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Home My WebLink About199-073CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3G-12 (PTD 1990073) Report of suspect IA pressure increase Date:Thursday, March 16, 2023 8:49:17 AM Attachments:AnnComm Surveillance TIO for 3G-12.pdf PTD is 1990073. From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, March 10, 2023 7:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3G-12 (PTD 199-073) Report of suspect IA pressure increase Chris, KRU 3G-12 (PTD 199-073) is exhibiting suspect IA pressure increase. The plan is for DHD to perform initial diagnostics including an MITIA, pack off tests, and adjusting the IA pressure for a 30 day monitor period. Any required paperwork for continued injection or corrective action will be submitted once initial diagnostics and monitor period have been completed. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 3G-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 35.0 Set Depth (ftKB) 3,040.6 Set Depth (TVD) … 3,040.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION 1991 OD (in) 7 ID (in) 6.276 Top (ftKB) 33.1 Set Depth (ftKB) 1,529.8 Set Depth (TVD) … 1,529.8 Wt/Len (l… 26.00 Grade J-55 Top Thread AB MOD- BTC Casing Description PRODUCTION 1990 OD (in) 7 ID (in) 6.276 Top (ftKB) 1,529.8 Set Depth (ftKB) 6,735.3 Set Depth (TVD) … 6,066.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5"x2.875" @ 6222' String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 31.4 Set Depth (ft… 6,260.8 Set Depth (TVD) (… 5,712.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.03 HANGER WKM GEN IV HANGER 3.500 1,812.9 1,812.9 0.52 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE (Locked out flapper only 4/29/2006) 2.812 6,221.7 5,683.2 42.12 XO Reducing CROSSOVER 3.5 x 2.875 2.875 6,222.2 5,683.6 42.12 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.387 6,225.0 5,685.6 42.13 PACKER BAKER D PERMANENT PACKER 3.250 6,228.6 5,688.3 42.15 SBE BAKER SEAL BORE EXTENSION 3.250 6,248.6 5,703.1 42.23 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,260.1 5,711.6 42.28 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 2,152.0 2,151.9 1.41 CSG PATCH 7" Csg Patch to Repair Collapsed Csg, Drift ID 5.851" 3/4/1991 5.976 6,431.0 5,837.9 42.27 FISH 5' Dyna Strip Strip Left in Hole from Perf Job on 8/8/91 8/8/1991 6,444.0 5,847.5 42.21 FISH 2 - 1 1/2" DV Left in Rathole 9/3/1991 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 6,344.0 6,354.0 5,773.6 5,781.0 C-4, UNIT B, 3G-12 8/8/1991 8.0 IPERF 90 deg pH; 2 1/8"Dyna Strip 6,390.0 6,420.0 5,807.6 5,829.7 A-4, A-3, 3G- 12 8/6/1991 8.0 IPERF 90 deg ph; 2 1/8"Dyna Strip 6,430.0 6,460.0 5,837.1 5,859.4 A-2, 3G-12 3/2/1991 4.0 IPERF 180 deg. ph, 4.5" Csg Gun Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,648.0 2,647.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/4/1991 2 4,585.3 4,500.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/4/1991 3 6,173.4 5,647.3 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/3/1991 Notes: General & Safety End Date Annotation 3/1/1991 NOTE: UPPOER 1500' PRODUCTION CASING REPLACED, SCREWED INTO EXISTING CSG 8/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: Locked Out Flapper3G-12, 1/25/2017 11:23:03 AM Vertical schematic (actual) PRODUCTION 1990; 1,529.8- 6,735.3 IPERF; 6,430.0-6,460.0 FISH; 6,444.0 FISH; 6,431.0 IPERF; 6,390.0-6,420.0 IPERF; 6,344.0-6,354.0 SOS; 6,260.1 NIPPLE; 6,248.6 SBE; 6,228.6 PACKER; 6,225.0 SEAL ASSY; 6,222.2 GAS LIFT; 6,173.4 GAS LIFT; 4,585.3 SURFACE; 35.0-3,040.6 GAS LIFT; 2,648.0 CSG PATCH; 2,152.0 SAFETY VLV; 1,812.9 PRODUCTION 1991; 33.1- 1,529.8 CONDUCTOR; 36.0-115.0 HANGER; 31.4 Annotation Last Tag: SLM Depth (ftKB) 6,419.0 End Date 1/2/2016 Annotation Rev Reason: PULL CA-2 PLUG W/GUAGE Last Mod By pproven End Date 1/25/2017 KUP INJ KB-Grd (ft) 36.21 Rig Release Date 6/21/1990 Annotation Last WO: End Date 3/1/1991 3G-12 H2S (ppm) Date ... TD Act Btm (ftKB) 6,749.0 Well Attributes Wellbore API/UWI 501032013100 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 47.08 MD (ftKB) 5,100.00 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220928 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT BCU 18RD 501332058401 222033 7/13/2022 AK E-Line Perf BCU 18RD 501332058401 222033 7/16/2022 AK E-Line GPT Perf BCU 18RD 501332058401 222033 7/23/2022 AK E-Line GPT CIBP Perf BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG END 1-45 500292199100 189124 7/23/2022 AK E-Line Perf END 4-02 500292178900 188022 7/21/2022 AK E-Line Perf HVB B-16 502312004000 212133 6/23/2022 AK E-Line Drift, Plug, Cement IRU 241-01 502832018400 221076 8/5/2022 AK E-Line CBL IRU 241-01 502832018400 221076 8/9/2022 AK E-Line Perf Kalotsa 6 501332068500 219114 7/16/2022 AK E-Line Perf KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift PBU F-26C 500292198703 213045 8/4/2022 AK E-Line Patch/LDL SRU 213-15 501332065200 215100 8/3/2022 AK E-Line GPT Perf Please include current contact information if different from above. T37068 T37069 T37069 T37069 T37070 T37070 T37071 T37072 T37073 T37081 T37081 T37074 T37075 T37076 T37077 T37078 KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.30 12:44:16 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220902 Well API #PTD #Log Date Log Company Log Type Notes AOGCC Eset # END 3-11 50029218480000 188087 8/1/2022 Halliburton CALIPER + Report KALOTSA 4 50133206650000 217063 7/18/2022 Halliburton PPROF + Processing KBU 22-06Y 50133206500000 215044 7/14/2022 Halliburton PPROF + Processing KTU 24-06H 50133204900000 199073 7/21/2022 Halliburton PPROF + Processing KU 24-05B 50133206830000 219072 7/20/2022 Halliburton PPROF + Processing MPU C-24A 50029230200100 209134 7/28/2022 Halliburton COIL FLAG MPU I-17 50029232120000 204098 7/19/2022 Halliburton FREEPOINT NS-10 50029229850000 200182 7/23/2022 Halliburton CALIPER + Report NS-32 50029231790000 203158 7/24/2022 Halliburton CALIPER + Report PBU 18-02C 50029207620300 213009 7/14/2022 Halliburton CAST/CBL PBU C-10B 50029203710200 211092 7/15/2022 Halliburton PPROF + Processing PBU L5-03 50029236230000 219033 7/25/2022 Halliburton PPROF + Processing Please include current contact information if different from above. 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: __________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,960 feet 8,484 feet true vertical 8,744 feet N/A feet Effective Depth measured 8,455 feet 5,859 feet true vertical 8,426 feet 5,859 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 6,944' 6,943' 5,859' MD Packers and SSSV (type, measured and true vertical depth)AS1-X Packer N/A 5,859' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 321-505 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 843 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 72 Ryan Rupert ryan.rupert@hilcorp.com 777-8503 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 20 2251,004 0 67 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 130' 1,493' 225 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-073 50-133-20490-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028142 Kenai / Beluga/Upper Tyonek Gas Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Kenai Tyonek Unit 24-06H measuredPlugs Junk measured N/A Length 130' 1,493' Size Conductor Surface Intermediate 20" 13-3/8" 9-5/8" Production Liner 5,300' 8,830' Casing 130' 1,493' 5,299' 8,674' 5,300' 8,830'7" 3,090psi 5,410psi 1,530psi 5,020psi 5,750psi 7,240psi Burst Collapse 5,020psi 2,260psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 7:59 am, Oct 28, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.10.27 13:36:09 -08'00' Dan Marlowe (1267) SFD 10/28/2021 DSR-10/28/21BJM 11/2/21 RBDMS HEW 10/28/2021 Rig Start Date End Date E-Line 9/30/21 Future Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 10/02/2021 - Saturday No activity to report. 10/04/2021 - Monday No activity to report. No activity to report. 10/03/2021 - Sunday No activity to report. 09/29/2021 - Wednesday No activity to report. 09/30/2021 - Thursday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3000 psi high. RIH w/gun 1 gas, 2-3/8' x12' HC, 6 spf, 60 deg phase and tie into CBL log. Run correlation and send to town. Said to ad 10'. Added 10' and spotted shot from 6914' to 6925' w/66.9/8882K, 5 min - 67.5/882.2K, 10 min - 67.1/910.8K and 15 min - 66.7psi/878K All shots fired/gun wet, RIH w/gun 2 gas, 2-3/8' x10' HC, 6 spf, 60 deg phase and tie into CBL log. Run correlation and send to town. On depth spot and fire gun from 6335' to 6345 with 67.9/9'28.7K. After 5 min - 68.5/962K, 10 min - 67.9/959K and 15 min - 67, 8/982.6K. POOH. All shots fired. Gun wet. RIH w/gun 3 gas, 2-3/8' x11' HC, 6 spf, 60 deg phase and tie into CBL log. Run correlation and send to town. Told to subtract 2.' Subtract 2' and spot and fire gun from 5934' to 5945' w/67. /957K, 5 min - 68./962K, 10 min - 67.9/959K and 15 min - 67.6/924K. Rig down lubricator and equipment. 10/01/2021- Friday 6335' to 6345 5934' to 5945' 6914' to 6925' w Rig Start Date End Date E-Line 9/30/21 Future Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 10/05/2021 - Tuesday No activity to report. Size Type Wt Grade Conn. ID Top Btm 20" Conductor 113 K-55 Surf 130' 13-3/8" Surf Csg 68 L-80 BTC 12.415" Surf 1,493' 9-5/8" Intermediate 40 L-80 BTC 8.835" Surf 5,300' 7" Prod Csg 26 & 29* L-80 BTC & Hydr 6.059* Surf 8,830' 3-1/2" Tubing 9.3 L-80 2.992" Surf 6,944' Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status MB_8 5,934' 5,945' 5,933' 5,944' 11' 9/30/2021 Open LB_1X 6,034' 6,047' 6,038' 6,051' 13' 6/23/2020 Open LB_2 6,335' 6,345' 6,334' 6,344' 10' 9/30/2021 Open LB_2E 6,577' 6,599' 6,575' 6,597' 22' 8/15/2020 Open LB_3B 6,672' 6,689' 6,671' 6,688' 17' 8/15/2020 Open LB_4 6,792' 6,801' 6,790' 6,799' 9' 8/15/2020 Open LB_4C 6,914' 6,925' 6,913' 6,924' 11 9/30/2021 Open LB_5B 7,059' 7,072' 7,058' 7,071' 13' 7/27/2020 Open TY_72_8 7,199' 7,215' 7,198' 7,214' 16' 6/20/2020 Open TY_73_1 7,243' 7,257' 7,241' 7,255' 14' 6/20/2020 Open UT_1B 7,380' 7,388' 7,379' 7,387' 8' 6/20/2020 Open TY_75_8 7,512' 7,533' 7,512' 7,533' 21' 7/27/2020 Open TY_84_6C 8,421' 8,439' 8,397' 8,415' 18' 7/27/2020 Open Revised by DH 10-26-21 PERFORATION DETAIL CASING DETAIL CEMENT DETAIL 12-1/4" Hole: 193bbls (540sxs) of 12.9ppg lead and 48bbls (235sxs) of 15.8ppg tail pumped. Did not bump plug. Volumetric ToC at 1372' MD with 10% washout. 9-5/8" 7"8-1/2" Hole: 134bbls (640sxs) 15.8ppg Class G cement pumped. 6/3/20 CBL: Solid cement up to 5780' MD. Patchy cement up to 5080' MD. 13-3/8"17-1/2" Hole: 246bbls pumped (580sxs) 12.0ppg Class G cement. 40bbls (94sxs) back to surface. Permit #:199-073 API #:50-133-20490-00-00 Prop. Des:FEDA - 028142 KB elevation:87' (21' AGL) TD:7/30/2000 KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Jewelry 5,859' MD - 7" x 3-1/2" AS1-X Pkr 6/7/20 6,943' MD - WLEG/Mule Shoe Btm SCHEMATIC TD 10,960' MD 8,744' TVD Tyonek D-16" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP ~7,600 MD PBTD 8,455' MD 8,426' TVD Tyonek D-1 Coal CIBP @ 8,484' MD w/ 29' Cement - TOC @ 8,455' 6/3/20 Cement plug in pilot hole LB-1X LB-2E LB-3B LB-4 LB-5B TY72-8 TY73-1 UT-1B TY75-8 TY84-6C DANGER: WLEG 2-3/8" x 10' guns got stuck and SL recovered 8/15/2020 MB-8 LB-2 LB-4C OpenLB_2 6,335' 6,345' 6,334' 6,344' 10' 9/30/2021 OpenMB_8 5,934' 5,945' 5,933' 5,944' 11' 9/30/2021 pp LB_4C 6,914' 6,925' 6,913' 6,924' 11 9/30/2021 Open 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: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 24-06H (PTD 199-073) Perf 09/30/2021 Please include current contact information if different from above. 37' (6HW Received By: d 10/25/2021 By Abby Bell at 12:23 pm, Oct 25, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___N2____ 2. Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 199-073 3. Address: Stratigraphic Service 6. API Number: 50-133-20490-00-00 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): 10,960'N/A Casing Collapse Structural Conductor 5,020psi Surface 1,540psi Intermediate 3,810psi Production 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: 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 8,674'8,120psi ryan.rupert @hilcorp.com AS1-X Packer; N/A 5,859' MD / 5,859' TVD; N/A Perforation Depth TVD (ft): Tubing Size: 8,744'8,455'8,426'~2,945psi 8,484' COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Kenai Tyonek Unit (KTU) 24-06H FEDA028142 Kenai Gas Field / Upper Tyonek - Beluga Gas Pool Length Size 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY L-80 TVD Burst 6,943' MD 6,330psi 1,530psi 3,990psi 130' 1,493' 5,299' 130' 1,493' 5,300' 20" 13-3/8" 130' 9-5/8"5,300' 1,493' Perforation Depth MD (ft): See Attached Schematic 8,830' 7" 8,830' 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: October 9, 2021 3-1/2" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:56 am, Sep 24, 2021 321-505 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.23 15:40:08 -08'00' Taylor Wellman (2143) 10-404 SFD 9/26/2021 DSR-9/27/21BJM 9/28/21 *Beluga/Upper Tyonek Gas Pool. SFD 9/26/2021 * dts 9/29/2021 JLC 9/29/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.29 10:34:42 -08'00' RBDMS HEW 9/30/2021 Well: KTU 24-06H Date: 9/23/2021 Well Name:KTU 24-06H API Number:50-113-20490-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:199-073 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Max. Expected BHP:~ 3787 psi @ 8,415’ TVD Based on 0.45psi/ft normal gradient Max. Potential Surface Pressure ~ 2945 psi Based on 0.1psi/ft gas gradient to surface Well Summary KTU 24-06H is a steady gas producer in the Beluga/Upper Tyonek Pool. It flows at ~800mcfd andonly occasional water production. Given the opportunityin unperf’d sands below the production packer,additional perforations are proposed below. The goal of this project is to perforate additional sands within the same pool, to add production to the well Notes Regarding Wellbore Condition x Min ID = 2.867” (4-1/2” drift ID) x Inclination o Max = 33 degrees at 8455’ MD (PBTD) o No deviation until below 7950’ MD x Drifts o 8/20/20: SL fished for 5 days to recover EL toolstring Had issued pulling fish through WLEG as well, and left SL fish downhole All ultimately recovered o 8/15/20: EL perf’d 3 intervals through the tubing tail with 2-3/8” guns up to 22’ long. Initial 2-3/8” x 9’ gun and logging assembly exited the tubing tail for correlation but couldn’t reenter the tubing tail. BHA pulled out of the weak point and fish left downhole. o 7/27/20: EL perf’d 3 intervals below the tubing tail with 2-3/8” guns up to 21’ long.Multiple runs had issues at the WLEG. o 7/19/20: SL D&T with a 2.25” x6’ DD bailer. Tagged at 8400’ MD. No issues o 6/23/20: GPT log found fluid at 7965’ MD EL perf’d 1 interval through the tubing tail with a 2-3/8” x 13’ gun o 6/20/20: EL perf’d 3 intervals below the tubing tail with 2-3/8” guns up to 14’ long (6 total runs with no issues) o June-2020: RWO to plug barefoot lateral and run 3-1/2” tubing o perforate additional sands within the same pool, e Beluga/Upper Tyonek Pool. Well: KTU 24-06H Date: 9/23/2021 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 E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3,500 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. RIH and drift tubing to PBTD. Take care when passing through WLEG 7. Rig up perf gun (Likely 2-3/8” 4-6 spf) 8. RIH and perforate the sand listed in the table below, per Geo/RE a) Evaluate risk of deepest gun (below WLEG) b) Perfs below WLEG may be shot with only CCL c) Critical to NOT drop below WLEG for upper 3 perf intervals Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) MB_8 ±5,934'±5,945'±5,934'±5,945'11' LB_2 ±6,335'±6,345'±6,334'±6,344'10' LB_4C ±6,914'±6,926'±6,913'±6,925'12' LB_5A ±7,005'±7,016'±7,004'±7,015'11' 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. Trudi Hallett (RE): 301-6657 ii. Ben Siks (Geo): 229-0865 9. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Size Type Wt Grade Conn. ID Top Btm 20" Conductor 113 K-55 Surf 130' 13-3/8" Surf Csg 68 L-80 BTC 12.415" Surf 1,493' 9-5/8" Intermediate 40 L-80 BTC 8.835" Surf 5,300' 7" Prod Csg 26 & 29* L-80 BTC & Hydr 6.059* Surf 8,830' 3-1/2" Tubing 9.3 L-80 2.992" Surf 6,944' Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status LB_1X 6,034' 6,047' 6,038' 6,051' 13' 6/23/2020 Open LB_2E 6,577' 6,599' 6,575' 6,597' 22' 8/15/2020 Open LB_3B 6,672' 6,689' 6,671' 6,688' 17' 8/15/2020 Open LB_4 6,792' 6,801' 6,790' 6,799' 9' 8/15/2020 Open LB_5B 7,059' 7,072' 7,058' 7,071' 13' 7/27/2020 Open TY_72_8 7,199' 7,215' 7,198' 7,214' 16' 6/20/2020 Open TY_73_1 7,243' 7,257' 7,241' 7,255' 14' 6/20/2020 Open UT_1B 7,380' 7,388' 7,379' 7,387' 8' 6/20/2020 Open TY_75_8 7,512' 7,533' 7,512' 7,533' 21' 7/27/2020 Open TY_84_6C 8,421' 8,439' 8,397' 8,415' 18' 7/27/2020 Open Revised by CRR 9-22-21 12-1/4" Hole: 193bbls (540sxs) of 12.9ppg lead and 48bbls (235sxs) of 15.8ppg tail pumped. Did not bump plug. Volumetric ToC at 1372' MD with 10% washout. 9-5/8" 7"8-1/2" Hole: 134bbls (640sxs) 15.8ppg Class G cement pumped. 6/3/20 CBL: Solid cement up to 5780' MD. Patchy cement up to 5080' MD. 13-3/8"17-1/2" Hole: 246bbls pumped (580sxs) 12.0ppg Class G cement. 40bbls (94sxs) back to surface. PERFORATION DETAIL CASING DETAIL CEMENT DETAIL Permit #:199-073 API #:50-133-20490-00-00 Prop. Des:FEDA - 028142 KB elevation:87' (21' AGL) TD:7/30/2000 KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Jewelry 5,859' MD - 7" x 3-1/2" AS1-X Pkr 6/7/20 6,943' MD - WLEG/Mule Shoe Btm SCHEMATIC TD 10,960' MD 8,744' TVD Tyonek D-16" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP ~7,600 MD PBTD 8,455' MD 8,426' TVD Tyonek D-1 Coal CIBP @ 8,484' MD w/ 29' Cement - TOC @ 8,455' 6/3/20 Cement plug in pilot hole LB-1X LB-2E LB-3B LB-4 LB-5B TY72-8 TY73-1 UT-1B TY75-8 TY84-6C DANGER: WLEG 2-3/8" x 10' guns got stuck and SL recovered 8/15/2020 Size Type Wt Grade Conn. ID Top Btm 20" Conductor 113 K-55 Surf 130' 13-3/8" Surf Csg 68 L-80 BTC 12.415" Surf 1,493' 9-5/8" Intermediate 40 L-80 BTC 8.835" Surf 5,300' 7" Prod Csg 26 & 29* L-80 BTC & Hydr 6.059* Surf 8,830' 3-1/2" Tubing 9.3 L-80 2.992" Surf 6,944' Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status MB_8 ±5,934' ±5,945' ±5,934' ±5,945' 11' TBD Proposed LB_1X 6,034' 6,047' 6,038' 6,051' 13' 6/23/2020 Open LB_2 ±6,335' ±6,345' ±6,334' ±6,344' 10' TBD Proposed LB_2E 6,577' 6,599' 6,575' 6,597' 22' 8/15/2020 Open LB_3B 6,672' 6,689' 6,671' 6,688' 17' 8/15/2020 Open LB_4 6,792' 6,801' 6,790' 6,799' 9' 8/15/2020 Open LB_4C ±6,914' ±6,926' ±6,913' ±6,925' 12' TBD Proposed LB_5A ±7,005' ±7,016' ±7,004' ±7,015' 11' TBD Proposed LB_5B 7,059' 7,072' 7,058' 7,071' 13' 7/27/2020 Open TY_72_8 7,199' 7,215' 7,198' 7,214' 16' 6/20/2020 Open TY_73_1 7,243' 7,257' 7,241' 7,255' 14' 6/20/2020 Open UT_1B 7,380' 7,388' 7,379' 7,387' 8' 6/20/2020 Open TY_75_8 7,512' 7,533' 7,512' 7,533' 21' 7/27/2020 Open TY_84_6C 8,421' 8,439' 8,397' 8,415' 18' 7/27/2020 Open Revised by CRR 9-22-21 12-1/4" Hole: 193bbls (540sxs) of 12.9ppg lead and 48bbls (235sxs) of 15.8ppg tail pumped. Did not bump plug. Volumetric ToC at 1372' MD with 10% washout. 9-5/8" 7"8-1/2" Hole: 134bbls (640sxs) 15.8ppg Class G cement pumped. 6/3/20 CBL: Solid cement up to 5780' MD. Patchy cement up to 5080' MD. 13-3/8"17-1/2" Hole: 246bbls pumped (580sxs) 12.0ppg Class G cement. 40bbls (94sxs) back to surface. PERFORATION DETAIL CASING DETAIL CEMENT DETAIL Permit #:199-073 API #:50-133-20490-00-00 Prop. Des:FEDA - 028142 KB elevation:87' (21' AGL) TD:7/30/2000 KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Jewelry 5,859' MD - 7" x 3-1/2" AS1-X Pkr 6/7/20 6,943' MD - WLEG/Mule Shoe Btm PROPOSED SCHEMATIC TD 10,960' MD 8,744' TVD Tyonek D-16" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP ~7,600 MD PBTD 8,455' MD 8,426' TVD Tyonek D-1 Coal CIBP @ 8,484' MD w/ 29' Cement - TOC @ 8,455' 6/3/20 Cement plug in pilot hole LB-1X LB-2E LB-3B LB-4 LB-5B TY72-8 TY73-1 UT-1B TY75-8 TY84-6C DANGER: WLEG 2-3/8" x 10' guns got stuck and SL recovered 8/15/2020 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/29/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 24-06H (199-073) 7” CBL 06/03/2020 Please include current contact information if different from above. Received by the AOGCC 09/29/2020 PTD: 1990730 E-Set: 34008 Abby Bell 09/29/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Plug Lateral Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,960 feet 8,484 feet true vertical 8,744 feet N/A feet Effective Depth measured 10,960 feet 9,108 feet true vertical 8,744 feet 8,720 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Cap String 2205 Stainless Steel 9,806' MD Tubing (size, grade, measured and true vertical depth) Tie-back 4-1/2" L-80 9,108' MD 8,720' TVD Packers and SSSV (type, measured and true vertical depth) Baker FKA-1; N/A 9,108' MD 8,720' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 130' 1,493' 10,960' 4 Oil-Bbl measured true vertical Packer 4-1/2" 6" Open Hole 9,108' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Upper Tyonek - Beluga Gas PoolN/A measured TVD Tubing Pressure 00 Kenai Tyonek Unit (KTU) 24-06H N/A FEDA028142 5,300' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-073 50-133-20490-00-00 4. Well Class Before Work: 5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-199 170 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 10 Authorized Signature with date: Authorized Name: 250 Casing Pressure Production 2,130' 1,401 8,744' 0 Representative Daily Average Production or Injection Data 5,300' 9,108' Conductor Surface Intermediate Production Casing Structural 20" 13-3/8" 9-5/8" Length 130' 1,493' Collapse 5,020psi 1,540psi 3,810psi N/A 7,500psi 7,020psi 1,530psi 8,440psi 130' 1,493' 5,299' 8,720' 6,330psi 3,990psi 8,674' 8,120psi todd.sidoti@hilcorp.com Senior Engineer: Senior Res. Engineer: N/A Burst Intermediate 8,830' 7" 8,830' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:19 pm, Sep 11, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.11 14:18:32 -08'00' Taylor Wellman gls 9/18/20 DSR-9/15/2020 RBDMS HEW 9/14/2020 Rig Start Date End Date Rig 401 5/25/20 8/15/20 05/26/2020 - Tuesday Hold PJSM and pre spud meeting. Check well pressure, bleed gas off tubing to zero. No pressure on annulus. Pump down tubing 110bbls of production water. Monitor well to ensure static. Set BPV, Disconnect pressure temp gauge wire. Check lock down screws and remove tree. N/U 13-5/8" BOP stack w/ 11" adapter. R/U accumulator hoses and mud cross. Function and test same. M/U 2-7/8" test jt. RIH and screw into hanger with same. fill up testing equipment with H2O and pre-test BOP and choke manifold 250 psi low - 4,000 psi high. Bleed off pressure and secure well for the night. 05/25/2020 - Monday Hold PJSM, level pad and spot containmet for rig package. Spot rig componets. R/U circulating system. Scope up mast and R/U guy wires. R/U bleed tank, bleed off the well. Tie in electrical components. Clean up location. 05/27/2020 - Wednesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 Perform PJSM for testing BOP. AOGCC waived witness. Fill the stack and begin testing BOP w/ 2-7/8" test jt and 4-1/2" test jt. from 250 low-4,000 psi high, test good. Annular test from 250psi - 2,500psi, good test. Complete draw down test. Total Safety performed test of H2S and LEL sensors, test good. R/D test equipment. Remove test plug and M/U landing jt. and screw into hanger. Back out lock down screws w/ NOS rep. P/U 2' and unseat hanger, shut pipe rams and test casing, test casing 4-1/2" X 7" to 2,000 psi for 30min w/ no loss. Bleed down pressure. R/U AK Eline w/ lubricator and test same. RIH w/ 3.50" jet cutter, tagged up at 8,440'. Attempt to work through tight spot to 8,448', not able to get down to 8,500'. Descision was made to POOH and run slickline in the morning. POOH and R/D E-line. Secure well for the night. 05/28/2020 - Thursday Perform PJSM and pre-spud w/ new crew. R/U Pollard slickline. Make run w/ 3" bailer and tag up at 8,452', worked the bailer and POOH recovering 1/2 gal of sand/mud. Make second run with pump bailer and had same results, discuss with engineers in town, decision was made to POOH and rig down slickline, back out landing jt. and lay down. R/U 2-7/8" PH6 handling equipment. Make up BHA#1, strap and tally 278 jts. Picked up 20 jts. 2-7/8" PH6 from pipe handler and RIH with BHA #1. Break circulation. Continue RIH t/ 3,600" and secure well for the night. 05/29/2020 - Friday Perform PJSM. Check well for pressure, zero pressure. Cont. P/U 2-7/8" workstring from 3,500 - 8,422'. M/U circ. hose, break circulation at 2bbl/min @ 1,000 psi. P/U weight 46K S/O weight 46K. Circulate for 20 min. slack off and tag fill @ 8,453'. Cont. wash down t/ 8,484' w/ Rig 401 RKB. P/U final single and cont. wash down t/8,500'. Circulate bottoms up at 2bbls/min @ 1,000psi. Insure well is static, L/D single and POOH 20 stands, racking pack 2-7/8" workstring. PJSM for testing BOP. AOGCC waived witness. 8,453'. Cont. wash down t/ 8,484' w/ Rig 401 RKB. and unseat hanger, shut pipe rams and test casing, test casing 4-1/2" X 7" to 2,000 psi for 30min w/ no loss. Rig Start Date End Date Rig 401 5/25/20 8/15/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 05/30/2020 - Saturday PJSM Check well pressure. All good. Continue POOH and Standing back 2-7/8" W.S. L/D BHA # 1 and R/D tongs and M/U 4-1/2" tubing Equipment, P/U 4-1/2" landing joint and screw in to hanger. PJSM w/ Pollard E-line crew and R/U lubricator, test 1,000 psi with 3.50 Jet cutter. RIH w/ CCL -3.5 jet cutter t/ 6,500' lost power to CCL. POOH. Slip 450' E.L. cable. Re-head and test same. OK. RIH # 2 w/ 3.5 jet cutter. Tag up at 8,510', CCL lost power again, worked and discussed with engineer. Decision was made to go ahead and cut @ 8,506', set slips at 100k, after cut 80k. POOH w/ e-line circulate bottoms up @ 3bbl/min 350psi. Monitor well and R/D E-line. pulled out of slips, pipe is free. land hanger, secure well for the night. 05/31/2020 - Sunday Hold PJSM, check well bore pressure and service rig. P/U, lay down Hanger. Disconnect control lines. inspect hanger and ship out with NOS. R/U 7/16" braded cable and control line to spooler, adjust pipe handler to fit range 3 tubing. Cont. POOH. L/D 4-1/2 12.6# IBT tubing. L/D SSSV and 4,000' of tubing. Displacing 4 bbls/20 jts. Secure well for the night. 06/01/2020 - Monday Hold PJSM, service the rig, and check well bore pressure. Cont. POOH 4-1/2" production tubing, L/D total of 205 jts, sssv, pressure gauge valve, cut pup jt. retrieve 299 clamps, 22 cannon clamps. Clean up floor. Noticed there was some SS clamps in the well head. R/U slickline magnet and recover 16 SS clamps out of well head. Decision was made to RIH w/ 5.90" gauge ring junk basket. RIH tag @ 8,520', POOH, recovered 3 SS bands. R/D slickline and secure well for the night. 06/02/2020 - Tuesday Hold PJSM, check well for pressure. R/U to run BHA #2 clean out assm. RIH w/ 2-7/8" work string from derrick t/ 8,510', no issues, spot 7' Casing scraper @ 8,508, M/U head pin and reverse circ. 3bbl @ 700psi. No issues. R/D head pin, POOH standing back work string. L/D BHA #2 Clean up Rig and Prep for BOP testing secure well for the night 06/03/2020 - Wednesday Hold PJSM, check well for pressure. M/U 2-7/8" and 3-1/2" test jt. R/U test equipment. AOGCC waived witness by Jim Riggs. Begin testing BOP's to 250 low - 4,000 high, Annular from 250 low - 2,500 high. Draw down was good. Tested all H2S and LEL sensors. R/D test equipment. Test 7" casing to 2,000 psi and chart for 30min with no loss. R/U AK-Eline, M/U and P/U CBL, RIH t/ 8,500' and log from 8,450' - 5,250'. Repeat same, all looked good. POOH. send results to ANC. Clarification was given to cont. w/ procedure. P/U Weatherford 7" CIBP. RIH with same t/ 8,500'. P/U, check collars and set and release center of CIBP @ 8,484'. POOH, L/D running tool and P/U cement bailer. Fill Bailer up w/ 29' of cement. RIH t/ top of plug at 8,484'. Dump cement and POOH. R/D e-line and secure the well for the night. 06/04/2020 - Thursday PJSM W/ CREW , CHECK WELL PRESSURE ALL GOOD. M/U 2-7/8" MULE SHOE. RIH W/ 2-7/8" WORK-STRING T/ 8,440'. R/U POLLARD SLICK LINE UNIT, LUBRICATOR TEST SAME 1,000 PSI. ALL GOOD. RIH, START SWAB WELL START OUT W/ 2 SWAB CUPS AND WORK UP TO 4 CUPS TOT FLUID REMOVED FROM WELL BORE 35 BBLS AS OF 06:00 AM. Cont. POOH 4-1/2" production t P/U Weatherford 7" CIBP. RIH with same t/ 8,500' RIH w/ 2-7/8" work string from derrick t/ 8,510', Test 7" casing to 2,000 psi and chart for 30min with no POOH. L/D 4-1/2 12.6# IBT tubing. L/D SSSV and 4,000' of tubing. Decision was made to go ahead and cut @ 8,506', Rig Start Date End Date Rig 401 5/25/20 8/15/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 06/05/2020 - Friday CONITNUE RIH W/ TANDEM SWAB MANDRELS 4 CUPS TOT FLUIDS RECOVER 53 IN 24 HRS. DECISION WAS MADE WE WILL USE NITROGEN IN A LATER DATE. R/D POLLARD SLICK LINE UNIT. R/U CIRCULATING HOSE AND CIRC 300 BBLS AROUND W/ CLAY BRAKE-1,000. ALL GOOD. R/D CIRC EQUIPMENT AND L/D - 7/8' WORK-STRING TOT L/D. SECURE WELL FOR THE NIGHT. 06/06/2020 - Saturday OPEN WELL, WELL STATIC. CONTINUE POOH WITH 201 JTS OF 2-7/8" PH-6 WORK STRING TO SURFACE. L/D 2-7/8" HANDLING TOOLS, P/U 3.5" HANDLING TOOLS, LAY OUT 3.5" RTS-8 PRODUCTION TBG & TALLY SAME. HOLD PJSM WITH WEATHERFORD & RIG PERSONNEL. P/U & TIH WITH WLEG & 36 JTS OF 3.5" TBG, P/U 7" ASX-1 MECHANICAL SET PACKER, CONTINUED P/U & TIH WITH 3.5" 9.3# RTS-8 TBG. TOTAL OF 106 JTS PICKED UP @ 1800 HRS. SECURE WELL SAME. DEPTH = 3,310'. 06/07/2020 - Sunday OPEN WELL, WELL STATIC. CONTINUE P/U & TIH WITH 3.5" 9.3# RTS-8 TBG TO 6,943' GET STRETCH READINGS, P/U WT = 45,000, S/O WT = 43,000, SPACE OUT & INSTALL HANGER. SET PACKER PER WEATHERFORD RECOMENDATION, LAND OUT TBG IN NEUTRAL POSITION, PACKER DEPTH = 5,859.39', EOT = 6,943.51', STRING WT = 44,000 LBS. TOTAL OF 187 JTS ABOVE PACKER. TEST 3.5" X 7" ANNULUS & PACKER TO 2000 PSI ON CHART FOR 30 MINUTES, HELD SAME. L/D HANDLING TOOLS & CLEAR RIG FLOOR, R/D FOSTER TONGS, HAND RAILS, STAIRS, & RIG FLOOR. N/D & REMOVE CHOKE, KILL LINES, 13-5/8" HYDRIL & LAY DOWN SAME. SECURE WELL & WAIT ON DAYLIGHT. 06/08/2020 - Monday N/D & LAY OUT DOUBLE RAM BOP, FLOW CROSS, & ADAPTOR SPOOL. N/U 11" 5M PRODUCTION TREE & TEST SAME TO 250LOW/5,000 HIGH. VOID TEST TO 5K, ALL HELD SAME. R/D ELECTRICAL WIRING, PREP DERRICK TO L/D, R/D PUMP & TANK LINES, ROLL KOOMEY LINES, REMOVE GAS BUSTER. PERFORM DERRICK INSPECTION, SCOPE IN & L/D DERRICK. MOVE RIG TO SOUTH SIDE OF PAD. RIG RELEASED FROM KTU 24-06H @ 1400 HRS. 06/11/2020 - Thursday PTW JSA. MIRU SLB CTU 13 with 1.75" CT. Start BOPE test. Test all Rams and valves 250/4,000 psi. Fill equipment with diesel. Prep CT end for Coil connector. Make up 1.80" roll on coil connector. 06/12/2020 - Friday PTW, JSA with SLB, Cruz Crane op, and Hilcorp Rep Fire equipment. Pick injector head. Make up reverse out BHA assembly. 1-11/18" tool string with reverse out nozzle. Stab on well. PT stack 250/4,000 psi. Open master and swab. Cool down N2. PT N2 lines 250/4,000 psi. RIH with 1.75" CT pumping 1,000 scf/min. Tag PBTD @ 8,466' CTMD. Pick up off bottom to 8,400'. Park at depth and unload well. N2 at surface. Creep in hole and tag PBTD at 8,466' CTMD. N2 to surface. 145 bbls recovered. POOH to surface. close in choke and start pressuring up well bore. Tagged up 2,300 psi WHP. Close master and swab. 2,300 psi SITP. Rig down SLB CTU 13. Mobe equipment to KU 42-12 and spot . 06/19/2020 - Friday Sign in. Mobe to location. Spot equipment and rig up lubricator. TEST 3.5" X 7" ANNULUS & PACKER TO 2000 PSI ON CHART FOR 30 MINUTES, P/U & TIH WITH WLEG &36 JTS OF 3.5" TBG, P/U 7" ASX-1 MECHANICAL SET PACKER, CONTINUED P/U & TIH WITH 3.5" 9.3# RTS-8 TBG. TOTAL OF 106 JTS PICKED UP @ 1800 HRS. SECURE WELL MIT packer casing Rig Start Date End Date Rig 401 5/25/20 8/15/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 06/23/2020 - Tuesday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. RIH w/GPT tool and tie into OHL. Run correlation log. Find fluid level at 7,965'. Send log to town and was on depth. POOH. Halliburton had the only 2- 3/8" perf charges so we rigged down Yellowjacket and have Halliburton come out. Rig down Yellowjacket and wait on Halliburton. PTW and JSA for Halliburton. Rig up equipment and lubricator. PT to 250 psi low and 3,000 psi high. RIH w/ 2- 3/8" x 13' Razor HC, 5 spf, 60 deg phase and tie into CBL log. Run correlation log and send to town. Told to subtract 4' from our correlation log. Subtract 4' and spot and gun from 6,034' to 6,047' with well flowing 196K/52 psi. After 5 min - 1.12 million/117 psi, 10 min - 1.23 million/131 psi and 15 min - 1.39 million/143 psi. POOH. All shots fired/Gun wet w/grey water (Cement colored). Rig down lubricator and turn well over to field. Move equipment to KU 24-32. 06/20/2020 - Saturday PTW and JSA. Rig back up lubricator. PT to 250 psi low and 3,000 psi high. TP - 2,290 psi. RIH w/ 2-3/8" x 8' HC Razor, 5 spf, 60 deg phase and tie into CBL. Run correlation log and send to town. Told to add 15' to correlation log. Added 15' and spotted gun from 7,380' to 7,388' with 1,750 on tubing. Fired gun. Pressure stayed on 1,750 psi for the 15 min. POOH. All shots fired and gun was wet. Gun #1. RIH w/ 2-3/8" x 14' HC Razor, 5 spf, 60 deg phase and tie into Perf Log. Run correlation log and send to town. Got ok to perf from 7,380' to 7,388' with 1,700 on tubing. Spotted and fired gun. After 5 min - 1,740 psi, 10 min 1,740 psi and 15 min - 1,740 psi. POOH. All shots fired and gun was dry. Gun #2 RIH w/ 2- 3/8" x 14' HC Razor, 5 spf, 60 deg phase and tie into Perf Log. Run correlation log and send to town. Got ok to perf from 7,243' to 7,257' with 1,745 psi on tubing. Spotted and fired gun. After 5 min - 1,750 psi, 10 min 1,750 psi and 15 min - 1,750 psi. POOH. All shots fired and gun was dry. Gun #3 RIH w/ 2-3/8" x 18' HC Razor, 5 spf, 60 deg phase and tie into Perf Log. Run correlation log and send to town. Got ok to perf from 7,243' to 7,257' with 1,705 psi on tubing. Spotted and fired gun. After 5 min - 1,705 psi, 10 min 1,705 psi and 15 min - 1,705 psi. POOH. All shots fired and gun was dry. Gun #4 RIH w/ 2-3/8" x 10' HC Razor, 5 spf, 60 deg phase and tie into Perf Log. Run correlation log and send to town. Got ok to perf from 7,205' to 7,215' with 1,500 psi on tubing. Spotted and fired gun. After 5 min - 1,500 psi, 10 min 1,500 psi and 15 min - 1,500 psi. POOH. All shots fired and gun was dry. Gun #5 RIH w/ 2-3/8" x 6' HC Razor, 5 spf, 60 deg phase and tie into Perf Log. Run correlation log and send to town. Got ok to perf from 7,199' to 7,205' with 1,350 psi on tubing. Spotted and fired gun. After 5 min , 10 and 15 min it was 1,350 psi. POOH. All shots fired and gun was dry. Gun #6. Rig down lubricator and turn well over to field. Rig Start Date End Date Rig 401 5/25/20 8/15/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 24-06H 50-133-20490-00-00 199-073 07/27/2020 - Monday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. (Yellowjacket). RIH w/ 2-3/8" x 18' Razor HC, 5 spf, 60 deg phase and tie into CBL log. Run correlation log and send to town. Told to add 16' from our correlation log. Add 16' and spot and and fire gun from 8,421' to 8,439' w/well flowing 622 MCF at 58 psi. Flow and pressure stayed about the same for the first 15 min. POOH. all hots fired and gun was dry. except for somegreasy sand. Also had trouble getting thru WLEG. GEO sent OH Las log. RIH/w 2-3/8" x 21', HC Razor, 5 spf, 60 deg phase and tie into OH Las log. Run correlation log and send to town. Get ok to perf from 7,512' to 7,533 w/633 mcfd at 63 psi. Spotted and fired gun #2. After 15 min - . POOH. All shots fired and gun was wet. Still had trouble at tubing tail. RIH/w 2-3/8" x 13', HC Razor, 5 spf, 60 deg phase and tie into OH Las log. Run correlation log and send to town. Get ok to perf from 7,059' to 7,072' w/647 mcfd at 64 psi. Spotted and fired gun. After 15 min - 759 mcfd at 68 psi. POOH. All shots fired and gun was dry. Flowing at 721 mcfd at 64 psi. Rig down equipment and turn well over to field. Flowing at 721 mcfd at 64 psi. 08/15/2020 - Saturday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. (Yellowjacket) RIH w/ 2-3/8" x 9' Razor HC, 5 spf, 60 deg phase. Drop below tubing tail to get a better correlation with GR. Unable to pull up through tubing tail. Pull out of weak point and leave perf gun BHA stuck in tubing tail. **FISH left in hole: 1" fishing neck, 1-7/16" x 1' cable head, 1-11/16" x 7' weight bar, 2.75" x 6.93' GR/CCL, 2-3/8" x 14.2' perf gun. OAL = 29.13' weight ~ 185 lbs. ** Load a new 9' gun and re-head. Continue with perforating operation. RIH w/ 2-3/8" x 9' Razor HC, 5 spf, 60 deg phase and tie into OH log. Run correlation log and send to town. On depth and perf from 6,792' to 6,801' w/well flowing 550 MCF at 86 psi. POOH. All shots fired, gun was wet. RIH w/ 2-3/8" x 17' Razor HC, 5 spf, 60 deg phase and tie into OH log. Run correlation log and send to town. On depth and perf from 6,672' to 6,689' w/well flowing 767 MCF at 92 psi. POOH. All shots fired, small amount of water in bullnose of gun. Flow increased to 1,525 mcfd @ 111 psi. RIH w/ 2-3/8" x 22' Razor HC, 5 spf, 60 deg phase and tie into OH log. Run correlation log and send to town. On depth and perf from 6,577' to 6,599' w/well flowing 1,550 MCF at 110 psi. POOH. All shots fired, small amount of water. Flow was continuing to increase to ~ 1,800 mcfd and whp = 107 psi when guns were out of the well. RDMO. Turn well over to operations with well flowing. Flowing at 721 mcfd at 64 psi. Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status LB_1X 6,034' 6,047' 6,038' 6,051' 13' 6/23/2020 Open LB_2E 6,577' 6,599' 6,575' 6,597' 22' 8/15/2020 Open LB_3B 6,672' 6,689' 6,671' 6,688' 17' 8/15/2020 Open LB_4 6,792' 6,801' 6,790' 6,799' 9' 8/15/2020 Open LB_5B 7,059' 7,072' 7,058' 7,071' 13' 7/27/2020 Open TY_72_8 7,199' 7,215' 7,198' 7,214' 16' 6/20/2020 Open TY_73_1 7,243' 7,257' 7,241' 7,255' 14' 6/20/2020 Open UT_1B 7,380' 7,388' 7,379' 7,387' 8' 6/20/2020 Open TY_75_8 7,512' 7,533' 7,512' 7,533' 21' 7/27/2020 Open TY_84_6C 8,421' 8,439' 8,397' 8,415' 18' 7/27/2020 Open PERFORATION DETAIL Permit #:199-073 API #:50-133-20490-00-00 Prop. Des:FEDA - 028142 KB elevation:87' (21' AGL) Lat: Long: Spud:6/2/2000 @ 09:00 hrs TD:7/30/2000 Rig Released:8/?/2000 Conductor Pipe 20" K-55 133 ppf Top Bottom MD Surf Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,493' TVD 0' 1,493' 17-1/2" hole cmt w/ 580 sks of Class-G, 12.0 ppg, 94 sks to surface Intermediate #1 Casing 9-5/8" L-80 40 ppf Top Bottom MD 0' 5,300' TVD 0' 5,299' 12-1/4" hole cmt w/ 540 sks 12.9 ppg Class-G Lead & 235 sks of 15.8 ppg Class-G Tail cmt, floats held KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Jewelry 5,859' MD - 7" x 3-1/2" AS1-X Pkr 6/7/20 6,943' MD - WLEG/Mule Shoe Btm TD 10,960' MD 8,744' TVD Tyonek D-1 6" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP PBTD 8,455' MD 8,426' TVD Tyonek D-1 Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Tyonek Unit 24-6H Kenai Peninsula Borough 6,034'-8,439,' 6.4º/ 100' @ 7,600' MD 11/27/2001 Donna Ambruz Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 6,038'-8,415' Open Hole @ 90º RKB:66' (AMSL)21' (AGL) 08/31/20 Intermediate #2 Casing 7" L-80 26 & 29 ppf BTC/Hydril Top Bottom MD 0' 8,830' TVD 0' 8,674' 26# BTC: 0' - 5,384' 29# BTC: 5,384' - 5,926' 29# Hydril: 5,926' - 8,830' 8-1/2" hole cmt w/ 640 sks (134 bbls), floats held CIBP @ 8,484' MD w/ 29' Cement - TOC @ 8,455' 6/3/20 Cement plug in pilot hole LB-1X LB-2E LB-3B LB-4 LB-5B TY72-8 TY73-1 UT-1B TY75-8 TY84-6C SCHEMATIC Tubing String 3-1/2" L-80 9.3 ppf Top Bottom MD 0' 6,944' TVD 0' 6,943' DANGER: WLEG 2-3/8" x 10' guns got stuck and SL recovered 8/15/2020 LB_1X 6,034' 6,047' 6,038' 6,051' 13' 6/23/2020 Open LB_2E 6,577' 6,599' 6,575' 6,597' 22' 8/15/2020 Open LB_3B 6,672' 6,689' 6,671' 6,688' 17' 8/15/2020 Open LB_4 6,792' 6,801' 6,790' 6,799' 9' 8/15/2020 Open LB_5B 7,059' 7,072' 7,058' 7,071' 13' 7/27/2020 Open TY_72_8 7,199' 7,215' 7,198' 7,214' 16' 6/20/2020 Open TY_73_1 7,243' 7,257' 7,241' 7,255' 14' 6/20/2020 Open UT_1B 7,380' 7,388' 7,379' 7,387' 8' 6/20/2020 Open TY_75_8 7,512' 7,533' 7,512' 7,533' 21' 7/27/2020 Open TY_84_6C 8,421' 8,439' 8,397' 8,415' 18' 7/27/2020 Open 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: Plug Lateral 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): 10,960'N/A Casing Collapse Structural Conductor 5,020psi Surface 1,540psi Intermediate 3,810psi Intermediate 7,020psi Production 7,500psi Production N/A 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: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 8,674'8,120psi 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: May 21, 2020 10,960'2,130' Tie-back 4-1/2" 8,744' 9,108' Perforation Depth MD (ft): 5,300' See Attached Schematic 9,108' 6" Open Hole 8,830'7"8,830' 8,720'4-1/2" 20" 13-3/8" 130' 9-5/8"5,300' 1,493' 1,530psi 3,990psi 130' 1,493' 5,299' 130' 1,493' L-80 TVD Burst 9,108' 8,440psi MD 6,330psi Length Size 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 199-073 50-133-20490-00-00 Kenai Tyonek Unit (KTU) 24-06H Kenai Gas Field / Upper Tyonek - Beluga Gas Pool COMMISSION USE ONLY Authorized Name: N/A Tubing Grade: 2205 Stainless Steel Tubing MD (ft): 9,806 See Attached Schematic tkramer@hilcorp.com 8,744'10,960'8,744'~2,795psi N/A Bakerk FKA-1 Permanent; N/A 9,108' MD / 8,720' TVD; N/A, N/A Perforation Depth TVD (ft):Tubing Size: Cap String 3/8" m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.12 10:43:15 -08'00' Taylor Wellman By Samantha Carlisle at 11:05 am, May 12, 2020 320-199 DSR-5/12/2020 Pull Tubing DLB 05/12/2020 Plug Perforations gls X 10-404 gls 5/14/20 Plug Lateral X Perforate rig 401 + 4000 psi BOPE test Comm 5/14/2020 dts 5/14/2020 JLC 5/14/2020 RBDMS HEW 5/15/2020 Well Prognosis Well: KTU 24-06H Date: 5/12/20 Well Name: KTU 24-06H API Number: 50-133-20490-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 5/21/20 Rig: 401 Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 199-073 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Second Call Engineer: Christina Twogood (907) 777-8443 (O) (907) 378-7323 (C) AFE Number Maximum Expected BHP: ~ 3,635 psi @ 8,415’ TVD Based on normal gradient Max. Potential Surface Pressure: ~ 2,796 psi Based on normal gradient minus 0.1 psi/ft gas Gradient Brief Well Summary: KTU 24-06H was drilled and completed in 2001 as an open hole lateral targeting the Tyonek D1 sand. It came online making 10 MMCFD. It produced at a flat 11% decline until mid-2019, when it started producing sand and rocks and eventually died October 2019. The well has cum’d just under 20 BCF of gas and 22 MBW. Objective: The purpose of this workover is to set a plug over the lateral and re-complete up hole. Pre- Sundry Work 1. RU capillary string truck. POOH with 3/8” capillary string spooling up same. RDMO Capillary truck. 2. RU Slickline. Pressure test lubricator to 250 psi low, 3,000 psi high. 3. PU RIH W/ X-plug to 8,518’. Set plug in X-profile. POOH. RDMO SL. 4. RU Pump truck to 4-1/2” X 7 ” Annulus. Load well (Tubing, 4-1/2” tubing X 7” annulus) with produced water. Conduct an MITIA on the 4-1/2” X 7” Annulus to 2,000psi for 30 minutes (on chart). 5. MIRU e-line and pressure control equipment and pump-in sub. PT lubricator to 250 psi low/3,000 psi high. 6. PU Jet cutter for 4-1/2” tubing. TIH W/same to 8,500’. Cut tubing. POOH RDMO E-line. Rig 401 Procedure 7. MIRU 401 Work over rig. 8. ND wellhead, NU BOP and test to 250 psi low & 4,000 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Test rams on 4-1/2” and 2-7/8” test joints. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 9. Circulate well and bleed off any pressure. 10. RU on 4-1/2” tubing string. 11. Pull landing joint to floor and lay down tubing hanger. 12. POOH W/ 4-1/2” tubing string spooling Pressure gauge wire and SSSV Cap line. Conduct an MITIA on the 4-1/2” X 7” Annulus to 2,000psi for 30 minutes (on chart) cut tubing 8500'r 4-1/2” tubing. TIH W/same to 8,500’ The purpose of this workover is to set a plug over the lateral and re-complete up hole. Load well. BOPE test NU BOP and test to 250 psi low & 4,000 psi high, annular to 250 psi low & 2,500 psi high. Circulate well a Well Prognosis Well: KTU 24-06H Date: 5/12/20 13. PU scraper on 2-7/8” WS and clean out well to 8,480’. CBU. POOH W/scraper. 14. PU RIH W/ 7” CIBP on WS to 8,480’ (+/-). Set same. 15. POOH W/ 2-7/8” WS laying down same. 16. RU E-line. Pressure test Lubricator to 3,000 psi high, 250psi low. (Note: No open perfs in the well. 17. PU, RIH W/ CBL in the 7” to 8,450’. Log 7” casing from 8,450’ to 5,300’. 18. PU dump bailer. RIH and Dump 25’ of cement on CIBP (TOC @ 8,455’( +/-)). RDMO E-line. 19. PU RIH With 3-1/2” X 7” Packer completion on 3-1/2“ tubing string. (Note: Space out to land Packer @ 5,850’(+/-) and bottom of tailpipe @ 6,950’ (+/-)). 20. Drop Ball and rod. Pressure up on tubing to set packer as per manufacturer’s setting procedure. 21. Pressure test back side to 2,000 psi on chart for 30 Min. Bleed down pressure. 22. RU Slickline. Pressure test lubricator to 3,000 psi. RIH and retrieve ball and rod. RDMO Slick line. 23. Hang off tubing. ND BOP, NU wellhead and test tree to 5,000 psi. 24. RDMO Rig 401. Coil Tubing Procedure 25. MIRU Coil tubing unit. Pressure test BOP to 4,000 psi. 26. RU Nitrogen. RIH W/ Coil, drop ball, and blow well dry with Nitrogen leaving 2,300 psi on well head. RDMO Nitrogen and CTU. E-line Procedure 27. MIRU E-line. Pressure test lubricator to 250 psi low, 3,000 psi. high. 28. Perforate the following Sand intervals that have good cement behind pipe: Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Comments MB_8 ±5,934' ±5,945' ±5,934' ±5,945' 11' Set Plug below B4 perfing LB_1X ±6,034' ±6,047' ±6,038' ±6,051' 13' LB_2 ±6,335' ±6,345' ±6,334' ±6,344' 10' LB_2E ±6,577' ±6,599' ±6,575' ±6,597' 22' LB_3B ±6,672' ±6,689' ±6,671' ±6,688' 17' LB_4 ±6,792' ±6,801' ±6,790' ±6,799' 9' LB_4C ±6,914' ±6,926' ±6,913' ±6,925' 12' LB_5A ±7,005' ±7,016' ±7,004' ±7,015' 11' LB_5B ±7,059' ±7,072' ±7,058' ±7,071' 13' Set Plug below B4 perfing TY_72_8 ±7,199' ±7,233' ±7,198' ±7,232' 34' TY_73_1 ±7,243' ±7,257' ±7,241' ±7,255' 14' UT_1B ±7,366' ±7,388' ±7,365' ±7,387' 22' TY_75_8 ±7,512' ±7,533' ±7,512' ±7,533' 21' TY_84_6C ±8,421' ±8,439' ±8,397' ±8,415' 18' 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. Middle Beluga _____________ Pressure test back side to 2,000 psi on chart for 30 Min. Set Plug below B4 perfing PU RIH W/ 7” CIBP on WS to 8,480’ (+/-). Set same. Lower Beluga CBL MB_8 ±5,934' ±5,945' ±5,934'±5,945'11' Set Plug below B4 perfing Tyonek ___________ Submit CBL via email to AOGCC TY_72_8 ±7,199' ±7,233' ±7,198'±7,232'34' TY_73_1 ±7,243' ±7,257' ±7,241'±7,255'14' UT_1B ±7,366' ±7,388' ±7,365'±7,387'22' TY_75_8 ±7,512' ±7,533' ±7,512'±7,533'21' TY_84_6C ±8,421' ±8,439' ±8,397'±8,415'18' MIT-IA Well Prognosis Well: KTU 24-06H Date: 5/12/20 c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation (Ben Siks- Geologist, Trudi Hallett – Reservoir Engineer). d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e. The listed Sands are governed by Conservation Order 510A. Comingling of pools is allowed under the same Order. f. Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, then a plug or an isolation patch may be set prior to moving up to the next sand interval. g. The tubing tail may need to be cut and dropped prior to setting isolation plugs to gain access to shallower perf intervals. h. Plugs will be set between pools if required. 29. POOH. RD e-line. 30. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Rig BOP Schematic 4. Coil BOP Schematic 5. Current Well Head Drawing 6. Proposed Well Head Drawing 7. Standard Nitrogen Procedure 8. RWO Sundry Revision Change Form Comingling of pools is allowed under the same Order.Co-mingling allowed 510A.A. The listed Sands are governed by Conservation Order g r Note: SVS safety valve test within 5 days Permit #: 199-073 API #: 50-133-20490-00-00 Prop. Des: FEDA - 028142 KB elevation: 87' (21' AGL) Lat: Long: Spud: 6/2/2000 @ 09:00 hrs TD: 7/30/2000 Rig Released: 8/?/2000 Conductor Pipe 20" K-55 133 ppf Top Bottom MD Surf 130' TVD Surf 130' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,493' TVD 0' 1,493' 17-1/2" hole cmt w/ 580 sks of Class-G, 12.0 ppg, 94 sks to surface Intermediate #1 Casing 9-5/8" L-80 40 ppf Top Bottom MD 0' 5,300' TVD 0' 5,299' 12-1/4" hole cmt w/ 540 sks 12.9 ppg Class-G Lead & 235 sks of 15.8 ppg Class-G Tail cmt, floats held KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Tubing String 4-1/2" L-80 12.6 ppf AB-Mod Butt Top Bottom MD 0' 9,108' TVD 0' 8,720' * Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 w/ round-nose re-entry guide @ 9,108' (91º hole angle) ID = 3.725" no-go, OD = 4-15/16" Promore pressure temp gauge @ 8,482' MD w/ 7/16" OD electric dual armored, seven strand cable TD 10,960' MD 8,744' TVD Tyonek D-1 Sand 6" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP PBTD 10,960' MD 8,744' TVD Tyonek D-1 Coal Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Tyonek Unit 24-6H Kenai Peninsula Borough Open Hole 8,830'-10,960' 6.4º/ 100' @ 7,600' MD 11/27/2001 Mike Sulley Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 8,674'-8,743' Open Hole @ 90º RKB: 66' (AMSL) 21' (AGL) 9/12/2012 X X Intermediate #2 Casing 7" L-80 26 & 29 ppf BTC/Hydril Top Bottom MD 0' 8,830' TVD 0' 8,674' 26# BTC: 0' - 5,384' 29# BTC: 5,384' - 5,926' 29# Hydril: 5,926' - 8,830' 8-1/2" hole cmt w/ 640 sks (134 bbls), floats held Baker CM&U sliding sleeve @ 8,518' w/ X-profile Halliburton safety valve landing nipple @ 1,027' w/ X-profile (ID=3.813") 1/4" , .049" WT control line to surface Cement plug in pilot hole Capillary String 3/8" 2205 Stainless Steel Top Bottom MD Surf 9086' TVD Surf 8720' Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status MB_8 ±5,934' ±5,945' ±5,934' ±5,945' 11' Proposed * LB_1X ±6,034' ±6,047' ±6,038' ±6,051' 13' Proposed TBD LB_2 ±6,335' ±6,345' ±6,334' ±6,344' 10' Proposed TBD LB_2E ±6,577' ±6,599' ±6,575' ±6,597' 22' Proposed TBD LB_3B ±6,672' ±6,689' ±6,671' ±6,688' 17' Proposed TBD LB_4 ±6,792' ±6,801' ±6,790' ±6,799' 9' Proposed TBD LB_4C ±6,914' ±6,926' ±6,913' ±6,925' 12' Proposed TBD LB_5A ±7,005' ±7,016' ±7,004' ±7,015' 11' Proposed TBD LB_5B ±7,059' ±7,072' ±7,058' ±7,071' 13' Proposed * TY_72_8 ±7,199' ±7,233' ±7,198' ±7,232' 34' Proposed TBD TY_73_1 ±7,243' ±7,257' ±7,241' ±7,255' 14' Proposed TBD UT_1B ±7,366' ±7,388' ±7,365' ±7,387' 22' Proposed TBD TY_75_8 ±7,512' ±7,533' ±7,512' ±7,533' 21' Proposed TBD TY_84_6C ±8,421' ±8,439' ±8,397' ±8,415' 18' Proposed TBD PERFORATION DETAIL * Set plug below before perfing Permit #:199-073 API #:50-133-20490-00-00 Prop. Des:FEDA - 028142 KB elevation:87' (21' AGL) Lat: Long: Spud:6/2/2000 @ 09:00 hrs TD:7/30/2000 Rig Released:8/?/2000 Conductor Pipe 20" K-55 133 ppf Top Bottom MD Surf Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,493' TVD 0' 1,493' 17-1/2" hole cmt w/ 580 sks of Class-G, 12.0 ppg, 94 sks to surface Intermediate #1 Casing 9-5/8" L-80 40 ppf Top Bottom MD 0' 5,300' TVD 0' 5,299' 12-1/4" hole cmt w/ 540 sks 12.9 ppg Class-G Lead & 235 sks of 15.8 ppg Class-G Tail cmt, floats held KTU 24-6H Pad 41-7 37' FNL, 4168' FWL Sec. 7, T4N, R11W, S.M. Tubing String Top Bottom 3-1/2" 0' ±6,950' MD 7" x 3-1/2" packer @ ±5,850' MD TD 10,960' MD 8,744' TVD Tyonek D-1 6" Open hole to 10,960' MD TVD = 8,709' - 8,744' KOP PBTD 8,500' MD 8,480' TVD Tyonek D-1 Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Kenai Tyonek Unit 24-6H Kenai Peninsula Borough Open Hole 8,830'-10,960' 6.4º/ 100' @ 7,600' MD 11/27/2001 Donna Ambruz Lease: State: Perf (TVD): Kenai Gas Field Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 8,674'-8,743' Open Hole @ 90º RKB:66' (AMSL)21' (AGL) 5/8/2020 Intermediate #2 Casing 7" L-80 26 & 29 ppf BTC/Hydril Top Bottom MD 0' 8,830' TVD 0' 8,674' 26# BTC: 0' - 5,384' 29# BTC: 5,384' - 5,926' 29# Hydril: 5,926' - 8,830' 8-1/2" hole cmt w/ 640 sks (134 bbls), floats held CIBP w/ ±20' Cement @ ±8500' MD Cement plug in pilot hole MB-8* LB-1X LB-2 LB-2E LB-3B LB-4 LB-4C LB-5A LB-5B* TY72-8 TY73-1 UT-1B TY75-8 TY84-6C ϭϯͲϱͬϴΗϱDKW ,<ϰϬϭZ/' ϭϯͲϱͬϴΗϱD^,&&Z^W,Z/>EEh>Z ϰϱΗd>> ϭϯͲϱͬϴΗϱDEKs>yd>'d͕ϯϭΗd>> Z^^tͬϮͲϳͬϴΗͲϱͲϭͬϮΗDh>d/ZD^/EdKW Z^^tͬ>/EZD^/EKddKD ϭϯͲϱͬϴΗϱDDhZK^^͕ϮϰΗd>> tͬϯ,ϮͲϭͬϭϲΗϱDD's Θϭ,ϮͲϭͬϭϲΗϱD,Z ϭϯͲϱͬϴΗϱD^WZ^WKK>͕ϮϰΗd>> ,<KtE ϭϯͲϱͬϴΗϱD^WZ^WKK>͕ϮϰΗd>> ,<KtE ΕϭϰϴΗdKd>^d<,/',d EEh>Z^dz>KW&>h/^W^͗ ͲϮϯ͘ϱϴŐĂůůŽŶĐůŽƐĞĐŚĂŵďĞƌǀŽůƵŵĞ Ͳϭϳ͘ϰϭŐĂůůŽŶŽƉĞŶĐŚĂŵďĞƌǀŽůƵŵĞ >ydKW&>h/^W^͗ Ͳϱ͘ϭϰŐĂůůŽŶƐƚŽĐůŽƐĞƉĞƌŐĂƚĞ Ͳϰ͘ϴϲŐĂůůŽŶƐƚŽŽƉĞŶƉĞƌŐĂƚĞ Ͳϲ͘ϰϳ͗ϭĐůŽƐŝŶŐƌĂƚŝŽ td,Z&KZ Kenai Gas Field KTU 24-06H 05-08-2020 Casing head, CIW-IC-6, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Casing spool, CIW-MBS lower, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, R-2P bottom prep Tubing head, CIW-MBS upper, 11 5M stdd X 11 5M stdd, w/ 2- 2 1/16 5M SSO Valve, WKM-M, 2 1/16 5M FE, HWO Valve, WKM-M, 2 1/16 5M FE, HWO Adapter, CIW, 11 5M FE X 4 1/16 5M, w/ 9 ¼ seal pocket, ½ npt control line exit BHTA, Otis, 4 1/16 5M FE X 6.5'’ Otis top Valve, swab, CIW-FL, 4 1/16 5M FE, HWO Valve, upper master, CIW-FL, 4 1/16 5M FE, HWO Valve, master, CIW-FL, 4 1/16 5M FE, HWO Valve, safety, 4 1/16 5M WKM w/ air oper Tubing hanger, CIW-CXS, 11 X 4 ½ IBT lift and susp, w/ 4'’ type H BPV profile, ¼’’ non continuous control line, 9 ¼ EN Kenai Gas Field KTU 24-06H 13 3/8 X 9 5/8 X 7 X 4 1/2 13 3/8'’ 9 5/8'’ 7'’ 4 ½’’ TEC wire fed out annulus valve Current Kenai Gas Field KTU 24-06H 05-08-2020 Valve, swab, WKM-M, 3 1/8 5M FE, HWO Valve, upper master, WKM-M, 3 1/8 5M FE, HWO Valve, master, WKM-M, 3 1/8 5M FE, HWO Valve, safety, 3 1/8 5M WKM-M w/ air oper Tubing hanger, CIW-CXS, 11 X 3 ½ IBT lift and susp, w/ 3'’ type H BPV profile, ¼’’ non continuous control line, 9 ¼ EN Casing head, CIW-IC-6, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Casing spool, CIW-MBS lower, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, R-2P bottom prep Tubing head, CIW-MBS upper, 11 5M stdd X 11 5M stdd, w/ 2- 2 1/16 5M SSO Valve, WKM-M, 2 1/16 5M FE, HWO Valve, WKM-M, 2 1/16 5M FE, HWO Adapter, CIW, 11 5M FE X 3 1/8 5M, w/ 9 ¼ seal pocket, ½ npt control line exit Kenai Gas Field KTU 24-06H 13 3/8 X 9 5/8 X 7 X 3 1/2 13 3/8'’ 9 5/8'’ 7'’ 3 ½’’ BHTA, Otis, 3 1/8 5M FE X 6.5'’ Otis top Proposed 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. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well KTU 24-06H (PTD 199-073) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date Imag~'"' 'reject Well History' File Cover I[' je 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL,~~/INDY [] Maps: [] Other items scannable by large scanner ~O~RSlZED (Non-Scannable) ~1/ Logs of various kinds Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~... WINDY Scanning Preparation c~x 30 = _~ BY: BEVERLY ROBIN VINCENT SHERY~~NINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _Z~ YES Stage 2 IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO ReScanned (indtvidua! p,~,qe ~p~ch~/ att~,ntio~J ,.~c~nnincj mmph]~ed) RESCANNEDBT~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Isl Quality Checked 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~l' Q~~ FILE # fem. C.c. ~ LD G<S To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Fax (907) 276-7542 RECEIVED • • STATE OF ALASKA OCT U 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION AOG VC REPORT OF SUNDRY WELL OPERATIONS V 1. Operations Abandon U Repair Well Li Plug Perforations Li Perforate L] Other [-!] Re- install capillary Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ string Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Marathon Alaska Production LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ISI Exploratory ❑ 199 -073 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Nurrer: Kenai, AK 99611 -1949 50- 133 - 20490 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Nqr ber: Federal Lease A028142 Kenai Tyonek Unit 24-6H 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ N/A Kenai Gas Field, Upper Tyonek - Beluga Gas Pool 11. Present Well Condition Summary: Total Depth measured 10,960 feet Plugs measured N/A feet true vertical 8,744 feet Junk measured N/A feet Effective Depth measured 10,960 feet Packer measured 9,108 feet true vertical 8,744 feet true vertical 8,720 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 20" 130' 130' 1,530 psi 5,020 psi Surface 1,494' 13 -3/8" 1,494' 1,494' 3,090 psi 1,540 psi Intermediate 5,300' 9 -5/8" 5,300' 5,300' 6,330 psi 3,810 psi Intermediate 8,830' 7" 8,830' 8,674' 8,120 psi 7,020 psi Production 9,108' 4-1/2" 9,108' 8,720' 8,440 psi 7,500 psi Production 2,130' 6" open hole 8,830'- 10,960' 8,674'4,744' N/A N/A Perforation depth Measured depth 8,830 10,960 feet (open hole) True Vertical depth 8,674 - 8,744 feet Tie -back: 4 -1/2" L-80 .Ap1!lrMD'"" 8,720' TVD Tubing (size, grade, measured and true vertical depth) Capillary: 3/8" 2205 Stainless Steel 9,086' MD 8,720' TVD Packers and SSSV (type, measured and true vertical depth) Packer Baker FA -1 Permanent 9,108' MD 8,720' TVD 12. Stimulation or cement squeeze summary: 2 Intervals treated (measured): SCANNED JAN !r 3 201 Treatment descriptions including volumes used and final pressure: IJ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - 2200 MCFD 2 BWPD • • - 220 psi Subsequent to operation: - 2450 MCFD 6 BWPD - 180 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development IO Service p Stratigraphic ❑ Daily Report of Well Operations Attached 16. Well Status after work: Oil ❑ - Gas 0 WDSPL ❑ Well Bore Diagram attached 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: 312-312 Contact Mike Marini Printed Name Mike Marini Title Production Engineer Signature Q+f. r a c f Phone 907 - 283 -1370 Date 9/26/2012 Form 10-404 Revised 11/2011 e 3DMS OCT 0 8 2012 � zr� 1 /, �/� /0 -g - i� Submit Original Only 1 • / 04 - • . KTU 24 -6H M Permit #: 199 073 Pad 41 -7 MARATND ! API #: 50 -133- 20490 -00 -00 37' FNL, 4168' FWL Prop. Des: FEDA - 028142 Sec. 7, T4N, R11W, S.M. Co nductor Pipe 20" K -55 133 ppf KB elevation: 87' (21' AGL) Tag Bottom Lat. ._. -.. _.. __: �._._- MD Surf 130' Long: TVD Surf 130' Spud: 6/2/2000 @ 09:00 hrs TD: 7/30/2000 Rio Released: 8/ ?/2000 Surface Casi 13 -3/8" L -80 68 ppf BTC Tyg Bottom MD 0' 1,493' TVD 0' 1,493' il 17 -112" hole cmt w/ 580 sks of Class -G, 12.0 ppg, 94 sks to surface Halliburton safety valve landing nipple Intermediate #1 Casing 9-518" L -80 40 ppf @ 1,027' Tog Bottom w/ X- profile (1D= 3.813 ") MD 0' 5,300' 1/4" , .049" WT control line to surface TVD 0' 5,299' 12.1/4" hole cmt w/ 540 sks 12.9 ppg Class -G Lead & 235 sks of 15.8 ppg Class -G Tail cmt, floats held Intermediate #2 Casing 7" L -80 26 & 29 ppf BTC/Hydril Tgg Bottom MD 0' 8,830' TVD 0' 8,674' 26# BTC: 0' - 5,384' 29# BTC: 5,384' - 5,926' 29# Hydril: 5,926' - 8,830' 8 -1/2" hole cmt wl 640 sks (134 bbls), floats held Tubing Strinq 4 -1/2" L -80 12.6 ppf AB -Mod Butt Bottom MD 0' 9,108' AIL TVD 0' 8,720' `Packer tailpipe: 4 -1/2 ", 12.6ppf, L -80, Hydril 521 w/ round -nose re -entry guide @ 9,108' (91° hole angle) ID = 3.725" no-go, OD = 4- 15/16" Capillary String 3/8" 2205 Stainless Steel Promore pressure temp gauge ^ Top Bottom @ 8,482' MD MD Surf 9086' w/ 7/16" OD electric dual armored, TVD Surf 8720' seven strand cable Baker CM &U sliding sleeve Tyonek D Coal w/ X roffile - :: ...:... KOP i., .. , - k *� Y ; Cement „� 6" Open hole to 10,960' MD , „,_. plug in TVD = 8,709' - 8,744' , ' j Tyonek D -1 Sand , pilot hole +i. --t- , b!1 ` - \ -.14,.. 8 "A` - \ TD PBTD 10,960' MD 10,960' MD 8,744' TVD 8,744' TVD Well Name & Number: Kenai Tyonek Unit 24 -6H Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska 1 Country' USA Perforations (MD): Open Hole 8,830'- 10,960' Perf (TVD): 8,674' - 8,743' Angle (a. KOP & Depth: 6.4 °I 100' A 7,600' MD _ Angle (a. Perfs: Open Hole 90° Date Completed: 11/27/2001 Ground Level: 66' (AMSL) 1 RKB:l 21' (AGL) Revised by: Mike Sulley Revision Date: 9/12/2012 • • (j \\ Jl Daily Completion (Onshore) Partner 1.0 : Report Number W ell Name: KENAI TYONEK UNIT 24-6H 9/11/2012 Date of Report Marathon Oil R &M MAINTENANCE State/Province Field Name County our Class Latitude ( °) Longitude ( °) ALASKA KENAI KENAI PENINSULA 60.459406 - 151.246033 BOROUGH Well Configuration Type 'Original B Elevation (m) 'Ground Elevation (m) 'KB round Distance (m) Daily Operations Report Start Date Report End Date WBS Number Daily Field Est Total (Cost) Cum Field Est To Date (Cost) Total WBS Amount (Cost) 9/10/2012 ! 9/11 /2012 IW0.12.26304.EXP.001 1 1,310.00 1,310.00 24 Hr Summary MIRO Pollard mast truck to pull well house. Install tree cap adapter for Cap string Pack - off. 24 Hr Forecast Run cap string in the moming. On Site Supervisor Job Contact Company ( Type Contact# Time Log 1 Start Cum Dur Ops Time End Time Dur (hr) (hr) Phase Ops Code Activity Code Status Trouble Code Can 13:00 13:15 0.25 0.25 SAFETY MTG Hold PJSM. Discuss emergency procedures, alarms, and muster area. Discuss hazards of lifting the well house. 13:15 14:15 1.00 1.25 RURD EQIP MIRU Pollard crane truck. Install lifting slings. Disconnect tubing. Electrician has aready disconnected the power. Lift well house and set aside. RD crane truck. 14:15 15:15 1.00 2.25 RURD PIPE ND our standard Otis tree cap connedtion. NU intemally threaded 4- 1/16" 5000 tree cap. Install cap and guage valve on tree cap. Close swab and tree cap valves. Personnel Log - - Reg Work Tot Wait Time Company Employee Type Note Count Time (hr) : (hr) POLLARD WIRELINE INC crane crew 2 3.00 6.00 CH2MHILL rousta bout 1 1.00 1.00 Tubing Strings Tubing Description !String Max Nominal... , D (mm) 'Weight/Length (kg /m) 'String Grade 1Set Depth (mKB) Casing Strings Csg Des OD (mm) ID Nom Min (mm) Grade Wt/Len (kg/m) Set Depth (mKB) " Set Depth (TVD) (mKB) Centralizers DRIVE PIPE 508.0 K -55 139.887 39.62 39.62 Surface 340.0 K -55 101.195 455.37 455.23 Intermediate 1 244.5 L -80 59.527 1,608.73 1,608.55 Intermediate 2 177.8 L -80 38.692 2,691.38 2,643.77 Report For: 9/11/2012 Report No: 1.0, DFS: 4482.88 Page 1/1 Report Printed: 9/26/2012 III • in.JJ Daily Completion (Onshore) Partner 2.0 : Report Number . Marathon Oil Well Name: KENAI TYONEK UNIT 24-6H 9/12/2012 Date of Report R&M MAINTENANCE State /Province Field Name County Sour Class Latitude r) Longitude (') ALASKA KENAI KENAI PENINSULA 60.459406 - 151.246033 BOROUGH Well Configuration Type [Original K Elevation (m) IGround levation (m) IKB round Distance (m) Daily Operations Report Start Date Date WBS Number Daty Field Est Total (Cost) Cum Field Est To Date (Cost) Total WBS Amount (Cost) 9/11/2012 'Report End 9/12/2012 I WO.12.26304.EXP.001 I 19,101.28 20,411.28 24 Hr Summary MIRU Baker DynaCoil to run 3/8" cap string. Run cap string to 9086'. Land in pack -off. Set BHA at 4300 psi. Pump 31 gals of foamer to displace MEOH. Connect CICM. Adjust POV to 3000 psi. Place well on foamer at 1 gal /day. 24 Hr Forecast Continue flowing well to sales. Well flowing 2.1 MMscff /d @ 202 psi. On Site Supervisor Job Contact Company 1 Type Contact# Time Log Start Cum Dur Ops Time End Time Dur (hr) (hr) Phase Ops Code Activity Code Status Trouble Code Com 07:30 08:15 0.75 0.75 SAFETY MTG Held Safety Meeting. Obtain SWP. Discuss alarms, muster area, and emergency response procedures. Review JSA's and make job assignments. Let's work slow and steady today so nobody gets hurt. 08:15 11:00 2.75 3.50 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. Clean wellhead adapter bushing. Dope and tape bushiing. Install bushing in tree cap adapter. Set operating pressure of FC Valve to 4300 psi. Thread coil thru side of injector assembly. Install Packoff assembly on cap string. Pull test BHA to 500 lbs. 11:00 12:00 1.00 4.50 TEST EQIP Carry injector and pack -off to WH. MU packoff. PT Hydraulic Packoff to 3000 psi. PT WH adapter to 2700 psi. 12:00 15:00 3.00 7.50 RUNPUL COIL Open swab valve. RIH to 9086' md. Cap string setting down and not wanting to go any further. Call Mike M to discuss. Decided that this depth is OK. Begin displacing cap string to foamer. 15:00 17:30 2.50 10.00 RURD COIL Land cap string at 9086' md. Set Ratigun. Set mechanical slips. Set packoff pressure to 3000 psi. Walk injector down off well head. Pull tubing out the side of injector and set coil spool at WH. RD DynaCoil unit. Reconnect tubing to foamer. Prime pumt and pressure test foamer lines. No leaks. Set flow rate at 1 gal /day. 17:30 17:45 0.25 10.25 SECURE ' WELL Secure well head. Install LOTO and signage on well valves. Turn in permit and leave loc. Notify OPs that we have finished. Foamer rate 1 gpd. - Personnel Log Reg Wait - Tot Work Time Company Employee Type Note Count lime (hr) (hr) - BAKER HUGHES INTEQ crane crew 2 12.00 24.00 MARATHON OIL CORP. site supervision 1 12.00 12.00 Tubing Strings Tubing Description String Max Nominal... 11D (mm) 'Weight/Length (kg /m7 'String Grade !Set Depth (mKB) Casing Strings Csg Des OD (mm) ID Nom Min (mm) Grade Wt/Len (kg/m) Set Depth (mKB) Set Depth (TVD) (mKB) Centralizers DRIVE PIPE 508.0 K -55 139.887 39.62 39.62 Surface 340.0 K -55 101.195 455.37 455.23 Intermediate 1 244.5 L -80 59.527 1,608.73 1,608.55 Intermediate 2 177.8 L -80 38.692 2,691.38 2,643.77 Report For: 9/12/2012 Report No: 2.0, DFS: 4483.88 Page 1/1 Report Printed: 9/26/2012 s • w • SUATIE LYLASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mike Marini Production Engineer IV Marathon Alaska Production, LLC 7 P.O. Box 1949 Kenai, AK 99611 -1949 Re: Kenai Gas Field, Upper Tyonek Beluga Gas Pool, Kenai Tyonek 24 -6H Sundry Number: 312 -312 Dear Mr. Marini: 51,4 AUGr 1U1 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, fq--e-- "h"-- Cathy P. Foerster Chair DATED this 22" day of August, 2012. Encl. r i • Marathon Alaska Production LL C NM" Alaska Asset Team P.O. Box 1949 Marathon Oil Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1380 RECEIVED August 8, 2012 AUG 10 2012 Mr. Daniel Seamount AOGCC Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: 1 10>40trRe of Sundry Well Operatiol �i- s Field: Kenai Gas Field Well: Kenai Tyonek Unit 24-6H (PTD 199 -073) Dear Mr. Seamount, We propose to re- install a capillary string in KTU #24 -6H. This equipment will be used to pump foamer into the well and mitigate liquid loading. Please find attached form 10 -403, current wellbore diagram, proposed wellbore diagram and detailed operations program. Please contact me at (907) 283 -1370 if you have any questions or need additional information. Sincerely, s obazt#9,„,,,e Mike Marini Production Engineer Enclosures: 10-403 Sundry Notice cc: Houston Well File Current Well Schematic Kenai Well File Proposed Well Schematic Detailed Operations Program STATE OF ALASKA • � g ` R E C E I V E IP ASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 0 2012 APPLICATION FOR SUNDRY APPROVALS /� 20 AAC 25.280 AOGCC 1. Type of Request: Abandon ❑ Plug for Redd ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other Re- Install capillary string . tri 2. Operator Name: Marathon Alaska Production LLC 4. Current Welt Class: 5. Permit to Drill Number. Development Ei • Exploratory ❑ 199 -073 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number. Kenai Alaska, 99611 -1949 50-133-20490-00-00 ' 7. If perforating, closest approach in pooi(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No D Kenai Tyonek Unit 24-6H 9. Property Designation (Lease Number): l=ei) A - a2bl`LL 10 . FieldIPoot(s): te'�, -T _- `� y �� j l K 37' FNL , R11 W, S.M. / fig + 4 L Kenai Gas Field, P P' A y; .6, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1 ' w%( 8744' 10861' 8744' NA NA Casing Length Size MD TVD Burst Collapse Structural - fL vv Conductor 130' 20" 130' 130' 1530 psi 5020 psi Surface 1494' 13 -318" 1494' 1494' 3,090 psi 1,540 psi Intermediate 5300' 9-518" 5300' 5300' 6330 psi 3810 psi Intermediate 8830' 7" 8830' 8674' 8120 psi 7020 psi Production 9108' 4-112" 9108' 8720' 8440 psi 7500 psi Production 2130' 6" Open Hole 8830'- 10960' 8674' -8744' nla nla Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Capillary 318" 2205 Stainless Steel 10,795' Tie -back 4-112" L-80 9,596' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packers: Baker FA Permanent 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development El Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Au 2012 Oil ❑ Gas Q s. WDSPL ❑ Plugged g9 ❑ 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 Mike Marini (907) 283-1370 Printed Name Mike Marini Title Production Engineer Signatures d Phone (907) 283 -1370 Date August 8, 2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 342. — 34a - Plug integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / 6 "-tie) Y t o APPROVED BY Approved by: /9 COMMISSIONER THE COMMISSION Dale: �3 p - 22 _- G i . r W DMS AUG 2 3 V ORIGLWAL C �� AV AV � e,. rm 10-403 Revised 12/2009 b �� L V c.a in nn mu.... !w / • (TU 24 -6H Pad 41 -7 M Permit #: 199 - 073 37' FNL, 4168' FWL M AW O N API ft: 50- 133 - 20490 -00 -00 Sec. 7, T4N, R11 W, S.M. Prop. Des: FEDA - 028142 Conductor Moe KB elevation: 87' (21' AGL) 20•' K -55 133 ppf Lat: Top Bo ll m MD Surf 130' Long I t TVD Surf 130' Spud: 6/2/2000 @ 09:00 hrs t • • TD: 7/30/2000 Rio Released: 8 / ?/2000 i ,• Surface Casing • , 13.318" L -80 68 ppf BTC _ To° Bo tom _.. _...... ....:... I' MD 0' 1,493' 1, t• TVD 0' 1,493' t 1 X 17 -112" hole cmt wl 580 sks of Class -G, 1 12.0 ppg, 94 sks to surface Halliburton safety valve landing nipple {f • , Intermediate $1 Casing @ 1,027' I 9 -518" L-80 40 ppf Top Bottom w/ X- profile (ID= 3.813"} f• • MD 0' 5,300' 1/4" , .049" WT control line to surface TVD 0' 5,299' ` 12.114" hole cmt wl 540 aks 12.9 ppg Class -G Lead & . 235 aks of 15.8 ppg Cless -G Tell curt. floats held Intermediate $2 Casing ' T• L-80 26 & 29 ppf BTC1Hydr11 Top Bottom t - MD 0' 8,830' TVD 0' 8,674' I 268 BTC: 0' - 5,384' I' - , 298 BTC: 5,384' - 5,926' 298 Hydrll: 5,926• - 8,830' • 5-1/2" hole curt w/ 640 sits (134 hbls), floats held - Tubing String 4-1/2" L-80 12.6 ppf AB -Mod Butt ottom AIL , MD 0' 9,108' „ TVD 0' 8,720' p� t ' Packer tailpipe: 4- 112 ", 12.6ppf, L-80, Hydrll 521 • w/ round -nose re -entry guide 9,10B' (91• hole angle) ID . 3.725" no-go, OD .4-15/16" i • Promore pressure temp gaups (' , 8,482' MD .- w/ 7/16" OD electric dual armored, •`• seven strand cable 1 l - Baker CM &U sliding sleeve L 6,518 : Tyonek D -1 Coal w/ X- profile rofile , 1 I •• !ice . .a KOP - h L it Cement 6° Open hole to 10,960' MD • > `R \ I. plug In \` TVD = 8,709' - 8,744' Tyonek D -1 Sand 1, pilot hole ' , t s a } • 1 ` ` - y • TD PBTD 10,960' MD 10,960' MD 8,744' TVD 8,744' TVD Well Name & Number: Kenai Tyonek Unit 24 -6H Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska 1 Country:I USA Perforations (MD): Open Hole 8,830'- 10,960' Pert (TVD): 8,674'- 8,743' - Angle p KOP & Depth: 6.4 °I 100' A 7,600' MD Angle p Perfs: Open Hole t 90° _ Date Completed: 11/27/2001 Ground Level: 66' (AMSL) 1 RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 8/16/2010 • KTU 24 -6H Proposed CS Re- Install Permit #: 199 -073 1 Pad 41 -7 x 4ARAnt0n API #: 50 -133- 20490 -00 -00 37' FNL, 416$' FWL Prop. Des: FEDA - 028142 Conductor Pipe KB elevation: 87' (21' AGL) I Sec. 7, T4N, R11 W, S.M. 20" K -55 133 ppf Lat: Igo Bottom I M Surf 130' • Long: I ' TVD Surf 130' IL Spud: 6/2/2000 @ 09:00 hrs i t, . f TD: 7/30/2000 Surface Csainq Rig Released: 8/7/2000 i 13 -3/8" L -80 68 ppf BTC To 0 om t_ .. _. _... _.. .. - MD 0' 1,493' L ;. ' . • TVD (' 1,493' ) 17 -112" hole cmt wl 580 aks of Class -G, 12.0 ppg, 94 sks to surface Halllburton safety valve landing nipple lnlermediela 01 Caslnq Q 1,027' ; 9.518" LAW Bottom w1 X- profile (1D= 3.813 ") MD 0' 5,300' 114" , .049" WT control line to surface : 0' 5,299' i. 12 -114" hole cmt wi 540 mks 12.9 ppg Class -G Lead & - - 41 '' 235 sks of 15.8 ppg Class -G Tall cm4 floats held i a Intermediate 02 Casing i 7" L-80 26 & 29 ppf BTC/Hydrtl • 4 Lop Bottom • , MD 0' 8,830' 8 TVD 0' 8,674' ti • 268 BTC: 0' - 5,384' { . -, r 290 BTC: 5,384' - 5,926' S 290 HydrII: 5,926' - 8,830' { .' -. 8 -112" hole cmt w1640 sks (134 bbls), floats held F , 1 �. Tub Str ' 4 -112" L-80 12.6 ppf AB -Mod Butt + Do Bottom h ** + MD 0' 9,108' TVD 0' 8,720' 8 ; • Packer tailpipe: 4 -112 ", 12.6ppf, L-80, Hydrll 521 � , , �� w/ round -nose re -entry guide @ 9,108' (91" hole angle) ID " 3.725" no-go, OD " 4- 15116" h . 4'`. Capillary String - Proposed V- 318" 2205 Stainless Steel promote pressure temp gaups �' Top Bottom @ 8,482' MD 4` MD Surf 9108' wl 7116" OD electric dual armored, �' TVD Surf 8720' seven strand cable l• ■ :_ i Baker CM &U sliding sleeve ` • @ 8,518' 1. w/ X- profile , s Tyonek D -1 Coal r•' KOP , ' ' \ Cement . 6" Open hole to 10,960' MD plug In ' '"�` TVD = 8,709' - 8,744' L,. ; .yonek D -1 Sand ' t, . pilot hole . '•>` TD PBTD 10,960' MD 10,960' MD 8,744' TVD 8,744' TVD Well Name & Number: Kenai Tyonek Unit 24 -6H Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska 1 Country:1 USA Perforations (MD): Open Hole 8,830'- 10,960' Perf (TVD): 8,674'- 8,743' Angle 0 KOP & Depth: 6.4 '1 100' (a? 7,600' MD Angle Ca? Perfs: Open Hole @ 90° Date Completed: 11/27/2001 Ground Level: 66' (AMSL) 1 RKB: [ 21' (AGL) Revised by: Mike Marini Revision Date: 8/08/2012 • * VIP 0 Marathon Oil MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM KTU 24 -6H CS Re- Install Procedure KGF Unit Pad 41 -7 WBS # WO.12.26304.EXP.001 APPROVALS: Mike Marini 8/8/12 Program Writer Well Status: This well is currently showing signs of liquid loading History: KTU 24 -06H: 07/16/10: Pull 1/4" capstring. 11/10/07: Capstring 8861'. 11/08/07: PT. 11/06/07: GR 2.30" tag 8948'. 08/03/00: 4-1/2" completion. 06/03/00: Spud well. Objectives: Re- Install Cap String, restore foamer injection v Resources: Baker Hughes Cap String unit Baker Hughes CICM Procedure: Re -Run Cap String: 1. MIRU DynaCoil unit. Lay drip liners. 2. Check Fluid Control Valve using hand pump. Set new Fluid Control Valve pressure. (Setting TVD 8720)(0.433 psi/ft H2OX1.036 foamer SG) = 3911 psi. Plus 400 psi. Or 4300 psi. 3. Install'/" 5000 psi nipple and valve in port between Rattiguns and hydraulic pack off. 4. Install valve on the end of coil string. KBU 24-6rd Procedure 6/6/12 - 1 - r w . • • 5. P/U Dyna -Coil injector with crane 6. Install rebuilt Pack -off. 7. Install and pull test BHA to 500 lbs.. 8. Lower injector head carefully on to the pack -off (line up slot with the pack - offs' /." x 4" nipple). 9. Attach hydraulic hoses to hydraulic rams and Insert snubbing guides. Prepare to pressure test. 10. Wrap wellhead and pack -off with absorbents to catch drips. Clear wellhead 11. Pressure hydraulic rams (top seal, '/" nipple) on pack -off to 3000 psi. 12. Open Rattiguns all the way. Watch for pressure leaks. 13.Open slips. Monitor weight indicator to ensure injector is holding weight. 14.Adjust hydraulic rams pressure to minimum level (100 — 500 psi). 15.Open swab valve. Watch for leaks at pack -off. 16. Set depth counter to zero. 17.RIH at 100 fpm, to set depth of 9108 feet (8720' TVD) (or new TD based on PT). 18. Set slips. Set Rattiguns. Release pressure on upper hydraulic seal (to protect operator). Watch for leaks. 19. Lift injector head off and away from well. 20. Pressure hydraulic rams (top seal) on pack -off to 2500 psi. Close needle valve and insert hydraulic plug. 21. Pull tubing excess through injector, or split injector head to remove tubing if over 500' of excess coil. 22. Connect tubing to Swagelok injection manifold (valve, gauge, filter, gauge, valve) to CICM line. 23. Lockout Swab, Upper Master, and Lower Master as per Capstring Lockout Procedure and install signage. 24. Pump foamer into capstring until fluid packed (if not already full). 25. Hookup injection line to CICM. Start foamer at previous rate. 26. Replace well house. Be careful of the tubing "bend" as it goes back inside if it extends through the roof. 27. RDMO. Cleanup site. Sign -out. Fill out Well Ops Transfer Sheet. Considerations, Instructions, and Plannino: Power CICM with temporary power until well house can be replaced. Baker Hughes conducted an analysis using CIRCA and Foam Expert. This analysis indicates we will be successful at installing this capstring given the deviation of the well and that foam is a solution to the loading problem. KBU 24 -6rd Procedure 6/6/12 -2- • • ~t-~f ctrt ma~nrNC~M a ~c'~s ~ C LiC~kIC~n ~.. August 16, 2010 l Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Tyonek Unit 24-6H Dear Mr. Aubert: lq Attached far your records is the10-404 Report of Sundry Well Operations for KBU 24-6H well. This report covers the work performed to remove the'/~ capillary string. The capillary string was pulled because it did not prove effective at enhancing water production. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations Well Schematic Operations Summary Marathon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907!283-1371 Fax 907/283-1350 ~~~~ A~~~ ~ ~ ~a~c: e'1(1~El~rd~~' cc: Houston Well File Kenai Well File KJS • STATE OF ALASKA • ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNQRY WELL OPERATIONS ~~ ~ ~ ~ 1 ~~'; E 1.Operations Abandon Repair Well Performed; Plug Perforations Stgnulate - emoved Alter Casin g ^ Pull Tubing^ Perforate New Pool ® Waiver® Time Extensio + ~I"~~1Cplllary String Change Approved Program ^ Operat. Shutdown ^ Perlaarate ® pended Well ^ Re-enter Sus 2.Operator ~~: Marathon Alaska Production LLC 4. Welt Class Before Work: 5. Permft to Drill Number. ~1elOpr"~ Q Exploratory^ ~ 199-073 3. Address: PO Box 1949 Stratigraphic ® Service ^ 6. API Number: Kenai Alaska, 99611-1949 ~' S0-133-20490-00-00 7. Property Designation (Lease Number): ~ 8. WeN Name and Num FEDA - 028142 Kenai T onek Unit 24-6H 9. FiekUPoal(s}: Kenai Gas Field ! Upper Tyonek & Beluga Gas 11. Present Wefl Condition Summary: Total Depth measured 10,960' feet Pkrgs (measured} NA feet true vertical 8,7,44• feet Junk (measured) NA feet Effective Depth measured 10,960' feet Packer (measured} 8,593' feet true vertical 8,744• feet {true vertical} 8,534• feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 130' 130' 1,530 psi 5,020 psi Surface 1,473' 13-3/8" 1,494'. 1,494' 3,090 psi 1,540 psi Intermediate #1 5,279• g_5/g" 5,300' 5,300' 6,330 psi 3,810 psi Intermediate #2 8,819' 7" 8,830' 8,674' 8,120 psi 7,020 psi Liner Pertoration depth: Measured depth: 6" Open hole 8,830'-10,960' True Vertical depth: 6" Open hole 8,674'- 8,743' Tubing (size, grade, MD & TVD): Production: 4-1/2" L-80 9,108' MD 8,720' TVD SSSV: Packers and SSSV (type, MD & TVD): Packers: NA NA MD NA TVD 4-1/2" ' ' 8,593 TVD MD 8,534 11. Stimulation or cement squeeze summary: Intervals treated (measured): The 1/4" capillary string was removed from the wellbore. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2.5 - 427 Subsequent to operation: 0 0 _ - 427 13. Attachments: 14. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Weli Operations X 15. Well Status after work: Oil Gas ~ W DSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Kevin Skiba (907) 283-1371 NA Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone (907) 283-1371 Date August 16, 2010 Aw- __ - Form 10-404 Revised 7/2009 Submit Original Only ~--- a ,~ r C)perations Summar Re rt b J b - , ~t~1 ny Well Name: y po y o KENAI TYONEK UNIT 246H QtrlQtr, ~odc, :seG, Tam. Range Field Name __--- _ KENAE _ ,Lim Pb. StatelProvinoe ~~~~, _ I ALASKA USA Daity Opeeatigns Re Date: 7/1712010 Job Category: R&M MAINTENANCE 24Hr MIRU E}yn i Start Ti,2re 07:30 --- aCoil to pu -- ~ End Fume 08:15 .; ll 114" r.~rp ~ err (hrs} 0.75 string. Re-insta ~ - ;. Ops Code SAFETY ll OTIS 6" Tree - Activity Code MTG Gap. oPS Status - T T.«~~ ,' Cie - - -- -- '. , _ Comment Hold PJSM. Discuss emergency response, alarms-red flashing strobe for fire alarm, blue flashing str~e for gas alarm, muster area, wind direction, ;and specific job hazards. Obtain SW Permit ; 08:15 09:00 0:15 1227 09:00 10:15 2:27 13:33 _ 0.75 1.25 .20 1.10 RURD RURD UNPUL PUMP EOIP COIL OIL TRET . Spot crane. RU equipment. WHause has been disconnected. Remove .WHause and set aside. RD crane unit. 'Spot DynaCoil unit Lay liners and drip pans. RU DynaGoil Unit PU spoof on unit Diconnect foamer line. Thread coil up thru injector assembly. Release Ratigun. Release mechanical slips. Reduce packoff pressure. See hanging string weight of 725 lbs. Cap string pulls free at 900 lbs. POOH - -. OOH. Cut BHA( wobble nose and Check valve) Bteed pressure. Attemp to flush tine w/ MEOH. Line pressure over 4000 psi. Cap string plugs off after only a gallon pumped. Unsuccessful) after several attemps. Cap string Plu99ed- 13:33 14:33 14:33 _ 14:48 1.00 0.25 RURD SECURE COIL ~ WELL _ RD unit. Install OGs 6" Tree Cap. PT to 1300 psi. Test good. Secure well. Tum in Permit Sign out and leave loc. i www.peloton.com Report Printed: 8/12/2010 i FEDA - 02a142 i &T (2[`AGL} 0.~2!2GG`J ~ Off:L~0 hrs ~isa~2ooo sed: 8E?t20~0 Hatliburton safety vahre landing niople ~ 1,027' wf Xprofile (ID=3.813' t14° , .049° t+YT control 8ne to surface Intermediate #2 7" L-80 Casino 26 & 29 ppf BTCAiydnl Toe Bottom MD 0' 8,830' TVD 0' 8,674' 26# BTC: 0' - 5,384' 29#BTC: 5,384' - 5,426' 29# Hydril~ 5,926' - 8,830' '~, 8-1/2" hole Cmt w/ 640 sks (134 hols) floats held TutNno String 4-112" L-80 12.6 ppf AB-Mod Butt Top Bottom MD 0' 9,108' TVD 0' 8,720' Packer tailpipe: 4-112", 12.6ppf, L-80, Hydril 521 w! round-nose re-entry guide @ 9,708' (91" hole angle) ID = 3.725" no-go, OD = 4.15/16" Pram®re preSSUre temp patlpe @ 8,482' MD w! 7116" OD electric dual armored, seven strand cable KTU 24-~H Pad 41-7 3T FNL, 4168` FWL Sec. 7, T4N, R11 W, S.M. JiIIiNIIIL AtARa1TNON CorMuctor Pine 2D° K-55 133 ppf Top Bottom MD Surf 130' TVD Surf 130' Surface Casino t3-3I8" L-80 68 ppf BTC Toe Bo om MD 0' 1,493' TVD 0' tp93' Cmt wl 580 sks of Class-G, t 2.0 ppg, 94 sks to surface kkermediate #1 Casino 9-5f8" L-80 40 ppf TO Bottom MD 0' 5,300' TVD D' 5,299' Cm[ w! 540 sks 12.9 ppg Class-G Lead 8 235 sks of 15.8 ppg Class-G Tail cmt, floats held BakerCM&U sliding sleeve @ 8,518' wl X-profile .. KOP 7,600 MD Cement plug in pilot hole TD _ PBTD 10,960' MD 70,960' MD 8,744' TVD 8,744' TVD 6" Open hole to 10,960' MD TVD = 8,709' - 8,744' Tyonek D-1 Coal ----", ~ ~ ~° ~ ~~;' ~~ x ~~*~~~ Tyonek D-1 Sand ~"' Well Name & Number: Kenai T onek Unit 24-6H Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): Open Hole 8,830'-10,960' Perf (TVD): 8,674'-8,743' Angle ~ KOP & Depths 6.4°/ 100' 7,600' MD Angie %a; Per`s: Open Hate 90° Date Completed: 11/27/2001 Ground Level: 66' (AMSL) RKB: 21' AGL Revised by: Kevin Skiba Revision Date: 8/16/2010 ~c"It`~~lOC1 MARATeo~ ~1~ ~~OiY1~111y ~~r;~AN~~D JUN ~ ~ 2D08 June 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Cannery Loop Unit, Pad 1 Well: Cannery Loop Unit 6 {PTD 200-033j Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 9071283-1350 We propose #o run a 3J8" capillary string in CLU 6. With the availability of a capillary injection unit on the Peninsula starting the week of June 23"~ 2008; we are able to mitigate water loading by running a capillary string and pumping foamers. Setting depth of the capillary string should be around 8020' MD. The past capillary string installation into: '~::'f-073-~1as yielded an approximate incremental gain of 475 MCFD over the past 3 months. We would tike to continue to install capillary strings in other wells like CLU 6 and be able to realize longer and more stable production. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~~. Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File DMD KJS • ALASSA OIL A1~TD GAS COI~SERQA'1`IO1~T COl-II~II55IO1~T Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 Pt-IONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field, Kenai, Beluga/Tyonek Gas Pool, Kenai Tyonek Unit 24-6H Q ~ ~. Sundry Number: 30?-351 Q~~~ ~~~% ~1 C U 2007. Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of November, 2007 Encl. • M Ma~r+a~thon MARATHON C~I~ Company November 13, 2007 Mr. Tom Maunder Alaska OII & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Tyonek Unit 24-6H (PTD 199-073) Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.o. a®x 1 sas Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 We propose to run a capillary string in KTU #24-6H. With the availability of a capillary injection unit on the Peninsula; we are able to mitigate water loading by running a capillary string and pumping foamers. Verbal approval to run this string was given November 9th 2007, this is the follow up 10-403. Please find attached a 10-403, current wellbore diagram, proposed wellbore diagram and detailed operations program. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~`~ Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Detailed Operations Program DMD KJS ~~ N~V ~ ~ ~~107 ORIGINAL Alsslca Oil ~ Gs~ GGn~. C~mr~issio~i An~hnrap~ STATE OF ALASKA /// ~~ i ALASKA O!L AN® GAS CONSERVATION COMMISSION ~i t~~ APPLICATION POR SUNDRY APPROVALS 20 AAC 25280 1 Type o' Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other i Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install 1/4" Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Capillary String 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Develo meet Ex lorato P ^ P rY ^ 199-073- 3, Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611.1949 50-133-20490-00.00 r. It perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No [~] Kenai T onek Unit 24-6H 9. Property Designation: ~ ~ o~~f, jla i 10. KB Elevation (ft): 11. Field/Pool(s): 37' FNL & 4168' FWL, Sec. 7, T4N, R11W, S.M. 21' - Kenai Gas Field, Pad 41-7, Tyonek Pool 12, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,861' 8,744' 10,861' 8; 744' N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 130' 130' 1530 psi 5020 psi Surface 1494' 13-3/8" 1494' 1494' 3090 psi 1540 psi Intermediate 5300' 9-5/8" 5300' 5300' 6330 psi 3810 psi Intermediate 8830' 7" 8830' 8674' 8120 psi 7020 psi Production 2031' 6" open hole 8830'-10960' 8674'-8743' N/A N/A Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4-1 /2" L-80 9108' Packers and SSSV Type: Baker Model FA-1 Permanent Packer Packers and SSSV MD (ft): 8595' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Navember 9, 2007 Oil ^ Gas ~ Plugged ^ Abandoned ^ 17, Verbal Approval: p,^;~<,~,cy r~'~a\ ~ v Date: 11/9/2007 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Commissioner Seamount 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M D novan Title Production Engineer I Signature Phone 907-283-1333 (W) 907- Date 398-1362 (Cell) 11/13/2007 COMMISSION USE ONLY Conditions oval: Notif f a Commi i n th t t ti it S ~ ~ T ~ J~ ppr y o ss o so a a represen a ve may w ness undry Number: 6 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~~~~ rel~,=° ~ 200 Subsequent Form Required: ~„~,~~i APPROVED BY Approved by: OMMISSI®NER THE COMMISSION Date: ~ZD ~D Form 10-403 Revised 06/2006 Submit in Duplicate `" U~I~IIVI~L - • • KB=87 feet GL-fis tee, KTU 24-6h Tyonek D-1 Sand Horizontal ITlT7 20" 133 Ibm/ft K-55 driven to 130' Halliburton safety valve landing nipple @ 1027' w/ X-profile (ID=3.813") 114" , .049" WT control line to surface 13-3/8" 68 Ibm/ft L-80 BTC @1494' MD/TVD cmt'd w/580 sks KOP -7800' ~M Marathon MARATHON Oil Company KTU 24-6H Kenai Gas Field Pad 41-7 6.5 Miles South of Kenai, Alaska fE: ORIGINATOR: FI~E_. 30/1999 ktu24-6h ~9-5/8" OD 40 Ibm/ft L-80 @ 5300' MDfTVD cmt'd w/ 775 sks in 12-1/4" Hole Tubing: 4-1/2" 12.6ppf, L-80, AB-Mod But. Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 wl round-nose re-entry guide @ 9108' (91deg hole angle) ID=3.725" no-go, OD=4-15/16" Promore pressure temp gauge at 8482' MD w/ 7/16" OD electric dual armored, seven strand cable Baker CM&U sliding sleeve @ 8518' w/ X-profile AB-Mod But. Packer @ 8593' MD ` F' Open Hole io 10,86'x° MC? `'/ .: OH TVD 8709'-8744TVD ?7" L-80 @ 8830' MD cmt'd w/ 646 sks Class G 26#BTC: 0'-5384' 29#BTC: 5384'-5926' 29# Hydril 521: 5926'-8830' 4:53 PM 11/13/2007 • • KB=87 feet GL-66 feet KTU 24-6h Tyonek D-1 Sand Horizontal PROPOSED WBD WITH 114" CAP. STRING Halliburton safety valve landing nipple @ 1027' w/ X-profile (ID=3.813") 1/4" , .049" WT control line to surface 13-3/8" 68 Ibm/ft L-80 BTC @1494' MDlTVD cmt'd w/580 sk< (9-5/8" OD 40 Ibm/ft L-80 @ 15300' MD/TVD cmt'd w/ 775 sks in 12-1/4" Hole ~ Tubing: 4-1/2" 12.6ppf, L-80, AB-Mod But. Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 w/ round-nose re-entry guide @ 9108' (91deg hole angle) ID=3.725" no-go, OD=4-15/16" Promore pressure temp gauge at 8482' MD w/ 7/16" OD electric dual armored, seven strand cable Baker CM&U sliding sleeve @ 8518' w/ X-profile AB-Mod But. Packer @ 8593' MD 11/4" Capilary String BHA @ 8861' MD (red-line) i"Open Hole to 10,861' I OH TVD 8709'-8744TVD __ .. ^ -~~?: 7" L-80 @ 8830' MD --_ . --- :Icmt'd w! 646 sks Class G -_ --- _- ~:?~:~ 26#BTC: 0'-5384' ---_ --_ ~~:' 29#BTC: 5384'-5926' _---_ -- ~ ~ 29# Hydril 521: 5926'-8830' ~M Marathon MARATHON Oil Company KTU 24-6H Kenai Gas Field Pad 41-7 6.5 Miles South of Kenai, Alaska ~~ QRIGINATOR'. FILE:. 30(1999 ktu24-6h 4:51 PM 1 1 /1 312 007 • Well KTU 24-6H Capillary String Installation W0.07.15202.EXP Page 1 Well KTU 24-6H Capillary String Installation Kenai Gas Field, Pad 41-7 WBS #W0.07.15202.EXP Objective -Install a'/4" Capillary String into the well to alleviate liquid loading. We intend to treat the producing fluid level with foamer. This should help the heel and horizontal of this wellbore unload. We intend to run the string to 9100' KB (as deep as we can but no deeper than 9100' KB, staying in the 4.5" tubing string). The capillary string must be landed lower than 8650' KB to be effective in this wellbore (see "Background" below). Background -Well KTU 24-6H is currently completed as a horizontal producer in the Tyonek Sands. The Well is currently producing around 4.0 MM/D. From a previous PT survey, producing fluid level is around 8650' KB. Procedure BJ Dynacoil Services 1.) Hold PJSM and fill out safe work permit. 1. Move in rig up BJ Dynacoil unit. 2. Replace Tree-cap Flange with 4-1/16" 8rd box Flange 3. MU BHA and secure to string. 4. MU WHA and Pressure test to 3000 psig 5. RIH to 9100' KB (cannot land capillary tubing higher than 8650' KB. Producing fluid level is at 8650' KB and any higher will yield ineffective for foamer injection) 6. Set Rattiguns and Leave 2000 psig on hydraulic packoff. 7. Leave 30-40' of tubing outside of well for soap injection skid hookup. 8. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge. 9. Lockout/Tagout Swab, Upper Master and Lower Master. 10. RDMO, Cleanup site, Sign-out • M Marathon MARATHON Oil Company November 13, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field, Pad 41-7 Well: Kenai Tyonek Unit 24-6H (PTD 199-073) Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 On November 9t" 2007, Marathon had ran a '/4" capillary string to 8861' KB for injection of foamers. Please find attached a 10-404, current wellbore diagram, operations summary. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~~ Dennis Donovan Production Engineer Enclosures: 10-404 Sundry Notice Current Well Schematic Operations Summary cc: Houston Well File Kenai Well File DMD KJS ~~~~N~~ N~V ~ ~ 200 Al~~ka Qil $ ~~~ Cnns, Cammissior~ Anchorage ~~~.,,-cr~i STATE OF ALASKA ~ ~ ALAS~OIL AND GAS CONSERVATION COMM1S510N ~~~ 1 6 ?_.~J~7 REPORT OF SUNDRY WELL OPERATIOIOM~ke Oil ~ Gas Cans, Commission Anchorage 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Installed 1/4" Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Capillary String 2.Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development^ Exploratory^ 199-073 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20490-00-00 7. K8 Elevation (ft): 9. Well Name and Number: 21' Kenai T onek Unit 24-6H 8. Property Designation: 10. Field/Pool(s): 37' FNL 8~ 4168' FWL, Sec. 7, T4N, R11W, S.M. Kenai Gas Field, Pad 41-7, T onek Pool 11. Present Well Condition Summary: Total Depth measured 10,861' feet Plugs (measured) N/A true vertical 8,744' feet Junk (measured) N/A Effective Depth measured 10,861' feet true vertical $,744' feet Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 130' 130' 1530 psi 5020 psi Surface 1494' 13-3/8" 1494' 1494' 3090 psi 1540 psi Intermediate 5300' 9-5/8" 5300' 5300' 6330 psi 3810 psi Intermediate 8830' 7" 8830' 8674' 8120 psi 7020 psi Production 2031' 6" open hole 8830'-10960' 8674'-8743' N/A N/A Liner 0 0 0 0 0 0 Perforation depth: Measured depth: N/A True Vertical depth: N/A 1/4" 2205 SS 8861' Tubing: (size, grade, and measured depth) 4-1l2" L-80 9108' Packers and SSSV (type and measured depth) Baker Model FA-1 permanent Packer and 8595' 12. Stimulation or cement squeeze summary: 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 3800 2.5 0 400 Subsequent to operation: 0 3800 2.5 0 400 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run No Logs/Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations Included 16. Well Status after work : Oil ^ Gas /^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: '3 01 - ~S Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M Donovan Title Production Engineer I (907)-283-1333 W Signature '~ ~ Phone (907x398-1362 C Date 13-Nov-07 __ Form 10-404 Revised 04/2006 ~~ ~~ ~~'` `~ `" ~~~/ ~~ '~ Submit Original Only . • • KB=87 feet GL=66 feet KTU 24-6h Tyonek D-1 Sand Horizontal 20" 133 Ibm/ft K-55 driven to 130' II` Halliburton safety valve landing nipple @ 1027' - w/ X-profile (ID=3.813") 1/4" , .049" WT control line to surface 13-3/8" 68 Ibm/ft L-80 BTC @1494' MD/TVD cmt'd w/580 sks KOP -7600' 9-5/8" OD 40 Ibm/ft L-80 @ 5300' MD/TVD cmt'd w/ 775 sks in 12-1/4" Hole Tubing: 4-1/2" 12.6ppf, L-80, AB-Mod But. Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 w/ round-nose re-entry guide @ 9108' (91deg hole angle) ID=3.725" no-go, OD=4-15/16" Promore pressure temp gauge at 8482' MD w/ 7/16" OD electric dual armored, seven strand cable Baker CM&U sliding sleeve @ 8518' w/ X-profile AB-Mod But. Packer @ 8593' MD 1/4" Capilary String BHA @ 8861' MD (red-line) OH TVD 8709'-8744'TVD 7" L-80 @ 8830' MD cmt'd w/ 646 sks Class G 26#BTC: 0'-5384' 29#BTC: 5384'-5926' 29# Hydril 521: 5926'-8830' D-1 ~M Marathon MARATHON Oil Company KTU 24-6H Kenai Gas Field Pad 41-7 6.5 Miles South of Kenai, Alaska ORIGINATOR-. FILE: 30/1999 ktu24-6h 4:52 PM 11/13/2007 I'" ~. • • Marathon Oil Company Page 1 of 1 Operations Summary Report. Legal Well Name: KENAI TYONEK UNIT 24-6H Common Well Name: KENAI TYONEK UNIT 24-6H Spud Date: 6/3/2000 Event Name: MAINTENANCE/REPAIR Start: 11/9/2007 End: 11/9/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code ..:Code Phase 11/10/2007 10:00 - 11:23 1.38 SAFETY MTG CTBG 11:23 - 14:30 I 3.121 RURD I COIL I CTBG 14:30 - 15:30 1.00 CHANGE EOIP CTBG 15:30 - 16:05 0.58 TEST_ TREE CTBG 16:05 - 17:00 0.92 RUNPU COIL CTBG 17:00 - 18:00 I 1.001 RUNPULI COIL I CTBG 18:00 - 20:00 2.00 WAITON EOIP CTBG 20:00 - 22:34 2.57 RUNPU COIL CTBG 22:34 - 23:15 0.681 RUNPUL COIL CTBG 23:15 - 00:00 I 0.75 f RURD I COIL I CTBG Description of Operations Hold PJSM w/ BJ Dynacoil crew. Discuss BJDC JSA. Location is slippery in spots. Puddles around wellhead. Take special precautions, cover alarms, muster area, right to stop job, muster area, ect. RU Dynacoil unit. Wait on 2" Hammer Wrench to replace tree cap Flange. Wait on manllift. Overall slow rigup Replace wellhead connection flange with new flange with 2-7/8" 8rd connection for Dynacoil. RU on Wellhead and pressure test WHA to 3000 psi, Test good RIH with Capilary String and sit down in tree. Well flowing. PUH and could not close Swab. Fully S/I upper and lower master, Fully S/I wing and SSV. Cut string with swab. Bleed down pressure at Tee and remove Dynacoil BHA. Due to the well flowing the small BHA tagged the Flow Tee. Redress BHA and RIH with Well S/1. Tagged up at 4.5" Tubing hanger (possible memory in the Capilary tubing), talk about using a weight bar and knucle joint, BJ went to shop to make one. BJ Dyancoil travel to shop to make weight bar for BHA (BHA is approximately 8" long, and weight bar added to bottom is approx 12". Knuckle Joint is constructed of an eyebolt.) MU BHA and RIH with Capilary String and sit down in tree. PU and RIH and pass obstruction at hanger. RIH at 100 ft/min to 8840' DCM before string tagged up (100 Ibs max on weight indicator), PUH and RIH to 8840' DCM, Cannot run any further. Final landing depth of 8861' KB (8840' DCM from Tubing Hanger + 21' KB) Set Rattiguns with 9/16" wench, tum clockwise and NEVER backoff (packoff and BI-DI slips) and leave 2000 psi on the hydraulic packoff above the rattiguns. Leave 30'-40' of Capilary string outsite of the well to hookup to the soap injection skid. Line is capped off with swagelok cap, valve and has pressure gauge. DO NOT OPERATE Signs were placed on Swab, Upper Maser, and Lower Master to prevent cutting the string. NOTE: The string cuts easily with closing a valve. RD Dynacoil Unit, Cleanup site, Leave Location and Sign out. Printed: 11/13/2007 10:04:44 AM r • M Marathon MARATHON Oil Company November 13, 2007 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission to ~~~ ~, ~ Z~07 Anchorage, Alaska 99501 ~~~~ Reference: 10-404 Sundry Report (Sundry # 307-210) Field: Kenai Gas Field, Pad 41-7 Well: Kenai Tyonek Unit 24-6H (PTD 199-073j Dear Mr. Maunder: We had proposed to run a 1.75" velocity string in KTU #24-6H. With the availability of a capillary injection unit on the Peninsula; we were able to mitigate water loading by running a capillary string. This report is to follow up on Sundry 307-210 to report that "NO WORK" was completed on an installation of a 1.75" velocity string. Please find attached a 10-404 and current wellbore diagram. if you have any questions or need further information please call me at (907) 398-1362. Sincerely, ~l~z. Dennis Donovan Production Engineer Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File DMD KJS ~=-~ ~~ ~OV '~ ZOO /lacks ~a~ ~~,; ~1~~~~y ~~t'~tl"I'is_ Ary~hOr~ge STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED ,~~, 6 2007 1. Operations Abandon Repair Well Plug Perforations Stimulate lack s Cons.. ammission Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ~Ch01~ WORK Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development^ Exploratory^ 199-073 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20490-00-00 7. KB Elevation (ft): 9. Well Name and Number: 21' Kenai T onek Unit 24-6H 8. Property Designation: 10. Field/Pool(s): 37' FNL & 4168' FWL, Sec. 7, T4N, R11W, S.M. Kenai Gas Field, Pad 41-7, T onek Pool 11. Present Well Condition Summary: Total Depth measured 10,861' feet Plugs (measured) N/A true vertical 8,744' feet Junk (measured) N/A Effective Depth measured 10,861' feet true vertical 8,744' feet Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 130' 130' 1530 psi 5020 psi Surface 1494' 13-3/8" 1494' 1494' 3090 psi 1540 psi Intermediate 5300' 9-5/8" 5300' 5300' 6330 psi 3810 psi Intermediate 8830' 7" 8830' 8674' 8120 psi 7020 psi Production 2031' 6" open hole 8830'-10960' 8674'-8743' N/A N/A Liner 0 0 0 0 0 0 Perforation depth: Measured depth: N/A True Vertical depth: N/A Tubing: (size, grade, and measured depth) 4-1/2" L-80 9108' Packers and SSSV (type and measured depth) Baker Model FA-1 permanent Packer and 8595' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A ~~~ ~~~~ ~ ~ 20~~ Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data ***NO WORK DONE*** Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to weN operation: 0 N/A NIA NIA N/A Subsequent to operation: 0 N/A N/A N/A N/A 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run No Logs/Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations NO WORK 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-210 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M Donovan Title Production Engineer I (907)-283-1333 W Signature ~ • Phone (907)-398-1362 C Date 13-Nov-07 Form 10-404 Revised 04/2006 ~11(~ Submit Original Only • Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, November 09, 2007 9:28 AM To: 'Donovan Jr, Dennis M.' Cc: Muffin, Mickey; Rang, Craig L.; CisseN, Wayne E.; lbele, Lyndon; Grant, Patrick; SuNey, Michael; Skiba, Kevin J.; Walsh, Ken Subject: RE: KTU 24-6H (199-073): Install capillary string Dennis, Thanks for the follow-up information. I have spoken to Commissioner Seamount and you have his approval to proceed. I look forward to receiving the sundry next week. In future emails, please include the permit number. That greatly helps with the processing. Call or message with any questions. Tom Maunder, PE ~~~~~~~ N~~ j. ~ 2Q~? AOGCC F :Donovan Jr, Dennis M. [mailto;ddonovan@marathonoil.com] Sen . ridgy, November 09, 2007 9:18 AM To: Mau er, Thomas E (DOA} Cc: Donova r, Dennis M.; Mullin, Mickey; Rang, Craig L.; CisseN, Wayne E.; Ibele, Lyndo rant, Patrick; Sulley, Michae , kiba, Kevin J.; Walsh, Ken Subject: FW: 4-6H: Install capillary string Tom, The reason that Marathon is re esting verbal approval on this project i ue to the availability of the Dyna Coil Personnel, they will be leaving the ate tomorrow. Dyna Coil had t opportunity to install capillary strings for another oil company in the inlet, duri their stay up here, they h asked us if we would like the same service on one (1) of our wells. We would like top orm the service, bu ould not be able to turn around a 10-403 in a timely fashion. Thanks Dennis Donovan <Uennis 9K. rponovan ,fir. Production Engineer I 907-283-1333 Office 907-39$-1362 Cell From: W ,Ken Sent: day, November 09, 2007 7:06 AM To: om_Maunder@admin.state.ak.us : Donovan lr, Dennis M.; Mullin, Mickey; Rang, Craig L.; CisseN, Wayne E.; Ibele, Lyndon; Grant, Patr~ ; Sulley, Michael; Skiba, Kevin J. Subject: KTU 24-6H: Install capillary string Tom, 11 /9/2007 Page I of 1 Maunder, Thomas E (©DA) From: Donovan Jr, Dennis M. [ddonovan@marathonoil.com} Sent: Friday, November 09, 2007 9:18 AM To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M.; Mullin, Mickey; Rang, Craig L.; Cisseil, Wayne E.; (bete, Lyndon; Grant, Patrick; Sultey, Michael; Skiba, Kevin J.; Walsh, Ken Subject: FW: KTU 24-6H: Install capillary string Tom, ~~~^~~3 The reason that Marathon is requesting verbal approval on this project is due to the availability of the Dyna Coil Personnel, they will be leaving the state tomorrow. Dyna Coil had the opportunity to install capillary strings for another oil company in the inlet, during their stay up here, they has asked us if we would like the same service on one (1) of our wells. We would like to perform the service, but would not be able to turn around a 10-403 in a timely fashion. Thanks Dennis Donovan Dennis Jl~f. Donovan ,fir. Production Engineer I 907-283-1333 Office 907-398-1362 Cell ~~ ~~~ F~ From: Walsh, Ken Sent: Friday, November 04, 2007 7:06 AM To: Tom_Maunder@admin.state.ak.us Cc: Donovan Jr, Dennis M.; Mullin, Mickey; Rang, Craig L; Cissell, Wayne E.; Ibeie, Lyndon; Grant, Patrick; Sultey, Michael; Skiba, Kevin ]. Subject: KTU 24-6H: Install capillary string Tom, As we spoke on Wednesday, I am requesting verbal approval to install a 1t4" stainless steel capillary string into the KTU 24-6H well. We want to install this string to allow foamer to be pumped into the heal of this horizontal wellbore to help unload produced water. We will send in a Form 10-403 to followup once we receive the verbal (or email) approval Thanks and best regards, Ken Walsh Marathon Oil Company 394-3060 11 /9!2007 ( MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 181-153 195-055 174-050 178-055 1 77-029 185-181 202-043 179-029 184-108 199-024 200-188 200-179 . >..~="'R'"'' J'.I íu~"n try) f0..L" 2nj'l/t S((;{\W\~~~E,~); ~Ii"~lhq (,JI \l~~lJU 0 KBU 23X-06 KBU 31-07' KBU 31-07RD KU 14-06RD KDU5 KBU 13-08 KBU 33-07 KTU 32-07H KBU 41-07 KTU 13-05 KBU 33-06 KBU 24-06 KBU 44-06 200-023 KTU 32-07 168-049 KDU 2 184-108 KTU 13-05 199-02A KBU 33-06 195-054 KTU 43-06XRD 203-066 KBU 43-07X 199-073 KTU 24-06H 195-054 KBU 43-06XRD 169-012 KDU 4 179-030 KBU 43-06X 199-025 KBU 42-07 202-025 KBU 41-07X . ~V~VŒ (ID~ ~~~~[\~ . I AI,A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 SARAH PALIN, GOVERNOR Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 SCANNE.D JUL 0 5 2007 Re: Kenai Gas Field, Kenai, BelugajTyonek Gas Pool, Kenai Tyonek Unit 24-6H Sundry Number: 307-210 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this 4- day of June, 2007 Encl. )C)C}-o+3 . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 '#A.') Marathon MARATHON Oil Company June 13, 2007 RECEIVED JUN 2 5 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 .Alaska Oil & Gas Cons. CDfTlmission Anchorage Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Tyonek Unit 24-6H Dear Mr. Maunder: We propose to run a 1.75" velocity string in KTU #24-6H. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. Sin~~ . Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File DMD KJS 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate D vvalver LJ Other [] Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D V-String Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~ Marathon Oil Company Development [] Exploratory D 199-073 3. Address: Stratigraphic D Service D 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20490-00-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes DA/LNO [] Kenai Tyonek Unit 24-6H - 9. Property Designation:,e-~ O¿¡/'/", ¿.:;fHJ? 10. KB Elevation (ft): 11. Field/Pool(s): 37FNL & 4168' FWL, Sec. 7, T4N, R11W, S.M. 21.6' . Kenai Gas Field, Pad 41-7 - 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,861' 8744' 10,861' 8744' N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 130' 130' 1530 psi 5020 psi Surface 1494' 13-3/8" 1494' 1494' 3090 psi 1540 psi Intermediate 5300' 9-5/8" 5300' 5300' 6330 psi 3810 psi Intermediate 8830' 7" 8830' 8674' 8120 psi 7020 psi Production 2031' 6" open hole 8830'-10960' 8674'-8743' N/A N/A Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4-1/2" L-80 9108' Packers and SSSV Type: Baker Model FA-1 permanent Packer Packers and SSSV MD (ft): 8595' 13. Attachments: Description Summary of Proposal D 14. Well Class after proposed work: Detailed Operations Program [] BOP Sketch D Exploratory D Development [] Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 20-Aug-07 Oil D Gas [] Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name \ Dennis Donovan Title Production Engineer Signature ~ ~ V, ..:tr\.. Phone (907) 283-1333 Date 13-Jun-07 - --- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ll)..¡J'7" ri./ Ò Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~SoO ~ c...\~ )Ç>~ ~ \ 0 ~~ D ~ o..~ ~ û..~ . Subsequent Form Required: ~CJ~ ~&:e:~R APPROVED BY 6-pl ,'t' Approved by: THE COMMISSION Date: Form 10-403 Revised 06/2006 ÕRJ~ I d~mit in Duplicate /K\; ,;,01 ~.~ RECt::.IVt::D VJ"1 ~'" STATE OF ALASKA '7-()¡1¡ ALA all AND GAS CONSERVATION COM ION ~ UN 2 5 70D7 APPLICATION FOR SUNDRY APPROVAALS 01 & Gas Cons. Commission 20 MC 25 280 - AlasKa I NA . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field, Pad 41-7 Kenai Tyonek Unit 24-6H 2007 CT Velocity String Hangoff Procedure Notes: . This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. . Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real-time Flowina Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top offill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil Tubina Head. 3. Make flowline modifications for coil tubina velocitv strina. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back eauipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubina unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHA). Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 Ibs. Nipple up injector to WHA. 7. Pressure test surface lines and CT eauipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in well bore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. . . Page 2 of2 10. Nipple UP injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubina velocitv strina and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubina. PUH to span WHA for final landing depth. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 Ibs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanaer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between a-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purae N2 from CT remainina in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release eauipment. RD flowback iron. Release tanks and all rental equipment to vendors. IKOP -7600' I ~ QJ Õ r:. Ë ë. !: C) ::> ë. .... t: QJ E QJ :.> Halliburton safety valve landing nipple @ 1027' wi X-profile (ID=3.813") 1/4" , .049" WT control line to surface 13-3/8" 681bm/ft L-80 BTC @1494' MD/TVD cmt'd w/580 sks 19-5/8" OD 40 Ibm/ft L-80 @ 15300' MD/TVD cmt'd wi 775 Isks in 12-1/4" Hole Tubing: 4-112" 12.6ppf, L"80, AB-Mod But. Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 w/ round-nose re-entry guide @ 9108' (91 deg hole angle) 10=3.725" no-go, 00=4-15/16" Baker CM&U sliding sleeve @ 8518' w/ X-profile Promore pressure temp gauge at 8482' MO w/ 7/16" 00 electric dual armored, seven strand cable 7" L-80 @ 8830' MD cmt'd wi 646 sks Class G 26#BTC: 0'·5384' 29#BTC: 5384'-5926' 29# Hydril 521: 5926'-8830' DATE ORIGINATOR: 9/30/1999 10:33 AM 6/13/2007 IKOP -7600' I ~. PROPOSED KTU 24-6h Tyonek D-1 Sand Horizontal 120" 133 Ibm/ft K·55 driven to 130' Halliburton safety valve landing nipple @ 1027' wi X-profile (ID=3.813") 1/4" , .049" WT control line to surface 13-3/8" 68 Ibm/ft L·80 BTC @1494' MDrrVD cmt'd w/580 sks 19-5/8" OD 40 Ibm/ft L-80 @ I 15300' MDrrVD. cmt. 'd wi 775 I ]SkS in 12-1!~:_~~1~__ Tubing: 4-1/2" 12.6ppf, L-80, AS-Mod But. Packer tailpipe: 4-1/2", 12.6ppf, L-80, Hydril 521 wi round-nose re-entry guide @ 9108' (91 deg hole angle) ID=3.725" no-go, OD=4-15/16" Baker CM&U sliding sleeve @ 8518' wi X-profile Promore pressure temp gauge at 8482' MD wi 7/16" 00 electric dual armored, seven strand cable '" õ s:: § ë. £: C» :> Õ. E Q) E '" :J T' L-80 @ 8830' MD cmt'd wi 646 sks Class G 26#BTC: 0'-5384' 29#BTC: 5384'-5926' 29# Hydril 521. 5926'-8830' KTU 24-6H Kenai Gas Field Pad 41-7 6.5 Miles South of Kenai, Alaska DATE ORIGINATOR: 9/30/1999 .EJ.1£. ktu24-6h 10:33 AM 6/13/2007 Permitto Drill 1990730 DATA SUBMITTAL COMPLIANCE REPORT 7131/2003 Well Name/No. KENAI TYONEK UNIT 24-06H Operator MARATHON OIL CO /~ ~ .~ ') J~/,~,'.:, APl No. 50-133-20490-00-00 MD 10960 -~ -I-VD 8743 f Completion Dat 8/1/2000 '~' Completion Statu 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey . N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments L L DSI/NGT 2/5 FINAL 8100 9010 OH 8/3/2000 8100-9010 _~N GT-'I-VD 2/5 FINAL 8100 8750 OH 8/3/2000 8100-8750 M~ 2 FINAL 1504 9030 OH 9/7/2000 EPOCH 1504-9030 PH 6/8/00 THRU ~ 2 FINAL 1504 10960 OH 9/7/2000 EPOCH 1504-10960 6/8/00 THRU .,~M.IJD 2 FINAL 8845 8940 OH 9/7/2000 EPOCH 8845-8940 PB1 ~ 2/5 FINAL 8837 10960 OH 9/7/2000 8837-10960 PB2 GR-MD 2/5 FIELD 8800 10900 OH 9/11/2000 8800-10900 PB2 7/19/00 THRU '~--")'-[/'.~ "'P 2/5 FIELD 8659 8724 OH 9/7/2000 8659-8724 PB2 7/19/00 THRU ~D 10-11 ,..GR"I~D 5 0 10960 OH 12/15/2000 BH 0-10960 J;3'-T/N GT/CAL-M D 2/5 FINAL 8100 9008 OH 8/3/2000 8100-9008 ~ 5 FINAL 5304 8310 OH 7/14/2000 5304-8310 PEX-DT/NGT/CAL 2/5 FINAL 5304 8310 OH 7/14/2000 5304-8310 ~X-AIT/MCFL/GR 2/5 FI NAL 5304 8310 OH 7/14/2000 5304-8310 P EX-G PJCA L 2/5 FINAL 5304 8310 OH 7/14/2000 5304-8310 ~..X,~ R/GR/CAL 2/5 FINAL 5304 8310 OH 7/14/2000 5304-8310 J;NSFF/~GT 2/5 FINAL 5304 8310 OH 7/14/2000 5304-8310 GPJMWD FIELD 8840 10960 CH 1/5/2001 8840-10960 BL/Sepia · -D1R---~ FINAL 8100 9010 OH 8/3/2000 8100-9010 ~ 2/5 FINAL 8100 9010 OH 8/3/2000 8100-9010 Permitto Drill '1990730 MD 10960 TVD DATA SUBMITTAL COMPLIANCE REPORT 7/3112003 Well Name/No. KENAI TYONEK UNIT 24-06H Operator MARATHON OIL CO 8743 Completion Dat 8/1/2000 Completion Statu 1-GAS Current Status 1 -GAS APl No. 50-133-20490-00-00 UIC N i L L NGT-TVD 2/5 FINAL r-..D'~GT/cAL-TVD 2/5 FINAL A'I~/MC FI_/GR-'I'VD 2/5 FINAL PE~CFL-MD 2/5 FINAL 8100 8750 OH 8100 8750 OH 8100 8750 OH 8100 9008 OH 8/3/2000 8/3/2000 8/3/2000 8/3/2000 8100-8750 8100-8750 8100-8750 8100-9008 Well Cores/Samples Information: Name ,~..~.- Interval Start Stop Sent Dataset Received Number Comments '~'~'uttings 5300 10960 ADDITIONAL INFORMATION Well Cored? Chips Received? Y k~N.N~ Analysis Y / Daily History Received? ~,~N Formation Tops ~' N Comments: Compliance Reviewed By: Date: ,,,' STATE OF ALASKA ALA~{, OIL AND GAS CONSERVATION COMIC' ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OILD GAS~] SUSPENDEDE~ ABANDONEDD SERVICEO 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 99-073 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20490 Classification of Service Well 4. Location of Well at Surface 37' FNL & 4168' FWL, Sec. 7, T4N, R11W, SM At top of Producing Interval 341' FSL & 3718' FWL, Sec. 6, T4N, R11W, S.M. 1502' FSL & 2334' FWL, Sec. 6, T4N, R11W, S 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. 21.6' DF-GL I A-028142 12. Date Spudded 113. Date T.D. Reached 6/2/00 I 7/28/00 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 10960' MD, 8743' TVD 10960' MD, 8743' TVD 22. Type Electric or Other Logs Run AIT-PEX-CMR-NGT-DSI-GR 9. Unit or Lease Name Kenai Tyonek Unit 10. Well Number KTU 24-6h 11. Field and Pool Tyonek Pool Kenai Gas Field 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 8/~0~t~. I N/A feet MSL I one 19. Directional Survey 120. Depth where SSSV set 121. Thickne,s~ oJ.,Peyma.E, ost, ~ ,..,, Y~No~ N/A feetMD N/A~' ~"'~ ~"' '" ""~ [.. 'L~ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMQUM~-p:,I~,,~ED 20" 133 K-55 0 130' Driven Driven N/A 13-3/8" 68 L-80 0 1494' 17-1/2" 580 sks N/A 9-5/8" 40 L-80 0 5300' 12-1/4" 775 sks N/A 7" 26 & 29 L-80 0 8830' 8-1/2" 646 sks N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) No perfs. Well is open-hole completion in the Tyonek D-1 Sand. Open hole exists 8830' - 10960' MD, 8674' - 8743' TVD. SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9108 8595 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) N/A 27. PRoDUcTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) flowing IAMON/UANT & KIND OF MATERIAL USED 1'3 I F'II I ^ I U I II' ML 18-Audi-00 Date of Test I Hours Tested I PRODUCTION FOR OIL-BBL GAS-MCF 9/16/00 I 24 ITEST PERIOD ~ 0 6536 FIowTubing Pres. ICasing Pressure ICALCULATED OIL-BBL GAS-MCF 1662 I 700 124-HOUR RATE ~ 0 6536 28. Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ~ater. Submit core chips. WATER-BBL 5 WATER-BBL 5 ICHOKE SIZE IGAS-OIL RATIO I N/A I OIL G RAVITY-API (corr) I N/A Tyonek D-1 Sandstone - fine to course grained, gas bearing sandstone Form 10-407 Rev. 7-1-80 N:\drlg\kgf\wells\KBUSS-6V~OG COM PL.xls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Middle Beluga 5338 5338 Interbedded sandstone, silt, shale, and thin coals Tyonek 7182 7182 Interbedded sandstone, silt, shale, and coal Tyonek D-1 8820 8665 Gas beadng sandstone ..... .... , · " ..~:: ,r : . 31. LIST OF ATTACHMENTS Daily operations summary, we{Ibore schematic, directional survey 32. I hereby ce~hat the forego~and correct to the best of my knowledge Signed ~ ...~~\ ~,.~,.~ Ga, Eller Title Production Engineer Date 10/5/00 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg~terling~su32-9~AOGCOMP L.×ls Kenai Gas Field Well KTU 24-6h, Pad 41-7 Marathon Oil Co., Alaska Region 20", 133#, K-55 Drive pipe @ 130' · 13-3/8", 68#, L-80, BTC Casing @ 1494' Cmt w/580 sks of Class G 9-5/8", 40#, L-80, BTC Casing @ 5300' Cmt w/775 sks of Class G Halliburton safety valve landing nipple @ 1027' w/X-profile (ID = 3.813") 1/4", 0.049" WT control line to surface API: 50-133-20490 RT-GL: 21.6' RT-THF: 18.90' 37' FNL, 4168' FWL Sec. 6, T4N, RllW, S.M. Tree cxn = 4-3/4" Otis Tubing: 4-1/2", 12.6 ppf, L-80, AB-Mod. Butt. Packer tailpipe: 4-1/2", 12.6 ppf, L-80, Hydril 521 Packer Fluid: 9.7 ppg KC1 Promote pressure/temperature gauge @ 8482' (35°hole angle) w/7/16" OD electric cable, dual-armored, seven-strand conductor. Baker CMU sliding sleeve @ 8518' (37°hole angle) w! X-profile (ID = 3.813") 7", L-80 Casing @ 8830' Cmt w/646 sks of Class G 26#BTC: 0'- 5384' 29# BTC: 5384' - 5926' 29# Hydril 521: 5926' - 8830' Baker model FA-1 permanent packer @ 8595' w/10' sealbore. (approx. 43°hole angle) 6" open hole to 10,960' MD TVD 8709' - 8744' er open section Round-nose Re-entry guide @ 9108' (91°hole angle) ID = 3.725" no-go, OD = 4-15/16" Last Rev: JGE, 8/3/00 Marathon Oil Compan Standard Survey Report Field: Kenai Gas Field Kenai, Alaska usa Map System:US State Plane Coord. Sys. 1927 (USFeet) Ellipsoid: Clarke - 1866 Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 North Reference: True Geomagnetic Model: Wmm_95 Site: Pad 41-7 Section 7 Centered on KU 13-5 Site Position: From: Map Position Uncertainty: 0.0 ft Water Depth: 0.0 ft Northing: Easting: 2361844.31 ft 275073.22 ft Latitude: 60 27 32.631 N Longitude: 151 14 45.826 W Magnetic Declination: 21.51 deg Grid Convergence: -1.08 deg Well: KTU 24-6H Well Position: +N/-S From Slot: +E/-W Position Uncertainty: 130.0 ft Northing: -2.5 ft Easting: 0.0 ft 2361974.31 ft Latitude: 60 27 33.911 N 275073.22 ft Longitude: 151 14 45.875 W Wellpath: OH Original hole Vertical Section: +N/-S 0.0 ft From: Well +E/-W 0.0 ft Measured Depth Reference: SITE Drilled From: Surface Tie-on Depth: ft V.Section Direction: 310.00 deg 87.0 ft Above System Datum: Mean Sea Level , Survey: Survey #1 Start Date: 6/3/2000 Company: Marathon Oil Company Engineer: Marathon Oil Company Tool: MWD/GYRO Survey: Survey #1 · ' .'.~ID' :ii:".!nci'". 3,zim · TVD ". +N/;S '. · +E/-W. . VS ::.. DLS" : Build...Turn ' T0ol/Comment . 'ff' ' ';.'..'id.eg:"" deg·. ' fti" "' "ff. ' ' ' ff..' . ' ft'" · ',deg/!00ft'd'eg~100ff deg/100ft ' · '; ~ .. 0.0 0.00 0.00 0.0 0.0 0.0 0.0 0.00 0.00 0.00 MWD/GYRO 283.0 1.77 303.40 283.0 2.4 -3.6 4.3 0.63 0.63 0.00 MWD/GYRO 316.0 1.98 263.30 315.9 2.6 -4.6 5.2 3.94 0.64 -121.52 MWD/GYRO 524.0 2.11 268.30 523.8 2.1 -12.0 10.6 0.11 0.06 2.40 MWD/GYRO 765.0 1.84 261.90 764.7 1.4 -20.3 16.5 0.14 -0.11 -2.66 MWD/GYRO 932,0 1.53 258.10 931.6 0.6 -25.1 19.6 0.20 -0.19 -2.28 MWD/GYRO 1107.0 0.44 253.00 1106.6 -0.1 -28.1 21.4 0.62 -0.62 -2.91 MWD/GYRO 1508.0 0.58 230.00 1507.5 -1.9 -31.1 22.6 0.06 0,03 -5.74 MWD/GYRO 1701.0 0.71 244.10 1700.5 -3.0 -32.9 23.3 0.11 0.07 7.31 MWD/GYRO 1892.0 0.66 242.30 1891.5 -4,0 -35.0 24.2 0.03 -0.03 -0.94 MWD/GYRO 2108.0 0.58 2275.0 0.63 2471.0 0.52 266O.O O.55 2849.0 0.51 3035.0 0.59 3226.0 0.59 3418.0 0.51 3610.0 0.46 3798.0 0.55 3985.0 0.48 418O.0 0.41 4364.0 0.44 4557.O 0.37 4747.0 0.40 238.30 2107.5 -5.2 -37.0 25.0 0.04 -0.04 -1.85 MWD/GYRO 236.30 2274.5 -6.1 -38.5 25.5 0.03 0.03 -1.20 MWD/GYRO 213.50 2470.5 -7.5 -39.9 25.7 0.13 -0.06 -11.63 MWD/GYRO 228,90 2659.5 -8.8 -41.0 25.8 0.08 0.02 8.15 MWD/GYRO 217.30 2848.5 -10.1 -42.2 25.9 0.06 -0.02 -6.14 MWD/GYRO 242.10 3034.5 -11.2 -43,6 26.2 0.13 0.04 13.33 MWD/GYRO 234.60 3225.5 -12.2 -45.2 26.8 0.04 0.00 -3.93 MWD/GYRO 226.30 3417.4 - 13.4 -46.7 27.1 0.06 -0.04 -4.32 MWD/GYRO 245.10 3609.4 -14.3 -48.0 27.6 0.09 -0.03 9.79 MWD/GYRO 240.30 3797.4 - 15.0 -49.4 28.2 0.05 0.05 -2.55 MWD/GYRO 240.00 3984.4 -15.9 -50.9 28.8 0.04 -0.04 -0.16 MW D/GYRO 260.40 4179.4 -16.4 -52.3 29.5 0.09 -0.04 10.46 MWD/GYRO 255.80 4363.4 -16.7 -53.6 30.4 0.02 0.02 -2.50 MWD/GYRO 289.90 4556.4 -16.7 -54.9 31.4 0.13 -0.04 17.67 MWD/GYRO 283.40 4746.4 -16.3 -56.1 32.5 0.03 0.02 -3.42 MWD/GYRO 4934.0 0.37 256.10 4933.4 -16.3 -57.4 33.5 0.10 -0.02 -14.60 MWD/GYRO Marathon Oil Company" Standard Survey Report : ~Field! .:i:: ~ :Kenai Ga§Field !':: · ': ~' ::: ,': .:: :: ,:-~ :~ ":'; ~: :' ' Co-ordinate(NEYReference: : .WelI::iKTU 24~6H, True North: :, :Site:' i:';: :-:pad 4:1!~Z,~::;~::~. :' .~' .,~ :::: :i! .i': :' :~.: :'~: :! :: :; vertiCal;.(TVD)iR~ferenCe: ?~ :::SITE87:0above'Meansea LeVel · W~H: :; :: KTU 24~6H ,:: '..~: .i~ :~. :i: :~:::': ~;:: ":~: ~ : :: .: :'section ~S):Reference~.: ;' .~..: .:;. W~IiI (0;0E,0.0N;31'0.0~i) ' :'!: · weliPath:':;:OHOriginalh01e:- ' :- ~:.:' ; : ': ~ :SurveYCaleulatlonMetb°d: :i::Minimurn:Curvature '; ,'::: ':'. Survey: Survey #1 5126.0 0.43 260.60 5125.4 -16.6 -58.7 34.3 0.04 0.03 2.34 MWD/GYRO 5249.0 0.34 252.90 5248.4 -16.7 -59.5 34.8 0.08 -0.07 -6.26 MWD/GYRO 5471.0 0.43 226.20 5470.4 ~17.5 -60.7 35.3 0.09 0.04 -12.03 MWD/GYRO 5600.0 0.70 31.10 5599.4 -17.2 -60.7 35.4 0.87 0.21 127.83 MWD/GYRO 5786.0 0.51 61.30 5785.4 -15.8 -59.3 35.3 0.20 -0.10 16.24 MWD/GYRO 6044.0 1.67 46.50 6043.3 -12.7 -55.6 34.5 0.46 0.45 -5.74 MWD/GYRO 6241.0 1.43 38.20 6240.3 -8.7 -52.0 34.2 0.17 -0.12 -4.21 MWD/GYRO 6434.0 1.18 48.30 6433.2 -5.5 -49.0 34.0 0.18 -0.13 5.23 MWD/GYRO 6620.0 0.91 49.10 6619.2 -3.3 -46.5 33.5 0.15 -0.15 0.43 MWD/GYRO 6803.0 0.74 54.30 6802.2 - 1.7 -44.4 33.0 0.10 -0.09 2.84 MWD/GYRO 6995.0 0.25 49.20 6994.1 -0.7 -43.1 32.6 0.26 -0.26 -2.66 MWD/GYRO 7190.0 0.83 88.00 7189.1 -0.3 -41.4 31.5 0.34 0.30 19.90 MWD/GYRO 7379.0 0.80 97.10 7378.1 -0.4 -38.7 29.4 0.07 -0.02 4.81 MWD/GYRO 7568.0 0.91 91.10 7567.1 -0.6 -35.9 27.1 0.07 0.06 -3.17 MWD/GYRO 7759.0 0.63 113.80 7758.1 -1.1 -33.4 24.9 0.21 -0.15 11.88 MWD/GYRO 7873.0 0.78 123.30 7872.1 - 1.8 -32.2 23.5 0.17 0.13 8.33 MWD/GYRO 7894.0 0.57 129.00 7893.1 -1.9 -32.0 23.3 1.05 -1.00 27.14 MWD/GYRO 7950.0 0.66 346.90 7949.1 - 1.8 -31.8 23.3 2.08 0.16 -253.75 MWD/GYRO 7979.0 2.13 335.60 7978.1 -1.1 -32.1 23.9 5.13 5.07 -38.97 MWD/GYRO 8012.0 3.34 335.80 8011.0 0.3 -32.8 25.3 3.67 3.67 0.61 MWD/GYRO 8073.0 6.87 327.00 8071.8 5.0 -35.5 30.4 5.91 5.79 -14.43 MW D/GYRO 8135.0 11.99 322.70 8132.9 13.2 -41.4 40.2 8.33 8.26 -6.94 MWD/GYRO 8199.0 17.01 322.20 8194.9 25.9 -51.2 55.9 7.85 7.84 -0.78 MWD/GYRO 8263.0 21.32 320.50 8255.3 42.3 -64.3 76.5 6.79 6.73 -2.66 MWD/GYRO 8325.0 25.45 317.20 8312.2 60.8 -80.5 100.8 6.99 6.66 -5.32 MWD/GYRO 8403.0 29.30 317.80 8381.4 87.2 -104.8 136.3, 4.95 4.94 0.77 MWD/GYRO 8419.0 30.50 317.10 8395.3 93.1 -110.2 144.2 7.81 7.50 -4.37 MWD/GYRO 8453.0 33.35 317.70 _{i.4~ 106.3 -122.3 162.1 8.43 8.38 1.76 MWD/GYRO ~18.0 36.80 316.20 ~ 133.6 -147.8 199.1 5.47 5.31 -2.31 MWD/GYRO 8555.0 39.73 315.50 8506.4 150.1 -163.8 221.9 8.01 7.92 -1.89 MWD/GYRO 8613.0 44.97 313.60 8549.3 177.4 -191.6 260.9 9.30 9.03 -3.28 MWD/GYRO 8642.0 48.13 312.00 8569.2 191.7 -207.1 281.9 11.61 10.90 -5.52 MWD/GYRO 8676.0 51.83 312.10 8591.1 209.2 -226.4 307.9 10.88 10.88 0.29 MWD/GYRO 8704.0 55.10 312.70 8607.7 224.3 -243.0 330.4 11.80 11.68 2.14 MW D/GYRO 8721.0 56.85 311.00 8617.2 233.7 -253.5 344.5 13.22 10.29 -10.00 MW D/GYRO 8769.0 59.01 311.10 8642.7 260.4 -284.2 385.1 4.50 4.50 0.21 MWD/GYRO 59.24 311.10 865.5.,~5.,g~'~ 274.6 -300.4 406.6 0.92 0.92 0.00 MWD/GYRO .___8794.0 8846.0 59.50 312.40 8682.0 .304.3 -333.7 451.3 2.21 0.50 2.50 MWD/GYRO 8852.0 59.80 312.50 8685.1 307.8 -337.6 456.5 5.20 5.00 1.67 MWD/GYRO 8867.0 61.00 311.10 8692.5 316.5 -347.3 469.5 11.40 8.00 -9.33 MWD/GYRO 8871.0 61.77 311.20 8694.4 318.8 -349.9 473.0 19.37 19.25 2.50 MWD/GYRO 8878.0 62.60 311.20 8697.7 322.9 -354.6 479.2 11.86 11.86 0.00 MWD/GYRO 8882.7 62.94 311.12 8699.8 325.7 -357.7 483.4 7.39 7.23 -1.70 MWD/GYRO 8893.9 64.62 310.86 8704.8 332.3 -365.3 493,4 15.16 15.01 -2.32 MWD/GYRO 8904.0 67.70 313.40 8708.8 338.5 -372.2 502,7 38.16 30.46 25.12 MWD/GYRO 8916.0 71.60 315.20 8713.0 346.3 -380.2 513.9 35.41 32.50 15.00 MWD/GYRO 8926.4 74.50 311.90 8716.0 353.2 -387.4 523.8 41.21 27.88 -31.73 MWD/GYRO 8936.4 76.60 316.60 8718.5 359.9 -394.4 533,5 50.12 21.00 47.00 MWD/GYRO 8946.5 78.60 316.10 8720.7 367.1 -401.2 543.3 20.38 19.80 -4.95 MWD/GYRO 8955.0 81.80 316.90 8722.2 373.1 -406.9 551.6 38.77 37.65 9.41 MWD/GYRO 8966.0 85.10 316.90 8723.4 381.1 -414.4 562.4 30.00 30.00 0.00 MWD/GYRO 8988.0 90.40 322.50 8724.3 397.9 -428.6 584.1 35.03 24.09 25.45 MWD/GYRO 9004.0 91.80 320.70 8724.0 410.4 -438.5 599.7 14.25 8.75 -11.25 MWD/GYRO 9035.0 92.46 320.70 8722.8 434.4 -458.2 630.2 2.13 2.13 0.00 MWD/GYRO Marathon Oil Compan Standard Survey Report ~ Field.~"! ;::: ::. .; ;Ke~nai Gas,Field: ~. ~:i: :', : ': : '.: ~- Co-ordinate(NE)~Reference: ::~ :,;; Well~;~u 24~6H:,~TrUe~North ?;iSite::; ~ . '::Pad;41',7 ,..: ':: i ::,,:~ '::: .: !:.' ; i: :. ;; ·. Vertical (TVD) Ri~ference:,~:!-~ :::~;:i;sITE87~O~bb~,Mean;SeaL~vel :;Wellp~th: OH'Original-hole : :: :: ,. :.: '. :~,: ';; ~: : surVeyCalculati~)n Methodic:: Minimure'curvature; ?'. :: :..:.:::;~ Survey: Survey #1 9068.0 92.37 318.97 8721.4 459.6 -479.4 662.7 5.24 -0.27 -5.24 MWD/GYRO 9112.0 90.79 316.16 8720.2 492.0 -509.1 706.3 7.32 -3.59 -6.39 MWD/GYRO 9133.0 91.05 314.75 8719.9 507.0 -523.8 727.2 6.83 1.24 -6.71 MWD/GYRO 9165.0 92.02 312.29 8719.0 529.0 -547.0 759.1 8.26 3.03 -7.69 MWD/GYRO 9196.0 92.37 309.83 8717.8 549.4 -570.4 790.1 8.01 1.13 -7.94 MWD/GYRO 9230.0 92.81 308.42 8716.3 570.8 -596.7 824.0 4.34 1.29 -4.15 MWD/GYRO 9262.0 92.81 308.78 8714.7 590.7 -621.7 856.0 1.12 0.00 1.12 MWD/GYRO 9294.0 91.76 308.42 8713.5 610.7 -646.7 887.9 3.47 -3.28 - 1.12 MWD/GYRO 9326.0 89.65 307.72 8713.1 630.4 -671.9 919.9 6.95 -6.59 -2.19 MWD/GYRO 9358.0 89.74 308.07 8713.2 650.1 -697.1 951.9 1.13 0.28 1.09 MWD/GYRO 9388.0 89.74 308.07 8713.4 668.6 -720.8 981.9 0.00 0.00 0.00 MWD/GYRO 9423.0 89.21 307.37 8713.7 690.0 -748.4 1016.9 2.51 -1.51 -2.00 MWD/GYRO 9455.0 88.77 307.37 8714.3 709.4 -773.9 1048.8 1.37 -1.37 0.00 MWD/GYRO 9474.0 89.03 307,02 8714.6 720.9 -789.0 1067.8 2.29 1.37 -1.84 MWD/GYRO 9514.7 91.14 307.72 8714.6 745.6 -821,3 1108.4 5.46 5.18 1.72 MWD/GYRO 9548.0 91.41 308.42 8713.8 766.1 -847.6 1141.7 2.25 0.81 2.10 MWD/GYRO 9577.0 91.85 308.07 8713.0 784.1 -870.3 1170.7 1.94 1.52 -1.21 MWD/GYRO 9610.4 91.76 308.07 8711.9 804.6 -896.6 1204.1 0.27 -0.27 0.00 MWD/GYRO 9640.5 91.41 307.37 8711.1 823.1 -920.4 1234.1 2.60 -1.16 -2.33 MWD/GYRO 9673.0 92.11 307.37 8710.1 842.8 -946.2 1266.6 2.15 2.15 0.00 MWD/GYRO 9703.6 91.49 307.72 8709.1 861.4 -970.5 1297.1 2.33 -2.03 1.14 MWD/GYRO 9737.0 88.77 307.72 8709.1 881.8 -996.9 1330.5 8.14 -8.14 0.00 MWD/GYRO 9767.0 88.95 307.72 8709.7 900.2 -1020.6 1360.5 0.60 0.60 0.00 MWD/GYRO 9799.0 89.38 308.42 8710.1 919.9 -1045.8 1392.4 2.57 1.34 2.19 MWD/GYRO 9830.0 87.71 308,07 8710.9 939.1 -1070.1 1423.4 5.50 -5.39 -1.13 MWD/GYRO 9843.0 87.00 307.40 8711.5 947.0 -1080.4 1436.4 7.51 -5.46 -5.15 MWD/GYRO 9862.6 87.19 307.37 8712.5 958.9 -1096.0 1455.9 0.98 0.97 -0.15 MWD/GYRO 9878.0 87.36 307.72 8713.2 968.3 -1108.2 1471.3 2.52 1.10 2.27 MWD/GYRO 9892.6 86.75 307.72 8714.0 977.2 -1119.7 1485.9 4.18 -4.18 0.00 MWD/GYRO 9908.8 86.04 307.02 8715.0 987.0 -1132.5 1502.0 6.15 -4.38 -4.32 MWD/GYRO 9929.0 86.75 305.86 8716.3 999.0 -1148.8 1522.2 6.72 3.51 -5.74 MWD/GYRO 9956.7 87.89 306.31 8717.6 1015.3 -1171.1 1549.8 4.42 4.12 1.62 MWD/GYRO 9990.7 88.15 305.96 8718.8 1035.4 -1198.6 1583.7 1.28 0.76 -1.03 MWD/GYRO 10021.4 86.66 305.61 8720.1 1053.3 -1223.4 1614.2 4.99 -4.85 -1.14 MWD/GYRO 10054.9 86.48 305.96 8722.1 1072.8 -1250.6 1647.6 1.17 -0.54 1.04 MWD/GYRO 10085.4 86.40 305.61 8724.0 1090.6 -1275.2 1677.9 1.18 -0.26 -1.15 MWD/GYRO 10119.1 86.75 304.91 8726.1 1110.1 -1302.7 1711.5 2.32 1.04 -2.07 MWD/GYRO 10149.0 87.19 305.61 8727.6 1127.3 -1327.1 1741.2 2.76 1.47 2.34 MWD/GYRO 10183.3 87.19 305.26 8729.3 1147.2 -1355.0 1775.4 1.02 0.00 -1.02 MWD/GYRO 10214.0 87.45 305.26 8730.8 1164.9 -1380.1 1805.9 0.85 0.85 0.00 MWD/GYRO 10247.0 87.54 304.91 8732.2 1183.8 -1407.0 1838.8 1.09 0.27 -1.06 MWD/GYRO 10281.0 87.89 305.61 8733.6 1203.4 -1434.8 1872.7 2.30 1.03 2.06 MWD/GYRO 10311.0 88.68 305.26 8734.4 1220.8 -1459.2 1902.5 2.88 2.63 -1.17 MWD/GYRO 10341.0. 89.56 304.91 8734.9 1238.0 -1483.8 1932.4 3.16 2.93 - 1.17 MWD/GYRO 10374.0 89.65 305.26 8735.1 1257.0 -1510.8 1965.3 1.10 0.27 1.06 MWD/GYRO 10406.0 89.12 304.91 8735.5 1275.4 -1536.9 1997.2 1.98 -1.66 -1.09 MWD/GYRO 10440.0 88.77 305.26 8736.1 1294.9 -1564.8 2031.1 1.46 -1.03 1.03 MWD/GYRO 10470.0 88.24 305.61 8736.9 1312.3 -1589.2 2060.9 2.12 -1.77 1.17 MWD/GYRO 10505.0 87.89 304.56 8738.1 1332.4 -1617.8 2095.8 3.16 - 1.00 -3.00 MWD/GYRO 10534.9 88.07 304.56 ' 8739.1 1349.4 -1642.4 2125.5 0.60 0.60 0.00 MWD/GYRO 10568.9 88.15 304.56 8740.2 1368.7 -1670.4 2159.4 0,24 0.24 0.00 MWD/GYRO 10600.0 88.51 304.91' 8741.2 1386.4 -1696.0 2190.3 1.61 1.16 1.13 MWD/GYRO 10633.0 88.51 304.91 8742.0 1405.3 -1723.0 2223.2 0.00 0.00 0.00 MWD/GYRO 'Marathon Oil Compan3, Standard Survey Report .. : C°'or~t~)iReference: . Well:..KTU 24~6H, TrUe:NOrth:I :: ::' : ¥~ti~:'(TVD)Reference: ·: SITE:87,0 above Mean !Sea:: Level :" ': ':-:: ~:. :. Well(010E;0:0N,31'0,0Azi) :: : .;::.i. ' ':::: 'survey CalCulati°n Meth°d: i ,'-Minimum.CurvatUre;":: :.::- :: ':': :: ! Survey: Survey #1 10664.0 88.77 304.91 8742.7 1423.0 10697.6 88.95 304.91 8743.4 1442.2 10727.5 89.12 304.91 8743.9 1459.3 10761.0 89.82 304.91 8744.2 1478.5 10791.8 89.82 304.52 8744.3 1496.0 10825.0 90.00 304.91 8744.4 1514.9 10855.7 90.28 304.91 8744.3 1532.5 10889.0 90.35 305.26 8744.1 1551.7 10911.0 90.26 304.91 8744.0 1564.3 -1748.4 2254.1 0.84 0.84 0.00 MWD/GYRO -1776.0 2287.5 0.54 0.54 0.00 MWD/GYRO -1800.5 2317.3 0.57 0.57 0.00 MWD/GYRO -1828.0 2350.7 2.09 2.09 0.00 MWD/GYRO -1853.3 2381.3 1.27 0.00 - 1.27 MWD/GYRO -1880.6 2414.4 1.29 0.54 1.17 MWD/GYRO -1905.7 2445.0 0.91 0.91 0.00 MWD/GYRO -1933.0 2478.1 1.07 0.21 1.05 MWD/GYRO -1951.0 2500.1 1.64 -0.41 -1.59 MWD/GYRO ...,.~RATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 29-May-00 Rig down and move rig to KTU 24-6H. 30-May-00 Nipple up diverter system. Work on derrick. Change rams in BOP stack. 31-May-00 Weld on mast. Strap BHA and drill pipe. Fill pits with water. 1 -Jun-00 Finish Welding on crown. Clean and paint. Accept rig. Raise derrick. Set wind walls and stairs. Rig up top drive. 2-Jun-00 Pick up top drive. Function test diverter system. Pick up drill pipe stand in derrick. [...,ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 3-Jun-00 Make up BHA. Spud well. Drill to 830'. 4-Jun-00 Drill to 1504'. Wiper trip. Circulate and condition mud. POH. 5-Jun-00 Finish POH. Rig up and run 13 3/8" casing. Cement. 6-Jun-00 Finish cement job. POH with stab assembly. Nipple down diverter system. Weld on starting head and test. 7-Jun-00 Nipple up and testing BOPS. 8-Jun-00 9-Jun-00 Finish test BOPE. Pick up DP. Pick up BHA. TIH. Test casing to 15 psi. Drill cement, float equipment and 20' new formation. Run leak off test. Displace mud system. Drilling F/1525'-2521'. Make wiper t¢ip to casing. Drilling F/2521'-3250'. ' ..,ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H lO-Jun-O0 Drilling F/3250'-4039'. Wiper trip to 2521'. Drilling F/4039'-4383'. 11-Jun-00 Drilling F/4383'-5200'. 12-Jun-00 Drilling F/5200'-5300'. TD F/Intermediate casing Circulate bottoms up. Trip out of hole to 1500'. Cut drill line. Trip in hole and circulate hole clean to run 9 5~8" casir 13-Jun-00 Finish circulate hole clean. Trip out of hole and lay down MWD and mud motor. Install casing rams in BOPS and test same. Rig up casing crew. Running a 9 5~8" casing. 14-Jun-00 Finish run and cement 9 5~8" casing to 5300'. WOC. Nipple down BOPS and set slips. Cut off casing. Nipple up 13 3~8" 3m x 11" 5m multi-bowl. Tubing spool and test 2400 psi. Nipple up BOPS. 15-Jun-00 Finish nipple up BOPS. Test BOPS. 250 psi Iow/5000psi high. Change out 3 1/8" manual valve and blind ram elements. 16-Jun-00 Finish repair blind rams and manual choke line valve. Test same OK. Test casing 2600 Pick up mud motor and MWD. Surface test equipment. Trip in hole with BHA. Pick up 4" drillpipe. Trip in hole. Drill cement and float equipment and 25' formation. ~...ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 17-Jun-00 Drilling F/5535'-6500' 18-Jun-00 Drilling F/6500-6667'. Wiper trip to 5300'. Drilling F/6667'-6860'. Trip out of hole F/bit #4. 19-Jun-00 Trip in hole w/bit #4. Drilling F/6860'-7390'. 20-Jun-00 Drilling F/7390'-7426'. Wiper trip to 6790'. Drilling F/7426'-7855'. 21-Jun-00 Drill to 7960' - POH to casing shoe. Hole not taking correct amount of fluid. RIH. Circulate out gas cut mud. Increase mud weight to 11.3 ppg. 22-Jun-00 POH. Test BOP equipment. Make up new drilling assembly. RIH to 9 5~8" shoe. Cut drilling line. Continue to RIH. 23-Jun-00 Continue to RIH. Circulate out gas. Rotary drill and directional drill from 7960' to 8205'. ...ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 24-Jun-00 Directional drill from 8205' to 8247. Repair mud pump. Drill ahead to 8336'. 25-Jun-00 Directional drill to 8463'. POH. LD BHA. 26-Jun-00 Change BHA. RIH with bit 6. Drilling ahead, building angle to 60 degrees. 27-Jun-00 Drilling ahead building angle to 60 degrees. 28-Jun-00 Directional drill from 8724' to 8840'. Circulate and sweep well bore. Back ream out of th, into vertical section. 29-Jun-00 Circulate and condition hole. POOH. Rig up to E-Log. First log run tagged up at 8310" Log out of hole. 30-Jun-00 Logging. RIH for wiper trip prior to running 7" casing. ' ._.~RATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 1-Jul-00 2-Jul-00 3-Jul-00 4-Jul-00 5-Jul-00 6-Jul-00 RIH. CBU. POH to verticle section of well. Circulate and reduce mud weight to 12.0 ppg. Continue to POH. Continue to POH. Lay down BHA. Change top pipe rams to 7". Rig up to run casing. Run 7" casing. Run 7" casing. Work to bottom @ 8830'. Circulate and condition mud. Cement. Displace with mud. Rig down cementing equipment. Lay down casing tools. Attempt to install 7" pack off. Nipple down to inspect hanger anc pack off. Machine pack off. Nipple up BOP. Install pack off. Test packoff. Test BOP equipment. Make up BHA and RIH. Attempt test casing. 500 psi leak over 30 minutes. Re-test pack off. Trip out of hole. Finish trip out of hole. Pick up 7" RTTS. Trip in hole testing casing at 2000' intervals to top of cement @8559'. Test casing F/8525' to surface Fl30 minutes @ 3100 psi. Test OK. Losing pressure below packer through show track. Release packer. Trip out of hole. r~,_ .ATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 8-Jul-00 Stage drill F/8860'-9030'. TD pilot hole. Circulate and condition mud. POOH to log. 9-Jul-00 POOH. Rig up to log. 1st Log: AIT/DEN/NEU F/9005'-8100' 2 runs. 2nd Log: SONIC/NGT/GPIT. Stuck tool logging out at 8913'. Could not work free. Pull out of rope socket and rig down loggers. Trip in hole with overshot. Engage fish and work free. POOH with fish. 10-Jul-00 POOH. Lay down fish and tools. Full recovery. RIH w/Bit to 9030'. Circulate and condition hole. TOH. Rig up to log. Run #4: Sonic/NGT/GPIT F/9010-8830'. Rig down loggers. PU 20 jts 2 3/8" tubing and RIH wi4" drill pipe to set kick off plug. 11-Jul-00 RIH with cement stinger. Spot 80 sk, 17 ppg kick off plug from 9030'-8663'. POOH to 8400'. CBU. Hold 3100 psi on plug for 2 hrs. POOH. Test BOPE. 12-Jul-00 Finish repairing and testing BOPE. RIH to top of cement at 8597'. Drilled cement 8597'-8940' at 65'-300'/hr. CBU. POOH. P/U cementing stinger. 13-Jul-00 RIH with cement stinger on 4" drill pipe to 8940'. Spotted 60 sack, 17 ppg kickoff plug from 8940'-8650'. POOH to 8300'. CBU. POOH and L/D stinger. RIH with rotary assembly to 8050'. Mixed mud and repaired top drive while WOC. 14-Jul-00 WOC. RIH. Tag cement at 8,675'. Drilled cement to 8940'. CBU. POOH. P/U 2 3~8" cement stinger. RIH with 4" drill pipe to 8940'. CBU MAI~I'" .iON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 15-Jul-O0 Circulate bottoms up at 8940'. Set kick-off plug #3. 112 SX class "G" cement mixed at 17.0 lb/gal. Estimated top of cement 8415'. Trip out of hole to 8000'. CBU. Tdp out of hole and L/D tubing. Trip in hole with rotary assembly to 8050'. Circulate and wait on cement. 16-Jul-O0 Trip on hole to top of cement at 8505' Drilling cement F/8505'-8845' with deill rate 35'-90'/hr. Circulate bottoms up. Trip out of hole. Pick up steerable assembly and MWD. Trip in hole to 8845'. Time drilling F/8845'-8847'. 17-Jul-00 Time and slide drilled F/8847'-8940'. MWD survey at 8912', 70 degrees. Projected survey at 8940' 77 degrees. Circulate bottoms up. Trip out of hole. Prep to set kick off plug ~4. 18-Jul-00 RIH to 8,940'. Spotted 112 SKS, 17 ppg cement plug from 8,940' to 8,412'. POOH to 7,940'. CBU. POOH. Test BOPE. RIH with rotary assembly. 19-Jul-00 RIH. Drill cement from 8,375'. Circulate bottoms up. POH. 20-Jul-00 Continued to POOH. BHA. RIH. Worked on disc brakes. RIH to 8,838'. Time drilled off of cement plug to 8,848'. 21-Jul-00 Time drilled from 8,848' to 8,863'. Directionally drilled to 8,894'. MWD failed. CBU. POOH. I~" ...ATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 22-Jul-00 POOH. BHA. RIH. Wash to bottom. Directional drill from 8,894' to 8,988'. 23-Jul-00 Back ream to shoe. POOH. BHA. RIH. Change over mud to 9.5 ppg. solids free FIo Pro mud. 24-Jul-00 Finished changing over mud system to 9.5 ppg FIo Pro mud. Directional drilling from 8,988' to 9,420'. 25-Jul-00 Drill to 9,438'. Circulate bottoms up. Pump out of the hole to 8,840'. Monitor well. RIH to 9,438'. Drill ahead to 9,867'. 26-Jul-O0 Drill ahead from 9,867' to 9,926'. Circulate and condition mud. Raise mud weight to 9.8 ppg. Replace drive shaft on number 1 carrier motor. Pump out of the hole to 7" casing shoe. Circulate bottoms up. Monitor well. POOH. Test BOPE. 27-Jul-00 Tested BOPE. BHA. RIH to shoe. Cut drill line. Serviced rig and installed new drive line to #2 hydraulic pump. RIH. Drilled from 9,926' to 10,227'. 28-Jul-00 Drilled from 10,277' to 10,752'. ~',. ~THON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 32-7 29-Jul-00 Drilled from 10,752' to 10,960'. Circulate bottoms up. Pumped out of the hole to the casing shoe. Monitor well and POOH. Picked up new BHA. 30-Jul-O0 RIH. Circulated well clean. Displaced with 9.5 ppg KCL water. Monitored well. Pumped out of the hole to the 7" casing shoe. Circulated out sand and raised completion fluid weight to 9.7 ppg. 31-Jul-00 Circulated and raised fluid weight to 9.7 ppg. RIH to 9,198. Circulated hole clean. POOH. Laid down BHA. Ran 4 1/2" liner. RIH with liner on drill pipe. l-Aug-00 RIH with 4" drill pipe. Set Baker packer. Circulated bottoms up. POOH. Laid down drill pipe. Changed pipe rams. Rigged up 4 1/2" completion string. 2-Aug-00 Finish running 4 1/2" tubing. Locate packer. Space out and land tubing hanger. Lock down hanger and install back pressure valve test annulus 500 psi. Nipple down BOPS. 3-Aug-00 ND BOPE, NU and test tree. Release rig @ 12:00 hours 8/2/00. Rig down and prepare to move to KTU 32-7. "'-' 4-Aug-00 Move rig components to KTU 32-7. Rigging up. MARATHON OIL COMPANY ('" DALLY WELL OPERATIONS REPOiT PAGE 1 OF 1 DATE: 8/10/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field 4 1/2" CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: Hrs. N/A TUBING: Pull Dummy Valve, shift sleeve Complete WELL #: KTU 24-6h 7" New Bi~l~ls/Dohert7 8 SUMMARY OF OPERATIONS Rig up, safety meeting RIH w/4" GS Pulling Tool to 1012'WLM, POOH w/4" Dummy Valve RIH w/4" B Shifting Tool to 8514'WLM, worked up and down through sleeve, shifted sleeve, POOH Rig down, move to next well Fluid beginning 775' Fluid end 730' Tool Cost: 4" GS Pulling Tool 4" B Shift Tool 150.00 150. O0 TOOL STRING: RS, 3' Stem, K J, 5' Stem, K J, 3' Stem, O J, SJ Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. W/L Unit w/2 man crew $1,150.00 $1,150.00 Pollard Wireline Inc. Tools $300.00 $300.00 DALLY COST: $1,450.00 CUM: $1,450.00 REPORTED BY: Bill Wolf 000811.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 8/11/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9204399 FIELD: Kenai Gas Field WELL #: KTU 24-6h TUBING: 4-1/2", 12.6#, N-80 CASING: 7" TREE CONDITION: good BENCHES OPEN: T¥onek D-1 Circulate packer fluid, displace tubing with nitrogen SUMMARY OF OPERATIONS MIRU Dowell pump truck and nitrogen pump. Test lines. Blend 130 bbl of 2% KCl with one drum of Petrolite CRW0132F corrosion inhibitor. Rig up to pump down tubing while taking returns on casing. SITP = 0 psig, Promore BHP = 3887 psi. Begin pumping packer fluid down tubing. Not getting any returns on casing. Continue pumping for a bit longer (cum. volume of 30 bbl) before concluding that sliding sleeve is not open as it should be. Bleed off pressure, RD Dowell. Standby for slickline unit to retry opening the sliding sleeve. Learned that Dowell choke manifold was partially plugged with sand from a previous job. Possible it was blocking returns, so decide to SDFN. In the morning, will try again to establish returns. Failing that, slickline will work on the sliding sleeve. Vendor Equipment Daily Cost Cumulative Cost Dowell pump truck, nitrogen Pollard slickline Halliburton flowback Petrolite corrosion inhibitor R&K vac truck Misc misc DALLY COST: $0 CUM: $0 REPORTED BY: G. Eller 000812a.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 8/12/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9204399 FIELD: Kenai Gas Field WELL #: KTU 24-6h TUBING: 4-1/2", 12.6#, N-80 CASING: 7" TREE CONDITION: good BENCHES OPEN: T¥onek D-1 Circulate packer fluid, displace tubing with nitrogen SUMMARY OF OPERATIONS MIRU Dowell pump truck after cleaning out choke manifold. Test lines. Pump 10 bbl of packer fluid down tubing. No returns on casing, tubing pressure rose to 1000 psig. Still not circulating. RD Dowell. RU Pollard wireline. Test BOPs. RIH with "B" shifting tool. Pressure up on tubing to 150 psi, casing has 0 psi. After several attempts, manage to latch CMU sliding sleeve. Jar once and come unlatched. No change in surface pressures. Unable to relatch. POOH. PU "Posi-B" shifting tool, RIH. Pressure up casing to 200 psi, holding steady. Latch CMU sliding sleeve, jar once and come unlatched. Unable to relatch onto sliding sleeve. No change in surface pressures. POOH. SDFN. Vendor Equipment Daily Cost Cumulative Cost Dowell pump truck, nitrogen Pollard slickline Halliburton flowback Petrolite corrosion inhibitor R&K vac truck Misc misc DAILY COST: $0 CUM: $0 REPORTED BY: G. Eller MARATHON OIL COMPANY DALLY WELL OPERATIONS REPOI~~. PAGE 1 OF 1 DAT E: 8/14~00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: Shift sleeve FIELD: Kenai Gas Field WELL #: KTU 24-6h TUBING: 4" CASING: 9 5/8" 8/12/00 TREE CONDITION: New BENCHES OPEN: Complete WlRELINE CREW: Bi~j~js/McRee Hrs. 11 SUMMARY OF OPERATIONS Travel to location, held safety meeting Rig up W/L, attempted to pressure test Lub., ordered new Lub. section (4") and tree connection Pressure tested Lub., RIH w/4" Positive Shifting Tool to 8518'WLM, located sleeve, picked up to 1075#, Oil Jar went off, fell through sleeve, made 4 attempts to relocate sleeve, POOH Ordered new key springs, replaced springs, repinned shifting tool RIH w/Shifting Tool to 8518'WLM, beat up approx. 10 times, shifted sleeve, casing pressure dropped from 150 PSI to Zero Rig down W/L TOOL COST: Shifting Tool 150.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Inc. W/L unit w/2 man crew $1,150.00 $1,150.00 Pollard Wireline Inc. Inc. 3 additional hours $300.00 $300.00 Pollard Wireline Inc. Inc. Tools $150.00 $150.00 DAILY COST: $1,600.00 CUM: $1,600.00 REPORTED BY: Gary Eller 000815,xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/15/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9204399 FIELD: Kenai Gas Field WELL #: KTU 24-6h TUBING: 4-1/2", 12.6#, N-80 CASING: 7" TREE CONDITION: good BENCHES OPEN: T¥onek D-1 Circulate packer fluid, displace tubing with nitrogen SUMMARY OF OPERATIONS MIRU Dowell pump truck and nitrogen pump. Test lines. Rig up to pump packer fluid (blended on 8/11/00) down tubing while taking returns on casing. SITP = 0 psig, Promore BHP = 3989 psi. Pump packer fluid down tubing while taking returns on casing. When packer fluid is pumped away, begin displacing tubing with nitrogem while continuing to take returns on casing. Displace 120 bbl from the tubing, down to a depth of approximately 7900'. SITP = 2750 psi, SICP = 65 psi, BHP (Promore) - 3891 psi. RDMO Dowell. Standby for slickline unit to close the sliding sleeve. RU slickline on KTU 24-6h. Pressure test to 3000 psig. RIH with a "Posi-B" shifiting tool. Engaged sliding sleeve at 8518', and beat down for two hours to close the sleeve. Attempts to pressure test the casing confirm that the sleeve in still open. POOH. Pin not sheared on Posi-B shifting tool. 8/16/00 Add roller stem and weight bar. Repin "Posi-B" shifting tool and RIH. Engage sliding sleeve, attempt to beat down but tool fell through. Unable to relatch shifting tool in sliding sleeve. POOH. Keys were worn on Posi-B shifting tool. MU "B" shifting tool and RIH. Engage sliding sleeve and jar down for about one hour. Pressure test casing annulus to 500 psi, indicating sleeve is closed. Continue jarring down until "B" shifting tool passed through the sliding sleeve, indicating full travel of the sleeve. POOH, pin on "B" shifting tool not sheared. RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost Dowell pump truck, nitrogen Pollard slickline Halliburton flowback Petrolite corrosion inhibitor R&K vac truck Misc misc DAILY COST: $0 CUM: $0 REPORTED BY: G. Eller MARATHON OIL COMPANY ~!" PAGE 1 OF 1 DATE: 8/16/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: DALLY WELL OPERATIONS REPO!r FIELD: Kenai Gas Field TUBING: 8/12/00 Shift sleeve Complete 4 1/2" CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: Hrs. WELL #: KTU 24-6h 9 5/8" New Bi~lgs/McRee 8 SUMMARY OF OPERATIONS Rig up W/L, pressure test Lub., safety meeting RIH w/4" Positive Shifting Tool to 8518', unable to shift, POOH RIH w! 4" B Shifting Tool, to 8518', shifted sleeve, POOH, rig down Pressure tested casing to 500 PSI TOOL COST: 4" B Shifting Tool 150.00 4" Positive Shifting Tool 150.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Unit w/2 man crew $1,1 50.00 $1,1 50.00 Pollard Wireline Inc. Tools $300.00 $300.00 DAILY COST: $1,450.00 CUM: $1,450.00 REPORTED BY: Gary Eller 000818.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/18/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9204399 FIELD: Kenai Gas Field WELL#: KTU 24-6h TUBING: 4-1/2", 12.6#, N-80 CASING: 7" TREE CONDITION: ~lood BENCHES OPEN' T¥onek D-1 Unload well with coil tubing. SUMMARY OF OPERATIONS 08/17/00 MIRU Coil Tubing Unit w/nitrogen pump and 4,000 gal of Nitrogen. Install BOP's and surface lines. Mix 500 bbls of 3% KCl water. Notify BLM and AOGCC inspectors of pressure test in morning. Promore BHP = 3989 psi. SD RU Operations at 2300 hrs. 08/18/00 Finish RU of DS CT Unit. Commence pressure test 1. Coil tubing, BOP body/choke to 500 psig/4500 psig. 2. Blind/Shear #1 to 250 pslg/4375 psig. 3. Blind/Shear #2 to 250 psig/4500 psig. 4. Pipe Rams to 250 psig/4500 psig. All held steady. Open tree (1200 psig SITP and 3854 psig ProMore Gauge Pressure). Bled well through gas buster to less than 700 psig. RIH w/2.25" OD multi port chisel pointed nozzel (all ports directed out the base of no77el). RIH to 10,910 TD while not pumping. Did not encounter any obstructions. Well began to flow with no assistance. FTP = 300 psig/ProMore = 3050 psig. Pumped 67 bbls of 3%KCI water while pulling CT from 10,910' TD into 4-1/2" TP @ 9,000' to displace 9.5 ppf completion fluid with the 8.4 ppg 3% KCI water. Pumped total of 67 bbl of 3% KCI. Well continued to flow with a max FTP of 700 pslg until 1500 hrs, then gradually died. Commence pumping Nitrogen while coil tubing is at 9, 000'. Well began to flow again. Resume pumping N2 at 300 SCFM. Well flowing 9.4 ppg water with a 85,000 mg/I Chloride. RIH while pumping N2. Set down at 9567'. Worked numerous times but unable to go deeper. Appears to be a sand bridge as it moves. COH while jetting N2. Total fluid unloaded is 314 bbls. SD DS coil tubing @ 1900 hrs. Flow through Halliburton to MOC production: Time SITP FTP MMCFGPD BW/hr 1900 1050 1000 4.7 0 2400 NA 850 3.4 0 0100 NA 1000 4.2 0 0500 NA 1040 4.4 4 Continue flowing well. Detailed production data on attached flow tabulation. Water continues to be 9.4 ppg completion fluid. Well is continuing to clean up very gradually. Unable to pump methanol via downhole control line because of apparent plugging. Still trying to determine where and why this line is plugged. Vendor Equipment Daily Cost Cumulative Cost Dowell Coil Tubing Equipment $35,000 $45,000 Halliburton flowback $20,000 $20,000 Misc misc $500 $3,500 Pollard Wireline slickline $0 $4,500 R&K va¢ truck $680 $2,380 S&R vac truck $525 $525 Toloff Crane Crane $3,640 $3,640 DAILY COST: $60,345 CUM: REPORTED BY: G. Eller/R. Affinito MARATHON OIL COMPANY ALASKA REGION KENAI GAS FIELD KTU 24-6H 08-19-00 08/20/00 0600 1100 1700 2000 2100 0600 Resume CT operations. Well continues to flow at 3.6 to 4.2 MMCFGPD w/1000 psi FTP. Down hole gauge reading approximately 1500 psig. At this point, the gauge is acting reasonable and thought accurate. SD well flow to HES. Downhole methanol injection line is still plugged. RU 2.21" mulit-port side w/single bottom nozzle. PT BOP body to choke to 4500 psig fine. RIH while maintiaining 1000 psig FTP. Check pick up weight. Well did not liR any fluid. Dry tag at 9540' unable to go deeper. Pull back into tail pipe at 9108'. Commence pumping 1.5 BPM 3% KCI water w/500 SCFM nitrogen. Exit robing and begin getting sand to surface through gas buster and MOC iron. Plugged all surface lines. Switched flow to Halliburton and open top tank. Install tarp over open top tank. Make provisions to unload the open top tank that is quickly filling. Work CT from 9108 to 9642 by washing slowly and then pulling back into TP. Make numberous trips getting sand returns only while making additional penetration. Penetration rate became slower at 9540' where we dry tagged earlier. During job approximately 1000 psig was maintained as the FTP. During this time the downhole gauge showed 2900 to 3800 psig. Stop washing at 9642' when only adequate nitrogen existed to unload the hole as a last step on'operation. Commence jetting nitrogen w/600 gal of Nitrogen left on location with CT at 9642', Slowly begin pulling out of hole while jetting at 500 SCFM. Set CT at 7600' and jet until receive gas returns to suface. Commence pulling out of hole at slowest possible rate to reach 1500' with any nitrogen remaining. Pumped a total of 302 bbls of 3% KC1 during operation. Received 320 bbls of liquid back. All returns were 8.4 ppg dear looking KCI water. Continue to flow well while standing back CT. All load recovered plus 18 bbls. Flowed well around HES vessels to open top tank on a 24 choke. FTP = 2000 psig with downhole pressure at 2750 psig. Making very little liquid and unknown gas rate. Turn well to production. Plan to keep FBHP above 2000 psig. Well flowed on a 24/64" AC at stabilized rate of 2.5 MMCFGPD with 2000 psig FTP and 2470 psig FBHP for 4 hrs. Open choke to a 26. Well flowed at stabilized rate of 2.5 MMCFGPD with 1750 psig FTP and 2100 psig FBHP. Continue to flow well Until resume CT clean out of Monday 08/22/00. , MARATHON OIL COMPANY Ii" DALLY WELL OPERATIONS REPO~ PAGE 1 OF 1 DATE: 8/21/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KTU 24-6h TUBING: 4 1/2" CASING: 9 5/8" TREE CONDITION: New Wash sand w/CT BENCHES OPEN: Complete CT CREW: Key etc. Hrs. 8 SUMMARY OF OPERATIONS IRU dual string injector head to BOP. Change out partially cut Halliburton choke. Perform Ipressure test to 4500#. RIH w/2.25" OD multiport nozzle on 1.75" CT. Maintain 1750 FTP while RIH allowing well to flow to production @ ~3MMscf/d. Tag fill @ 9195'. Commence pumping 2.4 bpm w/500 scf/m nitrogen. Make several trips in/out of open hole pumping--wash to 9813' MD. Sit @ 9813' Shut down Nitrogen and pump 60 bbls of 3% KCI followed by a 15 bbl flo-vis sweep. Then, 10 bbl 3% KCI. Resume pumping 2.0 bpm 3% KCI w/500 Scfm Nitrogen. No additoinal hole made by jetting @ 9813'. All pumpeing operations made w/FBHP between 3000 and 3800 psig. Circulate high vis. pill then pull coil into 4.5" tailpipe and commence jetting w/nitrogen to unload hole RIH from 9100' (tbg tail) to 9449'--tag up solid. Continue to jet well in keeping FBHP above 2600#. Well not appearing "lively". Unload fluid and turn well to production. Draw well down to 2000# FBHP @3 MMscf/d 1700psi FTP, 10 bbl/hr water (35,000 mg/I CI) Total Fluid pumped=330 bbl. Total fluid recovered=304 bbl Total sand recovered ~ 1.0 cubic yard SICP=700 psi Vendor Equipment Daily Cost Cumulative Cost DALLY COST: CUM: REPORTED BY: Affinito/Eller MARATHON OIL COMPANY ~:~ DAILY WELL OPERATIONS REPO{'I PAGE I OF 1 DATE: 8/22/00 FILL DEPTH/DATE: TUBING: 4 1/2" DATE LAST WORK: 8/12/00 WORK DONE: Coil Tubing--balance well pressure, tighten tree PRESENT OPERATION: Complete OTHER: FIELD: Kenai Gas Field WELL #: KTU 24-6h CASING: 9 5/8" TREE CONDITION: see below BENCHES OPEN: CT CREW: Key + Hrs. SUMMARY OF OPERATIONS RU Schlumberger w/chisel tip nozzle to wash sand Prepare to RIH w/CT. Observe visible flange leak below bottom master valve Check Lower Explosivity Level at leak site. No natural gas detected Begin to mix 9.7 ppg kill weight KCI water. RIH w/nozzle on CT to 9100' Hold safety meeting with Halliburton, Schlumberger to review course of action employed to kill well and to note potential hazards Move mixed KCI to Schlumberger pumps. Replace ruptured R&K hose. Begin pumping kill weight fluid on bottom at 2 bpm accepting returns through Halliburton choke. Choke to maintain BHP near 4000psi as observed at Promore BHP gauge post Slow pumps and check for kill weight fluid returns. Continue pumping w/o 9.7ppg KCI returns Total Fluid Pumped: -141 bbls Coil Capacity: 30 bbls Coil/Tubing Annulus Capacity: ~110 bbls Pumped 210 bbl KCI (Out of KCI), Continue to watch returns while mixing additional kill weight fluid Pump 9.6 ppg KCI at 1 bbl/m, Begin to detect heavy fluid at surface at 220 bbl. Circulate kill fluid at 2 bpm w/Coil on bottom Continue circulating. Slow pump to check return mud weight. Getting 9.6 ppg fluid at surface Shut well in to check for flow No flow observed. Start out of hole w/CT while filling tubing, PU @ lO0'/min while pumping 0.3 bbl/min. (~230 bbl pumped) 276 bbl pumped. Still flowing returns to Halliburton. Increase PU rate to 140'/min while pumping 0,4 bbl/min. CT nozzle at surface w/290 bbl total fluid circulated. RD CT for night Cameron tightened 2 bolts on tubing head adapter flange, 1/2 turn each. Dry-rod 2 way check valve and pressure test 250/4300 psi. Tree held Remove 2 way (*O-ring on valve lost downhole) secure well for night. Well on slight vacuum SICP=360psi BHP=4170 psi (Promore gauge) Vendor Equipment Daily Cost I Cumulative Cost DALLY COST: CUM: REPORTED BY: Titus/Affinito MARATHON OIL COMPANY i" DALLY WELL OPERATIONS REPC~i' PAGE 1 OF 1 DATE: 8/23/00 FILL DEPTH/DATE: TUBING: DATE LAST WORK: 8/12/00 WORK DONE: Coil Tubincj-attempt to wash sand, jet PRESENT OPERATION: Complete OTHER: FIELD: Kenai Gas Field WELL #: KTU 24-6h 4 1/2" CASING: 9 5/8" TREE CONDITION: new BENCHES OPEN: CT CREW: Key + Hrs. SUMMARY OF OPERATIONS Strap all tanks (have 330 bbl 3% KCI). Both return tanks are empty. PU DS CT injector head. Make up tool string head and perform pull test. Make up tool string of the following: circ sub, index sub (mechanical w/2 degree dog leg), x-over, stabilizer 3.68" OD, 3 X-overs, 4 degree bent sub, 2 x-overs, multiport nozzel (2.25" OD) Make up additional lubricator. Slack off crane and tighten tbg head adaptor flange (below bottom master). Make complete turn on one, 1/4 to 1/2 turn on others w/o hammering hard. Slack off weight of the BOP/injector head/lubricator about 10000#. Pull weight off tree to simulate CT running operation. Close lower master and PT to 4500#, testing entire tree above lower master-held fine. Should make a standard practice. RIH (w/well on slight vacuum) while pumping 350-500 scfm nitrogen. Set at 9080 until getting good returns of liquid to surface (9.5 ppg fluid). Drop out of tby tail @ 9108' noting slight slack off while exiting re-entry guide. RIH tagging @ 9220'. Ratchet index tool and retry w/o success. Re-ratchet tool and work aggressively but unable to get below 9220". ,*BHP 4160# (Promore). Attmept to pull back into tbg tail but unable to get back in. Work for 15 minutes. Begin pumping 3% KCl. *Go back down hole and retag to ratchet index tool again. Attempt to pull back into tail pipe. Get back in following additional work. Pull up hole and get stuck @ 8495'. Unable to move up and at one point unable to go down. Work free and COH while jetting nitrogen--switching to 3% KCl @ 8000'. All flow to Halliburton. Flowing well while maintaining 3000# FBHP. Continue flowing well while removing coil tbg tool string. All equipment recovered. Lay down index assembly Prepare to RIH slick w/CT to jet. Re-pressure test BOP body to 4500#. Swap out Toloff 70T crane for 40T crane. RIH to 9100' pumping nitrogen at 350 mscfm. Flow well to maintain about 2000 psig BHP, Stand at 9100' pumping for 1hr. Begin moving up hole about 60'/m while pumping nitrogen at 350 mscfm. RD CT. Secure tree for night. Annulus csg pressure=600 psig. Well flowing 3.3 mmscfd @ 1000psia. Producing about 3 bwpd. Turn to production 2300 hrs Total Fluid pumped yesterday 290bbl Fluid recoverd as of 2300 hrs ~233bbl Vendor Equipment Daily Cost I Cumulative Cost I DAILY COST: CUM: REPORTED BY: Affinito Alaska ~: DomestiC, oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 8, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 RE: Marathon Oil Company KTU 24-6H / Kenai Ga~ Field Dear Lori: These two reproducible logs replace the two you called me about yesterday for the above referenced well. Anchorage Reprographics assures me that these are reproducibles (prefold sepias). Let me know if you have any questions. My number is 564-6401. Thank you, Kaynell Zeman Enclosures SEP 0 7 000 Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alas~' ' ~gion Doml, Production I~arathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 5, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: Marathon Oil' Company KTU 24-6H / Kenai Gas Field Print Reproducible KTU 24-6H- Gamma Ray MWD - True Vertical Depth - 7/19/00 ........................................... ... 1 ................. 1 KTU 24-6H - Gamma Ray MWD - Measured Depth - 7/19/00 ................................................. 1 ................. 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Certified Receipt 7099 3220 0007 1780 6588 Received by:R ~ (3 ~!\'/[.! !) Date: t,',~D ('t '7 ,,~ ~ . "-'~' C0~5. "" n' A subsidiary of USX Corporation Environmentally aware for the long run. Alaska Ri'" n Domestid .duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 5, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: Marathon Oil Company KTU 24-6H / Kenai Gas Field Print Reproducible KTU 24-6H- Gamma Ray MWD - True Vertical Depth - 7/19/00 ............................................. 1 ................. 1 KTU 24-6H - Gamma Ray MWD - Measured Depth - 7/19/00 ................................................. 1 ................. 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Certified Receipt 7099 3220 0007 1780 6588 Alaska 0il & Gas Cons. Commission '~(., _~.., ~, 0 {~ . I 0 ,- · Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Marathon Oil Company Alaska R~" n Domestid. duction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 5, 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: [~( c~ . Q~-"2 ~ Marathon Oil Company KTU 24-6 / Kcnai Oas Field Print Reproducible KTU 24-6 - Probe Hole - Standard Digital Mudlog - 6/2/00 ...................................................... 1 ................. 1 KTU 24-6H - Horizontal Section - Standard Digital Mudlog - 6/2/00 ....................................... 1 ................. 1 KTU 24-6H - Sidetrack - Standard Digital Mudlog - 6/2/00 ...................................................... 1 ................. 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Certified Receipt 7099 3220 0007 1780 6588 Received bYRE C E~ Date: Alaska 0it & t,a:, Cons. Commissior~ Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alaska i,...4ion Domestic Production Marathon Oil Company P.Q. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 29 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA AIRBORNE EXPRESS The following well logs are enclosed: Marathon Oil Company KTU 24-6H / Kenai Oas Field Iq?.o?3 Print Reproducible KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H KTU 24-6H - Dipole Sonic Imager Natural Gamma Tool - 7/10/00 ............................................................. 1 - Dipole Sonic Imager Natural Gamma Tool, *True Vertical Depth* - 7/10/00 ....................... 1 - Natural Gamma Tool - 7/10/00 ................................... ' ............................................................ 1 - Natural Gamma Tool, *True Vertical Depth* - 7/10/00 ......................................................... 1 - Directional Survey - 7/10/00 ................................................................................................... 1 - Density, Neutron, Gamma Ray, Caliper, *True Vertical Depth* 7/8/00 ................................. 1 - Array Induction, MCFL, Gamma Ray, Caliper, *True Vertical Depth* - 7/8/00 ................... 1 - Array Induction, MCFL, Gamma Ray, Caliper, *Platform Express* - 7/8/00 .... '. ................... 1 - Density, Neutron, Gamma Ray, Caliper, *Platform Express* - 7/8/00 ................................... 1 - Gamma Ray, Caliper, *Platform Express* - 6/29/00 .............................................................. 1 - Array Induction, MCFL, Gamma Ray, Caliper, *Platform Express* - 6/29/00 ...................... 1 - Comb. Magnetic Res. Tool, Gamma Ray, Caliper, *Platform Express* - 6/29/00 .................. 1 - Natural Gamma Tool - 6/29/00 ............................................................................................... 1 - Density, Neutron, Gamma Ray, Caliper, *Platform Express* - 6/29/00 ................................. 1 - Dipole Sonic Imager, Natural Gamma Tool - 6/29/00 ............................................................ 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Received ~.y~~ Date: ~ /~}/~ / A subsidiary of USX Corporation Environmentally aware for the long run. ^ui-16-O0 09:08pm From-MAI~ATHON OIL +9155646489 T-078 P.OZ/O~ F-046 Reg~:,'-q - Alaska Domestic Pfc ~¢tion Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/.~61-5311 August 17, 2000 Mr. Blair Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Field: Kenai Gas Field Well: KTU 24-6H Permit No.: 199-073 APl Number: 50-133-20490 Project; Coil Tubing Unload Operation Dear Mr. Wondzell' Attached please find FORM 403 - APPLICATION FOR SUNDRY APPROVAL for the KTU 24-6H well. We intend to utilize coil tubing on approximately August 18*h, 2000 to unload the completion fluid from this recently drilled wellbore, Your earliest attention is thus appreciated, Please cell me if there is any additional data that can be provided. I can be reached at 907-564-6303 (work) or 231-3775 (pager), Ralph d. Af~ ~ Advanced Production Engineer RECEIVED AUG 17 2000 AJa~ 0~ & Gas C0,~s. C0mmis~iefl ~chora§e,,, A subsidiary of USX Corporation Environmentally aware/or [he long run. Aug-'1 ?-00 02:1?am F rom-MARATHON 01L +g155546489 T-034 (' STATE OF ALASKA { ALASKA OtL AND GAS CONSERVATION COMMISSION APPLICATION FOR ;SUNDRY APPROVALS P.02/02 F-05g 1, Typ~ of Request: Abandon Suspend__ Operation Shutdown AIt~ Casing -- RepairWefl Plugging__ Cl~ange Approved Program ~ Pull Tubing__ Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3, Addmas P. O, Box 196168, Anchorage, AK 99~1~-6168 4. Location of Well at Surface 37 FNL & 4168' FWL, Sec, 7, T4N, R11W, SM At top of Productive Interval 341' FSL & 3718' FWL, Sec. 6, T4N, R11W, SM. At Effective Depth At Total Depth 150~ FSL & 2334' FWL, Se~, 8, T4N, R11W, Plebent wei'Co;~ion sur"i~a~y ...... Total Depth: measured tl3960 true vertical 8744 Effective Depth: measured 10960 true vertical 8744 feet feet feet S. Type of Well: Development Exploratory Stratigraphi~ Service ORIGINAL 6. Datum Elevation (DF or KB) BT KB above MSL feet ?. Unit or Property Name Kenai Ty~neK unl~ $. Well Number KTU 24-6H Permit Number 189-073 lO, APl Number ~O-133-204g0 11. Field/Pool Kenal Gas Field/TyoneK Unload Well w/Coil Tubing Casing Structural Conductor Su~ace Intermediate PrecluSion Liner Perforation Depth: measured Length 130 1494 Size Cemented Measured Depth True Vertical Depth 20" Driven 130 130 9-~/8" 775 sks ~300 5299 Open hole from 883~1 true vertical Open hole from 8674.8744 Tubing (size, grade, and measured depth) 8B95' of 4-1/2" 12.6 ppf L-eO tbg w/AB Modified Buttress Connections Peel(ers and S$$V (type and measured depth) Baker Model FA.1 at 8.~q8' MD wt4-1/Z' 12.6 ppf L-80 Hydrl1521 tail pipe to 9t08' MD 13, Attachments ...... Description summary of Proposal ~ Detailed Operatlons'~rogram ~ ~4. ¥~tl~ated Date for Comm~cing Qperation 16. status of Well Classification a~:' ' --' 8/17/2000 '~6,'lf PmP0sal was verbalJy ApproQed Oil Gas X Nam~ of Appmver ~ Date Approved se~lca ........... %\\ ..... ~ ''~ ~" " FOR CbMMISSION USE ONLY c~nditions Of'Approval: ~_l~tify Commission so represen~Ive ma~. witness .... Plug Integrity.._ Bop Test_~ Location Clearance Mechanical Integrity Test__ Subsequent Form Required I0- ~ o ~ Appro~,e~ Dy Order of the C~mmisaion F~m lO-a03 R~v, o6q5186 ' BOI5' Sketch Suspended~ Date 8117r2ooo Sdbffllt InlTrlpi~eate Commissioner )RIGINAL SIGNED BY Taylor Seamount Approved ~p~, Re~_r~ · RECEIVED AUG 1 T ~ "~ ,,j , .Alaska 0~, & Gas Co;~s. Commissior~, ~c~omge Aul-l~-O0 O9:OBpm From-MARATHON OI L +g15554648g T-O~8 P.04/05 F-048 MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 24-6h AFE 9204399 Coil Tubing Unload Procedure Objective; Use coil tubing to jet-in well KTU 24-6H (Horizontal Tyonek Sand completion) which has not unloaded the completion fluid following initial drilling. Procedure: Mix 500 bbls of 3% KC! water. MIRU Dowell Schlumberger 1,75" OD coil tubing and nitrogen equipment on short string. Set up Marathon gas buster and open top tank with choke and flowback iron. Pressure test coil tubing and BOP equipment to 4,500 psi bleeding off to open top tank, Commence RIH circulating well with 3% KCl water. Clean hole noting any solid returns from open hole. Pull back into tail pipe and up hole to desired depth for initial unloading, Displace coil tubing with nitrogen and commence RIH jetting with nitrogen at 300 to 500 SCF/min rate. Work CT w/caution through: · Chemical injection nipple at 1027' MD · ProMore Gauge at 8482' MD CMU Sliding Sleeve at 8518' MD . Continue to RIH and jet as necessary to unload well, Note tubing tail is at 9108' MD, POOH and allow well to flow, Note that well should not be drawn down below 1.000 psig following unloading, Shut-in well. RD coil tubing, Secure well and clean up location. 4. Produce well to clean up as per engineer's instruction. 8~43 AM 08/17/00 ~\ALAR S01\CO MMON~DRLG~KG F~WELLS~klu24-6h\CoiltbgprO,(10c RECEIVED AUG 17 2000 Alaska 0i4 &,Gas Cons. Commission ~chora~e Au~-16-00 09:08pm F rom-MARATHON O I L +91558484ft9 T-021t Kenai Gas Field Well KTU 24-6h, Pad 41-7 Marathon Oil Co., Alaska Region P,O~/05 F-04; 20", 133#, K-55 Drive pip~ @ 130' 13-3/8", 68#, L-80, BTC Casing @ 1494' Cmt w/580 sk~ of Class G 9-5/$", 40#, L-80, BTC Casing @ 5300' Cmt w/775 sks of Class O Halliburton safety valve landil~g nipple @ 1027' w/X-profil~ (ID -- 3.813") 1/4", 0.049" WT control line to surfaco Baker CMU sliding sleeve @ 8518' (37°hole angle) w/X-profil~ (ID --- A?I: 50-133-20490 RT-GL: 21.6' RT-THF: 18.90' 37' FNL, 4168' FWL Sec. 6, T4N, RIIW,,S.M. Trec cxn = 4-314" Otis Tubing: 4.1/2", 12.6 ppf, L-80, AB-Mod, Butt. Packer tailpipe: 4-1/2", 12.6 ppf, L-80, Hydril 521 Packer Fluid: 9.7 ppg Prnmore pr~ss~r~ltemperat~re gauge @ 11482' (35°hole angle) wl 7/16" OD electric cable, dual-armored, Baker model FA-I p,rmanent packer ~ 8595' ealbote. [approx. 43 "hole~ angle) 6" openTvDhOlegT09, -t° 10,960'g744, MD 7", L-80 Casing @ 8830' Cmt w/646 sks of Cla,q~ G 26~ BTC: 0' - 5384' 29# BTC: 5384' · 5926' 299 Hydril 521', 5926' - 85317 Round-nose Re-entry guide @ 9108' (gt~hole angle) ID = 3.725" no-go, OD ~ 4-15/16" Last Rev: JGE, 8/3100 RECEIVED AUG 1 7 2000 Alaska Oii& Gas Cons. Commission Anchorage Alaska ~ -~n Domestk . eduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 1, 2000 Alaska Oil & Gas Conservation Commission Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following well logs are enclosed: Marathon Oil Company KTU 24-6H i~ q o 0t~ Kenai Q~ Field Print Dipole Sonic Imager Natural Gamma Tool - July 10, 2000 .................................................... 1 Dipole Sonic Imager Natural Gamma Tool, *True Vertical Depth* - July 10, 2000 .............. 1 Natural Gamma Tool - July 10, 2000 ...................................................................................... 1 Natural Gamma Tool, *True Vertical Depth* - July 10, 2000 ................................................ 1 Directional Survey ~ July 10, 2000 .......................................................................................... 1 Density, Neutron, Gamma Ray, Caliper, *True Vertical Depth* - July 8, 2000 ..................... 1 Array Induction, MCFL, Gamma Ray, Caliper, *True Vertical Depth* - July 8, 2000 .......... 1 Array Induction, MCFL, Gamma Ray, Caliper, *Platform Express* - July 8, 2000 .............. 1 Density, Neutron, Gamma Ray, Caliper, *Platform Express* - July 8, 2000 ......................... 1 Please sign and return confirming yon have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Certified Mail Receipt 7099 3220 0007 1780 6540 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL Reproducible Received by:~'-~~.,~ Date: P, Ub U o cvuv Alaska 0il & Gas Cons. commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alask~a, ,egion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 7, 2000 Alaska Oil & Gas Conservation Commission Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL HandDelivered Enclosed are the following samples collected for Marathon's KTU 24-6H Kenai Gas Field Well. KTU 24-6H - Kenai Gas Field Dry Samples Depth From Depth To (Feet) (Feet) Box No. 5,300 5,710 lA 5,710 6,030 2A 6,030 6,320 3A 6,320 6,700 4A 6,700 7,070 5A 7,070 7,450 6A 7,450 7,850 7A 7,850 8,270 8A 8,580 9A 8,580 8,860 10A 8~838 9,095 1 lA 8,850 8,940 12A 8,860 9,030 13A 9,095 9,440 14A 9,440 9,830 15A 9,830 10,120 16A 10,120 10,450 17A 10,460 10,960 18A Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Enclosures Hand Delivered A subsidiary of USX Corporation Received by: [!J.Jt.~ 00 !~ ~....,'] .... ~%,;,i ~' " Date: Environmentally aware for the long run~ ,,,",. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount,,,~P~ Chairman Blair Wondzell, P. I. Supervisor Lou Grimaldi FROM' ~ . SUBJECT: Petroleum Inspector DATE: July 27, 2000 Rig BOPE Inspection Glacier Drilling #1 Inlet Drilling (Contractor) NON-CONFIDENTIAL Thursday~ July 27, 2000; I traveled to Marathons Kenai Gas field to deliver our new BOP test form and discuss proper filing and naming conventions that will assist Bob Fleckenstein (A.O.G.C.C.) in the database entry. While there I made a short tour of the rig and found all to be apparently in good shape. The rig seems to be well maintained and operating properly. I spoke with George Brewster (Inlet Drilling Toolpusher) about some modifications to the "Blooey line" that had been required by the BLM and found them to be well in compliance with our regulations. ~, The area surrounding the rig is well maintained and although somewhat congested, it seemed to me that the best use of space had been accomplished. Summary: I made a visit to CC#1 to discuss changes in the BOP test form and make a tour of the location. No problems were noted. Cc;~. Pete Berga (Marathon Drilling Superviser) BOP lnsp Glacier .doc MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H ~c.,~,_ ~.-~ ~ 29-May-00 Rig down and move rig to KTU 24-6H. 30-May-00 Nipple up diverter system. Work on derrick. Change rams in BOP stack. 31-May-00 Weld on mast. Strap BHA and drill pipe. Fill pits with water. 1-Jun-00 Finish Welding on crown. Clean and paint. Accept rig. Raise derrick. Set wind walls and stairs. Rig up top drive. 2-Jun-00 Pick up top drive. Function test diverter system. Pick up drill pipe stand in derrick. 3-Jun-00 Make up BHA. Spud well. Drill to 830'. 4-Jun-00 Drill to 1504'. Wiper trip. Circulate and condition mud. POH. 5-Jun-00 Finish POH. Rig up and run 13 3/8" casing. Cement. 6-Jun-00 Finish cement job. POH with stab assembly. Nipple down diverter system. Weld on starting head and test. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 3-Jun-00 Make up BHA. Spud well. Drill to 830'. 4-Jun-00 Drill to 1504'. Wiper trip. Circulate and condition mud. POH. 5-Jun-00 Finish POH. Rig up and run 13 3/8" casing. Cement. 6-Jun-00 Finish cement job. POH with stab assembly. Nipple down diverter system. Weld on starting head and test. 7-Jun-00 Nipple up and testing BOPS. 8-Jun-00 Finish test BOPE. Pick up DP. Pick up BHA. TIH. Test casing to 15 psi. Drill cement, float equipment and 20' new formation. Run leak off test. Displace mud system. 9-Jun-00 Drilling F/1525'-2521'. Make wiper trip to casing. Drilling F/2521'-3250'. ,~IARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKRJKenai Peninsula/KTU 24-6H 10-Jun-00 Drilling F/3250'-4039'. Wiper trip to 2521'. Drilling F/4039'-4383'. 11-Jun-00 Drilling F/4383'-5200'. 12-Jun-00 Drilling F/5200'-5300'. TD F/Intermediate casing Circulate bottoms up. Trip out of hole to 1500'. Cut drill line. Trip in hole and circulate hole clean to run 9 5/8" casin! 13-Jun-O0 Finish circulate hole clean. Trip out of hole and lay down MWD and mud motor. Install casing rams in BOPS and test same. Rig up casing crew. Running a 9 5~8" casing. 14-Jun-00 Finish run and cement 9 5~8" casing to 5300'. WOC. Nipple down BOPS and set slips. Cut off casing. Nipple up 13 3/8" 3m x 11" 5m multi-bowl. Tubing spool and test 2400 psi. Nipple up BOPS. 15-Jun-00 Finish nipple up BOPS. Test BOPS. 250 psi Iow/5000psi high. Change out 3 1/8" manual valve and blind ram elements. 16-Jun-00 Finish repair blind rams and manual choke line valve. Test same OK. Test casing 2600 Pick up mud motor and MWD. Surface test equipment. Trip in hole with BHA. Pick up 4" drillpipe. Trip in hole. Drill cement and float equipment and 25' formation. ti' _.4ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 17-Jun-00 Drilling F/5535'-6500' 18-Jun-00 Drilling F/6500-6667'. Wiper trip to 5300'. Drilling F/6667'-6860'. Trip out of hole F/bit #4. 19-Jun-O0 Trip in hole w/bit #4. Drilling F/6860'-7390'. 20-Jun-00 Drilling F/7390'-7426'. Wiper trip to 6790'. Drilling F/7426'-7855'. 21-Jun-00 Drill to 7960'- POH to casing shoe. Hole not taking correct amount of fluid. RIH. Circulate out gas cut mud. Increase mud weight to 11.3 ppg. 22-Jun-00 POH. Test BOP equipment. Make up new drilling assembly. RIH to 9 5/8" shoe. Cut drilling line. Continue to RIH. 23-Jun-00 Continue to RIH. Circulate out gas. Rotary drill and directional drill from 7960' to 8205'. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 24-Jun-00 Directional drill from 8205' to 8247. Repair mud pump. Drill ahead to 8336'. 25-Jun-00 Directional drill to 8463'. POH. LD BHA. 26-Jun-00 Change BHA. RIH with bit 6. Drilling ahead, building angle to 60 degrees. 27-Jun-00 Drilling ahead building angle to 60 degrees. 28-Jun-00 Directional drill from 8724' to 8840'. Circulate and sweep well bore. Back ream out of th( into vertical section. 29-Jun-00 Circulate and condition hole. POOH. Rig up to E-Log. First log run tagged up at 8310". Log out of hole. 30-Jun-00 Logging. RIH for wiper trip prior to running 7" casing. NIARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKTU 24-6H 1-Jul-00 RIH. CBU. POH to verticle section of well. Circulate and reduce mud weight to 12.0 ppg. Continue to POH. 2-Jul-00 Continue to POH. Lay down BHA. Change top pipe rams to 7". Rig up to run casing. Run 7" casing. 3-Jul-00 Run 7" casing. Work to bottom @ 8830'. Circulate and condition mud. Cement. Displace with mud. Rig down cementing equipment. 4-Jul-O0 Lay down casing tools. Attempt to install 7" pack off. Nipple down to inspect hanger and pack off. Machine pack off. Nipple up BOP. Install pack off. 5-Jul-00 Test packoff. Test BOP equipment. Make up BHA and RIH. Attempt test casing. 500 psi leak over 30 minutes. Re-test pack off. Trip out of hole. 6-Jul-00 Finish trip out of hole. Pick up 7" RTTS. Trip in hole testing casing at 2000' intervals to top of cement @8559'. Test casing F/8525' to surface Fl30 minutes @ 3100 psi. Test OK. Losing pressure below packer through show track. Release packer. Trip out of hole. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 8-Jul-00 Stage drill F/8860'-9030'. TD pilot hole. Circulate and condition mud. POOH to log. 9-Jul-00 POOH. Rig up to log. 1st Log: AIT/DEN/NEU F/9005'-8100' 2 runs. 2nd Log: SQNICINGTIGPIT. Stuck tool logging out at 8913'. Could not work free. Pull out of rope socket and rig down loggers. Trip in hole with overshot. Engage fish and work free. POOH with fish. 10-Jul-00 POOH. Lay down fish and tools. Full recovery RIH w/Bit to 9030'.. Circulate and condition hole. TOH. Rig up to log. Run #4: Sonic/NGT/GPIT F/9010-8830'. Rig down loggers. PU 20 jts 2 3/8" tubing and RIH wi4" drill pipe to set kick off plug. 11-Jul-00 RIH with cement stinger. Spot 80 sk, 17 ppg kick off plug from 9030'-8663'. POOH to 8400'. CBU. Hold 3100 psi on plug for 2 hrs. POOH. Test BOPE. 12-Jul-00 Finish repairing and testing BOPE. RIH to top of cement at 8597'. Drilled cement 8597'-8940' at 65'-300'/hr. CBU. POOH. P/U cementing stinger. 13-Jul-00 RIH with cement stinger on 4" drill pipe to 8940'. Spotted 60 sack, 17 ppg kickoff plug from 8940'-8650'. POOH to 8300'. CBU. POOH and LID stinger. RIH with rotaryassemblyto 8050'. Mixed mud and repaired top drive while WOC. 14-Jul-00 WOC. RIH. Tag cement at 8,675'. Drilled cement to 8940'. CBU. POOH. P/U 2 3/8" cement stinger. RIH with 4" drill pipe to 8940'. CBU m.,~RATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KTU 24-6H 15-Jul-O0 Circulate bottoms up at 8940'. Set kick-off plug #3. 112 SX class "G" cement mixed at 17.0 lb/gal. Estimated top of cement 8415'. Trip out of hole to 8000'. CBU. Trip out of hole and L/D tubing. Trip in hole with rotary assembly to 8050'. Circulate and wait on cement. 16-Jul-00 Trip on hole to top of cement at 8505' Drilling cement F/8505'-8845' with deill rate 35'-90'/hr. Circulate bottoms up. Trip out of hole. Pick up steerable assembly and MWD. Trip in hole to 8845'. Time drilling F/8845'-8847'. 17-Jul-00 Time and slide drilled F/8847'-8940'. MWD survey at 8912', 70 degrees. Projected survey at 8940' 77 degrees. Circulate bottoms up. Trip out of hole. Prep to set kick off plug #4. 18-Jul-00 RIH to 8,940'. Spotted 112 SKS, 17 ppg cement plug from 8,940' to 8,412'. POOH to 7,940'. CBU. POOH. Test BOPE. RIH with rotary assembly. 19-Jul-00 RIH. Drill cement from 8,375'. Circulate bottoms up. POH. 20-Jul-00 Continued to POOH. BHA. RIH. Worked on disc brakes. RIH to 8,838'. Time drilled off of cement plug to 8,848'. 21-Jul-00 Time drilled from 8,848' to 8,863'. Directionally drilled to 8,894'. MWD failed. CBU. POOH. .ATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY / 9g-ov- AKR/Kenai Peninsula/KTU 24-6H 22-Jul-00 POOH. BHA. RIH. Wash to bottom. Directional drill from 8,894' to 8,988'. 23-Jul-00 Back ream to shoe. POOH. BHA. RIH. Change over mud to 9.5 ppg. solids free FIo Pro mud. 24-Jul-00 Finished changing over mud system to 9.5 ppg FIo Pro mud. Directional drilling from 8,988' to 9,420'. 25-Jul-00 Drill to 9,438'. Circulate bottoms up. Pump out of the hole to 8,840'. Monitor well. RIH to 9,438'. Drill ahead to 9,867'. 26-Jul-00 Drill ahead from 9,867' to 9,926'. Circulate and condition mud. Raise mud weight to 9.8 ppg. Replace drive shaft on number 1 carrier motor. Pump out of the hole to 7" casing shoe. Circulate bottoms up. Monitor well. POOH. Test BOPE. 27-Jul-00 Tested BOPE. BHA. RIH to shoe. Cut drill line. Serviced rig and installed new drive line to #2 hydraulic pump. RIH. Drilled from 9,926' to 10,227'. 28-Jul-00 Drilled from 10,277' to 10,752'. Alaska [~ )n Domesb~., coduction Marathon Oil Company July 12, 2000 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Logs: Iq~.o2~l) Marathon Oil Company/Kenai Gas Field KBU 33-6 GP1T May 21, 2000 2) Marathon Oil Company/Kenai Gas Field lax ~ "Lq- (.e ~ Array Induction, MCFL Gamma Ray, Caliper, **Platform Express** June 29, 2000 3) Marathon Oil Company/Kenai Gas FieldKTU 24-6H Density, Neutron Gamma Ray, Caliper, **Platform Express** June 29, 2000 4) Marathon Oil Company/Kenai Gas Field KTU 24-6H Dipole Sonic Imager Natural Gamma Tool June 29, 2000 5) Marathon Oil Company/Kenai Gas Field KTU 24-6H Comb. Magnetic Res. Tool Gamma Ray, Caliper, **Platform Express** June 29, 2000 6) Marathon Oil Company/Kenai Gas Field KTU 24-6H Gamma Ray, Caliper, **Platform Express** June 29, 2000 7) Marathon Oil Company/Kenai Gas Field KTU 24-6H Natural Gamma Tool June 29, 2000 Print Reproducible A subsidiary of USX Corporation Environmentally aware for the long run. Re: KTU 24-6h - Revision to Wellhead - - PTD #1 o~ ~ 3 Subject: Re: KTU 24-6h - Revision to Wellhead - - PTD #199-073 Date: Mort, 08 May 2000 14:53:23 -0800 From: Blair Wondzell <blair__wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: J Gary Eller <JGEller~MarathonOil.com> CC: CEYoung@MarathonOil.com, PKBerga~MarathonOil.corn, Tom Maunder <tom_maunder~admin.state.ak.us> Gary, This is as we discussed. The 13-3/8" casing is to be cemented at 1500', the 9-5/8" at 5300' and the 7" at 9055". Your hazard section notes, and we agree, that all of the sands are expected to range from normally pressured to severely depleted. We agree that a 3K rated well head is all that is need on the 13-3/8" casing. Thanks for the documentation. Blair Wondzell, 5/8/00. J Gary Eller wrote: > Blair - This is a follow-up to our telephone conversation regarding well KTU 24-6h, which has been issued an approved Permit-to-Drill but has not yet spud. The information Marathon sent the AOGCC stated that the "A" wellhead section on that well would be a 13-3/8" SOW x 13-5/8" 5M. That information is incorrect. The "A" wellhead section will instead be 13-3/8" SOW x 13-5/8" 3M. > > Use of the 3000 psi wellhead will mean that we will only be able to test our BOPE to 3000 psi from when we drill out surface casing until we set intermediate casing. Once we set intermediate we will nipple up a 5000 psi wellhead and be able to test to the full 5000 psi rating of the BOPE. > > Use of the 3000 psi "A" section wellhead in no way compromises the design of the KTU 24-6h well. The 13-3/8" casing shoe design is based on a 12.5 ppg equivalent mud weight (925 psi at the shoe). The MASP of the 13-3/8" casing section using this criteria is 802 psi. > > Please contact me if you have any questions. I of I 5/8/00 2:54 PM TONY KNOI/VLE$, GOVERNOR ALASi~ OIL AND GAS CONSERVATION COHH]SSION September 28. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 P. K. Berga Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage. AK 99519-6168 Re: Kenai Unit KTU 24-6H Marathon Oil Company Permit No: 99-073 Sur Loc: 37'FNL. 4168'FWL. Sec. 7. T4N. R11W. SM Btmhole Loc. 1502'FSL. 2334'FWL. Sec 6. T4N. R1 lW, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bx.' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by contacting the Commission at 279-1433. Robert N. nstenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. g:\cmn\drlgtsterling~su44-10~.ogccptd.x! / ',.,,_, STATE OF ALASKA r! ALA OIL AND GAS CONSERVATION COM : PERMIT TO DRILL 210 AAC 25.005 SION la. Type of Work Drill~-] Re-Drillr~ lb. Type of well. ExploratorYr~ Stratigraphic Test[--'] Development oilr-~] Re-EntrYr"--] Deepen[~] Servicer'--] Development Gasr~ single zone~] MuEiple Zoner"--] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 87' KB feet Kenai Gas Field/Tyonek 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 A-028142 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 37'FNL, 4168'FWL, Sec. 7, T4N, R11W, S.M Kenai Unit Blanket Surety At top of Productive Interval 8. Well Number Number 341'FSL, 3718'FWL, Sec. 6, T4N, R11W, S.M KTU 24-6H 5194234 At Total Depth 9. Approximate Spud Date Amount 1502'FSL, 2334'FWL, Sec. 6, T4N, R1 lW, S.M. 10/1/99 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Line(unit boundary) 12500 feet 480 feet 6000 10861' MD/8749' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 7927 feet Maximum Hole Angle 89.5 o Maximum Surface 3083 psig at Total Depth (TVD) 8732' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 P E 80-100' 0' 0' 80-100' 80-100' 17-1/2" 13 3/8" 61 K-55 BTC 1500' 0' 0' 1500' 1500' 1010sx .---~ J~""' J"' m ~ ,, ~ 12 1/4" 9 5/8" 40 L-80 BTC 5300' 0' 0' 5300' 5300' 1110sx ~ % ~ ~ ~' ~ ~/jl 8 1/2" 7" 26 L-80 BTC 9055' 0' 0' 9055' 8732' 700sx "~' ,,, nRiGiNA, '"" L. Kenai Unit well KTU 24-6H will be directionally drilled to an estimated total depih of 10861' MD, 8749' TVD from the existing Kenai Gas Field pad 41-7.A vertical pilot hole will be drilled through the D-1 sand, logged and plugged back prior to kicking off the well and drilling the D-1 horizontally. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing Fear'~ Property Plat~"] BOP Sketch[~] Diverter Sketchr'~ Drilling Program~] Drilling Fluid Program{~ Time vs Depth Plot~"] Refraction Analysisr---~ Seabed ReportF--'] 20 AAC 25.050 Requirementsr-"] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P.K. Barge ~2/~ Title Drilling Superintendent Date 7/15/1999 Commission Use Only Permit Number IAPI Number IApprova, Date ISee Cover Letter ~ ~' O "~ '~ 50-- I ~ ~'' ~ 0 c,(.~ 0 ? C~ ~" ~"~' For Other Requirements Conditions of Approval Samples Required r-'lYes [~No Mud Log Required r--~Yes ~No Hydrogen Sulfide Measures [--]Yes [~No Directional Survey Required ~Yes r"-]No Required Working Pressure for BOPE F--}2M [---]3M ~5M r---~ 1OM [--"~ 15M Other: ~Of~tGINALSIGNED. ByRah., by order of ~-..,~ 5/'~ ~'~ .~" Approved by --....,,,e. N. {~hrief;-.-- Commissioner the Commission Date ~/-,t~ Form ~0-40~ Rev, 124-85 ~Url Submit in Triplicate DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KTU 24-6H PAD: 41-7 SLOT: NA REVISION NO.: 0 SURFACE LOCATION: TARGETS: Tyonek D-1 FIELD: Kenai Gas Field AFE No.: 9204399 TYPE: Development. DATE: 7/15/99 37' FNL, 4168' FWL, Sec. 7, T4N, R11W, S.M. 341' FSL, 3718' FWL, Sec. 6, T4N, R11W, S.M. BOTTOMHOLE LOCATION: 1502' FSL, 2334' FWL, Sec. 6, T4N, R1 l W, S.M. KB ELEVATION: GL ELEVATION: 87 ft. mean S.L. (est.) 66 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 3577 3577 Upper Beluga 4664 4664 Middle Beluga 5319 5319 Lower Beluga 6064 6064 Tyonek 7165 71 65 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) Sterling 3577 Upper Beluga 4664 Middle Beluga 5319 Lower Beluga 6064 Tyonek 7165 D-1 Coal base 8771 D-1 Sand 9055 TD 10861 POTENTIAL DEPTH(TVD) ~(:ts~ CONTENT 3577 gas/water 4664 gas/water 5319 :~'~ gas/water 6064 gas/water 7165 gas/water 8677 gas/water 8732 --~0~ ~ gas/water 8749 page 1 g:\cmn\drlg\kgf\weils\ktu 24-6h\246hprog.xls III. WELL CONTROL EQUIPMENT DIVERTER S'FSTEMS The diverter system will consist of a 20" X 3000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 20" weld on x 20 3/4" 3M . CASING HEAD: 13 3/8" SOW x 13 5/8" 5M. CASING HEAD: 13 5/8" 5M x 135/8" 5M. TUBING HEAD: 135/8"-5000M x 11" 5M. CHRISTMAS TREE: 11" 5M x 4 1/16" 5M psi single christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls IV. CASING PROGRAM: CASING DESCRIPTION SET SET HOLE TYPE SIZE WT. GRADE THREAD FROM TO(md/tvd) SIZE. CONDUCTOR: 20" 133 ppf SURFACE: 13 3/8" 61 ppf K-55 PE Surf 80-100/80- Driven 100 K-55 BTC Surf 1500'/1500' 17 1/2" INTERMEDIATE: 9 5/8" 40 ppf L-80 BTC Surf 5300'/5300' 12 1/4" INTERMEDIATE: 7" 26 ppf L-80 BTC Surf 9055'/8732' 8 1/2" PRODUCTION: OPEN HOLE COMPLETION CASING DESIGN SETTING FRAC GRD FORM PRSS DESIGN FACTORS SIZE WEIGHT GRADE DEPTH,TVD ~ SHOE @ SHOE MASP TENS COLL BURST 13 3/8" 61 ppf K-55 1500' 11.5 700 802 12.21 1.47 3.89 9 5/8" 40 ppf L-80 5300' 14.0 2480 3524 5.02 2.46 1.71 7" 26 ppf L-80 8732' 15.2 4087 3083 3.32 2.13 1.46 All tubulars are new. page 3 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls V. CEMENTING PROGRAM SURFACE: 13 3/8" 1500'/1500' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.8 ppg. 2 cu. ft./sk gal/sk hrs:min 50 % in open hole. 510 sks. TAIL SLURRY: Class "G" TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: + required additives. 1000 ft. 1 5.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole. 500 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating. 3. M/U stabin float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Run inner cementing string with stab-in sub and centralizer.( Baker has false rotary and slips.) 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry.' 11, Displace cement. (Regulations require that cement be brought to surface.) Sting out. 12. Check floats. 13. POOH with inner string. WOC 14. N/D diverter. Weld on casing head and N/U blowout preventers. 15. Test BOPE. Run wear bushing. page 4 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 9 5/8" @ 5300'/5300' =LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: 1000 ft. WEIGHT: 12.8 ppg. YIELD: 2.00 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 50 % ESTIMATED VOLUME: 900 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: 4800 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 50 % ESTIMATED VOLUME 210 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U cementing head and test all lines, 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U casing head and test. N/U BOP stack. 15. Test BOPE. Install wear bushing. page 5 g :\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 7" @ 9055'/8732' LEAD SLURRY · Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: ft. PPg. cu. ft./sk gal/sk hrs:min % sks. TAIL SLURRY ' Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 4800 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % excess in open hole. 700 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U cementing head and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made, 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug, 0. Displace cement with water. Reciprocate as long as possible. 1. Bump plug with 500-1000 psi over pumping pressure. Check floats. 2. WOC page 6 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 1500' 8.6-9.0 80-250 15-30 Freshwater gel 1500' 5300' 8.6-9.0 42-80 < 12 Freshwater gel/LCM 5300' 8825' 8.6-9.0 42-80 < 12 Freshwater gel/LCM 7927' 8732' 9.0-12.8 50-70 < 8 FLO PRO/KCL* 8732' 8749' 9.0-9.5 50-70 < 8 FLO PRO/KCL (PILOT HOLE) *Be switched over to FIo Pro by kickoff point. High mud weight may be required to keep the D-1 coal open. MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM SURFACE: No logging is planned for this interval. INTERMEDIATE 1: No logging is planned for this interval. PILOT HOLE: INTERMEDIATE 2: AIT-DSI-FDC-CNL(bottom 3000' of well) LWD(GR/RESISTIVITY) calibration. LWD-GR-RESISTIVITY . PRODUCTION: LWD-GR-RESISTIVITY. MUD LOGGING The well will be mud logged from 1500' md(casing point) to TD at 10861' md. CORING PROGRAM TESTING PROGRAM page 7 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS See attached sheet for anticipated b3ttomhole pressures for all sands. Lost returns are possible. Hydrogen sulfide gas has not been encountered in any well in the Kenai Gas field IX. OTHER INFORMATION DIRECTIONAL PLAN DESC MD TVD INCL AZIM NORTH WEST VERT COORD COORD SECTION RKB 0 0 0 0 KICKOFF 7927 7927 0.0 298.7 build @ 10 deg/100ft HOLD 9055 8732 89.4 298.7 Total Depth 10861 8749 89.5 298.7 0 0 0 0 0 0 282 515 0 1150 2100 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) No serious interference exists. DEPTH (MD) page 8 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls X. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1500' md/1500' tvd. Run and cement 13 3/8" casing. WOC. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE 1: Drill out float equipment and make 5-10' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" hole to 5300' md/5300' tvd. Lost circulation is possible through this entire interval. Make wiper trip. Pull wear bushing. Run and cement 9 5/8" casing. WOC. N/U 1.3 5/8" 5M x 13 5/8" 5M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 2600 psi. PILOT HOLE: Drill float equipment and 10' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" hole from 5310' md/tvd to 8825md/tvd'.(Note: LWD tools will be run while drilling through the D-1 sand). Make a wiper trip, POOH. Log. RIH open ended and spot cement plug from 8825' to 7600'. POOH. WOC. INTERMEDIATE 2: Dress off cement plug. Kick off well and directionally drill 8 1/2" hole to 9055' md/8732' tvd as per the directional program. POOH. Pull wear bushing. Run and cement 7" casing. N/U tubing spool and test. Test BOPE to 250/5000 psi. Run wear bushing. RIH with 6" directional assembly. Test casing to 3100 psi. PRODUCTION: Drill a 6" horizontal hole from 9055' md/8732' tvd to 10861' md/8749' tvd as per directional program. The goal is to get +/- 2000' of total section in the D-1 sand depending on hole conditions. page 9 g :\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls NOTES: MASP CALCULATIONS: Surface casing: 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x.052x 1500' -(.115 x 1500') MASP = 925 psi- 173 psi MASP = 802 psi. Intermediate casing: 9 5/8". MASP -- Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP -- (14.0 ppg + 1.0 ppg) x .052 x 5300' - (.115 x 5300') MASP = 4134 psi - 610 psi MASP = 3524 psi. Intermediate casing: 7". Set in the pay sand. MASP = Formation pressure - Hydrostatic pressure of gas column. MASP = 9.0 ppg x.052x8732'-(.115x8732') MASP = 4087 psi- 1004 psi MASP = 3083 psi. Production casing: None. Open hole completion. Cementing The cementing of the 9 5/8" casing may be done in stages. The actual procedure and amount of cement will be determined once the severity of lost cirulation is determined. Tubulars All tubulars are new. page 10 g:\cmn\drlg\kgf\wells\ktu 24-6h\246hprog.xls X. POTENTIAL HAZARDS Well KTU 24-6H To comply with state regulations the Potential Hazards section and the well shut in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influ)~ is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 3577' tvd/3577'md to total depth of the well. These sands will range from normal pressured to severly depleted and lost circulation and differential sticking are protential hazards. The Flopro mus system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. There are no well interference hazards. page 10 n:\drlg\kgf~wells\ktu 24-6h~.46hp rog.xls Marathon Oil Well KTU 24-6H Diverter Flow line 20 3/4" 3M Diverter IDiverter Spool 16" Automatic Hydraulic Valve Marathon Oil Well KTU 24-6H BOP Stack JFIow Nipple J J135/8" 5M Annular Preventer J JFIow Line J 13 5/8" 5M Double Ram Preventer J J"----- J 3 1/8" 5M Manually J Operated Valves ~> 13 5/8" 5M Single J ~J~ Ram Preventer J ~> I J Pipe Ram J JBlind Ram J JPipe Ram J~ J3 1/8" 5M Manually J JOperated Valve , I 1 J3 1/8" 5M Hydraulically Operated Valve SENT BY:Marathon 0tl Company ' 8-26-99 ' 3'20PM ' Marathon Oil Well KTU 24-6H Choke Manifold Anchorage-* 907 276 7.542:~ 2/ 2 [~To Gas Buster ITo Blooey Line ;Bleed off Lin~'io I I Shakers 2 g/16" 10M Swaco Hydraulically Operated LE_rom BOP Stack Ch_0ke .... 3 1/8" 5M Manually Adjustable Choke I X~. /"~ I I K[I)I4Y 3' X la' x I I ...... I DITA 34 m I i 5w ~ I I I I I I ..... I ~[TA 34~ , I 75 ~ , 75 ~ ' 14' 14' ]- I O~Y~ t4' 14' iL ' ~=- ~ ~ · ~ , , ' I ~ ...... ~ I u~ i' ~ ..... , ~__.~.I ..... _ __.~.. ........r · . i j ii ii I = ~ ~ I'/ ~ F~~ _ ~-~ ~..~ ......... I .... I " ' .... . ..~ .. 1200 - 16O0 - 2000 240O 2800 ~ 5200 ,.i..,., ~ 5600 (D 40OO 0 4400 .-- ~ 4~oo I---. 5200 I V ~6oo 6OO0 64.0O 68O0 7200 7600 8000 840O 8800 ,L 13 3/8 Casing MAIt_,THON Oil CompanS, Structure: Pad 41-7 Well : KTU24-6H ~ Field : Kenai Gas Field Location : Kenai Peninsula, Alaska l <- West (feet) 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 I I I I I I I I I I I I I I I I I I I I I I I I RO0 1600 1400 :24-6I ~ 7 Casing 400 KTU24-6H Target 1 20-APR-gg 2OO KOP 0 1200 lOOO 2OO L 9 5/8 Casing KOP 5.00 6.00 9.00 ~.. 50.00 ~ 70.00 7 Casing == TD i r [ i i I i i i i i i i l 0 400 800 1200 1600 2000 2400 Vertical Section (feet) -> Azimuth 510.00 with r~ferenee 0.00 N, 0.00 W from slot 24-6 JCreated by jones ~'or: P I~ergar Dote plotted: 15-dul-lg99 Plot Reference is KTU 2~-6H Vet. Coordinates ore in feet reference clot 2,~-6.I True Vertical Depths or~l~lmnce Est. RKB. Creoted by jones For'=. P Boreal Dote plotted: 15-Ju1-1999 Plot Reference is KTU 24-6H Ver. ~4. Coord[notes om [n feet r~fer~nce slot 24-62 .True Ver~icol Oepl:he ars reference "~t. RKB, I INTlq Mi _',ATHON Oil Company'", Sfruafure: Pad 41-7 Well : KTU24-6H ~. Field : Keno! Gas Fi'eld Looaflon : Kenal Peninsula. Alaska l <- West (feet) 520 480 44O 4O0 ,360 320 280 240 200 I ~6o ~.. 12o '~ 8o o Z 4o 120 160 200 240 280 360 320 280 240 200 160 120 80 40 0 40 80 120 160 ,,,,,, ~, ,~,,,,,,,,, ,~,,,,,,,, 2100 ~, \ ~, 2900 ~ 1900 2000 t,, \ ~ 2800 \ t; 1800 '1 1900 ~, \\ t2700 \ J, 1700 1800 ~. \\ 12600 ~, '~ 1500 \ ,,. ,,., 0 \ 1400 \ \ 1500 \ \ ~. 2300 8~o3 ,, ,t,,oo\~ ~- \ ~ \ 1300 ~'(~0'~\ ~ 2200 13 \~ '~, 8500 1200 ~ \'\~,., 1201 1500 1100 ~ ~' 1~%" '., 8400 '~ \ ~,8~oo 1~ oo \ ~.~ 2000 ,.,82001 ~) \ e, ,e,ooo/ ;.o\ -~oo ,,/,ooo 1 ~00 1800 '~ 1700~ \ / / ,~oo~, 15oo ~, 14-00 \ ':::oX 80O 1900'~. ,360 520 280 240 200 160 120 80 40 0 40 80 120 160 <- Wesf (feel) 520 48O 443O 560 ;320 280 240 200 ^ 1SO I Z O 120 4O 4O 12O ! 60 200 2~0 :Creo~ed by jone~ [~or: P Bergel Dote plotted: 15-Ju1-1999 Plot Reference is KTU 24-6H Vet. ~4. : .Coord~notes om ;n feet reference slot 2¢-6. t True Vertical DepU~ ore r~femncs E~t. RKB. I 25OO 2200 2100 2OOO 1900 1800 1700 1500 '~- 1500 1400 O Z 1500 1200 1100 1000 900 800 700 600 500 M qATHON 0il Compai y Structure : Pad 41-7 Well : KTU24-6H Field : Kenai Gas Field Location : Kenai Peninsula, Alaska l 4- West (feet) 2 ! O0 2000 1900 1800 1700 1600 1500 1400 1.300 1200 1 ~i O0 1000 900 800 I I I I I I I I I I I I I I I I I I I I I I I I I I ',~ 7500 ~ ~. 7100 ~ ',~ ~6800 ~ ...6500 '~ ,,~ 6200 ~%5900 56o~ E~T.D. &: End of Build - 8748.95 Tvd, 1559.00 N, 1854.11 W i i i i i i i i i i i i i i i , i i i i i i i i i i l 21 O0 2000 1900 1800 1700 1600 1500 1400 1500 1200 11 O0 1000 900 SO0 <- West (feet) 24OO 250O 22OO 2100 2000 1900 1800 1700 1600 1500 1400 1Z~O 1200 1100 1000 900 8OO 700 600 500 MARATHON Oil Company Pad 41-7 KTU24-6H slot 24-6 Kenai Gas Field Kenai Peninsula, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : KTU 24-6H Ver. ~4 Our ref : prop3407 License : Date printed : 15-Ju1-1999 Date created : 20-Apr-1999 Last revised : 15-Ju1-1999 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000.N Slot location is n60 27 33.911,w151 14 45.875 Slot Grid coordinates are N 2361974.310, E 275073.220 Slot local coordinates are 15.42 S 4166.16 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference Northis True North MARATHON Oil Company Pad 41-7.KTU24-6H Kenai Gas Field. Kenai Peninsula. Alaska PROPOSAL LISTING Page 1 Your ref : KTU 24-6H Ver. #4 Last revised : 15-2u1-1999 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 0.00 0.00 310.00 0.00 0.00 N 0.00 W 0.00 0.00 500.00 0.00 310.00 500.00 0.00 N 0.00 W 0.00 0.00 1000.00 0.00 310.00 1000.00 0.00 N 0.00 W 0.00 0.00 1500.00 0.00 310.00 1500.00 0.00 N 0.00 W 0,00 0.00 2000.00 0.00 310.00 2000.00 0.00 N 0.00 W 0.00 0.00 2500.00 0.00 310.00 2500.00 0.00 N 0,00 W 0.00 0.00 3000.00 0.00 310.00 3000.00 0.00 N 0.00 W 0.00 0.00 3500.00 0.00 310.00 3500.00 0.00 N 0.00 W 0.00 0.00 4000.00 0.00 ~310.00 4000,00 0.00 N 0.00 W 0.00 0.00 4500.00 0.00 310.00 4500.00 0.00 N 0.00 W 0.00 0.00 5000,00 0.00 310.00 5000.00 0.00 N 0.00 W 0.00 0.00 5500.00 0,00 310.00 5500.00 0.00 N 0.00 W 0.00 0.00 6000,00 0.00 310.00 6000.00 0.00 N 0.00 W 0.00 0.00 6500.00 0.00 310.00 6500.00 0.00 N 0,00 W 0.00 0.00 7000.00 0.00 310.00 7000.00 0.00 N 0.00 W 0.00 0.00 7500.00 0,00 310.00 7500.00 0.00 N 0.00 W 0.00 0.00 7927,00 0,00 310,00 7927.00 0.00 N 0.00 W 0.00 0.00 KOP 8027.00 3.00 310.00 8026.95 1.68 N 2.01W 3,00 2.62 8127.00 6.00 310.00 8126.63 6.73 N 8.01 W 3,00 10.46 8227.00 9.00 310.00 8225.77 15.11 N 18.01 W 3.00 23.51 8260.33 10.00 310.00 8258.64 18.65 N 22.23 W 3.00 29.02 8360.33 20.00 310.00 8355.11 35,27 N 42.03 W 10.00 54.86 8460.33 30.00 310.00 8445.63 62.40 N 74,36 W 10.00 97.07 8560.33 40.00 310.00 8527.44 99.22 N 118.24 W 10.00 154.36 8660.33 50.00 310.00 8598,06 144.61N 172.34 W 10.00 224.98 8760.33 60.00 310.00 8655.35 197.20 N 235.01 W 10.00 306.79 8860.33 70.00 310.00 8697.55 255.38 N 304.35 W 10.00 397.31 8960.33 80.00 310.00 8723.40 317.39 N 378.25 W 10.00 493.78 9054.63 89.43 310.00 8732.08 377.68 N 450.10 W 10.00 587.57 9068.39 89.43 310.00 8732.22 386.52 N 460.64 W 0.00 601.32 9168.39 89.43 310.00 8733.21 450.80 N 537.24 W 0.00 701.32 9268.39 89.44 310.00 8734.19 515.07 N 613.84 W 0.00 801,31 9368.39 89.44 310.00 8735.17 579.35 N 690,44 W 0.00 901.31 9468.39 89.45 310.00 8736.14 643.62 N 767.04 W 0,00 1001.30 9568.39 89.45 310.00 8737.10 707.90 N 843.64 W 0.00 1101.30 9668.39 89,45 310.00 8738.06 772.18 N 920.24 W 0.00 1201.29 9768.39 89,46 310.00 8739.01 836,45 N 996.84 W 0.00 1301.29 9868.39 89.46 310.00 8739.95 900.73 N 1073.45 W 0.00 1401.28 9968.39 89.47 310.00 8740.89 965.00 N 1150.05 W 0.00 1501.28 10068.39 89.47 310.00 8741.82 1029.28 N 1226.65 W 0.00 1601,27 10168.39 89.47 310.00 8742.74 1093.56 N 1303.25 W 0.00 1701.27 10268,39 89.48 310.00 8743.66 1157.83 N 1379.85 W 0.00 1801,27 10368.39 89,48 310.00 8744.57 1222.11 N 1456.45 W 0.00 1901.26 10468.39 89.48 310.00 8745.47 1286.38 N 1533.05 W 0.00 2001.26 10568.39 89.49 310.00 8746.36 1350.66 N 1609.65 W 0.00 2101.25 10668.39 89.49 310.00 8747.25 1414.94 N 1686.26 W 0.00 2201.25 10768.39 89.50 310.00 8748,14 1479,21 N 1762.86 W 0.00 2301.25 10861.40 89.50 310.00 8748.95 1539.00 N 1834.11 W 0.00 2394.26 TD 10861,41 89,50 310.00 8748.95 1539.00 N 1834.11 W 0.01 2394.27 All data is in feet unless otherwise stated. Coordinates from slot 24-6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2394.27 on azimuth 310.00 degrees from wellhead. Total Dogleg for wellpath is 89.50 degrees. Vertical section is from wellhead on azimuth 310.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7.KTU24-6H Kenai Gas Field.Kenai Peninsula. Alaska PROPOSAL LISTING Page 2 Your ref : KTU 24-6H Ver. #4 Last revised : 15-Ju1-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 7927.00 7927.00 0.00 N 0.00 W KOP 10861.40 8748.95 1539,00 N 1834.11 W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOW 1750.00 1750.00 O.OON O.OOW 13 3/8" Casing 0.00 0.00 O.OON O.OOW 5287.00 5287.00 O.OON O.OOW 9 5/8" Casing 0.00 0.00 O.OON O.OOW 9049.19 8732.00 374.18N 445.94W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised KTU24-6H Target i 20 8732.00 150.00N 390.00W 20-Apr-1999 KTU24-6H Target PD 2 8749.00 1150.00N 2100.00W 20-Apr-1999 MARATHON Oil Company Pad 41-7.KTU24-6H Kenai Gas Field. Kenai Peninsula. Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : KTU 24-6H Ver. #4 Last revised : 15-Ju1-1999 Dogleg Vert G R I D C 0 0 R D S Deg/lOOft Sect Easting Northing 0.00 0.00 310.00 0.00 O.OON O,OOW 0.00 0.00 275073.22 2361974.31 500.00 0.00 310.00 500.00 O.OON O.OOW 0,00 0.00 275073.22 2361974.31 1000.00 0.00 310.00 1000.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 1500.00 0.00 310.00 1500.00 O.OON O.OOW 0,00 0.00 275073.22 2361974,31 2000,00 0.00 310.00 2000.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 2500.00 0.00 310.00 2500.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 3000.00 0.00 310.00 3000.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 3500.00 0.00 310.00 3500.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 4000.00 0.00 310.00 4000.00 O,OON O.OOW 0.00 0.00 275073.22 2361974.31 4500.00 0.00 310.00 4500.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 5000.00 0.00 310,00 5000.00 O.OON O,OOW 0.00 0.00 275073.22 2361974.31 5500.00 0.00 310.00 5500.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 6000.00 0.00 310.00 6000.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 6500.00 0.00 310.00 6500.00 O.OON O,OOW 0.00 0.00 275073.22 2361974,31 7000.00 0.00 310.00 7000.00 O,OON O.OOW 0.00 0.00 275073.22 2361974.31 7500.00 0.00 310.00 7500.00 O.OON O.OOW 0.00 0.00 275073,22 2361974.31 7927.00 0.00 310.00 7927.00 O.OON O.OOW 0.00 0.00 275073.22 2361974.31 8027.00 3.00 310.00 8026.95 1.68N 2.01W 3.00 2.62 275071.25 2361976.03 8127.00 6.00 310.00 8126.63 6,73N 8.01W 3.00 10.46 275065.34 2361981.19 8227.00 9.00 310.00 8225.77 15.11N 18.01W 3.00 23.51 275055.50 2361989.77 8260.33 10.00 310.00 8258.64 18.65N 22.23W 3.00 29.02 275051.36 2361993.38 8360.33 20.00 310.00 8355.11 35.27N 42.03W 10,00 54.86 275031.88 2362010.38 8460.33 30.00 310.00 8445.63 62.40N 74.36W 10.00 97.07 275000.08 2362038.13 8560.33 40.00 310.00 8527.44 99.22N 118.24W 10.00 154.36 274956,91 2362075.78 8660,33 50.00 310.00 8598.06 144.61N 172.34W 10.00 224,98 274903.70 2362122.21 8760.33 60.00 310.00 8655.35 197.20N 235.01W 10.00 306.79 274842.06 2362175.99 8860.33 70.00 310.00 8697.55 255.38N 304.35W 10.00 397.31 274773.86 2362235.50 8960.33 80.00 310.00 8723.40 317,39N 378.25W 10.00 493.78 274701.17 2362298.92 9054.63 89.43 310.00 8732.08 377.68N 450.10W 10.00 587.57 274630.50 2362360.58 9068.39 89.43 310,00 8732.22 386.52N 460.64W 0.00 601.32 274620.13 2362369.62 9168.39 89.43 310.00 8733.21 450.80N 537.24W 0.00 701.32 274544.79 2362435.36 9268,39 89.44 310,00 8734.19 515.07N 613.84W 0.00 801.31 274469,44 2362501.09 9368.39 89.44 310.00 8735.17 579,35N 690.44W 0.00 901.31 274394.10 2362566.83 9468.39 89.45 310,00 8736,14 643.62N 767.04W 0.00 1001.30 274318.76 2362632.57 9568.39 89.45 310.00 8737,10 707.90N 843.64W 0.00 1101.30 274243.41 2362698.31 9668.39 89.45 310.00 8738.06 772.18N 920.24W 0.00 1201.29 274168.07 2362764.04 9768.39 89.46 310.00 8739.01 836.45N 996.84W 0,00 1301.29 274092.72 2362829.78 9868.39 89.46 310.00 8739.95 900.73N 1073.45W 0.00 1401.28 274017.38 2362895.52 9968.39 89.47 310.00 8740.89 965.00N 1150.05W 0.00 1501.28 273942.03 2362961.26 10068.39 89.47 310.00 8741.82 1029.28N 1226,65W 0.00 1601.27 273866.68 2363026.99 10168.39 89.47 310.00 8742.74 1093.56N 1303.25W 0.00 1701.27 273791.34 2363092.73 10268.39 89.48 310.00 8743.66 1157.83N 1379.85W 0.00 1801,27 273715.99 2363158.47 10368.39 89.48 310.00 8744.57 1222.11N 1456.45W 0.00 1901.26 273640.65 2363224.21 10468.39 89.48 310.00 8745.47 1286.38N 1533.05W 0.00 2001.26 273565.30 2363289.94 10568.39 89.49 310.00 8746.36 1350.66N 1609.65W 0.00 2101.25 273489.96 2363355.68 10668.39 89.49 310.00 8747.25 1414.94N 1686.26W 0.00 2201.25 273414.61 2363421.42 10768.39 89.50 310.00 8748.14 1479.21N 1762.86W 0.00 2301.25 273339.27 2363487.16 10861,40 89.50 310.00 8748,95 1539.00N 1834.11W 0.00 2394.26 273269.19 2363548.30 10861.41 89.50 310.00 8748.95 1539.00N 1834.11W 0.01 2394.27 273269.18 2363548.31 All data in feet unless otherwise stated, Calculation uses minimum curvature method. Coordinates from slot 24-6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2394.27 on azimuth 310.00 degrees from wellhead. Total Dogleg for wellpath is 89.50 degrees. Vertical section is from wellhead on azimuth 310.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KTU24-6H Kenai Gas Field. Kenai Peninsula. Alaska PROPOSAL LISTING Page 2 Your ref : KTU 24-6H Ver. #4 Last revised : 15-Ju1-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 7927.00 7927.00 O.OON O.OOW KOP 10861.40 8748.95 1539.00N 1834.11W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOW 1750.00 1750.00 O.OON O.OOW 13 3/8" Casing 0.00 0.00 O.OON O.OOW 5287.00 5287.00 O.OON O.OOW 9 5/8" Casing 0.00 0.00 O.OON O,OOW 9049.19 8732.00 374.18N 445.94W 7" Casing Targets associated with this wellpath ,, Target name Geographic Location T.V.D. Rectangular Coordinates Revised KTU24-6H Target i 20 8732.00 150.00N 390.00W 20-Apr-1999 KTU24-6H Target PD 2 8749.00 1150.00N 2100,00W 20-Apr-1999 KTU 24-6H ESTIMATED TOPS AND PRESSURES* 7115/99 LOWEST PRESSURE LOWEST TOP SSTVD TVD GRAD, PRESSURE STERLING A8 3490 3577 0.08 286 A9 3520 3607 0.08 289 Al0 3560 3647 0.08 292 A11 3633 3720 0.08 298 Bt 3690 3777 0,08 302 B2 3750 3837 0,08 307 B3 3812 3899 0 08 312 B4 3892 3979 O. 08 318 B5 4080 4167 0.31 1292 Cl 4350 4437 0.08 355 C2 4533 4620 0.08 370 HIGHEST PRESSURE HIGHEST GRAD, PRESSURE 0.25 995 BELUGA U1 4577 4684 0.08 373 0.11 513 U2 4625 4712 0.08 377 0.11 518 U3 4673 4760 008 381 0.11 524 U4 4690 4777 0.08 382 0.11 525 U5 4738 4825 0.08 386 0,11 531 U6 4776 4863 0.44 2140 U7 4824 4911 0.08 393 0.11 540 U8 4883 4970 0.08 398 0.11 547 U9 4913 5000 0.08 400 0.11 550 UI0 4990 5077 0.08 406 0.11 558 Ull 5114 5201 0.08 416 0,11 572 U12 5184 5271 0.08 422 0.11 580 U13 5211 5298 0,44 2331 MI 5232 5319 0.2 1064 0.44 2340 M2 5269 5356 0,44 2357 M3 5301 5388 02 1078 0.44 2371 M4 5370 5457 0.44 2401 M5 5503 5590 0,2 1118 0,44 2460 M6 5597 5684 0.2 1137 0.44 2501 M7 5626 5713 0.44 2514 M8 5657 5744 0,2 1149 0.44 2527 M9 5680 5767 0.44 2537 M10 5730 5817 0.44 2559 M11 5747 5834 0.44 2567 M12 5761 5848 0,44 2573 Mt3 5776 5863 0.2 1173 0.44 2580 M14 5852 5939 0,2 1188 0.44 2613 M15 5962 6049 0.44 2662 L1 5977 6064 0.46 2789 L2 5985 6072 0.46 2793 L3 6025 6112 0.18 1100 0.46 2812 L4 6107 6194 0.18 1115 0.46 2849 L516 8217 6304 0.46 2900 L7 6286 6373 0.46 2932 L8 6352 6439 0.46 2962 L9 6375 6462 0.18 1163 0.46 2973 LI0 6439 6526 0.18 1175 0.46 3002 Lll 6628 6715 0.18 1209 0.46 3089 L12 6673 6760 0.18 1217 0.46 3110 L13 6749 6836 0.18 1230 0.46 3145 L14 6809 6896 0.18 1241 0.46 3172 L15 6826 6913 0.46 3180 L16 6882 6969 0.18 1254 0.46 3206 L17 6931 7018 0.18 1263 0,46 3228 L18 7007 7094 0.18 1277 0,46 3263 TYONEK 7078 7165 0,46 3296 72-8 7113 7200 0.37 2664 0.46 3312 73-1 7203 7290 0.37 2697 0,46 3353 75-8 7415 7502 0.37 2776 0,46 3451 76-7 7488 7575 0.37 2803 0,46 3485 NEARBY BELUGA COMPLETIONS KBU41-7KBU 13-8KBU 31-TRD KBU 31-7 x x x x x x x x x CASING POINT x x x x x x x X x x x x x X x x 78-2 7634 7721 0.37 2857 0.46 3552 84-6 8220 8307 0.55 4569 84-6coal 8373 8460 86-2 8475 8562 0.37 3168 0.46 3939 Base D-1 Coal 8590 8677 D-1 Sandstone 8645 8732 0.43 3755 Total Depth 8662 8749 *Middle and Lower Beluga depletions possible in zones identified by 'X" in the nearby wells. Sterling and Upper Beluga depletions expected across the field. KDU4RD KBU3~7 CONTROL Used b~is hmtzo~s structu~ .. u~a U. Bek~a strlJ~tffe arm KBU 41-7 Used M. Betuga~ructure and KBU 41-7 wel Used L. Beluga Stuctum and KBU 41-7 wel Used Top Tyonek Stucture and KBU 41-7 well Used Tyonek 75-8 Stucture and KDU 1 well Used Tyonek D1 Int. Stuc~ure and KDU 1 well Used Tyonek D1 SS. Stucture and KDU 1 wen o:~KG FU-Iorizont al~24-6ht opst ops.xls DLB 7114199 SURFACE USE PLAN FOR KENAI UNIT KTU 24-6H Surface Location: NE 1/4 of NE 1/4, Sec. 7, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KTU 24-6H are shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access KTU 24-6H. 3. Location of Existing Wells Well K'I'U 24-6H will be drilled on pad 41-7. A pad drawing is attached that shows existing wells and the proposed location for KTU 24-6H. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. These facilities will be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 11-17, N:~DRLG~KGF\WELLS~ktu24-6h~SUR FUSE.doc Surface Use Plan Kenai Unit KTU 24-6H Page 2, t am 9, 10. a Class II disposal well (AOGCC Disposal Injection Order No. 9, Permit ~1-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. Plans for Reclamation of the Surface Kenai Unit KTU 24-6H will be drilled from an existing pad. Reclamation of the pad will occur after abandonment of KTU 24-6H and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CIRI Native Corporation prior to any reclamation work beginning. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. Surface Use Plan Kenai Unit KTU 24-6H Page 3 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: Name & Title: "Marathon"Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 T 5 N T 4 N I 31~ 33 : { ""--'"' T. 6N. ":"??-'l i "'-L--'~+'~'~-?- '~ _-L' " ~' .:~; -'--,,,. ........... :... i .. ~.J-' :: ~'-: ~' "'- ? I * 4. '" .: *t ~ ~; . CJ--~ ":-- ~' "" ' -"~ - -- '~' *"- I T. 5N. · ., _ · . 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' %---.4 ....... ?-% .... :-ic .~-I - '~ 2 ~ ;~ ~ '-, · . i ~" I , ~ -~-' ~'"-'~'~_j/ ~ -- ~ .---- \ - , '-",' ." .' .., // : · - -- .... -~ .-- 2'.~ --~. --- ~ /. .: ." .....' 'i./ '. -""- .: :."' > .;:-~-' ? .... .'"' · ' i'---' ........ · , .... f ~ .............. .~ ~ -;~ -. , .- - · : .,, !, ~; - ., ~, i .... "---i" ' ¢ ~ 25 30 29' '-' ~ '; ' - · , '..: ....~26 '/' , * ; .... - ....... i ........ , · . . i -. . -, ..-? %': .~ ' . _: - -x. ~. _~' ,.? .. / , ~ "' . . ~..~ ..~ .' . ~% . ; --.~-., -~. :. , ._. ,. .....~ . ;~, ~ ,. . ; , -. -~. . . .?::_~, ........ · : ........ ,L ..... - ,',,,, · ' ' ' - ' :'?'t ~ :' ' :7-:--'7-'~, .'~.~ ~ .. t. ~ -0~: ~ ; I KENAI GAS FIELD .- ,~ '~'~'"' : " ~-',:-:- a;n~a~::' :."-~q FIGURE 1 ' '-- - .~r~ r u.. , /~ .? t~, , % - ii DETAIL Iirithon 011 OOlIpmfly I I PAD AS'"~-m--T SURVEY .... GAI ff~LD PAD 41-7 Alaska ¢,' .,,on Domestic Production Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 15, 1999 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Kenai Unit KTU 24-6H Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, P. K. Berga Drilling Superintendent PKB:nrs N:\DRLG\KGF~WELLS~ktu24-6h~aogccclt.doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. .~Ru~..~v.?~ --.. .i' . Marathon Oil Company ~ -::.'. 57 ..-~.,,~, ~,..~,~,.or~.,,~.~o,~:.......~:/: .... ~.- ....... ~..-~........~. ~.... ~ ~,c.'~.~.~ ...~ 01 3 9 6 .:....-'.. Ai'~' ~i ~ ~jS CO~'j~Vati°, C0~-~:~6~-'--<._--.: · - .,.~ · .........::: ~:.-....:.:.:; ~:..:... ....:.... ~... /15/99 .. :?:: --.:.:-:.;::An~h~]Be:~.-Al~.~ka ' 9.9501-3192 " MATCH AMOUNTIN. - . - . Pay;: '. ':-. '"'~:' .'" -: ' VOID A~E~ 180 DAYS NAtiONAL BANK' OF ":' A~SKA ...'.: . .. .: . · . .. ~ ANCHORAGE, A~S~ By_/~/~(~./_(__~ ........ -. ;; ........ .'. :': .... ; ..:'.: -:. ~: . - .. - / ~HORIZED SIGNA~RE ' OPERATOR CITY STATE '-' ~ 25 2000 S ?~-'0 ~,'0 Marathon Oil Company P.O. Box 196168 , ALASKA 99519-6168 OR NON-REPOR]~NG 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE l SERVICES TYPE OF NON-EMPLOYEE COMP. PAYMENT PRIZES, DAMAGES Filing Fee for Permit to Drill - KTU 24.6H WELL PERMIT CHECKLIST FIELD & POOL _~ ~ ~ ?"~ COMPANYJ~,~.~,- WELLNAME KTU PROGRAM:exp dev ~ redrll serv wellboreseg INIT CLASS ~) ~ L~ I" ~ 1~ _~ GEOL AREA ~ 2., ~ UNIT# ..5"/,/~ O ann. disposal para req ON/OFF SHORE ADMINISTRATION lA,PR DAT, E, 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................ .... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~'00 O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measum~ Y--N -- -- 31. Data presented on pote~'al ove~s~_~s ....... Y N 32. Seismic anal~one, s ............. Y N /~P, PR DATE 33~~.~rvey (if off-shore) ............. Y N ~ ~ ~/) 34 ct name/phone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL 35. With proper cementin,~krecords, ~s plan (A) will contain wasl~n a suita/l~e'rec~ne; . . . :.... Y N APPR DATE (B) will not contaminate fresh~at~o~ cau,,ef~ drilling w~e... Y N to surface; ~ /..// (C) will not imp~r mechani~al~iritegrity,~'f the~ll u,~d for disposal; Y N (P) will not damage produ~l~g format~n~or]mpair ~'ecovery from a Y N pool; an~. _ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEEIRU~G: _ UIC/Ann/ular BEW/I/~O~m,,~ O~~1~ WM JDH ~ COMMISSION: DWJ ~ RNC CO co ~/:~:/,,. ,~ Comments/Instructions: O Z O cSmsofflce\wordian\diana\checklist