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201-144
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 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 4,816 feet 4,370 feet true vertical 4,251 feet N/A feet Effective Depth measured 4,307 feet 3,135 feet true vertical 3,763 feet 2,766 feet Perforation depth Measured depth 4,191 - 4,430 feet True Vertical depth 3,651 - 3,880 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 3,903 MD 3,384 TVD 3,135 MD Packers and SSSV (type, measured and true vertical depth)DLH Hyd. Pkr 2,766 TVD SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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:Contact Phone: 321-465 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 250 7,240psi Chad Helgeson chelgeson@hilcorp.com (907) 777-8405Dan Marlowe - Operations Manager measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 000 0 30 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 136' 2,012' N/A 0 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-144 50-133-20358-01-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028142 Kenai Gas Field / Sterling 3 Gas Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Kenai Unit (KU) 24-05RD Hilcorp Alaska, LLC Other: ______________________ measuredPlugs Junk measured N/A Length 136' 2,012' Size Conductor Surface Intermediate 20" 13-3/8" Production Liner 3,500' 4,608' Casing 136' 1,864' 3,053' 7" 3,500' 4,608' 4,051' 9-5/8"4,750psi 1,530psi 3,090psi 6,870psi Burst Collapse 520psi 1,540psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 8:03 am, Nov 12, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.11 16:46:19 -09'00' Dan Marlowe (1267) RBDMS HEW 11/12/2021 SFD 11/15/2021BJM 11/15/21 DSR-11/12/21 _____________________________________________________________________________________ Updated by: JLL 11/09/21 SCHEMATIC Kenai Gas Field Well: KU 24-05RD PTD: 201-144 API: 50-133-20358-01-00 Last Completed: 12/22/2001 PBTD = 4,307’ MD / 3,763’ TVD RKB: MSL = 94’ / 21 AGL 3 4 5 TOC @ 4,307’ 07/24/13 20” 13-3/8” 9-5/8” 1 7” Sterling Pool 4 TD = 4,816’MD / 4,251’ TVD 2X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20” Conductor 94 / H-40 19.124 Surf 136’ 13-3/8' Surface 61 / K-55 12.515 Surf 2,012’ 9-5/8" Production 47 / N-80 / BTC 8.681 Surf 3,500’ 7" Liner 26 / L-80 6.276 3,195’ 4,608’ TUBING DETAIL 2-7/8” Tubing 6.5# / L-80 2.441 Surf 3,903’ PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Status Date Guns P3_A8 4,191' 4,214' 3,651' 3,674' 23' Open 09/25/21 2-1/8” Strip Gun 6 SPF P3_A9 4,225' 4,235' 3,685' 3,695' 10' Open 09/25/21 2-1/8” Strip Gun 6 SPF A11 4,380’ 4,430’ 3,833’ 3,880’ 50’ Isolated 07/23/13 4-5/8” Millenium Stimgun OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2" hole Cmt w/ 1,500 sks of Class G 9-5/8" 12-1/4" hole Cmt w/ 1,800 sks of Class G 7” 8-1/2" hole Cmt w/ 152 sks of Class G JEWELRY DETAIL No Depth Item 1 3,135’ DHL Hydraulic Packer 2 3,185’ X Profile Nipple (2.313” I.D.) 3 3,195’ Baker Flexlock Line Hanger w/ ZXP liner top packer 43,903’WLEG 5 4,370’ Umbrella Plug 9-5/8” Window (Cut 11/27/2001) 3,471’ to 3,488’ P3_A8 4,191' 4,214' 3,651' 3,674' 23' Open 09/25/21 2-1/8” Strip Gun 6 SPF P3_A9 4,225' 4,235' 3,685' 3,695' 10' Open 09/25/21 2-1/8” Strip Gun 6 SPF ()()()() Rig Start Date End Date E-Line 9/25/21 9/25/21 09/25/2021 - Saturday PTW and JSA. Spot equipment and rig up lubricator. Had trouble PT with bottom of lubricator blowing O-ring fixed and achieved low test of 250 and 2,000 psi High. TP - 303 psi. RIH w/2-1/8"x10' Strip gun, 6 spf, 45 deg, tie into CCL/GR and tag at 4259'. Ran correlation log and send to town. Get ok to perf from 4225'to 4235' w/303 psi. Spotted and fired gun. After 5 min - 304 psi, 10 min -304 psi and 15 min - 305 psi. Pull heavy until we got past nipple at 3185'. OOH. All shots fired. RIH w/2-1/8"x13' Strip gun, 6 spf, 45 deg, tie into perf log. Correlated with last log. Spot and fire gun from 4201' to 4214' w/304 psi. After 5 min - 304 psi, 10 min - 304 psi and 15 min 304 psi. got down to 302 psi. RIH w/2-1/8"x10' Strip gun, 6 spf, 45 deg, tie into perf log. Correlated with last log. Spot and fire gun from 4191' to 4201' w/303. After 5, 10, and 15 min pressure was 304 psi. POOH. All shots fired. Rig off well and turn over to field and then break down equipment. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 24-05RD 50-133-20358-01-00 201-144 Spot and fire gun from 4201' to 4214' w Spot and fire gun from 4191' to 4201' w o perf from 4225'to 4235' w/303 psi. Spotted and fired gun. 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: 11/08/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 24-05RD (PTD 201-144) Completion Record Perf 09/25/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 8:43 am, Nov 09, 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: ___________________ 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): 4,816'N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate Production 4,750psi Liner 5,410psi 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: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 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 todd.sidoti@hilcorp.com 4,251'4,307'3,763'1,241 4,370' DLH Hydraulic Packer ; N/A 3135' MD / 2766' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 7,240psi Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 201-144 50-133-20358-01-00 Kenai Unit (KU) 24-05RD Kenai Gas field / Sterling 3 Gas Pool Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 6.5# / L-80 TVD Burst 3,903' 6,870psi MD 1,530psi 3,090psi 136' 1,864' 136' 2,012' 3,053'9-5/8" 20" 13-3/8" 136' 2,012' 3,500' Perforation Depth MD (ft): See Attached Schematic 3,500' 7" 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: September 24, 2021 4,608'4,608' 2-7/8" 4,051' wwn amamm ee d ed ss No ss No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:11 pm, Sep 10, 2021 321-465 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.10 15:02:21 -08'00' Taylor Wellman (2143) SFD 9/10/2021 CO 510B DSR-9/13/21SFD 9/10/2021BJM 9/17/21 10-404 dts 9/17/2021 JLC 9/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.17 14:39:34 -08'00' RBDMS HEW 9/17/2021 Well Prognosis Well: KU 24-05RD Date: 09/10/2021 Well Name: KU 24-05RD API Number: 50-133-20358-01-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 09/24/2021 Rig: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 201-144 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Maximum Expected BHP: ~1606 psi @ 3651’ TVD (Based on normal gradient) Max. Allowable Surface Pressure: ~1241 psi (Based on 0.1 psi/ft gas gradient) Brief Well Summary: KU 24-05RD was originally drilled in 1982 as a dual Sterling Pool 4/5.1 producer. The dual completion loaded up and died in 2001 so it was sidetracked in 4/2002 the to become the single completion KU 24-05RD targeting Pool 4 only and producing up the 7’’ liner until this completion. In 2008 a 2-3/8’’ concentric gas lift was installed which did little to alleviate the loading problems in the 7’’ production casing. A rig workover was performed in early 2013 to isolate the Sterling A11, run new 2-7/8” tbg string with packer up in 9-5/8” enable to access the upper Sterling section. The water was swabbed down to 2,000’ MD post workover, but the zones were never shot. The well has cum’d 5.3 BCF to date from the Sterling B1 sand from 2002-2008. Objective: The purpose of this project is to perf the Sterling A8 and A9 formation. Will need to swab down to the tbg tail at 3,903’ MD. Wellbore Notes: x 4,307’ PBTD on 7/24/2013 w/ a 3-1/8” Gamma Ray/CCL tool x 4,250’ RKB on 8/26/2013 w/ 2.125” x 15.5’ dummy gun Fluid level @ 2,000’ RKB Slickline: 1. MIRU slickline and pressure test lubricator to 250 psi low / 2000 psi high. 2. Swab well down to tubing tail. 3. RDMO E-line: 1. MIRU E-line, PT lubricator to 250 psi low and 2000 psi high. 2. Perforate the below zones from the bottom up with 2-1/8” Spiral Strip Guns: Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt P3_A8 ±4,191' ±4,214' ±3,651' ±3,674' 23' P3_A9 ±4,225' ±4,235' ±3,685' ±3,695' 10' a. Discuss wellhead pressure with OE, anticipate wanting to hold 900 psi for initial shot. If necessary, RU sales gas or Nitrogen to pressure up well prior to perforating. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. Sterling A8 to A11 sands all lie within the Sterling 3 Gas Pool. SFD 9/10/2021 Well Prognosis Well: KU 24-05RD Date: 09/10/2021 c. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. 3. RD E-Line. 4. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Nitrogen (Contingency) If Nitrogen is required to pressure up well prior to perforating or push fluid away: 1. MIRU Nitrogen Unit, review Nitrogen SOP, pressure well to desired perforating pressure. E-line Procedure (Contingency) If any zone produces sand and/or water or needs isolated: 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH and set 2-7/8” x 7” TTBP above the zone and dump 25’ of cement on top of the plug. Attachments: Current Well Schematic Proposed Well Schematic Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 02/18/16 SCHEMATIC Kenai Gas Field Well: KU 24-05RD PTD: 201-144 API: 50-133-20358-01-00 Last Completed: 12/22/2001 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20” Conductor 94 / H-40 19.124 Surf 136’ 13-3/8' Surface 61 / K-55 12.515 Surf 2,012’ 9-5/8" Production 47 / N-80 / BTC 8.681 Surf 3,500’ 7" Liner 26 / L-80 6.276 3,195’ 4,608’ TUBING DETAIL 2-7/8” Tubing 6.5# / L-80 2.441 Surf 3,903’ PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status Date Guns A11 4,380’ 4,430’ 3,833’ 3,880’ 50’ Isolated 4-5/8” Millenium Stimgun OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2" hole Cmt w/ 1,500 sks of Class G 9-5/8" 12-1/4" hole Cmt w/ 1,800 sks of Class G 7” 8-1/2" hole Cmt w/ 152 sks of Class G JEWELRY DETAIL No Depth Item 1 3,135’ DHL Hydraulic Packer 2 3,185’ X Profile Nipple (2.313” I.D.) 3 3,195’ Baker Flexlock Line Hanger w/ ZXP liner top packer 4 3,903’ WLEG 5 4,370’ Umbrella Plug 9-5/8” Window (Cut 11/27/2001) 3,471’ to 3,488’ _____________________________________________________________________________________ Updated by TWN 02/18/16 PROPOSED SCHEMATIC Kenai Gas Field Well: KU 24-05RD PTD: 201-144 API: 50-133-20358-01-00 Last Completed: 12/22/2001 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20” Conductor 94 / H-40 19.124 Surf 136’ 13-3/8' Surface 61 / K-55 12.515 Surf 2,012’ 9-5/8" Production 47 / N-80 / BTC 8.681 Surf 3,500’ 7" Liner 26 / L-80 6.276 3,195’ 4,608’ TUBING DETAIL 2-7/8” Tubing 6.5# / L-80 2.441 Surf 3,903’ PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status Date Guns P3_A8 ±4,191' ±4,214' ±3,651' ±3,674' 23' Proposed TBD P3_A9 ±4,225' ±4,235' ±3,685' ±3,695' 10' Proposed TBD A11 4,380’ 4,430’ 3,833’ 3,880’ 50’ Isolated 07/23/13 4-5/8” Millenium Stimgun OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2" hole Cmt w/ 1,500 sks of Class G 9-5/8" 12-1/4" hole Cmt w/ 1,800 sks of Class G 7” 8-1/2" hole Cmt w/ 152 sks of Class G JEWELRY DETAIL No Depth Item 1 3,135’ DHL Hydraulic Packer 2 3,185’ X Profile Nipple (2.313” I.D.) 3 3,195’ Baker Flexlock Line Hanger w/ ZXP liner top packer 4 3,903’ WLEG 5 4,370’ Umbrella Plug 9-5/8” Window (Cut 11/27/2001) 3,471’ to 3,488’ Sterling A8 to A11 sands all lie within the Sterling 3 Gas Pool. SFD 9/10/2021 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. • • Seth Nolan Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 wa Alaska,1,1.,C RECEIVED Fax 907 777-8510 E-mail: snolan@hilcorp.com AUG 2 9 2017 AOGCCDATA I 011 DATE 08/28/2017 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant II 333 W 7th Ave Ste 100 Anchorage, AK 195-055 28556( 01-144 28558 99501 205-117 28557 201-231 28559 DATA TRANSMITTAL PEARL STRATIGRAPHIC TESTS Log digital raster data CD: 1 Electric logs KBU 31-07RD_induction.pdf 9/19/2013 4:27 PM PDF Document 15,577 KB KBU 31-07RD_induction,of 9/18/2013 9:34 AM TIF File 797 KB Lift KBU_31-07RD_mudlog.pdf 8/14/2017 8:54 AM PDF Document 1,129 KB KBU_31-07RD_mudlog.of 8/14/2017 8:47 AM TIF File 3,362 KB ti KT1J43-6XRD2_ML_MD.pdf 9/1/2005 10:31 AM PDF Document 2,026 KB KTU43-6XRD2 ML MD.tif 8/14/2017 8:53 AM TIF File 3,701 KB i KU_24-05RD_mudlog.pdf 8/14/2017 8:54 AM PDF Document 561 KB KU 24-05RD mudlog.tif 8/14/2017 8:45 AM TIF File 2,677 KB KU 43-06RD_mudlog.pdf 8/14/2017 8:54 AM PDF Document 1,022 KB KU 43-O6RD_mudlog.of 8/14/2017 8:46 AM TIF File 3,362 KB Please include current contact information if different from above. SCANNED SEP 1 22017, Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Date: o_eite • a NI/ Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday,August 22, 2017 10:58 AM To: Donna Ambruz Cc: samantha.carlisle@alaska.gov Subject: RE:Sundry Cancellation - Sundry#316-138 KU 24-05RD (PTD 201-144) Donna, Missed this one...my apologies. AOGCC will withdraw sundry 316-138 as requested below. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell SCANNEDAUG 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Donna Ambruz (mailto:dambruz@hilcorp.com] Sent:Tuesday,August 22,2017 10:03 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: FW:Sundry Cancellation-Sundry#316-138 KU 24-05RD (PTD 201-144) Hi Guy—Status please. Thank you. Donna From: Donna Ambruz Sent:Tuesday, March 14,2017 1:27 PM To:Guy Schwartz(guy.schwartz@alaska.gov)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>;Taylor Nasse<tnasse@hilcorp.com> Subject:Sundry Cancellation-Sundry#316-138 KU 24-05RD(PTD 201-144) Guy, Please withdraw the above mentioned sundry. Thank you. `.Donna Qmljauvz Operations/Regulatory Tech Kenai Asset Team 1 RBDMS LU17 OF Tg� • • roi Iy :4. THE STATE Alaska Oil and Gas of Conservation Commission _: *Pi ALASI�:A 333 West Seventh Avenue , �� ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SEED MAR 0 4 nib' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Sterling Gas Pool 3, KU 24-05RD Permit to Drill Number: 201-144 Sundry Number: 316-138 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°qCt47k Cathy P. oerster Chair DATED this day of February, 2016. RBDMS V✓ FEB 2 6 2016 • • RECEIVED STATE OF ALASKA FEB 1 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS STs 2/i 41/6 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑Q - Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 - 201-144 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20358-01-00 . 7.If perforating: s lO74 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20_,SA625$55 / Kenai Unit(KU) 24-05RD - Will planned perforations require a spacing exception? Yes ❑ No 11 'A-Z-3-14' 9.Property Designation(Lease Number): 10.Field/Pool(s): _....-(e.-1 //`t s - -( 3 �t FEDA028142 Kenai Gas Field/Stee-- erfitned-4oas Pool • _ 1. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,816' 4,251' - 4,307' 3,763' 1,242psi 4,307' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 136' 136' 1,530psi 520psi Surface 1,991' 13-3/8" 2,012' 1,864' 3,090psi 1,540psi Intermediate Production 3,479' 9-5/8" 3,500' 3,053' 6,870psi 4,750psi Liner 1,413' 7" 4,608' 4,051' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 3,903 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraulic Packer; N/A 3,135'MD/2,766'TVD; N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development El Service E] 14.Estimated Date for 15.Well Status after proposed work: March 4,2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasse .hilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature /•'71(All- Phone 907-777-8405 Date Z/f el/f(p COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness 'Sundry Number. 61 (1)- 13?" Plug Integrity [] BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No CI , �/ FEB 2 6 2016 Spacing Exception Required? Yes El No RI/ Subsequent Form Required: / _ `'( RBDMS APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: Z-21----40 72-Z'(-/ 46, �y _1 � Submit Form and Form 10-403 Revised 11/21 Approved application is v id 1 R inOilif t/fetlLof approval. Attachments in Duplicate YYff d'''-----7/Z746 .h' -: • • Well Prognosis Well: KU 24-05RD Date: 2/18/16 I-lilcoru Alaska.LL Well Name: KU 24-05RD API Number: 50-133-20358-01-00 Current Status: Shut-In Leg: N/A Estimated Start Date: 3/4/16 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 201-144 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) AFE Number Estimated Bottom Hole Pressure: —1,618 psi at 3,763 TVD (Assumed 0.43 psi/ft) Max. Potential Surface Pressure: 1,242 psi (Based on 0.10 psi/ft gas gradient to surface) Brief Well Summary: KU 24-05RD was drilled as a sidetrack in December 2001 with a 7" liner targeting the Sterling Pool 4. It produced from the Sterling B1 sand until eventually going down due to loading. In 2013 the B1 interval was plugged back and a 2-7/8" completion was run, however no perforations were added. The objective of this sundry is to add perforations in the Sterling A9, A10, and All sands. Notes Regarding Wellbore Condition • MIRU slickline and make GR run and tag bottom prior to performing work. • Run PT survey to verify fluid level in well. If well is full of fluid, swab well prior to performing work. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/1,500 psi high. 2. Perforate the Sterling sands with 2" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each zone may be shot twice. Depths are from the Schlumberger RST log dated December 4th, 2001. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Sterling A9 ±4,228' ±4,235' ±7 Sterling A10 ±4,253' ±4,258' ±5 Sterling A10 ±4,273' ±4,278' ±5 Sterling All ±4,302' ±4,307' ±5 3. POOH. 4. Flow through test separator and record water and gas rates. 5. If any of the sands are not commercial or wet, the zone will be permanently plugged back. 6. RD e-line. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Kenai Gas Field .111 H . • Well: KU 24-05RD PTD: 201-144 SCHEMATIC API:50-133-20358-01-00 Hilcorp Alaska,LLC Last Completed: 12/22/2001 RKB:MSL=94'/21 AGL CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/H-40 19.124 Surf 136' • 13-3/8' Surface 61/K-55 12.515 Surf 2,012' 9-5/8" Production 47/N-80/BTC 8.681 Surf 3,500' 7" Liner 26/L-80 6.276 3,195' 4,608' TUBING DETAIL 2-7/8" Tubing 6.5#/L-80 2.441 Surf 3,903' JEWELRY DETAIL No Depth Item 1 3,135' DHL Hydraulic Packer 2 3,185' X Profile Nipple(2.313"I.D.) 3 3,195' Baker Flexlock Line Hanger w/ZXP liner top packer 4 3,903' WLEG 5 4,370' Umbrella Plug 9-5/8"Window(Cut 11/27/2001) 1 3,471'to 3,488' 13-3/8" PERFORATION DETAIL Sand Top Btm Top Btm Amt Status Date Guns (MD) (MD) (TVD) (TVD) All 4,380' 4,430' 3,833' 3,880' 50' Isolated 4-5/8"Millenium Stimgun 1 3E .. 1 x 2 9-5/8" ' 3 • wj tw",S P" - ' 4 TOC @ 4,307 01/24/13 �"�►. ` — OPEN HOLE/CEMENT DETAIL 5 Sterling Pool 13-3/8" 17-1/2"hole Cmt w/1,500 sks of Class G 9-5/8" 12-1/4"hole Cmt w/1,800 sks of Class G 7" 8-1/2"hole Cmt w/152 sks of Class G 7" Z PBTD=4,307 MD/3,763'11/D TD=4,816'MD/4,251'IVD Updated by DMA 02/18/16 Kenai Gas Field • PROPOSED • WeII: KU2405RD PTD:201-144 API:50-133-20358-01-00 SCHEMATIC Last Completed: 12/22/2001 Hilcorp Alaska,LLC RB:MSL=94'121AGL CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/H-40 19.124 Surf 136' 13-3/8' Surface 61/K-55 12.515 Surf 2,012' 9-5/8" Production 47/N-80/BTC 8.681 Surf 3,500' xy 7" Liner 26/L-80 6.276 3,195' 4,608' TUBING DETAIL 2-7/8" Tubing 6.5#/L-80 2.441 Surf 3,903' JEWELRY DETAIL • No Depth Item 1 3,135' DHL Hydraulic Packer 2 3,185' X Profile Nipple(2.313"I.D.) 3 3,195' Baker Flexlock Line Hanger w/ZXP liner top packer 4 3,903' WLEG 5 4,370' Umbrella Plug 9-5/8"Window(Cut 11/27/2001) 3,471'to 3,488' 13-3/8" PERFORATION DETAIL •• Sand Top Btm Top Btm Amt Status Date Guns (MD) (MD) (TVD) (TVD) A9 ±4,228' ±4,235' ±3,687' ±3,694' 7' Proposed TBD A10 ±4,253' ±4,258' ±3,711 ±3,716' 5' Proposed TBD • 1 A10 ±4,273' ±4,278' ±3,730 ±3,735' 5' Proposed TBD _ J All ±4,302' ±4,307' ±3,758 ±3,763' 5' Proposed TBD All 4,380' 4,430' 3,833' 3,880' 50' Isolated 07/23/13 4-5/8"Millenium Stimgun X 2 9-5/8" . 3 : A9 / A10 TOC @ 4,307 All 07/24/13 ►. y OPEN HOLE/CEMENT DETAIL 5 Sterling Pool 4 13-3/8" 17-1/2"hole Cmt w/1,500 sks of Class G 9-5/8" 12-1/4"hole Cmt w/1,800 sks of Class G 7" 8-1/2"hole Cmt w/152 sks of Class G PBTD=4,307'MD/3,763'1VD TD=4,816'MD/4,251'1VD Updated by TWN 02/18/16 • • Schwartz, Guy L (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, February 23, 2016 9:18 AM To: Schwartz, Guy L (DOA) Cc: Taylor Nasse Subject: RE: KU 24-05RD (201-144) Guy, At the time of the project we had some failures in some other sterling wells and by the time we were ready to perforate the well,we were focusing on the Tyonek within the gas field and the ATL didn't want to spend the money at the time chasing this Sterling. The log wasn't straight forward, but we have been doing some different log interpretations after all the drilling and well work we have conducted in the last 2.5 years and think this well offers some hope for some gas left behind. Our current reservoir engineer is conducting a field study of the Sterling sand in the Kenai Gas Field and this is a project (KU 24-05RD) and the KDU-2 workover are pieces of information that the engineer needs to conduct a thorough evaluation of these sands. If these 2 wells work and show there is still low pressure gas in this sand,we will start looking at more work to further develop some of these sterling sands. Hopefully that is not too much information, but if you need anything else let me know. Chad From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@aalaska.gov] Sent: Monday, February 22, 2016 3:54 PM To: Chad Helgeson Subject: KU 24-05RD (201-144 ) Chad, Saw this well was never perfed after running a new tubing string in 2013. Did the neutron log give poor results? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office SCANNED MAY 1 8 2016 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 1 • • Davies, Stephen F (DOA) From: Seth Nolan <snolan@hilcorp.com> Sent: Tuesday, February 23, 2016 10:51 AM To: Davies, Stephen F(DOA) Cc: Guhl, Meredith D (DOA) Subject: RE: Kenai Unit 24-05RD, PTD 201-144 Attachments: KU_24-05RD_ELECT-LOGS.LAS; KU_24-05RD_ELECT-LOGS_QUARTER.LAS Good Morning Steve, I have attached a couple files from Petra that we have for the GR-CCL log that was run. I hope this helps, if you need anything else just let me know. Thanks, Seth Nolan GeoTech iCANNECi Hilcorp Alaska LLC 3800 Centerpoint Dr. Anchorage,AK 99524 Office:907.777.8308 snolan0>hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies©©alaska.gov] Sent: Tuesday, February 23, 2016 10:40 AM To: Seth Nolan Cc: Guhl, Meredith D (DOA) Subject: FW: Kenai Unit 24-05RD, PTD 201-144 Seth, Does Hilcorp have a cased-hole gamma ray log recorded in Kenai Unit 24-05RD, PTD 201-144? If so, could Hilcorp please provide a copy of the digital data in LAS or ASCII text format? Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 • From: Seth Nolan [mailto:snolan@hilcorp.com] Sent: Tuesday, February 23, 2016 10:07 AM To: Guhl, Meredith D (DOA) Subject: RE: Kenai Unit 24-05RD, PTD 201-144 Good Morning Meredith, As far as open hole logs, Marathon did not run any for this particular well. 1 have just read through the well history and the drilling program.The only logs that were produced in the open hole were the directional survey and the mudlogs. If you have any questions regarding this discovery please let me know. Thanks, Seth Nolan GeoTech Hilcorp Alaska LLC 3800 Centerpoint Dr. Anchorage,AK 99524 Office:907.777.8308 snolan@hilcorp,com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, February 23, 2016 9:06 AM To: Seth Nolan Subject: Kenai Unit 24-05RD, PTD 201-144 Hello Seth, Steve Davies is reviewing proposed perforations and discovered that the AOGCC never received any digital data or logs from Kenai Unit 24-05RD, other than a mudlog and a mudlogging report. An open hole LAS file containing GR/Res+/-Neu/Den would be very useful to Steve. Does Hilcorp have one available that you could email me please? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100, Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMIVOION 1--EB 19 ?O16 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing❑ ❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Sus Well ✓ p ❑ Other: Plug Back&Complete ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 201-144 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20358-01-00 7. Property Designation(Lease Number): 8.Well Name and Number: FEDA028142 Kenai Unit(KU)24-05RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field/Sterling Upper Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured 4,816 feet Plugs measured 4,307 feet true vertical 4,251 feet Junk measured N/A feet Effective Depth measured 4,307 feet Packer measured 3,135 feet true vertical 3,763 feet true vertical 2,766 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 136' 136' 1,530psi 520psi Surface 1,991' 13-3/8" 2,012' 1,860' 3,909psi 1,540psi Intermediate Production 3,479' 9-5/8" 3,500' 3,053' 6,870psi 4,750psi Liner 1,413' 7" 4,608' 4,051' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic r p True Vertical depth See Attached Schematic 6 tI� ' fie r f f ,, t 4 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L- 3,903'MD 3,384'TVD DLH Hydraulic Pkr 3,135'MD 2,766'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ LI SUSP❑ SPLUG LI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-349 Contact Taylor Nasse-777-8354 Email tnasse@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature l J Phone 907-777-8405 Date47/17/1 6. Form 10-404 Revised 5/2015 c t)^��—� Submit Original Only %,4-..7-- .%-t5 RBDMS 1. - FGa 2 2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KU 24-05RD E-Line 50-133-20358-01 201-144 7/15/13 8/21/13 Daily Operations: 7/15/2013 - Monday MIRU 2-3/8" coil unit to pull V string. Notified AOGCC of BOP Test. 7/16/2013 -Tuesday Finish RU. Function test BOP's test BOP body, choke and 2" iron 250psi low/2,500psi high. Test upper blind rams 250psi low/2,500psi high. Test lower blind rams 250psi low/2,500psi high. Test pipe rams 250psi low/2,500psi high. Test slips with push pull test. PU BHA to retrieve V string. Carry injector to WH. Unable to NU lubricator to WH and get a good pressure test. 7/17/2013 -Wednesday Change out damaged Bowen pin on top of BOP's. PU BHA, dimple on, DFCV, Ball disconnect, 3" G sphere. RIH. Latch V string. Release Lock down screws. Pull V string into lubricator. Cut coil. Remove BHA. Install Dual Dimple on connection. Pull V string out of well. Close master valves on well. LD injector an lubricator. Secure well and location for the night. 7/18/2013 -Thursday RD coil equipmentLoad equipment on trailers. Prep location. 7/21/2013-Sunday RU Pollard Eline. RIH w/3-1/8" gamma ray/CCL to 4,381'. RIH w/7" umbrella plug and set at 4,370'. Bail in 2 gals of glass beads to hold basket open. Dump bail 10 gals latex cement. Secure well and location for the night. I 7/22/2013 - Monday RIH w/3-1/8"gamma/CCL, centralizer, 3-1/2" LIB. Close vent tube on umbrella plug. RIH w/40' bailer to dump 12 gals cement. Unable to pass thru linerhanger. Dump cement at lap, drop 60 bbls produced water to wash cement down hole. Have welder fabricate cone shaped nose for bailer. Make four 40' bailer runs and drop 48 gals of cement. Secure well and location. 7/24/2013 -Wednesday RU Pollard Eline. RIH w/3-1/8" gamma ray/CCLRun correlation pass.Tag TOC at 4,307'. POOH RD Eline unit. Fill wellbore with a total of 250bbls of produced water. 7/25/2013 -Thursday Pressure test cementplug/casing 1,600psi for 45 minutes. Test good. Pressure casing to 1,630psi: 2:25pm - 1,630psi; 2:35pm - 1,620psi -2:45pm - 1,610psi; 2:55pm - 1,605psi 15:05- 1,600 psi 7/26/2013 - Friday MIRU Halliburton to run 3D Neutron log. RIH to casing shoe. Run repeat pass. RIH to bottom. Tools failed. Spent all afternoon trying to fix tools. No luck. POOH and RD. 7/27/2013 -Saturday MIRU Halliburton to run 3D neutron log. 8/19/2013 - Monday MIRU WOR & all other equipment. Performed a shell test on lines& BOPE. TEST GOOD. SDFN. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KU 24 05RDzE, -Liiiec 50-133-20358-01 201-144 7/15/13 8/21/13 Daily Operations: 8/20/2013 -Tuesday Perfrom BOP test as follows: annular to 250 psi low/2,500 psi high. 2-3/8" x 3-1/2" VBR's, blind, HCR's, choke and kill manifold valves, TIW, IBOP, and kelly valve to 250 psi low/3,000 psi high. All components passed. Jim Regg, AOGCC waived witness 8/18/13 12:12. Justin Miller, BLM waived witness 8/18/13 11:50. MI RU 2-7/8" WLEG 5 jts of 2-7/8" 6.5# L-80 tbg, X- nipple 17 joint of tbg& 7" 26-32#AS1-X packer. TIH w/ BHA&tub tagged top of liner w/ PKR. Made multiple attempts to get through w/ No success. POOH w/3 stands. SI secure well SDFN. 8/21/2013 -Wednesday Finish POOH w/7" PKR &Tbg. LD 7" PKR. PU MU 9-5/8" PKR. RIH and set PKR @ 3,135'. EOT WLEG@ 3,903'. ; Installed hanger. Circulated PKR fluid. Drop Bar to set PKR. Pressured up on tbg to 4,000 psi in 500 psi increments. Held 5 min. GOOD TEST. Charted &Test backside to 2,000 psi for 30 min. GOOD TEST. MIRU Pollard SL unit. RIH and pull drop bar& plug. POOH RDMO SL unit. Set BPV in hanger. ND BOP & NU production tree. Test to 3,000 psi. GOOD TEST. RDMO &Turn over to production. • Kenai Gas Field la 1110 Well:KU 24-05RD PTD:201-144 SCHEMATIC API:50-133-20358-01-00 Last Completed: 12/22/2001 Hilcorp Alaska,LLC :MSL=94'/21 Aa CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm b�j . * ' 20" Conductor 94/H-40 19.124 Surf 136' }" p *+ ",# 13-3/8' Surface 61/K-55 12.515 Surf 2,012' S t+' 9-5/8" Production 47/N 80/BTC 8.681 Surf 3,500 *'' '+)`• 11% 7" Liner 26/L-80 6.276 3,195' 4,608' a. 4 TUBING DETAIL • 4 d ,- r' )0 s,^ , vn; 2-7/8" Tubing 6.5#i/L-80 2.441 Surf 3,903' N V 1 At !, * .X* JEWELRY DETAIL im to a lio T` *I ?I '. No Depth Item , Ni I/ Vis, I., . 1 3,135' DHL Hydraulic Packer tat M im4H ei4 2 3,185' X Profile Nipple(2.313"I.D.) '• { :4 + 3 3,195' Baker Flexlock Line Hanger w/ZXP liner top packer +'`+ s 'r '+"s 4 3,903' WLEG '7 5 4,370' Umbrella Plug 0. 144 4'4. :ip re: , ,. 9-5/8"Window(Cut 11/27/2001) )i',': 13-3/8" 4" 3,471,to 3,488 PERFORATION DETAIL `t. % Sand Top Btm Top Btm Amt Status Date Guns (MD) (MD) (TVD) (TVD) ,..,,V. t All 4,380' 4,430' 3,833' 3,880' 50' Isolated 4-5/8"Millenium Stimgun rii i4, 0 Alf,/ 15/8"# L, �=;`.��� 3 00 I— )", ... r i4 14 TOC@4,307 110▪., 07/24/13 *,� ,� „ 'Pi isr IV 5 Sterling OPEN HOLE/CEMENT DETAIL Pool t 13-3/8" 17-1/2"hole Cmt w/1,500 sks of Class G 44,4 fi444i ,- ; 9-5/8" 12-1/4"hole Cmt w/1,800 sks of Class G s i7< ' , 7" 8-1/2"hole Cmt w/152 sks of Class G 1, ie PBTD=4,307 MD/3,763'ND TD=4,816'MD/4,251'1VD Updated by DMA 02/18/16 • M Marathon MARATHON Oil Company August 25, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 333 W 7th Ave ~,~ ~FP ~'~ ~ 2D08 Anchorage, Alaska 99501 nn ~~~ I~~ d~ Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Unit 24-5 ReDrill Dear Mr. Maunder: Attached for your records is the Report of Sundry Well Operations 10-404 for installation of the velocity string in KU 24-5RD well. This work was completed in August of 2002 under Sundry # 302-241. Submission of this sundry is part of Marathon's effort to close- out the backlog of outstanding sundry reports. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ` '`~,J Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operation Summary Kenai Well File KJS ~~ STATE OF ALASl44 9 ALA~OIL AND GAS CONSERVATION Q~~$ REPORT OF SUNDRY WELL O TIONS . ~_,.4~n n41 Ri G~~ COe1S. '~O(~1~15$IOfI 1. Operations Abandon Repair Well Plug Perforatio Stim~ ~(~~ Other ~ Velocity String Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Hang-off Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development^ Exploratory^ 201-144 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20358-01-00' 7. KB Elevation (ft): 9. Well Name and Number: 94' (21' above GL) ~ Kenai Unit 24-5 ReDrill ' 8. Property Designation: ~ 10. Field/Pool(s): ~~ A - 028142 ~ Kenai Gas Field /Sterling Pool 4 - 11. Present Well Condition Summary: Total Depth measured 4,816' - feet Plugs (measured) NA true vertical 4,251' - feet Junk (measured) NA Effective Depth measured 4,761' feet true vertical 4,1g8' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 136' 136' 1,530 psi 520 psi Surface 1,991' 13-3/8" 2,012' 1,864' 3,090 psi 7,540 psi Intermediate Production 3,479' 9-5/8" 3,500' 3,053' 6,870 psi 4,750 psi Liner 1,358' 7" 4,608' 4,051' 7,240 psi 5,410 psi Perforation depth: Measured depth: 4,380' - 4,430' - True Vertical depth: 3,832' - 3,882' - Tubing: (size, grade, and measured depth) 2-3/8" HO-70 4,380' Packers and SSSV (type and measured depth) ZXP Liner Top Packer 3,197' 12. Gas Lift Summary: A 2-3/8" coil tubing velocity string was hung off at 4,380' to aid in water extraction. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ - Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^/ - WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 302-241 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ,,,(f~j~ , , ~ Phone (907) 283-1371 Date August 25, 2008 Form 10-404 Revised 04/2006 ~ ~ t k --i ~ ~ ~ L S ~~- 5~P ,~ ~ ~~~~Submit Original Only 111 v ~~It'"~ • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/31/2002 FIELD: Kenai Gas Field WELL #: KU 24-5 FILL DEPTH/DATE: TUBING: 2-3/8" CT CASING: 7" 26ppf, L-80 DATE LAST WORK: TREE CAP: 6-1/2" OTIS WORK DONE: Hangoff Velocity String BENCHES OPEN: SUMMARY OF OPERATIONS Start E ui ment, Safe meetin rocedure meetin .Wait on weld ins ection for BHA x-over Weld ins ection e Wait on BOP hose cxn Function and ressure test BOP. Blind shear leakin .Chan a out seals MU BHA. Successful ressure/function test 250/3000 si. Safe meetin O en well, RIH Run to 4400'. PUH to 4363' to make cut s ace out to land at 4380' Close i e sli s, lock in BOPs Walk u in'ector Cut wee hole and check for ressure. Cut coiled tubin MU coil connector and han er Pull test connector Stab back onto tree PU pipe weight, unlock rams and realease coiled tubing from slips. RIH and tag in hanger (landed at 4380' CTM . ABB run in lock screws and test han er Pum to release h draulic GS connector Ri off well Vendor Equipment Daily Cost Cumulative Cost Schlumber er CT & um Veco Crane, Vac Truck, O eratars S&R Truckin _ ABB Vetco Wellhead Svc Baker CT tools DAILY COST: CUM: REPORTED BY: Titus - " MARATHON OIL COMPANY • • DAILY WELL OPERATIONS REPORT DATE: 8/2/2002 FIELD: Kenai Gas Field WELL #: KU 24-5RD PILL DEPTHIDATE: N/A TUBING: 2 3/8" CASING: 13 5/8" DATE LAST WL WORK: N/A TREE CONDITION: Good WORK DONE: Pull Pluq WIRE TEST: 22 PRESENT OPERATION: Complete OTHER: WBS # TA.02.07226.EXP 3"OOL STRING: (1.5" TS) RS, KJ, 10' Stem, KJ, OJ, Spanqs Hrs. 12 WIRELIKE CREW: D. PollardlTomlinson PROD: DRILL: RSO #: 455-864 SUMMARY OF OPERATIONS Tlcket #: P-202 11:00 12:00 12:30 16:00 16:45 17:15 Vendor Equipment Dail Cost Cumulative Cost Pollard Wireline Inc. 12 hr min w/ 2 man crew Pollard Wireline Inc. 1 1/4" JDC Pollard Wireline Inc. Fuel Pollard Wireline Inc. Pollard Wireline Inc. DAILY GOST: CUM: REPORTED BY: Denise Titus • M Marathon MARATHON Oil Company April 23, 2008 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~ V APR 2 5 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Unit 245 ReDrill Dear Mr. Maunder: Alaska Oil ~ Gas Cans. Commission ...~,,. Anchorage ~Y d,o~~ ~~ Attached for your records is the 10-404 Sundry, reporting on the gas lift operation of KU 24-5RD well. This gas lifting operation commenced on 3/28/2008. Once initiated, the gas lift volume was adjusted to create a balance which unloaded the wellbore condensate while minimizing the lift rate. The well is presently operating at a two-to-one ratio. 600mcf of annulus flow gas is being produced with 400mcf of lift gas for a net increase of 200mcf. The production gas volume is the difference between the annulus gas and the lift gas. The metering process used to determine the formation production gas volume is described in the accompanying 10-403 Report of Sundry Well Operations. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~~~. ~~ Kevin J. Skiba Engineering Technician ~~~; MAY ~ 2D08 Enclosures: 10-404 Sundry Report cc: Houston Well File Well Schematic Kenai WeN File KJS STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMIv~ION APR 2 5 20Q~ REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ nc oraig~s Lift Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory^ 201-144' 3. Address: PO Box 1949 Stratigraphic ^ Service^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20358-01-00 7. KB Elevation (ft): 9. Well Name and Number: 94' Kenai Unit 24-5 ReDrill - 8. Property Designation: 10. Field/Pool(s): FEf~ A - 028142 - Kenai Gas Field / Sterlin Pool 4 11. Present Well Condition Summary: Total Depth measured 4,816' ' feet Plugs (measured) NA true vertical 4,251' ' feet Junk (measured) NA Effective Depth measured 4,761' feet true vertical 4,198' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 136' 136' 1,530 psi 520 psi Surface 1,991' 13-3/8" 2,012' 1,864' 3,090 psi 1,540 psi Intermediate Production 3,479' 9-5/8" 3,500' 3,053' 6,870 psi 4,750 psi Liner 1,358' 7" 4,608' 4,051' 7,240 psi 5,410 psi Perforation depth: Measured depth: 4,380' - 4,430' True Vertical depth: 3,833' - 3,880' Tubing: (size, grade, and measured depth) 2-3/8" N-80 4,380' Packers and SSSV (type and measured depth) 2JCP Liner Top Packer 3,197' 12. Gas Lift Summary: KU 24-5RD gas lift operation commenced on 3/28/08. The Lift Gas (24-5L) and Annulus Flow Gas (24-5AN) volumes are measured through similar meter runs consisting of Senior Daniel orifice plate fittings coupled to Multi Variable Transmitters (MVX) which feed values to Barton Electronic Flow Meter (EFM) computers. Both of these meter runs are located on Kenai Gas Field's, Pad 41-7. The MVX's measure static line pressures, orifice plate differential pressures, and gas temperatures which it feeds to the Barton EFM's to determine the flow volumes from each meter run. The actual formation gas production volume, used for reporting, is the difference of these two volumes and is derived by subtracting the lift gas volume from the annulus gas production volume. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 40 44 Subsequent to operation: 0 200 2 40 6 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations 16. Well Status after work: Oil^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ ~ ~~~` ~'~~ ~ '~ 200 NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~ Signature r ~ Phone (907) 283-1371 Date April 23, 2008 50-133-20358-01-00 A - 028142 n: 94' (21' AGL) 11 /29/2007 1 /15/2008 I: 12/6/2001 Kenai Unit 24-5RD Pad 41-7 332' FNL & 4,331' FWL Sec. 7, T4N, R11W, S.M. Directional Max hole angle 38.3° @ 3,530' Max dogleg = 6.36°/100' @ 3,840' Baker 7" Flexlock line hanger @ 3,197' MD _~ w/ ZXP liner top packer Window cut (11 /27/2001) _ 3,471' - 3,488' MD Top of 9-5/8" bridge plug at 3494' MD. 9-518" cement retainer set at 4375' MD. Squeezed 13 bbls 15.6 ppg cement bebw retainer. B-1 perfs sealed off w/ LCM XA Sliding Sleeve @ 4,587' ID 2.75" 'd hard cement out of tubing fror 5' to 4,608' wl CT prior to fishing left hard Cement @ 4,608'. 2.75"'X' Nipple @ 4,633' w/Mule shoe tbg tail @ 4,644' } ~ ~. B-4 Perfs 4,789'-4,864' DIL (81411982) , ~-~~', B-4 Perfs 4,899'-4,909' DIL (Sgz'd) ~~~ Fill @ 4781' SLM (8/27/1993) ~ Cement Retainer @ 4,886' TD 5,900' MD 4,956' ND MARATHON Drive Pipe 20" H-40 94 ppf Top Bottom MD 0' 136' TVD 0' 136' Surface Casino 13-318" K-55 61 ppf Top Bottom MD 0' 2,012' TVD 0' 1,864' 17-112" hole Cmt w11,500 sks of Class G 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 3,500' TVD 0' 3,053' 12-114" hole Cmt wl 1,800 sks of Class G Liner 7" L-80 26 ppf Top Bottom MD 3,250' 4,608' TVD 2,866' 4,051' 8-112" hole Cmt wl 1 52 sks of Class G '1 ' Velocity String Tubins;t '~ 2-318" N-80 ID = 2.107" a c Top Bottom 9 C MD 0' 4,380' i ND 0' 3,833' "' X profile nipple PBTD TD =~~4,81~6' MD 4,761' MD TD = 4,251' ND 4,198' ND KU 24-5RD Sterling, Pool 4 Perforations . _ -_--. ----_-_~ __ _. __.~.~___..__ .a_~..._..-~__~ Measured Depth_ __ TVD _ SPF . T~_ Bottom r Foota e _ T_~ _ _ Bottom 4,380' 4,430' S0' 3,833' 3,880' S 4-5/8" Millenium StimGun ..i ,, v~ ~l+- 9-518" N-80 47 ppf BTC Top Bottom MD 0' 5,900' TVD 0' 4,956' 12-114" hole Cmt wl 1,800 sks of Class G Well Name 8 Number: Kenai Unit 24-5 Lease: Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 4,380' - 4,430' MD (ND): 3,833' - 3,880' TVD An le KOP and Depth: 38° 3,500' MD An IelPerts: 16.75° Dated Completed: 1 21512 0 01 Completion Fluid: Prepared hy_ Kevin Skiba l,+st Revison Date: 3125/2008 RE: Contact information for T~Maunder AOGCC • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 25, 2008 1:07 PM To: 'Skiba, Kevin J.' Cc: Laughlin, Gary A. Subject: RE: KU 24-5RD (201-144) Kevin, You are correct. No sundry. We will have to see about a 404 documenting the change. I am sure we will talk/message further. Tom Maunder, PE AOGCC Page 1 of 2 From: Skiba, Kevin J. [mailto:kskiba@marathonoil.com] Sent: Tuesday, March 25, 2008 11:50 AM To: Maunder, Thomas E (DOA) Cc: Laughlin, Gary A.; Skiba, Kevin J. Subject: RE: KU 24-5RD (201-144) Tom I just want to confirm, for my records, that Marathon does not need a sundry to pen`orm the gas lift operation on KU 24-5RD well. This operation is scheduled to commence on Thursday 3/27/2008. The installation of the Velocity String meter has been reversed to correctly measure the flow down through the tubing. Notification has been given to the metering and accounting personnel regarding this change in operation. The production value submitted for this well will be the total flow of the well minus the gas lift volume. Thanks for your cooperation, Kevin Slaba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ~~;~ MAR ~ ~ Z00~ From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Monday, March 24, 2008 2:05 PM To: Sweet, Welby C. Cc: Skiba, Kevin J. Subject: RE: KU 24-5RD (201-144) Welby and Kevin, What is described is looks to a form of gas lift. I don't see an issue with the proposal. Right now you are planning to test the concept to see if it is possible to keep the well unloaded. You do plan to meter the lift gas so that net production can be determined. Since annular flow is involved, the pressures are likely to be low. Good luck. Keep us informed of the progress. 3/26/2008 RE: Contact information for T~ Maunder AOGCC Page 2 of 2 • Tom Maunder, PE AOGCC From: Sweet, Welby C. [mailto:wcsweet@marathonoil.com) Sent: Monday, March 24, 2008 11:08 AM To: Maunder, Thomas E (DOA) Cc: Skiba, Kevin ]. Subject: RE: Contact information for Tom Maunder AOGCC Tom, Briefly we want to try to restore the gas production from KU 24-5RD to an economic volume by injecting a volume of relatively "dry" gas down the existing 2.375" velocity string where it will then mix with formation gas in an ~3:1 ratio. The total volume of injected and formation gas will then be produced to the surface through the 9.625" X 2.375" annulus. The goal is to combine enough "dry" gas with the formation gas to eliminate water condensation in the wellbore and thereby eliminate the source of water loading. We will meter both the injected gas and the total produced wellstream through standard gas orifice meters equipped with flow computers. The volume of formation gas will be determined by difference. If you have any questions or need any further information, please let me know. Regards, Welby Sweet Adv. Sr. Process Engineer Marathon Oil company Office (713) 296-3111 Fax (713) 513-4389 From: Skiba, Kevin ]. Sent: Monday, March 24, 2008 1:05 PM To: Sweet, Welby C. Subject: Contact information for Tom Maunder AOGCC Welby Here is Tom Maunder's email address. He is the engineer for the AOGCC (Alaska Oil & Gas Commission) that I spoke with about KU 24-5RD. Please send him the information about your gas lift and metering plans. tom_maunder@admin.state.ak.us Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 3/26/2008 e e Alaska Asset Team United States Production Operations (.~ Marathon MARATHON Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-235-6322 July 2, 2007 FEDERAL EXPRESS Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED JUL 0 3 Z007 RE: Marathon KU #24-05RD - API 50-133-20358-01 CONFIDENTIAL b \ Dear Mr. Okland: ~ \ ç)J Alaska Oil & Gas Cons. eommission Anchorage Enclosed is one CD containing confidential digital well data for the above referenced well, as described on the attached CD Contents document. Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-235-6322. Thank you, SCANNED JUL 0 5 2007 Courtney McElmoyl Reccived by:j)J ðlJJ Date: 1 J \W~ ~ J Enclosures ~D1 ~/c..£4 e Directional Data: ~ . :ku_24-05rd_dir _sur. dat ¡ ............................................................~ Mudlog Data: ìQ!?.~.~..~~~~..j IÕ Morning reports rm.ìKU 24-5RD FINAL REPORT.doc [ KU24-5RD REMARKS.txt ~ KU24-5RD .Ias e KU 24-05RD API 50-133-20358-01 CD CONTENTS Confidential e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc ;;< ;t J~ ~ v( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011440 Well Name/No. KENAI UNIT 24-05RD Operator MARATHON OIL CO 5P~ ~O ¡J bu ~\ API No. 50-133-20358-01-00 MD 4816 ../ TVD 4250 '" Completion Date 12/22/2001 /' Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No ------ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) -~ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Interval Start Stop OHI CH Received Comments Well Cores/Samples Information: Name Cuttings Interval Start Stop 3470 4816 Sent Received Sample Set Number Comments 1111 -- ----==-~~J ADDITIONAL INFORMATION Well Cored? yr@) Chips Received? -::£..1J\L--- Daily History Received? (?)/N QN Formation Tops Analysis Received? ~ ---- Comments: U ù t{tì ~. ~~ ~ '<Z. - A.s r -,,~ t, -------- ~I --------~ Compliance Reviewed By: ~ Date: )[ d ~ ~t- --------- ~ i.' ~ Alaska~, .ness Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 20, 2002 K1iJ) ;;(0 ) -- l t[ 1 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 VIA COURIER S~~ ft- I l , RE: Marathon Kenai Unit #24-5RD - CONFIDENTIAL Accompanying this letter are two (2) boxes of CONFIDENTIAL well samples for the above referenced well, as described below Box# Depth To Depth 1 3470 - 4380 2 4380 - 4816 Please review the enclosed data, sign and return one copy of this transmittal. Thank you, 4(&crJf2 ? ~"--- Kaynell Zeman ëS Technical Assistant Attached (2 boxes) Received by: Date: ~~t\ 1LJ 0 JJJ ~ '2......00 ).. Environmentally aware for the long run. lNdl F',' If.- . ~UL-30-2002 TUE 12:56 PM(~^~ATHON OIL COMPANY F AX NO, gp7 283 6175 P, 02 ~ ( ~l . AOGCC24-5rdhE\ngOffSUndry.~ ~ ~ / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Typo of RE:!que$l: Abandon - Suspend - Qperalion Shutdown - Re-enter Suspended Well - Alter Casing - Repair Wen ~ Plugging - Time ExtcnslOI1- Stimulate - Change Approved Program - Pull Tubing - Variance - Porforat~ - Other .2.... ~. Type of Well: 6. Datum Elevation (DF or KB) Development X KB Exploratory - 'T. Unit or Property Name Stratigraphic - Kenai Unit Service = 6. Well Number / ~, KU 24.5RO 9. Permit Numb~ 201.144 .V' 10. API Number 50-- 133-20356-01 -/ 11. Field/Pool Kenai Gas Fiøld, Pool 4 21 feet 2. Narno of Op~rator MARATHON OIL COMPANY 3. Address P. O. So)/. 196168. Anchorage, AK 99519-6168 4. LocÇJlIOfl or Well at Surface 332' FNL, 4331' FWL. Sec. 7, T4N, R11W, S.M. At top clf Productive Intervõ11 837' rSL, 5381 FWL. Sec. 5, T4N, R11W, S.M. At Effective Depth (Ha!:!RYelocity String to Lift Water I At 1'ol<.11 Depth 940' F~<;;L, 606' FWL. See 5. T4N, R11W, S.M. 12. Prasenl Well Condition Summary Tot\ll Depth: measured true vertical 4816 feet 4250 feet Plugs (measured) N/A Effeclive Depth: measured true vertical 4717 feet 4155 feet Junk (l'Y1easured) N/A Casino Struc~ural Conductor Surface Intermedi<J.te ~)roduction Liner PerfóralÎon Depth: length SIze Cemented Measured Depth True Vertical Depth 136' 2012' 20" 13.3/8" Driven 1500 sks 136' 2012' 136' 1861' meas,¡rad 3500' 9-5/8" 161~ r 8~1 : 4380' .4430' MD 1800 sks 152sx 5900' 4816' 35001 4250' true vertical 8.1: 3832' - 3882' TVD '."':Ii"""f"'\f""'ì\~~.,~....i"'I"\1. ~, ¿ "~"! f ..,1 ," ~'( 11".,~ II il ~~, h., ,1.,;1' ;1 .;~ i"..". I"~;"~", \...,' ' ... TuÞing ($i~è, {Jrade, and measured depth) 2M3/8", 3.21 ppf, HO.70, coiled tubing to 4380'MD t' ("1 '\ I"'. \'1\'. "\n. ..>\d~/ ¡ \ " ' " ",-"" I. \., '",.; ~.,. ."~' Packers and SSSV (type and me;Jsured depth) N/A .. j!r'~Ii,\¡~H:;)gUj\ ¡.\\3:skaOiI g! bhf', ""","'~'»'. . Anûhor&~~ " 13. Atl~chmenls Description Summary of Pro~osal- l')etailed Operations Program X - BOP Sketch - 14, ~stirn;:lted Date for Conlmenoing Operation 15. status of Well Classification as; 16. If Propo$al was Verbally Appfoved Oil Gas X - - Suspended ~ Name of AppfO\lt;'.f Date Approved Service 17. berc: lJy certify thLJt the foregoing is true and corn¡)ct to the best of my knowl~dge. Sll'n~~' ,~n.". ¡Ih 4fÞDE..nl.se M. Tl'tus " vI.' \Y:'\J"., III f Title ProdlJOliOn ~nÇJineer ~--=---, FOR COMMISSION USE ONLY .. Conditions of Approval: Notify Commission S. 0 repr~;entDtivD may witness Plug InlegrÎty BOP Test.A.. Locatiol'1 Clearance Mcché1nit'1al Integrity Test Subsequent Form Requited 10- '-\0 '::l-. ~ OrIginal Signed By Cammy Oechsli T aylOf D;!!te 7/30/2002 IAPprov~1 N°'3 0 Z.. Z ~ 1 Appro~~ ~)y Order of the Comr'níS$ion F~,1( (\ 10.~O~j r~C!V OG/1!./I!¡') Commissioner ¡ Date 'i7 /:~ll'~)~ - Subrflit In Tnplir.all~ - C'" f. ...~ , (""~' "I [1 j~' in, ~ P $1, f, ~ ,1 ~ ~'\"'~.:."."-"::~II\.I...I'\\ ~ ~' II I) ì i ,'<". iJY ij, ~.",") a ", iJ ¡,--. "i ,'J 'l (i It ~ MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 24-5rd WeSt RW.O1.GO650.CAP .CMP VELOCITY STRING HANG OFF History: KU 24-5 is a sidetrack from 9-5/8" casing to a 7" liner (liner hgr @ 3197'). The well was perforated with StimGun from 4380'-4430'. Objective: Install a 2 3/8" velocity string to lift water. This is a preliminary step to a potential concentric lift string. The velocity string will include a BST lift BHA which will seat a blanking plug or a standing valve insert. Note: Liner hanger restriction from 9 5/8" to 7" liner hanger @ 3197'. TO-4816' Procedure: 1. Prepare well for work (ie. Remove wellhouse, RU flowback iron, choke and tank) 2. MIRU CT unit wi 2-3/8" pipe (wi wireline retrievable running plug and BHA installed). 3. RU to annulus and coil reel wi fluid pump. Install pressure gauge on opposite side of annulus. Pressure test lines and BOPs to 250/1500psi. 4. RIHto4380'. Correlate to...... Mark pipe. 5. Measure distance from CT hanger lock screws on tree to above BOPs. Pick up measured distance. 6. Close BOP slips and rams. Monitor well pressure on annulus to make certain pressure remains at 0 psi. 7. Break the connection above the BOPs and raise injector head (as per Schlumberger CT Operating procedure) as needed to clear the hanger to cut CT and install CT hanger seal assembly. 8. Install C-Plate and dog collar slips on pipe. 9. Cut tubing and install CT connector, OFV, Hydraulic GS and CT hanger seal assembly. Pull test CT connector to 25,000 Ibs. 9:59 AM 07/31/02, DMT C :\DOCUME-l \ TEMA UN-I \LOCALS-l \ Temp\hangoff.doc 'f ( ( 10. Engage running tool in top of hanger. Remove dog collar and C-plate. Lower injector (as per Schlumberger CT Operating procedure) and make up riser to BOP. Pull Test connectors and hanger against slips to + 1-10000 Ibs. (4000 Ibs. Over pipe wt.) 11. Slowly lower pipe to hangoff depth using mark on pipe as reference, watch for drop off in weight to verify hanger location. Check measurements, and land hanger on load shoulder. 12. RU ABB Vetco to run in lock screws and torque per hanger specifications. Verify seal integrity via pressure test ports in tubing head. 13. Pump down CT 1.5 bpm to 2 bpm to release running tool and retract. 14. ROMO Coiled Tubing unit. 15. Turn flowing well over to system per instruction of operator. 9:59 AM 07/31/02, DMT C:\DOCUME-l \TEMAUN-l \LOCALS-l \Temp\hangoff.doc ¡2ö"fM~H4O:_ÖÌiv~Þ¡pe-@ 1-36'_- ~~;~8:~~~~-;:~;I~;~~~~' J ~;~~~8:k~:~~::Ö; ~. IKOP 3500' MD ( ,',' " J!. I !!~] < 1IIIi '\¡¡ '. .. " " ~¡~ m :;: ::¡ ,', .'" ~¡~ ~¡~ III ;i¡ m¡ ~:~ ~:.: ::: =::: ~!~ ~~~¡ ;¡¡¡ ~1~1 ;1 , .nl¡ ( ~ Pad 41-7 KU 24-5RD Sidetrack Well bore Liner Hanger at 3197' Sterling B-1 Sand Peñorations: 4380'-4430' MD 4-5/8" Millenium StimGun 5JSPF I I I 17" 26 ppf L-80 casing at 4816' MD Jun-14-02 01: 17pm From-MARATHON /' II ( ~ M ~ Marathon MARATHON Oil Company +9155646489 ( T-311 P.02/02 F-269 ,,01 Alaska Region Domestic Production P.O. Box 196168 Anchorage. AI( 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 June 14, 2002 Steve Davies AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Davies: At your request, Marathon Oil Company and McLane's Surveying have researched the proper offset information for the KU 24-5 original wellbore and the KU 24-5RD sidetrack located in Marathon's Kenai Gas Field. The proper offset for the identical surface location of these two wells is as follows: 332' FNL, 4331' FWL, Section 7, T4N, R11W. S.M. Please accept our apologies for any confusion associated with this matter. If you would like any other information) please contact me at 564-6305 or kdwalsh marathonoil.com. Sincerely) I~b,w~ Ken D. Walsh Advanced Production Engineer RECEIVED ,JUN 1 4 2002 l.\Iaska Oil & Gas Cons. Commission Anchorage "" F rom-MARATHON (II I. ( +9155646489 T-311 P.01/02 F-269 Jun-14-02 01 :17pm Fax To: Steve Davies, AOGCC From: Ken Walsh Fax: 276-7542 Pages: 2, inc1uding this cover sheet Phone: 793~1224 Date: 06/14/02 Re: KU 24~ 5 and 24~SRD surface offset cc: 0 Urgent ~ For Review 0 Please Comment D Please Reply 0 Please Recycle Comments: Steve;> Please find faxed with this cover, a leU:er containing the accurate offset information for the above- referenced weUbores. Ken Walsh Advanced Production Engineer Marathon Oil Company RECEIVED JUN 1 4 2002 From,... Marathon Oil Company 3201 "Cn SU'eet, Suite 800 Anchorage, AK 99503-3934 Phone: 564-6305 Fax: 564-6489 Alaska Oil & Gas Cons. CommisSion . Anchorage , ,---. - . - ,-.. .. , ( I¡' I Alaska Reg'ion Domestic Production Marathon Oil Company P,O, Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 May 28, 2002 Steve McMains AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. McMains: Attached in triplicate is the completed Form 10-407 Well Completion of Recompletion ߧJort and Loq for the abandonment of the producing intervals in well KU 24-5. The lower portion of this well bore was permanently abandoned prior to initiating work to drill and complete a sidetrack well bore identified as KU 24-5RD, Also attached for your records is the final well schematic which includes detail for both well bores, If you would like any other information, please contact me at 564-6305 or kdwalsh@marathonoil.com, Sincerely, I~~ , vJ~ Ken D. Walsh Advanced Production Engineer Enclosures /"" ;"". ~ \, f r~ ¡ ~...... ~ \!' t... ,-', " '" ,', ,:\,'/ ;.~' :) ?OO? A¡as!c:¡U,;y,,(:;:,::.;,,",i;;, ",,\::I;,'J.'~II¡! ,'~:,:::. (IC ::, '>1 'lr)lr'\lf'f[r ! to' f '\; ~ I ""7 f ,\ r /- \ ; ( ~.' !~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILD GAS ŒJ SUSPENDEDD ABANDONEDD SERVICED 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 201-144 3. Address 8. API Number P. O. Box 196168, Anchorage, AK 99519-6168 ,~... "" 50-133-20358-01 , ' ',,' ' 4. Location of Well at Surface ",'", ?i;f,'~~~~~f~' -?' 9. Unit or Lease Name '! t) " '-: ~ ,J 'i.~. I of. '\;"" (, 332' FNL, 4331' FWL, Sec. 7, T4N, R11W, S.M. IM~I, f¡~Ù1\"¡ Kenai Unit At top of Producing Interval ] "VI" '":"-":' , 1 O. Well Number ~~';' " ~~ r'~~r: --""0": 837' FSL, 538' FWL, Sec. 5, T4N, R11W, S.M. ' :" ,,' , . ,.. KU 24-5rd !,:..w "~""'::~"~"~:'::~:" '.~:f". - ¡:;. :.',.',.t~13'::~,,; At Total Depth ': .,,:'C"'t'{'-~"'-" ' "-" , -.' :" 11. Field and Pool 940' FSL, 606' FWL, Sec. 5, T4N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kenai Gas Field, Sterling Pool 4 21.5' DF-GL A-028142 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/28/2001 12/1/2001 12122/2001 N/A feet MSL one 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 4816' MD, 4250' TVD 4717' MD, 4155' TVD Yes~NoD N/A feet MD N/A .22. Type Electric or Other Logs Run GR-RST-CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 H-40 0 136 N/A Driven 13-318" 61 K-55 0 2012 17-1/2 1500 sx N/A 9-518" 47 N-80 0 3500 12-1/4 1800 sx N/A 7" 26 L-80 3197 4816 8-1/2 152 sx N/A 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A Sterling Pool 4 B1 Sand: (12/22/01) 4380'-4430'MD \ 3832'-3882'TVD 4-5/8" Millenium StimGun, 5spf, 60 deg wi 2150 psi overbalance (N2) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 27-Dec-01 flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 27-Dec-01 24 TEST PERIOD -. 0 16000 0 64/64" N/A Flow Tubing Pres. Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) 125 0 24-HOUR RATE -. 0 16000 0 N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPREg " E B-1 lithology is interbedded, light brown to gray, fine to medium grained graywacke sandstone, with minor siltstone, 1;0gy'Sc"Pn) \ Density log porosity ranges from 30 -37% in the Sterling B-1 sandstone. APR The Sterling B-1 sandstone is depleting gas (C1 methane) reservoir. :3 2OfP AI8IIrI 0111 Gal ConI. Commissioo . Form 10-407 Rev. 7-1-80 CONTINU1(-~...\..'..~I...I.i...'. ~ &.11"'.' ~.. .~'. ..'" ...~/r ~ ¡¡, Ii ~ ~.I n, I' t \ ¡ ~",,/ I \ 11 Lß '~ ~\ i¡'-' 1L- .-. .-- Submit In Triplicate RBDMS 8FL JQ -"~ ~ 8 2002 N: \d rlg\kgf\we 115 \K BU 33- 6\AOG CO M P L. xis ( r( 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sterling 4182 3629 RECEIVED APR '1 ..1' I'. ; .I !rJ {' ,\ ' _œ'GlaCœs. Con1missto!'I ~ 31. LIST OF ATIACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ uJ~en Walsh Title Advanced Production Eng. Date 4/1/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wens: 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 producìng 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 ~\. " t) " f I' ~ ! I;~ ~ \\ rJ :¡. ¡r::. ~ l\J' k") "~II , ",.~ N:\drlg\9terling\su32-9V\OG CaMP l. xIs KU 24-5, Pad 41-7 I Sidetrack Wellbore Liner Hanger at 3197' KOP 3488' MD Top CIBP @ 3494' MD ¡Cement Retainer @ 4375' I B-1 Perforations: 4380'-4430' MD 4-5/8" Millenium StimGun 5JSPF .-17" 26 ppf L-80 casing at 4816' MD _m_____--_--_m_m ----- -- 22"iJ4# H-4()m~~v~F'ipe~136' -- Top of 9-5/8" bridge plug at 3494' MD. 9-5/8" cement retainer set at 4375' MD. Squeezed 13 bbls 15.6 ppg cement below retainer. IB-1 perfs sealed off with LCM 1 IXA Sliding Sleeve @ 4587' 10 2.75" I ______m_- - - -- -- - BakEJ~~~d_~-'ek~_~_4607' . Drilled hard cement out of tubing from 4365 to 4608 wi CT prior to fishing job, left hard Cement @ 4608' -------------- 2.75" 'X' Nipple @ 4633' wlMule shoe tbQtail_@_j644' Pad 41-7 KU 24-5 Original Wellbore KU 24-5RD Sidetrack Well bore Liner Hanger at 3250' KOP 3500' MD Sterling B-1 Sand Perforations: 4380'-4430' MD 4-5/8" Millenium StimGun 5JSPF ....-17" 26 ppf L-80 casing at 4608'MD , """"-""--"'-'----"""""""'-"-'~~~------'-- ","',--, . . , .',',',', ','.,'.~---_._-,,--.. ((: -f r, - MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKU 24-5 AD 17-Nov-01 Demob. Rig down, 18-Nov-01 RID rig at GO #2 location and begin move to KU 24-5 Icoation, 19-Nov-01 RlU on KU 24-5rd. 20-Nov-0 1 RlU on KU 24-5rd, 21-Nov-01 RlU on KU 24-5rd. 22-Nov-01 Complete RlU rig. Fill well with water. Set BPV. N/D Xmas tree. N/U BOPE. Tested BOPE, 23-Nov-01 Test BOPE, Pull and UD hanger. Pull 3.511 TBG. M/U bit and scraper 24-Nov-01 Run bit and scraper, Circ hole. POOH, RIH with 9 5/811 EZSV Set at 4375', Perform squeeze job. 25-Nov-01 Complete circulation after squeeze. POOH and UD stinger. Test CSG to 1500 psi. RIH with 8,511 bit and 9 5/8" scraper. POOH. RIH with gauge ring junk basketRIH with Bridge plug, 26-Nov-01 RIH with overshot fishing assembly, Fish out setting tool. RIH, Drill out bridge plug chase to 4300', POOH and test casing. Run bit and scraper to 3900'. CBU, :( \, ' ( MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKU 24-5 AD 27-Nov-01 Run gauge ring and set bridge plug, M/U whipstock/Mill assembly and RIH, Orient whipstock and set at 3494', Displace hole to milling fluid, 28-Nov-01 Milling window, POOH for mill change, Milling at 3484', 29-Nov-01 Mill window, Open to 8 1/211 to 3514', Displace to Flo-Pro. Test shoe to 16,3 ppg, POOH. Test BOPE, 30-Nov-01 Test BOPE, RIH with MWD and motor. Drilli from 3514' to 3830', 1-Dec-01 Drill to 3853' with PDC, Tripped for bit. Drilled to 4675'. 2-Dec-01 Drill to 4816', Short trip, Circ sweep. POOH, Started running liner. 3-Dec-01 Ran 7" liner. Circ and add LCM. Cemented liner. Set packer. Circ out cement from liner top. Tested csg to 1500 psi. POOH, .,-..--..--.-.....--.-"--..-...-- --....... ---~.------_.-.._.-.~..~...,,-. "_,.",,"",'.-,,,""'--~""'~-~- '\ ¡ ( MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKA/Kenai PeninsulalKU 24-5 AD 4-Dec-01 Clean out to landing collar. Changeover to 6% KCL. Logging, 5-Dec-01 Finish logging, Reverse KCL from 4450' with nitrogen, Pick up perforating guns and RIH. 6-Dec-01 Run perforating guns. Correlate and hang on depth, Lay down D.P, Nipple down stack, 7-Dec-01 Nipple down stack. Nipple up tree and test. Release rig at 1800 hrs. Demob rig. 8-Dec-01 Move rig to Susan Dionne #1 9-Dec-01 Move rig to Susan Dionne #1 " ,",,-",. " MARATHON OIL COMPANY I( DAILY WELL OPERATIONS REPORT ( PAGE 1 OF 1 DATE: 12/22/2001 FIELD: Kenai Gas Field FILL DEPTH/DATE: 4717' Top LC LINER: WORK DONE: EOB Perforated Sterling B-1 PRESENT OPERATION: Complete OTHER: Perforations: 4380' - 4430' MD 7",26 # L-80 CASING: TREE CONDITION: CREW: WELL #: KU 24-5rd 9-5/8, 47#, N-80. New BJ Services Hrs. SUMMARY OF OPERATIONS 7:45 BJ Services nitrogen pumper on location. MIRU Nitrogen pumper. Layout and make up surface lines from wellhead to nitrogen pumper and to choke and diffuser tank. Halliburton TCP rep on location at 9 AM. Held PJSM to discuss operations and 9:00 hazards. Connected SPIDR gauge and TCP listening device to wellhead. Shut down to replace failed relief valve 10:30 on BJ Services nitrogen pumper. Pressure tested surface lines to 2800 psi with nitrogen. Pumped nitrogen at 2800 scfm until wellhead surface pressure reached 2150 psi at which time the listening device indicated firing of the perforating guns. Stopped pumping nitrogen and observed wellhead pressure drop from 2150 psi to 1550 psi in 10 13:00 minutes and then from 1550 psi to 500 psi in another 10 minutes, Began flowing back nitrogen to diffuser flowback tank. Total of 176,400 set of nitrogen pumped into 14:30 wellbore. Vendor Equipment Daily Cost Cumulative Cost Marathon Supervision $1,200.00 $1,200.00 BJ Services N2, pump, crew $10,700.00 $11,900.00 Halliburton Listening Device N/C $0.00 $0.00 Costs Forward...... $0.00 DAILY COST: $11,900.00 CUM: $0.00 REPORTED BY: Walsh (' (: MARATHON Oil Company Pad 41-7 KU24-5Rd slot #KU24-5X Kenai Gas Field Kenai Peninsula, Alaska PROPOSAL LIS TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd Version #4a Our ref: prop4790 License: Date printed: 31-0ct-2001 Date created: 10-Jul-2001 Last revised: 9-0ct-2001 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 30.878,w151 14 42.563 Slot Grid coordinates are N 2361663.250, E 275233.476 Slot local coordinates are 323.35 S 4332.39 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ( MARATHON Oil Company . PROPOSAL LISTING Page 1 Pad 41-7,KU24-5Rd Your ref : KU24-5Rd Version #4a Kenai Gas Field,Kenai Peninsula, A1.aska Last revised: 9-0ct-2001 Measured Inclin. Azimuth True Vert R E C TAN GULAR Dogleg Vert Depth Degrees Degrees Depth COO R D I N ATE S Deg/100ft Sect 3493.00 38.00 54.93 3047.27 896.90 N 1207.25 E 0.00 1503.42 KOP 3500.00 38.30 54.45 3052.77 899.40 N 1210.77 E 6.00 1507.74 3513.00 38.86 53.58 3062.94 904.16 N 1217.33 E 6.00 1515.84 3600.00 36.32 52.54 3131.87 936,04 N 1259.75 E 3.00 1568.89 3700.00 33.42 51.19 3213.91 971.32 N 1304.73 E 3.00 1626.05 3800.00 30.54 49.60 3298.73 1005.05 N 1345.55 E 3.00 1678.99 3900.00 27.67 47.73 3386.09 1037.14 N 1382.08 E 3.00 1727.54 4000.00 24.84 45.46 3475.77 1067.51 N 1414.25 E 3.00 1771.59 4100.00 22.06 42.65 3567.50 1096.06 N 1441.95 E 3.00 1811.01 4200,00 19.33 39.08 3661. 04 1122.72 N 1465.11 E 3.00 1845.69 4300.00 16.69 34.42 3756.14 1147.42 N 14 83.66 E 3.00 1875.54 4363.28 15.09 30.67 3817.00 1162.00 N 14 93 . 00 E 3.00 1891.89 Sterling Target - EOC 4500.00 15.09 30.67 3949.01 1192.62 N 1511.16 E 0.00 1925.07 4597,35 15.09 30.67 4043.00 1214.42 N 1524.09 E 0.00 1948.71 4811.75 15.09 30.67 4250.00 1262.43 N 1552.56 E 0.00 2000.75 TD All data is in feet unless otherwise stated. Coordinates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 2001.05 on azimuth 50.88 degrees from wellhead. Total Dogleg for wellpath is 26.73 degrees. Vertical section is from wellhead on azimuth 51.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ (' MARATHON Oil Company Pad 41-7,KU24-5Rd Kenai Gas Field,Kenai Peninsula, Alaska MD TVD Rectangular Coords. ( PROPOSAL LISTING Page 2 Your ref: KU24-5Rd Version #4a Last revised: 9-0ct-2001 Comments in wellpath ----------- ------------ ----------------------------------------------------------------------------------------------------------- Comment 3493.00 4363.28 4811.75 Target name 3047.27 3817.00 4250.00 896.90 N 1162.00 N 1262.43 N 1207.25 E 1493.00 E 1552.56 E KOP Sterling Target - EOC TD Targets associated with this wellpath ----------------------------- ----------------------------- T.V.D. Rectangular Coordinates Revised Sterling Tgt KU 24-5 Geographic Location ----------------------------------------------------------------------------------------------------------- 3817.00 1463.00E 10-Jul-2001 0 1071. CON ~ , .ÇOttlPåri.)': F1eld: . ..' Sitë:' .. Well: WëUp~th: Field: ~ ( Planning Report Marathon Oil Company Kenai Gas Field . Pad 41-7 KU 24-5 81 Sidetrack #1 Kenai Gas Field Kenai, Alaska USA Map System:US State Plane Coordinate System 1927 Goo Datum: NAO27 (Clarke 1866) Sys Datum: Mean Sea Level ( Date: 10/31/2001 TiIrie:>t3:28:08. . Co-ordinah.-(NE) Reference:Wèll: KU24~5,True North Vertical (TV]) Reference:SITE81.0.... .... . . Section (VS).Rcfercnce: Well(0~ObN.o;00E,51,87Azi) PIa)):. Plan #3 (INTEQ-DèeperTD) Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre Wmm_95 Site: Pad 41-7 Section 7 Centered on KU 13.5 Site Position: From: Map Position Uncertainty: Ground Level: 0.0 ft 66.0 ft Northing: Easting: 2361844,31 ft 275073.22 ft Latitude: 60 27 32.631 N Longitude: 151 14 45.826 W North Reference: True Grid Convergence: -1.08 deg Well: KU 24-5 Well Position: +N/-S +EI-W Position Uncertainty: -178,0 ft Northing: 163.7 ft Easting: 0.0 ft 2361663.25 ft 275233.48 ft Slot Name: Latitude: Longitude: 60 27 30.878 N 151 14 42.562 W Wellpath: S1 Sidetrack #1 Proposed sidetrack to recomplete in the Sterling Current Datum: SITE Height 87.0 ft Magnetic Data: 7/19/2001 Field Strength: 55185 nT Vertical Section: Depth From (TVD) ft 0,0 Plan: Principal: Plan #3 (INTEQ-Deeper TD) Get TO to TVO of 4,250' Yes +N/-S ft 0.0 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/- W ft 0.0 Date Composed: Version: Tied-to: OH Original hole 3493.0 ft Mean Sea Level 21.25 deg 73.45 deg Direction deg 51.87 9/17/2001 1 User Defined Plan Section Information ,:'.i;..>,:..l\:>..... .. 3493,0 3500,0 3513.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300.0 4363.3 4500.0 4597.4 4811.7 . . Ioef . . ..... Azim . rVD _?_~~_._.,._'..' d:~ ... . -:...' ,'ft .. 38,00 54,93 3047.3 38.30 54.45 3052.8 38.86 53.58 3062.9 36.32 52.54 3131.9 33.42 51.19 3213.9 30.54 49.60 3298.7 27.67 47.73 3386,1 24.84 45.46 3475,8 22,06 42.65 3567.5 19.33 39.08 3661,0 16.69 34.42 3756.1 15.09 30.67 3817.0 15.09 30.67 3949,0 15.09 30.67 4043.0 15.09 30.67 4250.0 +N/-S .;. : . ft ,. 896.9 899.4 904.2 936.0 971.3 1005.1 1037.1 1067.5 1096.1 1122.7 1147.4 1162.0 1192,6 1214.4 1262.4 +EI~ W . ft,. 1207.2 1210.8 1217,3 1259.8 1304.7 1345.6 1382.1 1414.3 1442.0 1465.1 1483.7 1493,0 1511.2 1524.1 1552.6 ------,. .DLS... Build:, Turn deg/100ft .deg/1 OOft deg/1 OOft 0.00 0.00 0,00 6.03 4.29 -6,86 6.00 4.31 -6.69 3.01 -2.92 -1.20 3.00 -2.90 -1.35 3.00 -2.88 -1.59 3.01 -2.87 -1.87 3.00 -2.83 -2.27 3,00 -2.78 -2.81 3.01 -2.73 -3.57 3.01 -2.64 -4.66 3.00 -2.53 -5.92 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO' .deg. 0,00 315.15 315.57 193.61 194,35 195.63 196.77 198.52 200.63 203.14 206.42 210.89 0.00 0,00 0.00 ..' ..: :/ Target - Survey .. 'MD fuel. .. ....Azhn TVO.. . +N/;'S +E/-W. .VS . DLS .. .Build. Turn. Tool/Comment. . .:! u ft de~f :; . Çieg. 'ft : .ft ft ft deg/100ft.deg/100ft deg/100ft . . . ... .: ..J . . - .. .--.----...--------..---'--------------.---.---- 3493.0 38.00 54.93 3047.3 896.9 1207.2 1503.4 0.00 0.00 0.00 MWD/GYRO 3500,0 38.30 54.45 3052,8 899.4 1210.8 1507.8 6.03 4.29 -6.86 MWD/GYRO 3513.0 38.86 53.58 3062.9 904.2 1217.3 1515.8 6.00 4.31 -6.69 MWD/GYRO 3600.0 36.32 52.54 3131.9 936.0 1259.8 1568.9 3.01 -2.92 -1.20 MWO/GYRO 3700.0 33.42 51.19 3213.9 971.3 1304.7 1626.0 3.00 -2.90 -1.35 MWD/GYRO 3800.0 30.54 49.60 3298.7 1005.1 1345.6 1679.1 3.00 -2.88 -1.59 MWD/GYRO 3900.0 27.67 47.73 3386.1 1037.1 1382.1 1727.5 3.01 -2.87 -1.87 MWO/GYRO 4000,0 24.84 45.46 3475.8 1067.5 1414.3 1771.6 3.00 -2.83 -2.27 MWD/GYRO .,. " ,. ", ( ( Planning Report COIç-pany: : Fjel~d: ,', K." ... Gi::': I :,: I~j " Síte~ ".' , Paq41a , 'Well{', ,KLJ, 24§ , .'" Wellpåth:" . Sl SidÊÜrack #:1 Survey Azim TVD deg ft 4100.0 42.65 3567.5 4200.0 39.08 3661.0 4300.0 16.69 34.42 3756.1 4363.3 15.09 30.67 3817.0 4400.0 15.09 30.67 3852.4 4458.6 15.09 30.67 3909.0 4500.0 15.09 30.67 3949.0 4515.5 15.09 30.67 3964.0 4593.2 15.09 30.67 4039.0 4597.4 15.09 30.67 4043.0 4600.0 15.09 30,67 4045.5 4700,0 15.09 30.67 4142.1 4800.0 15.09 30.67 4238.6 4811.7 15.09 30,67 4250,0 Targets ", . , Date:10/31/20Ö1 Time:13:28:08", ",','" , Co~ordinate(~"E)Reference:' Well:' KU. 24-5, TfÙøNorth Vcrtical (TVD) Reference: SITE 87.0 , , Section (VS) Reference: Well (0.00N,0.00E,51.87Azi) Plan: Plan #3 (INTEQ-Deeper TD) TVD 'ff ' 3817.0 . ' +N/-S +FJ- W VS DLS Build Turn TooVComment ft tt tt deg/100ft deg/100ft deg/1 OOft _u_---- 1 096.1 1442.0 1811.1 3.00 -2.78 -2.81 MWD/GYRO 1122.7 1465.1 1845.7 3.01 -2.73 -3.57 MWD/GYRO 1147.4 1483.7 1875.6 3.01 -2.64 -4.66 MWD/GYRO 1162.0 1493.0 1891.9 3.00 -2.53 -5.92 Top Sterling 81 Sand 1170.2 1497.9 1900.8 0.00 0.00 0.00 MWD/GYRO 1183.3 1505.7 1915.0 0.00 0.00 0.00 Sterling 82 1192.6 1511.2 1925.1 0.00 0.00 0.00 MWD/GYRO 1196.1 1513.3 1928,9 0.00 0.00 0.00 Sterling 83 1213.5 1523.6 1947.7 0.00 0.00 0.00 Sterling 84 1214.4 1524.1 1948.7 0.00 0,00 0.00 MWD/GYRO 1215.0 1524.4 1949.3 0.00 0.00 0.00 MWD/GYRO 1237.4 1537.7 1973.6 0.00 0.00 0.00 MWD/GYRO 1259.8 1551.0 1997.9 0.00 0.00 0.00 MWD/GYRO 1262.4 1552.6 2000.8 0.00 0.00 0,00 MWD/GYRO ':<--- Longitude ---> I Map ,M~\p , <---- Latitude ----> +N/-S ',' , +~:¡~ W "Northing,', Eastin~ Deg Min' Sec:' Deg Mill See,,"..: ft: ' ft ft ft 1100,3 1445.0 2362736,02 276698.99 60 27 41.713 N 151 14 13.745 W 1162.0 1493.0 2362796.81 276748.18 60 27 42.321 N 151 14 12.787 W :, : Name '" ' Description' " ' , Top Sterling 81 Sand -Circle (Radius: 250) -Plan out by 78,20 at Formations 3817.0 , u"'9~lations ': ' ': Li(~ol~gy " ,<I >, ; l\1P , ,::'>ft ' ' 4458.6 4515.5 4593.2 , , , "':, TVD, ft :' ,,:' , 3909.0 3964.0 4039.0 Sterling 82 Sterling 83 Sterling 84 SANDSTONE SANDSTONE SANDSTONE , .pip Angle, Dip Direction " ',deg" ':,:deg , 0,00 0.00 0.00 0.00 0.00 0.00 ( (' Alaska Region Domestic Production Marathon Oil Company P,Q, Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 2, 2001 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 RECE~\lE[) Reference: Field: Kenai Gas Field Well: KU 24-5 RD Permit No.: 201-144 Regarding: Changes to drilling plan NOV 0 ~) 2001 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find the permit application, drilling plan, directional survey, and cementing program. These were modified for the reasons list below. None are a major change. Directional QrQ9ram: It was found that the original submitted program did not allow enough rathole for logging and completion. The new program is 200' TVD deeper than the previous program. A detailed copy of the drilling program is attached. CementinQ...Qægram: Because of the low pore pressure in the zones in this well, the cementing program was changed to using 13.5 ppg. cement instead of 15.7 ppg. cement. This change reflects the same cementing program we used successfully on the KU 21-6 RD well. A detailed copy of the cementing program is attached. Drillinqplan and Permit Al2Plication: Was changed to reflect the two changes detailed above, If you require further information, I can be reached at 907-564-6332 or bye-mail at Ifshannon @ marathonoil.com. Sincerely, ~af. Leonard F. Shannon Senior Drilling Engineer (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMIVIISSION PERMIT TO DRILL 210 AAC 25.005 g:\cmn\drlg\sterling\su44-10\AOGCCPTD,XLW 1a. Type of Work DrillD Re-EntryŒ] 2. Name of Operator MARATHON OIL COMPANY 3. Address Po O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 332'FNL, 4331'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 830'FSL, 544'FWL, Sec. 5, T4N, R11W, S.M. At Total Depth 930'FSL, 604'FWL, Sec. 5, T4N, R11W, S.M. Re-D rill [8J DeepenD 1b. Type of well. Explorat°rO Stratigraphic TesD serviceD Development GaŒ Single Zone[8] 5. Datum Elevation (DF or KB) 10. Field and Pool I DF - MSL 87' (original 94') Kenai Gas Field/Sterling 6. Property Designation A-028142 Development OiD Multiple Zona 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) 12. Distance to Nearest Property Line(unit boundary 2800 feet 16. To be Completed for Deviated Well: Kickoff Depth 3500 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well 9. Approximate Spud Date 08/10/2001 14. Number of Acres in Property 1600' feet 6000 4812' MD/4250' TVD feet 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2» 38 0 Maximum Surface 1564 pslg at Tolal Depth (TVD) 4250' Hole Casing Weight Driven 20" 94 17-1/2" 13-3/8" 61 12-1/4" 9-5/8" 47 8-1/2" 7" 26 Specifications Grade Coupling H-40 PE K-55 BTC N-80 BTC L-80 BTC Setting Depth Top Bottom Quantity of Cement Length MD TVD MD TVD (including stage data) 136 0' 0' 136' 136' In Place, Driven 2012 0' 0' 2012 1861 In Place w/1500 sacks 3500 0' 0' 3500 3054 In Place, w/1800 sacks 2400' 3250 2858 4812 4250 135 sx Note: all depths are referenced to original KB elevation due to historical data on drawings, etc. Except that the attached directional plan which has compensated for the 87' elevation for the new sidetrack. Kenai Unit well KU 24-5 will be plugged back to 3500' MD and sidetracked. KU 24-5rd will be directionally drilled to an estimated total depth of 4812' MD, 4250' TVD from the existing Kenai Gas Field pad 41-7,The production interval will be cased with T', cemented in place as a production liner, 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 Fee[8] Property Pla(8] BOP SketchŒ] Drilling Fluid prograrrG Time vs Depth PloD Refraction Analys¡[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Phone: 564-6332 I Title Senior Drilling Engineer Commission Use Only Approval Date Diverter SketcO Seabed ReporD Drilling program[8J 20 AAC 25.050 RequirementD Signed L. F.Shannon cq:~1 Date: 11/1/2001 API Number 50-- Conditions of Approval Samples Required DYes Hydrogen Sulfide Measures DYes DNo Required Working Pressure for BOPE D2M Other: Permit Number See Cover Letter For Other Requirements D No Mud Log Required DYes D No ¡l:,;¿~. ."" ~ ". Directional Survey Required DYes DNo D3M D5M D1OM D15M NOV 0 5 2001 Approved by Form 10-401 Rev. 12-1-85 Commissioner by order of the Commission }-\!aska Oil & Gas Cons, Commiss I'iJ Anchorage Date Submit in Triplicate ( Marathon Oil Company Alaska Region ( Prepared By: Approved By: Date: L. F. Shannon 11-2-2001 Updated Drilling Program Well: KU 24-5rd AFE: To be determined Area: Kenai Gas Field Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No.1 Geologic Program Depth Target Locations FNL FWL Block MD TVD Tolerance Surface 332' 4331' Sec. 7, T4N, R11W, S,M, 87' 87' Sterling B1 1162' 1493' Coordinates from 4363' 3817' 250' North East Wellhead Bottom Hole 1262' 1553' Coordinates from 4812' 4250' North East Wellhead RKB Elevation: 87' Total Depth: TVD 4250' MD 4812' Avg. Angle 38.86 Course 51.87 Note: See attached directional program for more detail. Abnormal Pressures: Subnormal Pressures: 250 psi to 1000 psi in Sterling Sands Coring and DST's: Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection. 10' samples to TD Logging Program: Contractor To be determined LWD Wireline Logs Surface NA production NA GR/AIT/DSI/NGT KU 24-5rd Drilling Program Page 1 of 7 ",' ( t Drilling Program Summary Production: The existing wellbore will have been plugged back to <= 4500' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at 13500' MD. Test plug and casing to 2500 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (12.5 PPG anticipated). Drill a 8 1/2" hole to 4812' MDI 4250' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 7" production liner and cement per the attached program. Proceed with completion program, Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (psi) (ps i) (K lbs) (MD) 9 5/8" 0' 3500' 47.0 N-80 BTC 12 1/4" 6870 4750 1086 7" 3250' 4812' 26.0 L-80 BTC 8 1/2" 7240 5410 604 Note: The 9-5/8" casing is already installed, window being cut in same. Casing Design Fracture Formation casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8" 47 N-80 3054' 12,5 9,0 1043 2.6 3,3 3 .5 7" 26 L-80 4250' 9.0 1490 2.8 2,7 3 .8 KU 24-5rd Drilling Program Page 2 of 7 (" (- Directional Program Directional Co: Baker Hughes Inteq Gyro Co: To be determined KOP: 3500 Direction: 51. 87 Dog Leg: 3,0 To: 15 deg @ 3817' TVD Hold Depth: 4812 MD/ 4250 TVD Hold Angle: 15.1 Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below drive pipe See attached directional program Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 9 5/8" Inte~ediate Casing @ 3054' TVD MASP = ((PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd» MASP = (9.0 * 0.052 * 4250) - (0,3 * 0,052 * 9,0 * 4250) - (0,7 * 0.1 * 4250» MASP = 1095 psi 7" Production Liner @ 4250' TVD* MASP = PP * 0.052 * TVDf - (GG * TVDf) MASP = 9,0 * 0.052 * 4250' - (0.1 * 4250') MASP = 1564 psi *This will also be the new MASP for the 9-5/8" casing as production. Cementing Program Contractor: BJ Services Production Casing Size: 7 " Setting Depth: 4812' MD/ 4250' TVD Annular Volume to 3500' with 8 1/2" gauge hole: 165 ft3 Tail Slurry: Top of Cement: Specifications: Density: 13.5 ppg, Yield: 3250'MD/ 2857' TVD Class G + additives Mixed w/ fresh water 1,838 ft3/sx, Sx: 135 sx, cf: 248 ft3 Compress Strgth: 500 psi in 16.24 hrs, 820 psi in 24 hrs Total Volume: 248 ft3, ~% Open Hole Excess, WOC Time: 6 hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions. KU 24-5rd Drilling Program Page 3 of 7 ( (' Diverter and BOP Program The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi, It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (ps i) (psi) Size & Rating (psi) 1043 1500 (1) 13-5/8" 5M Annular 250/3000 Intermediate 9 5/8" ( 1) 13-5/8" 5M Blind ram (9.2 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 2500 (1) 13-5/8" 5M Annular 250/3000 production 7" 1490 (1) 5M Blind ram (10.0 13-5/8" 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8,3 PPG back-up unless otherwise noted. 9 5/8" Inte~diate Casing at CTPMASP = 1043 psi CTPBurst = 6870 * 0.7 - Test to 1500 psi 3054' TVD ( (9,O-8.3) * 0.052 * 3054) = 4697 psi 7" Production Liner (and 9-5/8" Casing) at 4250' TVD CTPMASP = 1490 psi Test to 2500 psi CTPBurst = 7240 * 0.7 - ((9,O-8.3) * 0.052 * 4250) = 4913 psi KU 24-5rd Drilling Program Page 4 of 7 ( i( Mud Program Contractor: MI Drilling Fluids Interval (TVD) Mud Weight From To (ppg) Water Loss Mud Type 3054' 4250' 8.7 - 9,0 <8 Flo Pro/KCl Wellhead Program Manufacturer Vetco Model Annular Flow Tubing Head 11" 3M Xli" 3M w/ 2-1/16" 5M flanged outlet & 7-1/16" 3M flngd outlet Tubing Hanger 11" x 3-1/2 Mandrel Tubing hanger Detailed Drilling Procedure Fo~tion Leakoff Test Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out, 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke, 3, Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals, A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation, Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes, Bi t Program The following guidelines are recommended for use on this well, Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 3500' - 4812' 8 1/2" XR15TDGPS 447X 15/35 200 KU 24-5rd Drilling Program Page 5 of 7 (' , (" Drill String Item Ppf Makeup Torque Max Pull - Premium 3 112" HWDP, 3 %" IF 24.4 12000-13200 248,400 Ibs. ft.-lbs. 4", 8-135, HT 38 15,53 13,500-19,800 403,500 Ibs. ft.-lbs. 5" HWDP, 4%" IF 49.3/53.6 29,000 543,000 Ibs. ft.-lbs. Hydraulics Program Rig mud pumps available are shown below, Install 5 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (sprn) Oilwell A 600 PT 4 %" 8" 3207 1. 6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 Oilwell A 600 PT 5 %" 8" 2147 2,3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (ps i) ( fpm) ( ppg) (32"s) Remarks 4812' 8 1/2" 390 2200 - 175 9,5 14,14,14 Motor Drilling 2400 Note: 5" liners are recommended. KU 24-5rd Drilling Program Page 6 of 7 , ' ( { OPERATIONAL PROCEDURE 1. MIRU the drilling rig. Install 13 5/8" 5M X 11" 3M DSA. program. Record test on IADC book. Set wear bushing. NU 13-5/8", 5M BOP system. Tes t as per 5. Abandon existing perforations according to program filed with AOGCC. RIH and set CIBP at +1- 3500' md. Test plug and casing to 1500 psi. MU and RIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside casing exit. Cut window and ensure that all mills are worked thru window, CBU and test shoe to leakoff (- 12.5 ppg anticipated). Drill a 8-1/2" hole to 4812' MDI 4250' TVD per the attached directional program. Backrearn each stand. Lost circulation is possible throughout this interval. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. 2, 3. 4. 6. At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH, laying down 5" HWDP. Run 10£ as per geology requirements. Pull wear bushing. Locate casing swage and safety valve. Function safety valve and place on rig floor. Record function test in IADC book. RU and run 7" casing liner. Cement casing as per the attached cementing program. Ensure circulation of cement to above top c liner. 7, 8. 9. 10. Pullout of liner hanger and circulate cement clean, Pullout of hole with setting tool. Clean out liner, Test casing, liner and liner lap to 2500 psi. 11. Prepare for completion. A separate completion procedure will be developed. KU 24-5rd Drilling Program Page 7 of 7 ..~ , ~ (' Wj October 31,2001 Will Tank Marathon Oil Co P, 0, Box 196168 Anchorage, Alaska 99519 Subject: Cement Proposal The following is BJ Services' 711 Liner Cementing Operation proposal for the KU 24-5RD in the Kenai Gas - Pad 41-7 Field in Kenai County, Alaska, This proposal includes fluid specifications and price estimate, The following Cementing Services Proposal for the KU 24-5RD is based on the well / directional data as provided by Marathon Alaska's Drilling Engineering team, As per our previous discussion, the proposed 13.5 ppg cementing system for the subject well is consistent with that successfully applied on the KU 21- 6RD, This, light, low density slurry exhibits exceptional set and fluid loss properties and should yield good zone isolation across section. BJ Services Pacific Region Technology Center will conduct pilot blend testing of the cement system prior to on-site operations with resulting data to be forwarded upon completion. Thank you for giving BJ Services the opportunity to submit this proposal. If you have any questions or require additional information, please contact me, Sincerely, J, Jay Garner Manager, City Sales (907) 349-6518, Anchorage (Bus Phone) BJ Services Company cc: Leonard Shannon Gr41 03 " ( ~, Wj Proposal No: 100168342A Marathon Oil CO KU 24-5RD Glacier Rig No.1 Rig Kenai Gas - Pad 41-7 Field Kenai County, Alaska October 31, 2001 Cement Recommendation Prepared for: Will Tank Senior Drilling Engineer Marathon Oil Co, Prepared by: J, Jay Garner Manager, City Sales Kenai, Alaska Bus Phone: (907) 349-6518, Anchorage Email: jgarner@ bjservices,com p,:" 1:"'0; , :E R 'V I S I ;0 N$M Service Point: Kenai Bus Phone: (907) 776-8182 (907) 659-2329 Service Representatives: J, Jay Garner Manager, City Sales Kenai, Alaska Bus Phone: (907) 349-6518, Anchorage Email: jgarner@bjservices.com Gr41 05 , Operator Name: Well Name: Job Description: Date: Marathon Oil cJ' KU 24-5RD T' Liner Cementing Operation October 31 2001 ( f£j Proposal No: 100168342A JOB AT A GLANCE Depth (TVD) Depth (MD) 4,250 ft 4,812 ft Hole Size 8,5 in Liner SizelWeight : 7 in, 26 Ibs/ft Pump Via Drill Pipe 3 1/2" O,D, (2,602" ,I.D) 15,5 Drill Pipe 7" 0,0. (6,276" .1.0) 26 Total Mix Water Required 1 ,41 0 gals Weighted Spacer Spacer MCS-4D Density 30 bbls 10.5 ppg Cement Slurry Class G Cement Density Yield 152 sacks 13,5 ppg 1 .84 cf/sack Displacement Drilling Mud Density 78 bbls 9,5 ppg Report Printed on: October 31,2001 6:24 PM Page 1 Gr4109 . Operator Name: Marathon Oil Co( Well Name: KU 24-5RD Job Description: 711 Liner Cementing Operation Date: October 31, 2001 ( Wj Proposal No: 100168342A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. .. 00) 8.681 CASING 8,500 HOLE DEPTH ft . MEASURED TRUE VERTICAL 3,493 3,047 4,812 4,250 SUSPENDED PIPES DIAMETER (in) I WEIGHT I DEPTrmi. . . O.D. I I.D. (Ibs/ft) MEASURED TRUE VERTICAL. 7.000 I 6,276 I 26 I 4,812 I 4,250 Drill Pipe 3.5 (in) OD, 2.602 (in) ID, 15.5 (Ibs/ft) set @ Drill Pipe 7.0 (in) OD, 6.276 (in) ID, 26 (Ibs/ft) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 3,250 ft 4,732 ft 3,250 ft 4,732 ft 9.50 ppg Water Based 99 0 F 90 0 F VOLUME CALCULATIONS 243 ft x 0.1438 cf/ft with 0 % excess = 1,319 ft x 0.1268 cf/ft with 35 % excess = 80 ft x 0,2148 cf/ft with 0 % excess = TOTAL SLURRY VOLUME = 35 cf 226 cf 17 cf (inside pipe) 278 cf 50 bbls = SterlinQ B-1 Sand /2,8 darcies with anticipated reservoir pressure of 250-270 psi. Report Printed on: October 31,2001 6:24 PM Page 2 Gr4117 ".. 9peratQr Name: Marathon Oil Co( Well Name: KU 24-5RD Job Description: 7" Liner Cementing Operation Date: October 31 , 2001 ( ~ Proposal No: 100168342A FLUID SPECIFICATIONS Weighted Spacer FLUID VOLUME CU-FT VOLUME FACTOR Cement Slurry 278 I Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 90 0 F @ 90 0 angle Free Water (mls) @ 90 0 F @ 45 0 angle Fluid Loss (cc/30min) at 1000 psi and 900 F COMPRESSIVE STRENGTH 12 hrs @ 1000 F (psi) 24 hrs @ 1000 F (psi) 48 hrs @ 1000 F (psi) 72 hrs @ 1000 F (psi) RHEOLOGIES BJJJ.P Cement Slurry ~ --2IDL.. @ 80 0 F 216 30.0 bbls Spacer MCS-4D + 6 Ibs/bbl MCS-D + 8,99 Ibs/bbl Potassium Chloride + 30,15 Ibs/bbl Bentonite + 90 Ibs/bbl Barite, Bulk @ 10,5 ppg A 1,84 = 152 sacks Class G Cement + 10% bwoc BA-90 + 2% bwow Calcium Chloride + 2.5% bwoc BA- 56 + 0.1 % bwoc ASA-301 + 1 gals/100 sack FP- 6L + 0,15% bwoc Sodium Metasilicate + 82.3% Fresh Water 78,1 bbls Drilling Mud @ 9,5 ppg SLURRY NO.1 13,50 1.84 9.27 9.28 7:30 0.0 0.0 10.0 300 820 1410 1925 300 134 3 12 100 58 6 13 200 98 Slight additive adjustments should be expected to achieve the desired slurry properties, based on pilot test results. Report Pri nted on: October 31, 2001 6:25 PM Page 3 Gr4129 \ . , ~ (' Operatòr Name: Marathon Oil Co' Well Name: KU 24-5RD Date: October 31 2001 ,( ~.. f£j Proposal No: 100168342A PRODUCT DESCRIPTIONS ASA-301 Additive used to reduce or eliminate free water and settlinq in cement slurries, BA-56 A gas migration additive that controls fluid loss, limits free water and provides excellent solids support, It is functional at low to moderate temperatures ranges, BA-9O An non-compacted silica fume that produces high compressive strength, low density cement slurries which prevent annular gas migration by reducing slurry permeability. It can be used in the low to high temperature ranges, Barite, Bulk A naturally occuring mineral (Barium Sulfate), It is widely used as a weighting material in cement spacers and occasionally in cement slurries, It can yield a slurry density in excess of 19 Ibs/gal. Bentonite Commonly called oel. it is a clay material used as a cement extender and to control excessive free water. Calcium Chloride A powdered, flaked or pelletized material used to decrease thickening time and increase the rate of strength development. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures, FP-6L A clear liquid that decreases foamino in slurries durino mixino, M CS-4 A turbulent flow spacer system that prevents water and oil-base mud and cement contamination and water-wets the casing to increase bonding, Potassium Chloride A oranular salt used to reduce clay swellino caused bv water-base stimulation fluids, Sodium Metasilicate An extender used to produce an economical. low density cement slurry, Report Printed on: October 31,20016:25 PM Page 6 Gr4163 (' (' ~ Nt. ') Marathon !URA11tel Oil Company 3201 "C" Street, Suite 800 Anchorage, AK 99503-3934 Telephone 907/561-5311 Mr. Tom Maunder AOGCC 333 West ill Avenue Suite 100 i\nchorage,AJ< 99501 )C) \-\~\-\ October 8, 2001 ~<Þc " O¿';- ~¿.,.i-. ij'Qlcf ./ 1 ~() ~ð' '¿/> Af¡)~ q,~ (/O/ t)~ a'.c -;Ys ~ ~<rd) , ~-? RE: KU 24-5 and KU 24-5rd, Kenai Gas Field Dear Mr. Maunder: Attached please find a copy of the procedure for the work to prepare the KU 24-5 wellbore for a sidetrack designated the KU 24-5rd. Also included in the procedure is an outline of the completion work planned for the sidetrack. The perforations in the KU 24-5 will be isolated and a plug will be set as a base for the whipstock. After the well is sidetracked and drilled to TD, a liner will be hung and cemented, The B-1 sand will be perforated in the new wellbore, Should the well require a velocity string to prevent liquid loading, a coil tubing production string is planned. This procedure is being submitted to the AOGCC to satisfy a condition of approval stipulated in the sundry request to perform the KU 24-5rd sidetrack. The depths and pressures in the sidetrack portion of this completion are estimated according to reservoir and drilling interpretation, Actual parameters will be adjusted to reflect the depths and pressures encountered in the new wellbore, Please contact me at 564-6305 if you have any questions. Sincerely, J~~. vJ~ Ken D, Walsh Advanced Production Engineer Marathon Oil Company (t4') ( ( Marathon Oil Company Alaska Region KU 24-5rd Kenai Gas Field, Pad 41-7 Partial Wellbore Abandonment and Sidetrack Procedure History: KU 24-5 is a shut-in Sterling completion that was worked over in May 2001, in an attempt to improve deliverability by reworking it as an annular producer. The attempts to clean out the well below the B-1 perforations from 4498'- 4553' were unsuccessful. The well could not be unloaded to production after the workover, which encompassed the killing with LCM pills, milling and fishing operations that were eventually suspended. Attempts to pump into the perforations or otherwise establish communication into the B-1 perforations have been unsuccessful. Objective: To return the B-1 to production, the well will be sidetracked to a bottomhole location practically twinning the existing wellbore, Prior to sidetracking operations, the B-1 perforations will be isolated from the portion of the wellbore (9-5/8" casing) that will be retained for the sidetrack. The lower perforations, below the B-1, were previously isolated during the aforementioned workover operations, The following procedure will result in isolation of the remaining perforation section from the rest of the wellbore in preparation for the setting of a whipstock (see proposed abandonment schematic), Based on previous work to establish/determine the hydraulic connectivity between the 9-5/8" wellbore and the B-1 perforations, and verbal discussions with AOGCC and BLM, it is anticipated that the cement squeeze outlined in Step #5 may not be performed. Procedure: Partial abandonment of existinf! wellbore 1. Monitor casing and tubing for gas head; 9-5/8" annulus and 3-1/2" tubing pressure should be 0 psig. Haul 10 joints of 3-1/2", 9.3 ppfEUE 8rd tubing to location (yellow band is acceptable), Haul flowback tank, chicksan, and flowback iron to location. RU flowback equipment to casing valve outlet. Line up to circulate fresh water down tubing and out casing flowline valve to kill well, Shut in annulus and verify injection rate into perforations. If the perforations will not take fluid, pressure up to 250 psi maximum with fresh water and monitoring pressure bleed off. 2. Install BPV. MIRU Glacier Drilling Rig No.1. Nipple down tree, Nipple up adapter spool and BOP's. BOP to have Variable Bore Rams (2-7/8" x 5") in top pipe rams and 4" rams in bottom rams, RU ABB Vet co to replace BPV in tubing head with a 2-way check valve for BOP test. Test BOPE to 250 psi! 3000 psi (tubing head is rated to 3000 psi WP). Pull 2-way check. RD ABB Vetco, KU 24-5rd Partial Wellbore Abandonment and Sidetrack Procedure KDW - 10/9/2001 4:46 PM Page 2 (' ( ( 3. Back out lock down nuts. Make up 3-1/2", 8rd landing joint into tubing hanger and pull out of hole with 143 joints of 3-1/2" tubing. Stand back 3-1/2" tubing in derrick. Leave the 3- 1/2" Model "X" profile nipple between joints # 1 and #2 in the string. LD tubing hanger and 4' 3-1/2" tubing pup. LD all 2-3/8" equipment below bottom joint of 3-1/2" tubing. 4. Make scraper run in 9-5/8",47 ppfcasing on 3-1/2" tubing to 4450':MD. 5. Make up cement retainer and Rlli on 3-1/2" tubing to +/- 4400':MD. Set retainer at 4400' MD and attempt to establish injection rate. If injection rate is achieved, proceed to cement squeeze in Step #6. Otherwise, proceed to Step #7. 6, MIRU BJ Services cementer. Establish rate into perforations. Mix and pump 75 sacks Class "G" cement with additives below retainer. Attempt to place at least 60 sacks of Class G cement with additives below the retainer. Pull out of retainer and spot 15 sacks of cement on top of cement retainer. PUR two joints and reverse circulate two tubing volumes with fresh water. POOH and LD cement retainer stinger. 7, Test cement and retainer to 1500 psi. Make scraper run in 9-5/8" casing on 3-1/2" tubing to about 3600':MD. POOH laying down tubing. 8. MIRU Schlumberger wireline. PU and RIH with Halliburton CIBP for 9-5/8",47 ppf casing on wireline. Set cmp for whipstock base at about 3515' md (may vary with whipstock length, 9-5/8" casing collar location, and desired KOP). Test cmp and casing to 2500 psi, RD Schlumberger wireline, Contact Brent Senette (MOC-Kenai) prior to performing the wellhead work in the next step so that either Brent or his representative can observe and approve the placement of the tubing head and spacer spool. 9. RU ABB Vetco to place a 13-5/8", 3K spacer spool (24" length) between the existing II" 5K tubing head and the 13-5/8", 3K spacer spool (19,88" length), Test flange voids to 3000 psi. Sidetrack Proceed to drilling plan-of-operations to set whipstock, cut window, and drill to 4250' TVD. A 7", 26 ppf, L-80 liner with a liner hanger and packer will be run and cemented from TD to approximately 3250' MD, Completion 1. PU and RIH with a 6-1/8" flat bottom mill, cross-over sub, 7", 26 ppf casing scraper, bit sub, and eight (8) 6-1/4" drill collars on 4", 16.1 ppf, S-135 w/HT-38 connection drill pipe to TD at top of float collar. 2. Roll hole by mixing and pumping 30 Bbls. Safe-Kleen (surfactant) sweep followed by 260 bbls, of 6% KCL water while reciprocating drill string. Pressure test 7" liner and liner lap to 3,000 psi with 6% KCL water. KU 24-5rd Partial Wellbore Abandonment and Sidetrack Procedure KDW - 10/9/2001 4:46 PM ( ( Page 3 3. PUR placing flat bottom mill at 3250' MD. Close pipe rams and set slips on 4" drill pipe. Install 4" TIW valve to top of drill pipe. MIRV BJ Services nitrogen pumper. MU surface lines to TIW valve on drill pipe. Test surface lines to 3,000 psi with nitrogen. Displace drill pipe and casing with nitrogen through choke manifold to rig gas buster. Bleed nitrogen pressure from drill pipe and casing. RD BJ Services nitrogen pumper. POOH and LD drill pipe and BHA. 4. NU Christmas tree including tubing head for coil tubing. Set two-way check in tubing head and test tree to 3000 psi. RDMO Glacier Drilling Rig #1. Remove two-way check. 5. RV Schlumberger logging service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Have on location the appropriate centralizers and roller stem to allow passage of tools to TD. Hold safety and environmental awareness meeting. Pressure test lubricator to 3,000 psig using 50:50 mixture of 6% KCI water and methanol. Dump methanol mixture down well, PV and run junk basket and 3.81" gauge ring to TD. Baker Oil Tools is providing the junk basket and associated gauge ring, (Maximum tool OD will be 3.81" OD). Run cased hole logging RST from TD to 3400' MD. Correlate depth to Schlumberger open hole logs dated August 1982. PV and RIH with Halliburton CIBP for 7" , 26 ppf casing. Correlate depth with openhole logs, Set CffiP at 4426' MD. POOH and RD Schlumberger wireline. Note the amount of time it takes to pull out of the hole from 4426' to surface to set firing head delays prior to Step #7. 6. Haul forklift, air compressor, generator, and light plant to location, RV Halliburton test equipment to well. Pressure test flowback iron to 4000 psi with 50:50 methanol and 6% KCL water, B-1 Sand 4,,363'-4413' Total 50' NOTE: The SBHP of this B-1 sand is approximately 350 psia (0.092 psi/ft gradient) 7. MIRV slickline, test to 3000 psi. Prepare to perforate with 2.75" modular StimGuns loaded 6 SPF 60 degree phased with 12,5 gram Super DP charges. Pick up Modular StimGun perforating equipment as follows: a. Gun space-out rod twelve (12) feet in length. b, 2.75" OD, Modular 6 SPF, 60 degree phased, 12.5 gram, Super DP charges loaded to perforate the B-1 Sand from 4,363' -4,413' (50 feet of Sterling B-1 perforations) w/24' of propellant (18' on lower gun and 6' on the base of the upper gun), c. Pyrotechnic Delay Firing Device with 4 delays (will allow 16-19 minutes prior to firing), The number of delays may vary based upon actual time out of the hole from earlier tests, KU 24-5rd Partial Wellbore Abandonment and Sidetrack Procedure KDW - 10/9/2001 4:46 PM ( ( Page 4 8. Rlli w/slickline firing head and activate detonation sequence. Pull out of hole above swab valve and wait for guns to fire. Monitor surface pressure. Rlli and retrieve guns and gun space out rod. RD slickline service. 9. Flow test well to unload liquid. Approximately 42.0 bbls of fluid (1100' * 0.03826 bbl/ft) should be resident in wellbore trom fluid level to mid perf. The unloading rate up 7" and 9- 5/8" casing is attached but is 3.7 :rvtMCFGPD @ 110 psig FTP and 7.1 :rvtMCFGPD @ 110 psig FTP, respectively. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of on site production engineer. Contact Paul Williams at 907-564-6403 with Anchorage engineering for questions relating to the flowback. NO FLOW CONTINGENCY @!eps #10 & 11) Ifwellbore does not flow or appears to be loading up with fluid, proceed to Step #10. Ifwell flows, proceed to Step # 13. 10. RU Slickline company, Hold Safety and environmental awareness meeting, Pressure test lubricator to 3000 psi. Rlli w/tandem quartz electronic gauges using roller stem and weight bars as necessary. Make gradient stops to determine fluid level with 2 hour stop on bottom at 4,388' mid perf. COH making same gradient stops. RD slickline equipment. 11, RU BJ Services nitrogen unit and coil tubing unit with Marathon-owned 2-3/8" CT. Hook up flowback iron, Fully function and pressure test BOP and rams to 3000 psi. RIH with 2-3/8" MOC tubing with centralizer, 1,90" profile nipple sub (with pump-thru blanking plug installed), crossover, two (2) 5' weight bars, and Baker slip-type coil connector. Please refer to attached diagram for proposed velocity string BHA. Jet well dry with nitrogen to PBTD. 12. PUR and hang coil tubing tail 2' above the top B-1 perforations. Make rough cut and install coil tubing hanger to top of coil tubing string with coil connector. Make up Baker GS disconnect to coil in injector head with a coil connector, Sting into top of coil tubing hanger with Baker GS tool. Land coil tubing hanger in coil tubing head. Turn in lock down screws. Pump 6% KCL water down coil tubing pigtail to release Baker GS disconnect from tubing hanger. POOH with Baker GS disconnect. RDMO BJ Services coil tubing and nitrogen units. 13, Resume flow test of well as outlined above. Once well is cleaned up, shut well in and make final production tie-in. Put well on sales. CONTACTS Ken Walsh: Gary Eller: 907-564-6305 (w) 907-268-5660 (p) 907-564-6315 (w) 907-268-0411 (p) Bob Lanz: 907-564-6427 (w) KU 24-5rd Partial Wellbore Abandonment and Sidetrack Procedure KDW - 10/9/2001 4:46 PM Page 5 ( ( 907-696-2346 (h) Wayne Cissell: 907-283-1308 (w) 907-262-3620 (p) 907-564-6403 (w) 907- 729-0338 (h) Paul Williams: KU 24-5rd Partial Wellbore Abandonment and Sidetrack Procedure KDW - 10/9/2001 4:46 PM w/1500 sks of Class G IKOP 3500' MD I Pad 41-1 w/1800 sks of Class G 245 BHT: (TVD) KU 24-5 Completion Fluid: ". ~ ~v£~~ @~ £~£~~£ ( TONY KNOWLES, GOVERNOR OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DWISION OF GOVERNMENTAL COORDINATION 0 SOlITHCENTRAL REGIONAL OFFICE 550 W. 7TIi AVENUE, SUITE 1660 ANCHORAGE, ALASKA 99501 PH: (907) 269-7470 / FAX: (907) 269-3981 Q CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562 / FAX: (907) 465-3075 Q PIPELINE COORDINATOR'S OFFICE 411 WEST 4TIi AVENUE, SUITE 2C ANCHORAGE, ALASKA 99501-2343 PH: (907) 269-7470 / FAX: (907) 561-6134 September 11, 2001 Mr. Charles A. Underwood, Jr. Marathon Oil Company P.O. Box 196168 Au1chorage,AJe 99519-6168 Dear Mr. Underwood: SUBJECT: MARATHON KU 24-SRD STATE ID NO. AK 0108-010G FINAL CONSISTENCY DETERMINATION The Division of Governmental Coordination (DGC) is coordinating the State's review of Marathon Oil Company's (MOC) proposed project for consistency with the Alaska Coastal Management Program (ACMP) and has developed this final consistency determination based on reviewers' comments. Because all parties with elevation and petition rights concurred with this project per the ACMP, I did not issue a proposed consistency determination. Scope of Project Reviewed The project subject to this consistency review entails redrilling existing gas well KU 24-5. MOC would sidetrack the well to gain access to targeted gas production intervals by abandoning existing completion intervals and isolating them with cement and plugs as directed by the Alaska Oil and Gas Conservation Commission (AOGCC) and Bureau of Land Management (BLM). MOC's redrilling operation would include the following: 1) A dual liner (impermeable 20 mil thick synthetic, underlain with felt) over the operational footprint for the drilling rig, diesel storage tank, and mud system. Edges of the liner would be bermed using timbers to create a 6" freeboard. Total capacity of the lined area would be greater than 110% of the volwne of the diesel tank, plus 12" of freeboard, 2) A double-walled diesel storage tank capable of containing 110% of the inner tank volwne; 3) Placing the diesel storage tank at least 100 feet away from the edge of the existing pad. 4) Adequate spill response equipment on site to handle accidental leaks or releases ( ( Marathon Ku 24-5RD AK 0108-0100 - 2- September 11, 2001 of oil, gas, or other toxic materials. MOC would temporarily store generated domestic wastewater in an existing, permitted in-ground holding tank, pending removal and disposal. Well testing would not involve flaring. The entire redrilling project would not use more than 42,000 gallons of water per day. The location is Pad 41-7 in the Kenai Gas Field, T. 4N, R. 11 W, Section 31, Seward Meridian. This final consistency detennination applies to the following federal and State authorizations per 6 AAC 50: U. S. Bureau of Land Management (BLM) Permit to Drill Department of Natural Resources (DNR) Temporary Water Use Permit (TWUP) A99-20 No State or federal agency may issue an authorization before DGC issues a final consistency determination. But, a consistency determination does not obligate any agency to issue authorization under its own statutory authorities, nor does it supersede its statutory obligations. Authorities outside the ACMP may result in additional permit/lease conditions not contained in the consistency determination. The Alaska Departments of Environmental Conservation, Fish and Game, and Natural Resources and the Kenai Peninsula Borough coastal resource district have reviewed your proposed project. Based on that review, the State concurs with your certification that the project is consistent with the ACMP Your consistency determination may include reference to specific laws and regulations, but this in no way precludes MOC's responsibility to comply with all other applicable State and federal laws and regulations. This consistency determination is ONLY for the project as described. If MOC proposes any changes to the approved project, including its intended use, prior to or during its siting, construction, or operation, MOC must contact this office immediately to determine if further review and approval of the revised project is necessary. Changes may require amendments to the TWUP or may require additional authorizations. This final consistency determination represents a consensus reached between you as the project applicant and the reviewing agencies listed above, regarding the conditions necessary to ensure the proposed project is consistent with the ACMP. We are informing the federal agency ( ( Marathon Ku 24.5RD AK 0108-0100 .3- September 11, 2001 responsible for approving a federal authorization for your project that your original proposal has been modified subject to the conditions in this consistency determination. This final consistency determination is a final administrative decision for purposes of Alaska Appellate Rules 601-612. Any appeal from this decision to the superior court must be made within 30 days of the date of this determination. If the proposed activities reveal cultural or paleontological resources, please stop any work that would disturb such resources and immediately contact the State Historic Preservation Office (907-269-8720) and the BLM (907.267..1443) so that consultation per section 106 of the National Historic Preservation Act may proceed. By copy of this letter, I am informing the BLM ofDGC's final determination. If you have any questions regarding this process, please contact me at 907-269..7474 or email tom - atkinson@gov.state.ak.us. cc: Sincerely, /s! Tom Atkinson Project Review Coordinator Daniel Bevington, KPBCMP Coordinator, KPB, Soldotna Bob Crandall, AOGCC, Anchorage Wendy Mahan, AOGCC, Anchorage Tom Maunder, AOGCC, Anchorage Matt Rader, DNR/DO&G, Anchorage Mark Fink, ADF&G, Anchorage Stewart Seaberg, ADF&G, Anchorage Bob Blankenburg, ADEC, Anchorage Scott Bailey, ADEC, Anchorage David Johnson, ADEC, Soldotna Mike Munger, CIRCAC, Kenai Mike Frank, Trustees for Alaska, Anchorage Kellie Westphal, DNR, Anchorage Karlee Gaskill, DNR, Anchorage Greg Noble, BtM, Anchorage " t ':. ( dÐ 1 - ,~ ~ ~v£v~ @~ £~£~~£ TONY KNOWLES, GOVERNOR DEPARTMENT OF FISH AND GAME 333 Raspberry Road Anchorage. AK 99518-1599 PHONE: (907) 267-2338 FAX: (907) 267-2464 Habitat and Restoration Division MEMORANDUM TO: FROM: Tom Atkinson Project Review Coordinator Division of Governmental Coordination Office of Management and Budget Mark Fink d Habitat Biologist Region II Habitat and Restoration Division RECEiVED DATE: August 28, 200 1 SEP 0 5 2001 SUBJECT: Marathon Oil KU 24-5, Kenai Gas Field State ill No, AK 0108-010G Alaska Oil & Gas Cons. Commission Anchorage The Alaska Department ofFish and Game (ADF&G) has reviewed the subject proposal to work over KU 24-5, an existing gas production well, located on Pad 41-7, in the Kenai Gas Field. The pad is located in Section 31, T4N, Rll W, Seward Meridian. In the event sidetracking becomes necessary, the existing completion intervals will be isolated and abandoned with cement and plugs, as directed by the Alaska Oil & Gas Commission and the Bureau of Land 11anagement, prior to perfonning the sidetracking. The redrill will be renamed wellJ(.U 24-5RD. A 20-mil synthetic impenneable liner will be placed over the operational footprint for the drilling rig, diesel storage tank, and mud system; the liner would be benned to create a six inch freeboard. Diesel will be stored in a double-walled tanle Drill cuttings will be dewatered on location, and the cuttings and excess mud will be hauled to Pad 41-18 for injection into an approved Class II disposal well. Oil spill response equipment would be maintained on-site to handle accidental leaks or releases of oil, gas, or other toxic materials, Marathon plans to use an existing temporary water use permit (TWill A99-20), The department has no objection to the project proposal and recommends the project be found consistent with the Alaska Coastal Management Program, A Fish Habitat Pennit from ADF&G is not required for the project as proposed. We appreciate the opportunity to review and comment on this proposal. { ~~&~~ @~ &~&~~£ ( 1/(301- 1'1~ J-f- TONY KNOWLES, GOVERNOR '1, q Þ ¿SÞ OFFICE OF THE GOVERNOR Bob Crandall ADGCC 333 W. 7111 Ave., Suite 100 Anchorage, AK 99501 OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION . SOUTIICENTRAL REGIONAL OFFICE 550 W. 7TH AVENUE, SUITE 1660 ANCHORAGE, ALASKA 99501 PH: (907) 269-7470 I FAX: (907) 269-3981 0 CENTRAL OFFICE P.O, BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562 1 FAX: (907) 465-3075 0 PIPELINE COORDINATOR'S OFFICE 411 WEST 4TH AVENUE, SUITE 2C ANCHORAGE, ALASKA 99501-2343 PH: (907) 269-7470 1 FAX: (907) 561-6134 August 3. 2001 Dear Mr. Underwood: RECEIVED AUG 062001 Alaska Oil & G as Cons C . Anchorag~ ornmlssion Mr. Charles A. Underwood, Jr. Marathon Oil Company P.O, Box 196168 Anchorage, AK 99519-6168 SUBJECT: MARATHON KU 24-5RD STATE ID NO. AK 01O8-010G START OF ACMP REVIEW The Division of Governmental Coordination (DGC) received the Coastal Project Questionnaire and consistency certification, applications, and supporting information you submitted for Marathon Oil Company's (MOC) proposed project. Because this proposed project is within, or affects the coastal zone of Alaska, DGC will coordinate a consistency review as required under the federal Coastal Zone Management Act (Section 307(c)(3)(A)) and Alaska Coastal Management Program (ACMP) (AS 46.40). This letter initiates the State of Alaska review of this proposed project under the schedule and process described in State regulations (6 AAC 50). I have described the review process and outlined the schedule below and on the enclosed project information sheet. Scope ofProiect to be Reviewed The project subject to this consistency review entails redrilling existing gas well KU 24-5. MaC would sidetrack the well to gain access to targeted gas production intervals by abandoning existing completion intervals and isolating them with cement and plugs as directed by the Alaska Oil and Gas Conservation Commission (AOGCC) and Bureau of Land Management (BLM). MaC's redrilling operation would include the following: 1) A dual liner (impermeable 20 mil thick synthetic~ underlain with felt) over the operational footprint for the drilling rig, diesel storage tank, and mud system. Edges of the liner would be bermed using timbers to create a 6" Marathon KU 24-5RD AK OI08-0IOG Page 2 August 3. 2001 freeboard, Total capacity of the lined area would be greater than 110% of the volume of the diesel tank, plus 12" of freeboard. 2) A double-walled diesel storage tank capable of containing 1100/0 of the inner tank volume: 3) Placing the diesel storage tank at least 100 feet away from the edge of the existing pad, 4) Adequate spill response equipment on site to handle accidental leaks or releases of oil, gas~ or other toxic materials. Mac would temporarily store generated domestic wastewater in an existing, permitted in- ground holding: tame pending removal and disposal. Well testing would not involve flaring. The entire redrilling project would not use more than 42,000 gallons of water per day, The location is Pad 41-7 in the Kenai Gas Field, T, 4N, R, 11 W, Section 31, Seward Meridian, Review Process I distributed the packet of information you submitted to the following review participants: Alaska Departments of Environmental Conservation. Fish and Game, and Natural Resources, and the Kenai Peninsula Borough Coastal District, the Cook Inlet Regional Citizens' Advisory Committee, as well as other interested parties (see enclosed distribution list), A notice published and posted on 8/6/01 informed the public of the proposed project. This proposed proj ect will require the following federal and State permits: U.S, Bureau of Land Management (BLM) Permit to Drill Alaska Department of Natural Resources (DNR) Temporary Water Use Permit A99-20 Mac has already obtained Temporary Water Use Permit A99-20, valid through 9/7/2004, to withdraw up to 42.000 gallons per day on Pad 41-7, No State or federal agency can issue an authorization before DGC issues the final consistency determination. Most State agencies should issue permits within five days after DOC issues the final consistency determination, DOC will coordinate the consistency review of this project under a 50-day review schedule. I have listed deadlines for additional information requests, comments. and proposed and final determinations on the attached project information sheet. State review participants will evaluate this proposed project for consistency with the standards of the ACMP and policies of the Kenai Peninsula Borough Coastal District Program, The public also may submit comments, DOC must receive reviewer and public comment before 5:00 p.m. on 9/8/01, Comments may include modifications to the proposed project to ensure it is consistent with coastal program standards and policies. DGC will review and integrate comments and issue a proposed consistency determination that will notify you of any modifications required to make the proposed project consistent with the coastal program, MaC, State resource agencies, and an affected coastal resource district with an approved program have { l' ~~ Marathon KU 24-5RD AK 0108-010G Page 3 August 3. 2001 five days from receipt of the proposed detennination to request an elevation of the determination to the resource agency directors. Please note that in addition to their consistency review, State agencies with permitting responsibilities will evaluate this proposed project according to their specific permitting authorities, Agencies will issue permits and authorizations only if they find the proposed project complies with the agency's statutes and regulations in addition to being consistent with the coastal program. Permits and authorizations will contain both those stipulations necessary to ensure consistency with the coastal program and stipulations necessary for compliance with agencies' statutory authorities. By a copy of this letter I am informing the BLM that the State has begun its consistency review. Please contact me at 269-7474, or email tom_atkinson@gov.state.ak.us if you have any questions. -...... Enclosure: PIS, applications, project description, map, diagrams Daniel Bevington, KPBCMP Coordinator, KPB, Soldoma Bob Crandall, AOGCC, Anchorage Wendy Mahan, AOGCC, Anchorage Tom Maunder, AOGCC, Anchorage Matt Rader. DNR/DO&G, Anchorage Mark Fink, ADF&G, Anchorage Stewart Seaberg, ADF&G, Anchorage Bob Blankenburg, ADEC, Anchorage Scott Bailey, ADEC, Anchorage David Johnson, ADEC, Soldoma Mike Munger, CIRCAC, Kenai Greg Noble, BLM, Anchorage Mike Frank, Trustees for Alaska, Anchorage Enclosure: PIS (Backup Material on Request) Kellie Westphal, D~ Anchorage Karlee Gaskill. DNR, Anchorage ( ( STATE OF ALASKA TonyKnow/es,Govemor OFFICE OF THE GOVERNOR SouthcentralOff1£g, OFFICE OF MANAGEMENT AND BUDGET Consistency Review Unit DIVISION OF GOVERNMENTAL COORDINATION 550 West 7th Ave.,Suîte 1660 Anchorage, AK 99501 DGC DEC DFG DNR DISTRICT CaE Contacts Tom Atkinson Robert Blankenburg Mark Fink Matt Rader Daniel Bevington Phone (907) 269-7474 (907) 228-2200 (907) 267-2338 (907) 762-2547 (907) 262-4441 Fax (907) 269-3981 (907) 225-1845 (907) 267-2464 (907) 562-3852 (907) 262-8618 Email tom_atkinson@gov,state,ak.us Mark_A nk@fishgame,state,ak,us mattJader@dnr.state.ak.us dbevington@borough.kenai.ak.us PROJECT INFORMATION SHEET PROJECT TITLE: Marathon Kenai Unit (KU) 24-5 STATE ID NUMBER: AK 0108-010G APPLICANT/PROPONENT: Marathon Oil Company AGENT: Chick Underwood Phone: (907) 564-6435 Fax: (907) 564-6489 Email: caunderwood@marathonoil.com DIRECT FEDERAL ACTION: REVIEW TYPE: Consistency ACTIVITY TYPE: OIL AND GAS - DEVELOPMENT PROJECT LOCATION: Nearest Coastal District: Kenai Peninsula Borough Project is INSIDE the District Coastal Zone Boundary District Plan Approved? Yes REVIEW SCHEDULE: 50 Days REVIEW MILESTONES: Day 1:,."""..,."",."""""", ". ..,.. ".. .. ,.,.. ., . Reviewer Request for Additional Information on or before:. , , , , , , , , , , , CommentsDuetoDGConorbefore:""".,."""""....",., Proposed Consistency Determination Issued on or before: . , . , , , , , . , . Final Consistency Determination Issued on or before: , , , . , , . , , , , , , . , PREVIOUS OR RELATED PROJECT REVIEW STATE ID#'S: STATE AND FEDERAL APPROVALS: No 08/06/2001 08/30/2001 09/08/2001 09/18/2001 09/24/2001 STATE DNR FEDERAL BlM TEMPORARY WATER USE PERMIT PERMIT TO DRILL TWUP 99020 Federal Deadline: 02/06/2002 'i; ~.. r ~ PUBLIC NOTICE Alaska Coastal Management Program Division of GovernmentID Coord~(DGC) Marathon Oil Company (MaC) is proposing the project, described below, in your area, DGC is coordinating the State of Alaska's review of the project for consistency with the Alaska Coastal Management Program, and requests your written comments, particularly on the project's consistency with the Kenai Peninsula Borough Coastal Management Plan. To be considered, DOC must receive written comments by 5:00 p.m. on 9/8/01. (contact information below). Comments regarding inconsistency with an affected coastal district's enforceable policy or a state standard set out in 6 AAC 80.040-6 AAC 80,150 must identify the enforceable policy or standard and explain how the project is inconsistent. PROPOSED PROJECT & LOCATION: The project subject to this consistency review entails redrilling existing gas well KU 24-5, MOC would gaín access to targeted gas production intervals by abandoning existing completion intervals and isolating them with cement and plugs as directed by the Alaska Oil and Gas Conservation Commission (AOGCC) and Bureau of Land Management (BLM). The location is Pad 41-7 in the Kenai Gas Field, T, 4N, R. 11 W, Section 31, Seward Meridian. APPLICANT/AGENT: Marathon Oil Company/ Mr. Charles Underwood PROJECT NUMBER: State ID # AK 0108-010G PROJECT NAME: KU 24-5 RD DEADLINE FOR WRITTEN COMMENTS: 5:00 p.m., 9/8/01 FOR MORE INFORMATION OR TO SUBMIT COMMENTS CaNT ACT: Division of Governmental Coordination Contact: Tom Atkinson 550 W. 7th Avenue, Suite 1660 Phone: 907-269- 7474 Anchorage, AK 99501 Fax: 907-269-3981 Email: tom_atkinson@gov,state,ak.us Individuals with disabilities who may need auxiliary aids, services, or special modifications to participate in this review may contact the number above. Dated at Anchorage, AK on 8/3/01, Published in Peninsula Clarion on 8/7/01. Posted at Kenai, Soldotna and KasHof post offices on or before 8/7/01, ~' '" ~ :( Coastal Project Questionnaire and Certification Statement Please answer all questions, To avoid a delay in processing, please call the department ¡fyou answer "yes" to anv of the questions related to that department. Maps and plan drawings must be included with your packet. An incomplete packet will be returned. . APPLICANT INFORMATION 1. Marathon Oil Companv Name of Applicant P, 0, Box 196168 Address Anchorage, AK City/State ŒQ1) 561-5311 Daytime Phone (907) 564-6489 Fax Number E-mail Address 2, Charles A. Underwood, Jr. Agent (or responsible party if other than applicant) P, a, Box 196168 Address Anchorage, AK City/State State (907) 564-6435 Daytime Phone (907) 564-6489 Fax Number Zip Code 99519-6168 Zip Code 99519-6168 Zip Code caunderwood@marathonoil,com E-mail Address . PROJECT INFORMATION 1. This activity is a: X new project 0 modification or addition to an existing project If a modification, do you currently have any State, federal or local approvals related to this activity? .......,.... ...,.., ....,......... ............"...............,..,..,..",......",...."...",...,.."""""..",.. ..,. . Note: Approval means any form of authorization, If "yes," please list below: Approval Type Approval # Issuance Date ail & Gas Lease A-028142 1957 Permit to Drill (AaGCC) 82-98 June 17, 1982 Yes No 0 Expiration Date 1983 2, If a modification, has this project ever been reviewed by the State of Alaska under the ACMP? ....,.., 0 Previous State I.D, Number: AK Previous Project Name: . . PROJECT DESCRIPTION 1, Provide a brief description of your entire project and ALL associated facilities and land use conversions. Attach additional sheet(s) as needed, Marathon Oil Company intends workover existing gas well KU 24-5. located on Pad 41-7, Kenai Gas Field. If the planned workover operations are unsuccessful a re-drill will be necessarY to recomplete the well. A 5-year permit is requested if a delay prevents completing the work as scheduled. (See Attachment A for details) Proposed starting date for project: September 1,2000 Proposed ending date for project: September!, 2005 2, Attach the following: . a detailed description of the project, all associated facilities. and land use conversions, etc, (Be specific, including access roads, caretaker facilities, waste disposal sites, etc.); . a project timeline for completion of all major activities in the proposal; . a site plan depicting property boundary with all proposed actions: . other supporting documentation that would facilitate review of the project, Note: If the project is a modification. identify existing tàcilities as well as proposed changes on the site plan, Revised 1/99 Page 1 . PROJECT LOCATION 1. Attach a copy of the topographical and vicinity map clearly indicating the location of the project. Please include a map title and scale. 2. The project is located in which region (see attached map): D Northern. Southcentral D Southeast D within or associated with the Trans-Alaska Pipeline corridor 3. Location of project (Include the name of the nearest land feature or body of water.) 9 Miles South of Kenai. Alaska Township 4N_- Range ~'- Section 2)- Meridian _S- LatitudelLongitude 60°30'50.6 I 151°16'37.4- USGS Quad Map Kenai B-4 4. Is the project located in a coastal district? Yes. No D If yes, identify: Zone 17, Kenai Peninsula Borough (Coastal districts are a municipality or borough, home rule or first class city, second class with planning, or coastal resource service area.) Note: A coastal district is a participant in the State's consistency review process. it is possible for the State review to be adjusted to accommodate a local permitting public hearing. Ear!"\! interaclion with the district is important; please contact the district representative listed on the allached contact list. 5. Identify the communities closest to your project location: Soldotna. Alaska 6. The project is on: . State land or water* D Federal land D Private land 0 Municipal land D Mental Health Trust land *State land can be uplands. tidelands, or submerged lands to 3 miles offshore. See Question #1 in DNR section. Contact the applicable iandowner(s) to obtain necessary authorizations. . DEPARTMENT OF ENVmONMENT AL CONSERVATION (DEC) APPROVALS Yes 1. Will a discharge of wastewater from industrial or commercial operations occur?..,..,......................... 0 Will the discharge be connected to an already approved sewer system?,................",......,.................... D Will the project include a stOrm water collection/discharge system? ,........,........................................... D ') ...... Do you intend to construcL instalL modify, or use any part of a wastewater (sewage or greywater) disposal system? """"""""""""""""""""""""""""""".,.....,........................................ a) If so, will the discharge be 500 gallons per day or greater? .....,..................,.........................,......." D b) If constructing a domestic wastewater treatment or disposal system, will the system be located within fill material requiring a CaE permit?.."................................................. D If you answered yes to a) or b), answer the following: 1) What is the distance from the bottom of the system to the top of the subsurface water table? 2) How far is any part of the wastewater disposal system from the nearest surface water? 3) Is the surrounding area inundated with water at any time of the year? .,.........,..............,................ D 4) How big is the fill area to be used for the absorption system? (Questions J & 2 will be used by DEC to determine whether separation distances are being met; Questions 3 & 4 relate to the required size of the.fill ~f wetlands are involved) 3. Do you expect to request a mixing zone for your proposed project? """"""."""""."""""".."""""'" 0 (!fyour wastewater discharge will exceed Alaska water quality standards, you may applyfor a mixing zone. !f so, please contact DEC to discuss information required under J 8 AA (' 70.032) Revised 1/99 Page 2 No . . . D . . D . 4, a) l 11\ ( Yes b) Will your project result in the construction, operation, or closure of a facility for the disposal of solid waste?..,..........,......,..........., ,..,.., ,..,......, ,..,.., '.., ,.....",.. ..".., "..".......,...", ,.......",.. 0 (Note: Solid waste means drilling wastes, household garbage, refuse, sludge, construction or demolition wastes. industrial solid waste, asbestos, and other discarded, abandoned, or unwanted solid or semi-solid material, whether or not subject to decomposition, originatingfrom any source. Disposal means placement of solid waste on land.) Will your project result in the treatment of solid waste at the site?,..........,......,.......,..,..........,...... 0 (Examples of treatment methods include, but are not limited to: incineration, open burning, baling, and composting.) Will your project result in the storage or transfer of solid waste at the site?.,..,....,....,.........."....... Will the project result in the storage of more than 50 tons of materials for reuse, recycling, or resource recovery? ".. "....,... ....,........" ....,..,.......,..,..,....,...,..,.. ,.."..."..",..,.. ....",..,.,..",.. ,..."......, 0 Will any sewage solids or biosolids be disposed of or land-applied to the site? ....,...."........"..,... 0 (Sewage solids include wastes that have been removed from a wastewater treatment plant system, such as a septic tank, lagoon dredge, or wastewater treatment sludge that contain no free liquids. Biosolids are the solid. semi-solid. or liquid residues produced during the treatment of domestic septage in a treatment works which are land applied for beneficial use.) c) d) e) 5. Will your project require the application of oil, pesticides, and/or any other broadcast chemicals? ... ....,.. ,... ..,..........,.."..,.." .......""........., '......" ....".,..,.........."....,.. ,..,..,.."". ".....".., ....,....,..", 0 6. a) b) Will you have a facility with industrial processes that are designed to process no less than five tons per hour and needs air pollution controls to comply with State emission standards?"... ,..,........" '........ ..,...."..,..,...,.....,..,.., ,.. .........,..,."",.......,., "..",...".."",...,..,.., 0 Will you have stationary or transportable fuel burning equipment, including flares, with a total fuel consumption capacity no less than 50 million Btu/hour?,......,..",...........,......,..,..D Will you have a facility with incinerators having a total charging capacity of no less . than 1,000 pounds per hour? ".. ,........ .........."...,.... ........,.. ...' ,..,.." ....,.."",....,.,..".... ,...... ..........."... 0 Will you have a facility with equipment or processes that are subject to Federal New Source Performance Standards or National Emission Standards for hazardous air pollutants?." 0 i) Will you propose exhaust stack injection? "..............,..,..,.. ...,............,.. ,.... ,......,..,..,...., .......... 0 Will you have a facility with the potential to emit no less than 100 tons per year of any regulated air contaminant? .. ..,...... ,..,..." ..,........,.......,..........., .........,..."."..,.."..,.......,.."......,.. "..",. 0 Will you have a facility with the potential to emit no less than 1 0 tons per year of any' hazardous air contaminant or 25 tons per year of all hazardous air contaminants?...................... 0 Will you construct or add stationary or transportable fuel burning equipment of no less than 10 million Btu/hour in the City of Unalaska or the City of S1. Paul?"....,..,...."......,......"...... 0 Will you construct or modify in the Port of Anchorage a volatile liquid storage tank with a volume no less than 9,000 barrels, or a volatile liquid loading rack with a design throughput no less than 15 million gallons?.,..,..................................................,..,........................ 0 Will you be requesting operational or physical limits designed to reduce emissions from an existing facility in an air quality nonattainment area to offset an emission increase from another new of modified facility?, ..,.............. ................,.... ...... ........ ,.......,. ....,...,..., .........,.... 0 c) d) e) t) g) h) i) 7, Will you be developing, constructing, installing, or altering a public water system?...,....,.........."..".. 0 8. a) Will your project involve the operation of waterborne tank vessels or oil barges that carry crude or non-crude oil as bulk cargo, or the transfer of oil or other petroleum products to or from such a vessel or a pipeline system?..."..,......,..,..,..,........,..,.......... 0 b) Will your project require or include onshore or offshore oil facilities with an effective aggregate storage capacity of greater than 5,000 barrels of crude oil or greater than 10,000 barrels of non-crude oil? ,..,......"............."....,.......,........,..,..,..........,.......... 0 Revised 1/99 Page 3 No . . 0 . . . . . . . . . . . . . . . . Yes No c) Will you be operating facilities on the land or water for the exploration or production of hydrocarbons? .........................., ...........,..........,...,.."",........, ....."..,."......................,..,. ..,............' If you answered "NO" to ALL questions in this section, continue to next section. Uyou answered "YES" to ANY of these questions, contact the DEC office nearest you for information and application forms. Please be advised that all new DEC permits and approvals require a 30-day public notice period. DEC Pesticide permits take effect no sooner than 40 days after the permit is issued. 0 Based on your discussion with DEC, please complete the following: Types of project approvals or pennits needed Temporary Waste Storage Approval Date application submitted July 16, 200] 9. Does your project qualify for a general pennit for wastewater or solid waste?...........,......"................ 0 Note: A general permiT is an approval issued by DEC for Gerwin types of roUline aclivilies. . If you answered "YES" to any questions in this section and are not applying for DEC permits, indicate reason: 0 (DEC contact) told me on that no DEC approvals are required on this project because . Other: ADEC approved in-f!round holdinf! tank will be used for camp wastewater. . DEPARTMENT OF FISH & GAME (DFG) APPROVALS 1. Will you be working in, removing water or material from, or placing anything in, a stream, river or lake? (This includes work or activities below the ordinary high water mark or on ice, in the active flood plain, on islands, in or on the face of the banks. or. for streams entering or flowing through tidelands. above the level of mean lower low tide.) Note: If the proposed project is located within a special flood hazard area, afloodplain development permit may be required. Contact the affected city or borough planning department for addilional information and ajloodplain determination,)..,..,.....,. 0 Name of water body: Revised 1/99 . ') ..... . Will you do any of the following: .......,....",....,.,.................,.....,...............,................................,.,....,.... 0 Please indicate below: 0 Build a dam, river training structure, other instream impoundment. or weir 0 Use the water 0 Pump water into or out of stream or lake (including dry channels) 0 Divert or alter the natural stream channel 0 Change the water flow or the stream channel 0 Introduce silt, gravel, rock, petroleum products, debris, brush, trees, chemicals, or other organic/inorganic material, including waste of any type, into the water 0 Alter, stabilize or restore the banks of a river, stream or lake (provide number of linear feet affected along the bank( s) 0 Mine, dig in, or remove material, including woody debris. from the beds or banks of a waterbody 0 Use explosives in or near a waterbody 0 Build a bridge (including an ice bridge) 0 Use the stream, lake or waterbody as a road (even when frozen), or cross the stream with tracked or wheeled vehicles, log-dragging or excavation equipment (backhoes, bulldozers, etc.) 0 Install a culvert or other drainage structure 0 Construct, place, excavate, dispose or remove any material below the ordinary high water of a waterbody 0 Construct a stonn water discharge or drain into the waterbody 0 Place pilings or anchors 0 Construct a dock 0 Construct a utility line crossing 0 Maintain or repair an existing structure 0 Use an instream in-water structure not mentioned here Page 4 t ( Yes 3, Is your project located in a designated State Game Refuge, Critical Habitat Area or State Game Sanctuary?."."..".. .""""""""'" ,.., ,........,..,..".. '.." ......,... ......",..,.."... ......,..,..",.."....,....,.... 0 4, Does your project include the construction/operation of a salmon hatchery?.,............,........................ 0 5, Does your project affect, or is it related to, a previously pennitted salmon hatchery?.........,.........,...., 0 6, Does your project include the construction of an aquatic fann?,..................,...........,..,..,...................... 0 If you answered "No" to ALL questions in this section, continue to next section. If you answered "Yes" to ANY questions under 1-3, contact the Regional or Area DFG Habitat and Restoration Division Office for information and application forms. If you answered "Yes" to ANY questions under 4-6, contact the DFG Commercial Fisheries Division headquarters for information and application forms. Based on your discussion with DFG, please complete the following: Types of project approvals or pennits needed Date application submitted No . . . . If you answered "YES" to any questions in this section and are not applying for DFG permits, indicate reason: 0 (DFG contact) told me on that no DFG approvals are required on this project because 0 Other: . DEPARTMENT OF NATURAL RESOURCES (DNR) APPROVALS 1. Is the proposed project on State-owned land or water or will you need to cross State-owned land for access? ("Access" includes temporary access for construction purposes, Note: In addition to State-owned uplands. the State owns almost aff land below the ordinary high water line of navigable streams, rivers and lakes. and below the mean high tide line seaward for three miles.), ......,......,..,.....,.. ,...,..,.."..,. "......",.,...,....""""",..",..,..""'" ,.... ........ 0 a) Is this project for a commercial activity?"".,.........,...,.."""",..""""""""".,..""".""""",..""....,....". 2. Is the project on Alaska Mental Health Trust land (AMHT) or will you need to cross AMHT land? Note: Alaska Mental Health Trust land is not considered State landfor the purpose of ACMP reviews,....,........,....".."....,... 0 3, Do you plan to dredge or otherwise excavate/remove materials on State-owned land?..............,....".. 0 Location of dredging site if different than the project site: Township Range Section Meridian USGS Quad Map 4. Do you plan to place fill or dredged material on State-owned land? ..,.............,.."............,.."............... 0 Location of fill disposal site if other than the project site: Township Range Section Meridian USGS Quad Map Source is on: 0 State Land 0 Federal Land 0 Private Land 0 Municipal Land 5, Do you plan to use any of the following State-owned resources:...,..,.................,...,..,..,....,..,............... 0 0 Timber: Will you be harvesting timber? Amount: 0 Materials such as rock, sand or gravel, peat, soil, overburden, etc.: ,.."",....,..,......"......."........."." Which material? Amount: Location of source: 0 Project site 0 Other, describe: Township Range Section Meridian USGS Quad Map Revised 1/99 Page 5 . 0 . .- . . . Yes 6. Are you planning to diven, impound, withdraw, or use any fresh water, except from an existing public water system or roof rain catchment system (regardless of land ownership)?............................. Amount (maximum daily, not average, in gallons per day): 42,000 Source: Permitted Water Well Intended Use: Mix Drilling Mud & Maintain Mud Properties If yes, will your project affect the availability of water to anyone holding water rights to that water? 0 7. Will you be building or altering a dam (regardless of land ownership)?.....,.......,................,..,............ 0 8. Do you plan to drill a geothermal well (regardless of land ownership)? ...,.........,..........,.,.......,..........., 0 9. At anyone site (regardless of land ownership), do you plan to do any of the following?,................... 0 0 Mine five or more acres over a year's time 0 Mine 50,000 cubic yards or more of materials (rock, sand or graveL soil, peat, overburden, etc.) over a year's time 0 Have a cumulative unreclaimed mined area of five or more acres If yes to any of the above, contact DNR about a reclamation plan. If you plan to mine less than the acreage/amount stated above and have a cumulative unreclaimed mined area of less than five acres. do you intend to file a voluntary reclamation plan for approval?.. 0 10. Will you be exploring for or extracting coal? ....,........,....................,.......,...........,........,.......,..............., 0 II. a) Will you be exploring for or producing oil and gas? ........"......"............,..,....,....,....,..........,......"..... b) Will you be conducting surface use activities on an oil and gas lease or within an oil and gas unit? . 12. Will you be investigating, removing, or impacting historical or archaeological or paleontological resources (anything over 50 years old) on State-owned land?..............................................................0 13. Is the proposed project located within a known geophysical hazard area?,............"......,.......,............." 0 Note: 6 AAC 80.900(9) defines geophysical hazard areas as "those areas which present a threat to life or property from geophysical or geological hazards. including flooding, tsunami run-up. storm surge run-up. landslides, snowslides, faults, ice hazards, erosion. and IiCloral beach process" "known geophvsical hazard area" means any area identified in a reporT or map published by afederaJ, state, or local agency, or by a geological or engineering consultingfirm, or genera/(v known by local knowledge, as having known or potential hazards from geologic, seismic, or hydrologic processes. 14. Is the proposed project located in a unit of the Alaska State Park System?.......................................... 0 If you answered "No" to ALL questions in this section, continue to Federal Approvals section. If you answered "Yes" to ANY questions in this section, contact DNR for information. Based on your discussion with DNR, please complete the following: Types of project approvals or penn its needed Date application submitted No 0 0 . . . 0 . 0 0 . . . If you answered "YES" to any questions in this section and are not applying for DNR permits, indicate reason: 0 - (DNR contact) told me on that no DNR approvals are required on this project because . Other: Existing Temporary Water Use Pennit (TWUP) A99-20. Revised 1/99 Page 6 u.s. Army Corps of Engineers (COE) 1. Will you be dredging or placing structures or fills in any of the following: tidal (ocean) waters? streams? lakes? wetlands*?.......,.."......,..,...."....,...................."........,..,......,......' 0 If yes, have you applied for a CaE permit? ......,..,...........,..,.............,......,..,..,..",........,.....,.......,..,' 0 Date of submittal: (Note: Your applicarionfor this activity to the CaE also serves as application for DEC Water Quality Certification.) */fyou are not certain whether your proposed project is in a wetlands (wetlands include muskegs), contact the CaE, Regulatory Branch at (907) 753-2720 for a wetlands determination (outside the Anchorage area cali toli free 1-800-478-2712). Bureau of Land Management (BLM) 2, Is the proposed project located on BLM land, or will you need to cross BLM land for access?,.......... 0 If yes, have you applied for a BLM permit or approval? ,..,..,..,.......,.,................,............,.............. 0 Date of submittal: f ( . FEDERAL APPROVALS Yes u.s. Coast Guard (USCG) 3. a) Will you be constructing a bridge or causeway over tidal (ocean) waters, or navigable rivers, streams or lakes? .. ................. ........... .......,... ,...",.., ,....,..,...........,..,.""."", .."",.."...",.., ....."", ....,..... 0 b) Does your project involve building an access to an island? ....,..."........"......"........,......",......,......, 0 c) Will you be siting, constructing, or operating a deepwater port? ......,.............,..,..,..........,...."......,' 0 If yes, have you applied for a USCG permit? ..,............................,..............""..,...........,.....".., 0 Date of submittal: u.s. Environmental Protection Agency (EPA) 4, a) Will the proposed project have a discharge to any waters?.....,................................,..,................., 0 b) Will you be disposing of sewage sludge (contact EP A at 206-553-1941 )?.......,..,......................... 0 If you answered yes to a) or b), have you applied for an EPA National Pollution Discharge Elimination System (NPDES) permit?"""",."",..,..",...".",.""",..""",......"...."....".."",..,....,.. 0 Date of submittal: (Note: For information regarding the need for an NPDES permit. contact EPA at (800) 424-43ì2,j C) Will construction of your project expose 5 or more acres of soil? (This applies to the total amount of land disturbed, even if disturbance is distributed over more than one season. and also applies to areas rhar are parr of a larger common plan of development or sa/e.)...............,...."........,.....,.."....""...."",....""..,..,..".,..."..."....... 0 d) Is your project an industrial facility which will have storm water discharge which is directly related to manufacturing, processing, or raw materials storage areas at an industrial plant?.....,.., 0 If you answered yes to c) or d), your project may require an NPDES Stormwater permit, Contact EPA at 206-553-8399, Federal Aviation Administration (FAA) 5, a) Is your project located within five miles of any public airport?......,....,..",......".......................,.... 0 b) Will you have a waste discharge that is likely to decay within 5,000 feet of any public airport?,.. 0 If yes, please contact the Airports Division of the FAA at (907) 271-5444, Federal Energy Regulatory Commission (FERC) 6, a) Does the project include any of the following: 1) a non-federal hydroelectric project on any navigable body of water.....................................,.. 0 2) a location on federal land (including transmission lines)......,......,.......,.....,.........,............,..,.... 0 3) utilization of surplus water from any federal government dam ,....,..........,....,.....,...."..".......... 0 b) Does the project include construction and operation, or abandonment of natural gas pipeline facilities under sections (b) and (c) of the Federal Power Act (FPA)?........,....,..........,.,..,............. 0 Revised 1/99 Page 7 No . 0 . 0 . . . 0 . . 0 . . . . . . . . Yes c) Does the project include construction for physical interconnection of electric transmission facilities under section 202 (b) of the FP A? .............,.....,..........,...,...,.,...,........,.............,.,.......,...... 0 If you answered yes to any questions under number 6. have you applied for a pennit from FERC? .....,...............,...............,..........,......,..............,...........,...................................."""""""" 0 Date of submittal: (Note: For information, contact FERC, Office of Hydropower Licensing (202) 219-2668; Office of Pipeline Regulation (202) 20B-0700; Office of Electric Power Regulation (202) 208-1200.) u.s. Forest Service (USFS) 7. a) Does the proposed project involve construction on USFS land?,..,.......................,......................... 0 b) Does the proposed project involve the crossing ofUSFS land with a water line?.....,................... 0 If the answer to either question is yes, have you applied for a USFS pennit or approval? ...... 0 Date of submittal: 8. Have you applied for any other federal penn its or authorizations? ......,.....,.......,....,....,....."....,......,..... 0 AGENCY ApPROV AL TYPE DATE SUBMITIED Please be advised that the CPQ identifies permits subject to a consistency review. You may need additional permits from other agencies or the affected city and/or borough government to proceed with your activity. Certification Statement The infonnation contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with. and will be conducted in a manner consistent with~ the Alaska Coastal Management program/) / A L /)~ . () Signaillre (ofAP~tr ~{en';' '¡/fdtJ/ W Date I 3' ¿/'t/I¡ 200 I Note: Federal agencies conducting an activity that will affect the coastal zone are required to submit a federal consistency detennination, per 15 CFR 930, Subpart C, rather than this certification statement. DGC has developed a guide to assist federal agencies with this requirement. Contact DGC to obtain a copy. This certification statement will not be complete until all required State and federal authorization requests have been submitted to the appropriate agencies. . To complete your packet, please attach your State permit applications and copies of your federal permit applications to this questionnaire. Revised 1/99 Page 8 No . 0 . . 0 . ( i( Attachment "A" Marathon Oil Company KU 24-5 (Potential Sidetrack) Marathon Oil Company, Marathon, plans to workover an existing Kenai Gas Field gas production well, KU 24-5, located on Pad 41-7, However, due to the complexity of the workover there is a reasonable possibility that the existing wellbore will require sidetracking. In this instance, the existing completion intervals will be isolated and abandoned, and will be redrilled to gain access to the targeted gas production intervals. The sidetrack will be only a short distance away from the existing well bore, Well KU 24-5 was originally drilled and completed in 1982. Even though the sidetrack drilling may not be required. in order to prevent permitting delays, Marathon is submitting approvals at the present time in the event sidetracking becomes necessary. This work must be done while the workover/drilling rig is on location and available. Prior to performing the sidetrack~ the existing completion intervals will be abandoned and isolated with cement and plugs, as directed by the Alaska Oil & Gas Conservation Commission (AOGCC) and Bureau of Land Management (BLM). To protect the land surrounding Pad 41-7 and avoid potential releases from the project, Marathon intends to take the following three precautions: 1) place a dual liner over the entire operational footprint for the drilling rig, diesel storage tank, and mud system. The dual liner is comprised of a 20 mil thick synthetic impermeable liner that is underlain by a felt liner which acts to cushion the surface liner and prevent punctures; 2) use a double- walled diesel storage tank that has an annulus capable of containing 110% of the volume of the inner tank; 3) place the diesel storage tank at least 100 feet away from the edge of the existing pad; and 4) store adequate spill response equipment on site to handle accidental leaks or releases of oil, gas, or other toxic materials. The edges of the liner are bermed using timbers that create a 6-inch freeboard. The total capacity of the lined area under the rig, diesel tank, and mud system is greater than the equivalent volume of 110% of the volume of the diesel tank, plus 12 inches of freeboard. Marathon has an existing permit from the Department of Natural Resources for use of the water well on the pad, TWlJP A99-20, and no additional approval is necessary for the use of water during the project. Marathon previously permitted an in-ground holding tank for the wastewater generated by the drilling rig camp. The wastewater generated is removed by a private company for disposal. Ifnecessary, upon completion of the redrill, well KU 24-5RD~ will be tested without using a flare. - -- -:-;-r------ G3~ 'PIpeline " --- ' Gravel, Pit : ..", -" L-,- ~;<t_, VI.l: i" '-'-'-~r'-'::..!.'-:-"--- : ' ~ - : " . ,'. ' " J , ,-,c_,"--, --'-~-'=,,:, c( Ini' I~l)") , ..:' . I -'" Cook Inl.' ,". 'i -, Kenat,Ie.1s Ft.akt..,pfflcB \- I' , -~,---'_c, I; S' Pad 34-31 " ,f" --lr",:ìß- -~.!!s_--,---,-------- - ---- ¡""'-:"O:fadIOI_" -Kenai Gas 1\ " \ - '-", --- '" ,....., ,- - '.. 1--:: ,:to, Ii-- , ,0 "'" ~,.." ,;:::: I'.. - " ,....:¡ 1 ... ' .- \" :Oil ~ , ,.:n: (.) , 'I Landing ,\.,' "- ' ,Strips , ", -"_"'=.,=~~~-'--_.~c.==;,_.-,,-,-,~=.,-~, ,,""~'-"'-'--- Field, ,--,~-c..-:' I' -~, , I , ¡ ~ I' 14-6 Pad 41-7 ells , ~- p-ProjëëlLocatio:n , ':===----==-=;--" .. ,.,--~". 'I . I 'i- '" "" ~ V:J Gravel :~" 'Pits: ....~: I'.: ,'it !~ .,. ,I: \ I ' ~: ,]\ ' \ '4\)' f Àð'-~ ;"':', .'v~.a. lXI' .,".' '" : "'~, 6 5 -4 I , , 1,_- ..._1' ---II' ,'. i "; .. -" --..... -, --_.. . ' :.. , ,i; oI,i'" I' : i :i " ,:¡ ,,' ,:1 " .\ . I' _,i 7 --~ i! I, I' \. landing \" Strip ,:. . , . ' ;;;.t ..- ",,: I 2- := r, ,... " ~, ... " J l.. .. I... 8 9 " \ ! " :,' :r E1 Pad' 41-18 E'cho Luke " .' , ,:\-' " -,,-', ,'LanOlng ,/ r ~,'StriP)l ;/ ¡ .c :(.-7~" ,~ .. " ;!...~~, ~' /~--=~ \ ' ,f ' ':' II .. ¡ - ,:7~ .n': '..---...- ,::---1.-,;-- -::!hb" ./ L,,:,~'--';----'- '-----r"----- -:?'-'"'-:'~'~I" ! - ,0' ..t/ ' c~ ~:¡: f t, ,þ -' "t -./ , ,----" :-/---" .'-,- ,",,/::~' f ,c-~-- . ,- .. ,- -~--- ." , " ¡ , )~.. ,f , ',- /', ..- , "":'~;Ä ..~: " , t " (,~, Well ' , ! " f ,': l ï: ,: ' t .. " G/J~ Well ,. ' r::~:") ~ : . ¡' . ./ '".1 .-:KílUfOMk)' t' , ,- ~Ir'"! . (. ,. """', -- :~ , ¡ ..;, ~ '\, ~' ,I. .. ~ \: -- --', \ , " " i, ' ¡ . \:~,j;,= ( 1 . , \ .i i, - ,'" ',':.,." ...::: :-: " ...' \, I' l~ :.... ,'" '/: .- -: '- \' -i\ ' I.", " .1 R¡>'flcirtion-:,:,~"",:,;,,<,,~:,-;,,:tl..,~...'.. / :'" Lake .... . "~V/~-': , - ." ::, ;"..' . :,ij(~":"'"" :- .' '~"'" ø-J" ' - ---- -- - --=---- - -- -:.~'--' -- ,-,~-.W, ,,;~'_.: -\~:r,-- ,-",,-,;~" ""; ,- - - - --- , " !~;--""'--: . 7/ " ,,' ,,{, ", \ ,- - -, ,- -- -- ¡,~ ; '", \ 3';" \ , f" .. ,;:. - . '" ~~'~?:¿(è;,~".:~ \ , u;;~, \. : NO 63~, " ----~",-'""-' -\.. --" ,..' :2 , ..' ~ ' \ 'I .r . ::,¡ .. ..,{.. . ,~"'" - - - ~nd.ng -, ' StriP * Ic" SCALE Jh:~:-;(-,(' ," ¡ " " . Mil!.' c::.;..:...'-,- ..~...:. ,0 ~"-:J-~====---', --:::=:::"'_,-'¡:;---~ ---~=-:.'..':~.:::...--:-::--,==-~:::::::::.,,~:~~...:....:.::.~...::..::.-==--....:....:::"'-:,:::::,,:::::"" ;«):: r, ~o:,,) lf~-,ï. 900(1 170<.\ :5C\X1 1800" ~¡C-vj fU: ~':::¡:=--'--!' "::=-:-:.l."::'::::::::-=--, -.r:=:...... --==':'-:-,! '-=-:'--"":::==:-,',--':"-0"':::=:"..',:-:-=:::'-.... ;'::~:'L,_-'-;::::::;-"--.:.,:_::-:-::;¡=--=:'--'~::"¡ , I' " ~,r_(\"I[Tr"" =r:::",T.:..-,=:'-=i=:.",--=-"""~="'1-::'_.."'- "':""'::F""'":..__:'-:-=- :_--'--=-'-:--- ,-=::---- ".!:.,:::.,-::,~==:-' ----_._, , , , "^ ( " ',: ' ¡'~6' : 26 "Il~ :, ¡: '. ~6 ~1:i ' 1'",r."",AI,D!9!!"""'-"""';"""'" f>fCIJNAI,()~.l;;"""',J".'.'" CON10UR IN1ERVAL 50 FEll DOTlED LINE'S REPRESfN1 l5,FOO1 CONTOURS NATIONAL GEODETIC VERTICAL D^TlIM Of 1929 Df.P1H ClJRVFS IN rEfT'D.a.1lJM IS MEA'I lOW::R LOW WA"rR ~'({)RrUl¡~ ~HO"'II RlPRE:;!'H" lHr ""'";{lIXI""'lt lINE 01 ME'~ hlroH WAil' 1 "F ~Vf ~A(;~ ":.Nia ()I 1I!)~ I~ AI"'I'"X"""'I Ll Y 17 Fl, '-: KENAI (8-4) QUADRANGLE ALASKA-KENAI PENNISJU, BOROUGI~ 1:63::m SERIES (TOPOGRAPHIC) Marathon Oil Company Project: KU 24-5 Form 3160-3 (July 1992) II SUBMIT IN TRIPLICATE* UNiTt 3T A TES (Other Instructlors on DEPARTMENT OF THE INTERIOR d ) ( FORM APPROVED OMB NO. 1004-0136 raverse $I e pires: ruery . 199 BUREAU OF LAND MANAGEMENT 5. Lease Designation and Serial No. A-028142 APPLICA TION FOR PERMIT TO DRILL OR DEEPEN 6. If Indian, Allottee or Tribe Name 1a. TYPE OF WORK D ~ DRILL DEEPEN ~ Un~AgÆementName b. TYPE OFWELL Kenai Unit I Sterling Oil Gas Single Multiple 8. Farm or Lease Name, Well No. Well D Well ŒJ Other Zone D Zone ŒJ KU 24-5s 2. Name of Operator 9. API Well No. Marathon Oil Company 50-133-20358 3. Address and Telephone No. 10. Field and Pool, or Wildcat P. O. Box 196168, Anchorage AK 99519-6168 907-561-5311 Kenai Gas Field, Pool 4 4. Location of Well (Report location clearly and in accordance with any State requirements:) 11. Sec., T., R., M., or BLK. and Surveyor Area At surface 332' FNL,4331' FVVL,Sec.7, T4N, R11W, S.M. T4N, R11W, S.M. At proposed prod. zone 514'FVVL, 734' FSL,Sec. 5,T4N, R11W,S.M. 12. County or Parish 13. State Kenai Peninsula Alaska Ex' Feb 28 5 14. Distance in Miles and Direction from Nearest Town or Post Office" 6.5 Mile South of Kenai, Alaska 15. Distance from Proposed" 16. No. of Acres in Lease 17. No. of Acres Assigned Location to Nearest Unit Boundary to this Well Property or Lease Une, ft. 2800' 6000 (Also to nearest drig. unit line, if any) 18. Distance from Proposed Location" 19. Proposed Depth 20. Rotary or Cable Tools to Nearest Well, Drilling, Completed, or Applied for, on this Lease, Ft. 1600' 4608' Rotary 21, Elevations (Show whether DF, RT, GR, etc,) 22. Approx. Date Work Will Start" 87' RKB . MSL (original well 94') All depths below reflect original KB elevation. 8/10/2001 23. PROPOSED CASING AND CEMENT PROGRAM SIZE OF HOLE GRADE, SIZE OF CASING WEIGHT PER FOOT SETIING DEPTH QUANTITY OF CEMENT Driven H-40 20" 94 136' In Place. Driven 171/2" K-55 133/8" 61 2012'MD/1861 'TVD In Place w/1500 sxs 12 1/4" N-80 9 5'8" 47 4450'MD/3801 'TVD In Place WI 700 sxs 8 1/2" L-BO 7" 26 4608'MD/4050'TVD 200 SX Kenai Unit well KU 24-5 will be plugged back to 3500' MD and sidetracked. KU 24-5rd will be directionally drilled to an estimated total depth of 4608' MD, 4050' TVD from the existing Kenai Gas Field pad 41-7.The production interval will be cased with 7", cemented in place as a production liner. 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. Note: Attached directional plan has depths adjusted for new KB elev. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen, give data on present productive zone and proposed new productive zona. If proposal is to drill or deepen directionaJly, give pertinent data on subsuriace locations and measured and true vertical depths. Give blowout preventer program, if any. SIGNED P. K. Berf: . (This space for Federal or State office use TITLE Drilling Superintendent . ':2 /J DATE I ~ t. ~t)/ PERMIT NO. APPROVAL DATE Application approval does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon. CONDITIONS OF APPROVAL, IF ANY: OSee Instruction on Reverse Side Title 18 U.S.C. Section 1001. makes It a Cllme for aIlY person knowingly ana willfully to make to any department or agency 01 the United States any false. fictitious or fraudulent statement representations as to any mœ1er wl1hin its jurisdiction. O:\EXCEL\BLMAPPl.XLS ( Marathon Oil Company Alaska Region ( Prepareâ By: Approveâ By: Date: T ..r:... Laylock 07-11-01 Drilling Program f¡Jell: KU 24-Srd AFE: To be determined Area: Kenai Gas Field Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No.1 Geologic Program Depth Target Locations FNL FWL Block MD TVD Tolerance Surface 332' 4331' Sec, "7 T4N, RJ..1W, S.M. 21' 21'OKB ! ¡ I ( 2 8 ' OKB ) ( 2 8 ' OKB) Sterling Bl 1071' 1463' Coordinates from 4371'OKB 3824'OKB 250' North East Wellhead Bottom Hole 1100' 1530' Coordinates from 460B'OKB 4050'OKB North East Wellhead Note: Preliminary directional plan does not intersect target center. OKB=Original Kelly Bushing RKB Elevation: RKB to MSL=87' (original hole/well 94') All data herein reflects original KBi except that attached directional program considers new KB elevation for GDR #1. GL-MSL=65,68' Total Depth: TVD 4050' MD 4608' Avg. Angle 20 Course 34 Abnormal Pressures: Subnormal Pressures: 250 psi to 1000 psi in Sterling Sands Coring and DST's: Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection, 10' samples to TD Logging Program: Contractor To be determined LWD Wireline Logs Surface NA Production NA GR/AIT/DSI/NGT KU 24-5rd Drilling Program Page 1 of 7 Drilling Program Summary production: The exisLing wellbore will have been plugged back to <= 4500' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at 13500' MD. Test plug and casing to 2500 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside for casing exit. Cut window and ensure all mills are worked thr~ window. CBU. Test shoe to leakoff (15.5 PPG anticipated). Drill a 8 1/20 hole to 4608' MD/ 4050' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 70 production liner and cement per the attached program. Proceed with completion program. Casing Program API Values Casing I Casing I Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (psi) (psi) (K lbs) (MD) 9 5/80 0' 3500' 47.0 N-80 BTC 12 1/4" 6870 4750 1086 70 3250' I 4603' I 23 or L-80 I LTC or 8 1/20 6340 3830 532 I I 26.0 BTC , 7240 5410 604 Note: The 9-5/8" casing is already installed. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8" 47 N-80 3054' 15.5 9.0 1043 2.6 3.6 NA 7" 23 or 26 L-80 4050' 9.0 1490 1.5 2.0 3.0 KU 24-5rd Drilling Program Page 2 of 7 (' ( Directional Program Directional Co: 3aker Hughes Inteq KOP: 3500 Direction: 33 Gyro Co: To be àetermined Dog Leg: 3.0 To: 17.1 deg @ 3756' TVD Hold Depth: 4608 MD/ 4050 TVD Hold Angle: 17.1 Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below drive pipe General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas, The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas, 9 5/8" Intermediate Casing @ 3054' TVD MASP = ((PP * ,052 * TVDtd) - MASP = (9,0 * 0,052 * 4050) - MASP = 1043 psi (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) (0,3 .... 0,052 I< 9.0 .... 4050) - (0,7 * 0.1 * 4050)) 7" production ~iner @ 4050' TVD* MASP = PP * 0.052 * TVDf - (GG * TVDf) MASP = 9.0 * 0,052 .... 4050' - (0,1 .... 4050') MASP = 1490 psi *This will also be the new MASP for the 9-5/8" casing as production, Cementing Program Contractor: BJ Services Production Casing Size: 7" Setting Depth: 4608' MD/ 4050' TVD Annular Volume to 3500' with 8 1/2" gauge hole: 140 ft3 Tail Slurry: Top of Cement: Specifications: Density: 15,8 ppg, Yield: 3250'MD/ 2857' TVD Class G + additives Mixed w/ fresh water sx, cf: 230 ft3 1,15 ft3/sx, Sx: 200 Compress Strgth: 500 psi in 6 hrs, 3600 psi in 24 hrs Total Volume: 230 ft3, ~% Open Hole Excess, WOC Time:~ hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions, KU 24-5rd Drilling Program Page 3 of 7 Diverter and BOP Program The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with plpe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) 1043 1500 (1) 13-5/8" 5M Annular 250/3000 Intermediate 9 5/8" (9.2 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 2500 (1) 13-5/8" 5M Annular 250/3000 production 7" 1490 (10.0 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) Casing Test Pressure Calculations Casing test pressures are based on the lesse~ of (1) MASP, or (2) 70% of rated burst pressure of the caslng adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 95/B" Intermediate Casing at CTPMASP = 1043 psi CTPBurst = 6870 * 0.7 - Test to 1500 psi 3054' TVD ((9.0-8.3) * 0.05::? * 3054) = 4697 psi 7" Production Liner (and 9-5/8" Casing) at 40501 TVD CTPMASP = 1490 psi Test to 2500 psi CTPBurst = 7240 * 0.7 - ((9.0-8.3) * 0.052 * 4050) = 4920 psi KU 24-5rd Drilling Program Page 4 of 7 "i' , :,1 ~I. Mud Program Contractor: MI Drilling Fluids Interval iTVD) ! Mud Weight From To (ppg) Water Loss Mud Type 3054' 4050' 8.7 - 9.0 <8 Flo Pro/KCl Wellhead Program Manufacturer Vetco Model Annular Flow Tubing Head 11" 3M Xli" 3M wi 2-1/16" 5M flanged outlet & 7-1/16" 3M flngd outlet Tubing Hanger 11" x 3-1/2 Mandrel Tubing hanger Detailed Drilling Procedure Formation Leakoff Test Surface and Zntermediate casing shoes will be tested to Leak-off, Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section, Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out, 2, Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3, Begin slowly pumping fluid down the drill string at 1/2 bpm drillpipe pressures at 1/2 bbl intervals. A running plot of kept by the drilling foreman while the test is in progress, 4, Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports, ~, Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes, while recording casing and pressure versus volume should be Bit program The following guidelines are recommended for use on this well, Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 3500' - 4608' 8 1/2" XR15TDGPS 447X 15/35 200 KU 24-5rd Drill~~g Program Page 5 of 7 --,. _. - - . Drill String S-135, 3 1/2" IF I HT 38 24,4 12000-13200 ft.-lbs. 13,500-19,800 ft.-lbs. 29,000 ft,-lbs. Max Pull - I Premium I I 248,400 Ibs. Item Ppf Makeup Torque 3 1/2" HWDP, 4" , 15.53 403,500 Ibs, 5" HWDP, 41/2" IF 49.3/53.6 543,000 Ibs. Hydraulics Program Rig mud pumps available are shown below. Install 5 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oilwell A 600 PT 4 1/:" 811 3207 1.6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 Oilwell A 600 PT 5 7':" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (psi) (fpm) (ppg) (32"s) Remarks 4608' 8 1/2" 390 2200 - 175 9.5 14,14,14 Motor Drilling I 2400 Note: 5" liners are recommended. KU 24-5rd Drilling Program Page 6 of 7 'Ii' i{ (' OPERAT~ONAL PROCEDURE 1. MIRU the drilling rig. Install 13 5/8" 5M X II" 3M DSA, program. Record test on IADC book. Set wear bushing. NU 13-5/8", 5M BOP system. Test as per :J . Abandon existing perforations according to program filed with AOGCC. RIHand set CIBP at +1- 3500' md, Test plug and casing to 1500 psi. MU and RIH with bottom trip whipstock and MWD, Set whipstock for 45 degrees left of highside casing exit. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 15,5 ppg anticipated), Drill a 8-1/2" hole to 4608' MDI 4050' TVD per the attached directional program, Backream each stand. Lost circulation is possible throughout this interval, Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. 2. 3. 4. 6, At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe, TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH, laying down 5" HWDP. Run log~ as per geology requirements, Pull wear bushing, Locate casing swage and safety valve. Function safety valve and place on rig floor, Record function test in IADC book, RU and run 7" casing liner, Cement casing as per the attached cementing program, Ensure circulation of cement to above top of liner. 7. 8. 9, 10. Pullout of liner hanger and circulate cement clean, Pullout of hole with setting tool. Clean out liner, Test casing, liner and liner lap to 2500 ps~. 11. Prepare for completion, A separate completion procedure will be developed. KU 24-5rd Drilling Program Page 7 of 7 Ù"""~d by bmoCho," For: P Berga ! StrucTure: Pod 41 - 7 Oil (~ornpanYi I I I i Location: Kenai Peninsula. Alasko: _.! Well: KU24-5Ro - - - fã&. \ I .r~ \ f ~~~ ~ i u r. r; ';'H.!OM Ë ~ t'l'!~ñ.~! 11 !~::: ~ ~ ~- --_.".._..~ iMARATl-ION Dole plotted: 12-Jul-2001 Plot R.I.."no. is KU24-5Rd V.rslon#4 Field: Kenai Gas Field ,coordIOotes ore on ,..." relerence slot ~KU2"-5X.: "rup Verl'c.ol Depths ore ,elerenoe wellheod. I i !!.!.IŒ= ~~ "'jHi ,---- WELL PROFILE DATA ---- ¡ Point ----.- i ¡Tie on I lEnd of Build/Turn MO lac Drr NO North Eost V. Sect , , Deg/10O¡ , 3493.00 38.00 54.93 3047.27 896.90 1207.2:' 1503.42 0.00 ! 3513.00 38.86 53.58 3062.94 904.16 1217.33 1515.84 6,00 i I i I lEnd ot Drop/Turn i iT.O. & End of Hold 4363.28 15.09 30.67 3817,00 1162.00 1493.00 1891.89 3.00 : 4597.3:, 15.09 30.67 4043.00 1214 42 1524.09 1948.71 0.00 ; East (feet) -> 51,87 AZIMUTH 1892' (TO TARGET) 1100 120C 1.300 1400 150: 1600 170:' 1800 3000 I : KOP ~ / I 1:,DU ~ /"'-.... r 1400 ./ ì! ,./ ~/I ~/ 1300 ...honE' of Proposal... ,/'\" /Tv-, \ . .. , . , \ \ v-t ) '\~ 3400 .30:)4 ':", \' 27,67 \\' \ \ 24,8':; \ DLS: 3.00 deg oer 100 f\ / / T~. f'OgO 81 Tocget-ED:1 / // I ~// J ,/~,/ . Y'. / /KOP ~-----_// 1200 1\ I z 0 , -+ ::J 38.30 '\ 3100 3200 363:~ \' 1100 ~ -+, CD CD ~ '-../ Target-EOC \ 22.06 \ 19.33 \ 16.69 \ \ \ \ \ LTD ~ /"-r ./ //' ".6 r \," ," ) 1." / .J,.\J ,/ \,// i f- 1000 I I ~ 1900 l L 800 ~ ...- (!) (!) 3300 '+- '-../ L - Q.. OJ 0 3500 J 0 0 3600 ...- L Q) > 3700 Q) :J I- r- I V I 3800 ~ I Sterling l , , , , , 3900 \, 4000 , , , , \ 4100 J I I I l 4200 I '~ <;:0 vis,:. \. U 1400 1S00 1600 '700 1800 1900 2000 2100 2200 2300 2400 Vertical Section (feet) -> å7iml,th 1:); R7 with rl'!f"'r~;I" n nn N n nn :" frnm c::Jílt .tiKI 1).1-1:)'1 t (' MARATHON oil Company Pad 41-7 KU24-5Rd slot tKU24-5X Kenai Gas Field Kenai Peninsula, Alaska PROPOSAL LIS TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd Version~4 Our ref: prop4790 License: Date printed: l2-Jul-2001 Date created: lO-Jul-2001 Last revised: l2-Jul-2001 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 30.878,w151 14 42.563 Slot Grid coordinates are N 2361663.250, E 275233.476 Slot local coordinates are 323.35 S 4332.39 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North y,AR1'.'!'!!~~: c:.:.: Comp,,:~" Pad 41-7,KU24-5Rå Kenai Gas Field,Kena~ Peninsula, Alaskõ Measured Inclin Dep~h Deç¡rees 3493.00 3500.00 3513.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4363.28 4500.00 4597.35 38.0 C' 38.30 38.86 36.32 33.42 30.54 27.67 24.84 22.06 19.33 16.69 15.09 15.09 15.09 Azimuth Dearees True Vert Dep,.:. R E eTA N G U LA R con R r : ~ A T £ S 896.90!; 6 9 9 . 40!, 904.161'1 936.04N 971.321' 1005.05N 1037.14N 1067.511'1 1096.06N 1122.721' 1147.42N 1162. OON 1192.62N 1214.42N 1207.25£ 1210.77E 1217.33£ 1259.75£ 1304.73£ 1345.55£ 1382.08£ 1414.25£ 1441.95£ 1465.11£ 1483.66£ 1493.00E 1511.16£ 1524.09£ Dogleg Deg/100f,. PRO?O:;;.:. LIST}::;', ,'ae¡,,; Your ref: KU24-5Rd Version#4 Last revised: 12-Jul-2001 0.00 6.00 6.00 3.00 3.00 1503.42 1507.74 1515.84 1568.89 1626.05 Vert Sect G RID Eastu:',: coo R D S Northin'] 2362536.68 2362539.11 2362543.75 2362514.80 2362609.20 2362642.14 2362613.52 2362703.26 2362731.27 2362157.48 2362781. 82 2362796.22 2362826.48 2362848.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coord~nates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 1948.76 on azimuth 51.45 degrees from wellhead. Total Dogleg for wellpath is 26.73 degrees. Vert"cal sect~on is from wellhead on azimuth 51.87 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 54.93 54.4:, 53.58 52.54 5::'.10 3047.:' 3052.77 3062.94 3l3l.87 3213.9: 49.60 47.7:, 45.46 42.65 39.08 3298.7'0 3386.09 3475.77 3567.5C 3661. 04 34. G:: 30.67 30.67 30.67 3756.14 3817.00 3949.01 4043.00 3.00 3.00 3.00 3.00 3.00 16ìB.99 1727.54 1771.59 1811.01 1845.69 3.00 3.00 0.00 0.00 1875.53 1891.89 1925.07 1948.71 276457.73 276461. 31 276467.96 276510.98 276556.6J 276598.09 276635.23 276667.97 276696.22 276719.89 276738.91 276748.53 276767.27 276780.62 ~. ~~RATHON Oil Company ?ad 4l-7,KU24-5Rd Kenai Gas Field,Kenai Peninsula, Alaska MD TVD Rectangular Coords. ( ?ROPOSAL LISTING ?age 2 Your ref: KU24-5Rd Version"4 Last revised: l2-Jul-200l Comments in wellpath -------------------- -------------------- Comment 3493.00 4363.28 4597.35 ----------------------------------------------------------------------------------------------------------- Target name 3047.27 3817.00 4043.00 896.90N 1162. OON 1214.42N 1207.25E 1493. OOE lS24.09E KOP Sterling Bl Target-EOC 'l'D Geographic Location Targets associated with this wellpath T.V.D. Rectangular Coordinates ------------------------------------- ------------------------------------- Revised ----------------------------------------------------------------------------------------------------------- 10-Jul-200l Sterling Bl tgt - 11 J 3817.00 1071. OON 1463.00E MARATHON Oil Company Pad 41-7 KU24-5Rd slot #KU24.-:,X Kenai Gas Field Kenai Peninsula, Alaska PRO P~S A L L ! S TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd Version#4 Our ref: prop4790 License: Date pr~nted : 12 Jul-2001 Date created: lO-Jul-2001 Last revised: 12-Jul-2001 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centreà on 270908.300,2362070.01C,999.00000,N Slot location is n60 27 30.878,w151 14 42.563 Slot Grià coordinaces are N 2361663.250, E 275233.476 Slot local coordinates are 323.35 S 4332.39 B Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ,tf :-'.ARATHON Oil Company PROPOSAL LISTING ?age 1 ?ad 41-7.KU24-5Rd Your ref : KU24-5Rd Versioni4 Kena1. Gas F1.eld.Kenai Peninsula. Alaska Las1: revised : ¡;¡-Jul-2001 :-!easured Incli=-.. Azimu1:h True Vert R E C TAN G U LA R Dogleg Vert Depth Degrees Degrees Depth COO R DIN A T E S Deg/100ft Sect 3493.00 :.8.~0 54.93 3047.27 896.90 N 1207.25 E 0.00 1503.42 KOP 3500.00 38.30 54.45 3052.77 899.40 N 1210.77 E 6.00 1507.74 3513.00 38.86 53.58 3062.94 904.16 N 1217.33 E 6.00 1515.84 3600.00 36.32 52.54 3131. 87 936.04 N 1259.75 E 3.00 1568.89 3700.00 33.42 51.19 3213.91 971.32 N 1304.73 E 3.00 1626.05 3800.00 30.54 49.60 3298.73 1005.05 N 1345.55 E 3.00 1678.99 3900.00 27.67 47.73 3386.09 1037.14 N 1382.08 E 3.00 1727.54 4000.00 24.84 45.46 3475.77 1067.51 N 1414.25 E 3.00 1771.59 4100.00 22.06 42.65 3567.50 1096.06 N 1441.95 E 3.00 1811. 01 4200.00 19.33 39.08 3661. 04 1122.72 N 1465.11 E 3.00 1845.69 4300.00 16.69 34.42 3756.14 1147.42 N 1483.66 E 3.00 1875.53 4363.28 15.09 30.67 3817.00 1162.00 N 1493.00 E 3.00 1891. 89 Sterling Bl Target:-EOC 4500.00 15.09 30.67 3949.01 1192.62 N 1511.16 E 0.00 1925.07 4597.35 15.09 30.67 4043.00 1214.42 N 1524.09 E 0.00 1948.71 TD All data is in feet unless otherwise stated. Çoordinates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 1948.76 on azimut:h 51.45' degrees trom wellhead. Total Dogleg for wellpath is 26.73 degrees. Vertical section is from wellhead on azimut:h 51.87 degrees. Calculation uses the minimum curvature met:hod. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KU24-5Rd Kenai Gas Field,Kenai Peninsula, A1ask~ MD TVD Rectangular Coorà~. PROPOSAL LISTING Page 2 Your ref: KU24-5Rd Version~4 Last revised: 12-Ju1-2001 Comments in we1lpath -------------------- -------------------- Comment 3493.00 4363.28 4597.35 ----------------------------------------------------------------------------------------------------------- KOP Sterling B1 Target-EOC TD Target name 3047.27 3817.0C 4043.0[: 896.90 N 1162.00 ¡, 1214.42 r-; 1207.25 E 1493.00 E 1524.09 E Geographic Location TargetS associated with this wellpath Revised ------------------------------------- ------------------------------------- T.V.D. Rectangular Coordinates ----------------------------------------------------------------------------------------------------------- Sterling Bl tgt - 11 J 3817.00 1071. OON 1463.00E 10-Ju1-200l { Il SURFACE USE PLAN FOR KENAI UNIT KU 24-5rd Surface Location: SW 1/4 of SE 1/4, Sec. 7, T4N, R11 W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KU 24-5 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 KU 24-5. 3. Location of Existing Wells Well KU 24-5 will be sidetracked from an existing well on pad 41-7. A pad drawing is attached that shows existing wells and the location for KU 24-5. 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 may be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud, 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class" disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). E:\Documents and Settings\nz6\My Documents\ku24X-5\SURFUSE.doc Surface Use Plan Kenai Unit KU 24-5rd Page 2 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. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose, Bottled water will be used for human consumption, Potable water will be obtained from the existing water well on the pad, Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary, 9. Plans for Reclamation of the Surface Kenai Unit KU 24-5 will be drilled from an existing pad, Reclamation of the pad will occur after abandonment of KU 24-5 and the other existing wells on the pad, Approval of the plan of reclamation will be obtained from GIRl Native Corporation prior to any reclamation work beginning, 10. Surface Ownership The surface owner of the land in the Kenai Unit is the GIRl Native Corporation, Surface Use Plan Kenai Unit KU 24-5rd Page 3 11. ( t 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: I '3 M ';;¿,f)() / Name & Title: I}J{ /tJ¿aat1h Ûd-~;'/ ì;~ ~/..o I. Marathon Oil Company / r P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 Marathon Oil Well KU 24-5rd Choke Manifold ~::::I ~ ffi0I[] '\ 0 [II@]] t 13" 5M Valves I 29/16" 10M Swaco I Hydraulically Operated Choke 1 3 1/8" 5M Manually Adjustable Choke ~~ []I@]][]I@]] ¡Flow Nipple I 13 5/811 5M Annular Preventer 13 5/811 5M Double Ram Preventer 3 1/811 5M Manually Operated Valves 1135/811 5M Cross I 13 5/8" 5M Single Ram Preventer ( {, Marathon Oil Well KU 24-5rd BOP Stack -- I Flow Line I I ~ I Î ~ '" / '" r I I I /' I Pipe Ram I I I ¡Blind Ram I I ...... ~ ..... I I Î ...... ,... I Kill I I Choke II ~I~ I Î 7 I I Pipe.Ram I /' '" ..... Î I ..... -/ \ I ~ 3 1/8" 5M Hydraulically Operated Valve ,¡ IT10I1l1I0I1J t 3 1/8" 5M Manually Operated Valve ~ :Y WOHK POlt¡ r /. ~,8i2.713 61,757.248 / REBAR) ~- 5 -- -- IIII ~(::~? ~';:','¡":: ':";:';~:'~; ~~~;1:;~f , "~"". ~jmt !f:'?i. "" \ WELL HOUSE X:275,073-2L Y=2,361,844-31 WASTE WATER , BLDG. 6 -t- OVERHEAD CONDUIT 2-4" ø PIPES STORAGE BLDG. 5 INSULA TED PIPING -or 0 'V 6" ø PIPE GOES UNDERGROlJNO 8" ø PIPE DEAD ENDS O.H.E. ". .; . ~'. "" " \ \, " \ / SEE DETAIL ~ _...J I \ \1 I I I I I I I I J~ 10 4" ø OH PIPE 0 I m / . ~ O.H E. 242' PAD LIMITS METER BLDG. 1 (',I '<t K.U, 13-5 ~t 142' WELL HOUSE X=275,O63.53 Y=2..361.775,96 Q K.U. 43-6X -~ I I ) 10' II WEll HOUSE WITH 17'X17' PIPE GUARD X=275,133.33 +Y=2,361,787.18 \@ K.U. 43-6 0 K.D,U. NO.4 X=275,108.77 Y=2..361,743.64 Iv 65'> ~~' S '6'" 66 '1~' -+- @ K,U, 43-7 10' ø i't'ELL HOUSE X=275.1.30,59 Y= 2.361.596.60 ELECTRIC PANEL r - FOR DRILUNG -l- OPERA TrONS G 0 0 0 0 X=275. 201 ,30 Y=2,361,BOB.64 K.U. +1-7 K.U. 43-6A 0 . X-275,189.9B Y=2,.361,721.01 X=275,179.48 Y=2,361,661.55 0 K.D.U. NO.2 K.U. 24-5 a r:--J WELL HOUSE ~ ~ X=275,23.3.476 Y=2361,66325 16.0' , , /10' Ð WELL HOUSE ~. 0 X-275,167.14 Y=2,361,621 ,14 .U. 11-8 .. i \ \ O'J I .- '<t 0 I- - - - OJ JUNCTION BOX wI GUARD PIPE ~ 0 0 0 0 I") Y = 2,361,800.00 P AD LIMITS \. ~ 2-.3"Ø FLARE PIPES 2-2"- FLARE PIPES .. Y = 2,361,600.00 ~ 1) [I"ation, 01 thc lep 01 "'PC ler n,",'" ,,-..¡ .~¡¡, ""« le'cr. .ith eo,er off or opcn 2) R"",ne. dalum ¡. ",co" ..0 I..c'- C QQ' lor .' ,ho~n '" """\\'" ",,"~~.(?f..o\(..¡ "~I .. ".'".... ..-b....s'L " :",..' ~ ':.<yl ~~1.;;~~*% ~"\'w'. ~¿¡;nw~", i:: ~ ~ ... <""-5 ' .!' : I,~ ,~........... ".. 1'1 ~;:.;- f'..,$' . ",\\."", 3) Ail blorings ore g'¡d u"I", noto. ""'",wi" 4) 8a,i, 01 Coord",o!" i. u s.c. .. G 5 I" "utio", ""û~Y ". A.S.P, Zona <. (NAD 27) "',.,o c <","C"OOe' ,.1 po OlJ ,hOn'" -01'05'03' . 5) AUORY location, Lot: 60'JO'50.559." Long' 15116'37445"W X~269.ê66.75 Y=2.J62,0<5.<2 6)T.8JJ.61-31-'è'i"""LP~ G5j,!,"o«.- .coo,",S, McLANE CQ/,SUL TING CROUP ="", .o.u.'"' ..... ('0') 11)-<2'1 HE OF S>JAV¡:Y'1I/21/" HI, DU!: 8Y APP. <E'" """ , - NO, 1\:,(, U:i, ~ RQ.Æ:CT '°, ISm, Marathon RAw+<: NO., ""DUal Oil Company CAe!: ,'-~' Alaüo R'"on . ..... 8r. <AA . '""'""" APPROu",- KENAI GAS fiELD PAD AS-BuILT SURVEY ¡¡y ". "O;(eT S1IlUCT. KENAI GAS FIELD PAD 41-7 PROC", we""... nrel. seOJ..( IDv,,¡..... OHr 'lU/" fU: tfQ IT'r1t"e¡ wo-o 1"'5cl SYSI I D'C HO rHT Nol " liSIR"w 'CH.D., -= DATE ARC>< ".so'I....."...-."..",' U-I 5 0 00 J 00 0001 , . , . < .,. ( KENAI GAS FIELD DIAGRAMMATIC CROSS SECTION 14-6 Pad 41-7 Pad A KU 24-ðrd West - 10 ODD' HM4084 ( + L.1 T5N-R~W KDU-7 X , . 1..- [j , UNIT ¡BOUNDARY. .-1 / .....1 . -J.... I ~11 . LI- . I . I -R11W A' ..... I.U -,J, :e , + . I . ..... . I . I r-" + . ~. 0 0 0 . I 1-.. I 'I -'I . ~._I~ + I Structure Map -- C::terlina Fro. B4 sand 0 ë.l. : 100' 1 I I . -I_I MILE MARATHON OIL COMPANY ALASKA REGION KU 24-5rd Location KENAI GAS FIELD COOK INLET. ALASKA July 200. 0: \freehand\ku24-5Ioc. fh 7 . I~ i: I' " Attachment 1 Marathon Oil Company Kenai Gas Field, Pad 41-7 Well KU 24-5, Request for Temporary Waste Storage 18 AAC 60.430(a) 1. Stora2e Plan A. Responsible Parties Involved With Drilling Activity Peter K. Berga Rowland Lawson Jerry Lorenzen J. Gary Eller Ralph J. Affinito Denise Titus 564-6319 283-1312 283-1312 564-6315 564-6303 564-6317 MOC, Drilling Superintendent Contract Foreman Contract Foreman MOC, Operations Engineer MOC, Operations Engineer MOC, Operations Engineer B. Storage Containers Steel leak-proof tanks will be used for the storage of the solids and fluids generated during drilling operations. The steel tanks will be placed upon 20-mil synthetic Novathene liner material that is underlain by a felt liner. The tanks are constructed from steel plate that is at least one-quarter inch in thickness and will be located adj acent to the drilling rig. The liner will be supported by 6-inch boards on the perimeter that will act to prevent a release onto the liner from escaping to the drilling pad C, Not applicable. D. The steel tanks will be inspected and monitored for leakage during use. The liner under the tanks will provide secondary containment and will act to prevent the escape of fluid onto the pad in the event of a release. E. The location for the final disposal of the drilling waste will be at the Kenai Gas Field, Pad 41-18, where a permitted Class II well is in operation. A second option will be for the disposal of any exempt, clear fluids, into WD-I a Class II well at KGF Pad 34-31. F. Marathon is requesting approval for the one-year storage time that will commence when the waste is first generated by drilling. Drilling waste is usually disposed via injection either concurrent with drilling operations or within 90 days after placed into the storage facility at Pad 41-18. G. Marathon certifies that all drilling wastes will be removed from the drilling location within a one-year time frame after completion of the wells listed above. Written notification will be provided to the ADEC after the waste has been injected. 2. Containment Structures A. The covered steel tanks will be sized to allow the storage for all drilling waste and liquids. Marathon is requesting a waiver for I-foot of freeboard instead of the standard 2-feet. This will permit greater use of the tanks and minimize the operational footprint. B. The steel tanks are designed to be leakproof. C. The Novathene synthetic liner material is hydrocarbon resistant. Drilling fluids used to develop the drilling mud are composed of inert materials that will not degrade the liner if spilled. D. Marathon's plan satisfies section 18 AAC 60.430(c)(7)(A), The Novathene synthetic liner is 20 mil thick and is impermeable to fluid spills, including hydrocarbons. Prior to laying down the upper liner. a base of felt is placed on the pad to provide a cushion and reduce the potential for puncture. When the Novathene is placed on top of the felt all seams are welded. creating a continuous impermeable layer over the operational area. Elevated berms around the perimeter are constructed to act as additional containment and prevent fluid loss if a spill occurs. 3. Removal of Drillin~ Waste A. A visual site inspection will occur after all drilling waste has been removed from the location. B. Written notification will be provided to the ADEC within seven days of the final inspection, Marathon documents the transfer for each shipment of drilling waste with an Intercompany Waste Manifest (IWM). Waste transfers may not be initiated, nor accepted, unless accompanied by an IWM that has been approved, by a Marathon employee or authorized representative. All drilling wastes are transported via vacuum truck to Pad 41-18 for final storage and disposal. KU 24-5 Plug Back ( ,:( Subject: KU 24-5 Plug Back Date: Mon, 9 Jul 2001 16:00:08 ~O800 From: "Eynon, Donald E," <DEynon@MarathonOil.com> To: "Tom Maunder (E~mail)" <tom_maunder@admin,state,ak,us> Dear Tom; Enclosed please find the wellbore schematics for KU 24-5, one is post workover, and the other is proposed sidetrack. We hope to plug back with a clap and then kick off at 3500' MD to redrill to the B-1 perforations. After drilling to approximately 4608' MD we will then run and cement 7" casing from 3250' MD to 4608'. I would like to discuss this with you when you have time. «ku24-5sidetrack,xls» «ku24-5postWO.xts» Thanks, Don Eynon Production Engineer Intern Marathon Oil Company 907 -5,64~3Q2 work 907-268-7868 pager 907-529-0523 cell 907-344-0604 home "---- Name: ku24~5sidetrack.xls ~.-.}~. k 24-5 "d t k .1 Typ. e: Microsoft Excel Worksheet (application/vnd,ms~excel) -.".":. U SI e rac .X S E d" b 64 on nco Ing: age " Description:, ku24~5sidetrack,xls ---~ --- ---- Name: ku24~5postWO.xls ~-.:~ro,,: k 24-5 tWO I Type: Microsoft Excel Worksheet (application/vnd,ms-excel) ..". U pos ,x S E d" b 64 on nco Ing: sse . ' Description: ku24-5postWO,xls ~~--~~~ 1 of 1 10/12/01 6:40 AM .:. ~i Ï[:':' ..:::: "1 I', ;. " "" " , , - 0' .: :~ ~- ,-. ... :-, ! . ,-,"" - '.',' ,',' - :':':':':.:~':':': ':'I"".""1<t'\":~..t'(""~:"""",,,"t'~1"" ~,-::. '~,~,-"'-"',"-',,";:"~~"-~".~\'-" ,"~'-~""","~" ""i""""""" ,<1["..~"...",.~""::"':Ii..;...,<.'} ..,-,~.,..'1>.;'I:'..,1i:"I1.....,..,-",..., "',"'.>"~'....."-",.'-',J."'~"',,, " ' - ',""" ,...., "B 3 P rfs 4691 4731' DIL (08 04 1982 P'.~', ~..'-"" "~'" ',', ,:,:,:,:,:;:,:,:,:,:a:,:,..(" - e - - - ) ~~-,.~'.ï'Jì'~';,-',:~~'~~':'" """.""..,...." ......".",..,..,."." ,',' ....,.,.. "~~-"'~n-.-'\110"""" "...,- '... ""'~"'iI'.....,.,...-..,~..",;..!-"_....,, '".-!>', ':~ :~:~ ?~:~:??~:~ :\~~:~:~..~-"':':~:':;~:::-:'~'::~.~':;'.~.~~. ~ :::~:~'~:~_:~:~::',:~~ ~':::~~:- :.~::~:':: ~"'¡'~'~'~\~\', .:::~B-4 Perfs 4789-4864' DIL (08-04-1982) ¡:~~~~f~\~~:,~~;.~~,:i~ ,.11:';'.,.,.,., "'~'-'" ..."~- w",'w ,.... "...,' "...._, ""','" '" .....~..... ""..~,.,,' ""-'~"""-"'," ',...' ""1.".".".".' "'~'~ \,~--,-~,...~\,~..""-¿""..:,.,,,.~..~,¡:,...~.!;~.')t."" "",~"",',~r..,:!....."",<,,-,:..- :.if.¡o. .'¡ '.', ".,.,.,., ,',' ,B4Perfs48994909'DIL(S 'd) ,.."..:.->:'.r,-"':."""" ','. ..".".".".' , .... - - qz .',' ,,!- "~'-<~'~'.i.o,; ,:..-n,' " .,-"'-,,,..... .,~-' .....""'-"',...~. ,. .-c....-c..-c'.-c ,', ,~"""..~.,...,~......-~....,,...~.,,!'_..,...,....,~.u ,~_.~,.-:,¡,.".,,-.-,...--o,...,')'C :::: j.-:j.-:j.-:j.-:j.' :::?":o)b~.-.. '{o':i::,.f¡..~~.."',~' ::>f'~'!.'::'-" ;;J.",j.f:~.~ ~':~"').-""'~i;;',-t::-,,::,;-,\..:t~ -:-?':'. -.t'.;,,:"'~,", ','. .."."."."..' ,',' ~ [20" 94# H-40 Drive Pipe @ 136' j -1 13-3/8" 61# K-55 BTC @ 2õ1Yl Cmt'd w/1500 sks of Class G I , \..\S\ ~ I B-1 perfs sealed off with LCM I XA Sliding Sleeve @ 4587' ID 2.75" ' Baker Model 'D' pkr @ 460~ Drilled hard cement out of tubing from 4365 t, 4608 w/ CT prior to fishing job, left hard Cement @ 4608' ~75" 'X' Nipple @ 4633' w/Mule shoe tbg tail @ 4644' ~z C~me~t ~f B-3 & B-4 Perfs ~iII ~_4781' (Slickline) 08-27-1993 J If.ement Retainer @ 48~ ô 9-5/8" 47# N-80 BTC @ 5900' ] C~~'d w/1800 sks of Clas~~~ [!D @ 5900' I ::::::::;::::::::::: \.",/ KU 24-5, Pad 41-7 I Sidetrack Well bore I ~. ~, t . .. 0' ,"' " ',0 ~ '~ Ì'o ., . Well Name & Number: I KU 24-5 Lease: Kenai Gas Field County or Parish: Kenai, AK State/Prov, Alaska I Country: I 0 " ~- Drilled hard cement out of tubing from 4365 to 4608 wI ~~~~ CT prior to fishing job, left hard Cement @ 4608' :::::.:,:::.;,::::: :::I"~';'~ "",'t:~...'¡;,JI.i"".~~ ,;~l'o1.' ~~'~~-,\. (~,""...,~~'O(..._,>30:"" ,~,~ :'~.-;,'. ";'~,."'I:. "t' .. 1:"f,,' .;: ""'.',, 01(" I.."~.~õ!kt _'I'"'á .........."'1i":'.',".~.n",-:l~:. ."'.,'&."'4C...~~."il,..'.. ,_«0. ~.~;"..,..~. 'J-,~"":9>' :::::::::::::::::::":::~B-3 Perfs 4691-4731' DIL (08-04-1982) !-,'iI};'~-t}'.(~~x.i~:',: ,:::;:;:;;;=:=;:;:;: .:::~~,",J'1¡,.~W'.,;~-.;,~::.:-~:: '::'~"":~!'~~ \? "";;':.~~'~:,.. "~-,:1'l::~ ~~f<~t.t~~::::.;':~',:!.~~,':', :':':':':':.:':';': ':'1' "'~'~'~"',',~ .".H,""'.."'" ",'~ '~~-...."<.'" >..~' ""'--'.'.""""'~-"" ~""~'~'j",..-'t..::'I: .,,~ ", " i(i~..~-;j', '::; ~B-4 Perfs 4789-4864' DIL (08-04-1982) ~~\.~;;':~~i:~~.;~~:~~,).; ".".".".", "....- '~.-""'~'"'"- """.¡'~'~~~"-.U.' -"" '...,~.. ."';").':""'~'\~~"~':;-{':': ~4,~,~,--:".... ~,.:¡>-~. "".".".". .'. ~.\~À;!~,,¡t...~...:a<........-.:f~.-..,~~~.~,'(...,~¿'¡ L\_"I..t.~,~4...;~...".,~""'~ ",¡r;¡, ,~ .............. . ";\B 4 Perfs 4899 4909' Oil (Sqz'd) <T,..,~.\~ ~ '-""'~"'."" ,.".".".".' ::: ~, - - :¡'~,i;;1!!.::-::';;'-~"~"',~ ....."..."."...", . '~~",~...'" --.,.', "'~_..~ ~.' ~I'!o"-j """':v"::i o,,:'~~' 't!::' "~,,,"'~~""'~~~'-~"""""'~"'" ~.J' "..,..,.,,:;..,. ::::'::-¡iD;¡.",~J~¡;t~~~, .:~.,¡t.~~::-i'",",-","¡,n.0(.."'Õi'"j;x-~",~;",~;~!;",~,"'1i';:::-':'~'-"¡;~~:" .".".".".' .',' m ~_.. ",~ :::: ~ J ~~j~ "-' !,?o" 94# H-40 Drive Pipe @ 136' 13-3/8" 61# K-55 BTC @ 2012' Cmt'd w/1500 sks of Class G 3-1/2" 9,3# l-80 EUE 8rd tbg [2,813" 'X' Nipple @ 442O' I 1.71" Seating Nipple @ 4450' ~-3/8" WL re-entry guide @ 4453' B-1 perfs sealed off with LCM ~ Model'D' pkr @ 4607' , 2.75" 'X' Nipple @ 4633' w/Mule shoe tbg tail @ 4644' \;) I Sqz Cement of 8-3 & 8-4 Perfs . IFiII@ 4781' (Slickline) 08-27-1993 rcement Retainer @ 4886' I 9-5/8" 47# N-80 BTC @ 5900' Cmt'd w/1800 sks of Class G V' KU 24-5, Pad 41-7 1 Joint 3-1/2" 9,3# L-80 EUE 8rd tbg, Swedge to 2 3/8 tbg and 2 3/8 pup joint Top of fish at 4512', Blast joints with parts of Baker A-5 Dual packer alongside ::~ ~";?~rJ;$~~&Efl!:~;:' ~~fù!~1J~~ ;~1:~,~ ~~:~ '~. ;,~:.1.þ~.,' '-"'~~~1fm~~~-~".ì(';'L"~~~,~",;"","-f!.~i"!':f'9,.....,..<r\,,#~ .:0:' !l:;~'1I't:',{ ~:::~B-1 'Pe'rtS 449å~455J..Ólr (08-'04:"1982)' ~"'.'~'~%,i;;~~.~;, -::::~ " ~" ... '~;;""r~;:-1f~-"~~~4!:t~r~~::-?~~~¡?-r~ii:~::;.~i~~_~~;:,::.;~ '. , .,.¡~ -.'ï'~~~,,~"-,~,r ,L~:,~:t,. '-it. ,'. -,l:J'" '-'...., '~-.... .~ ~~: ~, ¡i~ ~~ -& ...~~~~~~~!j!iw.~itt.ij~~~~~r.~~~~;~; ~ (--~A Sliding Sleeve@4587' ID 2.7~" l . Well Name & Number: I KU 24-5 Lease: Kenai Gas Field County or Parish: Kenai, AK StatelProv. Alaska I Country: I D ( ~1f~1fŒ (ill~ ~~~~~~ :f ALAS IiA 0 IL AND GAS CONSERVAnONCO~SSION TONY KNOWLES, GOVERNOR 333 W. "fTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 P .K, Berga . Drilling Superintendent Marathon Oil Company PO Box 196168 Anchorage AK 99519 Re: Kenai Unit KU 24-5 Marathon Oil Company Permit No: 201-144 Sur Loc: 313' FNL,4331' FWL, See, 7, T4N, R11W, SM Btmhole Loc. 768' FSL, 581' FWL, Sec. 5, T4N, R11 W, SM Dear Mr. Berga: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting detenninations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kenai Unit KU 24-5. 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 may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ç¿~cer~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this13th day of September 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( f ~ ~ ') Marathon MARATHON Oil Company Alaska Region Domestic Production P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 July 12, 2001 Tom Maunder AOGCC 333 West 7th Ave, Anchorage, AK 99501 Dear Mr, Maunder: Attached is the Permit to Drill for Well Number KU 24 - 5rd, the accompanying Drilling Program summary, schematics and procedure, Please note that this well has been renamed because it is a sidetrack well. The previous well name was KU 24-5, If you would like any other information, please contact me at 564-6319 or pkberQ.ê.@marathonoil. com, Sincerely, I j MiM~ RECEIVED JUL 1 6 2001 ~ter K Berga Drilling Superintendent Alaska Oil & Gas Cons. Commission Anchorage Enclosure bjv ORIGINAL ( f g:\cmn\drlglsterllnglsu44-10\AOGCCPTD.XLW t . STATE OF ALASKA .ðI\1 W kc. ALASKA OIL AND GAS CONSERVATION COMMISSION q}\ 2101 ~'" PERMIT TO DRILL I,' 210 AAC 25,005 013 '7)/ Z-/ú / 1a. Type of Work DrillD Re-Entry[8] 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 313'FNL, 4331'FWL, Sec. 7, T4N, R11W, S.M. At top of Productive InteNal 734'FSL, 514'FWL, Sec. 5, T4N, R11W, S.M. At Total Depth 768'FSL, 581'FWL, Sec. 5, T4N, R11W, S.M. Re-D rill [8] DeepenD 1b. Type of well. ExploratoU Stratigraphic TesD SeNiceD Development Ga{8J Single Zone[8] 5. Datum Elevation (DF or KB) 10. Field and Pool I DF - MSL 87' (original 94') Kenai Gas Field/Sterling 6. Property Designation A-028142 Development OiD Multiple Zone[] 7. Unit or Property Name Kenai Unit 8. Well Number KU 24-5 Q.. \> 9. Approximate Spud Date 08/10/2001 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 12. Distance to Nearest Property Line(unit boundary 2800 feet 16. To be Completed for Deviated Well: Kickoff Depth 3500 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) 1600' feet 6000 4608' MD/4050' TVD feet Length MD 136 0' 2012 0' 4450 0' 2400' 3250 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2) 38 0 Maximum Surface 1490 pslg at Total Depth (TVD) Setting Depth Top Bottom TVD MD TVD 0' 51' 51' 0' 2012 1861 0' 3500 3054 2858 4608 4050 4050' Hole Casing Weight Driven 20" 94 17-1/2" 13-3/8" 61 12-1/4" 9-5/8" 47 8-1/2" 7" 26 Specifications Grade Coupling H-40 PE K-55 BTC N-80 BTC L-80 LTC Quantity of Cement . (iOyluding stage data) ,¡~l¥):¡Pfå:bér Driven 1:,~I;jl!Jffi\P;laê.øJW/ 1500 sacks /¡¡¡;~~, :\jÞ.lâaê'~~I'w/ 1800 sacks 200 sx Note: all depths are referenced to original KB elevation due to historical data on drawings, etc. Except that the attached directional plan which has compensated for the 87' elevation for the new sidetrack. Kenai Unit well KU 24-5 will be plugged back to 3500' MD and sidetracked. KU 24-5rd will be difYq;üop.aJ4'fVi~~ ~ an estimated total depth of 4608' MD, 4050' TVD from the existing Kenai Gas Field pad 41-7, The p~ctidtiol! iþtVht!1 ~II be cased with 711, cemented in place as a production liner, Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: JUL 1 6 2001 Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Dir<%:t8i:taáJi~ß8$ MJmj.~mmissior drawing and Blowout Prevention Equipment drawings. Anchorage 20. Attachments Filing Fee[]] Property Pla(8] BOP Sketch[8] Drilling Fluid Progra~ Time vs Depth PloD Refraction AnalysiG 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ "- tJ . . i /.' ~ .t/HJØ4'~? Diverter SketcO Seabed ReporD Drilling program[8J 20 MC 25.050 RequirementO Phone: 564-6319 Title Drilling Superintendent Commission Use Onl API Number . Approval Date () 50-- /33 - 2ð3S8 -01 "'I. I Conditions of Approval Samples Required DYes [XJ No Mud Log Required DYes C5(I No Hydrogen Sulfide Measures DYes IZJNo Directional SuNey Required IXJYes DNo Required Working Pressure for BOPE D2M~. _D5M D 10M D 15M Other: c:.e\"'l\..~\~'~\>~~~ ~C'L ~~~~ ç>~c,-\~ \:)~~~~~ .. ORIGINAL SIGNED BY by order of 0 Taylor Seamount Commissioner the Commission Signed P. K. Berga Date: 7/9/2001 Permit Number 20/- /S£ See Cover Letter For Other Requirements Approved by Date 3.D I Form 10-401 Rev. 12-1-85 ORIGINAL Submit in Triplicate ( Marathon oil Company Alaska Region ( Prepared By: Approved By: Date: T.A.Laylock 07-11-01 Drilling Program Well: KU 24-5rd AFE: To be determined Area: Kenai Gas Field Drilling Contractor: Inlet Drilling Company Rig: Glacier Drilling Rig No.1 Geologic Program Depth Target Locations FNL FWL Block MD TVD Tolerance Surface 332' 4331' Sec. 7, T4N, R11W, S.M. 21' 21'OKB ( 2 8 ' OKB) ( 2 8 ' OKB) Sterling B1 - 1071' 1463' Coordinates from 4371'OKB 3824'OKB 250' North East Wellhead Bottom Hole 1100' 1530' Coordinates from 4608'OKB 4050'OKB North East Wellhead Note: Preliminary directional plan does not intersect target center, OKB=Original Kelly Bushing RKB Elevation: RKB to MSL=87' (original hole/well 94') All data herein reflects original KB¡ except that attached directional program considers new KB elevation for GDR #1, GL-MSL=65,68' Total Depth: TVD 4050' MD 4608' Avg, Angle 20 Course 34 Abnormal Pressures: Subnormal Pressures: 250 psi to 1000 psi in Sterling Sands Coring and DST's: Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection. 10' samples to TD Logging Program: Contractor To be determined LWD Wireline Logs Surface NA Production NA GR/AIT/DSI/NGT KU 24-5rd Drilling Program Page 1 of 7 ( (" Drilling Program Summary 0 ~O'.-d' production: The existing wellbore will have been plugged back to <= 4500' MD as per the AOGCC regulations. Set CIBP 3' above casing collar at 13500' MD. Test plug and casing to 2500 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside for casing exit. Cut window and ensure all mills are worked thru window, CBU. Test shoe to leakoff (15.5 PPG anticipated). Drill a 8 1/2/1 hole to 4608' MDI 4050' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 7/1 production liner and cement per the attached program, Proceed with completion program. Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (ps i) (psi) (K lbs) (MD) 9 5/8/1 0' 3500' 47.0 N-80 BTC 12 1/4" 6870 4750 1086 7/1 3250' 4608' 23 or L-80 LTC or 8 1/2/1 6340 3830 532 26,0 BTC 7240 5410 604 Note: The 9-5/8/1 casing is already installed, Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8/1 47 N-80 3054' 15.5 9.0 1043 2.6 3.6 NA 7/1 23 or 26 L-80 4050' 9.0 1490 1.5 2,0 3.0 KU 24-5rd Drilling Program Page 2 of 7 / ( ( Directional Program Directional Co: Baker Hughes Inteq KOP: 3500 Direction: 33 Gyro Co: To be determined Dog Leg: 3.0 To: 17.1 deg @ 3756' TVD Hold Depth: 4608 MD/ 4050 TVD Hold Angle: 17.1 Gyro Survey Required: at TD Magnetic Multishots Required: Use MWD surveys below drive pipe General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 9 5/8" Intermediate Casing @ 3054' TVD MASP = ((PP * .052 * TVDtd) - (%mud * 0,052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) MASP = (9.0 * 0.052 * 4050) - (0.3 * 0,052 * 9,0 * 4050) - (0.7 * 0.1 * 4050)) MASP = 1043 psi 7" Production Liner @ 4050' TVD* MASP = PP * 0,052 * TVDf - (GG * TVDf) MASP = 9.0 * 0.052 * 4050' - (0.1 * 4050') MASP = 1490 psi *This will also be the new MASP for the 9-5/8" casing as production, Cementing Program Contractor: BJ Services Production Casing Size: 7" Setting Depth: 4608' MD/ 4050' TVD Annular Volume to 3500' with 8 1/2" gauge hole: 140 ft3 Tail Slurry: Top of Cement: Specifications: Density: 15,8 ppg, Yield: 3250'MD/ 2857' TVD Class G + additives Mixed w/ fresh water 1.15 ft3/sx, Sx: 200 sx, cf: 230 ft3 Compress Strgth: 500 psi in 6 hrs, 3600 psi in 24 hrs Total Volume: 230 ft3, *50% Open Hole Excess, WOC Time: 6 hrs *Actual cement volumes to be based on open hole log data and/or drilled hole conditions, KU 24-5rd Drilling Program Page 3 of 7 ( ~ Diverter and BOP Program The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventor with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke, Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) 1043 1500 ( 1) 13-5/8" 5M Annular 250/3000 Intermediate 9 5/8" (9.2 ( 1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram .,;I~~~~'~;a~:Øi~I," "';:,:,;, ~s"-,:;~:,,,"'t".~\-i'\~!~"" mud) 2500 (1) 13-5/8" 5M Annular 250/3000 Production 7" 1490 (10.0 ( 1) 13-5/8" Blind 250/3000 5M ram ppg (2) 13-5/8" 5M Pipe ram " ;';¡!2§Ø,7:~!P:H:.. mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 9 5/811 Intermediate Casing at CTPMASP = 1043 psi CTPBurst = 6870 * 0.7 - Test to 1500 psi 3054' TVD ((9.0-8.3) * 0.052 * 3054) = 4697 psi 7" production Liner (and 9-5/8" Casing) at 4050' TVD CTPMASP = 1490 psi 'r.e...t' 'to' '250'0 :-P'9:1' JjiÞ' CTPBurst = 7240 * 0,7 - ((9.0-8,3) * 0,052 * 4050) = 4920 psi KU 24-5rd Drilling Program Page 4 of 7 ,( ( Mud Program Contractor: MI Drilling Fluids Interval (TVD) Mud Weight From To (ppg) Water Loss Mud Type 3054' 4050' 8,7 - 9.0 <8 Flo Pro/KCI Wellhead Program Manufacturer Vetco Model Annular Flow Tubing Head 11/1 3M X 11/1 3M w/ 2-1/16/1 5M flanged outlet & 7-1/16/1 3M flngd outlet Tubing Hanger 11/1 x 3-1/2 Mandrel Tubing hanger Detailed Drilling Procedure Formation Leakoff Test Surface and Intermediate casing shoes will be tested to Leak-off, Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section, Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm drillpipe pressures at 1/2 bbl intervals. A running plot of kept by the drilling foreman while the test is in progress, 4, Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5, Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. while recording casing and pressure versus volume should be Bit Program The following guidelines are recommended for use on this well. Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 3500' - 4608' 8 1/2/1 XR15TDGPS 447X 15/35 200 KU 24-5rd Drilling Program Page 5 of 7 f ( Drill String Item Ppf Makeup Torque Max Pull - Premium 3 %" HWDP, 3 %" IF 24.4 12000-13200 248,400 lbs. ft.-lbs. 4", 8-135, HT 38 15.53 13,500-19,800 403,500 lbs. ft.-lbs. 5" HWDP, 4%" IF 49.3/53.6 29,000 543,000 lbs. ft.-lbs. Hydraulics Program Rig mud pumps available are shown below. Install 5 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oilwell A 600 PT 4 7'2" 8" 3207 1. 6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 Oilwell A 600 PT 5 7'2" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (ps i) ( fpm) (ppg) (32"s) Remarks 4608' 8 1/2" 390 2200 - 175 9,5 14,14,14 Motor Drilling 2400 Note: 5" liners are recommended. KU 24-5rd Drilling Program Page 6 of 7 t I{ OPERATIONAL PROCEDURE 1. MIRU the drilling rig. Install 13 5/8" 5M X 11" 3M DSA. program. Record test on IADC book. Set wear bushing. NU 13-5/8", 5M BOP system. Test as per 5. Abandon existing perforations according to program filed with AOGCC. RIH and set CIBP at +1- 3500' md. Test plug and casing to 1500 psi. MU and RIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside casing exit. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 15.5 ppg anticipated). Drill a 8-1/2" hole to 4608' MDI 4050' TVD per the attached directional program. Backream each stand. Lost circulation is possible throughout this interval. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. 2. 3. 4. 6. At TD, pump a hi-vis sweep and circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability, POOH, laying down 5" HWDP. Run logs as per geology requirements, Pull wear bushing. Locate casing swage and safety valve, Function safety valve and place on rig floor. Record function test in IADC book. RU and run 7" casing liner, Cement casing as per the attached cementing program. Ensure circulation of cement to above top of liner. 7. 8. 9. 10, Pullout of liner hanger and circulate cement clean. Pullout of hole with setting tool. Clean out liner, Test casing, liner and liner lap to 2500 psi, 11. Prepare for completion, A separate completion procedure will be developed. KU 24-5rd Drilling Program Page 7 of 7 ~. f MARATHON Oil Company Pad 41-7 KU24-5Rd slot #KU24-5X Kenai Gas Field Kenai Peninsula, Alaska PRO PO S A L LIS TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd Version#2 Our ref: prop4790 License: Date printed: 10-Jul-2001 Date created: 10-Jul-2001 Last revised: 10-Jul-2001 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 30.878,w151 14 42.563 Slot Grid coordinates are N 2361663.250, E 275233.476 Slot local coordinates are 323.35 S 4332.39 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ( MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KU24-5Rd Your ref : KU24-5Rd Version#2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised: 10-Jul-2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 3500.00 38.03 54.92 3059.78 899.41N 1210.84E 0.00 1507.80 276461.37 2362539.12 3520.00 38.89 53.56 3075.44 906.68N 1220.93E 6.00 1520.23 276471.61 2362546.20 3600.00 36.59 52.43 3138.70 936.14N 1260.04E 3.00 1569.18 276511.28 2362574.90 3700.00 33.74 50.83 3220.45 971.86N 1305. 21E 3.00 1626.76 276557.12 2362609.74 3800.00 30.91 48.98 3304.94 1006.26N 1346.12E 3.00 1680.19 276598.69 2362643.34 3900.00 28.11 46.79 3391.97 1039.25N 1382.68E 3.00 1729.31 276635.87 2362675.63 4000.00 25.35 44.16 3481.28 1070.75N 1414.76E 3.00 1774.00 276668.55 2362706.49 4100.00 22.65 40.95 3572.63 1100. 65N 1442.30E 3.00 1814.12 276696.66 2362735.86 4200.00 20.03 36.93 3665.77 1128. 89N 1465.21E 3.00 1849.58 276720.11 2362763.65 4300.00 17.52 31. 78 3760.45 1155. 38N 1483.43E 3.00 1880.27 276738.83 2362789.78 4346.43 16.41 28.89 3804.86 1167. 06N 1490.28E 3.00 1892.87 276745.91 2362801. 33 4366.38 16.41 28.89 3824.00 1172.00N 1493.00E 0.00 1898.06 276748.72 2362806.21 4500.00 16.41 28.89 3952.17 1205.06N 1511. 24E 0.00 1932.82 276767.60 2362838.91 4601. 98 16.41 28.89 4050.00 1230.29N 1525.16E 0.00 1959.35 276782.00 2362863.87 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 1959.52 on azimuth 51.11 degrees from wellhead. Total Dogleg for wellpath is 25.99 degrees. Vertical section is from wellhead on azimuth 51.87 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 4l-7,KU24-5Rd Kenai Gas Field,Kenai Peninsula, Alaska MD TVD t PROPOSAL LISTING Page 2 Your ref: KU24-5Rd Version#2 Last revised: 10-Jul-2001 Rectangular Coords. Comments in wellpath Comment -------------------- -------------------- ----------------------------------------------------------------------------------------------------------- 3500.00 4346.43 4366.38 4601. 98 Target name 3059.78 3804.86 3824.00 4050.00 899.41N 1167.06N 1172.00N 1230.29N 1210.84E 1490.28E 1493.00E 1525.16E KOP EOC Target TD Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 10-Jul-2001 Target 1 3824.00 1071 . OON 1463.00E (' ~I' /M~ . \ r \ { 1 ~MARAT~~~j MARATHON Company Oil I (.r~ed by bmichoel For: P Berga ! Date plotted: 12-Jul-2OCl J Plot Rel..ence is KU24-5Rd Version'4. koordinoles ore in f~1 reference slot iKU24-5X. i ¡True Vertical Depths ore reference wellhead. I I i " ...- ID Q) - '----' ...c ...- a.. ( J 0 0 0 ...- S- ID > ID :J !o- l- II V 51.87 AZIMUTH 1892' (TO TARGET) ***Plone of Proposal*** 33.42 \ ~\ 30.54 \~ DLS: 3.00 deg per 100 ft 27.67 \ \ \ '\ '\\ \ \ \ \~ U!(9 HUOI8i ""1>:.) 3000 3100 3200 3300 3400 3500 3600 3700 3800 Sterling Target-EOC 3900 4000 4100 4200 1400 1500 Structure: Pad 41 - 7 Well: KU24-5Rd Field: Kenai Gas Field Location: Kenai Peninsula, Alaska -- ---- WELL PROFILE DATA ---- Point ----- MD Inc Dir NO North Eost V. Sect Oeg/100 Tie on 3493.0D - 38.00 54.93 3047.27 896.90 1207.25 1503.42 0.00 End of Build/Turn 3513,00 38,86 53.58 3062.94 904.16 1217.33 1515.84 6.00 End of Drop/Turn 4363.28 15.09 30.67 3817.00 1162.00 1493.00 1891.89 3.00 T.D.l! End of Hold 4597,35 - 15,09 30.67 4043.00 1214.42 1524.09 1948.71 0.00 East ( feet) - > 1100 1300 1500 1700 1200 1400 1600 KOP ~ V /// /// Ø'/~ 'J,?-ò ~' ~~'l ,/' //' ,// // ,,// / ,/ ,/' / /" // ~/,./ 16.69 TD 1600 1700 2000 2200 2400 1800 1900 2100 2300 A7imllth .'i1 P,? wHh rAfArAn~A n nn N n nn r from c;lnt :l:IKIJ?A.-'i)( Vertical Section (feet) - > 1800 1500 1400 1300 ^ I Z 0 .., -f- :J 1100 ............. -+- CD CD -f- 1000 '-'" 1200 900 800 ¡i , ( MARATHON oil Company Pad 41-7 KU24-5Rd slot #KU24-5X Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd Version#4 Our ref: prop4790 License: Date printed: 12-Jul-2001 Date created: 10-Jul-2001 Last revised: 12-Jul-2001 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 30.878,w151 14 42.563 Slot Grid coordinates are N 2361663.250, E 275233.476 Slot local coordinates are 323.35 S 4332.39 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North / \ (' MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KU24-5Rd Your ref : KU24-5Rd version#4 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 12-Jul-2001 Measured Inc1in Azimuth True Vert R E C TAN GULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R D I NATES Deg/100ft Sect Easting Northing 3493.00 38.00 54.93 3047.27 896.90N 1207.25E 0.00 1503.42 276457.73 2362536.68 3500.00 38.30 54.45 3052.77 899.40N 1210. 77E 6.00 1507.74 276461.31 2362539.11 3513.00 38.86 53.58 3062.94 904.16N 1217.33E 6.00 1515.84 276467.96 2362543.75 3600.00 36.32 52.54 3131. 87 936.04N 1259. 75E 3.00 1568.89 276510.98 2362574.80 3700.00 33.42 51.19 3213.91 971.32N 1304. 73E 3.00 1626.05 276556.63 2362609.20 3800.00 30.54 49.60 3298.73 1005.05N 1345.55E 3.00 1678.99 276598.09 2362642.14 3900.00 27.67 47.73 3386.09 1037.14N 1382.08E 3.00 1727.54 276635.23 2362673.52 4000.00 24.84 45.46 3475.77 1067.51N 1414.25E 3.00 1771.59 276667.97 2362703.26 4100.00 22.06 42.65 3567.50 1096.06N 1441. 95E 3.00 1811.01 276696.22 2362731.27 4200.00 19.33 39.08 3661.04 1122. 72N 1465.11E 3.00 1845.69 276719.89 2362757.48 4300.00 16.69 34.42 3756.14 1147. 42N 1483.66E 3.00 1875.53 276738.91 2362781.82 4363.28 15.09 30.67 3817.00 1162. OON 1493.00E 3.00 1891.89 276748.53 2362796.22 4500.00 15.09 30.67 3949.01 1192. 62N 1511.16E 0.00 1925.07 276767.27 2362826.48 4597.35 15.09 30.67 4043.00 1214.42N l524.09E 0.00 1948.71 276780.62 2362848.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 1948.76 on azimuth 51.45 degrees from wellhead. Total Dogleg for wellpath is 26.73 degrees. Vertical section is from wellhead on azimuth 51.87 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 186.6 spheroid Presented by Baker Hughes INTEQ ~' MARATHON oil Company Pad 4l-7,KU24-SRd Kenai Gas Field,Kenai Peninsula, Alaska MD TVD Rectangular Coords. j'" ( PROPOSAL LISTING Page 2 Your ref: KU24-SRd Version#4 Last revised: l2-Jul-2001 Comments in wellpath -------------------- -------------------- Comment 3493.00 4363.28 4597.35 ----------------------------------------------------------------------------------------------------------- Target name 3047.27 3817.00 4043.00 896.90N 1162. OON 1214 .42N 1207.2SE 1493.00E 1S24.09E KOP Sterling Bl Target-EOC TD Geographic Location Targets associated with this wellpath T.V.D. Rectangular Coordinates ------------------------------------- ------------------------------------- Revised ----------------------------------------------------------------------------------------------------------- 10-Jul-2001 Sterling B1 tgt - 11 J 3817.00 1071. OON 1463.00E ~' t MARATHON Oil Company Pad 41-7 KU24-5Rd slot #KU24-5X Kenai Gas Field Kenai peninsula, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: KU24-5Rd version#4 Our ref: prop4790 License: Date printed: 12-Jul-200l Date created: 10-Jul-200l Last revised: 12-Jul-2001 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 30.878,w151 14 42.563 Slot Grid coordina~es are N 2~~~Ái3. .250, E 275233.476 Slot local coord~nates are r 323.55 S 4332.39 E "-.......-':> / .' Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North " \ ~: MARATHON oil Company PROPOSAL LISTING Page 1 Pad 4l-7,KU24-5Rd Your ref : KU24-5Rd Version#4 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : l2-Jul-200l Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN A T E S Deg/100ft Sect 3493.00 38.00 54.93 3047.27 896.90 N 1207.25 E 0.00 1503.42 KOP 3500.00 38.30 54.45 3052.77 899.40 N 1210.77 E 6.00 1507.74 3513.00 38.86 53.58 3062.94 904.16 N 1217 . 33 E 6.00 1515.84 3600.00 36.32 52.54 3131. 87 936.04 N 1259.75 E 3.00 1568.89 3700.00 33.42 51.19 3213.91 971.32 N 1304.73 E 3.00 1626.05 3800.00 30.54 49.60 3298.73 1005.05 N 1345.55 E 3.00 1678.99 3900.00 27.67 47.73 3386.09 1037.14 N 1382.08 E 3.00 1727.54 4000.00 24.84 45.46 3475.77 1067.51 N 1414.25 E 3.00 1771.59 4100.00 22.06 42.65 3567.50 1096.06 N 1441. 95 E 3.00 1811.01 4200.00 19.33 39.08 3661.04 1122.72 N 1465.11 E 3.00 1845.69 4300.00 16.69 34.42 3756.14 1147.42 N 1483.66 E 3.00 1875.53 4363.28 15.09 30.67 3817.00 1162.00 N 1493.00 E 3.00 1891. 89 Sterling B1 Target-EOC 4500.00 15.09 30.67 3949.01 1192.62 N 1511.16 E 0.00 1925.07 4597.35 15.09 30.67 4043.00 1214.42 N 1524.09 E 0.00 1948.71 TD All data is in feet unless otherwise stated. Coordinates from slot #KU24-5X and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 1948.76 on azimuth 51.45 degrees from wellhead. Total Dogleg for wellpath is 26.73 degrees. vertical section is from wellhead on azimuth 51.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ( MARATHON oil Company Pad 4l-7,KU24-5Rd Kenai Gas Field,Kenai Peninsula, Alaska MD TVD Rectangular Coords. i( PROPOSAL LISTING Page 2 Your ref: KU24-5Rd Version#4 Last revised: l2-Jul-200l Comments in wellpath -------------------- -------------------- Comment 3493.00 4363.28 4597.35 ----------------------------------------------------------------------------------------------------------- Target name 3047.27 3817.00 4043.00 896.90 N 1162.00 N 1214.42 N 1207.25 E 1493.00 E 1524.09 E !COP Sterling Bl Target-EOC TD Geographic Location Targets associated with this we1lpath T.V.D. Rectangular Coordinates ------------------------------------- ------------------------------------- Revised ----------------------------------------------------------------------------------------------------------- 10-Jul-2001 Sterling B1 tgt - 11 J 3817.00 1071. OON 1463.00E ( ( SURFACE USE PLAN FOR KENAI UNIT KU 24-5rd Surface Location: SW 1/4 of SE 1/4, Sec. 7, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KU 24-5 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 KU 24-5. 3. Location of Existing Wells Well KU 24-5 will be sidetracked from an existing well on pad 41-7. A pad drawing is attached that shows existing wells and the location for KU 24-5. 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 may be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). E:\Documents and Settings\nz6\My Documents\ku24X-5\SURFUSE.doc ( ~ \ I': ~. Surface Use Plan Kenai Unit KU 24-5rd Page 2 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. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Kenai Unit KU 24-5 will be drilled from an existing pad. Reclamation of the pad will occur after abandonment of KU 24-5 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. 10. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. Surface Use Plan Kenai Unit KU 24-5rd Page 3 ,I' ( " ,{ 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: / :3 ~ ;2£Jð / Name & Titl~ ~ /udt'- - (lt7i:u -: JJd¡-. ¥ Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 ~ ( Marathon Oil Well KU 24-5rd Choke Manifold ~:: ~~ ~ t t 3 1/811 5M Manually Adjustable Choke 2 9/1611 10M Swaco Hydraulically Operated Choke ~ ¡Flow Nipple - 13 S/8" SM Annular Preventer 13 S/8" SM Double Ram Preventer ~ 3 1/8" SM Manually Operated Valves ~ ~~ [JI:EJ]J[JI:EJ]J I Kill I 135/B"5MCross I ~ 13 S/8" SM Single Ram Preventer ~ Marathon Oil Well KU 24-5rd BOP Stack .. IFlow Line I Pipe Ram I Blind Ram Cho ke Pipe Ram t 3 1/8" SM Hydraulically Operated Valve JI [[@]]DIßII] t 3 1/8" SM Manually Operated Valve EY WORK POINT .4,812.713 351,757.248 . REBAR) . WAS1E WA 1ER BLDG. 6 + OVERHEAD CONDUIT 2-4" ø PIPES' STORAGE BLDG. 5 INSULA 1ED PIPING '---II SUI? ~Yij.¡ °l?/r . '-IA¡, .~ 6 -..-.. O.H.E. ---~ 80: "" '\ \ \ 1 I I I 24.2' I I I METER ~I I BLDG. 1 I I )~ 4" ø O.H. PIPE 0 12" ø O.H. PIPE / m '<; - f'... ~. . WELL HOUSE X=275,O73.22 Y=2,361,844.31 ';.t ó ...¡-" 6" ø PIPE GOES UNDERGROUND 8" ø PIPE DEAD ENDS SEE DETAIL~ ~-- \ ~ .~ ~;f:~~.i: 'f~~~~~~ ',,>! '.. :;~k:.i¡1 (>;;?Ý¡:: '! ,~~,.,. W :.I.~':J' ~J1~ \\ ~, .~'. K.U. 13-5 14.2' WELL HOUSE X=275,O63.53 Y=2,361 ,775.96 EJ K.U. 4-3-6X I I ) / ~ .... 0> Vt 10' ø WELL HOUSE Wl1H 17'X17' PIPE GUARD X=275,133.33 +Y=2,361 ,787,18 ~ K.U. 4-3-6 0 K.D,U. NO.4- X=275,108.77 Y=2,361 ,743.64 Iv 65J ~<'T6" 566 ~ ~ "'1<' + @ K,U, 4-3-7 10' ø WELL HOUSE X=275,130.59 Y=2.361.596.60 ELECTRIC PANEL r- FOR DRILUNG -l- OPERATIONS -..-..-..-..-.. P AD LIMITS a.H.E. 0 0 0 0 ..- II) " 0 X=275,201.30 Y=2,361,808.64 K.U. 4-1-7 K.U. 4-3-6A 0 . X=275,189.98 Y=2,361,721.01 X=275,179.48 Y=2,361,661.55 0 K,D.U, NO.2 K,U. 24--5 à m WElL HOUSE :t~ X=275,233,476 Y=2361,663.25 16.0' , Y = 2,361,800.00 PAD LIMITS \. -. ~ 2-3"Ø FlARE PIPES , 140' B WELL HOUSE co' .... 0 X:27~,167.14 Y-2,361,621.14 .U. 11-8 Q] JUNCTION BOX wi GUARD PIPE 2-2"Ø FLARE PIPES ... \ co I ~ 0 f- 0 0 0 0 t") II) " Y = 2,361,600.00 ~ ~'. "..., ""'\'\\"'1 ..."'£. OF.<I( I, $' ';-:---"""'.1.s-. " ;:t;-/ ~..~/- ...*,.g¡IliN .*~ ¡:~~~~::...:~ ~ \ '.IL SCOTT WcUJ£'l' ... I ~"'" 4028-S ..,' ;: II"'" '~.!"."""".., ~ ',;~;~""......,,, . """"", 1) ElevatIon. at the tap of pipe for monitoring we"s were taken wIth caver aft or open. 2) Reference datum is mean sea level- 0.00' for elevations ShaN". --"'-" 3) All bearing. are grid unle.. noted atherwl.e. . '. 4) BasIs of Coordinate. i. U.S.C. lit G.S. Tri Stotian AUORY ;n A.S.P. Zone 4. (NAO 27) Average convergence of paint. shoon: -01'05'03" 5) AUORY location: Lot.: 60'JO'50.559'N Lang.: 151Ï6'37.445'w X=269.866.75 Y=2,362,045.42 6) T.B.t,4. 81-31-16 spOte In P.P. G5 3210 elev. 65.66 M.S.L McLANE CONSULTiNG GROUP sa.DOT>U. AlASKA ..." ('07) 28J-421O No. DATE BY IoPP. RE'o'SlQNS RO.£CT >;0.: ~ Marathon RAWoNG NO" Oil Company Alaska R..i"" 4 "" BY: . O/CIHEER _Rav,,- KENAI GAS FIELD PAD AS-BUILT SURVEY BY DA PRO.£CT FIELD PAD SlR'.JCT. KENAI GAS 41-7 PROCESS ELECT. SCAlE 0"". ow DATE ""/II fltL NO. "STROw. ",;m.. woco DATE ..."'. "050' APP.s 00<kCf AIT 41-7 a r APP.~ """"DATE (" ( IIIDDUI IIIJLUGA + L,. T5N-R~ W . KENAI GAS FIELD DIAGRAMMATIC CROSS SECTION 14-6 Pad 41.7 Pad A KU 24~rd I L..... UNIT ¡BOUNDARY. ._.~ ..I L.. . -J.-. I -'.1 . L.- . I . I KDU-7 X . [j LOWER ULUGA DIi8P ..... T\'ONBK I.U ..... ~ ..... + ~. 0 0 (J A' . I v " -... ,,"...'" """Ú+ . p'" . I . I I.-" + . . L... . I .-.. I .....-. + . I . I I. -.. . ,....-.-+ I Structure Map -- terling Fm. B4 sand 0 C.I. : 100' 1 . I MILE MARATHON OIL COMPANY ALASKA REGION KU 24-5rd Location KENAI GAS FIELD COOK INLET, ALASKA July 2001 HM4094 0: \freehand\ku24-5IoC.fh 7 .- _/ ~ 120" 94# H-40 Drive Pipe @ 136' I KU 24-5, Pad 41-7 .. I Sidetrack Well bore I 13-3/8" 61# K-55 BTC @ 2012' Cmt'd w/1500 sks of Class G . Liner Hanger at 3250' IB-1 perfs sealed off with LCM I XA Sliding Sleeve @ 4587' ID 2.75" . ¡Baker Model'D' pkr @ 4607' I Drilled hard cement out of tubing from 4365 to 4608 wI CT prior to fishing job, left hard Cemen @ 4608' :~ :~: ¡~~ i?: :x :::=¡ ~ ~Ij I; ~:: ..;.:-:-:-:-:-:-:-:-:-:-: :::' II ., ~:Æ*lll. ::':..-17 26 ppf L-80 casing at 4608 MD I ~~-:-~-:-~-:-~-:-~-:-~-:-~-:-~-:-~-:-~~ ~.x.:~.x.x.x.x.x.x.x.~ 2.75" 'X' Nipple @ 4633' w/Mule shoe tbg tail @ 4644' Sqz Cement of B-3 & B-4 Perfs Fill @ 4781' (Slickline) 08-27-1993 ¡Cement Retainer @ 4886' I 9-5/8" 47# N-80 BTC @ 5900' Cmt'd w/1800 sks of Class G ~m~~~m111:::::t~ ¡TD @ 5900' I Well Name & Number: KU 24-5 Lease: Kenai Gas Field County or Parish: Kenai, AK StateiProv, Alaska I Country: I Perforations (MD) Pool 4 - B-1 (TVD) Angle/Perfs Angle @ KOP and Depth BHP: 245 BHT: 105 Completion Fluid: Dated Completed: T 4 N <f . , \ \ \ '.00 c';;,; -.' ','.0 . ':'J.; O"~,,,'/'-,.. ; 0 ....=-...-.U::.....,,:~.o o. 0 0 . 0 .. * , ... J' . .. . . . * . .* \.. . (?Cf 6}¡ " . *It ... " .. . . . . T 5 N IE IE .. .,'~--_.,( \ \ ":"'", " ::':":,:>,:",,'::':::':':' ',; , . , ,FIGURE: 1 .. ',' ; , ! ' , , i', , ! ' " " I ': ' ""'" ' ", ,',::',,:, ,~ ' , .", " " '. ,: ':; , ',' i', ": :,"'" ,', ' , ", , ',' , , ' ,.. .. i' "',' j:" " , ' '.. , , ': t~,'.., ! " , ',' ¡, " , ' , ¡', ' , ' " , ,', ¡, , , , , " ! , ' ~ T ---..- .- A-..a 1.m.:~1 >': , , .. , ' ,8 , '.. ....a , , ....tt .a- .. 1.LI ~d"'" -;~ I f' I I' I ' I ' " I I t ' t % , ' -< ",=, t - I % I 1"1 I ,. :-t I "" I x I ' r:J .e-" .. '--..-. "- lm:~1 , IdOO9':"~ '16M, ~ . Id 009-'" , l' ^!; ----r- t . .- , , , , So ' I ¿~ 91 'åH Sl , t r'\. r. , ' -, , \...~j .æ ÞUDI1. mw , 8IU':~ J ~~ t "".6-- 4' , ' ,,- , ..., '!;X 9 dl';L ~". ~ , i ',.1, 9,X,9 dH ç¿, ) . --r .., 1!ilrDi1. .. , - "-.ÌI , 4 " ...t ' S',X 9 dH~l on --. ,ai X ,e 4~ .ë!-Arl , ',~ . n x .2 eMU awi: I', !' , ~ '," ':10 ' >'~;"""'I ' , ~:SW,93d.I"',:', \ ÁœæOdlf .' , \: .', "" ,',':" '~'" I ' "',: ,~:. I ' , , I . , , " I " , i " I t ,,' I ~--~~~""'--, , , , I :"'. " 'I , I, """"1 ( " ' ...... ,.. '..... "".nr \.... " \.., , , I:t :;a "- "' i ' :Pt' -" ..' P1 .., , " ... ' , " , ',', , i ..,' , " " ' , , :",' , , , ' :,', ',' , '.. , ' ", ' " , , ",' ::'",,"{ " , ': ':' , , ", ,...~ " t- . ' , , ".\ " .': , . 'I_. . .. Pi:1~' t~ \111:- Jraer of Marat!~91~,.q!,~, Ç~tl1pany I\."';\,, -~v;t,,~.. I\._""r<.., 01533 ~,~ ',' 1~:~i. .. . , . , . .. ". '. .. . '" .' "'" ". ".. .. '.... ".. " 07 /Í3 leu ~,'~; D'" Yi~ Alaska,Oil6. 333 ~':est, 7th Anchorage, AI< Gas Cocr.ni£sion .:,ve, Suite 100 9950L ¡- -- ."rJiATëH ^~:.,t)ONr'IÑ .. - -.! ~ '. .~VC?RD~:~ ~,ITH..,~~M.~~I~,~ ,_...J i $" ,'1" .0:: ':'O'::'-:r~O'{,:~r~(}::Z?:/;~,t:~~:~ir] " ,.I.J.., "... . . -.......8 Pay. "(i!t) f"i-1EH u~ üA'r'~:l : .: '::'" ,/:::.: ;::'.: '.':" '~': .~:' .:' .:",.,: ::' ~:i~i:E ~~~9~~~~"Tl\~Eil~.~~~~~~1tj~T,~~~~;'~~;~~~~~r~~~~:Pl:\~,?~P:~:~~~'/\.-::::/<:~:~:'):': }:"/j~':;l:J.'jV,)~:~f..:~~~} On ð : 'ñundrnod .::and 001 OO"'----::-""!"~::oP~';"~"":":-:-:o:"-:":""-:-:';--::::~:-,::-""":'::-;':':'.=-:'¡"'-:O:~::-':-:::-"::"..~::::"";~"':':-::~~-::-:~- ".. ,,~.. ..~: ..:':~.:.:: ,Ð'"r,:w"r' ~~,~.I ..... ""., '" """"'""".""""""""""'" .." ...",.,,~A,""I::c;;J. i..---'-'::"-' .~-,.:...:",':. ,::.... '...' -. ,": . ':-..,..,',,"-": :_'..:'_."..::'.~:':"':;.~.:':-/:y..;~:,...;::..,~~::.:¿:~:.~i:~':':"':::"'::':L.~:~:::"i:'::::~~~~~:::Ll:::;.Lf....:.:'::j NATIONAL BANK OF ALASKA ANCHORAGE,ALASKA ßy Murothon Oil Comr)émy Jf ß(J~ ,. .-'.."_u,. \1". TI,,','.. IL'I~ ::" :;:>.,'" ".1:" THE BACK OF THIS DOCUMENT CONTAINS AN ARllF1CtAL WATERMARK HOLD AT AN ANGLE TO V1EW UI 0 0 ¡. 5 3 3 III I: ¡. 2 5 2 0 0 OS? I: 0 ¡. III 0 ? a 5 b t¡ III .- -- .... _. ..-.. -- ...,- ..- -- .,.- - -"- - -. .---.- -- .-..-..- -- _.-.- -' -- - .--., A,F,E, / ACCT, CODE OR NON-REPORTING 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT NON-EMPLOYEE COMP, PRIZES, AWARDS, OR DAMAGES OPERATOR CITY STATE ------- i DESCRIPTION - -- - - -- ..""..",.."".""",.""""",.,..E.,!,!.in,g""",.F",ê.,ê.""",,,"f .Q":f"""",...,r",§":f",ill,i:t",,,,. "t.Q."",.þ',,!;..,!1..!_- w ê.,1!......m._,_?~=.1f-Q..",~"""..",._..,.._"-,_.".""""..,,,."""-""",.."""""..."""",............."""""."",,, "".' """""""""."""""" . """"""". .-'-""""."'- ."...-.."...."."". """""""""'."""""""""""""""""".' ","."" .."......" '.""""""""""'-.""""" -"'" ""--""""""""'--""'-,-..""", """"'-"-""'-'-"---.--.----"'-'.""-'--"."--'.""-""-."".,...-,......-.....-.---."...,...-.,..-,- ,.-.-.."." "'----"""."""--""""'--"'---""" """'--" .,-.., . .'.' ".. .."" .,.. """"'-"""-'."'-"".-'-""""'.""'" .". "".""'...-"." -,..., """'-""..",...,. .."" "....."..-..-.----.....,...-".... " ".........-....... -""'."""'-'---"'- ----..-- ..._-, -,-_. '-"--' -,-, -. ...-.. ..---.... "",,-- ,- "--'.'-'--' ""'.--"-'-'-' ----_._. .,,-- -----...,.. '-.-.'-' . .. . . ......." .,,- """"--'-""." ""..-"'----"-""'------""---'-"---"---.""."'-"""--'--'-...-.---...----.-.----------"...------------,--..-------------..--, ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME KU 2 Lj~- S £b CHECK 1 STANDARD LETTER DEVELOPMENT -J- l DEVELOPMENT REDRILL / l EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D ~r;~L ( () NO ---c ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be "clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs.acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The .permit is approved. subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. . WELL PERMIT CHECKLIST COMPANY t:Lv.-:1 FIELD & POOL ~ s;-~ 2- INIT CLASS ADMINISTRATION 1. Permittee attached, . . . , . , , , . . . . . . . . . . , . , . 2, Lease number appropriate, . . , . . . . , . . , . . . . . . . 3. Unique well name and number, .. . . . . . . . . . . . . . . . 4. Well located in a defined pool., , . , . , , , , . . . . , , . , 5. Well located proper distance from drilling unit boundary, . , . 6. Well located proper distance from other wells., , , . . . , , . 7, Sufficient acreage available in drilling unit.. . , , , . , , . , . 8, If deviated, is well bore plat included,. , . . . . . . . . . . . . 9, Operator only affected party" . . , , , . . . . , , . . . . , . N 10, Operator has appropriate bond in force, . . , , . . . . , . . . N 11. Permit can be issued without conservation order. . , . . . . . N .!JA, TE , ;12, Permit ca~ be issued without administrativ~ approval.. . , , , N 7 11 D 13. Can permit be approved before 15-day walt.. . . . . . . . . . N NGINEERING ~~: ~~~~~~t~:~~~~~~~e:1I kn~~n' US'oWs.' ., " '. '. '. " '. " '. " ~ ~~~,:~.:\~<-~~~<è:~\~~.~' ,~(C\ \ 16, CMT vol adequate to circulate on conductor & surf csg. . , . . Y N . \ ~ 17, CMT vol adequate to tie-in long string to surf csg. , . , . . . . Y N 18, CMT will cover all known productive horizons, , , . , . , , . , N 19, Casing designs adequate for C, T, B & permafrost. " , , , , N 20, Adequate tankage or reserve pit., , , . . . , . . . , . . . . , N (/~\~~\." ~ r'\. ~ '~ë ~~<2..,~Q...\'~ 21, If a re-drill, has a 10-403 for abandonment been approved. , , N '3.0, - ~ \~ ~ 22, Adequate wellbore separation proposed,. . . . . . . , , . . . N 23, If diverter required, does it meet regulations, , . , . . . . , , . Y N ~þ.. 24, Drilling fluid program schematic & equip list adequate, . . , . N 25. BOPEs, do they meet regulation, , . . , ., , , . , , , , , . N . , 26. BOPE press rating appropriate; test to ~OOtJpsig. N~'S:>'Ç> ':. \4~O ~.. 27, Choke manifold compliesw/API RP~53 (May 84), , . . , . . . N ~~: ~~~~:~~~~~rH~~h~~~ ~~:~:~f; ~~u~d~~n: : : : : : : : : : : Y <[) GEOLOGY 30.. Permit can be issued wlo hydrogen sulfide measures. , , , " ~ 31, Data presented on potential overpressure zones. . . . . . , vA 32. Seismic analysis of shallow gas zones, . , . , , , '~' , " Æ/v N A~R DATE. 33, Seabed condition survey (if off-shore), . , . , , . . . , , . , Y N ~ -¡« /7-0 ( 34. Contact name/phone for weekly progress reports {expl atory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . , . , . , . (B) will not contaminate freshwater; or cause drilling waste. ., to surface; . (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOL GY: ENGINEERING: ~ COMMISSION: ~~ WM~ {I"¡-It> I AP .~~ APPR DATE -.sK~ROGRAM: exp - dev - redrll serv well bore seg _ann. disposal para req - GEOLAREA B2D UNIT# D5//2.D ON/OFF SHORE U/1 Y Y N Y N ",," Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -4 ~ ::u ( - -4 m ... -.-.- ... - Z -4 :J: - ( ) > ::u m » (
