = medium to medium dark gray overall with a strong "salt and • pepper" appearance with individual grains dominantly light to medium translucent gray, dark gray to black, clear to translucent quartz and volcanic glass, white and trace pale greenish gray; very fine upper to very coarse upper with pebble fragments, dominantly medium upper to lower; angular to subangular; poor to fair sorting unconsolidated; common light gray, clay /ashy supporting matrix. Tuffaceous Claystone/Tuffaceous Siltstone (2720'- 2840') = light to medium light gray with light brown to light brownish gray secondary hues; very soft; shapeless, globular cuttings, firmer fragments show pdc bit "scooped" appearance; silty to clayey texture; dull, earthy to slightly waxy luster; moderate to very soluble; expansive when hydrated poor to fair cohesiveness; poor to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and particles. Sand (2800'- 2880') = medium gray with a strong "salt and pepper" appearance with individual grains dominantly light to medium translucent gray, dark gray to black, clear to translucent quartz and volcanic glass, white and trace pale greenish gray; very fine upper to trace very coarse lower, dominantly fine upper medium lower; angular to subangular; poor to fair sorting; disaggregated with light gray clayey /ashy supporting matrix common; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (2840'- 2960') = light to medium light gray with light brown to light brownish gray secondary hues; very soft; shapeless, globular cuttings, firmer fragments show pdc bit "scooped" appearance; silty to clayey texture; dull, earthy to slightly waxy luster; moderate to very soluble; expansive when hydrated poor to fair cohesiveness; poor to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and particles. Sand (2920'- 3040') = medium light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to light greenish gray, medium to dark gray, black and white; very fine lower to medium lower, dominantly fine; angular to subangular; fair to good sorting; • unconsolidated with common light gray clayey supporting matrix; abundant clay with floating sand grains. Coal (3030' - 3050') = black with dark brown secondary hues; blocky to platy; massive; planar fracture dominant with conchoidal and birdeye common; smooth to slightly gritty texture; resinous to earthy lustre; trace to common outgassing bubbles. Tuffaceous Claystone/Tuffaceous Siltstone (3020'- 3140') = medium light gray with light brown and light olive secondary hues; very soft and sticky; shapeless, globular, amorphous cuttings; silty to clayey to slightly gritty texture from suspended sands; dull earthy luster; moderate to very soluble; hydrophilic; moderately expansive when hydrated; poor cohesiveness; good adhesiveness; slight to moderately calcareous; trace dark brown to black microthin carbonaceous laminations and particles in firmer fragments. Sand (3100'- 3220') = medium to medium dark gray with a moderate "salt and pepper" appearance, individual grains dominantly clear to translucent quartz and volcanic glass with equal amounts of light to medium to dark gray, black and trace white and pale greenish gray; fine lower to coarse lower, dominantly fine upper to medium lower; angular to subangular; moderately well sorted; unconsolidated with common light gray clayey /ashy supporting matrix; non calcareous. EPOCH 5 "M MARATHON OIL COMPANY SD6 Tuffaceous Claystone/Tuffaceous SiltstoneNolcanic Ash (3160'- 3500') = occurs as redeposited, • reworked sediments derived from volcanic ash; all closely gradational with many shared characteristics; microshards shards discernible and often abundant to pervasive; light brownish gray to medium gray; many subtle color gradient changes to other gray and brown primary colors and secondary hues; soft to firm to brittle; very dominant slightly firm or slightly brittle; cuttings that 100% of a single mudrock type are uncommon; nearly all soft cuttings are a complex mix of clay - silt -ash; roughly equal overall percentages of massive and interbedded soft rocks; tuffaceous claystone is usually the dominant lithology, and occasionally exclusive in very massive sections; clayey to silty to ashy to various soft matte, mixed and mottles textures; earthy lustres; also commonly displays microgritty texture and microsparkly lustre when the shard content is very high; many devitrified clays have a dull to subwaxy lustre; tuffaceous mudrocks are the intergrain support material of most sandstones; most soft mudrocks are hydrophilic and entirely to partially soluble, with poor to marginally good cohesiveness and adhesiveness; consistent spotty microthin dark brown to black laminations of coal and other carbonaceous material; laminations are locally abundant when tuffaceous mudrocks are adjacent to coals. Sand /Sandstone /Tuffaceous Sandstone /Conglomeratic Sand (3220'- 3700') = medium gray to medium dark gray with generally strong light olive gray secondary hue and faint light brownish gray; greenish colors apparently derived from greenstone lithics and minerals; brownish coloration from increased volume of tuffaceous matrix clays; very fine lower to granule (lower conglomerate); nearly all glass shards winnowed from volcanic ash; very dominant percentage very fine are g ry a is fine lower to coarse p 9 upper; moderately sorted when fine, poorly sorted when coarser; evident fining upward in massive sands; basal consistently with medium upper and larger; very dominant angular to subangular with spotty subrounded; abundantly disaggregated; very dominant clay matrix supported if consolidated; abundant tuffaceous sandstone with very light volcanic ash matrix grading to tuffaceous claystone; spotty sandstone with complex mix of intergrain material that includes tuffaceous clay- ash -silt, calcite - silica cements, devitrified ash, "packed" microshards and various replacement mineralization and /or alteration products; compositional graywacke; estimate 30 -75% quartz and volcanic glass, trace feldspar, 5 -15% cryptosilica (chalcedony, chert) and non - differentiated silica, 25 -60% lithic fragments and mafic minerals; dominant lithics are medium to dark gray phyllite rock fragments and grayish black associated argillite rock fragments, closely followed by very distinctive light -dark green to grayish green to variegated green low grade meta greenstone rock fragments; remaining spotty lithics are from diverse sources. Tuffaceous Claystone/Tuffaceous Siltstone (3620'- 3740') = light gray with light yellowish gray secondary hues; very soft; shapeless, globular cuttings; very sticky; silty to clayey to slightly gritty texture from fine suspended sands dull, earthy to waxy luster; hydrophilic moderate to very soluble; moderately expansive when hydrated; poor cohesiveness; fair to good adhesiveness; slight to moderately calcareous; trace dark brown to black microthin carbonaceous laminations and particles in firmer pieces; trace light gray siltstone is hard and very calcareous; commonly grades between a silty sandstone and sandy siltstone. Sand /Sandstone /Conglomeratic Sand (3700'- 3840') = medium to medium dark gray overall with a moderate to strong "salt and pepper" appearance, individual grains dominantly light to medium translucent gray, medium to dark gray, clear to translucent quartz and volcanic glass and lesser amounts of black, white and light greenish gray; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; moderately well sorted; disaggregated with trace dark gray sandstone; very fine grain; hard and brittle; very calcareous cement; trace dark brown to black carbonaceous material /coal. Sand /Conglomeratic Sand (3800'- 3900') = medium to medium dark gray overall with a strong "salt and pepper" appearance with individual grains dominantly light to medium translucent gray, dark gray to black, clear to translucent quartz and volcanic glass, white and trace pale greenish gray; very fine upper to very coarse upper with pebble fragments, dominantly medium upper to lower; angular to subangular; poor to fair sorting; unconsolidated; common light gray, clay /ashy supporting matrix. S EPOCH 6 " MARATHON OIL COMPANY SD6 Sand /Sandstone /Conglomeratic Sand (3860'- 3980') = medium to medium dark gray overall with a • moderate to strong "salt and pepper" appearance, individual grains dominantly light to medium translucent gray, medium to dark gray, clear to translucent quartz and volcanic glass and lesser amounts of black, white; fine lower to very coarse upper with pebble fragments, dominantly medium upper to lower; angular to subangular; moderately well sorted; dominantly unconsolidated with scattered cemented sandstone pieces medium grain; grayish white, non calcareous cement; trace thin coal beds. Tuffaceous Claystone /Tuffaceous Siltstone (3920' - 4040') = light gray with light yellowish brown secondary hues; very soft; shapeless, globular cuttings; very sticky; silty to clayey to slightly gritty texture from fine suspended sands dull, earthy to waxy luster; hydrophilic moderate to very soluble; moderately expansive when hydrated; poor cohesiveness; fair to good adhesiveness; slight to moderately calcareous; trace dark brown to black microthin carbonaceous laminations and particles; trace thin coal beds /carbonaceous shale. Coal (3960'- 4080') = black with dark brown secondary hues; blocky to platy; massive; planar fracture dominant with conchoidal and birdeye common; smooth to slightly gritty texture; resinous to earthy lustre; none to trace outgassing bubbles. Sand /Sandstone /Conglomeratic Sand (4040' - 4180') = medium to medium dark gray overall with a moderate to strong "salt and pepper" appearance, individual grains dominantly light to medium translucent gray, medium to dark gray, clear to translucent quartz and volcanic glass and lesser amounts of black, white; fine lower to very coarse upper with pebble fragments, dominantly medium upper to lower; angular to subangular; moderately well sorted; dominantly unconsolidated with scattered cemented sandstone pieces soft to friable; fine to medium grain; light grayish white, calcareous cement; trace thin coal beds. Tuffaceous Claystone/Tuffaceous Siltstone (4120' - 4240') = light gray to light medium gray to light • brownish gray very soft; shapeless, globular cuttings; very sticky; silty to clayey to slightly gritty texture from fine suspended sands dull, earthy to waxy luster; hydrophilic moderate to very soluble; moderately expansive when hydrated; poor cohesiveness; fair to good adhesiveness; none to slightly calcareous; trace dark brown to black microthin carbonaceous laminations and particles; trace thin coals /carbonaceous shale beds. Sand (4220' - 4340') = medium to medium light gray with light greenish gray secondary hue, weak "salt and pepper" appearance, individual grains dominantly light to medium translucent gray, clear to translucent quartz and volcanic glass medium to dark gray, black, light greenish gray; fine lower to coarse lower, dominantly medium; angular to subangular fair to good sorting; dominantly unconsolidated with trace light grayish white ashy /clayey supporting matrix; soft; non calcareous; trace dark brown to black carbonaceous shale /material /coal. Tuffaceous Claystone/Tuffaceous Siltstone (4300' - 4420') = light gray with light yellowish brown secondary hues; very soft; shapeless, globular cuttings; very sticky; silty to clayey to slightly gritty texture from fine suspended sands; dull, earthy to waxy luster; hydrophilic moderate to very soluble; moderately expansive when hydrated; poor cohesiveness; fair to good adhesiveness; slight to moderately calcareous; trace dark brown to black microthin carbonaceous laminations and particles; trace thin coal beds /carbonaceous shale. Sand /Sandstone /Conglomeratic Sand (4360'- 4480') = medium to medium dark gray overall with a moderate to strong "salt and pepper" appearance, individual grains dominantly light to medium translucent gray, medium to dark gray, clear to translucent quartz and volcanic glass and lesser amounts of black, white and light greenish gray; very fine lower to trace very coarse upper, dominantly fine upper to medium lower; angular to subangular; moderately well sorted; disaggregated with common light gray ashy /clay supporting matrix; non to slightly calcareous; trace black carbonaceous clastic material. I E I EPOCH M MARATHON OIL COMPANY SD6 Tuffaceous Claystone/Tuffaceous Siltstone/Volcanic Ash (4420' - 4900') = occurs as redeposited, • reworked sediments derived from volcanic ash; all closely gradational with many shared characteristics; microshards and shards easily discernible and often abundant to pervasive; light brownish gray to medium gray; note wide - ranging subtle changes to other gray and brown primary colors and secondary hues; soft to firm to brittle; very dominant slightly firm or slightly brittle; local occurrences of a single lithology are uncommon; soft cuttings are a very dominantly a complex mix of clay - silt -ash; note generally equal amounts of massive and interbedded soft rocks; tuffaceous claystone is most often the dominant lithology and, when very massive, is most likely to exclude other rock types; clayey to silty to ashy to various soft matte, mixed and /or mottled textures; earthy lustres; note common combined microgritty texture and microsparkly lustre when the shard content is very high; many devitrified clays have a dull to subwaxy lustre; soft tuffaceous mudrock is the pervasive intergrain support material of most sandstone; soft tuffaceous claystones and other mudrocks are hydrophilic and partially to totally soluble, and have poor to marginally good cohesiveness and adhesiveness; note consistent spotty micro -thin dark brown to black coal and carbonaceous laminations and particles, which become abundant when adjacent to coals; also note localized distinctive gradation to brown - colored carbonaceous tuffaceous claystones /siltstones. Coal /Carbonaceous Shale (4500'- 5000') = black to brownish black; generally not very massive, but thinly interbedded zones of coal /carbonaceous shale, or differing coal grades, or coal and other lithologies; range from low grade lignite to high grade lignite; note that much of the coal is finely ground up by the bit action ( "coffee ground coal "); some coal is locally common as clastic lithic constituent of sandstone; larger pieces are irregular- shaped to thin and subplaty- platy; blocky coal cuttings habit is much less common; occasional microbubbles from outgassing; very dense matte to smooth texture; dull to occasionally resinous lustre; irregular to platy fracture; thinly interbedded with the carbonaceous shale and the tuffaceous lithologies. Sand /Sandstone /Tuffaceous Sandstone /(4480'- 5100') = medium gray to medium dark gray with consistently strong light olive gray secondary hues and faint light brownish gray secondary hues; greenish • coloration derived from abundance of greenstone lithics and minerals; brownish coloration from increased volume of tuffaceous matrix clays; very fine lower to medium upper; nearly all of the very fine are glass shards winnowed from volcanic ash; very dominant percentage is fine lower to medium lower; moderate to moderately well sorted overall; note repeated slight fining upward in massive sands; basal zones consistently medium and larger; very dominant angular to subangular with spotty subrounded; abundantly disaggregated; very dominant clay matrix support when consolidated; common very thin localized sandstones have very light gray volcanic ash matrix support; minor grain supported sandstone with calcite or silica cementation and fragile to marginally hard; also sandstone with complex mix of intergrain material that includes tuffaceous clay- ash -silt, calcite - silica cements, devitrified ash, "packed" microshards and various replacement mineralization and /or alteration products; compositional graywacke; estimate 30 -70% quartz and volcanic glass, trace feldspar, 5 -15% cryptosilica (chalcedony, chert) and non - differentiated silica, 30 -60% lithic fragments and mafic minerals; dominant lithics are medium to dark gray phyllite rock fragments and grayish black associated argillite rock fragments, closely followed by very distinctive light -dark green to grayish green to variegated green low grade meta greenstone rock fragments; remaining spotty lithics are from diverse sources; mafic minerals not differentiated except for augite, biotite and occasionally magnetite, but note many dark opaque to translucent "black- green- brown" minerals; 75 -80% of quartz is colorless to very pale gray and other very pale colors and translucent, 20- 25% of quartz and nearly all volcanic glass is colorless and transparent. Coal (5080'- 5160') = black with dark brown secondary hues; firm to hard; brittle at times; platy to blocky; splintery to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture; earthy to resinous luster; smooth to slightly gritty texture; common to abundant visible outgassing bubbles; coal present in dominantly abundant thin beds. El EPOCH 8 "M MARATHON OIL COMPANY SD6 Tuffaceous Claystone/Tuffaceous Siltstone (5120'- 5240') = medium light gray to light gray with light • brown to light brownish gray secondary hues; very soft to rarely firm; occasionally very sticky; amorphous, shapeless, globular cuttings; silty to clayey texture; earthy to waxy luster; moderately soluble; slight to moderately expansive when hydrated; poor cohesiveness; good adhesiveness; dominantly non calcareous with trace light gray hard very calcareous silty sandstone to sandy siltstone; trace dark brown to black microthin carbonaceous laminations and particles; trace thin coal beds. Sand (5200'- 5320') = medium to medium light gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray to light greenish gray, dark gray to black; very fine lower to coarse upper, dominantly fine lower to medium lower; angular to subangular; moderately well sorted; dominantly unconsolidated with trace light gray silty sandstone /sandy siltstone; hard; brittle; very calcareous; trace to common light gray ashy /clayey supporting matrix for loose sands; trace dark brown to black carbonaceous shale /coal; present as thin beds. Coal (5260'- 5400') = all thinly bedded; black with dark brown secondary hues; firm to brittle to hard; platy to blocky; splintery to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture; earthy to resinous luster; smooth to slightly gritty texture; trace to common visible outgassing. Tuffaceous Claystone/Tuffaceous Siltstone (5320'- 5440') = medium light gray to light gray with light brown to light brownish gray secondary hues; very soft to rarely firm; very sticky at times amorphous, shapeless, globular cuttings, trace firm pieces with bit metamorphism; silty to clayey to slightly gritty texture from abundant fine floating sands; dull, earthy to slightly waxy luster; slight to moderately soluble; slightly expansive when hydrated; poor cohesiveness; poor to fair adhesiveness; trace dark brown to black microthin carbonaceous laminations and particles; trace light gray sandy siltstone /silty sandstone; hard; very calcareous; common to abundant thin coal beds /carbonaceous shale. Sand /Sandstone (5400'- 5580') = medium light gray overall, individual grains dominantly clear to • translucent quartz and volcanic glass, light to medium gray to light greenish gray, dark gray to black; very fine lower to coarse upper, dominantly fine lower to medium lower; angular to subangular; moderately well sorted; dominantly unconsolidated with trace light gray silty sandstone /sandy siltstone; hard; brittle; very calcareous trace "salt and pepper" sandstone; fine to medium grain; moderately hard; poorly sorted; grayish white, very calcareous cemented grains. Tuffaceous Claystone /Tuffaceous Siltstone (5500'- 5620') = medium light gray to light gray with light brown to light brownish gray secondary hues; very soft to rarely firm; very sticky at times amorphous, shapeless, globular cuttings; silty to clayey texture; earthy to waxy luster; moderate to very soluble; slight to moderately expansive when hydrated; poor cohesiveness; good adhesiveness; dominantly non calcareous; trace black microthin carbonaceous laminations. Sand /Sandstone (5580'- 5720') = note several changes in characteristics in this interval before a significant change after 5720'. sands before 5580':are dominant medium dark gray with strong light olive gray and light brownish gray secondary hues and 100% compositional graywacke with locally up to 70% lithics; 75 -80% of all lithics are medium grade meta phyllite rock fragments; grain size ranges from very fine to coarse lower, overall sorting is mostly moderate and fining upward is discernible; grains are dominantly sharp and angular; pervasively disaggregated; consolidated sandstone when present is very dominantly clay matrix supported. after 5580': nearly all disaggregated sand; more complex matrix plus grain support when disaggregated, consolidated sandstone pieces often calcareous cemented; continued compositional graywacke, but lithics fraction is reduced to 30 -50 %, affecting subtle color changes; overall increased lightness values; dominant color shifts to medium gray with continued olive gray and brownish gray secondary hues, and also a faint, but pervasive, yellowish gray secondary hue; note that phyllite- argillite fraction remains dominant, but lithic greenstone fraction increases significantly, and there are distinctive trace minerals that include yellowish green epidote, clear zircon, rose quartz yellow citrine, smoky quartz and red jasper; note average grain size is slightly reduced to dominant fine upper, and there may be some fining downward; grains are more subangular than angular, and subrounded grains • are increasing; overall composition is changing from compositional graywacke to marginal lithic arenite. EPOCH 9 (M) MARATHON OIL COMPANY SD6 411 Sand /Sandstone (5720'- 6200') = note significant change in characteristics after 5720'. overall color dominantly light medium gray with faint light olive gray and very faint yellowish gray secondary hues; note that darker olive gray and brownish gray hues are absent; size range continues from very fine lower to medium upper, but improved sorting overall; dominantly moderately well sorted at fine upper to borderline medium lower; some very subtle fining upward in very sections; note that trace grains larger than medium upper appear to be a second mode "floating" in the finer sand; well distributed consistent very fine is <5% and almost all appears to be glass shards winnowed from volcanic ash; dominant angular to subangular and discoidal to subdiscoidal with gradually increasing minor (5 -10 %) fraction of subrounded to rounded grains; note also that more of the angular grains appear equi - dimensional after 5720'; nearly all disaggregated; trace consolidated pieces display both matrix and grain supported pieces with volcanic ash- tuffaceous clay filling intergrain space; trace "clean- looking" grain supported sandstone with weak calcite and /or silica cementation; more homogeneous overall appearance of all sand characteristics after 5720'; apparent thicker more massive bedding; composition is sublithic arenite to lithic arenite with major decrease in percentage lithics; note that thin "caps" of thick sand section are borderline lithic quartz arenite; note greater overall contrast of light and dark colored grains creates a faintly "olivish" salt and pepper appearance. Sand /Sandstone (5720'- 6200') = estimate 70 -85% quartz and volcanic glass, trace feldspar, tr -10% various types of cryptosilica (chalcedony, chert) and non - differentiated silica (especially very pale orangish brown translucent with near opaque brown zones, agate ? ?), 10 -25% lithics and mafic minerals; note very significant decrease in phyllite rock fragments; dominant dark gray to grayish black lithics appear to be medium grade meta argillite rock fragments, followed by light green -dark green to grayish green to variegated green low grade meta greenstone rock fragments (and associated minerals, then minor phyllite fragments and minor multi -color multi- source group of diverse lithics; identified minerals are black augite, black -brown biotite, green chlorite, white muscovite and silvery black magnetite; note slightly goldish, bronzish colored mica may be phlogopite; most minerals are not identified, but well distributed persistent trace amounts of distinctive minerals (and rocks) that include: greenish yellow epidote, yellow • citrine, rose quartz, clear zircon, red jasper, pale "off- white" quartzite, greenish blue variation fluorite, rare vari- colored amber, mossy quartz and dark yellowish brown colored lithic calcareous tuff; 75 -80% of quartz is colorless to very pale gray to other very pale colors and translucent; 20 -25% of quartz and nearly 100% of volcanic glass is colorless and transparent; local clastic coal. Coal (5400'- 6400') = black to brownish black; smooth to very dense matte texture; dull to resinous to minor vitreous lustre; irregular to platy to spotty conchoidal and birdeye fracture; low grade lignite to subbituminous; most coal appears to have lamination layers of different coal grades; often present as particle in sandstone, and as micro -thin layers and particles in claystone; abundant visible outgassing. Sand /Sandstone/Tuffaceous Sandstone (6320'- 6440') = light gray with individual grains dominantly clear to translucent quartz and volcanic glass, light gray to light translucent gray, trace white, black, light bluish green and dark bluish green; very fine lower to trace coarse lower, dominantly fine upper to medium lower; angular to subangular; moderately well to well sorted; friable; very loosely grain supported with light grayish white, yellowish gray and light bluish gray ashy tuff supporting matrix; very soft; pulverulent; very calcareous to non calcareous; abundant visible glass shards; trace thin coals. Tuffaceous Claystone/Tuffaceous Siltstone/Volcanic Ash (6400'- 6540') = medium light gray to light brownish gray to very light gray with light brown secondary hues; very soft; sticky at times; fragile to pulverulent; irregular, shapeless to trace firm pieces with pdc bit metamorphism; dull, earthy to sparkly luster from strong ash content; silty to clayey to slightly gritty texture; slight to moderately soluble; slightly expansive when hydrated poor to fair cohesiveness; fair adhesiveness; abundant glass shards in volcanic ash; ash also acts as a supporting matrix for sands; trace thin coal beds. Coal (6460'- 6600') = black with dark brown secondary hues; firm to hard; brittle at times; platy to blocky; splintery to flaky; planar fracture dominant with scattered conchoidal and birdeye fracture; earthy to resinous luster; smooth to slightly gritty texture; none to trace visible outgassing bubbles present; coal • present in thin beds. El EPOCH 10 M MARATHON OIL COMPANY SD6 Sand /Sandstone/Tuffaceous Sandstone (6520'- 6660') = light gray with individual grains dominantly clear to translucent quartz and volcanic glass, light gray to light translucent gray, trace white, black, light bluish green and dark bluish green; very fine lower to trace coarse lower, dominantly fine upper to medium lower; angular to subangular; moderately well to well sorted; friable; very loosely grain supported with light grayish white, yellowish gray and light bluish gray ashy tuff supporting matrix; very soft; pulverulent; very calcareous to non calcareous; abundant visible glass shards; trace thin coals. Tuffaceous Claystone/Tuffaceous Siltstone /Ashy Tuff (6600'- 6737') = medium light gray to light brownish gray to very light gray with light brown secondary hues; very soft; sticky at times; fragile to pulverulent; irregular, shapeless to trace firmer pieces with pdc bit metamorphism; earthy to sparkly luster from strong ashy content; silty to clayey to slightly gritty texture; slight to moderately soluble; slightly expansive when hydrated; poor to fair cohesiveness fair adhesiveness; abundant glass shards in volcanic ash; local sandstones have ash as the dominant intergrain support material. 3.1. SAMPLING PROGRAM AND DISTRIBUTION SD6 Set Type and Purpose Interval Frequency Distribution Marathon Oil Company c/o C & M Storage, Inc. 3311 S U.S. Highway 77 A Washed and Dried 2020' — 6737' 20' Schulenburg, TX 78956 Attn: Dave Martens (713) 296 3302 BOX INTERVALS: 2020'- 3100', 3100'- 4340', 4340' — 5620', 5620' — 6737' (4 Boxes Total) • [I EPOCH 11 "" MARATHON OIL COMPANY SD6 4. DRILLING DATA • 4.1. DAILY ACTIVITY SUMMARY 11/01/2008: Note several loads from Kenai Gas Field Pad 34 -31, including the directional drillers trailer and M -I trailer have been moved to the Susan Dionne locatlion before final wellhead reinstallation is performed for the KU 24 -6RD Workover. Begin partial rig down operations and preparation for moving various smaller rig modules. 11/02/2008: Continue rig down operations on the Kenai Gas Field Pad 34 -31 and prep for moving to the the Susan Dionne Pad. Lay down torque tube, T -bar, anchor post and torque tube slider. Rig up to lay down, and then rig down BOP conex stairs and beaver slide. Scope down derrick and secure lines and hoses. Start crane operations. Crane down flowline stairs, chokehouse, doghouse, wind walls, flowline and gray iron. Pump off remaining fuel and remove fuel tank. Lay mast down on carrier. Pull and secure all wires as rig down proceeds. Move carrier off mud boat. Move mud boat off well center. Move sub -base from wellhead, scope down derrick and make road ready. Continue loading trailers for move. Wait for daylight to continue moving. Prep camp for move. Finish all remaining rig down operations on Pad 34 -31. Clean up pad and get last rig components ready to move to Susan Dionne. 11/03/2008: All moving activities begging at daybreak. Continue unloading trucks that have been arriving at the Susan Dionne location for the previous 2 days. Load and assemble camp trailers and then move to Susan Dionne location. Spot, set up and rig up all camp trailers. Load out generator, boiler house and water tank. Move mud pumps, shop and parts house. Continue moving, spotting and setting up all rig major and minor rig modules and accessory components as they arrive at the Susan Dionne Pad. Move sub -base over Susan Dionne 6 conductor and scope up. Move mud boat onto well center. Move carrier onto mud boat. Spot and set Pits and Pumps modules. Spot and set up parts, shop and mechanics houses. Spot and set up generator, boiler house and water tank. Start crane operations. Crane up gray • iron, doghouse, flowline, flowline stairs and landing, chokehouse and v -door wind walls. Begin pulling all wires into place. Install panic line. Set BOP conex in place. Raise mast. Crane up back landing and carrier side wind walls. 11/04/2008: Continue rig up operations at SD6. Set trip tank. Scope up derrick. Secure guide lines. Rig up catwalk, beaver slide and stairs on top of conex. Rig up hydraulic lines. Make up lower stand pipe and cement lines. Rig up and make up choke lines. Rig up Geronimo line. Install cylinder socks. Rig up geolograph. Rig up stand pipe manifold, fill -up lines, kill lines, splash guards, brake handle, driller's console, dresser sleaves and pop -off lines. Set down matting boards and prep for spotting #3 pump module. Set #3 mud pump module in place and make up all connections to rig. Draw up and secure carrier tarps. Change out Teflon torque bushings on Topdrive. Rig up shock hoses, poor boy, u -tube, derrick board windwalls and accumulator lines. Install cellar grating. Tighten brake blocks. Set cuttings tank in place. Spot and set Hanson tank. Set up auxiliary generator for pump #3. Set stack in gray iron. Spot and set in place Baker Inteq and Epoch units. Craig Silva arrives at the Susan Dionne 6 location, spots EPOCH logging unit ML006 and begins rigging up EPOCH's external camp workstations, power to Unit 6, the Gaitronics communications, the Rigwatch 8.7 system, the Starband Satellite System, the wireless network to camp, the unit's computers and equipment, the analog outputs and the gas system. S EPOCH 12 AML MARATHON OIL COMPANY SD6 11/05/2008: Continue rig up operations at SD6. Install torque tube and tighten turnbuckles. Pick up Topdrive. Unhang blocks and check crown -o- matic. Begin mixing spud mud. Nipple up riser, annular preventer, diverter stack, knife valve and diverter line. Test diverter system. Set wear ring. Attach kill line to annular valve. Install trip tank fill -up line. Install and chain down mousehole. Hang pipe spinner. Pick up tongs, bails and elevators. Spot pipe racks. Function test diverter, and then follow with full system test. Begin mixing spud mud. Build containment barriers around rig. Set in place BJ cementing unit. Off load and spot last matting boards at reserve location. Level up pipe racks and begin loading with 5" drill pipe off of truck flatbeds. Finish mixing spud mud. Craig Silva finishes rigging up all final items, calibrates the gas system, initializes the new well for Rigwatch and DML and organizes Unit #6 before mudlogging operations commence. Steve Forrest arrives on location and aims the Starband Satellite dish. 11/06/2008: Finish general rig -up operations. Performing rig audit. Troubleshoot and fix sticking problem with #2 carrier throttle. Pick up, make up, stand back in derrick and strap 42 joints (21 stands) of 5" drill pipe. Cull bad drill pipe. Pick up, make up, stand back in derrick and strap 21 joints of 5" HWDP plus jars (11stands). Pick up and make up lowermost section of directional assembly (bit, motor, NM stabilizer, MWD, crossover, NM pony flex collar). Run in hole and tag fill at 74'. Break circulation. Drill out and clean out to base of conductor at 101'. Drill ahead and Spud Well. Drill from 101' to 109'. Flowline starting to plug off. Cease drilling and pick up off bottom. Pump through flowline at variable rates to clear. Drill from 109' to 112'. Flowline plugged off. Cease drilling, shut down pumps and pick up off bottom. Clean out flowline and flowline adaptor. Remove Epoch flow sensor to open slot for using water hoses. Kick on pumps. Flowline fills up rapidly with cuttings before drilling ahead. Continue to clean out flowine while unloading hole. Circulate hole clean. Drill from 112' to 129'. Flowline again plugs off. Remove flowline extension. Insert 2" line into flowline, suck out cuttings with vac truck and then wash out. Repeat process several times until flowline remains clean. Put flowline extension back together. Replace rosemount throttle control. Drill from 129' to 131'. Cease drilling while troubleshooting and fixing fuel pump problem • with carrier. Drill ahead from 131' picking up and making up NM flex collars, crossovers, shock sub and first stand of HWDP out of derrick. Drill from 131' to 224' (rotating to 194' and sliding to 224'. James Foradas and Tollef Winslow arrive on location to start normal logging tours. 11/07/2008: Drill (rotating and sliding) from 224' to 1442'. Prep 9 5/8" casing while drilling ahead. 11/08/2008: Drill (rotating and sliding) from 1442' to 1666'. Detect leak at base of stand pipe. Cease drilling and replace washed out gasket in standpipe union. Reciprocate pipe while work is in progress. Resume drilling after gasket replacement. Drill (rotating and sliding) from 1666' to 2031' (surface casing point). Take final survey. Circulate bottoms up and continue to circulate, clean and condition well (while reciprocating pipe and rotating at 65rpm). Pull out of hole (SLM with no correction) from 2031' to top of directional tools at 303'. Clear and clean rig floor. Pump up weight indicator. Run back in hole from 303' to 1981'. Wash down from 1981' to bottom at 2031' with no fill. Begin circulating bottoms up. Start pumping around small pill of nut plug to determine washout volume. Record 72 units of wiper gas. Nut plug returns indicate hole is near gauge. Circulate, clean and condition hole. Pull out of hole from 2031' to 843'. Pull and stand back HWDP and jars to 303'. Pull, break and lay down directional tools. Grade bit. Clear and clean rig floor. Li EPOCH 13 " MARATHON OIL COMPANY SD6 11/09/2008: Blow down mud lines. Remove drill pipe elevators and short bails. Install long bails and pick- up sling -line. Install casing elevators. Move breakout tongs to driller's side and install correct tong head. Rig up Weatherford casing tongs and tall snub post. Remove rotary bushings. Rig up casing spider slips. Rig up and function stabbing board. Make up EZ -turn valve onto casing swage (to act as a safety valve), function test and record in IADC. Pick up centralizers and lock rings and stage on rig floor. Tie one (red) tugger line back in derrick for picking up pipe, and the second (blue) tugger line back for hanging casing tongs. Hold pre job meeting with all hands on procedures and safety for running surface casing string. Inspect rig -up. Pick up shoe joint. Run in hole with 9 5/8" casing as per Marathon program. Clean and Bakerlok casing threads on successive shoe track joints during make up. Pick up and make up shoe track (shoe joint, 1 spacer joint, float collar, "float joint') and run in hole to 121'. Circulate casing volume through shoe track and check float equipment. Continue running 9 5/8" casing in hole as per Marathon. Attach centralizers as per tally and fill every joint on way in. Run casing from 121' to tight spot 1107'. Work casing down from 1107' to 1132'. Break circulation and wash casing down from 1132' to 1172'. Continue running 9 5/8" casing in hole as per Marathon program from 1172' to 2024'. Make up 8' pup joint. Rig up circulating swage and wash down to bottom at 2031'. Reciprocate pipe and circulate to condition mud for cement job. (Condition well at 93spm, 182gpm, 160- 250psi). Record 12 units of trip gas. Rig down stabbing board. Rig down and lay down casing spider slips and Weatherford casing tongs. Move and re -hang breakout tongs to off side and install correct tong head. Remove tall snub post and replace with short snub post. Build 20 bbl spacer of Mud Clean II preflush. Make up cementing head with top and bottom plugs pre - installed. Continue to circulate and condition mud prior to cement job. Hold pre - job meeting with BJ and all hands on procedures and safety for cement job. Install cementing head. Pump 20 bbls of Mud Clean II preflush with rig pumps. Switch to BJ pumping unit. Pump 4.8 bbls of water and pressure test cement lines to 1887psi. Bleed off pressure. Continue cement job as per Marathon. Open up bottom valve, drop first (bottom) plug and pump out with 0.6 bbls. Mix and pump 222.0 bbls of 12.0ppg cement slurry (490 sacks of Class G cement plus accelerator chemicals mixed with 120.46 bbls water to batch -up at 10.33 gal /sk and yield of 2.544 cu- ft/sk). Reciprocate pipe while pumping cement. Open top valve and close middle and bottom valve on circulating head. Attempt to drop second (top) plug, • but pin puller assembly would not retrace and plug failed to drop. Pull the plug dropping assembly from the cementing head. Block the pump out opening with a bull plug and manually insert the plug in the direct open line of the cementing head. Pump 5.9 bbls of water to kick the plug out. Switch over to rig pumps. (BJ flushes cementing lines and begins wash up while rig is displacing). Displace with 142.1 bbls of mud (and 148.0 bbls total displacement). Slow pump rate to bump plug. Bump plug (at 3109 strokes) with 1132psi total and 640psi over displacement pressure. Cement in place. Note 9 5/8" casing shoe set at 2030.50'. Bleed down pressure. Note 71 bbls of cement slurry returned to surface. Begin wait on cement. Flush down, blow down and rig down BJ cementing head and cement lines. Blow down Topdrive, mud lines and mud pumps. Nipple down knife valve and diverter line. Nipple down and hot bolt diverter stack. Begin draining and cleaning pits. Begin heating the mix water for the Flo -Pro mud system. Clean cellar. Pick up all tools and put in proper places. Clean rig floor. 11/10/2008: Remove pick up sling line. Make rough cut on 9 5/8" casing and lay down stub section. Pick up stackwasher and thoroughly wash and flush diverter stack inside and out to remove residual cement. Finish nippling down the last components of the diverter system. Move the diverter stack out of the cellar and mount on stand. Remove and load off 21 1/4" sliplock starter head. Cut 20" conductor. Make final cut on 9 5/8" casing and then dress out. Remove casing elevators and long bails and install short bails and drill pipe elevators. Install 9 5/8" sliplock connection by 11" 5M flanged multibowl wellhead. Test wellhead to 2400psi for 10 minutes. Remove casing pack -off. Begin nipple up of 13 5/8" 5M BOPE. Set spool and HCR on stack. Set stack and continue nipple up of 13 5/8" 5M BOPE. Begin loading and strapping 5" drill pipe for next hole section on pipe racks. Finish cleaning pits and begin mixing new Flo -Pro mud. Service Topdrive and carrier. Prepare to test BOPE. Pull wear ring. Set test plug. Rig up testing equipment. Test all BOPE to 250psi Low / 2000psi High for 10 minutes (annular, upper pipe rams, upper topdrive, check valve, annular, dart valve, floor valve, lower topdrive, outside kill, inside kill, HCR, manual choke, lower pipe rams, blind rams, CMVs 1 -12). Perform accumulator drawdown test. Test all gas alarms. Rig down test equipment. Pull test plug. Install wear ring. Run in lock downs. Rig up test equipment. Prep to test casing. • E I EPOCH 14 "M MARATHON OIL COMPANY SD6 11/11/2008: Test 13 3/8" casing to 1500psi for 30 minutes. Rig down test equipment. Make up bit and bit • sub to first stand of HWDP. Run in hole with HWDP to 663'. Pick up, make up and run in hole 40 joints (1267') of pre- strapped 5" drill pipe off the pipe racks to 1930'. Continue running in hole with drill pipe out of the derrick, and tag float collar at 1945'. Drill out shoe track (float, cement, casing shoe, rathole) from 1945' to 2031'. Drill 20' of new hole from 2031' to 2051'. Circulate briefly over shakers and then overboard returns while displacing. Displace old 9.3ppg spud mud with new 9.0ppg Flo -Pro NT mud system. Cease pumping and perform Formation Integrity Test to 15.0ppg (490psi, 1578'tvd, 9.0ppg). Pump dry job. Check for flow. Pull and stand back 22 stands of 5" drill pipe out of hole from 2051' to top of HWDP. Pick up, make up and run in hole 40 joints (1268') of pre- strapped 5" drill pipe off the pipe racks. Pull out of hole standing back 20 stands of 5" drill pipe. Pick up, make up and run in hole 26 joints (824') of pre - strapped 5" drill pipe off the pipe racks. Pull out of hole standing back 13 stands of 5" drill pipe. Continue pulling out of hole standing back 5" HWDP and jars. Break and lay down bit and bit sub. Grade bit. Clear and clean rig floor. Pick up, install and nipple up Baker's APBA manifold for generating and receiving AUTOTRAK mud pulse signals. Lay out BHA on catwalk. Pick up, make up and run in hole AUTOTRAK directional tools (crossover, 3 CSNMDP flex collars, NM stabilizer, NM float sub, NM filter sub, OnTrak MWD collar, Autotrak Xtreme rotating collar, bit) to 178'. Link up and function check MWD tool on way in. Continue running in hole with 5" HWDP to 838'. Check lock -outs on all 3 rig pumps. Check grabber interlock. Circulate to check the pulse output performance and down link capability of the Baker manifold. Blow down mud lines. Continue running in hole with pre- strapped 5" drill pipe off the pipe racks. Pick up, make up and run in hole 38 joints (1141') of 5" drill pipe to 1980'. Wash in hole, continuing to pick up and make up single joints of 5" drill pipe, from 1980' to bottom at 2051' (with no fill). Drill from 2051' to 2060'. 11/12/2008: Drill from 2060' to 3498'. 11/13/2008: After drilling to 3498', circulate bottoms up and continue to circulate hole clean. Pull out of hole from 3498' to 1978' (inside shoe) on wiper trip. Service rig and Topdrive. Run back in hole from 1978' to 3434'. Break circulation and wash down from 3434' to 3498' (with no fill). Initiate AUTOTRAK. Drill from • 3498' to 4716'. 11/14/2008: Drill from 4716' to 5084'. Circulate hole clean. Pull out of hole on wiper trip from 5084' to 3400'. Circulate out at 4147' and continue pulling out. Pull tight in 16 different spots total. Run back in hole from 3400' and tag bridge at 4740'. Pick up stand, break circulation, wash and ream from 4703' to 4766'. Clean up spot at 4740'. Continue running in hole from 4766' to 5020'. Wash down from 5020' to 5084' with no fill. Perform data downlink to AUTOTRAK tool. Drill from 5084' to 5839' 11/15/2008: Drill from 5839' to 6737'. Circulate bottoms up. Circulate, clean and condition well. Check for flow. Pull out of hole from 6737' to 4830' on wiper trip. Blow down AUTOTRAK surface manifold and hoses. Run back in hole from 4830' to 6730'. Wash down from 6730' to bottom at 6737' with no fill. Circulate bottoms up. Record 187 units of wiper gas. Continue to circulate, clean and condition well. Nipple down, rig down and lay down AUTOTRAK Bypass Actuator and 2" chicksan hardline. Pull out of hole from 6737' to 6478'. HI EPOCH 15 mM MARATHON OIL COMPANY SD6 11/16/2008: Break circulation and pump dry job. Continue pulling out of hole from 6478' (SLM) to top of 5" • HWDP at 838' (with no correction). Pull and stand back 21 joints 5" HWDP plus crossover and jars (//stands) to 178'. Break, lay down and load off directional tools (crossover, 3 NMCSDP flex joints, NM stabilizer, NM float sub, NM crossover, NM filter sub, MWD, AUTOTRAK, bit). Make up datalink and download recorded data from AUTOTRAK tool before laying down. Grade bit. Clear and clean rig floor. Hold pre job meeting on procedures and safety for handling Weatherford Logging Services' shuttle logging system. Prepare and stage logging tools on catwalk. Pick up and make up shuttle outer assembly (reamer, circulating sub, 4 joints 3 1/2" drill pipe, lower latch, upper latch, 1 joint 3 1/2" drill pipe, float valve, crossover sub). Pick up and make up inner string of WLS Quad -Combo logging tools (with inner latching spear). Install, seat and latch up logging assembly in 3 1/2" drill pipe. (Drift all tools with 2 1/2" Weatherford drift while making up and running in). Load neutron sources (before latching assembly and making up last joint of 3 1/2" drill pipe). Run shuttle logging assembly in hole on 5" HWDP (with crossover) to 782'. Perform staged pressure check (at 2bpm to 158psi, 4bpm to 360psi, 6bpm to 700psi). Pull corrosion ring from first stand of 5" drill pipe. Continue running shuttle logging assembly in hole on 5" drill pipe to 1922'. Perform staged pressure check (at 2bpm to 181 psi, 4bpm to 400psi, 6bpm to 725psi). Continue running shuttle in hole to 3950'. Perform staged pressure check (at 2bpm to 233psi, 4bpm to 467psi, 6bpm to 810psi). Continue running shuttle in hole to 6548'. Break circulation, fill pipe and wash down with shuttle from 6548' to 6675'. Circulate bottoms up (at 122spm, 238gpm, 923psi). Record 36 units of trip gas. Continue to circulate, clean and condition hole (for 2 complete circulations before logging pass). Finish circulating and pull back up (2 stands) to 6548'. Drop and pump down Messenger dart to engage assembly. Pressure up until the seating plug is sheared and inner string released. Push out and deploy shuttle logging assembly to 6651'. Check for flow. Pump dry job. Pull out of hole at controlled rate of 30' per minute logging up with Weatherford Logging Service Quad -Combo tools from 6651' to 1898'. Pull out of hole at normal rate from 1898' to top of shuttle assembly at 782'. 11/17/2008: Pull and stand back 5" HWDP to 183'. Break and lay down 3 1/2" drill pipe. Remove neutron sources. Break, lay down and load off WLS Quad -Combo tools. Break and load off running equipment (upper and lower latches, float valve, circulating sub, crossover sub, reamer). Clear and clean rig floor. Weatherford Wireline Services begins processing recorded Quad -Combo data. Lube and service rig , Topdrive, crown, blocks and carrier. Pick up and make up muleshoe to first stand of HWDP. Run in hole with 5" HWDP and 5" drill pipe to 2000'. Cut and slip drilling line (173'). Perform rig maintenance while waiting on Marathon geologist to determine MFT pick points. Change out hydraulic hose for elevators, adjust Topdrive compensator and grease mud manifold valves. Run in hole from 2000' to 6625'. Wash down from 6625' to 6737'. Circulate bottoms up. Record 21 units of trip gas. Continue to circulate, clean and condition hole. WWS finishes processing Quad -Combo data and and sends finished logs and files to Marathon geologist for final evaluation. Check for flow. Pull out of hole from 6737' to 5550'. Hold pre -job meeting with Weatherford Wireline Services' loggers on procedures and safety for handling wireline logging tools. Rig up Weatherford Wireline Services sheaves, safety valve, lubricator and other surface running equipment. Pick up, make up and run in hole with MFT logging assembly. Install pump down plug behind assembly on way in. Pump logging assembly down pipe while running with in adjusted tension on wireline. Pump tools out through muleshoe and into open hole. Cease pumping and continue running MFT assembly downhole on wirleline to first pressure point at 6034'. Log up with MFT tool taking pressure points from 6034' to 5800'. Rig needs to move pipe to prevent differential problems. Pull logging assembly all the way out to the surface.. Inspect clean logging tool. Set assembly down on catwalk. Move and work pipe while briefly circulating. Pick up and run MFT assembly (with pump down swab) back in hole. Begin pumping logging assembly down hole and become temporarily stuck inside 5" drill pipe at 1600'. • E I EPOCH 16 M MARATHON OIL COMPANY SD6 11/18/2008: Free MFT tool at 1600'. Pool out of hole with logging assembly and set down on catwalk. • Note that the plug set above the logging assembly to push the tools when being pumped down hole, was ripped and "blown out ", and removed from the wireline. Circulate drill pipe volume while working drill pipe. Pick up MFT logging assembly and run back in hole. Pump logging assembly down pipe while running with in adjusted tension on wireline. Pump tools out through muleshoe iand top open hole. Cease pumping and continue running MFT assembly downhole on wirleline to first pressure point at 6392'. Log up with MFT tool taking pressure points from 6392' to 5188'. Note two logging runs and 74 total tests (that included first trys, immediate retests or a retrys of first run points on the second run) yielded good usable data (and a net 100% success rate) for 51 different pressure points. Pull MFT logging assembly out of hole and load off on catwalk. Rig down Weatherford Wireline Services sheaves, safety valve, lubricator and other surface running equipment. Pull out of hole with 5" drill pipe and 5" HWDP. Break and lay down mule shoe. Make up bit and bit sub to first stand of 5" HWDP. Run in hole with 5" HWDP. 11/19/2008: Continue running in hole with 5" HWDP and 5" drill pipe on clean out run. Run in hole to 6682'. Wash down from 6682' to 6737' (with no fill). Circulate bottoms up. Record 73 units of trip gas. Continue to circulate, clean and condition hole. Check for flow. Pull! out of hole from 6737' to 4845' standing back 5" drill pipe in derrick. Rig up for laying down drill pipe. Continue pulling out the hole laying down 5" drill pipe from 4845' to 663'. Pull out of hole laying down 5" HWDP. Break and lay down bit and bit sub. Load off all tools and subs no longer needed for drilling operations. Clear and clean rig floor. Lube rig and Topdrive. Pull wear bushing. Prepare to test pipe rams. Set test joint of 4 1/2" tubing. Rig up testing equipment. Test pipe rams to 250psi Low / 2500psi High for 10 minutes. Rig down testing equipment. Pull test joint. Set wear bushing. Blow down choke lines. Prep and rig up to run 4 1/2" liner. Rig down pipe spinner. Remove elevators. Change out from short bails to long bails. Install casing elevators. Rig up sling line. Rig up cementing line and circulating swage. Move breakout tongs to driller's side and install correct tong head. Rig up Weatherford casing tongs and tall snub post. Make up EZ -turn valve onto casing swage (to act as a safety valve), function test and record in IADC. Pick up centralizers and lock rings and stage on rig floor after arrival on location. Tie one tugger line back in derrick for picking • up pipe, and the second tugger line back for hanging casing tongs. Inspect rig -up. Hold pre -job meeting with Weatherford on procedures and safety for running production liner. Run in hole with 4 1/2" liner as per Marathon program. Pick up, make up and run in shoe track (float shoe, 2 liner joints, float collar, liner joint, landing collar, liner joint) to 172'. Install stop collars and centralizers as directed. Check float equipment. Continue running 4 1/2" liner in hole. Attach centralizers as per tally and fill on way in. Run casing from 172' to 1988' (just inside shoe). Circulate liner volume (at 99spm, 194gpm, 220psi). Record 1 unit of gas. Continue running 4 1/2" liner from 1988' (to 2676'). • El EPOCH 17 "' MARATHON OIL COMPANY SD6 11/20/2008: Continue running 4 1/2" liner from 2676' to 3679'. Circulate bottoms up. Record 5 units • maximum gas. Continue running 4 1/2" liner from 3679' to 4884'. Circulate bottoms up. Record 13 units maximum gas. Load off unused centralizers and lock rings off rig floor. Remove casing tongs. Re -rig tugger lines for picking up drill pipe. Remove EZ -turn valve. Rig down Weatherford casing tongs and remove tall snub post. Move breakout tongs to driller's off -side and install correct tong head. Remove pick -up sling line. Replace long bails with short bails. Remove casing elevators and install drill pipe elevators. Begin mixing brine for later displacement of cement. Pick up and make up Baker Oil Tool 7" by 9 5/8" liner hanger assembly (pup joint, crossover, PBR, crossover, Flex -Lock hanger, RS pack -off, HR setting sleeve). Fill liner tie -back with PAL mix up to top of liner tie -back sleeve. Set dust cover to top of liner sleeve and lock down. Run hanger assembly in hole to 4922'. Break circulation and check flow. Continue running 4 1/2" liner in hole (with 29 joints of 5" drill pipe) from 4922' to 6674'. Wash down from 6674' to bottom at 6737' (with no fill). Circulate, reciprocate (17' up /dn) and rotate pipe (at 395gpm, 485psi). Circulate bottoms up and record 16 units of trip gas. Stop circulating. Pick up, rig up and make up BJ cementing head and rig floor cement lines. Continue to circulate and condition hole with rig pumps prior to cementing. Hold pre job meeting (while circulating) with BJ and all hands on procedures and safety for cementing 4 1/2" liner. Stop circulating. Gas down to 2 units. Switch from rig pumps to BJ pumping unit. Pump 2.2 bbls of water into cementing lines and pressure test to 3847psi. Batch mix and pump 40 bbls of 10.0ppg Sealbond sweep (using 36.95 bbls of mix water), followed with 105 bbls of 12.5ppg lead cement slurry (blended with 270 sacks Class G cement to 76.416 bbls water and accelerator chemicals at 11.887 gal /sack and a yield of 2.100 cuft/sack) and then 196 bbls of 15.8ppg tail cement slurry (blended with 970 sacks Class G cement to 114.53 bbls water and accelerator chemicals at 4.959 gal /sack and a yield of 1.183 cuft/sack). Note rotating and reciprocating liner while pumping cement. Stop reciprocating liner after 215 total bbls of cement is pumped due to high torque. Continue to rotate liner unitl last 10 bbls of cement is displaced. Close cementing head after tail slurry is pumped, open wash up tee to slop tank and pump 5.6 bbls of water to wash lines and pump. Open head back up. Drop 4 1/2" liner dart. Start pumping brine to displace and stop after only 7.9 bbls when dart did not deploy. Open head, manually drop second dart in drill pipe and resume displacing with brine. (Note that • the first dart later released and deployed 31.1 bbls behind the second dart). Displace cement with 76.0 bbls of 3% KCL brine and 29.0 bbls mud (105 bbls total displacement). Note pumping was stopped 8 bbls short of total displacement to factor fluid in front of second dart. Plug did not bump. Bleed off and check floats. Floats holding. (Pressure reduction below plug apparently enough for plug to seat). Cement in place. Pressure up. Set liner hanger by surging pressure. Set 43K down weight on hanger and put 1/2 turn in drill pipe to release HR tool. Turn over to rig. Pressure drill pipe to 500psi and then pull out running tool when pressure reaches 650psi. Circulate out excess cement (20 -25 bbls) to surface and continue to circulate hole clean. Lay down Topdrive cemeting head. Blow down lines. Begin cleaning pits and hauling off surface mud. Pull out of hole with 5" drill pipe. Break and lay down running tool. Flush cement from stack. Service rig and change out grabber dies. Pick up and break down cementing head and then lay back down. Pick up polish mill for 7 1/2" tie back sleeve. Run in hole to top of tie -back at 1814'. Polish tie- back sleeve as per Baker toolhand. Pull out of hole with polish mill. Lay down mill. Pick up and make up 7 1/2 "OD tie -back seal stem and ZXP packer. Run packer assembly in hole on 5" drill pipe (to 1238'). • HI EPOCH 18 "M MARATHON OIL COMPANY SD6 11/21/2008: Continue running ZXP packer assembly in hole (from 1238') to 1685'. Wait on cement. Clean 411/ pipe rack. Rack and prep 4 1/2" tubing. Band mud products. Build new batch of 3% KCL brine. Continue running ZXP packer assembly in hole from 1685' to 1814'. Run the 7 1/2 "OD tie back seal stem and ZXP packer into the top of the Flexlock hanger assembly using a HR running tool with a hydraulic pusher tool. Space out rig up BJ. Drop a 1 7/16" ball and let it migrate close to the ball seat. Use rig pump to pump onto the ball seat. Stab into the stem /running sleeve on the Flexlock hanger. Line up BJ to pressure up on the hydraulic tool. Pressure up to 2000psi and hold for 5 minutes, then pressure up to 2400psi to set a minimum overweight on the ZXP packer, then pressure up to 3500psi (generating a set down weight > 60K) to set the packer and continue pressuring up to 4825psi to blow the ball seat. Test liner and casing (annulus) to 1500psi for 10 minutes. Pull out of the hole from 1793' laying down 5" drill pipe (56 joints). Make service breaks on the Baker running /packer setting tools and lay down. Inspect and clean running tools. Make up wear bushing puller. Pull wear bushing. Rig down and load off pipe spinner and tongs. Clear rig floor of all remaining drill pipe handling tools. Clean rig floor. Set multi -bowl 11" by 7" hanger bushing /pack -off and test to 5000psi for 10 minutes. Make a gauge run with the 4 1/2" tubing hanger. Change bails and elevators. Pick up Weatherford hydraulic tongs, power slips and tubing handling equipment ad rig up to run 4 1/2" tubing. Hold pre job meeting with all hands on procedures and safety for running tubing. Pick up and make up Baker 4 1/2" locater seal assembly to first joint of 4 1/2" tubing. Run first 8 joints 4 1/2" tubing in hole as per Marathon program to 339'. Rig up Pollard Oilfield Service to do banding of control line. Hang sheave for running chemical injection line. Make up injection nipple and attach 1/4" stainless steel chemical line. Test injection line to 2000psi. Continue running in 4 1/2" tubing (44 joints total) from 339' to 1801', putting 2 steel bands per joint to secure injection line. Tag top of liner. Rig down Pollard banding equipment. Record pickup and slackoff weights. Stab into seal assembly and continue into monobore. Pressure up backside to 200psi to insure seals are engaged and then land locator. Space out for tubing hanger. Rig up circulating lines. Rig down and load off Weatherford hydraulic tongs, power slips and remaining tubing handling equipment. Cut and tie off chemical injection line. Load remaining equipment off of rig floor. Prepare to change over mud. Clean pill pit. Build Hi -Vis sweep. Pump 30 bbl H -Vis sweep, and then displace well with 94 bbls of 3% KCL brine and 40 bbls of inhibited KCL. • Land tubing hanger. Test hanger body seals to 5000psi for 10 minutes. Test down 4 1/2" liner string (to contact seal at 9 5/8" casing) to 1500psi for 30 minutes. Test annulus to 1500psi for 10 minutes. Lay down and load off landing joint. Set Blowout Prevention Valve. Rig down and lay down sheave for running chemical injection line and spool back unused line. Clear rig floor. Load off all remaining handling equipment, subs, valves, slips and crossovers. 11/22/2008: Flush all surface equipment (mud pumps 1 -2 -3, choke manifold, stack, choke and kill lines, cementing lines, Topdrive, poorboy, stand pipe manifold and lines to pits). Clean pits and sump. Offload all remaining fluid in the pits to Vac truck. Rig down drip pan, turnbuckles, fill -up line, trip tank line, flowline, and choke and kill lines. Nipple down check and kill valves, spacer spool, BOP stack, and DSA. Load off BOP stack. Clean and inspect gas buster. Prepare and install the tree with Vetco -Gray. Remove Blowout Prevention Valve. Install 2 -way check valve. Test void to 5000psi for 10 minutes. Test tree to 5000psi for 10 minutes. Pull 2 -way check valve and reinstall BPV. Begin rig down of all Glacier No.1 rig and camp components and commence transporting to the Beaver Creek Field location or to various service provider locations. Note that major service /maintenance and overhaul /upgrade operations are to take place at Beaver Creek before the start of next drilling season. Craig Silva rigs down EPOCH's Rigwatch 8.7 system, the gas system, the Unit 6 computers and equipment, the external camp workstations, the wireless network to camp, the Starband Satellite system, the Gaitronics communications and unit power. Unit #6 is organized and secured for transport back to Anchorage. Glacier No.1 will be performing major maintenance until the start of the 2009 drilling season. 11/23/2008: Continue rig down of all Glacier No.1 rig and camp components at Susan Dionne and subsequent transport to either the Beaver Creek Field location or to various service provider locations. • E EPOCH 19 • M O S "'""°'"°" MARATHON OIL COMPANY SD6 4.2. SURVEY RECORD Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section Azimuth (+) N/S ( -) _ ( +) ENV ( -) (ft) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft ) (deg) (deg /100ft) 0 0.00 0.00 0 0 0 0 0 0 0 135 0.50 205.60 135.00 0.40 -0.53 -0.25 0.59 205.60 0.37 183 1.05 229.52 182.99 0.94 -1.01 -0.68 1.21 214.05 1.31 244 4.02 256.71 243.93 _ 3.59 -1.86 -3.19 3.69 239.72 5.12 305 8.26 259.98 304.57 10.08 -3.11 -9.59 10.08 252.00 6.97 363 10.06 259.21 361.82 19.25 -4.79 -18.66 19.27 255.61 3.11 424 11.27 259.96 421.77 30.46 -6.82 -29.77 30.54 257.09 2.00 483 14.52 259.72 479.27 43.53 -9.15 -42.73 43.69 257.91 5.51 544 17.53 260.13 537.90 60.25 -12.09 -59.30 60.52 258.48 4.94 604 20.66 259.24 594.59 79.74 -15.62 -78.61 80.15 258.76 5.24 665 23.59 258.79 651.09 102.59 -20.00 - 101.16 103.12 258.82 4.81 725 25.53 258.82 705.66 127.40 -24.84 - 125.62 128.06 258.81 3.23 784 26.47 257.57 758.69 153.16 -30.14 - 150.94 153.92 258.71 1.84 847 27.71 257.84 814.77 181.75 -36.24 - 178.97 182.60 258.55 1.98 911 30.33 256.82 870.73 212.70 -43.06 - 209.25 213.64 258.37 4.17 974 32.46 255.76 924.51 245.47 -50.85 - 241.13 246.44 258.09 3.49 1037 34.17 253.79 977.16 280.05 -59.95 - 274.51 280.98 257.68 3.21 1101 35.99 251.72 1029.53 316.82 -70.87 - 309.63 317.64 257.11 3.40 1164 37.89 250.98 1079.88 354.67 -82.98 - 345.50 355.32 256.50 3.10 1228 39.08 247.77 1129.98 394.40 -97.02 - 382.76 394.86 255.78 3.63 1291 40.60 244.55 1178.36 434.46 - 113.34 - 419.66 434.69 254.89 4.07 1355 42.91 244.30 1226.10 476.60 - 131.74 - 458.10 476.66 253.96 3.62 1419 45.46 244.90 1271.99 520.72 - 150.87 - 498.39 520.72 253.16 4.04 1482 48.28 246.11 1315.06 566.30 - 169.92 - 540.23 566.32 252.54 4.69 1545 51.28 246.37 1355.73 _ 614.07 - 189.29 - 584.25 614.15 252.05 4.77 1609 54.47 246.62 1394.36 664.76 - 209.64 - 631.04 664.95 251.62 4.99 1672 58.19 247.92 1429.28 716.92 - 229.88 - 679.40 717.23 251.31 6.15 E I EPOCH 20 0 • • (M MARATHON OIL COMPANY SD6 Vertical Rectangular Rectangular Closure Measured Inclination Azimuth TVD Section Coordinate Coordinate Closure Azimuth DLS Depth ( +) N/S ( -) ( +) ENV ( -) (ft) (deg) (deg) (ft ) (ft ) (ft ) (ft) (ft ) (deg) ( deg /100ft) 1735 61.28 249.34 1461.03 771.16 - 249.70 - 730.06 771.58 251.12 5.28 1799 63.63 251.41 1490.63 827.84 - 268.74 - 783.51 828.32 251.07 4.66 1861 65.65 252.84 1517.18 883.86 - 285.93 - 836.83 884.33 251.14 3.87 1924 68.12 254.24 1541.91 941.79 - 302.34 - 892.39 942.22 251.28 4.42 1970 69.77 254.46 1558.44 984.70 - 313.92 - 933.73 985.09 251.42 3.61 2052 68.16 254.96 1587.87 1061.20 - 334.11 - 1007.55 1061.50 251.65 2.04 2115 68.73 255.13 1611.02 1119.76 - 349.23 - 1064.16 1120.00 251.83 0.94 2179 68.69 255.55 1634.25 1179.34 - 364.32 - 1121.85 1179.52 252.01 0.61 2242 68.70 255.90 1657.14 1237.97 - 378.79 - 1178.73 1238.10 252.18 0.52 2307 68.88 254.62 1680.66 1298.52 - 394.21 - 1237.33 1298.61 252.33 1.86 2369 68.94 255.23 1702.97 1356.33 - 409.26 - 1293.19 1356.40 252.44 0.92 2432 68.95 255.35 1725.60 1415.08 - 424.18 - 1350.06 1415.13 252.56 0.18 2496 69.05 255.46 1748.54 1474.78 - 439.24 - 1407.88 1474.80 252.67 0.22 2558 68.81 253.81 1770.83 1532.61 - 454.57 - 1463.66 1532.62 252.75 2.51 2621 68.75 254.34 1793.63 1591.33 - 470.68 - 1520.14 1591.34 252.80 0.79 2687 68.81 253.68 1817.52 1652.84 - 487.63 - 1579.28 1652.85 252.84 0.94 2751 68.77 253.16 1840.68 1712.50 - 504.66 - 1636.46 1712.51 252.86 0.76 2814 68.77 252.13 1863.49 1771.23 - 522.17 - 1692.51 1771.23 252.85 1.52 2877 68.73 252.63 1886.32 1829.94 - 539.95 - 1748.48 1829.95 252.84 0.74 2941 68.74 252.04 1909.54 1889.58 _ - 558.04 - 1805.30 1889.59 252.82 0.86 3003 68.76 251.30 1932.01 1947.35 _ - 576.22 - 1860.16 1947.36 252.79 1.11 3066 68.77 252.22 1954.83 2006.05 - 594.60 - 1915.93 2006.07 252.76 1.36 3128 68.79 252.73 1977.27 2063.85 - 612.00 - 1971.04 2063.87 252.75 0.77 3192 68.81 251.92 2000.41 2123.51 - 630.12 - 2027.89 2123.53 252.74 1.18 3255 68.73 252.55 2023.22 2182.23 - 648.03 - 2083.82 2182.26 252.73 0.94 3318 68.78 251.88 2046.05 2240.94 - 665.97 - 2139.73 2240.97 252.71 0.99 3382 68.82 251.70 2069.20 2300.60 - 684.62 - 2196.41 2300.63 252.69 0.27 3445 68.92 252.50 2091.91 2359.35 - 702.68 - 2252.33 2359.39 252.67 1.20 3508 68.66 252.16 2114.70 2418.08 - 720.50 - 2308.29 2418.12 252.66 0.65 3572 68.77 252.07 2137.93 2477.71 - 738.82 - 2365.04 2477.76 252.65 0.22 El EPOCH 21 • M • • "'"""""'°" MARATHON OIL COMPANY SD6 Measured Vertical Rectangular Rectangular Closure Depth Inclination Azimuth TVD Section Coordinate Coordinate Closure Azimuth DLS ( +) N/S ( -) ( +) E/W ( -) (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft) (ft ) (deg) ( deg /100ft ) 3635 68.77 252.40 2160.75 2536.43 - 756.74 - 2420.97 2536.48 252.64 0.49 3698 68.84 252.91 2183.52 2595.16 - 774.25 - 2477.03 2595.22 252.64 0.76 3762 68.73 253.06 2206.68 2654.83 - 791.71 - 2534.08 2654.88 252.65 0.28 3825 68.05 253.13 2229.88 2713.40 _ - 808.74 - 2590.12 2713.45 252.66 1.08 3890 67.04 252.75 2254.71 2773.47 - 826.36 - 2647.55 2773.52 252.67 1.65 3953 64.58 253.66 2280.53 2830.93 _ - 842.97 - 2702.56 2830.98 252.68 4.12 4016 62.53 252.50 2308.58 2887.33 - 859.38 - 2756.53 2887.38 252.68 3.65 4080 60.27 252.58 2339.22 2943.52 - 876.24 - 2810.12 2943.57 252.68 3.53 4144 57.90 252.51 2372.09 2998.42 - 892.71 - 2862.50 2998.47 252.68 3.70 4207 55.28 252.52 2406.78 3051.00 - 908.51 - 2912.66 3051.06 252.68 4.16 4270 52.40 252.35 2443.95 3101.86 - 923.85 - 2961.14 3101.91 252.67 4.58 4334 49.53 252.03 2484.25 3151.56 - 939.05 - 3008.47 3151.62 252.66 4.50 4397 46.81 252.09 2526.26 3198.50 - 953.51 - 3053.13 3198.56 252.66 4.32 4460 44.47 252.29 2570.31 3243.53 - 967.29 - 3096.01 3243.59 252.65 3.72 4523 41.82 252.62 2616.27 3286.61 - 980.28 - 3137.08 3286.67 252.65 4.22 4586 39.31 253.41 2664.13 3327.57 - 992.25 - 3176.26 3327.64 252.65 4.07 4650 36.87 252.88 2714.49 3367.05 - 1003.69 - 3214.04 3367.11 252.66 3.85 4713 34.56 253.07 2765.64 3403.82 - 1014.46 - 3249.20 3403.89 252.66 3.67 4777 31.94 252.96 2819.16 3438.91 - 1024.71 - 3282.76 3438.97 252.66 4.09 4840 29.81 253.73 2873.23 3471.24 - 1033.98 - 3313.73 3471.30 252.67 3.44 4904 29.82 254.18 2928.76 3503.05 - 1042.78 - 3344.31 3503.11 252.68 0.35 4967 29.68 255.08 2983.45 3534.30 - 1051.06 - 3374.45 3534.36 252.70 0.74 5027 29.73 255.36 3035.57 3564.01 - 1058.65 - 3403.20 3564.06 252.72 0.25 5094 29.78 255.00 3093.74 3597.24 - 1067.16 - 3435.35 3597.28 252.74 0.28 5158 29.84 254.69 3149.27 3629.04 - 1075.47 - 3466.06 3629.07 252.76 0.26 5221 29.84 255.05 3203.91 3660.37 - 1083.65 - 3496.32 3660.40 252.78 0.28 5284 29.79 255.12 3258.58 3691.67 - 1091.72 - 3526.58 3691.70 252.80 0.10 5348 29.81 254.97 3314.11 3723.46 - 1099.92 - 3557.31 3723.48 252.82 0.12 5411 29.77 253.79 3368.79 3754.75 - 1108.35 - 3587.46 3754.77 252.83 0.93 El I EPOCH 22 • M � • • (""°') MARATHON OIL COMPANY SD6 Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section Azimuth ( +) N/S ( -) ( +) ENV ( -) (ft) (deg) (deg) (ft ) (ft) (ft) (ft) (ft) (deg) ( deg /100 ft) 5475 29.80 254.36 3424.33 3786.54 - 1117.07 - 3618.03 3786.55 252.84 0.44 5538 29.87 254.23 3478.98 3817.87 - 1125.56 - 3648.20 3817.88 252.85 0.15 5601 29.83 254.57 3533.63 3849.22 - 1133.99 - 3678.40 3849.23 252.87 0.28 5664 29.86 254.72 3588.27 3880.56 - 1142.29 - 3708.63 3880.57 252.88 0.13 5728 29.90 254.67 3643.76 3912.43 - 1150.71 - 3739.39 3912.44 252.90 0.07 5790 29.92 254.76 3697.50 3943.33 - 1158.86 - 3769.21 3943.34 252.91 0.08 5852 29.96 254.68 3751.23 3974.26 - 1167.01 - 3799.06 3974.26 252.92 0.09 5918 29.75 255.88 3808.47 4007.09 - 1175.36 - 3830.83 4007.09 252.94 0.96 5982 29.79 255.20 3864.03 4038.83 - 1183.30 - 3861.60 4038.83 252.96 0.53 6045 29.68 255.43 3918.73 4070.06 - 1191.22 - 3891.83 4070.06 252.98 0.25 6110 29.77 255.33 3975.18 4102.26 - 1199.35 - 3923.02 4102.26 253.00 0.16 6173 29.68 254.80 4029.89 4133.47 - 1207.41 - 3953.20 4133.47 253.02 0.44 6234 29.61 254.64 4082.90 4163.63 - 1215.36 - 3982.31 4163.63 253.03 0.17 6298 29.67 254.69 4138.53 4195.27 - 1223.73 - 4012.83 4195.27 253.04 0.10 6362 29.62 254.07 4194.15 4226.92 - 1232.25 - 4043.32 4226.92 253.05 0.49 6426 29.56 251.77 4249.81 4258.52 - 1241.53 - 4073.52 4258.52 253.05 1.78 6489 29.54 251.62 4304.61 4289.58 - 1251.29 - 4103.02 4289.58 253.04 0.12 6551 29.55 251.39 4358.55 4320.14 - 1260.99 - 4132.01 4320.14 253.03 0.18 6615 29.53 251.38 4414.23 4351.68 - 1271.06 - 4161.91 4351.68 253.02 0.03 6678 29.66 251.48 4469.01 4382.78 - 1280.97 - 4191.41 4382.78 253.01 0.22 *6737* 29.66 251.48 4520.28 4411.97 - 1290.24 - 4219.09 4411.97 253.00 0.00 *Projected* El EPOCH 23 • M • • • """"TM°" MARATHON OIL COMPANY SD6 4.3. MUD RECORD Contractor: MI Drilling Fluids Mud Types: Spud Mud 101' - 2031'; 6% KCI Flo -Pro 2031' - 6737' DATE MD / TVD MW VIS PV YP GELS FL FC SOL OIL /H20 SD MBT pH AIk CI- Ca+ 11/05/08 101 / 101 8.6 57 19 17 10/14/16 14.8 2 3.0 0/97 0.0 25.0 9.0 0.25 800 100 11/06/08 133 / 133 8.7 150 13 47 20/23/ 11/06/08 193 / 193 8.7 160 12 48 24/27/ 15.2 2 3.0 0/97 Tr 25.0 8.9 0.20 700 100 11/07/08 665 / 651 8.8 90 13 37 24/29/ 14.8 2 4.0 0/96 Tr 22.5 9.0 0.35 600 100 11/07/08 1350 / 1222 9.0 80 12 37 23/30/ 14.8 2 5.0 0/95 Tr 22.5 9.0 0.35 500 100 11/08/08 1674 / 1430 9.3 75 22 20 11/23/ 14.8 2 6.5 0/94 0.25 25.0 8.8 0.20 700 80 11/08/08 2031 / 1578 9.3 78 21 24 10/23/25 8.8 2 7.0 0/93 0.25 22.5 8.4 0.10 700 60 11/09/08 2031 / 1578 9.3 55 16 21 8/13/ 8.6 2 6.5 0/94 Tr 20.0 8.3 700 60 11/10/08 2031 / 1578 9.0 55 8 20 7/10/11 6.6 1 4.0 3/93 0 0 9.0 0.20 17000 100 11/11/08 2051 / 1587 9.0 54 10 18 8/10/11 6.8 1 4.5 2/94 Tr 8.5 0.20 20000 100 11/12/08 2612 / 1790 9.1 56 12 22 9/12/13 6.0 1 4.5 3/93 Tr 1.0 9.0 0.30 22000 120 11/12/08 3401 / 2076 9.2 59 15 25 11/14/15 5.6 1 5.5 3/92 Tr 3.0 9.2 0.35 21000 100 11/13/08 3925 / 2269 9.5 61 16 29 12/16/17 5.4 1 7.0 3/90 Tr 3.5 9.3 0.35 18000 100 11/13/08 4590 / 2667 9.5 58 16 27 12/15/16 5.3 1 7.0 3/90 Tr 4.5 9.3 0.35 17000 100 11/14/08 5590 / 3524 9.5 60 15 27 12/16/17 5.8 1 6.5 3/91 Tr 4.0 9.7 0.45 18000 80 11/14/08 5780 / 3689 9.6 61 16 26 12/16/17 5.6 1 7.0 3/90 Tr 4.5 9.8 0.45 19000 80 11/15/08 6420 / 4248 9.6 63 16 34 16/19/20 5.4 1 7.0 3/90 Tr 5.0 8.8 0.25 18000 80 11/15/08 6737/ 4520 9.6 57 16 22 10/15/16 5.2 1 7.0 3/90 Tr 6.0 9.7 0.45 22000 80 11/16/08 6737 / 4520 9.7 58 15 22 10/15/16 5.2 1 7.5 3/90 Tr 6.0 9.4 0.40 22000 80 11/17/08 6737 / 4520 9.8 58 15 21 10/16/20 4.2 1 9.0 3/88 Tr 7.5 10.0 0.25 20000 100 11/18/08 6737 / 4520 9.8 58 14 19 8/14/ 4.2 1 9.0 3/88 Tr 7.5 9.7 0.20 19500 80 11/19/08 6737 / 4520 9.8 59 14 19 8/14/ 4.2 1 9.0 3/88 Tr 7.5 9.5 0.20 19000 80 11/20/08 6737 / 4520 9.7 65 15 26 11/17/ 8.0 1 9.0 2/89 Tr 6.0 10.2 0.60 16000 440 11/21/08 6737 / 4520 8.6 28 1 1 KCL Brine 7.7 16000 E I EPOCH 24 • M • s 1 " ""TM°" MARATHON OIL COMPANY SD6 4.4. BIT RECORD BIT SIZE JETS/ AVE WOB PP NO. TYPE S/N TFA IN OUT FT HRS ROP Lo —Avg — Hi RPM Lo — Avg CONDITION — Hi 1 12.25 HCC 6044740 3x18 101 2031 1930 23.56 100.9 0.2 — 11.8 — 43 158 —1076 1- 2- WT- A- E- 1 -SS -TD MX -1 1 x12cj 35.0 —1618 2RR 8.5 HCC MXL-1 6054215 3x28 2031 2051 20 0.46 47.2 15.0 —18.2 — 68 289 — 297 — 1- 1- WT- A- E -1 -NO -BHA 18.8 300 3 8.5 HCC 506Z 7114298 6x13 2051 6737 4686 53.69 97.7 2.1 — 14.0 — 34 486 —1330 - 1- 1- BT- G- X- 1 -NO -TD 33.3 1728 2 8.5 HCC MXL -1 6054215 3x29 6737 6737 0 n/a n/a n/a n/a n/a 1 1 WT A E 1 NO BHA RR2 Clean out run only El EPOCH 25 DEPTH (FT) 0 0 O 0 01 0 0 0 W NJ 0 O 0 0 O O • O O O O O O co co O co O co O co cn 11/3/2008 - 4 ED F 11/4/2008 - 4 r- --- 0 11/5/2008 - 4 )3 0 C) 11/6/2008 - R Cn 11/7/2008 - 2 y 11/8/2008 - ‘4 11/9/2008 - • D D 11/10/2008 - • —I I-U 0 C 11/11/2008 - Z ^ O • �J _ 11 /1 2/2008 - O o 0 D o K "'11/ 13/2008 - m 0) > 7. ` Z y -< 11/14/2008 - o m 0 v x 11/15/2008 - 11/16/2008 - • 11/17/2008 - • 1 11/18/2008 - • 11/19/2008 - • 1 1 _1 w N 11/20/2008 - • N \ A I O I 11/21/2008 - • (IT 0 m N 11/22/2008 - • • a) 11/23/2008 - • • • (M ) MARATHON OIL COMPANY SD6 5. DAILY REPORTS El EPOCH 27 Marathon Oil Company EPOCH ill Ninilchikunit DAILY WELLSITE REPORT El Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 06, 2008 DEPTH 224 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 101 24 HOUR FOOTAGE 123 CASING INFORMATION 20" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 224 (Projected) 224.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1RR 12.25 HCC MXL -1 6044740 3x18 1x16cj 101 123 3.10 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 141.8 © 117 3.3 @ 112 72.2 88.3. FT /HR SURFACE TORQUE 2923 @ 149 0 @ 207 1937.6 755.2 AMPS WEIGHT ON BIT 9.8 @ 204 0.3 @ 145 3.6 80 KLBS ROTARY RPM 33 © 115 0 @ 135 31.1 30.0 RPM PUMP PRESSURE 611 @ 120 158 @ 135 433.0 421.5 PSI DRILLING MUD REPORT DEPTH 193 / 193 TVD MW 8.7 VIS 150 PV 12 YP 48 FL 15.2 Gels 24/27/ CL- 700 F. 2 SOL 3.0 SD Tr OIL 0/97 MBL 25.0 pH 8.9 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS ill GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 © 117 0 @ 112 0.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 7 © 196 4 © 112 5.4 CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 / 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Finish general rig -up operations. Performing rig audit. Troubleshoot and fix sticking problem with #2 carrier throttle. Pick up, make up, stand back in derrick and strap 42 joints (21 stands) of 5" drill pipe. Cull bad drill pipe. Pick up, make up, stand back in derrick and strap 21 joints of 5" HWDP plus jars (1 lstands). Pick up and make up lowermost section of directional assembly (bit, motor, NM stabilizer, MWD, crossover, NM pony flex collar). Run in hole and tag fill at 74'. Break circulation. Drill out and clean out to base of conductor at 101'. Drill ahead and Spud Well. Drill from DAILY 101' to 109'. Flowline starting to plug off. Cease drilling and pick up off bottom. Pump through flowline at variable rates to clear. Drill from 109' to ACTIVITY 112'. Flowline plugged off. Cease drilling, shut down pumps and pick up off bottom. Clean out flowline and flowline adaptor. Remove Epoch flow SUMMARY sensor to open slot for using water hoses. Kick on pumps. Flowline fills up rapidly with cuttings before drilling ahead. Continue to clean out flowine while unloading hole. Circulate hole clean. Drill from 112' to 129'. Flowline again plugs off. Remove flowline extension. Insert 2" line into flowline, suck out cuttings with vac truck and then wash out. Repeat process several times until flowline remains clean. Put flowline extension back together. Replace rosemount throttle control. Drill from 129' to 131'. Cease drilling while troubleshooting and fixing fuel pump problem with carrier. Drill ahead from 131' picking up and making up NM flex collars, crossovers, shock sub and first stand of HWDP out of derrick. Drill from 131' to 224' (rotating to 194' and sliding to 224'. EPOCH PERSONNEL ON BOARD 3 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva • Marathon Oil Company III NinilchikUnit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Mitch Bums DATE Nov 07, 2008 DEPTH 1442 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 224 24 HOUR FOOTAGE 1218 CASING INFORMATION 20" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 135 0.50 205.60 135.00 SURVEY DATA 424 11.27 259.96 421.77 784 26.47 257.57 758.69 1101 35.99 251.72 1029.53 1419 45.46 244.90 1271.99 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1RR 12.25 HCC MXL -1 6044740 3x18 1x16cj 101 1341 16.73 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.8 @ 1143 11.5 © 1357 100.9 97.06120 FT /HR SURFACE TORQUE 6211 © 1342 0 © Sliding 2155.5 755.21149 AMPS WEIGHT ON BIT 26.6 @ 1341 0.2 © 422 10.5 20.18117 KLBS ROTARY RPM 59 @ 1404 0 @ Sliding 42.9 0.00000 RPM PUMP PRESSURE 1457 @ 1264 320 @ 422 988.0 1214.93433 PSI DRILLING MUD REPORT DEPTH 1350 / 1222 TVD MW 9.0 VIS 80 PV 12 YP 37 FL 14.8 Gels 12/30/ CL- 500 FC 2 SOL 5.0 SD Tr OIL 0/95 MBL 22.5 pH 9.0 Ca+ 100 CCI • MWDSUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ 1143 0 @ 242 5.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 2723 © 1143 4 © 353 1148.4 CONNECTION GAS HIGH ETHANE (C -2) @ © AVG PROPANE (C -3) @ © CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 3 / 8 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill (rotating and sliding) from 224' to 1442'. Prep 9 5/8" casing while drilling ahead. EPOCH PERSONNEL ON BOARD 3 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva • Marathon Oil Company EPOCH III NinilchikUnit DAILY WELLSITE REPORT El Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 08, 2008 DEPTH 2031 PRESENT OPERATION Laying down bottom hole assembly at surface casing point TIME 24:00 YESTERDAY 1442 24 HOUR FOOTAGE 589 CASING INFORMATION 20" @ 101' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1482 48.28 246.11 1315.06 1609 54.47 246.62 1394.36 SURVEY DATA 1735 61.28 249.34 1461.03 1861 65.65 252.84 1517.18 1970 69.77 254.46 1558.44 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1RR 12.25 HCC MXL -1 6044740 3x18 lx16cj 101 2031 1930 23.56 1- 2- WT- A- E- 1 -SS -TD Casing point DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 187.0 @ 1859 9.4 @ 1512 107.4 114.2 FT /HR SURFACE TORQUE 8729 © 2027 0 © Sliding 6736.9 7868.8 AMPS WEIGHT ON BIT 34 @ 1546 4 © 2003 16.2 7.8 KLBS ROTARY RPM 73 © 2021 0 @ Sliding 44.0 63.1 RPM PUMP PRESSURE 1618 @ 1721 1088 © 1478 1396.8 1499.5 PSI DRILLING MUD REPORT DEPTH 2031 / 1578 TVD MW 9.3 VIS 78 PV 21 YP 24 FL 8.8 Gels 10/23/25 CL- 700 FC 2 SOL 7.0 SD 0.25 OIL 0/93 MBL 22.5 pH 8.4 Ca+ 60 CCI lb MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 48 @ 1973 7 @ 1676 13.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 72 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 9699 @ 1973 1415 @ 1676 2683.8 CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Drill (rotating and sliding) from 1442' to 1666'. Detect leak at base of stand pipe. Cease drilling and replace washed out gasket in standpipe union. Reciprocate pipe while work is in progress. Resume drilling after gasket replacement. Drill (rotating and sliding) from 1666' to 2031' (surface DAILY casing point). Take final survey. Circulate bottoms up and continue to circulate, clean and condition well (while reciprocating pipe and rotating at ACTIVITY 65rpm). Pull out of hole (SLM with no correction) from 2031' to top of directional tools at 303'. Clear and clean rig floor. Pump up weight indicator. SUMMARY Run back in hole from 303' to 1981'. Wash down from 1981' to bottom at 2031' with no fill. Begin circulating bottoms up. Start pumping around small pill of nut plug to determine washout volume. Record 72 units of wiper gas. Nut plug returns indicate hole is near gauge. Circulate, clean and condition hole. Pull out of hole from 2031' to 843'. Pull and stand back HWDP and jars to 303'. Pull, break and lay down directional tools. Grade bit. Clear and clean rig floor. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva • Marathon Oil Company EPOCH NinichikUnit DAILY WELLSITE REPORT Ell Susan Dionne 6 • REPORT FOR John Nicholson / Mitch Burns DATE Nov 09, 2008 DEPTH 2031 PRESENT OPERATION Cement job completed. Nipple down /nipple up operations. TIME 24:00 YESTERDAY 2031 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2031 (Projection) 71.96 254.96 1578.43 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ © KLBS ROTARY RPM © @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2031 / 1578 TVD MW 9.3 VIS 55 PV 16 YP 21 FL 8.6 Gels 8/13/ CL- 700 FC 2 SOL 6.5 SD Tr OIL 0/94 MBL 20.0 pH 8.3 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 12 @ 2031 1 @ displacing 5 (displacing) TRIP GAS 12 CUTTING GAS @ @ WIPER GAS III CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Blow down mud lines. Remove drill pipe elevators and short bails. Install long bails and pick -up sling -line. Install casing elevators. Move breakout tongs to driller's side and install correct tong head. Rig up Weatherford casing tongs and tall snub post. Remove rotary bushings. Rig up casing spider slips. Rig up and function stabbing board. Make up EZ -turn valve onto casing swage (to act as a safety valve), function test and record in IADC. Pick up centralizers and lock rings and stage on rig floor. Tie one (red) tugger line back in derrick for picking up pipe, and the second (blue) tugger line back for hanging casing tongs. Hold pre -job meeting with all hands on procedures and safety for running surface casing string. Inspect rig -up. Pick up shoe joint. Run in hole with 9 5/8" casing as per Marathon program. Clean and Bakerlok casing threads on successive shoe track joints during make up. Pick up and make up shoe track (shoe joint, 1 spacer joint, float collar, "float joint ') and run in hole to 121'. Circulate casing volume through shoe track and check float equipment. Continue running 9 5/8" casing in hole as per Marathon. Attach centralizers as per tally and fill every joint on way in. Run casing from 121' to tight spot 1107'. Work casing down from 1107' to 1132'. Break circulation and wash casing down from 1132' to 1172'. Continue running 9 5/8" casing in hole as per Marathon program from 1172' to 2024'. Make up 8' pup joint. Rig up circulating swage and wash down to bottom at 2031'. Reciprocate pipe and circulate to condition mud for cement job. (Condition well at 93spm, 182gpm, 160 - 250psi). Record 12 units of trip gas. Rig down stabbing board. Rig down and lay down casing spider slips and Weatherford casing tongs. Move and DAILY re -hang breakout tongs to off side and install correct tong head. Remove tall snub post and replace with short snub post. Build 20 bbl spacer of ACTIVITY Mud Clean II preflush. Make up cementing head with top and bottom plugs pre - installed. Continue to circulate and condition mud prior to cement SUMMARY job. Hold pre -job meeting with BJ and all hands on procedures and safety for cement job. Install cementing head. Pump 20 bbls of Mud Clean II preflush with rig pumps. Switch to BJ pumping unit. Pump 4.8 bbls of water and pressure test cement lines to 1887psi. Bleed off pressure. Continue cement job as per Marathon. Open up bottom valve, drop first (bottom) plug and pump out with 0.6 bbls. Mix and pump 222.0 bbls of 12.Oppg cement slurry (490 sacks of Class G cement plus accelerator chemicals mixed with 120.46 bbls water to batch -up at 10.33 gal /sk and yield of 2.544 cu- ft/sk). Reciprocate pipe while pumping cement. Open top valve and close middle and bottom valve on circulating head. Attempt to drop second (top) plug, but pin puller assembly would not retrace and plug failed to drop. Pull the plug dropping assembly from the cementing head. Block the pump out opening with a bull plug and manually insert the plug in the direct open line of the cementing head. Pump 5.9 bbls of water to kick the plug out. Switch over to rig pumps. (BJ flushes cementing lines and begins wash up while rig is displacing). Displace with 142.1 bbls of mud (and 148.0 bbls total displacement). Slow pump rate to bump plug. Bump plug (at 3109 strokes) with 1132psi total and 640psi over displacement pressure. Cement in place. Note 9 5/8" casing shoe set at 2030.50'. Bleed down pressure. Note 71 bbls of cement slurry returned to surface. Begin wait on cement. Flush down, blow down and rig down BJ cementing head and cement lines. Blow down Topdrive, mud lines and mud pumps. • Nipple down knife valve and diverter line. Nipple down and hot bolt diverter stack. Begin draining and cleaning pits. Begin heating the mix water for the Flo -Pro mud system. Clean cellar. Pick up all tools and put in proper places. Clean rig floor. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva Marathon Oil Company • NinilichikUnit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 10, 2008 DEPTH 2031 PRESENT OPERATION Testing casing TIME 24:00 YESTERDAY 2031 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2031 / 1578 TVD MW 9.0 VIS 55 PV 8 YP 20 FL 6.6 Gels 7/10/11 CL- 17000 FC 1 SOL 4.0 SD 0 OIL 3/93 MBL 0.0 pH 9.0 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 0 DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Remove pick up sling line. Make rough cut on 9 5/8" casing and lay down stub section. Pick up stackwasher and thoroughly wash and flush diverter stack inside and out to remove residual cement. Finish nippling down the last components of the diverter system. Move the diverter stack out of the cellar and mount on stand. Remove and load off 21 1/4" sliplock starter head. Cut 20" conductor. Make final cut on 9 5/8" casing and then dress out. Remove casing elevators and long bails and install short bails and drill pipe elevators. Install 9 5/8" sliplock connection by 11" 5M DAILY flanged multibowl wellhead. Test wellhead to 2400psi for 10 minutes. Remove casing pack -off. Begin nipple up of 13 5/8" 5M BOPE. Set spool and ACTIVITY HCR on stack. Set stack and continue nipple up of 13 5/8" 5M BOPE. Begin loading and strapping 5" drill pipe for next hole section on pipe racks. SUMMARY Finish cleaning pits and begin mixing new Flo -Pro mud. Service Topdrive and carrier. Prepare to test BOPE. Pull wear ring. Set test plug. Rig up testing equipment. Test all BOPE to 250psi Low / 2000psi High for 10 minutes (annular, upper pipe rams, upper topdrive, check valve, annular, dart valve, floor valve, lower topdrive, outside kill, inside kill, HCR, manual choke, lower pipe rams, blind rams, CMVs 1 -12), Perform accumulator drawdown test. Test all gas alarms. Rig down test equipment. Pull test plug. Install wear ring. Run in lock downs. Rig up test equipment prep to test casing. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 REPORT BY Craig Silva • Marathon Oil Company • NinilchikUnit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 11, 2008 DEPTH 2060 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 2031 24 HOUR FOOTAGE 29 CASING INFORMATION 9 5/8' @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2052 68.16 254.96 1587.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2RR 8.5 HCC MXL -1 6054215 3x28 2031 2051 20 0.46 1- 1- WT- A- E -1 -NO -BHA Clean out shoe only 3 8.5 HCC 506Z 7114298 6x13 2051 9 0.22 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 114.2 @ 2031 27.5 @ 2052 47.7 48.0 FT /HR SURFACE TORQUE 7868 © 2031 3609 @ 2052 5678.5 3803.9 AMPS WEIGHT ON BIT 18 @ 2048 6 © 2052 14.9 7.3 KLBS ROTARY RPM 74 @ 2045 29 @ 2055 50.8 36.9 RPM PUMP PRESSURE 1499 @ 2031 289 @ 2045 422.3 525.6 PSI DRILLING MUD REPORT DEPTH 2051 / 1587 TVD MW 9.0 VIS 54 PV 10 YP 18 FL 6.8 Gels 8/10/11 CL- 20000 FC 1 SOL 4.5 SD Tr OIL 2/94 MBL 0.0 pH 8.5 Ca+ 100 CCI MWD SUMMARY INTERVAL TO • TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 2043 1 @ 2052 3.1 TRIP GAS 1 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 977 @ 2043 213 @ 2052 611.7 CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 1 / 3 PENTANE (C -5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY Major Sand /Sandstone, Conglomeratic Sand /Conglomerate, Tuffaceous Claystone, Tuffaceous Siltstone, Volcanic Ash. Minor Tuffaceous Sandstone PRESENT SAND TUFFACEOUS CLAYSTONE LITHOLOGY Test 13 3/8" casing to 1500psi for 30 minutes. Rig down test equipment. Make up bit and bit sub to first stand of HWDP. Run in hole with HWDP to 663'. Pick up, make up and run in hole 40 joints (1267') of pre - strapped 5" drill pipe off the pipe racks to 1930'. Continue running in hole with drill pipe out of the derrick, and tag float collar at 1945'. Drill out shoe track (float, cement, casing shoe, rathole) from 1945' to 2031'. Drill 20' of new hole from 2031' to 2051'. Circulate briefly over shakers and then overboard retums while displacing. Displace old 9.3ppg spud mud with new 9.Oppg Flo -Pro NT mud system. Cease pumping and perform Formation Integrity Test to 15.Oppg (490psi, 1578'tvd, 9.Oppg). Pump dry job. Check for flow. Pull and stand back 22 stands of 5" drill pipe out of hole from 2051' to top of HVVDP. Pick up, make up and run in hole 40 joints (1268') of DAILY pre - strapped 5" drill pipe off the pipe racks. Pull out of hole standing back 20 stands of 5" drill pipe. Pick up, make up and run in hole 26 joints ACTIVITY (824') of pre - strapped 5" drill pipe off the pipe racks. Pull out of hole standing back 13 stands of 5" drill pipe. Continue pulling out of hole standing SUMMARY back 5" HVVDP and jars. Break and lay down bit and bit sub. Grade bit. Clear and clean rig floor. Pick up, install and nipple up Baker's APBA manifold for generating and receiving AUTOTRAK mud pulse signals. Lay out BHA on catwalk. Pick up, make up and run in hole AUTOTRAK directional tools (crossover, 3 CSNMDP flex collars, NM stabilizer, NM float sub, NM filter sub, OnTrak MWD collar, Autotrak Xtreme rotating collar, bit) to 178'. Link up and function check MWD tool on way in. Continue running in hole with 5" HWDP to 838'. Check lock -outs on all 3 rig pumps. Check grabber interlock. Circulate to check the pulse output performance and down link capability of the Baker manifold. Blow down mud lines. Continue running in hole with pre- strapped 5" drill pipe off the pipe racks. Pick up, make up and run in hole 38 joints (1141') of 5" drill pipe to 1980'. Wash in hole, continuing to pick and make up single joints of 5" drill pipe, from 1980' to bottom at 2051' (with no fill). Drill from 2051' to 2060'. • EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 REPORT BY Craig Silva Marathon Oil Company • Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR Mitch Burns / Dan Byrd DATE Nov 12, 2008 DEPTH 3498 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 2060 24 HOUR FOOTAGE 1438 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2115 68.73 255.13 1611.02 2432 68.95 255,35 1725.60 SURVEY DATA 2751 68.77 253.16 1840.68 3066 68.77 252.22 1954.83 3382 68.82 251.70 2069.20 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC 506Z 7114298 6x13 2051 1467 16.80 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 169.3 © 2931 18.0 @ 2070 98.5 98.5 FT /HR SURFACE TORQUE 8328 @ 2508 2722 © 2676 5560.0 5965.8 AMPS WEIGHT ON BIT 30 © 3453 2 @ 2423 14.6 26.3 KLBS ROTARY RPM 39 © 2066 30 @ 2086 33.5 33.5 RPM PUMP PRESSURE 1414 @ 3485 486 @ 2062 1137.4 1331.3 PSI DRILLING MUD REPORT DEPTH 3401 /2076 TVD MW 9.2 VIS 59 PV 15 YP 25 FL 5.6 Gels 11/14/15 CL- 21000 FC 1 SOL 5.5 SD Tr OIL 3/92 MBL 3.0 pH 9.2 Ca+ 100 CCI 410 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 237 © 3472 2 @ 2069 14.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 47449 @ 3472 412 @ 2069 2954.2 CONNECTION GAS HIGH ETHANE (C -2) 22 @ 3473 0 @ 0.3 AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG 6 / 14 PENTANE (C -5) @ @ HYDROCARBON Potential gas sand show from 3458' to 3479' but mixing with very fine coal particles make it suspect. SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 3458 -3479 Massive clay matrix supported sandstone. Volume of 237u Max; 25u before -50u Sd /SS = med -med dk gry, comp gywke, v hi fraction intergrain clays make higher Por -Perm suspect. after; 210u avg thru of lithics, abnt dy mtrx, fn -med, ang -ang, mod srtd, interval Por ?? LITHOLOGY Major Sand /Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Tuffaceous Sandstone, Volcanic Ash, Coal /Carbonaceous Shale. Minor Conglomeratic Sand /Conglomerate, Tuffaceous Shale, Calcareous Tuff. PRESENT SAND /SANDSTONE/TUFFACEOUS SANDSTONE LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 2060' to 3498'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 REPORT BY Craig Silva • Marathon Oil Company • Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR Dan Byrd / Mitch Burns DATE Nov 13, 2008 DEPTH 4716 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 3498 24 HOUR FOOTAGE 1218 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3445 68.92 252.50 2091.91 3762 68.73 253.06 2206.68 SURVEY DATA 4080 60.27 252.58 2339.22 4397 46.81 252.09 2526.26 4713 34.56 253.07 2765.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC 506Z 7114298 6x13 2051 2665 28.49 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 177.0 @ 3569 19.6 @ 3617 112.4 145.9 FT /HR SURFACE TORQUE 8807 © 4621 3926 @ 3499 6822.7 6982.0 AMPS WEIGHT ON BIT 29 @ 4138 3 @ 3501 14.7 15.0 KLBS ROTARY RPM @ @ RPM PUMP PRESSURE 1476 @ 4621 860 @ 3505 1294.2 1376.8 PSI DRILLING MUD REPORT DEPTH 4590 / 2667 TVD MW 9.5 VIS 58 PV 16 YP 27 FL 5.3 Gels 12/15/16 CL- 17000 FC 1 SOL 7.0 SD Tr OIL 3/90 MBL 4.5 pH 9.3 Ca+ 100 CCI 40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 242 @ 3523 4 © 4261 41.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 64 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 48522 @ 3523 922 © 4197 8206.2 CONNECTION GAS HIGH ETHANE (C -2) 22 @ 3521 0 © 1.1 AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 24 / 55 PENTANE (C -5) @ @ HYDROCARBON One sand zone with gas over 100 units and poor to fair show. SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 4837 -4863 Massive fine to medium sand with mixed clay matrix and Max 209u; Avg thru Sd /SS: medium dark gray, fn lower to fine upper, mod grain spprt with calc cmttn. Vis Poor to Fair Por. zone 190u; before /after w srtd, sbang, mixed mtrx and gr spprt, comp grywke Speculate fair Perm gas 40u with 50% lithics; est fair vis Por. LITHOLOGY Major Sand /Sandstone/Tuffaceous Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Coal /Carbonaceous Shale, Volcanic Ash. Minor Conglomeratic Sand, Calcareous Tuff, Tuffaceous Shale. PRESENT SAND TUFFACEOUS CLAYSTONE LITHOLOGY DAILY ACTIVITY After drilling to 3498' circulate bottoms up and continue to circulate hole clean. Pull out of hole from 3498' to 1978' (inside shoe) on wiper trip. SUMMARY Service rig and Topdrive. Run back in hole from 1978' to 3434'. Break circulation and wash down from 3434' to 3498' (with no fill). Initiate AUTOTRAK. Drill from 3498' to 4716'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 REPORT BY Craig Silva • Marathon Oil Company • Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR Dan Byrd / Mitch Burns DATE Nov 14, 2008 DEPTH 5839 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 4716 24 HOUR FOOTAGE 1123 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4777 31.94 252.96 2819.16 5027 29.73 255.36 3035.57 SURVEY DATA 5348 29.81 254.97 3314.11 5601 29.83 254.57 3533.63 5852 29.96 254.68 3751.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC 506Z 7114298 6x13 2051 3788 40.95 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 150.6 @ 4973 18.0 © 4964 95.4 84.3 FT /HR SURFACE TORQUE 11745 @ 5838 5260 © 4895 8490.4 11215.2 AMPS WEIGHT ON BIT 33 @ 5215 2 © 5017 13.4 12.7 KLBS ROTARY RPM @ @ RPM PUMP PRESSURE 1622 @ 5033 1077 @ 5197 1435.7 1485.9 PSI DRILLING MUD REPORT DEPTH 5780 / 3689 TVD MW 9.6 VIS 61 PV 16 YP 26 FL 5.6 Gels 12/16/17 CL- 19000 FC 1 SOL 7.0 SD Tt OIL 3/90 MBL 4.5 pH 9.8 Ca+ 80 CCI • MWDSUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 209 @ 4848 5 @ 5085 59.1 TRIP GAS CUTTING GAS @ @ WIPER GAS 61 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 41839 @ 4848 1024 @ 5085 11744.7 CONNECTION GAS HIGH ETHANE (C -2) 22 © 5664 0 @ 5574 3.4 AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 20 / 65 PENTANE (C -5) @ @ HYDROCARBON 11 Sand sections with gas over 100 units. Range from poor to good estimated gas shows SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION Best interval from Massive zone of "cleaner looking" sand with probable (All in indicated "best" zone) SD: med It gry, fine, mod w srtd, massive, subtle 5723'to 5839' good Por and Perm. Characteristics inidicate obvious 170u Max, 145u Avg, 40u fnning upward, ang, disaggtd, good Vis Por in Tyonek sand. before and after consol pcs. Likely good Perm. LITHOLOGY Major Sand /Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Tuffaceous Sandstone, Volcanic Ash, Coal. Minor Calcareous Tuff, Conglomeratic Sand. PRESENT SAND LITHOLOGY DAILY Drill from 4716' to 5084'. Circulate hole clean. Pull out of hole on wiper trip from 5084' to 3400'. Circulate out at 4147' and continue pulling out. ACTIVITY Pull tight in 16 different spots total. Run back in hole from 3400' and tag bridge at 4740'. Pick up stand, break circulation, wash and ream from SUMMARY 4703' to 4766'. Clean up spot at 4740'. Continue running in hole from 4766' to 5020'. Wash down from 5020' to 5084' with no fill. Peform data downlink to AUTOTRAK tool. Drill from 5084' to 5839' EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 0 REPORT BY Craig Silva Marathon Oil Company EPOCH • Ninilchik Unit DAILY WELLSITE REPORT Susan Dionne 6 REPORT FOR John Nicholson / Mitch Bums DATE Nov 15, 2008 DEPTH 6737 PRESENT OPERATION Pulling out of hole after TD wiper trip TIME 24:00 YESTERDAY 5839 24 HOUR FOOTAGE 898 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5918 29.75 255.88 3808.47 6110 29.77 255.33 3975.18 SURVEY DATA 6298 29.67 254.69 4138.53 6489 29.54 251.62 4304.61 6678 29.66 251.48 4520.28 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC 506Z 7114298 6x13 2051 6737 4686 53.69 In Hole TD of well DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 131.3 @ 5921 9.4 @ 5987 80.2 72.6 FT /HR SURFACE TORQUE 13571 @ 6706 8677 @ 6158 11332.0 12716.9 AMPS WEIGHT ON BIT 27.9 @ 5985 4.3 @ 6426 12.7 17.8 KLBS ROTARY RPM @ @ RPM PUMP PRESSURE 1728 © 6400 1324 @ 5901 1565.1 1653.5 PSI DRILLING MUD REPORT DEPTH 6737 / 4520 TVD MW 9.6 VIS 57 PV 16 YP 22 FL 5.2 Gels 10/15/16 CL- 22000 FC 1 SOL 7.0 SD Tr OIL 3/90 MBL 6.0 pH 9.7 Ca+ 90 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 149 @ 5981 11 @ 6525 53.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 187 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 29905 @ 5981 2648 @ 6525 10719.0 CONNECTION GAS HIGH ETHANE (C -2) 14 @ 5982 0 © 2.1 AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS Only 2 Sand sections with gas over 100 units, and first one is continuation of zone from previous report . Range from fair to good estimated gas shows INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION Best interval is a coninuation Continued massive zone of "cleaner looking" sand (All in indicated "best" SD: med It gry, fine, mod w srtd, massive, from 5839'to 5890'. Minor zone with probable good Por and Perm. Characteristics zone) 170u Max, 145u subtle fnning upward, ang, disaggtd, good from 5975' -5990' inidicate obvious Tyonek sand. Avg, 40u before and after Vis Por in consol pcs. Likely good Perm. LITHOLOGY Major Sand /Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, Tuffaceous Sandstone, Volcanic Ash, Coal. Minor Calcareous Tuff, Conglomeratic Sand. PRESENT TUFFACEOUS CLAYSTONE SANDSTONE LITHOLOGY DAILY Drill from 5839' to 6737'. Circulate bottoms up. Circulate, clean and condition well. Check for flow. Pull out of hole from 6737' to 4830' on wiper ACTIVITY trip. Blow down AUTOTRAK surface manifold and hoses. Run back in hole from 4830' to 6730'. Wash down from 6730' to bottom at 6737' with SUMMARY no fill. Circulate bottoms up. Record 187 units of wiper gas. Continue to circulate, clean and condition well. Nipple down, rig down and lay down AUTOTRAK Bypass Actuator and 2' chicksan hardline. Pull out of hole from 6737' to 6478'. EPOCH PERSONNEL ON BOARD 4 DAILY COST ML: 3400 RW: 635 0 REPORT BY Craig Silva Marathon Oil Company • Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 16, 2008 DEPTH 6737 PRESENT OPERATION Pulling out of hole with Weatherford's Quad -Combo shuttle logging assembly TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6737 (Projection) 29.66 251.48 4520.28 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC 506Z 7114298 6x13 2051 6737 4686 53.69 1- 1- BT- G- X- 1 -NO -TD TD of well DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6767 /4520 TVD MW 9.7 VIS 58 PV 15 YP 22 FL 5.2 Gels 10/15/16 CL- 22000 FC 1 SOL 7.5 SD Tr OIL 3/90 MBL 6.0 pH 9.4 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 36 @ at 6675 w/ shuttle 2 @ at 6675 w/ shuttle 14 TRIP GAS 36 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) © @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Break circulation and pump dry job. Continue pulling out of hole from 6478' (SLM) to top of 5" HWDP at 838' (with no correction). Pull and stand back 21 joints 5" HWDP plus crossover and jars (11stands) to 178'. Break, lay down and load off directional tools (crossover, 3 NMCSDP flex joints, NM stabilizer, NM float sub, NM crossover, NM filter sub, MWD, AUTOTRAK, bit). Make up datalink and download recorded data from AUTOTRAK tool before laying down. Grade bit. Clear and clean rig floor. Hold pre -job meeting on procedures and safety for handling Weatherford Logging Services' shuttle logging system. Prepare and stage logging tools on catwalk. Pick up and make up shuttle outer assembly (reamer, circulating sub, 4 joints 3 1/2" drill pipe, lower latch, upper latch, 1 joint 3 1/2" drill pipe, float valve, crossover sub). Pick up and make up inner string of WLS Quad -Combo logging tools (with inner latching spear). Install, seat and latch up logging assembly in 3 1/2" drill pipe. (Drift all tools DAILY with 2 1/2 " Weatherford drift while making up and running in). Load neutron sources (before latching assembly and making up last joint of 3 1/2" ACTIVITY drill pipe). Run shuttle logging assembly in hole on 5" HWDP (with crossover) to 782'. Perform staged pressure check (at 2bpm to 158psi, 4bpm to SUMMARY 360psi, 6bpm to 700psi). Pull corrosion ring from first stand of 5" drill pipe. Continue running shuttle logging assembly in hole on 5" drill pipe to 1922'. Perform staged pressure check (at 2bpm to 181 psi, 4bpm to 400psi, 6bpm to 725psi). Continue running shuttle in hole to 3950'. Perform staged pressure check (at 2bpm to 233psi, 4bpm to 467psi, 6bpm to 810psi). Continue running shuttle in hole to 6548'. Break circulation, fill pipe and wash down with shuttle from 6548' to 6675'. Circulate bottoms up (at 122spm, 238gpm, 923psi). Record 36 units of trip gas. Continue to circulate, clean and condition hole (for 2 complete circulations before logging pass). Finish circulating and pull back up (2 stands) to 6548'. Drop and pump down Messenger dart to engage assembly. Pressure up until the seating plug is sheared and inner string released. Push out and deploy shuttle logging assembly to 6651'. Check for flow. Pump dry job. Pull out of hole at controlled rate of 30' per minute logging up with Weatherford Logging Service Quad -Combo tools from 6651' to 1898'. Pull out of hole at normal rate from 1898' to top of shuttle assembly at 782'. • EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 Consulting: 1300 REPORT BY Craig Silva Marathon Oil Company EPOCH • Ninilchik Unit DAILY WELLSITE REPORT Susan Dionne 6 REPORT FOR John Nicholson / Mitch Burns DATE Nov 17, 2008 DEPTH 6737 PRESENT OPERATION Wireline logging with Weatherford's formation testing tool TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6737 / 4520 TVD MW 9.8 VIS 58 PV 15 YP 21 FL 4.2 Gels 10/16/20 CL- 20000 FC 1 SOL 9.0 SD Tr OIL 3/88 MBL 7.5 pH 10.0 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 21 @ TG at 6737 1 @ circ pumping tool down 3 circ moving pipe TRIP GAS 21 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 1 / 3 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Pull and stand back 5" HWDP to 183'. Break and lay down 3 1/2" drill pipe. Remove neutron sources. Break, lay down and load off WLS Quad- Combo tools. Break and load off running equipment (upper and lower latches, float valve, circulating sub, crossover sub, reamer). Clear and clean rig floor. Weatherford Wireline Services begins processing recorded Quad -Combo data. Lube and service rig , Topdrive, crown, blocks and carrier. Pick up and make up muleshoe to first stand of HWDP. Run in hole with 5" HWDP and 5" drill pipe to 2000'. Cut and slip drilling line (173'). Perform rig maintenance while waiting on Marathon geologist to determine MFT pick points. Change out hydraulic hose for elevators, adjust Topdrive compensator and grease mud manifold valves. Run in hole from 2000' to 6625'. Wash down from 6625' to 6737'. Circulate bottoms up. Record 21 DAILY units of trip gas. Continue to circulate, clean and condition hole. WWS finishes processing Quad -Combo data and and sends finished logs and files ACTIVITY to Marathon geologist for final evaluation. Check for flow. Pull out of hole from 6737' to 5550'. Hold pre -job meeting with Weatherford Wireline SUMMARY Services' loggers on procedures and safety for handling wireline logging tools. Rig up Weatherford Wireline Services sheaves, safety valve, lubricator and other surface running equipment. Pick up, make up and run in hole with MFT logging assembly. Install pump down plug behind assembly on way in. Pump logging assembly down pipe while running with in adjusted tension on wireline. Pump tools out through muleshoe and into open hole. Cease pumping and continue running MFT assembly downhole on wirleline to first pressure point at 6034'. Log up with MFT tool taking pressure points from 6034' to 5800'. Rig needs to move pipe to prevent differential problems. Pull logging assembly all the way out to the surface.. Inspect clean logging tool. Set assembly down on catwalk. Move and work pipe while briefly circulating. Pick up and run MFT assembly (with pump down swab) back in hole. Begin pumping logging assembly down hole and become temporarily stuck inside 5" drill pipe at 1600'. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 Consulting: 1300 REPORT BY Craig Silva • Marathon Oil Company • Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Mitch Bums DATE Nov 18, 2008 DEPTH 6737 PRESENT OPERATION Running in hole on clean out run. TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2RR2 8.5 HCC MXL -1 6054215 3x28 6737 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE © @ AMPS WEIGHT ON BIT @ © KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6737 / 4520 TVD MW 9.8 VIS 58 PV 14 YP 19 FL 4.2 Gels 8/14/ CL- 19500 FC 1 SOL 9.0 SD Tr OIL 3/88 MBL 7.5 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS II GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 4 @ Brief circ to work drill pipe 1 @ brief circ to work drill pipe 3 brief circ to work drill pipe TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Free MFT tool at 1600'. Pool out of hole with logging assembly and set down on catwalk. Note that the plug set above the logging assembly to push the tools when being pumped down hole, was ripped and "blown out ", and removed from the wireline. Circulate drill pipe volume while working drill pipe. Pick up MFT logging assembly and run back in hole. Pump logging assembly down pipe while running with in adjusted tension DAILY on wireline. Pump tools out through muleshoe iand top open hole. Cease pumping and continue running MFT assembly downhole on wirleline to ACTIVITY first pressure point at 6392'. Log up with MFT tool taking pressure points from 6392' to 5188'. Note two logging runs and 74 total tests (that SUMMARY included first trys, immediate retests or a retrys of first run points on the second run) yielded good usable data (and a net 100% success rate) for 51 different pressure points. Pull MFT logging assembly out of hole and load off on catwalk. Rig down Weatherford Wireline Services sheaves, safety valve, lubricator and other surface running equipment. Pull out of hole with 5" drill pipe and 5" HWDP. Break and lay down mule shoe. Make up bit and bit sub to first stand of 5" HWDP. Run in hole with 5" HWDP. EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 Consulting: 1300 REPORT BY Craig Silva • Marathon Oil Company - 411, Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Dan Byrd DATE Nov 19, 2008 DEPTH 6737 PRESENT OPERATION Running in hole with 4 1/2" liner TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2030' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2RR2 8.5 HCC MXL -1 8054215 3x29 6737 6737 0 n/a 1- 1- WT- A- E -1 -NO -BHA Clean out run only DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6737 / 4520 TVD MW 9.8 VIS 59 PV 14 YP 19 FL 4.2 Gels 8/14/ CL- 19000 FC 1 SOL 9.0 SD Tr OIL 3/88 MBL 7.5 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 73 @ TG at 6737 1 @ circ liner volume 16 circ on C/O run TRIP GAS 73 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Continue running in hole with 5" HWDP and 5" drill pipe on clean out run. Run in hole to 6682'. Wash down from 6682' to 6737' (with no fill). Circulate bottoms up. Record 73 units of trip gas. Continue to circulate, clean and condition hole. Check for flow. Pulll out of hole from 6737' to 4845' standing back 5" drill pipe in derrick. Rig up for laying down drill pipe. Continue pulling out the hole laying down 5" drill pipe from 4845' to 663'. Pull out of hole laying down 5" HWDP. Break and lay down bit and bit sub. Load off all tools and subs no longer needed for drilling operations. Clear and clean rig floor. Lube rig and Topdrive. Pull wear bushing. Prepare to test pipe rams. Set test joint of 4 1/2" tubing. Rig up testing equipment. Test pipe rams to 250psi Low / 2500psi High for 10 minutes. Rig down testing equipment. Pull test joint. Set wear bushing. Blow down DAILY choke lines. Prep and rig up to run 4 1/2" liner. Rig down pipe spinner. Remove elevators. Change out from short bails to long bails. Install casing ACTIVITY elevators. Rig up sling line. Rig up cementing line and circulating swage. Move breakout tongs to driller's side and install correct tong head. Rig up SUMMARY Weatherford casing tongs and tall snub post. Make up EZ -turn valve onto casing swage (to act as a safety valve), function test and record in IADC. Pick up centralizers and lock rings and stage on rig floor after arrival on location. Tie one tugger line back in derrick for picking up pipe, and the second tugger line back for hanging casing tongs. Inspect rig -up. Hold pre -job meeting with Weatherford on procedures and safety for running production liner. Run in hole with 4 1/2" liner as per Marathon program. Pick up, make up and run in shoe track (float shoe, 2 liner joints, float collar, liner joint, landing collar, liner joint) to 172'. Install stop collars and centralizers as directed. Check float equipment. Continue running 4 1/2" liner in hole. Attach centralizers as per tally and fill on way in. Run casing from 172' to 1988' (just inside shoe). Circulate liner volume (at 99spm, 194gpm, 220psi). Record 1 unit of gas. Continue running 4 1/2" liner from 1988' (to 2676'). EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva • Marathon Oil Company Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 0 REPORT FOR John Nicholson / Dan Byrd DATE Nov 20, 2008 DEPTH 6737 PRESENT OPERATION Running in hole with ZXP packer TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 6735' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6737 / 4520 TVD MW 9.8 VIS 59 PV 14 YP 19 FL 4.2 Gels 8/14/ CL- 19000 FC 1 SOL 9.0 SD Tr OIL 3/88 MBL 7.5 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ cbu before cementing 1 @ last circ before pooh N/A TRIP GAS 16 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY li p METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Continue running 4 1/2" liner from 2676' to 3679'. Circulate bottoms up. Record 5 units maximum gas. Continue running 4 1/2" liner from 3679' to 4884'. Circulate bottoms up. Record 13 units maximum gas. Load off unused centralizers and lock rings off rig floor. Remove casing tongs. Re -rig tugger lines for picking up drill pipe. Remove EZ -tum valve. Rig down Weatherford casing tongs and remove tall snub post. Move breakout tongs to driller's off -side and install correct tong head. Remove pick -up sling line. Replace long bails with short bails. Remove casing elevators and install drill pipe elevators. Begin mixing brine for later displacement of cement. Pick up and make up Baker Oil Tool 7" by 9 5/8" liner hanger assembly (pup joint, crossover, PBR, crossover, Flex -Lock hanger, RS pack -off, HR setting sleeve). Fill liner tie -back with PAL mix up to top of liner tie -back sleeve. Set dust cover to top of liner sleeve and lock down. Run hanger assembly in hole to 4922'. Break circulation and check flow. Continue running 4 1/2" liner in hole (with 29 joints of 5" drill pipe) from 4922' to 6674'. Wash down from 6674' to bottom at 6737' (with no fill). Circulate, reciprocate (17' up /dn) and rotate pipe (at 395gpm, 485psi). Circulate bottoms up and record 16 units of trip gas. Stop circulating. Pick up, rig up and make up BJ cementing head and rig floor cement lines. Continue to circulate and condition hole with rig pumps prior to cementing. Hold pre -job meeting (while circulating) with BJ and all hands on procedures and safety for cementing 4 1/2" liner. Stop circulating. Gas down to 2 units. Switch from rig pumps to BJ pumping unit. Pump 2.2 bbls of water into cementing lines and pressure test to 3847psi. Batch mix and pump 40 bbls of 10.Oppg Sealbond sweep (using 36.95 bbls of mix water), followed with 105 bbls of 12.5ppg lead cement slurry (blended with 270 sacks Class G DAILY cement to 76.416 bbls water and accelerator chemicals at 11.887 gal /sack and a yield of 2.100 cuft/sack) and then 196 bbls of 15.8ppg tail cement ACTIVITY slurry (blended with 970 sacks Class G cement to 114.53 bbls water and accelerator chemicals at 4.959 gal /sack and a yield of 1.183 cuft/sack). SUMMARY Note rotating and reciprocating liner while pumping cement. Stop reciprocating liner after 215 total bbls of cement is pumped due to high torque. Continue to rotate liner unit) last 10 bbls of cement is displaced. Close cementing head after tail slurry is pumped, open wash up tee to slop tank and pump 5.6 bbls of water to wash lines and pump. Open head back up. Drop 4 1/2" liner dart. Start pumping brine to displace and stop after only 7.9 bbls when dart did not deploy. Open head, manually drop second dart in drill pipe and resume displacing with brine. (Note that the first dart later released and deployed 31.1 bbls behind the second dart). Displace cement with 76.0 bbls of 3% KCL brine and 29.0 bbls mud (105 bbls total displacement). Note pumping was stopped 8 bbls short of total displacement to factor fluid in front of second dart. Plug did not bump. Bleed off and check floats. Floats holding. (Pressure reduction below plug apparently enough for plug to seat). Cement in place. Pressure up. Set liner hanger by surging pressure. Set 43K down weight on hanger and put '% turn in drill pipe to release HR tool. Turn over to rig. Pressure drill pipe to 500psi and then pull out running tool when pressure reaches 650psi. Circulate out excess cement (20 -25 bbls) to surface and continue to circulate hole clean. Lay down Topdrive cemeting head. Blow down lines. Begin cleaning pits and hauling off surface mud. Pull out of hole with 5" drill pipe. Break and lay down running tool. Flush cement from stack. Service rig and change out grabber dies. Pick up and break down cementing head and then lay • back down. Pick up polish mill for 7 1/2" tie back sleeve. Run in hole to top of tie -back at 1814'. Polish tie -back sleeve as per Baker toolhand. Pull out of hole with polish mill. Lay down mill. Pick up and make up 7 1/2 "OD tie -back seal stem and ZXP packer. Run packer assembly in hole on 5" drill pipe (to 1238'). EPOCH PERSONNEL ON BOARD 2 DAILY COST ML: 2625 RW: 635 REPORT BY Craig Silva Marathon Oil Company Ninilchik Unit DAILY WELLSITE REPORT EPOCH • Susan Dionne 6 REPORT FOR John Nicholson / Dan Byrd DATE Nov 21, DEPTH 6737 PRESENT Preparing to nipple down after running 4 1/2" liner, displacing with inhibited brine and 2008 OPERATION testing all seals back to surface TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 6735 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH Surface MW 8.6 VIS 28 PV 1 YP 1 FL Gels CL- 16000 FC 3% KCL Brine SOL SD OIL MBL pH 7.7 Ca+ CCI MIND SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Continue running ZXP packer assembly in hole (from 1238') to 1685'. Wait on cement. Clean pipe rack. Rack and prep 4 1/2" tubing. Band mud products. Build new batch of 3% KCL brine. Continue running ZXP packer assembly in hole from 1685' to 1814'. Run the 7 1/2 "OD tie -back seal stem and ZXP packer into the top of the Flexlock hanger assembly using a HR running tool with a hydraulic pusher tool. Space out rig up BJ. Drop a 1 7/16" ball and let it migrate close to the ball seat. Use rig pump to pump onto the ball seat. Stab into the stem /running sleeve on the Flexlock hanger. Line up BJ to pressure up on the hydraulic tool. Pressure up to 2000psi and hold for 5 minutes, then pressure up to 2400psi to set a minimum overweight on the ZXP packer, then pressure up to 3500psi (generating a set down weight > 60K) to set the packer and continue pressuring up to 4825psi to blow the ball seat. Test liner and casing (annulus) to 1500psi for 10 minutes. Pull out of the hole from 1793' laying down 5" drill pipe (56 joints). Make service breaks on the Baker running /packer setting tools and lay down. Inspect and clean running tools. Make up wear bushing puller. Pull wear bushing. Rig down and load off pipe spinner and tongs. Clear rig floor of all remaining drill pipe handling tools. Clean rig floor. Set multi -bowl 11" by 7" hanger bushing /pack -off and test to 5000psi for 10 minutes. Make a gauge run with the 4 1/2" tubing hanger. Change DAILY bails and elevators. Pick up Weatherford hydraulic tongs, power slips and tubing handling equipment ad rig up to run 4 1/2" tubing. Hold pre -job ACTIVITY meeting with all hands on procedures and safety for running tubing. Pick up and make up Baker 4 1/2" locater seal assembly to first joint of 4 1/2" SUMMARY tubing. Run first 8 joints 4 1/2" tubing in hole as per Marathon program to 339'. Rig up Pollard Oilfield Service to do banding of control line. Hang sheave for running chemical injection line. Make up injection nipple and attach 1/4" stainless steel chemical line. Test injection line to 2000psi. Continue running in 4 1/2" tubing (44 joints total) from 339' to 1801', putting 2 steel bands per joint to secure injection line. Tag top of liner. Rig down Pollard banding equipment. Record pickup and slackoff weights. Stab into seal assembly and continue into monobore. Pressure up backside to 200psi to insure seals are engaged and then land locator. Space out for tubing hanger. Rig up circulating lines. Rig down and load off Weatherford hydraulic tongs, power slips and remaining tubing handling equipment. Cut and tie off chemical injection line. Load remaining • equipment off of rig floor. Prepare to change over mud. Clean pill pit. Build Hi -Vis sweep. Pump 30 bbl H -Vis sweep, and then displace well with 94 bbls of 3% KCL brine and 40 bbls of inhibited KCL. Land tubing hanger. Test hanger body seals to 5000psi for 10 minutes. Test down 4 1/2" liner string (to contact seal at 9 5/8" casing) to 1500psi for 30 minutes. Test annulus to 1500psi for 10 minutes. Lay down and load off landing joint. Set Blowout Prevention Valve. Rig down and lay down sheave for running chemical injection line and spool back unused line. Clear rig floor. Load off all remaining handling equipment, subs, valves, slips and crossovers. EPOCH PERSONNEL ON BOARD 1 DAILY COST ML: 1485 RW: 635 REPORT BY Craig Silva Marathon Oil Company 0 Ninilchik Unit DAILY WELLSITE REPORT EPOCH Susan Dionne 6 REPORT FOR John Nicholson / Dan Byrd DATE Nov 22, 2008 DEPTH 6737 PRESENT OPERATION General rig down operations after installing and testing tree. TIME 24:00 YESTERDAY 6737 24 HOUR FOOTAGE 0 CASING INFORMATION 4 1/2" @ 6735' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ © PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE III DITCH GAS @ @ TRIP GAS CUTTING GAS © @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ © HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Flush all surface equipment (mud pumps 1 -2 -3, choke manifold, stack, choke and kill lines, cementing lines, Topdrive, poorboy, stand pipe manifold and lines to pits). Clean pits and sump. Offload all remaining fluid in the pits to Vac truck. Rig down drip pan, turnbuckles, fill -up line, trip DAILY tank line, flowline, and choke and kill lines. Nipple down check and kill valves, spacer spool, BOP stack, and DSA. Load off BOP stack. Clean and ACTIVITY inspect gas buster. Prepare and install the tree with Vetco -Gray. Remove Blowout Prevention Valve. Install 2 -way check valve. Test void to SUMMARY 5000psi for 10 minutes. Test tree to 5000psi for 10 minutes, Pull 2 -way check valve and reinstall BPV. Begin rig down of all Glacier No.1 rig and camp components and commence transporting to the Beaver Creek Field location or to various service provider locations. Note that major service /maintenance and overhaul/upgrade operations are to take place at Beaver Creek before the start of next drilling season. EPOCH PERSONNEL ON BOARD 1 DAILY COST ML: 1100 Rig Down: 2925 REPORT BY Craig Silva ID