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Home My WebLink About202-025David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 12/11/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 41-07X (PTD 202-025) Miscellaneous Well Logs: −KBU 41-07X SCMT (06/19/2002) −KBU 41-07X PERF (2 RUNS) (11-10-2020) −KBU 41-07X JUNK BASKET (11-10-2020) −AOGCC T11158 REPLACEMENT FILES SFTP Transfer - Data Folders: PTD: 2020250 E-Set: 34376 Received by the AOGCC 12/11/2020 Abby Bell 12/14/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 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: 3,680; 3,810; Total Depth measured 5,300 feet 4,650; 4,875 feet true vertical 5,239 feet N/A feet Effective Depth measured 3,680 feet N/A feet true vertical 3,635 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A Packers and SSSV (type, measured and true vertical depth)N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,160psi 1,511'6,340psi Collapse 3,830psi 10,540psi Casing Structural 13-3/8" 7" Length 99' 1,514' 5,292' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,291 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-467 73 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-025 50-133-20510-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 7426 Kenai Beluga Unit (KBU) 41-07X N/A FEDA 028142 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling Gas Pool 3N/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 3-1/2" 99' 5,292'5,231' WINJ WAG 884 Water-Bbl MD 99' 1,514' 49 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:29 pm, Nov 18, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.18 13:46:16 -09'00' Taylor Wellman gls 12/11/20 cement packer completion (gls 12/1/20) SFD 11/24/2020 Perforate DSR-11/19/2020 RBDMS HEW 11/20/2020 Rig Start Date End Date E-Line 11/10/20 11/10/20 11/10/2020 - Tuesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. RIH w/2.75" GR/JB and tie into a GPT log. Tag at 3,677'. Run correlation log and send to town to see if we are on depth. POOH. RIH w/ 2-3/8" x 5' HC Razor, 5 spf, 60 deg phase and tie into GR/JB. Run correlation log and send to town. Town said we were on depth to perf from 3,656' to 3,661'. Spotted and fired gun #1 w/Well flow 824.9K/57.7 psi. After 5 min - 975.3K/60.2 psi, 10 min - 1.074 mil/61.1 psi, 15 min - 1.139 mil/63.5 psi. Gun did get blown up hole and came down pretty hard. Didn't lose tools. POOH. All shots fired and had soapy looking grease in gun bull plug. Had to cut off 100' of line and re-head. RIH w/ gun #2, 2-3/8" x 6' HC Razor, 5 spf, 60 deg phase and tie into perf log. Run correlation log and send to town. Get ok to perf from 3,628' to 3,634' w/well pinched back to flow rate of 238K/166.6 psi. Spotted and fired gun. Gained about 3 psi but had well pinched back. POOH. All shots fired and bull plug looked like gun #1. Rig down lubricator and equipment and turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 41-07X 50-133-20510-00 202-025 Lease: Country: Angle/Perfs:KOP (TVD): 62' 21' Well Name & Number:KBU 41-7X County or Parish:Kenai Peninsula Angle @KOP and Depth: A-028142 Ground Level (above MSL): USAState/Prov.: RKB (above GL): Prepared By:Donna Ambruz Last Revision Date: Date Completed: Alaska 11/13/20 Structural Casing 13-3/8" J-55 68 ppf Top Bottom MD 0' 99' TVD 0' 99' Surface Casing 7" L-80 23 ppf BTC Top Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks Production 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 5,292' TVD 0' 5,231' Cemented with 530 sacks, Class "G" Permit #:202-025 API #:50-133-20510-00-00 Property Des:A - 028142 KB:21' AGL (83' KB Elevation) Spud Date:2/26/2002 Reached TD:3/5/2002 Rig Released:3/7/2002 X:275,251 Y:2,361,771 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. PBTD = 3,680' MD TD = 5,300' MD Isolated Sterling Pool 4 perfs A10 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 A10 3,729' -3,755' 2-3/8"x26' HSC EXP Gun 8/6/07 B1 3,833' -3,843' 2-3/8"x10' SDP, 4 SPF 60°7/28/07 B1 3,843' -3,853' 2-3/8"x10' SDP, 4 SPF 60°7/28/07 B1 3,864 '-3,890' 2-3/8"x26' SDP, 4 SPF 60°7/28/07 Isolated Upper Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Plug @ 4,875' Active Sterling Pool perfs A8 3,639'-3,645' 6 SPF 60 Deg 09/17/19 A8 3,639'-3,645' 5 SPF 60 Deg 11/10/20 A8 3,656'-3,661' 5 SPF 60 Deg 11/10/20 X-Nipple @ 4,933' MD (4,923' ELMD) Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve TOC @ 4,650' Bridge Plug @ 4,700' Isolation Plug @ 3,810' MD / 3,761' TVD SCHEMATIC Isolation Plug @ 3,705' MD / 3,659' TVD TOC @ 3,680' MD / 3,635' TVDA8 ,,g A8 3,639'-3,645' 5 SPF 60 Deg 11/10/20 A8 3,656'-3,661' 5 SPF 60 Deg 11/10/20 A8 3,639 3,645 6 SPF 60 Deg 09/17/19 109 bbls When was last MIT-IA ? wrong perf int. gun 2 3628-3634' cement packer. A u AAA 3 1/2 x 6 1/8 " = .0245 bbl/ft TOC? (TOC ?.... CBL?) 1514 ft ? gls 12/11/20 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 10:37 am, Nov 04, 2020 320-467 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.03 13:35:59 -09'00' Taylor Wellman 10-404 gls 11/5/20 DLB 11/04/2020 DSR-11/4/2020 X 11/5/2020 dts 11/5/2020 JLC 11/5/2020 RBDMS HEW 11/12/2020 Well Prognosis Well: KU 41-07X Date: 10/20/2020 Well Name: KU 41-07X API Number: 50-133-20510-00-00 Current Status: Shut-In Gas Producer Leg: N/A Estimated Start Date: September 20th, 2020 Rig: E-Line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 202-025 First Call Engineer: Todd Sidoti (907) 777-8443 (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Max. Expected BHP: ~ 1552 psi @ 3,584’ TVD (Based on normal gradient) Max. Potential Surface Pressure: ~ 1193 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Brief Well Summary KBU 41-07X was completed in the A10 sand in August 2007 and flowed until early 2008 when the well went down. The well was brought back online in 2013 and flowed at a stable rate of 1.5 MMSCFD before going down again in May 2014. A slickline survey in December 2015 indicated fluid level at 3,050’ and sand fill at 3,725’. In January 2016 the well was bailed, swabbed and then bailed again. In February 2016 the well was bailed and then perforated in the Sterling A10 sand. The A10 was not productive. In September of 2019, the middle section of the sterling A8 sand was perforated and came online making 2-2.5 MMCFD at ~ 350 psi. It has declined off to just under 1 MMCFD at 60 psi. To date the Sterling A8 has cum’d just over 700 MCF from the KBU 41-07X. The purpose of this work is to perforate the lower A8 sand and the Upper A8 sand using e-line. Notes Regarding Wellbore Condition x Minimum ID is 2.992” production casing x No known last tag – RIH with GPT tool on 9/16/2019, did not tag stopped at 3720’ MD. Since then, RIH w/ plug and dumped bailed cement on 9/17/2020, with TOC @ 3680’ MD. Safety Concerns x Ensure all crews are aware of stop job authority. E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH with junk basket / gauge ring and drift to PBTD . 3. RIH and perforate the following intervals with 2-1/2” guns loaded at 6 SPF 60 degree phasing: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom A8 (Pool 3) ±3,628' ±3,635' 6' ±3,584' ±3,590' A8 (Pool 4) ±3,656' ±3,661' 5' ±3,611' ±3,616' a. Perforate with the fell flowing. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. The purpose of this work is to perforate the lower A8 sand and the Upper A8 sand using e-line. A8 (Pool 3) ±3,628'±3,635'6'±3,584'±3,590' A8 (Pool 4)±3,656'±3,661'5'±3,611'±3,616' Well Prognosis Well: KU 41-07X Date: 10/20/2020 d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. All perforations in table above are located in the Sterling 3 Gas Pool based on Conservation Order No. 510A. 4. Turn well over to production. Lease: Country: Angle/Perfs:KOP (TVD): 62' 21' Prepared By:Donna Ambruz Last Revision Date: Date Completed: Alaska 10/04/19 Ground Level (above MSL): USAState/Prov.: RKB (above GL): Well Name & Number:KBU 41-7x County or Parish:Kenai Peninsula Angle @KOP and Depth: A-028142 Structural Casing 13-3/8" J-55 68 ppf Top Bottom MD 0' 99' TVD 0' 99' Surface Casing 7" L-80 23 ppf BTC Top Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks Production 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 5,292' TVD 0' 5,231' Cemented with 530 sacks, Class "G" Permit #:202-025 API #:50-133-20510-00-00 Property Des:A - 028142 KB:21' AGL (83' KB Elevation) Spud Date:2/26/2002 Reached TD:3/5/2002 Rig Released:3/7/2002 X:275,251 Y:2,361,771 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. PBTD = 3,680' MD TD = 5,300' MD Isolated Sterling Pool 4 perfs A10 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 A10 3,729' -3,755' 2-3/8"x26' HSC EXP Gun 8/6/07 B1 3,833' -3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843' -3,853' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,864 '-3,890' 2-3/8"x26' SDP, 4 SPF 60° 7/28/07 Isolated Upper Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Plug @ 4,875' Active Sterling Pool perfs A8 3,639' -3,645' 6 SPF 60 Deg 09/17/19 X-Nipple @ 4,933' MD (4,923' ELMD) Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve TOC @ 4,650' Bridge Plug @ 4,700' Isolation Plug @ 3,810' MD / 3,761' TVD SCHEMATIC Isolation Plug @ 3,705' MD / 3,659' TVD TOC @ 3,680' MD / 3,635' TVD A8 perforations Lease: Country: Angle/Perfs:KOP (TVD): 62' 21' Prepared By:Trudi Hallett Last Revision Date: Date Completed: Alaska 10/09/20 Ground Level (above MSL): USAState/Prov.: RKB (above GL): Well Name & Number:KBU 41-7x County or Parish:Kenai Peninsula Angle @KOP and Depth: A-028142 Structural Casing 13-3/8" J-55 68 ppf Top Bottom MD 0' 99' TVD 0' 99' Surface Casing 7" L-80 23 ppf BTC Top Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks Production 3-1/2" L-80 9.3 ppf EUE 8rd Top Bottom MD 0' 5,292' TVD 0' 5,231' Cemented with 530 sacks, Class "G" Permit #:202-025 API #:50-133-20510-00-00 Property Des:A - 028142 KB:21' AGL (83' KB Elevation) Spud Date:2/26/2002 Reached TD:3/5/2002 Rig Released:3/7/2002 X:275,251 Y:2,361,771 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. PBTD = 3,680' MD TD = 5,300' MD Isolated Sterling Pool 4 perfs A10 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 A10 3,729' -3,755' 2-3/8"x26' HSC EXP Gun 8/6/07 B1 3,833' -3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843' -3,853' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,864 '-3,890' 2-3/8"x26' SDP, 4 SPF 60° 7/28/07 Isolated Upper Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Plug @ 4,875' Proposed Perfs A8 ±3,639' - ±3,645' MD A8 ±3,656' - ±3,661' MD Active Sterling Pool perfs A8 3,639' -3,645' 6 SPF 60 Deg 09/17/19 X-Nipple @ 4,933' MD (4,923' ELMD) Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve TOC @ 4,650' Bridge Plug @ 4,700' Isolation Plug @ 3,810' MD / 3,761' TVD PROPOSED Isolation Plug @ 3,705' MD / 3,659' TVD TOC @ 3,680' MD / 3,635' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS "' 1. Operations Abandon LJ Plug Perforations Fracture Stimulate Pull Tubing 11 Operations shutdown Ll Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ - Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Nitrogen ❑Q 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 202-025 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-20510-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: A028142 Kenai Beluga Unit (KBU) 41-07X 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field / Up Tyonek Beluga Gas -Sterling 3 Gas 11. Present Well Condition Summary: 3,680; 3,810; Total Depth measured 5,300 feet Plugs measured 4,650; 4,875 feet true vertical 5,239 feet Junk measured N/A feet Effective Depth measured 3,680 feet Packer measured N/A feet true vertical 3,635 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural 78' 13-3/8" 99' 99, Conductor Surface 1,493' 7" 1,514 1,511 6,340 psi 3,830 psi Intermediate Production 5,271 3-1/2" 5,292 5,231 10,160 psi 10,540 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A Packers and SSSV (type, measured and true vertical depth) N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:0 658 0 0 459 Subsequent to operation: 0 1477 10 0 427 14. Attachments (required per 20 AAC 25.070, 25077, 8 25.263) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ❑✓ 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 ❑ susP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-399 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(rDhilcoro.com 1 Authorized Signature: J `� Date: 1 f-7 ZQ 1 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 1j`/� 74- /o.y./7 AMS '-/ OCT 0 7 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 41-07X E -Line 50-133-20510-00 1 202-025 1 9/16/19 1 9/17/19 Daily Operations: 09/16/2019 - Monday Sign in. Mobe to location. PTW and JSA. Rig up lubricator, Wait on man lift. Had several o -ring leaks. Change O -rings. PT to 250 psi low and 3,500 psi high. TP - 0 psi. RIH with GPT tool w/2.80" GR and tie into perf log. Stopped at 3,725' because didn't want to get very far into open perfs with gauge ring. Found FL at 3,176'. Ran correlation log and sent to town. Called SLB N2 to come out. They had their N2 truck at Cannery Loop. Town said GPT log was on depth and I could correlate plug log myself. SLB showed Up. PT there lines to 4,000 psi and started pumping. N2. Got fluid pushed away with about 1,700 psi and broke over down to 1,250 psi. Used approx. 700 gals of N2. Have about 400 gals left. RIH with 2.75" OD CIBP and tie into GPT log. Run correlation log. Bring N2 on line and pressured tubing up to 1,400 psi. Spotted and set plug at 3,705'. Lost 150 Ib of line tension when plug set. Waited 5 min and picked up 30'. Run back down and tagged plug. POOH. Good set. RIH w/ 2.5" x 20' dump bailer filled with 4.75 gal of 17 ppg cement and dump bailed on top of plug (13'). POOH. Good dump. RIH w/ 2.5" x 20' dump bailer filled with 4.75 gal (9.5 gals total) of 17 ppg cement and dump bailed on top of cement (26' total cement dumped). POOH. Good dump. TOC - 3,679' CIP -2100 hrs. Rig down lubricator and secure well. We will be here at 0800 hrs to perforate. 09/17/2019 -Tuesday Meet at office. Mobe to location. PTW, JSA. Rig up lubricator and pressure test to 250 psi low and 3,500 psi high. Arm gun. TP - 1,550 psi. RIH w/ 2-3/8" x 6' HC Razor, 5 spf, 60 deg phase, tie into plug log and tag TOC at 3,679'. Run correlation log and send to town. Get ok to pert from 3,639' to 3,645' with 820 psi. Bleed well down to 820 psi. Spot and fired gun with 820 psi on tubing. After 5 min pressure was 780 psi, 10 min - 700 psi and 15 min - 670 psi. POOH. All shots fired and gun was dry. TP 620 psi. Rig down equipment and turn well over to field. Move equipment to CLU -14. "-f Hilcorp Alaska ,-028142 'KB Elevation) 2/26/2002 3/5/2002 3f7/2002 Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Active Sterling Pool Derfs AS 3,639' -3,645' 6 SPF 60 Deg 09/17/19 A10 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 At 3,729' -3,755'2-3/8"x26' HSC EXP Gun 8/6/07 B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60' 7/28/07 B1 3,843'-3,853' 2-3/8"x10' SDP, 4 SPF 60' 7/28/07 B1 3,864'-3,890' 2-3/8"x26' SDP, 4 SPF 60' 7/28/07 Isolated Upper Beluga oerts 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 -4735-4756 U1 - 4764 - 4768 U2-4780-4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. R SCHEMATIC Structural Casing KBU 41-7x 133/8" J55 68 ppf TOR Bottom MD 0' 99' TVD 0' 99' Surface Casing 7" L-80 23 ppf BTC 702 Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks OC @ 3,680' MD / 3,635' TVD Isolation Plug @ 3,705' MD / 3,659' TVD Isolation Plug @ 3,810' MD / 3,761' TVD 70 Production 3-112" L-80 9.3 ppf EUE 8rd Tag Bottom a MD 0' 5,292' TVD 0' 5,231' + ` Cemented with 530 sacks, Class "G" 711 X= E i7 G zTs7 � 1@r r.7E#[E S7t a 1171 G @ 4,650- e Plug @ 4,700' Plug @ 4,875' X -Nipple @ 4,933' MD (4,923' ELMD) $ LLL !Q � IER at >1CC XX on A R, PBTD = 3,680' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: I I Ground Level (above MSL): 62' RKB (above GL): 21' Prepared By: Donna Ambruz I Last Revision Date: 10/04/19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Re: Kenai Gas Field, Upper Tyonek Beluga and Sterling 3 Gas Pool, KBU 41-07X Permit to Drill Number: 202-025 Sundry Number: 319-399 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this g day of September, 2019. RBDMS SEP 0 51019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 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: Nitrogen ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: oa Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 202-025 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20510-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A Will planned perforations require a spacing exception? Yes ❑ No ❑ Kenai Beluga Unit (KBU) 41-07X - 9. Property Designation (Lease Number): 10. Field/Pool(s): A-028142 Kenai Gas Field / Up Tyonek Beluga Gas -Sterling 3 Gas 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): 5,300' 5,239' 3,810' 3,761' 3,000 psi 4,650'; 4,875' N/A Casing Length Size MD TVD Burst Collapse Structural 99, 13-3/8" 99' 99' Conductor Surface 1,514' 7" 1,514" 1,511' 6,340 psi 3,830 psi Intermediate Production 5,292' 3-1/2" 5,292' 5,231' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A WA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; WA 12. Attachments: Proposal Summary ,. Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑+ Service ❑ 14. Estimated Date forX19 (3 Syr 15. Well Status after proposed work: Commencing Operations: .Jo'ir-e_Sg OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: ctw0 OOd hilcof .com Contact Phone: 777-8443 �-1 Z Authorized Signature. Date: µ•+ -L I ti COMMISSION SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 01 J 0101 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No p •ry■� Spacing Exception Required? RUDMS_ SEP 0 5 2019 " y Yes CI No Subsequent Form Required: l o Qy APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: F ` C I I 1 a— Submit Farm and Form),�403 RevI AOve(picatilon®aR iIy ate of approval. Aft chme is in Duplicate ra ff Hilcorp Alaska ,-028142 'KB Elevation) 2/26/2002 3/5/2002 3/7/2002 2,361, Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. SCHEMATIC Active Sterlina Pool Darts A10 3,729'-3,755'2-3/8"x 26' HSC FRCP Gun 8/6/07 At 3,715'-3,745' 2-3/8"x30' Connex 5 spf 214/16 Isolated Sterling Pool 4 Parts B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843'-3,853' 2-3/8"x10' SDP, 4 SPF 60' 7/28/07 B1 3,864'-3,890' 2-3/8"X26' SDP, 4 SPF 60` 7/28/07 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 49516 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 Production 3-1/2" L-80 9.3 ppf EUE 8rd 3R Bottom MD 0' 6,292' TVD 0' 6,231' Cemented with 530 sacks, Class "G" La T Cement Plug @ 4,650' \ Bridge Plug @ 4,700' 4ff— Plug @ 4,875' a c 3S Q E J X -Nipple @ 4,933' MD (4,923' ELMD) a c » Q S7r Q PBTD = 4,650' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Structural Casina A-028142 13-3/8" J-55 68 ppf Kenai Peninsula Mop Bottom e MD 0' 99' USA TVD 0' 99' Angle @KOP and Depth] Surface Casino KOP (TVD 7" L-80 23 ppf BTC Date Completed: TOP Bottom Ground Level (above MSL): 62' 1 MD 0' 1,614' Prepared By: TVD 0' 1,611 - I Last Revision Dale: Cemented with 140 sacks A+ Q Isolation Plug @ 3,7610' TVD Active Sterlina Pool Darts A10 3,729'-3,755'2-3/8"x 26' HSC FRCP Gun 8/6/07 At 3,715'-3,745' 2-3/8"x30' Connex 5 spf 214/16 Isolated Sterling Pool 4 Parts B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843'-3,853' 2-3/8"x10' SDP, 4 SPF 60' 7/28/07 B1 3,864'-3,890' 2-3/8"X26' SDP, 4 SPF 60` 7/28/07 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 49516 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 Production 3-1/2" L-80 9.3 ppf EUE 8rd 3R Bottom MD 0' 6,292' TVD 0' 6,231' Cemented with 530 sacks, Class "G" La T Cement Plug @ 4,650' \ Bridge Plug @ 4,700' 4ff— Plug @ 4,875' a c 3S Q E J X -Nipple @ 4,933' MD (4,923' ELMD) a c » Q S7r Q PBTD = 4,650' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth] KOP (TVD Date Completed: Ground Level (above MSL): 62' 1 RKB (above GL): 21' Prepared By: Donna Ambruz I Last Revision Dale: 02/08/16 ff Hilcorp Alaska 'KB Elevation) 2/26/2002 3/5/2002 3/7/2002 Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Active Sterling Pool Perlis 3,628'-3,634- 6 SPF 60 Deg Proposed 3,639' -3,645' 6 SPF 60 Deg Proposed 3,653' -3,661' 6 SPF 60 Deg Proposed 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 - 3,729'-3,755- 2-3/8"x26' HSC EXP Gun 8/6/07 B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843' -3,853' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 Bt 3,864'-3,890' 2-3/8"x26' SDP, 4 SPF 60° 7/28/07 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U 1 - 4735 - 4756 U1 - 4764 - 4768 U2-4780-4791 U2-4824-4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. PROPOSED SCHEMATIC Structural Casino Isolation Plug @ 3,810' MD / 3,761' TVD 13-3/8" J-55 68 ppf 23 ppf BTC Top Bottom MD 0' 99' TVD 0' 99' Surface Casing Isolation Plug @ 3,810' MD / 3,761' TVD a 7" L-60 23 ppf BTC Alaska TO Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks TOC @ 3,680' MD / 3,635' TVD - Isolation Plug @ 3,705' MD / 3,659' TVD �7 Isolation Plug @ 3,810' MD / 3,761' TVD a ICS >a Production Alaska 3-1/2" L-80 9.3 ppf EUE Plug @ 4,875' 8rd a TOR Bottom a MD 0' 5,292' I I Ground Level (above MSL): 62' TVD 0' 5,231' Prepared By: Cemented with 530 sacks, Class "G" i TOC @ 4,650' a ICi a c Bridge Plug @ 4,700' �7 6I >a ICS 3a I� Alaska Country: Plug @ 4,875' XX Angle @KOP and Depth: 3L7 � Date Completed: I I Ground Level (above MSL): 62' RKB (above GL): 21' Prepared By: X -Nipple @ 4,933' MD (4,923' ELMD) a ICI �an CS LJ Q a 16 IL PBTD = 4,650' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (ND): Date Completed: I I Ground Level (above MSL): 62' RKB (above GL): 21' Prepared By: Christina Twogood I Last Revision Date: 08128/19 H Inlcary Alaska, LL Well Prognosis Well: KBU 41-07X Date:08/28/2019 Well Name: KBU 41-07X API Number: 50-133-20510-00 Current Status: Shut In 1? — Leg: N/A Estimated Start Date: September , 2019 Rig: E -Line Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 202-025 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) AFE Number: Current Max. BHP: Max. Expected BHP: Max. Potential Surface Pressure: Max. Potential Surface Pressure Brief Well Summary — 345 psi @ 3,760' TVD — 1,580 psi @ 3,616' TVD -1,219 psi @ 3,616' TVD 3,000 psi @3,616' TVD (Based on 12/11/15 pressure survey and expected reservoir pressure) (Based on normal pressure gradient) (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) (Based on coiled tubing with Nitrogen contingency) KBU 41-07X was completed in the A10 sand in August 2007 and flowed until early 2008 when the well went down. The well was brought back online in 2013 and flowed at a stable rate of 1.5 MMSCFD before going down again in May 2014. A slickline survey in December 2015 indicated fluid level at 3,050' and sand fill at 3,725'. In January 2016 the well was bailed, swabbed and then bailed again. In February 2016 the well was bailed and then perforated in the Sterling A10 sand. The purpose of this work is to plugback the open intervals and perforate the Sterling A8 sands. Safety Concerns Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Considertank placement based on wind direction and current weatherforecast (venting Nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -line and pressure control equipment. Pressure test lubricator to 250 psi Low/3,500 psi High. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 2. If needed, RIH with GPT tool and find fluid level. If fluid level is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. RU Nitrogen Truck. 4. If needed, pressure up on well and push water back into formation. Use GPT tool to confirm Water level is at or below the existing open Sterling A10 perfs. 5. RIH with 3-1/2" CIBP and set at 3,705' MD. Dump bail 25' cement on top. 6. RU 2-3/8" 6 spf, 602 perf guns. a. All intervals maybe shot twice for up to 12 spf. K Ililcoru Mask., M 7. RIH and perforate the following intervals: Well Prognosis Well: KBU 41-07X Date: 08/28/2019 Zone Sands I Top (MD) I Btm (MD) I Top (TVD) I Btm (TVD) FT SPF Sterling A8 ±3,628' ±3,634' ±3,584' ±31590' ±6' 6 Sterling A8 ±3,639' ±3,645' ±3,595' ±3,600' +6' 6 Sterling A8 +3,653' +3,661' +3,608' +3,616' +8' 6 a. Pressure up well to 500 psi before shooting. b. Proposed perfs also shown on the proposed schematic in red font. c. Final perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. The A8 perforations in the table above are located in the Sterling Gas Pool 3 based on Conservation Order No. 510A. g. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressure before and after each perforating run. h. Record 5, 10 and 15 minute pressures after firing guns. 8. POOH. 9. RD E -line. 10. Turn well over to production. (Test SSV within 5 days of stable production on well — notify AOGCC 24 hours before testing.) r310tC1 Contingency Coiled Tubing Procedure (if unable to bail fill to PBTD): 1. MIRU Coiled Tubing. Pressure test BOPE to 250 psi Low / 4,500 psi High. Notify AOGCC 24 hrs in advance of BOPE test. 2. RIH with 1-3/4" coiled tubing and 2-1/4" jet nozzle BHA. 3. If overpulls are seen during weight checks start FCO. 4. From 3,600' start pumping down coil 800 scf/min nitrogen and .45 bbls/min 8.4 ppg water (batch mixer with F104 and M045 foam and foam breaker will be on location if needed). S. Attempt to clean out to 3,719' MD. Watch and record levels in return tank to ensure 100% returns. If fluid loss is seen attempt to increase nitrogen rate and decrease fluid rate. If returns don't increase, mix 50 bbl batch of foam. 6. Once returns indicate sand has been cleaned out, stop pumping fluid and jet well dry with nitrogen. 7. POOH w/ coil. LD 2-1/4" jet nozzle BHA. 8. RD Coiled Tubing. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E -line. Pressure test lubricator to 250 psi Low/ 3,500 psi High. 3. RIH and set 3-1/2" Casing Patch or CIBP above the zone and dump 25' of cement on top of the plug. 4. RD E -line. H fnLcom Alaska. LL Attachments: 1. Actual Well Schematic 2. Proposed Well Schematic 3. N2 Standard Operations Well Prognosis Well: KBU 41-07X Date:08/28/2019 STANDARD WELL PROCEDURE Hllearp Alaska. LU: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AA(. 2F 2Rn 1. Type of Request: Abandon ❑ Plug Perforations ❑v - Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ ' / �\ l J A JN n Suspend ❑ Perforate Q _ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development El. Stratigraphic ❑ Service ❑ 202-0 " 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20510-00-00 7. If perforating: V 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A / Statewide Spacing Will planned perforations require a spacing exception? Yes ❑ No Q Kenai Beluga Unit (KBU) 41-07X 9. Property Designation (Lease Number): 10. Field/Pool(s): A-028142 Kenai Gas Field / Up Tyonek Beluga Gas -Sterling 3 Gas -Sterling Undefined Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,300' - 5,239' 3,810' 3,761' 00 psi 4,650'; 4,875' WA Casing Length Size MD Burst Collapse Structural 99, 13-3/8" 99' 99' Conductor Surface 1,514' 7" 1,514" 1,511' 6,340 psi 3,830 psi Intermediate Production 5,292' 3-1/2" 6,29N 5,231' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic /A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary Wellbore schem ti a 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Slratigrephic ❑ Development ❑✓ ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/5/201 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑� WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true a/tthprocedure approved herein will not be deviated from without prior written approva Authorized Name: So York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: Ctwo od(Whilcorp.conn ��I1 Contact Phone: 777-8443 ')_0fF�^ -?J °I Authorized Signature: Date: 1 COMMISSION UdE ONLY Conditions of approval: Notify Commissi so that a representative may witness Sundry Number: h✓ 7llJ l Plug Integrity ❑ B Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [I Spacing Exception Required? Yes ❑ No L Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10x03 Revised 4/2017 Approved applicati rs i fo 1 on Alk he date of approval. Attachments in Duplic3(g ff Hilcorp Alaska Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP-2217' DOP - 3418' Max hole angle 17.8 Deg KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11 W, Sec. 7, S.M. Active.Ate Poot 3 oerfs >=31 Q A10 3,729' -3,755' 23/8"x 26' HSC F -XP Gun 8/6/07 W A10 3,715' -3,745' 2-3/8"x30' Connex 5 spf 2/4/16 B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843'-3,853- 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 131 3,864'-3,890' 2-3/8"x26' SDP, 4 SPF 60° 7/28/07 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1-4735-4756 U1 -4764-4768 U2-4780-4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 US - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 US - 5038 - 5056 6 SPF 60 Deg 5/5/02 SCHEMATIC Structural Cas ng 13-3/8" J-55 68 ppf Too Botto MD 0' 99' TVD 0' 99' r Surface Casing 7" L-80 23 ppf BTC Tiro Bottom MD 0' 1,514' TVD 0' 1,511' Cemented with 140 sacks Isolation Plug @ 3,760' TMD Production 3-1/2" L-80 9.3 ppf EUE 8rd TORBottom MD 0' 5,292' TVD 0' 5,231' Cemented with 530 sacks, Class "G" Cement Plug @ 4,650' Bridge Plug @ 4,700' Plug @ 4,875' X -Nipple @ 4,933' MD (4,923' ELMD) L zM �L77 �CjS L7 ra a= >0 � EPEBTD�0' MD' MD Well Name 8 Number: KBU 41-7x Lease: A-028142 County or Padsh: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Peds: Angle @KOP and Depth: KOP (ND): Date Completed: Ground Level (above MSL): 62' 1 RKB (above GL): 21' Prepared By: Donna Ambruz I Last Revision Date: 02/08/16 U Hilcorp Alaska )510-00-00 ,-028142 ' KS Elevation) 2/26/2002 3/5/2002 3/7/2002 2,361, Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg 3,429' -3,451' 6 SPF 60 Deg Proposed A8 3,628'-3,634' 6 SPF 60 Deg Proposed A8 3,639' -3,645' 6 SPF 60 Deg Proposed A8 3,653' -3,661' 6 SPF 60 Deg Proposed A10 3,715' -3,745' 2-3/8"x30' Connex 5 SPF 2/4/16 A10 3,729' -3,755' 2-3/8'X26' HSC EXP Gun 8/6/07 B1 3,833'-3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 Bt 3,843'-3,853' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,864'-3,890' 2-3/8"x26' SDR 4 SPF 60° 7/28/07 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 - 4791 U2-4824-4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, SA PROPOSED SCHEMATIC llkkL i TOC @ 3,588' MD / 3,545' TVD i Isolation Plug @ 3,608' MD / 3,565' TVD TOC @ 3,680' MD / 3,635' TVD -Isolation Plug @ 3,705' MD / 3,659' TVD aIsolation KBU 41-7x Lease: Plug @ 3,810' MD / 3,761' TVD a Country: Production 3-1/2" L-80 9.3 ppf EUE a KOP (TVD): and Tog Bottom MD 0' 5,292' TVD 0' 5,231' Cemented with 530 sacks, Class "G" TOC @ 4,650' a tct ra c Bridge Plug @ 4,700' La Q a � f Plug @ 4,875' ra a � c X -Nipple @ 4,933' MD (4,923' ELMD) » L9t G U � Q 7G1 Q PBTD = 4,650' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: Ground Level (above MSL): 62' RKB (above GL): 21' Prepared By: Christina Twogood Last Revision Date: 08/19/19 H Ilileogi A64.. LL Well Prognosis Well: KBU 41-07X Date: 08/19/2019 Well Name: KBU 41-07X API Number: 50-133-20510-00 Current Status: Shut In Leg: N/A Estimated Start Date: September 5th, 2019 Rig: E -Line Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 202-025 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) AFE Number: Current Max. BHP: Max. Expected BHP: Max. Potential Surface Pressure: Max. Potential Surface Pressure Brief Well Summary — 345 psi @ 3,760' TVD —1,580 psi @ 3,616' TVD "' 1,219 psi @ 3,616' TVD — 3,000 psi @3,616' TVD (Based on 12/11/15 pressure survey and expected reservoir pressure) (Based on normal pressure gradient) (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) (Based on coiled tubing with Nitrogen contingency) KBU 41-07X was completed in the A10 sand in August 2007 and flowed until early 2008 when the well went down. The well was brought back online in 2013 and flowed at a stable rate of 1.5 MMSCFD before going down again in May 2014. A slickline survey in December 2015 indicated fluid level at 3,050' and sand fill at 3,725'. In January 2016 the well was bailed, swabbed and then bailed again. In February 2016 the well was bailed and then perforated in the Sterling A10 sand. The purpose of this work is to plugback the open intervals and perforate the Sterling A8 and AS sands. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Considertank placement based on wind direction and current weatherforecast (venting Nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -line and pressure control equipment. Pressure test lubricator to 250 psi Low/3,500 psi High. a. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 2. If needed, RIH with GPT tool and find fluid level. If fluid level is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. RU Nitrogen Truck. 4. If needed, pressure up on well and push water back into formation. Use GPT tool to confirm Water level is at or below the existing open Sterling A10 perfs. 5. RIH with 3-1/2" CIBP and set at 3,705' MD. Dump bail 25' cement on top. 6. RU 2-3/8" 6 spf, 602 perf guns. a. All intervals maybe shot twice for up to 12 spf. ff llilmra Alaska. LD 7. RIH and perforate the following intervals: Well Prognosis Well: KBU 41-07X Date:08/19/2019 Zone Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Sterling AS +3,429' +3,451' ±3,392' ±3,413' +22' 6 Sterling A8 ±3,628' ±3,634' +3,584' ±3,590' ±6' 6 Sterling A8 ±3,639' ±3,645' ±3,595' +3,600' ±6' 6 Sterling A8 ±3,653' ±3,661' ±3,608' +3,616' ±8' 6 a. Pressure up well to 500 psi before shooting. b. Proposed perfs also shown on the proposed schematic in red font. c. Final perfs tie-in sheet will be provided in the field for exact pert intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. The A8 perforations in the table above are located in the Sterling Gas Pool 3 based on Conservation Order No. 530A. g. The AS perforations in the table above are located are located in an undefined Gas Pool and are subject to Statewide Spacing regulations. h. If the AS interval is perforated, the A8 perforation intervals will be plugged back prior to shooting the AS perforation interval. Set the 3-1/2" CIBP at 3,608' MD. Dump bail 25' of cement on top. i. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressure before and after each perforating run. j. Record 5, 10 and 15 minute pressures after firing guns. 8. POOH. 9. RD E -line. 10. Turn well over to production. (Test SSV within 5 days of stable production on well — notify AOGCC 24 hours before testing.) Contingency Coiled Tubing Procedure (if unable to bail fill to PBTD): 1. MIRU Coiled Tubing. Pressure test BOPE to 250 psi Low / 4,500 psi High. Notify AOGCC 24 hrs in advance of BOPE test. 2. RIH with 1-3/4" coiled tubing and 2-1/4" jet nozzle BHA. 3. If overpulls are seen during weight checks start FCO. 4. From 3,600' start pumping down coil 800 scf/min nitrogen and .45 bbls/min 8.4 ppg water (batch mixer with F104 and M045 foam and foam breaker will be on location if needed). 5. Attempt to clean out to 3,719' MD. Watch and record levels in return tank to ensure 100% returns. If fluid loss is seen attempt to increase nitrogen rate and decrease fluid rate. If returns don't increase, mix 50 bbl batch of foam. 6. Once returns indicate sand has been cleaned out, stop pumping fluid and jet well dry with nitrogen. 7. POOH w/ coil. LD 2-1/4" jet nozzle BHA. 8. RD Coiled Tubing. E -Line Procedure (Contingency) Well Prognosis Well: KBU 41-07X Date: 08/19/2019 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E -line. Pressure test lubricator to 250 psi Low / 3,500 psi High. 3. RIH and set 3-1/2" Casing Patch or CIBP above the zone and dump 25' of cement on top of the plug. 4. RD E -line, Attachments: 1. Actual Well Schematic 2. Proposed Well Schematic 3. N2 Standard Operations STANDARD WELL PROCEDURE Ifilcnrp Alaska. LIX NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H25/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 Davies, Stephen F (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Friday, August 30, 2019 9:16 AM To: Davies, Stephen F (CED) Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Thank you Steve. I have updated and resubmitted the sundry for KBU 41-07X. I was in the field yesterday and received notification this morning that it was received. Thank you! Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Monday, August 26, 2019 9:23 AM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Christina, The well record will be clearest if you would resubmit the sundry without the AS perfs. Please note that spacing requirements are based on distances between perforations or other take points where wells are open to a pool, regardless of whether those wells are shut-in or active. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesfdalaska.eov. From: Christina Twogood - (C) <ctwo¢ood@hilcorp.com> Sent: Thursday, August 22, 2019 4:23 PM To: Davies, Stephen F (CED) <steve.davies(talaska.eov> Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Steve, From our geologist: The A8 sands do not lie shallower than the defined Pool 3 sands. A8 defines the top of Pool 3 in reference well KU21-06 (4,175' to 4, 412' md). The nearest well that is shut-in in the A8 sands is 14-06Y which is 2, 900' away. Closest well within the Pool 3 is KU 11-08 (shut in) at —1, 800' away. The A5 sand is in the undefined pool. 21-07X is a shut in well that was Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Monday, August 26, 2019 9:23 AM To: Christina Twogood - (C) Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Christina, The well record will be clearest if you would resubmit the sundry without the AS perfs. Please note that spacing requirements are based on distances between perforations or other take points where wells are open to a pool, regardless of whether those wells are shut-in or active. Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.aov. From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Thursday, August 22, 2019 4:23 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Steve, From our geologist: The A8 sands do not lie shallower than the defined Pool 3 sands. A8 defines the top of Pool 3 in reference well KU 21-06 (-1,175' to 4.412' ntd). The nearest well that is shut-in in the AR sands is 14-06Y which is 2, 900' away. Closest well within the Pool 3 is KU 11-08 (shut in) at —1,800' away. The A5 sand is in the undefined pool. 21-0171V is a shut in well that was open in the A6' but hasn't produced for 5 years. It is the only other well in the undo. fined pool. I guess we will need a spacing czennption, for it. I'd like to move forward with this sundry with only the three A8 sand intervals at this time, with A5 to be submitted separately at a later date. Would you like me to resubmit the sundry documents without the A5 listed, or is this email sufficient? Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.eov] Sent: Thursday, August 22, 2019 2:15 PM Davies, Stephen F (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Thursday, August 22, 2019 4:23 PM To: Davies, Stephen F (CED) Subject: RE: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Steve, From our geologist The AS sands do not lie shallower than the defined Pool 3 sands. A8 defines the top of Pool 3 in reference well KU 21-06 (4,175' to 4,413' und). the nearest well that is shut-in in the A8 sands is 14-06Y which is 2,900' awmll. Closest well within the Pool 3 is KU I1-08 (shut in) at —1,800' away. The A5 sand is in the undefined pool. 21-07X is a shut in well that was open in the A6 hitt hasp 't produced for 5 years. It is the only other well in the undefined pool. I guess we will need a spacing exemption for it. I'd like to move forward with this sundry with only the three A8 sand intervals at this time, with A5 to be submitted separately at a later date. Would you like me to resubmit the sundry documents without the A5 listed, or is this email sufficient? Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Thursday, August 22, 2019 2:15 PM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Subject: [EXTERNAL] KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Christina, Hilcorp's planned A5 and A8 sand perforations in well 41-07X will lie shallower than the Sterling Pool 3, so statewide spacing requirements of 20 AAC 25.055 apply. According to my records, these planned perforations in 41-07X will lie about 2300' from existing perforations in the same stratigraphic interval in nearby well 21-07X. Since gas has been discovered, 20 AAC 25.055 (a)(4) specifies that "...a well may not be drilled or completed closer than 3000 feet from any well drilling to or capable of producing from the same pool." Hilcorp's planned perforations appear to violate statewide spacing requirements, so a spacing exception will be needed. Or am I mistaken? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Thursday, August 22, 2019 2:15 PM To: Christina Twogood - (C) Subject: KBU 41-07X (PTD 202-025; Sundry 319-387) - Spacing Question Christina, Hilcorp's planned A5 and A8 sand perforations in well 41-07X will lie shallower than the Sterling Pool 3, so statewide spacing requirements of 20 AAC 25.055 apply. According to my records, these planned perforations in 41-07X will lie about 2300' from existing perforations in the same stratigraphic interval in nearby well 21-07X. Since gas has been discovered, 20 AAC 25.055 (a)(4) specifies that "...a well may not be drilled or completed closer than 3000 feet from any well drilling to or capable of producing from the same pool." Hilcorp's planned perforations appear to violate statewide spacing requirements, so a spacing exception will be needed. Or am I mistaken? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(aalaska.eov. RECEIVED 1 STATE OF ALASKA AAA OIL AND GAS CONSERVATION COM SION MAR 21 2016 REPORT OF SUNDRY WELL OPERATIONS AOCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate E Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Li 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development [] Exploratory ❑ 202-025 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20510-00 7.Property Designation(Lease Number): 8.Well Name and Number: A-028142 Kenai Beluga Unit(KBU)41-07X 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Gas Field/Up Tyonek Beluga Gas-Sterling 3 Gas 11.Present Well Condition Summary: 3,810'; Total Depth measured 5300 feet Plugs measured 4,650';4,875' feet true vertical 5239 feet Junk measured N/A feet Effective Depth measured 3810 feet Packer measured N/A feet true vertical 3761 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural 78' 13-3/8" 99' 99' Conductor Surface 1,493' 7" 1,514' 1,511' 6,340 psi 3,830 psi Intermediate Production 5,271' 3-1/2" 5,292' 5,231' 10,160 psi 10,540 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 63 Subsequent to operation: 0 0 0 0 21 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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 Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Li GINJ ❑ SUSP Li SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-032 Contact Taylor Nasse-777-8354 Email tnasse(a hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature r/; :.% Phone 907-777-8405 Date 3At,I 6. s �3 /` MAR 222016 OriginalOnly Form 10-404 Revised 5/2015 ��/ RBDMS L(/ Submit • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 41-07X E-Line 50-133-20510-00 202-025 2/4/16 2/4/16 Daily Operations: 02/04/2016-Thursday Meet at office. Mobe to location. PTW,JSA and spot equipment. Rig up lubricator and pressure test to 250 psi low and 1,000 psi high. Arm gun. RIH w/2-3/8" x 30' Connex, 5 spf. 60 deg phase and tie into RST log sent by Taylor.Tool set down at 3,745' which was 10' shallow from where we wanted to perf. Ran correlation log and sent to town.Town decided to perf from 3,715'to 3,745'. Bleed well down to 71 psi and spotted shot. Fired shot with 91 psi on tubing and pressure went to 105 psi and 115 psi after 5 min. POOH all shots fired.TP was at 126 psi. Rig down lubricator and turn well over to field. ` KBU 41 -7x Pad 41-7SCHEMATIC 179' FNL, 4,3553' FWL Hilcorp Alaska T4N, R11W, Sec. 7, S.M. Permit#: 202-025 API#: 50-133-20510-00-00 i . Property Des: A-028142 KB: 21'AGL(83'KB Elevation) Structural Casing 13-3/8" J-55 68 ppf Spud Date: 2/26/2002 Top Bottom Reached TD: 3/5/2002 MD 0' 99' Rig Released: 3/7/2002 ND 0' 99' X: 275,251 I. 2,361,771 I Z 1 Surface Casing Chemical injection Mandrel @ 117" L-80 23 ppf BTC 1461' 1/4", 0.049 wall SS Top Bottom control line TVD 0'MD 0' 1,514' 1" sidepocket injection valve Cemented with 140 sacks Directional: Q KOP-2217' — 3,810' MD DOP-3418' I Isolation Plug @ 3,761' TVD Max hole angle 17.8 Deg or ? Production Active Sterling Pool 3 perfs a i= 3-1/2" L-80 9.3 ppf EUE a 8rd A10 3,729'-3,755'2-3/8"x 26'HSC EXP Gun 8/6/07 Top Bottom A10 3,715'-3,745'2-3/8"x30'Connex 5 spf 2/4/16 - 11 I MD o' 0' 5,292' ND 5,231' Cemented with 530 sacks,Class"G" FW Isolated Sterling Pool 4 perfs F°� . Cement Plug @ 4,650' B1 3,833'-3,843' 2-3/8"x10'SDP,4 SPF 60° 7/28/07 cm _ B1 3,843'-3,853' 2-3/8"x10'SDP,4 SPF 60° 7/28/07 , , Bridge Plug @ 4,700' B1 3,864'-3,890' 2-3/8"x26'SDP,4 SPF 60° 7/28/07 Isolated Upper Beluga perfs '° ICI I 2-3/8"HSC,4SPF,60 Deg 12/16/03 a Plug @ 4,875' U 1 -4735-4756 ..- U1 -4764-4768 a Q U2-4780-4791 at U2-4824-4836 U5-4892-4910 6 SPF 60 Deg 8/16/02 U5-4913-4922 6 SPF 60 Deg 8/16/02 1, X-Nipple @ 4,933' MD (4,923' ELMD) U6-4942-4951 6 SPF 60 Deg 8/16/02 U7-4992-5002 6 SPF 60 Deg 5/5/02 U7-5012-5026 6 SPF 60 Deg 5/5/02 a U8-5038-5056 6 SPF 60 Deg 5/5/02 =I Q U rs cc xa cx Jill LL PBTD=4,650'MD TD=5,300'MD Well Name&Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth:! KOP(TVD): Date Completed: Ground Level(above MSL): 62' RKB(above GL): 21' Prepared By: Donna Ambruz Last Revision Date: 02/08/16 VOF T7t �\ yy,�6.A THE STATE Alaska Oil and Gas '4'70T • OfA LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA 6ltt' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Upper Tyonek Beluga Unit(KBU)41-07X Permit to Drill Number: 202-025 Sundry Number: 316-032 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, 19-44. ) Cathy P oerster �, Chair DATED this�day of January, 2016. RBDMS 0-- JAN 2 1 2016 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 4 01 5 APPLICATION FOR SUNDRY APPROVALS A GAOG�Z°��`� 20 AAC 25.280 ' 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. CICO N — 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: FL C Exploratory ❑ Development 0• 202-025 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20510-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A ' Kenai Beluga Unit(KBU)41-07X • ❑ Will planned perforations require a spacing exception? Yes ❑ No - 9. Property Designation(Lease Number): 10. Field/Pool(s): . A-028142 • Kenai Gas Field/Up Tyonek Beluga Gas-Sterling 3 Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 3,810'; Junk(MD): 5,300' • 5,239' ' 3,810' 3,761' 300psi 4,650';4,875' N/A Casing Length Size MD TVD Burst Collapse Structural 99' 13-3/8" 99' 99' Conductor Surface 1,514' 7" 1,514' 1,511' 6,340 psi 3,830 psi Intermediate Production 5,292' 3-1/2" 5,292' 5,231' 10,160 psi 10,540 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Proposal Summary 0 Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development n Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 27,2016 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( hiICOrD.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date //g //(,, COMMISSION USE ONLY i Conditions of approval: Notify Commission so that a representative may witness Sundry Number o ' 3\ Le - o32 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: /r y�0L $ ��/ /e S 1`— (Cr-) Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes No L'J l Subsequent Form Required: ti"'4-1D Li Qii, APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: /— - /6 0i /-,26ftfrdJjja, fl� � At 04 ` , .,Submit Form/and 4 Form 10-403 Revis 11/2015 Es:alid fpj' ,QM 5 from theO a al. Attachments it Duplicate Well Prognosis Well: KBU 41-07X Ililcor)Alaska,LU Date: 1/13/2016 Well Name: KBU 41-07X API Number: 50-133-20510-00 Current Status: Shut In Leg: N/A Estimated Start Date: Jan. 27, 2016 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 202-025 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: Maximum Expected BHP: — 345 psi @ 3,760' TVD (Based on 12/11/15 pressure survey and expected reservoir pressure) Max. Potential Surface Pressure: — 300 psi (Based on pressure survey and calculated gas gradient) Brief Well Summary KBU 41-07X was completed in the A10 sand in August 2007 and flowed until early 2008 when the well went down. The well was brought back online in 2013 and flowed at a stable rate of 1.5 MMSCFD before going down again in May 2014. A slickline survey in December 2015 indicated fluid level at 3,050' and sand fill at 3,725'. The purpose of this work/sundry is to clean out well to PBTD and perforate the Sterling A-10 and A-11 intervals. Safety Concerns—if coiled tubing work is performed • Discuss nitrogen asphyxiationconcerns and identify any areas where nitrogen could collect and people could enter. . F/ la,-L(4.' • Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) • Ensure all crews are aware of stop job authority Slickline Procedure 1. MIRU SL and PT lubricator to 1,000 psi Hi 250 Low. 2. RIH w/bailer and bail fill to PBTD of 3,810'. 3. RIH w/swab cups and swab well dry. 4. RD SL. Contingency Coiled Tubing Procedure (if unable to bail fill to PBTD): 5. MIRU Coiled Tubing, PT BOPE to 250 low/4,500 psi high. Notify AOGCC 24 hrs. in advance of BOP test. TI 6. RIH w/ 1-3/4" coiled tubing and 2-1/4"jet nozzle BHA. 7. If overpulls are seen during weight checks start FCO. 8. From 3,700' start pumping down coil 800 scf/min nitrogen and .45 bbls/min 8.4 ppg water(batch mixer with F104 and M045 foam and foam breaker will be on location if needed). 9. Attempt to cleanout to top of plug at 3,810' MD. Watch and record levels in return tank to ensure 100% returns. If fluid loss is seen attempt to increase nitrogen rate and decrease fluid rate. If returns don't increase, mix 50 bbl batch of foam. 10. Once returns indicate sand has been cleaned out, stop pumping fluid and jet well dry with nitrogen. • II Well Prognosis Well: KBU 41-07X HiIcorp Alaska,LL Date: 1/13/2016 11. POOH w/coil. LD 2-1/4"jet nozzle BHA. 12. RD Coiled Tubing. E-Line Procedure 13. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/1,000 psi high. a. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 14. Perforate the Tyonek sands with 2-3/8" 5 SPF 60 deg phased perf guns. All intervals are planned for 10 SPF so each may be shot twice. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Sterling A-10 ±3,725 ±3,755 ±30 • Sterling A-11 ±3,779 ±3,809 ±30 15. POOH. 16. Bleed off nitrogen and flow well through test separator and record water and gas rates. 17. If any of the sands are not commercial or wet, the zone will be permanently plugged back. 18. RD e-line. Attachments: 1. Actual and Proposed Schematic 2. Coil BOPE Schematic 3. CT Flow Diagram KBU 41 -7x CURRENT SCHEMATIC Permit#: 202-025 Pad 41-7 API#: 50-133-20510-00-00 FNL 4 353' FWL Property Des: A-028142 > > KB: 21'AGL(83'KB Elevation) T4N, R11 W, Sec. 7, S.M. 11 Spud Date: 2/26/2002 Reached TD: 3/5/2002 — Rig Released: 3/7/2002 HiCOt'�7 Alaska X: 275,251 Y Y: 2,361,771 Structural Casing 13-3/8" J-55 68 ppf Top Bottom MD 0' 99' Chemical injection Mandrel @ , TVD 0' 99' 1461' 1/4", 0.049 wall SS — control line 1" sidepocket injection valve ii Surface Casing L-80 23 ppf BTC Top Bottom MD 0' 1,514' TVD 0' 1,511' Directional: r Cemented with 140 sacks KOP-2217' ri" DOP-3418' — Max hole angle 17.8 Deg _ IG 3,810' MD '' 1 isolation Plug @ 3,'761' TVD Production Active Sterling Pool 3 perfs xni Q 3-1/2" L-80 9.3 ppf EUE xni 8rd A10 3,729'-3,755'2-3/8"x 26'HSC EXP Gun 8/6/07 Top Bottom TVDIN I MD 0' 0' 5,231 5,231' Cemented with 530 sacks,Class"G" Isolated Sterling Pool 4 perfs 7 : Cement Plug @ 4,650' B1 3,833'-3,843' 2-3/8"x10'SDP,4 SPF 60° 7/28/07 a _ B1 3,843'-3,853' 2-3/8"x10'SDP,4 SPF 60° 7/28/07 Bridge Plug @ 4,700' B1 3,864'-3,890' 2-3/8"x26'SDP,4 SPF 60° 7/28/07 Isolated Upper Beluga perfs 2-3/8"HSC,4SPF,60 Deg 12/16/03 titl. .. '4 Plug @ 4,875' U 1 -4735-4756 U1 -4764-4768 =a U2-4780-4791 =a Q U2-4824-4836 U5-4892-4910 6 SPF 60 Deg 8/16/02 U5-4913-4922 6 SPF 60 Deg 8/16/02 X-Nipple @ 4,933' MD (4,923' ELMD) U6-4942-4951 6 SPF 60 Deg 8/16/02 U7-4992-5002 6 SPF 60 Deg 5/5/02 U7-5012-5026 6 SPF 60 Deg 5/5/02 3=11 '1= U8-5038-5056 6 SPF 60 Deg 5/5/02 LI 1:I Q a c A LI PBTD=4,650'MD TD=5,300'MD Well Name&Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP(TVD): Date Completed: Ground Level(above MSL): 62' RKB(above GL): 21' Prepared By: Kevin Skiba Last Revision Date: 08/30/07 KBU 41 -7X PROPOSED SCHEMATIC ' Permit#: 202-025 Pad 41-7 API#: 50-133-20510-00-00 179' 4 353' FWL Property Des: A-028142 FNL, > KB: 21'AGL(83'KB Elevation) T4N, R11 W, Sec. 7, S.M. Spud Date: 2/26/2002 Reached TD: 3/5/2002 _ — Rig Released: 3/7/2002 HilCOI'p la, k_� X: 275,251 Y: 2,361,771 Structural Casing 13-3/8" J-55 68 ppf Top Bottom MD 0' 99' Chemical injection Mandrel @ TVD 0' 99' 1461' 1/4", 0.049 wall SS -� control line 1" sidepocket injection valve Al I oh, Surface Casing7" L-80 23 ppf BTC T� Bottom MD 0' 1,514' TVD 0' 1,511' Directional: Cemented with 140 sacks KOP-2217' DOP-3418' — rQ Max hole angle 17.8 Deg . /,, CM 3 810' MD _._.., Isolation Plug @ 3,761' TVD € E3 Production Active Sterling Pool 3 perfs a " rQ 3-1/2" L-80 9.3 ppf EUE a I.= 8rd A10 3,729'-3,755'2-3/8"x 26'HSC EXP Gun 8/6/07 Top Bottom .10 3,125'- ,/55'2-318x30' PROPOSED IliMD 0' 5,292' 11 3,779'-3,809'7 110, 0'r' "Y Rr)POSED - TVD h' 5,2 Cemented with 530 sacks,,Class"G" Isolated Sterling Pool 4 perfs r Cement Plug @ 4,650' B1 3,833'-3,843' 2-3/8"x10'SDP,4 SPF 60° 7/28/07 Q B1 3,843'-3,853' 2-3/8"x10'SDP,4 SPF 60° 7/28/07i , Bridge Plug @ 4,700' B1 3,864'-3,890' 2-3/8"x26'SDP,4 SPF 60° 7/28/07 Isolated Upper Beluga perfs a=' 2-3/8"HSC,4SPF,60 Deg 12/16/03 #Y iPlug @ 4,875' U 1 -4735-4756 1 U 1 -4764-4768 3=311 rQ U2-4780-4791 rA __ U2-4824-4836 U5-4892-4910 6 SPF 60 Deg 8/16/02 U5-4913-4922 6 SPF 60 Deg 8/16/02 X-Nipple @ 4,933' MD (4,923' ELMD) U6-4942-4951 6 SPF 60 Deg 8/16/02 11 1 U7-4992-5002 6 SPF 60 Deg 5/5/02 U7-5012-5026 6 SPF 60 Deg 5/5/02 3=11 IC= U8-5038-5056 6 SPF 60 Deg 5/5/02 =II CI =1111 /1/C=C Q PBTD=4,650'MD TD=5,300'MD Well Name&Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP(TVD): Date Completed: Ground Level(above MSL): 62' RKB(above GL): 21' Prepared By: Taylor Nasse Last Revision Date: 12/30/15 § 81 : 'I O b 4 U g1 J N wm D N z 3 t Y m-_-, 8 .7 z ] I a w C I D U QN°oL 1K Li J •41 0 U J O a` 0 4r -0 Iii' 0 III!II.lI, .ISI . 4 5t in wi nn nn — • A 3 ji. y E . a 1 ., E a k i a 1t IC'' ...'",•. .....,7 li 3g C H O, OOU5 O, 10 . x 5 U 0 ` 6 E i Kenai Gas Field , ll- COIL BOPE KBU 41-07X 1/4/2016 Hih.,r t $1.i.k...1.1 t.. KBU 41-07X 133/8X7X3'/2 Coil Tubing BOP Lubricator to injection head Lai IA) 1.75"Tandem Stripper 1 1.',I, Blind/Shear=min 1/16 10 =.Blind/Shear III'. r .11 M. MINI- IIIIIIIIM 1,1 j .1i1t Blind/Shear = 5 Blind/Shear ,I1'J al= 111111; O% - _ Slip 5' Slip ,I,'•I0 tFl1 s MM 2111111Mud Cross 10111 Pipe •= _= Pipe �I�'• 4 1/16 10M X 41/16 10M Outlet r w/2-2 1/16 10M full opening FMC valves 111-111 i IIIIIi ] MI = i `II. I i[ o I ]NI Mel III i - Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 3 1/8 5M 34Ac 340 J.Je E� • Valve,Swab, cpI\ 3e 34 (.& • 3 1/8 5M FE,HWO �7`r-a 3ti1 3a� age N Valve, Upper Master, .c , 3 1/8 5M FE,HWO ` � ` Valve,Lower Master, eta" 3 1/8 5M FE,HWO I I I I IMIlaa l� -( Grade Level Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q~ - O'J-$ Well History File Identifier DIGITAL DATA /Rescan Needed OVERSIZED (Scannable) Organizing 1,1,,",\ 7E CAN . Color items: 0 Two-Silled 0 Diskettes. No. 0 Maps: 0 Grayscale items: 0 Other. NofType 0 Other items scannable by large scanner 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds NOTES: B(: BEVERL'( ROBIN VINCENT SHER'(L &IND" 1£ 0 Other DATE7f9 d¡ Isl v~1f Project Proofing B'(. BEVERL'( ROBIN VINCENT SHERYL -PjNIND'r' DATE:1/r¡d¡-/SI J11!J 3 x 30 = 1ð + 1(:1 = TOTAL PAGES ¡OJ VINCENT SHE"'''~INDI DATE:7!~~/SI V/1fJ Scanning Preparation BY, BEVERL'( ROBIN Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: lOr PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: þES NO Bo': BEVERLY ROBIN W'CENT SHE"" ÐVIND' DATE '6' '3(Ot/S,' V¡,W Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO B (: BEVERLY ROBIN VINCENT SHER'(L MARIA WIND'( DATE. 151 ISc...rJIl,rIG IS COMPlE rE ^T THIS POINr urlLESS SPECIAL AITErmON IS REQUIPED or! AN IrIQIVlDUlIl PAGE BASIS DUE fO QUAl! r f. GAA (SCALE O~ COlOR IMAGES) ReScanned 111/,/,\ ',",',. :1 pl'1 ' ''''f''''" :.11,111{ ,!F!','I; ',f . 01'''''''' """,'))1"/,'(11 RESCANNED B''': BEVERL'( ROBIN VINCENT SHERYL MARI.I\ WINDY DATE: ISI General Notes or Comments about this file: Quality Checked Id,"I"1 12/10/02Rev3NOTScanned wpd STD 2~2-~~~~ M Marathon MARATHON Oil Company June 24, 2008 .Marathon Oil Company Alaska Asset Team ~'°' P.O. Box 1949 ~'~- Kenai, AK 99611 Telephone 907/283-1371 aUN 2 ~ X008 Fax 907/283-1350 4, ; Ccm~;~~or~ plas~a Oil ~ A~~'"~~~~e Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-421 Open Flow Potential Test Report Field: Kenai Gas Field ,: r:; ~~~~ Well: Kenai Beluga Unit 41-7x ~~~~`~ ~~~ Dear Mr. Maunder: As you are aware, we have been reviewing our files to locate and correct any reporting deficiencies. We have also been developing a Data Base to help us track our regulatory activities. The latest revision of the Data Base identified a missing 10-421 Open Flow Potential Test Report. Enclosed for your records is the Open Flow Potential Test Report for KBU 41-7x well. The Beluga formation, in KBU 41-7x, was isolated in late July of 2007. The well was then re-completed into the Sterling Pool 3 zone on August 6, 2007. KBU 41-7x is a low pressure well that has a flowing pressure of ~ 13 psi. This limits our ability to vary the rate and pressure of this well. Thus, the information provided, on the 10-421 Report, is the result of data collected from a one point test. If you have any questions or require additional information, please call me at (907) 283- 1371. Sincerely, .~~ ,Jti>ti •~ Kevin J. Skiba Engineering Technician Enclosures: 10-421 Open Flow Report cc: Houston Well Fife Kenai Well File KJS STATE OF ALASKA ;,I ALAS AND GAS CONSERVATION COMMIS GAS WELL OPEN FLOW POT~~ii~--~`'~'~`~ST l~EP4RT 1a. Test: ~ Initial Annual Special 1b. Type Test: ~ Stabilized Non Stabilized Multipoint ^ Constant Time ^ Isochronal ^ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill #: 202-025 Marathon Oil Company 5/5/2002 Sundry#: 307-238 3. Address: 6. Date TD Reached: 12. API Number: PO Box 1949, Kenai Alaska, 99611-1949 3/6/2002 50-133-20510-00-00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 238' FNL, 4,346' FWL, Sec. 7, T4N, R11W, S.M. 87' above MSL, 21' above GL Kenai Beluga Unit 41-7x Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 217' FNL, 3,993' FWL, Sec. 7, T4N, R11W, S.M. 3,810' MD 3,761' TVD Kenai Gas Field / Total Depth: 9. Total Depth (MD + TVD): Beluga & Sterling Pools 191' FNL, 3,836' FWL, Sec. 7, T4N, R11W, S.M. 5,300' MD 3,761' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 275,251.28 Y- 2,361,771.21 Zone- 4 A - 028142 TPI: x- 274,898.66 Y- 2,361,799.17 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 274,742.13 Y- 2,361,827.37 Zone- 4 Monobore 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 3-1/2" 9.3 ppf 2.992" 5,362' MD Active (MD): 3,729' - 3,755' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. NA NA NA NA 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): NA - - 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): ^ Tubing /^ Casing 135.3 F° 62.4 psia @ Datum 3,ggQ TVDSS 14.73 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % COZ: % N2: % HZS: Prover: Meter Run: Taps: 3,729' MD 3,682' TVD 0.617 0.638 0.043 0 Facility 26. FLOW DATA TUBING DATA CASING DATA No Prover Choke Line X Orifice Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow . psig Hw F° psig F° psig F° Hr. Size (in.) Size (in.) 1 • 3,826 X 1.000 13 27 52 - - - - 4.00 2. X 3. X 4. X 5. X Basic Coefficient ~ Pressure Flow Temp. F Gravity Factor Super Comp. F t Rate of Flow No. (24-Hour) h Pm actor F 9 or ac O~ Mcfd Fb or Fp Ft Fpv 1. 14.70510212 37.469988 27.73 1.00 1.336 1.0287 551 2. 3. 4. 5. for Separator for Flowing No. Pr Temperature Tr z Gas Fluid T Gg G 1. 0.04 460 1.34 0.945 0.617 NA 2. 3. Critical Pressure 673.1 4. Critical Temperature 343.2 5. Form 10-421 Revis S ~F~, ~~-~„ d 200~ONTINUED ON REVERSE SIDE ~~ Submit in Duplicate ~3v 1 Pc 57 Pct 3218.2929 ~ Pf ~ p{~ 25. AOF (Mcfd) Remarks: I hereby certify that the foregoing is true and qrr Signed v 640 to the best of my knowledge. Title Engineering Technician n 0.750 Date June 24, 2008 No. Pt Ptz Pct-Ptz Pw Pub Pct-Pv~ Ps PsZ Pf -Psz 1 • 28 763.4169 2. 3. 4. 5. DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ h Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= ~ dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 M Marathon MARATHON Oil Company August 30, 2007 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 E~~iVEC~ Mr. Tom Maunder ~Ep Q 4 ~0Q7 Alaska Oil & Gas Conservation Commission 333 W 7th Ave Alaska Oii & Gas Cons. Cnmmissiari Anchorage, Alaska 99501 Anchorag# Reference: 10-407 Completion Report N0~ ~, ~ ~~01 ~ ~ j Field: Kenai Gas Field ~~ ~~ Well: KBU 41-7x Dear Mr. Maunder: Attached and submitted for your records is a Completion Report 10-407 for well KBU 41-7x. The Beluga formation was recently isolated, as witnessed by the AOGCC field representative. The well was recompleted into the Sterling Pool 4, B1 sand. No gas production was realized from this zone which was then isolated utilizing a bridge plug. Activities then moved up hole to the Sterling Pool 3 zone. The A10 sand was then perforated leading to the current production of 0.5MM at 12 psi flowing pressure. If you have any questions or need additional information please contact me at (907) 283- 1371. Please direct any returning correspondences to me utilizing the address in the letterhead. Sincerely, .~s,~.~ Kevin J. Skiba Production Technician Enclosures: 10-407 Completion Report cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD h : ~ ~ a"y< <td~ s Co~t.SiS '~c.~~f ~ ~- `/( ~ ~!-h, ~ >~ r~ ~l~TATE OF ALASKA ~ d 'Y'',~''~ /o ~ • '~'-is A~LOIL AND GAS CONSERVATION COM ION ~~s'`°f ELL COMP I PO~~ LET ON OR RECOMPLETION tR ~ S E P 0 ~ 200? ~~{I~ ~,~1 (~,01"ftmissiarl 1 II S~tatysj _ ~ it G ~ Plu ed Abandoned ^ Suspended ^ _ ~ ll lOt- ~~ `u ~4o's zor,~c zs.~ ~o GINJ^ WI DSPL^ WAG^ they^~/ No. ofCompletio 1b. Well Class: Development Q Exploratory ^ rvice ^ StratigraphicTest^ 2. Operator Name Marathon Oil Company 5. Date Co p., S ~/ ,,q~,,~ Aband ~ ~i~~!~ p2 ~L 2. P it to Drill N tuber: ~ 202-025 " 3. Address: PO Box 1949 Kenai Alaska 99611-1949 6. Date Spu ~ 2/27120 13. I Number: , 50-133-20510-00-00 4a. Location of Well (Governmental Section): Surface: 238' FNL, 4,346' FWL, Sec. 7, T4N, R11W, S.M. 7. Date TD Reached: 3/6/2002 14. Well Name and Number: Kenai Beluga Unit 41-7x Top of Productive Horizon: 217' FNL, 3,993' FWL, Sec. 7, T4N, R11W, S.M. 8. KB (ft above MSL}: 21' Ground (ft MSL): 66' 15. Field/Pool(s): Total Depth: 191' FNL, 3,836' FWL, Sec. 7, T4N, R11 W, S.M. 9. Plug Back Depth(MD+TVD): 3,810' MD 3,761' ND Kenai Gas Field /Beluga 8~ Sterling Pools 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 275,251.28 y- 2,361,771.21 Zone- 4 10. Total Depth (MD + TVD): 5,300' 5,239' - 16. Property Designation: A - 028142 TPI: x- 274,898.66 y- 2,361,799.17 Zone- 4 Total Depth: x- 274,742.13 y- 2,361,827.37 Zone- 4 11. SSSV Depth (MD + TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050} 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071 }: Gamma Ray, CCL 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8" 68# K-55 0' 99' 0' 99' Driven NA NA 0 7" 23# L-80 0' 1,515' 0' 1,512' 8-1/2" 140 sks (to surface) NA 0 3-1/2" 9.3# L-80 0' 5,292' 0' 5,231' 6-1/8" 530 sks NA 0 23.Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Tap 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET {MD) NA NA NA ' ' ' ' ' - 3,755 3,729 MD 3,682 - 3,707 2.3/8" EXP TVD 26 3 833' 3 843' MD 3 793' 83' 3 ' 2 / " 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , - , ,7 - , -3 ND 10 8 4SPF 3 843' - 3 853' MD 3 793' - 3 803' ND 10' 2-3/8" 4SPF DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED , , , , 3,864' - 3,890' MD 3,813' - 3,839' ND 26' 2-3/8" 4SPF 26. PRODUCTION TEST Date First Production: g/7/2007 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 8/22!2007 Hours Tested: 24 Production for Test Period Oil-Bbl: 0 Gas-MCF: 535 Water-Bbl: 0.5 Choke Size: 4" Gas-Oil Ratio: 0 Flow Tubing Press. 12 0 Calculated 24Hour Rate ~-- Oil-Bbi: 0 Gas-MCF: 535 Water-Bbl: 0.5 Oil Gravity -API (corr): NA 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewal! Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COfJPLETiOIv ~Bt.~UIS BFI SEP 2 810D7/ Form 10-407 Revised 2/2007 ~ R ~ ~ ~ n~ QC~NTINUED ON REVERSE ~`~~~o~ STATE OF ALASKA '~~''~ SAP Q `~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPC~~~ ~l~IbsE~Q(~~""m'sst°~ 1a. Well Status: Oil ^ Gas 0 Plugged ^ Abandoned ^ Suspended ^ zoanczs.los 20AAC25.110 GINJ^ WINJ^ WDSPL^ WAG^ Other^ No. of Completions: 1 b. Well Class: ' Development ~ Exploratory^ Service ^ StratigraphicTest^ 2. Operator Name: Marathon Oil Company 5. Date Comp., S}~ ~ Aband.: ?~~~2 2. Permit to Drill N tuber: ~ ~D 202-025 " 3. Address: PO Box 1949, Kenai Alaska, 99611-1949 6. Date Spudded: ~ 2/27/2002 13. API Number: 50-133-20510-00-00 4a. Location of Well (Governmental Section): Surface: 238' FNL, 4,346' FWL, Sec. 7, T4N, R11W, S.M. 7. Date TD Reached: 3/6/2002 14. Well Name and Number: Kenai Beluga Unit 41-7x Top of Productive Horizon: 217' FNL, 3,993' FWL, Sec. 7, T4N, R11W, S.M. 8. KB (ft above MSL): 21' Ground (ft MSL): g6' 15. Field/Pool(s): Total Depth: 191' FNL, 3,836' FWL, Sec. 7, T4N, R11W, S.M. 9. Plug Back Depth(MD+TVD): 3,810' MD 3,761' TVD Kenai Gas Field /Beluga & Sterling Pools 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 275,251.28 y- 2,361,771.21 Zone- 4 10. Total Depth (MD +TVD): 5,300' 5,239' - 16. Property Designation: A - 028142 TPI: x- 274,898.66 y- 2,361,799.17 Zone- 4 Total Depth: x- 274,742.13 y- 2,361,827.37 Zone- 4 11. SSSV Depth (MD +TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gamma Ray, CCL 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8" 68# K-55 0' 99' 0' 99' Driven NA NA 0 7~ 23# L-80 0' 1,515' 0' 1,512' 8-1/2" 140 sks (to surface) NA 0 3-1/2" 9.3# L-80 0' 5,292' 0' 5,231' 6-1/8" 530 sks NA 0 23. Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) NA NA NA ' ' 3,729' - 3,755' MD 3,682 - 3,707' ND 26 2-3/8" EXP ' ' ' ' " ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - 3,843 - 3,793 2-3/8 3,833 MD 3,783 ND 10 4SPF 3 843' - 3 853' MD 3 793' - 3 803' TVD 10' 2-3/8" 4SPF DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED , , , , 3,864' - 3,890' MD 3,813' - 3,839' TVD 26' 2-3/8" 4SPF 26. PRODUCTION TEST Date First Production: 8/7/2007 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 8/22/2007 Hours Tested: 24 Production for Test Period Oil-Bbl: 0 Gas-MCF: 535 Water-Bbl: 0.5 Choke Size: 4" Gas-Oil Ratio: 0 Flow Tubing Press. 12 0 Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: 535 Water-Bbl: 0.5 Oil Gravity -API (corr): NA 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COt~rf'LF r i01v~ ~~ S ~F~ SEP 2 81007 .D -D~ Form 10-407 Revised 2/2007 0 R ~ ~ ~ N /~ CpNTINUED ON REVERSE ~/_ /~G 11"9 r P-~ ~' l i! G I It 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost -Top detailed test information per 20 AAC 25.071. Permafrost -Base Sterling A10 Sand 3,707' 3,661' Sterling B1 Sand 3,832' 3,782' Formation at total depth: Upper Beluga 4,729' 4,668' 30. List of Attachments: Daily Operations Summary and Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Dennis Don van Title: Production Engineer Signature: Phone: (907) 283-1333 Date: 8/30/2007 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base ofi permafrost in Box 28. item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas lnjection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 is 50-133-20510-00-00 ertv Des: A - 028142 21' AGL (83' KB Elevation) I Date: 2/26/2002 KBU 41-7x Pad 41-7 179' FNL, 4,353' FWL T4N, R11W, Sec. 7, S.M. Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Active Sterling Pool 3 perfs 1.a a A10 3,729' -3,755' 2-3/8"x 26' HSC EXP Gun 8/6/07 ~j Isolated Sterling Pool 4 perfs 61 3,833' -3,843' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 B1 3,843' -3,853' 2-3/8"x10' SDP, 4 SPF 60° 7/28/07 61 3,864'-3,890' 2-3/8"x26' SDP, 4 SPF 60° 7/28/07 Isolated Upger Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U 1 - 4735 - 4756 U 1 - 4764 - 4768 U2 - 4780 - 4791 U2 - 4824 - 4836 U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 1---- --- - - -- - --l Structural Casing 13-318" J-55 68 ppf ~' ~ Bottom MD 0' 99' TVD 0' 99' Surface Casing 7" L-80 23 ppf BTC + Tom Bottom MD 0' 1,514' ND 0' 1,511' Cemented with 140 sacks Q Q 3,810' MD ~- Isolation Plug @ 3,761' TVD a ~\ to a a >Q mt is Production 3-112" L-80 9.3 ppf EUE 8rd T~ Bottom MD 0' 5,362' ND 0' 4,877' Cemented with 530 sacks, Class "G" Cement Plug @ 4,650' Bridge Plug @ 4,700' Plug @ 4,875' X-Nipple @ 4,933' MD (4,923' ELMD) at a a rs ~ ~ a ~s PBTD = 4,650' MD TD = 5,300' MD Well Name & Number: KBU 41-7x Lease: A-028142 County or Parish: Kenai Peninsula State/Prov.: Alaska Country: USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: Ground Level (above MSL): 62' RKB (above GL): 21' ~.ev S„it; v~i'~v' Marathon Oil. Company Page 1 of 2 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 41-7X Common Well Name: KENAI BELUGA UNIT 41-7X Spud Date: 2/26/2002 Event Name: ABANDONMENT Start: 7/27/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 10/6/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To I Hours Code Code Phase Description of Operations 7/28/2007 08:00 - 09:00 1.00 SAFETY MTG_ PLUGAB 09:00 - 10:00 1.00 RURD_ ELEC PLUGAB 10:00 - 10:25 0.42 LOG_ CSG_ PLUGAB 10:25 - 10:35 0.17 LOG_ CSG_ PLUGAB 10:35 - 11:25 0.83 LOG_ CSG_ PLUGAB 11:25 - 12:00 0.58 LOG_ CSG_ PLUGAB 12:00 - 12:15 0.25 SAFETY MTG_ PLUGAB 12:15 - 13:20 1.08 LOG_ CSG_ PLUGAB 13:20 - 13:40 0.33 LOG_ CSG_ PLUGAB 13:40 - 14:08 0.47 SAFETY MTG_ PLUGAB 14:08 - 14:20 0.20 DUMPB CMT_ PLUGAB 14:20 - 14:45 0.42 RURD_ ELEC PLUGAB 14:45 - 15:00 0.25 DUMPB CMT_ PLUGAB 15:00 - 15:10 0.17 RURD_ ELEC PLUGAB 15:10 - 15:25 0.25 RURD_ ELEC PLUGAB 15:25 - 15:40 0.25 DUMPB CMT_ PLUGAB 15:40 - 15:50 0.17 RURD_ ELEC PLUGAB 15:50 - 16:05 0.25 RURD_ ELEC PLUGAB 16:05 - 16:15 0.17 DUMPB CMT_ PLUGAB 16:15 - 16:30 0.25 RURD_ ELEC PLUGAB 16:30 - 17:15 0.75 RURD_ ELEC PLUGAB 7/29/2007 09:00 - 09:30 0.50 SAFETY MTG_ WRLN 09:30 - 09:45 0.25 RURD ELEC WRLN 09:45 - 10:00 0.25 RURD_ ELEC WRLN 10:00 - 10:45 0.75 LOG CSG WRLN 10:45 - 10:55 0.17 SAFETY MTG_ WRLN 10:55 - 11:20 0.42 PERF_ TBG_ WRLN 11:20 - 11:50 0.50 PERF_ TBG_ WRLN 11:50 - 13:30 1.67 LOG CSG WRLN 13:30 - 13:38 0.13 SAFETY MTG_ WRLN 13:38 - 13:55 ~ 0.281 PERF_ TBG_ ~ WRLN 13:35 - 14:05 0.50 PERF_ TBG_ WRLN 14:05 - 14:30 0.42 SAFETY MTG WRLN 14:30 - 14:35 0.08 PERF_ TBG_ WRLN 14:35 - 15:10 0.58 PERF_ TBG_ WRLN 15:10 - 15:40 0.50 PERF CSG WRLN 15:40 - 16:00 I 0.331 RURD I ELEC I WRLN Arrive location. Hold PJSM, and obtain Safe Work Permit. MIRU equipment. PUlubricator, tool string and 2.80" GR. PTest lubricator to 500 psi. WHP 43 psi. RIH w/ Gamma ray/CCL and 2.80" GR. Fluid level @2700'. Tag bottom @4720'. Run Gamma ray. End gamma ray pass @ 3500'. POOH. OOH. Hold exp;osives safety meeting. Check fire. PU 3-1/2"CIBP (2.75" OD). RIH to 4700'. Position plug @4700' and set. POOH. OOH. Hold explosives safety meeting. Mix cement. RIH with 40' dumpbailer. Tag plug and dump first run (6 gals.) POOH OOH. Mix and fill bailer. RIH with second run. Dump 2nd bailer full. POOH. OOH. Mix and fill bailer. RIH with 3rd bailer. Dump 3rd bailer full. POOH. OOH. Mix and fill bailer. RIH with 4th bailer run. Dump 4th bailer full. POOH. OOH. Rig down. Leave location Arrive location. Hold PJSM, and obtain Safe Work Permit. MIRU equipent PU tool string 20' stem. MU tool string with CCL on bottom to tag top of cement. PTest lubricator to 500 psi. WHP = 0 psig. RIH tagged top of cement at 4620'. AOGCC on location verified top of cement was fine. POOH with CCL. OOH with CCL, MU 10' to make 1st gun run. Held explosive safty meeting prior to arming the gun. Arm gun, PU 10' of 2.375", SDP, 4 SPF, 60 deg phased. gun. PT to 500 psig., RIH to perforate from 3833' - 3843', run#1. Correlate gun with Schlumber Rst, Sigma log dated July 19, 2002. On depth perforate from 3833' - 3843', 10'. No change in WHP. 0 psig. POOH OOH with gun. Monitor well for 1 hour. No change in pressure continue perforating. MU gun #2. Go to communication black out. PU arm gun #2. RIH with 26' gun to perforate from 3864' - 3890'. ~ Correlate gun with Schlumber Rst, Sigma log dated July 19, 2002. On depth perforate from 3864' - 3890', 26'. No change in WHP. 0 psig. POOH OOH with gun#2. Fluid level at 2700'. . MU gun#3, plan to perforate from 3843' - 3853', 10'. PU gun go to communication black out. PT, RIH with gun#3. Tagged bottom @ 4620 '. PU and correlate gun location to same log as perviously perforated from. WHP= 0 psig. On depth with gun #3, Perforate from 3843' - 3853', 10' of 2.375" gun. Perforate, no change in pressure. POOH with gun. All shots fired on all three perforating runs. No well head pressure. Monitor well for hour. No change in well pressure. MU jumper gas to flow line. Ask operators to try and bullhead gas down well to displace water. OOH. Rig back a line unit. Expro left location Printed: 8/30/2007 2:30:28 PM s Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 41-7X Common Well Name: KENAI BELUGA UNIT 41-7X Event Name: ABANDONMENT Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code phase . Code 8/1/2007 08:00 - 08:30 0.50 SAFETY MTG_ WRLN 08:30 - 08:45 0.25 RURD_ ELEC WRLN 08:45 - 08:50 0.08 RURD_ ELEC WRLN 08:50 - 10:00 1.17 RUNPU ELEC WRLN 10:00 - 11:55 1.92 RUNPU ELEC WRLN 11:55 - 12:20 0.42 RURD ELEC WRLN 8/7/2007 08:00 - 08:45 0.75 SAFETY MTG_ WRLN 08:45 - 09:00 0.25 RURD_ ELEC WRLN 09:00 - 09:05 0.08 RURD_ ELEC WRLN 09:05 - 10:06 1.02 RUNPU ELEC WRLN 10:06 - 10:38 0.53 RUNPU ELEC WRLN 10:38 - 11:20 0.70 SAFETY MTG_ WRLN 11:20 - 11:54 0.57 RURD_ ELEC WRLN 11:54 - 12:40 0.77 RUNPU ELEC WRLN 12:40 - 13:03 0.38 RURD_ ELEC WRLN 13:03 - 13:26 0.38 RURD_ ELEC WRLN 13:26 - 13:48 0.37 RUNPU ELEC WRLN 13:48 - 14:00 0.20 RUNPU ELEC WRLN 14:00 - 14:30 0.50 RUNPU ELEC WRLN 14:30 - 15:00 0.50 RURD_ ELEC WRLN 15:00 - 16:00 1.00 RURD ELEC WRLN Page 2 of 2 Spud Date: 2/26/2002 Start: 7/27/2007 End: Rig Release: 10/6/2002 Group: Rig Number: 1 Description: of Operations Arrive location. Hold PJSM, and obtain Safe Work Permit. PU lubricator and PLT tool string PTest lubricator. WHP = 5 psig. RIH w/ PLT string. End pass. Fluid level @ 3878'. Run up pass with 5 min benches every 500' and at surface. OOH with PLT string. RD lubricator and tool string. Shut down waiting on orders. Arrive location. Hold PJSM, and obtain Safe Work Permit. PU lubricator and PLT tool string PTest lubricator. WHP = 59 psia. RIH w/ PLT string. End pass. Fluid level @ 3884'. POOH. Wait on orders. Hold Explosives Safety Meeting. Check fire and PU 3-1/2" CIBP( 2.75" OD). RIH with CIBP to 3810'. PU to next collar. SET weight down on BP. POOH. OOH. PTest lubricator to 1000 psi. Test good. PTest lubricator to 1000 psi. Test good. Check fire and PU 2/3/8" x 26' HSC EXP GUN. RIH. Correlate and position gun sot shoot @3729'-3755' (26'). Wait on orders. Shoot gun. POOH. OOH. RD. Turn in permit and leave location. Panted: 8/30/2007 2:30:28 PM · Marathon Oil Company AI. Asset Team United States Production Operations P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-235-6322 August 30, 2007 FedEx Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7fu Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon Ninilchik State #3 (NS 3) - API 50-133-20566-00 Marathon Kenai Beluga Unit 4l-7X (KBU 41-7X) - 50-133-20510-00 .;2 C.;2...- C;lS- CONFIDENTIAL Dear Mr. Okland: Enclosed are one hard copy each of the following logs. NS3 Dual Radial Cement Bone Gamma Ray/CCL Log SCANNED SEP 0 7 2007 KBU 41-7X . Gamma Ray/CCL Log ~ 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, ðtt~~ Courtney McElmoyl Reccived by (4 ð))J Date: )( ~ 2ù·~ì ;a Enclosures . . TO: State of Alaska Alaska Oil and Gas Conservation Commission Jim Regg \{êf? 81)07 DATE: July 29.2007 P. I. Supervisor MEMORANDUM FROM: Bob Noble Petroleum Inspector SUBJECT: Plug Upper Beluga Perfs KBU 41-7X Marathon Oil Co. ____. PTO - 202-025 julv 29, 2007:itraveledroMaratnonolJ Co. rœu 41-7X to wltnêss~1aggJngõf1f1e- cement plug set to plug the upper Beluga perforations with Marathon's Wayne Cissel. ~._-~----_.- A bridge plug was set at 4700 feet, (The top of upper Beluga perforations are at 4735 feet). Cement was then bailed into the well to 4620 feet. The E-line work was completed by Expro E-line's Ed Hawker. J verified the plug depth by E-lines color log. I witnessed the top of the cement both with E-lines log and the weight indicator and I found it to be at 4620 feet. Summary: Marathons well KBU 41-7X Upper Beluga Perforations were /'/ successfully plugged according to 10-403 Sundry Notice. Attachments: None SC*tWNED SfP 1 1 2007 2007-0729]&A]lug_tag_KBU_ 41-7X_.doc . ~,[~,[Œ (ID~ ~~~~æ~ . AI4A~1iA. OIL AlQ) GAS CONSERVATION COltDllSSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 I Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Anchorage, AK 99611 Re: Kenai Gas Field, Beluga Gas Pool, KBU 41-7X Sundry Number: 307-238 Dear Donovan: sCANNED JUL 1 ß Z007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ffday of July, 2007 Enc!. é)Od-ö'd5 < . . . (.MJ Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 July 10, 2007 FtECE'VED JUL 13 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 ¿St Gas Cons. C(}mmission Anchorage Reference: 10-403 Sundry Notice Field: Kenai Gas Field Well: KBU 41-7X Dear Mr. Maunder: We propose to plug back non productive Upper Beluga perfs in well KBU 41-7X and add perforations in the Sterling Pool 4, B-1 sand. If Pool 4 is not productive we will move up to Sterling Pool 3 A-1 0 sand. We anticipate producing Sterling gas from a currently shut in well. Please refer to the attached procedure and wellbore diagrams for specific operations. If you have any questions or need further information please call me at (907) 283-1333. IL. Enclosures: 10-403 Sundry Notice Well Schematic Proposed Well Schematic Operations Procedure cc: AOGCC Houston Well File Kenai Well File DD KJS ~ . "', ", n .- 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 perforat~"'Wiij~'êr't:]'-" \,,"'~ IJu''''Òtner U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Anchorage Change approved program 0 Pull Tubing 0 Perforate New Pool ~~1N Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: " \, 5. Permit to Drill Number: Marathon Oil COmpany Development 0 Exploratory 0 202-025 - 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20510-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 KBU 41-7X . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Kenai Unit A-028142 , 21' Kenai Gas Field / Beluga Pool _ 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5300' -. 5239' - 5228' - 5167' 4875' N/A ~ Casing Length Size MD TVD Burst Collapse Structural 99' 13-3/8",61#, J-55 99' 99' 3090 1540 Conductor Surface 1514' 7", 23#, L-80 1514' 1511' 6340 3830 Intermediate Production 5292' 3-1/2",9.3#, L-80 5362' 4877' 10160 10530 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: N/A Tubing Grade: N/A Tubing MD (ft): N/A 4735' - 5056' 4831' - 4995' Packers and SSSV Type: None in current completion Packers and SSSV MD (ft): N/A 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 20-Jul-07 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Donovan Printed Name ^ I Dennis Donovan Title Production Engineer Signature I..... "'I,~ ~n Phone (907) 283-1333 Date 11-Jul-07 ~ 1\'YI ' ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: {~7 J :J. ~ Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~~\~(:s;,,~ ç>~~ O~ O~~~~~I ~ ~\\~tS~ ~~~ Subsequent Form Required: RBDMS BFl JUL 1 8 2007 APPROVED BY Date: l' /7- ~ (- Approved by: THE COMMISSION Form 10-403 Revised 06/2006 Jffi&ij '-- ~74,tf? Submit in Duplicate . STATE OF ALASKA (ß-7,n!;::ff RECEIVED ALASKA OIL AND GAS CONSERVATION COM SION ~ i APPLICATION FOR SUNDRY APPROVALS t';h"""\ JUL 1 3 Z007 20 MC 25 280 sion MM. . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 41-7X 2007 Plug Beluga and Peñ Sterling WBS # WO.07.15658.EXP ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: · This procedure covers work to abandon non-productive Upper Beluga perfs and perforate Sterling Pool 4 with a Pool 3 contingency. · After Sundry approval is obtained, all work will be performed with Expro E-line. · Contact AOGCC to discuss which parts of the operation they would like to witness. Abandonment of Upper Beluga perfs: 1. MIRU Expro E-line unit with gauge ring, Expro 3-1/2" CIBPs, 2" bailer with enough cement to dump 60' in 3-1/2" and perf guns. 2. Pressure test lubricator to 200/2500 psia with 6% KCL water. 3. MU 2.80" aauae rina. 4. Taa plua at 4875' MD. Minimum workable depth is 3900'. If unable to pass 4700' discuss plug and cement setting depths with engineer. 5. RIH with cast iron bridae plua and set at 4700' ELMO. 6. RU 30' of 2" bailer. RU to mix cement and fill bailer. 7. Dump bail 5 runs (55') of cement. 8. WOC 24 hours. Tag cement any time after 12 hours. If cement tag is not 50'+ above plug, continue bailing. Notify AOGCC to witness official tag after cement depth is verified and adjusted if necessary. Perforating Sterling: 9. RU e-line to peñorate usina the SAFE system. 10. Start radio silence if necessary due to operations on the pad. 00 not shut down SCAOA communications. . . Page 2 of2 11. RIH 2-3/8" X 10' perf aun. Perforate Sterling B-1 sand from 3833' - 3843'. 12. Open well to LP and test. If the well flows, continue perforating B-1. 13. RIH 2-3/8" X 26' perf aun. Perforate Sterling B-1 sand from 3864' - 3890'. 14. RIH 2-3/8" X 10' perf aun. Perforate Sterling B-1 sand from 3843' - 3853'. 15. If B-1 will not sustain unload rate contact the engineer and prepare to continue job. If B-1 flows above unload rate, rig down and turn well over to production. 16. If B-1 will not sustain unload rate: RU 3-1/2" cast iron bridge plug. Set plug at 3810' ELMO. 17. NOTE: Space does not allow for legal abandonment of Sterling B-1. It will be necessary to dump bail 50' of cement on the plug in the future to complete the B-1 abandonment. 18. RIH 2-3/8" X 26' perf aun. Perforate Sterling A-10 sand from 3729' - 3755'. 19. Flow test well. 20. Release Expro E-line. CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (cell) David Martens: 713-296-3302 (w) 832-472-6249 (cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emeraency Dial 911 KBU 41-7X Plug and Perf procedure MAM - 7/11/2007 9:20:48 AM Revised 7/11/2007 by KDW 179' FNL & 4353' FWL T4N, R11W, Sec ,S.M. API # 50-133-20510 RT - GL = 21.0' Chemical injection Mandrel @ 1461' 1/4", 0.049 wall 58 control line 1" sidepocket injection valve Directional: KOP - 2217' DOP - 3418' Max hole angle 17.8 Deg Plug @ 4875' Isolated Upper Beluga perfs U5 - 4892 - 4910 6 8PF 60 Deg 8/16/02 U5 - 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 5038 - 5056 6 SPF 60 Deg 5/5/02 Well Name & Number: County or Parish: Perforations: (MD) Angle/Perfs P: KBU 41..7X PBTD 5228' MD TO 5300' MD KBU 41-7X KPB State/Prov. Date Completed: Prepared By: Gary Eller o 133/8" 68 ppf J-55 n/a 99' 7" L-80 23ppf BTC 1514MD Cemented with 140 sacks Upper Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 - 4780 4791 U2 - 4824 - 4836 X-Nipple @ 4933' MD (4923' ELMD) 3.5" L-80 5292 MD 9.3 ppf EUE 8rd Cemented with 530 sacks Class "G" Lease o o Last Revision Date: KBU 41..7X Proposed 179' FNL & 4353' FWL T4N, R11W, See ,S,M, API # 50-133-20510 RT - GL = 21.0' 133/8" 68 ppf J-55 n/a 99' Chemical injection Mandrel @ 1461' 1/4", 0.049 wall SS control line 1" sidepocket injection valve 7" L-80 23 ppf BTC 1514 MD Cemented with 140 sacks Upper Beluga perfs 2-3/8" HSC, 4SPF, 60 Deg 12/16/03 U1 - 4735 - 4756 U1 - 4764 - 4768 U2 4780 - 4791 U2 4824 - 4836 Directional: KOP - 2217' DOP ~ 3418' Max hole angle 17.8 Deg Plug @ 4875' Isolated Upper Beluga perfs U5 - 4892 - 4910 6 SPF 60 Deg 8/16/02 U5 4913 - 4922 6 SPF 60 Deg 8/16/02 U6 - 4942 - 4951 6 SPF 60 Deg 8/16/02 U7 - 4992 - 5002 6 SPF 60 Deg 5/5/02 U7 - 5012 - 5026 6 SPF 60 Deg 5/5/02 U8 - 5038 - 5056 6 SPF 60 Deg 5/5/02 X-Nipple @ 4933' MD (4923' ELMD) 3.5" L-80 5292 MD 9.3 ppf EUE 8rd Cemented with 530 sacks Class "G" PBTD 5228' MD TD 5300' MD o Lease Well Name & Number: County or Parish: Perforations: (MD) Angle/Perfs BHP: FWHP: Date Completed: Prepared By: o KBU 41-7X KPB State/Provo o Gary Eller Last Revision Date: . . Page 1 of 1 Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com} Sent: Tuesday, July 17, 200711:15AM ao~"O~ To: Maunder, Thomas E (DOA) Cc: lbele, Lyndon; ddonovan@marathonoil.com; Walsh, Ken; Cissell, Wayne E.; mmullin@marathonoil.com; Skiba, Kevin J. Subject: Well Information Confidentiality Tom, Confidentiality statements are standard for many Marathon documents. Marathon is not requesting additional confidentiality above what is applicable. The statement just verbalizes Marathon's confidentiality expectations. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DCA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 17, 20078:54 AM To: Donovan Jr, Dennis M.; Skiba, Kevin J. Subject: KBU 41-7X Dennis and Kevin, I am reviewing the sundry submitted to plug the Beluga perfs and move up to the Sterting. At the top of the procedure page it states that "All data relative to testing of this well is confidential". I have seen this statement on some other procedures as well. Confidentiality of well information generally applies for 25 months after the original completion of a well. There has lately been some statute changes that removes the 25 month period for wells in established fields. Is it indeed Marathon's intent to have this information confidential? Confidential information is covered in 20 AAC 25.537. I look forward to your reply. Tom Maunder, PE AOGCC 7/17/2007 . . Review of Sundry Application 307-238 Marathon Oil Company Well KBU 41-7X Kenai Gas Field, Upper TyoneklBeluga Gas Pool AOGCC Permit 202-025 Requested Action: Marathon Oil Company (Marathon) proposes to plug the existing perforations in the well and to re-perforate the well. Recommendation: I recommend approval of Marathon's request. Discussion: The KBU 41-7X well was originally drilled beginning in February 2002 and was completed in June 2002. The well has never been capable of regular sustained production. Marathon has made multiple attempts at making this well productive with virtually no success. They have attempted installing a velocity string to help de-water the well and they have isolated existing perforations and re-perforated the well in shallower formations. None of this work has proved successful. The well.produced for a total of 19 days during April and May 2003 and has not produced. Cumulative production was 1,145 mcf of gas and 175 bbls of water. Conclusion: Since the well has never been productive plugging the existing perforations and re- perforating the well will not result in waste and is the only viable option for trying to make this a productive well. D.S.RObY#~ Reservoir Engineer July 16, 2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marlœr.doc «i L~ J-.~ '-( DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2020250 Well Name/No. KENAI BELUGA UNIT 41-07X Operator MARATHON OIL CO S,1 Vl ¿ Æ ì Ft.lø) ù ~ "). API No. 50-133-20510-00-00 MD 5300- TVD 5239"" Completion Date 6/4/2002 " Completion Status 1-GAS Current Status 1-GAS ~Q ------ -- -- - . - ---------- -- - -. - .-- -.-- ------- -- ------ --- ---- ---- REQUIRED INFORMATION - -- - -- --- ---- -- - -- - - - -------- --------- ----- .~~.'", f"¡AI.\ I: J! 11 Directional Survey CY~y Mud Log No Samples No - -. -- - --- - ----------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: PEX-DSI (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name C€ou -¿- - ------ ~568 See Notes -- ---- Log Log Run Scale Media No ------------------ -------- --- 1 Interval OH / Start Stop CH Received Comments -- ---- ---- ------- 1403 5219 Open 2/5/2003 Digital Well Logging Data - ----- -- ----- --------- -------------- ----------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION yG) Daily History Received? G/N ¿~/N Well Cored? Chlps.Recelved? VJW - Formation Tops Analysis Received? Y/N -. ----------- ---- . -- - ----------- - --- - - - - - -- - - - ----------------- - -------- Comments: r~~ Ù"1 ~ \. i F';h ,,\ JW"~') ~ . eV). P ï; IJ }, J-G. .P COmpl-¡anCe ~-~v:~:~~~~: ~--~-- - -- -~-- -----~- -~-: -- - -- ----- - ---------- Date: -- ---- q .J~~) ~O~_--~l l\'IEl\"IO TO EACH "TELL FILE LISTED BELO\V Date January 7, 2004 T\\'o previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been cOlnbined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change \vas effective in January 2004. Production from these hvo intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the \vells listed belo\\'. The \vells listed belo\v have had their production records modified reflecting this change. 184-1 09 KEU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBLJ 33-06 178-055 KDU5 195-054 KTU 43-06XRD 177-029 KBU 13-08 103-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 14-06H 202-043 KTU 32-07H 195-054 KBLJ 43-06XRD 179-029 KBU 41-07 169-012 KDU4 184-108 KTU 13-05 I 79-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-1 79 KBU 44-06 " ' M Marathon MARATHON Oil Company 'Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 31, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KBU 41-7x Dear Mr. Aubert: Enclosed is the 10-404 Report of Sundry Well Operations form for well KBU 41-7x. The work that was done included pulling a velocity string to access existing perfs. A plug was placed above existing perfs at 4875'. New Upper Beluga perforations were then added in the wellbore. This work was completed 12/17/03. An operations summary and updated wellbore diagram are enclosed for your review. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, ~~ryÞ Denise M. Titus Production Engineer Enclosures RECE\VEO JAN 0 5 2004 C mmisslOn 0.\ & Gas Cons. 0 1\ \as\c.a \ t\ Anchorage OQIGINAL 9 'cmn'drlg'f:gi'wOÕ'IIS'~',u1..-321'AOGCC5und UpnOh~ Peris 5ut>s.:-QLJent.XLS ,) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COl\lllvilSSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation Shutdown - Pull Tubing- 2 Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface '238' FNL, 4346' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval At Effective Depth At Total Depth 191' FNL, 3837' FWL, Sec. 7, T4N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 68 ppf 23 ppf 99 1514 9.3 ppf 5292 Stimulate Alter Casing - 5 Type of Well: Development ~ Exploratory - Stratigraphic - Service Set Plug and Perforate uphole 5300 feet Plugs (measured) 5239 feet 5228 feet Junk (measured) 5267 feet Size Cemented 13-3/8" Driven 7" 140 sks 3-1/2" 700 sks Plugging - Repair Well- Perforate Other X 6 Datum Elevation (OF or KB) 21 feet 7. Unit or Property Name Kenai Beluga Unit 8 Well Number KBU 41-7x 9, Permit Number 202-025 10, API Number 50-- 133-20510-00 11 Field/Pool Kenai Gas Field, Beluga Pool 3-1/2" wireline set bridge plug @ 4875' Measured Depth True Vertical Depth 99' 1514' 99' 1511' 5292 5231' measured New: 4735'-4756',4764'-4768',4780'-4791',4824'-4836' Isolated: 4892'-4910', 4913'-4922', 4942'-4951', 4992'-5002', 5012'-5026', 5038'-5056' true vertical New: 4674'-4695',4703'-4707',4719'-4730',4763'-4775' Isolated: 4831'-4849', 4852'-4861', 4881'-4890', 4931'-4941', 4951'-4965', 4977'-4995' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13 Stimulation or Cement Squeeze Summary N/A Intervals Treated (measured) N/A N/A NIA Treatment Description Including Volumes Used and Final Pressure RECEIVED .IAN 05 7004 Alaska Oil & Gas Cons. Commis: ;:" Anchorage 1~ Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 0 Subsequent to Operation 0 0 0 0 15 Attachments Copies of Logs and Surveys run Dally Report of Well Operations X Oil Gas X 17 I hereby cerify that the foregoing is true and correct to the best of my knowledge. {"',,I\ /1(\ JJL~ RØOMS 8FL Signed ifh I,I'"P {1I- Denise M. Titus Title Production Engineer FO'm '''~,'' R" '",","' ' 0 ~ ! GIN A L 16 Status of Well Classification as: Suspended - Service JAM 0 1 200' Date 12/31/2003 -- BFl JAQØ 0 " Submit in Duplicate " ,"n,. . Page 1 of 2 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 41-7X Common Well Name: KENAI BELUGA UNIT 41-7X Event Name: RECOMPLETION Contractor Name: Rig Name: GLACIER DRILLING Date I From - To Hours I Code J~dbe Phase 12/10/2003 09:30 - 12:00 2.50 CL TBG 'RURD WBPR 12:00 - 16:00 : 4.00 CL TBG RURD WBPR , , ; 16:00 - 17:30 1.501 CLTBG WBPR I 1 17:30 - 18:00 0.50 CL TBG POCT: WBPR 18:00 - 20:00 2.00 CL TBG 'POCT ,WBPR 20:00 - 20:30 0.50 ¡ CL TBG RPTL WBPR 20:30 - 21 :00 ' 0.501 CL TBG WBPR 21 :00 - 22:00 22:00 - 23:00 ' 23:00 - 23:10 23:10 - 23:20 23:20 - 00:00 , 00:00 - 01 :00 12/15/2003 11 :00 - 12:30 I 12:30 - 12:55 12:55 - 13:05 13:05 - 13:15 '13:15 - 14:00 12/16/2003 107:00 - 09:00 09:00 - 10:00 ' 10:00 - 12:00 12:00 - 13:30 13:30 - 14:45 1 14:45 - 15:35 15:35 - 17:00 1.00' CLTBG WBPR 1.00 CL TBG I WBPR 0,17 CLTBG WBPR 0.17' CLTBG WBPR 0.67 CL TBG ,WBPR 1.00 CL TBG 1.50 N2LFT WBPR :OTHER 0.42 N2LFT OTHER 0.17 N2LFT OTHER 0.17 N2LFT OTHER 0.75 N2LFT OTHER 2.00 PERF RURD PERF 1.00 PERF WLNC PERF 2.00 PERF WLNC PERF I 1.50 PERF I WLNC PERF 1.25 PERF I WLNC PERF 0.83 PERF WLNC PERF 1.421 PERF WLNC PERF Start: 12/10/2003 Rig Release: 10/6/2002 Rig Number: 1 Spud Date: 2/26/2002 End: Group: Description of Operations , Spot and begin RU BJ services 2" CT equipment. NU WHA. Spot and RU MOC flowback. Stab 2" MOC stinger string through injector head. Rollon connector to velocity string stub. MU WHA. Crack open hanger gland nuts and lockscrews to equalize pressure 'across CT hanger. Pressure test flowback iron using WHP. SI BJ 'flowback valves, bleed pressure to tanks, and hammer up leaks. With packoff open and one-directional (down) slips engaged, PU on CT. (String wt -11 OOOlbs). PU to 15000lbs with string starting to move. POOH at 5'/min until rollon connector is on wooden spool. Open lever that holds slips and POOH wI 2" CT string. Bumped up at surface. Turn swab valve to ensure CT is clear of valves. CT is still across valves. Appears 1/8" upset on BHA is not : clearing wellhead slips. I RIH 30' and PU in another attempt to clear hanger x2. Cycle lockscres and gland nuts. Lever that operales slips will not function opened or closed. String will only travel downward +1-3'. Call ABB Velco wellhead hand for assistance. Cycle lockscrews and gland nuts again. Slip lever still restricted. PU and tag again. Retighten packoff and bleed off WHP to ensure packoff is holding. Discuss options and review wellhead schematic. Suspect material is 1 interfering with slip movement. Elect to heat wellhead in the event ice is impeding slip motion. Borrow heater from rig. tarp tree and apply heat. , Function slip lever. Getting more motion than previous. Able to re-set slips. Open packoff and work pipe while functioning slip lever. Able to get slip lever in full open position. Able to PU BHA through hanger. Close swab valve ensuring CT is clear of tree. Break WHA. Cut BHA off end of CT and reconnect injector. Ciruclate purge nitrogen through reel to tank for storage. Rig back for night. Secure localion and depart. BJ Services arrive on location, fill out permit. safety meeting. RU N2 to : tree cap. Cool down pumping unit and pressure test agaisnt swab valve to 2500psi. Open swab valve and begin pumping downhole with initial pressure WHP=1300psi. Pump at 2000 scfm wI pressure rising to 2250psi. Pump pressure remains at 2250psl SO pump and RDMO MIRU Expro double drum truck, Get work permit. Hold safety meeting. i MU tool string including 2.80" GR. Pwh=1600 psi (was left at 2000psi yesterday) RIH wI gauge ring and GR/CCL. Tubing clear to 4950' correlated. Did not tag bottom. POOH. Break out GR. MU bridge plug and setting tool. RIH wI plug. Correlate and set at 4875'. POOH, MU 12' Gun #1, RIH and correlate. Fire gun wI shot indications good. Pwh=1600psi. POOH. At surface, Pwh=1300 psi. MU 11' Gun #2. RIH and correlate. Fire wI good indications. POOH. At surface. Pwh=1000psl. MU 4' Gun #3. RIH and correlate, Fire w/ good indications. POOH. Pwh=925psi. Pr'n!E:O 12131120û3 1 1û;:;a PM Page 2 of 2 Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 41-7X KENAI BELUGA UNIT 41-7X RECOMPLETION Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date GLACIER DRILLING From - To I Hours I Code I ¿~dbe Phase 1.00 PERF WLNC PERF , I I I 12/16/2003 17:00 - 18:00 18:00 - 19:00 ' 1,00 I PERF I ! I RURD PERF Spud Date: 2/26/2002 Start: 12/10/2003 End: Rig Release: 10/6/2002 Group: Rig Number: 1 Description of Operations At suface. Pwh=750psi. PU 21' Gun #4. RIH and correlate. Fire wI good indications. Pwh=800psi. POOH. At surface. all shots fired. RD Expro. Leave well 51 for night. I Pr,ntea 1213112ûû3 1 lû 28 Pf\,' API: 50-133-20510-00 AOGCC: 202-025 RT -GL: 21.0' 179' FNL. 4353' FWL Sec. 7, T4N, R11W, S.M. Tree cxn: 4-3/4" Otis Hanger lift threads: 3.725" MCA KBU 41-7x ~ Chemical Injection Mandrel @ 1461' - 1/4".0.049" wall. 55 control line - 1" side pocket injection valve ~ . Directional KOP - 2217' DOP - 3418' Max hole angle 17.8 deg All doglegs less than 3 deg/1 00' Well Name & Number: County or Parish: FWHP: I I Date Completed: Prepared By: I Isolation plug @ 4875' ::::8 II::::: :::II: II::::: ::::I -= ::::8 II::::: :::II: II::::: ::r J:: ==- :II:::: ==- :II:::: =:J I: ==- :II:::: ==- :II:::: -Ú :. .: Otis X Nipple @ 4933' =- "" 10=2.813" ¡, ri =- "" '"" ., Note: E-line shows X- ] [ nipple at 4923' MD - - =- "" ,. ., ~ ~ =- "" j l PBTD: 5228' MD TO: 5300' MD KBU 41-7x I Kenai Borough FBHP: State/Prov. FWHT: API# Gary Eller Last Revision Date: ... 13-3/8", 68 ppf, J-55 Drivepipe @99' .. 7".23 ppf. L-80. BTC Casing @ 1514' cemented wI 140 sx Upper Beluga Perfs: 2-3/8" HSC, 4spf, 60deg (12/16/03) 4735'-4756' 4764'-4768' 4780'-4791' 4824'-4836' Isolated Upper BeluQa Perfs: U5 - 4892'-4910'.6 spf, 60 deg. 8/16/02 U5 - 4913'-4922',6 spf, 60 deg, 8/16/02 U6 - 4942'-4951'.6 spf, 60 deg. 8/16/02 U7 - 4992'-5002',6 spf. 60 deg, 5/5102 U7 - 5012'-5026'. 6 spf, 60 deg. 5/5102 U8 - 5038'-5056', 6 spf. 60 deg, 5/5/02 3-1/2", 9,3ppf, L-80. EUE 8rd (Mod) at 5292' Cemented with 530 sxs of class G Lease I AK I I FBHT: Kenai Gas Field, Pad 41-7 Country: USA Other: KB-GL: . , M MAUTHO. ~ 0: EXCEL,AOGCC upnOh~ 5una,XLS WGM 1l./¡J"I2.CC~ bTJ' 12f è}J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3 Address P. O. Box 196168. Anchorage. AK 99519-6168 ..k Location of Well at Surface '238' FNL, 4346' FWL, Sec. 7. T4N. R11W, S.M. At top of Productive Interval Suspend - Operation Shutdown Repair Well - Plugging ~ Pull Tubing - Variance 5 Type of Well: Development ~ Exploratory - Stratigraphic - Service At Effective Depth Isolate existing perfs and add perforations uphole At Total Depth 191' FNL, 3837' FWL. Sec. 7. T4N. R11W, S.M. 12 Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 68 ppf 23 ppf 99 1514 9.3 ppf 5292 4892'-4910'.4913'-4922'.4942'-4951', 4992'-5002'.5012'-5026'.5038'-5056' measured Re-enter Suspended Well- Time Extension Stimulate Perforate X Other 6 Datum Elevation (OF or KB) 21 feet 7 Unit or Property Name Kenai Beluga Unit 8. Well Number KBU41-7x /' 9. Permit Number 202-025 /' 10 API Number / 50- 133-20510-00 11 Field/Pool Kenai Gas Field. Beluga Pool 5300 feet Plugs (measured) 5239 feet 5228 feet Junk (measured) 5267 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" Driven 99' 99' 7" 140 sks 1514' 1511' 3-1/2" 700 sks 5292 5231' true vertical 4831'-4849'.4852'-4861',4881'-4890'. 4931'-4941'. 4951'-4965'. 4977'-4995' Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) NIA , 3 Attachments Descnption Summary of Proposal ~ 15. Status of Well Classification as: Detailed Operations Program ~ BOP Sketch , I 14 Estimateç1 Date for Commencing Operation /1/25/,2003 16. If PropÒ5ak1iÍás Verbally Approved Oil Gas X Suspended - Name of Approver Date Approved Service 17 I hereby certify that tne foregoing is true and correct to the best of my knowledge. li\l, .ln~¿, , Signed ,1,\ "" 11,' / l' 'n,; d. 1,\ \" r f,.--, Title Production Engineer _/ . FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Approval No. Plug Integrity BOP Test Location Clearance _'"?r .~~ -:::,..:./t) ,) Mechanical. Integrity Test - Subsequent Form R,equired 10- - I q i..; 'f . , r~vv' +0 C~C.U,..duL,-~~t A.Ll L4'r~-t ß~lc.£~" e~Y"~"'''-~'Ú~c.. mw.c.,t b.€ piU4¥J pW 2.NAAc 2S. "z..(C.)U), ' J J /J Approved by Order of the Commission Original Signed 8:. CommiSSioner Date J J\ Ä () 7 Form 1Ü-403 Rev ,'jo;."5'88 ~arah ~a"f1 Subml. in "triplicate OR'G'~JAL Date 11/21/2003 ~Sfl œ, '1 '~fd \..:~ , .., M MARATHON . 4 I\Iarathon Oil Company Alaska Region KBU 41-7x Kenai Gas Field, Pad 41-7 Recomplete Uphole Procedure \\"8S # \VO.03.09790.EXP History: KBU 41-7x was initially completed in the Upper Beluga U5, U6, U7, and U8. The ".ell appeared to be capable of minin1um gas production with substantial water. A \.elocity string ,,'ith lift gas was installed. After several months of gas lift, no incremental gas was visible and the water did not subside. Objective: Recomplete the \\'ellbore uphole in depleted Upper Beluga zones. This will require pulling the velocity string and the hanger spool to permit setting a plug and perforationg. Procedure: 1) RU wireline and set blanking plug in velocity string x-style nipple at 4884'. 2) Bleed pressure off of CT string and tree. Strip tree and flowlines dO\\1l to the second master \'alve (the valve above the CT hanger spool). 3) l'vllRU BJ sef\'ices wi J.\tl0C 2"' w/ 0.1 09'\vall, flash free, 70 grade CT stinger spool. NU BOPs on second nlaster \'alve flange (3-118" 3l'vI, R31). Stab 2" CT and 1\:IU injector head. BOP stack \\'ill be pressure/function tested and docUlllented in the BJ shop. Pump down CT to shell test above 2nd master vah'e to 150/2500psi. Bleed off pressure to choke. 4) Break stack below 1nd nlaster valve (imlllediately above CT hanger spool) to expose velocity string stub with re-entry guide. Remove wireline re-entry guide and prep stub for roll on connector. RIH \\'/ 1" pipe until stinger stub is visible and prep for roll on CT. If clearance penl1its, roll on CT x CT connector. If studs from the CT hanger interfere with roll on tooL use grapple by grapple connection. This will require a collar to 1\1U the t\\'o grapples. 5) \\lith the \"elocity string attached to the stinger, walk the injector w/ BOPs and 2nd master valve down the pipe and bolt the valve up to the tree. Pressure test to 150/1 OOOpsi through the BOP kill line to ensure flanged connections are holding. J.\tleasure distance from above the hanger to above the BOPs if grapple connections are used. 6) PO pipe weight to pull test connection. Release CT hanger mechanisn1 per True Turn n1achine procedure. PUH slowly watching weight indicator for signs of sticking. May wish to lea\'e le\'er engaged until spoolable connection is through injector head. If there is any failure abo\'e~ the grapples will hold the pipe. This will create excess drag through CT head. 7) With the splice on the spool, continue RIH w/ pipe. Once at surface, carefully exercise 2nd n1aster \'ah'e a few tU1l1S to ensure CT is clear of tree. 8) Shut in 111aster \'ah'es and bleed off pressure. ND BOPs and top master \'ah"e. Begin RD while wellhead/pipe fitters ND Tnle Turn hanger spool and NU ren1aining tree. RDMO CT unit. 9) l\tIIRU slickline/eline unit. RlH with a 2.85"' GR and tag to ensure 31,<~"' tubing is clear to top of perfs (-4950'). RIH w/ bridgeplug and set at 4875" 10) Run pressure sUlTey to detem1ine fluid level in the well. RU CT w/ N2 to jet off any fluid in the wellbore prior to perforating. 11) l\¡1U gun assembly and perforate as follows. Expect BHP--400psi: of 735' -4756 " 4 764 ~ -4768' 4780"-4791" 4824" -4836' 11) RDlVlO slickline/eline. Bleed off any nitrogen pressure to atmosphere and flow well to low pressure system per instruction of production engineer. API: 50-133-20510-00 AOGCC: 202-025 RT -GL: 21.0' 179' F NL. 4353' FWL Sec. 7, T4N, R11W, S.M. ... Tree cxn: 4-3/4" Otis Hanger lift threads: 3.725" MCA Chemical Injection Mandrel @ 1461' - 114",0.049" wall, SS control line - 1" sidepocket injection valve Velocity String: 2" wI 0.109" wall, flash free, grade 70 CT to 4890' BST 1.625" OM (x style) nipple at 4884' Otis X Nipple @ 4933' ID=2.813" Note: E-line shows X- nipple at 4923' MD Directional KOP - 2217' DOP - 3418' Max hole angle 17.8 deg All doglegs less than 3 deg/100' Well Name & Number: County or Parish: FWHP. I I Date Completed: Prepared By: I KBU 41-7x I Kenai Borough FBHP: Gary Eller KBU 41-7x ..., , , ... III ~ ,1 i I :J :I :JI " 0' . I' :J ::I ::I :J :J :8 ] :J 31 :8 ... ... PBTD: 5228' MD TD: 5300' MD State/Prov. FWHT: API # ... 13-3/8". 68 ppf, J-55 Drivepipe @99' .. 7",23 ppf, L-80, BTC Casing @ 1514' cemented wI 140 sx Upper BeluQa Perfs: II: IE I: U5 - 4892'-4910',6 spf. 60 deg. 8/16/02 U5 - 4913'-4922',6 spf, 60 deg, 8/16/02 U6 - 4942'-4951', 6 spf. 60 deg, 8/16/02 U7 - 4992'-5002'. 6 spf, 60 deg. 5/5102 U7 - 5012'-5026', 6 spf. 60 deg, 5/5/02 U8 - 5038'-5056', 6 spf, 60 deg. 5/5/02 I~ II I . I: I: I: [ II: IE [ [ I: I: 3-1/2", 9,3ppf, L-80. EUE 8rd (Mod) at 5292' Cemented with 530 sxs of class G Lease I AK I I FBHT: Kenai Gas Field, Pad 41-7 Country: USA Other: KB-GL: Last Revision Date: , , M MARATHOI ~ API: 50-133-20510-00 AOGCC: 202-025 )KBU 41-7x proposed M .ARATlO. j RT -GL: 21.0' 179' FNL, 4353' FWL Sec. 7, T4N, R11W, S.M. ... Tree cxn: 4-3/4" Otis Hanger 11ft threads: 3.725" MCA Chemical Injection Mandrel @ 1461' - 1/4", 0.049" wall, SS control line - 1" sidepocket injection valve . ... .. 13-3/8",68 ppf. J-55 Drivepipe @99' .. 7",23 ppf, L-80, BTC Casing @ 1514' cemented w/ 140 sx ==- IIC:: Added Upper Beluga Perfs: ==- II:::: :::::I I:: 4735'-4756' ==- -= ::::II: II:::: 4764'-4768' =r .t:: :::31 -== 4780'-4791' =:II -== ::::::I J:: 4824'-4836' :::31 -== ==- -== Isolation plug @ 4875' (~Œ) "" --..:.....---/ Directional KOP - 2217' DOP - 3418' Max hole angle 17.8 deg All doglegs less than 3 deg/100' ;. .i. Otis X Nipple @ 4933' '"" IE ID=2.813")1 ri =- -= '"" IE Note: E-line shows X- I I nipple at 4923' MD - - ,. IE ,. -= ~ ~ '"" 80 j l PBTD: 5228' MD TD: 5300' MD Well Name & Number: County or Parish: FWHP: I I Date Completed: Prepared By: I KBU 41-7x I State/Prov. FWHT: Kenai Borough FBHP: API# Gary Eller Last RevIsion Date: Isolated Upper BeluQa Perfs: U5 - 4892'-4910',6 spf, 60 deg, 8/16/02 U5 - 4913'-4922',6 spf, 60 deg, 8/16/02 U6 - 4942'-4951',6 spf, 60 deg, 8/16/02 U7 - 4992'-5002', 6 spf, 60 deg, 5/5/02 U7 - 5012'-5026', 6 spf, 60 deg, 5/5/02 U8 - 5038'-5056', 6 spf, 60 deg, 5/5/02 3-1/2", 9.3ppf, L-80, EUE 8rd (Mod) at 5292' Cemented with 530 sxs of class G Lease I AK I I FBHT: Kenai Gas Field, Pad 41-7 Country: USA Other: KB-GL: ~ - , I Alaska Business Unit Domestic Production - M Marathon MARATHON Oil Company ~ P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 21, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KBU 41-7x Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals form for KGF well KBU 41-7x. The proposed work is to plug back the existing perforations with a plug and add new uphole perfs in the same zone. This work will require pulling the 2" CT velocity string. A bridge plug will be set and new perforations will be added. This work is expected to begin 11/25/03. A proposed well schematic and an operations procedure are included for your review. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, )\\,' l~ ~j")/ ,J~,~/r - Denise M. Titus Production Engineer Enclosu res OR'fGI NAL AUG-26-2003 TUE 03:31 PM MARATHON OIL COMPANY ) FAX NO. 907 283 6175 t P. 03 v-I~/~ Blu{u;o~ 8T A TE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type (¡f Request: Abandon Atter Casing Change Approved Program Suspend - Operation Shutdown Repair Well - Plugging- Pull TubIng - Variance x 5 Type of Well: Development Exploratory = StratigraphIc Service - 2. Name of Operator MARATHON Oil COMPANY 3. Addr€:ss P. O. Box 196168. Anchorage, AK 99519-6168 4, location of Well at Surface At ton of Productive Interval At Eifective Depth At r'ltal Depth 12 PrÐ[.ent Well ConditIon Summary Re-enter Suspended Well - Time Extension - Stimulate - Perforate Other X 6 Datum Elevation (DF or KB) feet 7 Unit or Property Name Kenai Gas Field 8 Well Number . X. i./-/-D7A: 9 Permit Number 202-025 ,.... 10. API Number 50- 133-20510-00 ,- 1 t. Field/Pool Kenai Gas FIeld ~{.¡Ir Thi!:. sundry will be used to notify your office that we would like to utilize the KNPL gas to purge the KKPL pipeline of air. ./ The estimated gas volume will be some where around 6.0 MMCF of natural gas. There will be a need to install the 4" by-pass pIping & break thE valve seals on the 4" by-pass line Inlet valve which is before the KGF 400 meter gas sales meter. We Installed a 4" meter run with a ché.rt recorder last year when we flowed gas around the 400 meter. This meter and recorder is In place, It is calibrated and ready to /" mE: asure flOw. Th(: seal that will be broken IS number 16512. This process to purge the KKPL pipeline of air will in no way reduce the amount of gas that Is currently flowing through the 400 sales meter. /'" / Th~ 4" meter run by-pass will be disconnected. as soon as the KKPl pipeline is purged of air. This work will be Instrumental In brlng{ng the KKPL producllon to market. ~. See attached drawing for more details. Packers and SSSV (type and measured depth) Description Summary of Proposal ~ Diagram of proposal 14. [stimate;j-l>ate for C~mencing Operation (8/2]1'2003 16. If Propo'Sãï was Verbally Approved 13. Attachments t '"", I'-~ ,.', .. 15 Status of Well Classification as: Detailed Operations Program - BOP Sketch Oil Gas X Name of Approver Date Approved Service 171 hereby cerli~ Iha,he foregoing is ~ue and ".:':ef¡ to, ~e best of my knowledge. S'gned ~ o\J\J.. ~~~ "I Title Englneenng Technician - FOR COMMISSION USE ONLY Cônditions úf Approval: Notfy CommiSSIon so representative may witness Plug IntegrIty BOP Test Location Clearance Mechanical Integrity Test - Subsequent Form Required 10- - 4- L? tf- Approved by Order of tne CommiSSion FG' ,n 1:'...103 R~,¡ C3.'~ 5,85 ~1 r~~ I ".1 :.~, ~ I) r": ~ .-', \.) .' W~, _'I 0 ~ , G , ~, ð f Suspended - Date 8/22/2003 [APproval No. ..3D 3 - :z :s 3 CommISSioner Date ~~~f,~b -- . -. .. - .. i '1 "".' 1'1 : ! ":" ¡", 1"1 '"j -,.:~! 1 ¡ I I I', I, ' "., I' I ,I !: I".: I ,...,.: "'" 'z . '.. "." :.' ' \ I' I. I I 't. . I I I . ',I :'.: I j .1 .1. . -,...\ ' '. , : : . .. . I ¡. . - ~!.' . V ' I . \..-1., ..!., -..1 .'. Î' .1, ,f":'I"¡'' ! ! ;.I~ -f!,¡'¡ '-. r:, '.ni-.- .-- .1_- .¡. ~ ¡ .'i 1 '- - '.- ' : I ! ,I ': I I I I . .L. "'j'--l_,. --".,1,," "''''''''''[''''-'--, 1 . ! .. '. -- ~. .. .'--. -! --. ¡. . -' 1-"-."I'~ - ... ,.. I"'~ -. '1 I, i, : I i I '¡ :',,!: \. ! 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I' L ,'., 'I" . i ? i<...Ä I I I .II '," i ' '" ¡ ¡ ¡ ! \, ¡..:. i .11 }.' ¡. I. !, ¡ ..~ \' -, 'r;-', ' 'l ; , , ., !. . 'I - !! . Iii I' I II ' tt- Cri. '~ . I ¡ ~ I I,: , ! \ : .: 1., I ',. '. . i """".'-. I,' 1'-"":1 : ; I '.: .! ., ¡ ]'; I' I': I i ! 'I ~çtt ~' : J;: . I ! " - -. -., ,,,I . .!.. . - ,--;-- .~ I I I ,!.. ..1_--.'_--- ,,,,,,--/...'..,:. -'-"-"'''''''r'-- ,""---''''-' I ~ ,-;0, "" - ,,' ¡. . "."''' .. ",' I I"" I' I, ", (~ ~ ¡ "', I I ' ' I '¡ ': I Ii: '!._, j.,A """""'" .;-_..'.. ..:,' '--'1'- "!. I :....1 i ..- -¡-- ¡". ',' ¡. ]'--("-' ,...--. ¡ : J : ~ ! i :..:. .I..: I :' ! I I I, , ., I., ',- . ../ I.... I ...., . .. I I : I I J , "". " I I I I t [ -- : . ' . . . -- I '~; \ I " I , :: " I, !. I " '¡ \ Ii. :. ¡I' ' I," j ¡: I I' , J I : ¡ I I I , I I f I , I ' I ~ .. : ' : ¡, , ! ! : i I : i I :1.,1"1 ': ,. ¡-t ;:-: "P-' i " I , 'J "" - ... .. I'" Î I , ;':;-:::1 ,'.!-;' ';-:Ji,'¡"'W£. . I! : .. \ ..1. ", I, , :' Ii! I I r"~ I I, ',I , I I, ! , ! I I' I: 'I. I. \. .. I " I .. , '. " I I.: I I' ; ¡I, . I: ' , I, .' '. - . ., :.. -'I :.',.' ¡ .... ~. ""~"""", : ¡, , , I í' I I . I. , :. . j.. . ,. : . .. , .. _. , . 1. - 'I _..: . .:. ~ . ¡ f I ... - i '" ,'- . ¡ . - j I ¡ AUG-26-2003 TUE 03:32 PM MARATHON OIL COMPANY , FAX NO, gn7 283 6175 ) ~'Yi. S\lbject rY\ S)J Lf Õo Page No. -- Fde By , '" ;. ¡ :, I ! - I I ' ,J- - .¡ '1 ¡. I .- . ¡.. ; , ',"'" . , ' I ¡ ,I I.. .. ,. _1- . . -- -. ," I - _I. . --.. ï' -- '-Li~..-~, ï. , J F';'"1I 101':! n."" 3,f,1) P, 04 (.M\ & 'II MARATHO¡I) ~ Of Date .. I' i. i I -. I ' " ' I ' .. I I I , '. i ! \ I' .:. ; I , I I I i. . ¡ "I J.. , ' , I I . . ¡" i I . I' ...1 I I,. .. ! \ ' \ ! '1' , .. .:. ~\.. : .. j'"" !. I . . , , , . '''' ~ I ' AUG-26-2003 TUE 03:31 PM MARATHON OIL COMPANY ) FAX NO, 907 283 6175 J P, 01 .':'~':":'::"t~"-' ;'j ',:' '¡,:" " .-. ~ ; ."', i: ,.:"~" ~\~ ,': M~r~th'o'n on Oom,pany Kel1~ï. ~~s Fj~,{~ , ~C? ~~~ 1. ~4.~ Keni4i, AK 9~611. ;.1'949. T e1~phon~ (907)' '12~~,~1 ri09 Fax (907) 283..,6175 ,~ax Cover' Shee'~ I . . ß-z.«øJ(J [ Al E._-:--__-,--,--_._-- 'U'-------"- . /tfcfß t1CV(~~ TIME.....,...~_.__._---,--,-.._,._- ,"..., '_h',,, '----"" - TO: NAME: _~'AlT()N ~-~~~ T.~ lÞlA'fJuÞØ- "L- -----. I ." COMPANY: '~'I' ", -I .' ' FAX:____..---..., '--' ~~J"~ '.:'''"1 ~ ...;.. '.. -...'HIo'. ", i'~." ....11" \ :~ ~'~"'¿ ~.:.:-; FROM: NAME: __,il,~~r .(~ f"- rrt' ~ß J - (J() , , ?1 « - ( 3 J 7 ..-----. PHONE: FAX: 907-?83-6175 -- PAGES SENT (Including Cover Sheet) -..--:1--------. , [ ] Response Requested [ ] Immediate [] I nfornlation Only R.EMARKS: ~:r.r~~ -~~ ~-l[ LQ'rrt.'"\'t \)~ 1. 2, AV6t.?$ì ~ ~ ~ W.rt ,"~ Cl!>5lÌl4.- ,." It", --- --------,--------- í.d_~~ O:r.. O(j(.u~S~ (;~(,.~ItJ~, -- --------...----.--' --'--.--'--- ~(.,~~_~AX ~i' 'tV "b1~5S" l~~W 1('tVr Qvei~U~~~==.~_._.__.._._--_._- U'.~'- ~ou_~_J:i~_tJ j'~-~<A.(oA( ~_T!!!_U>fØt,1JW~ T~=4J__JE- f~j~---,~u!. ~JJÞr vP' , ORIGINAL AUG-26-2003 TUE 03:31 PM MARATHON OIL COMPANY ~ FAX NO. 907 283 6175 ~ P. 02 . t l\1arathon Oil Company P.O. Box 1949 Kenai, Alaska 99611-1949 101- l1 ~ Ow l.rtf 1... ~ ~1.~ ..~) Alaska Oil & Gas Conservation Commission AUn: Tom Maunder "()1....1~3 "'/lrO 333 \V. 7th. Ave., Ste 100 ~t<:O - t.,rJ1:r LAoij"b Anchorage, ..\.k. 99501 íJc¡,o 7: ~c.ÙJ--~AI()~ (kiPM,~fÞD '-~ 08-22-2003 Subject: Utilizing KNPL gas to purge KKPL pipeline of air l\'lr. Maunder: r have enclosed a Sundry and a diagram of our intentions utilize the KNPL gas to purge the KKPL pipeline of air. There is an 4" by-pass around the MSN 400 meter that \vill be connected on the upstreaITI side of the meter. A jumper will be installed to connect the KNPL to the KKPL pipeline. The natural gas used will be metered through a 4" meter run and recorded with a /' Barton Chart ree.order. The time to purge the line is estimated to be done within a 12 hour period. ;' The total volume of gas used to purge the pipeline of air will be added to the MSN 400 master meter. Any Questions please call me at 907-283-1308. S~T1Y, (L.~f2iJ WaP;~sel\ ..."~-"""--_._' . --- ----- Ì\1 arathon Oi 1 Company l\BU Gas n1easurelnent Pa(k~..;p In 9171082133 'S9)0 183"1 ?"_:I.~O A GOt"III:-':".rc ID t.) II~M'JSl\GTlON \oj) ~ D::.'~;,.tin~tion lIP [:00':) 995lJ 1 . p;),:lo.a:~.:' b.11 t,"'d~ ^CCrP fH) ~-; ~ Hc:cipi{nt: - POP AÇI;O"lit l,I.. 2221:5060 :) J) ^(i{hc'3-~: S~¡j.t II, 55'~1956? .'\Ii (, ? ;. (oJ û 0 ~ 1 2 : ? l, P . - -. '.' ORIGINAL ~ .., Nt Marathon MARATHON Oil Company 4 ~ Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 30, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7lh Ave Anchorage, Alaska 99501 Reference: KBU 41-7x Dear Mr. Maunder: Enclosed is the 10-404 Application for Report of Sundry Well Operations for Kenai Gas Field well KBU 41-7x. The proposed work to install a 2" coiled tubing lift string in the cemented wellbore was completed. Gas from a nearby higher pressure Tyonek well is being metered and used as lift gas. With lift gas assistance, the well began producing about 360 bwpd. This water rate has tapered down to about 170 bwpd. Currently, there is no gas contribution coming from the formation. Production is anticipated upon dewatering as has been seen in similar Beluga wells. I have included daily work summaries. If you need any additional information, I can be reached at 907-283-1333 or bye-mail atdmtitus@marathonoil.com. Sincerely, i~ , ..I' i~,^VlÞ Denise M. Titus Production Engineer RECEIVED Enclosures MAY 0 2 2003 Alaska Oil & Gas Cons. Commission Anchorage g:lcmnldrlglkol\wellslkuI4-321IAOGCCsund Gas Lift subseQuent.XLS STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown - Pull Tubing - 2. Name of Operator MARATHON OIL COMPANY 3, Address P. O. Box 196168, Anchorage. AK 99519-6168 4, Location of Well at Surface '238' FNL, 4346' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval At Effective Depth At Total Depth 191' FNL, 3837' FWL. Sec. 7, T4N, R11W, S.M. 12 Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 68 ppf 23 ppf 99 1514 9.3 ppf 5292 4892'-4910',4913'-4922',4942'-4951', 4992'-5002'.5012'-5026',5038'-5056' measured true vertical 4831'-4849'.4852'-4861',4881'-4890', 4931'-4941', 4951'-4965'. 4977'-4995' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or Cement Squeeze Summary N/A Intervals Treated (measured) Stimulate Alter Casing- 5 Type of Well: Development ~ Exploratory - Stratigraphic - Service Plugging - Repair Well- Perforate Other X 6. Datum Elevation (DF or KB) 21 feet 7. Unit or Property Name Kenai Beluga Unit 8. Well Number " KBU 41-7x ''''"' 9, Permit Number 202-025 10. API Number 50-- 133-20510-00 11 Field/Pool Kenai Gas Field, Beluga Pool 5300 feet Plugs (measured) 5239 feet 5228 feet Junk (measured) 5267 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" Driven 99' 99' 7" 140 sks 1514' 1511' 3-1/2" 700 sks 5292 5231' N/A N/A 14. Treatment Description Including Volumes Used and Final Pressure RECE\VEO MA'< () 2 2003 . Cons r.omm\SS\on ~\as\l.a u\' & Gas . ~nchofalJe Oil-Bbl Representative Daily AveraQe Production or Injection Data Casing Pressure Tubing Pressure Prior to Well Operation 0 Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 X 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil Gas X Signed ~ I\~¡{{~ Form 10-404 Rev. 06/15/88 RBDMS Bfl t4AY Gas-Mcf Water-Bbl 0 0 0 170 bwpd 16. Status of Well Classification as: Denise M. Titus Title Production Engineer . . , - I: ',)\ Il":~ i1 ...."" ORiGiNAL 0 1 OOpsi Suspended - Service Date 4/30/2003 Submit in DUPli~ API: 50-133-20510-00 AOGCC: 202-025 RT-GL: 21.0' 179' FNL, 4353' FWL Sec. 7. T4N. R11W, S.M. .. Tree cxn: 4-3/4" Otis Hanger lift threads: 3.725" MCA Chemical Injection Mandrel @ 1461' - 1/4".0.049" wall, SS control line - 1" side pocket injection valve Velocity String: 2" wI 0.109" wall, flash free, grade 70 CT to 4890' BST 1.625" OM (x style) nipple at 4884' Otis X Nipple @ 4933' 10=2.813" Note: E-line shows X- :I nipple at 4923' MO :I :I Directional KOP - 2217' OOP - 3418' Max hole angle 17.8 deg All doglegs less than 3 deg/1 00' Well Name & Number: County or Parish: FWHP: I I Date Completed: Prepared By: I KBU 41-7x I Kenai Borough FBHP: Gary Eller KBU 41-7x , I i r I : i H ¡ r , , II ¡, 'I \1 ,', .. , , III II ; ,; I j i ~ I I: , i , 'I i ¡ ~ I , , i I I' 1 : I' I , j , \ <~ ~ j :II :I :I , . ,¡ :I :I :I ] :I :I :I .. ~ PBTO: 5228' MO TO: 5300' MO State/Prov. FWHT: API # Kenai Gas Field, Pad 41-7 Country: USA Other: KB-GL: ~ 13-3/8", 68 ppf, J-55 Orivepipe @99' ... 7",23 ppf, L-80. BTC Casing @ 1514' cemented w/ 140 sx Upper BeluQa Perfs: E It I: rt U5 - 4892'-4910',6 spf, 60 deg. 8/16/02 U5 - 4913'-4922',6 spf. 60 deg, 8/16/02 U6 - 4942'-4951',6 spf, 60 deg, 8/16/02 U7 - 4992'-5002'.6 spf. 60 deg. 5/5/02 U7 - 5012'-5026'. 6 spf. 60 deg. 5/5/02 U8 - 5038'-5056', 6 spf. 60 deg. 5/5/02 IE I: IE IE I: IE [ IE I: I: 3-1/2", 9.3ppf. L-80. EUE 8rd (Mod) at 5292' Cemented with 530 sxs of class G Lease I AK I I FBHT: Last Revision Date: . , M MARATlO. MARATHON OIL COMPANY Daily Workover Report Optimize Lift System Page 1 of 1 WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS Kill weight fluid pumped. Well SIFN OPERATION COMMENTS RU BJ 1.5" CT to cleanout fill and load hole with kill weight fluid. bbl3% KCI in hole. RDMO. KB IGL 66.00 124 HR PROG TMD TVD AUTH MD WBS I DFSO 1 DOLO I RPT # DATE 1 03-Apr-2003 SAPIWBS COST 21.0 RIG NAME & NO. RIG PHONE RW.03.07999.CAP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 26,949.86 I LAST CASING I NEXT CASING ~ 0 (in) ~ 0 (ft) 124 HR FORECAST Will ND tree and NU CT hanger 1 CUM WELL COST 26,949.86 I LEAKOFF COUNTY/OTHER Kenai Borough Find top of fill at 4922' CTM. Wash and circulate to TD 5214' CTM. Leave 36 SAFFTY SUr'MARY ~NOHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT ~EGULATORY INSP? ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: I LAST RIG INSPECTION FROM TO HRS 07:00 10:00 3.00 FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL WBPR EQUIP 15:00 17:30 2.50 WBPR TEST WBPR CL TBG WBPR CL TBG WBPR TRIP WBPR CIRC WBPR CL TBG WBPR FLUID WBPR CL TBG DESCRIPTION Warm up eqp and begin RU. PU injector head. Pickle pipe and begin to load CT with 6% KCI pressure test fluid. PJSM Body test BOPs to 250/2500psi (function test was completed and documented in shop prior to work). Test good. RIH -50'/min to 4000' Begin pumping KCI at 1.25 bpm and N2 at 350 scfm. Continue RIH looking for top of fill. At top of fill 4922' CTM. Wash at 6'/min keeping returns 1:1 and monitoring solids in returns. Complete perf passes as needed. Tag bottom at 5214' CTM. PUH to 5210 and CBU x1.5. Shut down N2 and pump kill weight fluid at 1 bpm. PUH to 500' 36 bbl 6%KCI pumped from bottom. Stop pumping KCI and bring on N2 to clear CT. N2 returns at surface. Finish POOH. At surface with CT. Total fluid pumped: 155bbl. RDMO BJ services. 10:00 10:30 0.50 10:30 11 :50 1.33 11 :50 12:10 0.33 12:10 12:55 0.75 12:55 13:25 0.50 13:25 14:30 1.08 14:30 15:00 0.50 LAST BOP TEST: SIZE I ID I SHOE TEST CA~ING ~IIMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnted: 4/30/2003 10:06'28 AM WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS Pump methanol to tree OPERATION COMMENTS Vetco and Udelhoven on location to NU CT spool. Grease bottom master and drift CT spool. wing flowcross. SD for weekend while production thaws and isolates tree. MARATHON OIL COMPANY Daily Workover Report Optimize Lift System IGL 66.00 Page 1 of 1 KB 124 HR PROG TMD TVD AUTH MD WBS 1 DFS IDOL 1 RPT # DATE 0 0 2 04-Apr -2003 SAPIWBS COST 21.0 RIG NAME & NO. COUNTY/OTHER Kenai Borough 1 LAST CASING ~ 124 HR FORECAST Thaw and bId tree RW.03.07999.CAP MOC WI NRI 1 DAILY WELL COST 100.0000 92.2000 940.00 I NEXT CASING 0 (in) @ 0 (ft) I CUM WELL COST 27,889.86 I LEAKOFF RIG PHONE Unable to bleed down and NO tree due to ice in MANHRS WORKED I ACCIDENT TYPE LAST SAFETY MTG 0.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: SAFFTY SUnMARY BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? N LAST RIG INSPECTION FROM TO HRS FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL DESCRIPTION TE WBPR EQUIP SOTH Vetco and Udelhoven on location to NU CT spool. Grease bottom master and drift CT spool. Unable to bleed down and ND tree due to ice in wing flowcross. SO for weekend while production thaws and isolates tree. LAST BOP TEST: SIZE I 10 I SHOE TEST CA~ING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled: 413012003 10.06:32 AM WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATElPROV Alaska CURRENT STATUS / MTS CT hanger installed. Well secure. OPERATION COMMENTS Vetco and Udelhoven ND tree above master valve and flow line section. and CT side outlet. Install tree cap. MARATHON OIL COMPANY Daily Workover Report Optimize Lift System Page 1 of 1 KB IGL 66.00 I DFSO I DOLO I RPT , DATE 3 07 -Apr-2003 SAPIWBS COST 124 HR PROG TMD TVD AUTH MD WBS 21.0 RIG NAME & NO. RIG PHONE RW.03.07999.CAP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 3.962.00 I NEXT CASING 0 (in) (á} 0 (ft) I CUM WELL COST 31,851.86 I LEAKOFF COUNTY/OTHER Kenai Borough I LAST CASING (á} 124 HR FORECAST Mob CT eqp Orientate CT spool side outlet and NU hanger. Install blind on flowline SAFFTY sur, MARY ~~RS WORKED I ~~~:ENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS FROM LAST BOP TEST: SIZE I ID I SHOE TEST LAST RIG INSPECTION TO OPERATIONS SUMMARY SUB PHASE OP TRBL RCMP CL TBG DESCRIPTION Vetco and Udelhoven ND tree above master valve and flow line section. Orientate CT spool side outlet and NU hanger. Install blind on flowline and CT side outlet. Install tree cap. CA~IN~ ~UMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled 413012003 10.06:33 AM MARATHON OIL COMPANY Daily Workover Report Optimize Lift System Page 1 of 1 WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS SDFN OPERATION COMMENTS MI BJ Services CT unit with MOC 2" x 0.109" wall hangoff grade 70 pipe. Stab pipe, RU BOPs, RU flowback, and weld on BHA connector per BST Lift Systems. Inc 4975-000 Welding Procedure. Pressure test weld to 1000psi. Test good. SAFFTY SUIIMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I RNEGULATORY INSP? LAST RIG INSPECTION 0.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: KB IGL 66.00 124 HR PROG TMD TVD AUTH MD WBS I DFSO I DOLO I RPT if. DATE 4 09-Apr-2003 SAPIWBS COST 21.0 RIG NAME & NO. RIG PHONE RW.03.07999.CAP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 27.465.02 I NEXT CASING 0 (in) @ 0 (ft) I CUM WELL COST 59,316.88 I LEAKOFF COUNTY/OTHER Kenai Borough I LAST CASING @ 124 HR FORECAST Run velocity string FROM TO HRS FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL RCMP CL TBG DESCRIPTION MI BJ Services CT unit with MOC 2" x 0.109" wall hangoff grade 70 pipe. Stab pipe, RU BOPs. RU flowback, and weld on BHA connector per BST Lift Systems, Inc 4975-000 Welding Procedure. Pressure test weld to 1000psi. Test good. LAST BOP TEST: SIZE I ID I SHOE TEST CA~IN~ SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled' 4/3012003 10:0635 AM Page 1 of 2 MARATHON OIL COMPANY Daily Workover Report Optimize Lift System WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATElPROV Alaska CURRENTSTATUS/MTS Well secure. Demob BJ CT. SDFN OPERATION COMMENTS Install 2" x .109" wall thickness, 70 grade, flash free coiled tubing velocity string to 4890' EaT w/1.625" x style nipple. G&G machine wireline entry guide above CT hanger spool. Cap well and SDFN. SAFFTY SUr1MARY MANHRS WORKED ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? 0.00 None N ACCIDENT DESCRIPTION: KB GL 66.00 21.0 RIG NAME & NO. RIG PHONE COUNTY/OTHER Kenai Borough SAFETY MTG TOPICS: 124 HR PROG TMD TVD AUTH MD WBS 1 DFS I DOL 1 RPT # DATE 0 0 5 1 O-Apr -2003 SAPIWBS COST RW.03.07999.CAP MOC WI NRI 1 DAILY WELL COST 100.0000 92.2000 32,575.19 I LAST CASING 1 NEXT CASING ~ 0 (in) ~ 0 (ft) 124 HR FORECAST NU remaining tree and flowlines 1 CUM WELL COST 91,892.07 1 LEAKOFF Leave 5-1/2" CT stub with I LAST RIG INSPECTION FROM TO HRS 09:30 11 :30 2.00 TO OPERATIONS SUMMARY SUB PHASE OP TRBL RCMP CL TBG FROM 11 :30 12:00 0.50 RCMP TEST RCMP TEST RCMP TRIP 12:00 13:00 1.00 13:00 14:00 1.00 14:00 14:15 0.25 RCMP TEST 14:15 16:20 2.08 RCMP PLRNRP 16:20 16:30 0.17 RCMP PLRNRP 16:30 16:40 0.17 RCMP PLRNRP 16:40 17:10 0.50 RCMP TEST 17:10 17:20 0.17 RCMP CL TBG 17:20 17:40 0.33 RCMP CL TBG 17:40 18:30 0.83 RCMP CL TBG 18:30 19:00 0.50 RCMP CL TBG DESCRIPTION Start equipment. Prepare to run CT. PU injector head. Straighten 10' section of pipe above BHA connector. Ftn test BOPs on ground. BOP pressure ftn test was completed in shop on test stub prior to RU. MU injector head to well to fill CT. Pump 6% KCI to flowback. Shut in flowback and pressure test CT, BOP body, and ground lines to CT reel to 200/2500psi. Break injector to install following BHA: 1.90" NUE 10rd X CT adaptor. BST 1.9" NUE 10rdx 1.625" BST Lift Systems Inc DM (x style) profile nipple w/2.125" aD with 1.625" DM locking mandrel/plug with internal fishing neck, 5' wt bar w/ 2.128" aD & 1.609" ID w/ 45 deg internal wireline re-entry taper. Go to well. NU injector head. Zero end of pipe with KB meas. Body test connection, underside of running plug, and kill line to 200/1 OOOpsi. Open master valve and RIH slowly. Run 15'/min through hanger with BHA (2-3/16" hanger drift). RIH -50'/min. On bottom at 4890'. RIH 30' and PUH in tension to 4890' settin~ depth (2' above perfs) Turn hanger lever to engage slips. Set down w/1 OK Ibs. Energize packoff and tighten gland nuts. Pressure test packoff from above via kill line to 300/1300psi. Test good. Bleed off pressure to tank. Close rams on pipe. Engage shears and cut pipe in BOPs. Open shears and rams and PU to ensure pipe is free. Evacuate remaining CT to tank RD injector head and BOPs. Finish cut and dress CT stub 5-112" above hanger flange. Instal wireline entry guide on top of stub. NU tree cap and secure for night. Pnnled: 4/3012003 10:06:37 AM WELL NAME KENAI BELUGA UNIT 41-7X MARATHON OIL COMPANY Daily Workover Report Optimize Lift System I GL 66.00 124 HR PROG I TMD Page 2 of 2 IKB 21.0 ITVD I DFS I DOLO I RPT # I DATE 0 5 10-Apr-2003 FROM TO HRS 19:00 21 :00 2.00 FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL RCMP CL TBG DESCRIPTION ROMO BJ Services ~HA BHA ~O. I LE~~TOH EFF WT. I PICK UP SLACK OF1 ROT WT. I TORQUE (~axlmin) BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd , 1.9" NUE 10 rd x 1.625 OM x-style nipple, Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I 10 I SHOE TEST I CASING SUMMARY LAST CASING TEST: MAX SICP I MO I TVO NEXT BOP TEST: WT I GRADE BURST Pnnted: 413012003 1006:37 AM MARATHON OIL COMPANY Daily Workover Report Optimize Lift System Page 1 of 1 WELL. NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS reconstructing spool OPERATION COMMENTS PipefiUing error. Will need to reconstruct surface spool and install and x-ray. SAFFTY SUIIMARY ~;RS WORKED I ~~~:ENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? ACCIDENT DESCRIPTION: KB GL 66.00 124 HR PROG TMD TVD AUTH MD WBS I DFSO I DOLO I RPT # DATE 6 11-Apr-2003 SAPIWBS COST 21.0 RIG NAME & NO. RIG PHONE RW.03.07999.CAP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 0.00 I LAST CASING I NEXT CASING ~ 0 (in) @ 0 (ft) 124 HR FORECAST install new spool and x-ray over weekend I CUM WELL COST 91,892.07 I LEAKOFF COUNTY/OTHER Kenai Borough I LAST RIG INSPECTION SAFETY MTG TOPICS: FROM TO HRS FROM TO OPERATIONS SUMMARY SUB PHASE OP TRBL TE RCMP PLRNRP DESCRIPTION Pipefitting error. Will need to reconstruct surface spool and install and x-ray. ~HA BHA ~o. I LE~~9T~ I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS MWD HRS I MTR HRS SS HRS BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd , 1.9" NUE 10 rd x 1.625 DM x-style nipple. Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I ID I SHOE TEST CA~INA SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled 4/3012003 10.06.39 AM WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS SDFN OPERATION COMMENTS Equalized and pulled 2" XX plug. MARATHON OIL COMPANY Daily Workover Report Optimize Lift System 21.0 IGL 66.00 RIG NAME & NO. GLACIER DRILLING 1 RIG PHONE Page 1 of 1 KB 124 HR PROG TMD TVD AUTH MD WBS 1 DFS 1 DOLO I RPT # DATE 0 7 15-Apr-2003 SAPIWBS COST COUNTY/OTHER Kenai Borough RW.03.07999.CAP MOC WI NRI 1 DAILY WELL COST 100.0000 92.2000 1,215.00 1 LAST CASING I NEXT CASING ~ 0 (in) ~ 0 (ft) 124 HR FORECAST install surface safety systems 1 CUM WELL COST 93,107.07 I LEAKOFF Ran 1" DD bailer out the end of CT and tagged bottom of 3-1/2" tubing at 5220' KB. SAFFTY SUI I MARY ~~;RS WORKED ~~~:ENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO HRS 08:30 09:30 1.00 09:30 10:20 0.83 FROM 10:20 11:15 0.92 11:15 13:00 1.75 TO OPERATIONS SUMMARY SUB PHASE OP TRBL RCMP WIRELN RCMP WIRELN RCMP WIRELN RCMP WIRELN DESCRIPTION RU PWS wI 1-1/4" tool string to 2" CT string. RIH wI equalizing prong for 2" XX plug to 4898' KB, equalize XX, well went on vacuum. POOH RIH and pull 2" XX plug at 4898' KB, POOH MU 1" tool string and RIH wI 1" DD bailer. Run out end of CT to 5220' KB, POOH wI small sample of sand. RD and secure well. ~HA BHA ~O, LE~~9TOH EFF WT, I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) BHA HRS I JAR HRS MWD HRS I MTR HRS 55 HR5 BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd , 1.9" NUE 10 rd x 1.625 DM x-style nipple, Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I ID I SHOE TEST CA~IN~ ~lJMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnted: 4/3012003 10:06.41 AM Page 1 of 1 MARATHON OIL COMPANY Daily Workover Report Optimize Lift System WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS Well open to atmospheric tank with no flow OPERATION COMMENTS Displaced wellbore kill fluid to open top tank with N2 and overdisplace. Allow well to flow up 2" CT to atmosphere until Pwh=O (-1hr). annulus lift gas at 11150 psi with no response from well. Leave well open to atmosphere. SAFFTY SUI I MARY MANHRS WORKED ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? 0.00 None N ACCIDENT DESCRIPTION: KB IGL 66.00 21.0 RIG NAME & NO. RIG PHONE COUNTY/OTHER Kenai Borough SAFETY MTG TOPICS: 124 HR PROG TMD TVD AUTH MD WBS I DFS I DOL 1 RPT 'II DATE 0 0 8 18-Apr-2003 SAPIWBS COST MOCWI 100.0000 RW.03.07999.CAP NRI I DAILY WELL COST 92.2000 6,951.09 I NEXT CASING (in) cæ 0 (ft) 1 CUM WELL COST 100.058.16 I LEAKOFF 1 LAST CASING @ 124 HR FORECAST RIH and tag fill 0 Engage LAST RIG INSPECTION FROM TO HRS 09:00 10:00 1.00 12:00 12:25 0.42 12:25 12:35 0.17 12:35 13:00 0.42 OPERATIONS SUMMARY PHASE OP TRBL FLOW N2LFT FLOW N2LFT FLOW N2LFT FLOW N2LFT FROM TO SUB 13:00 13:20 0.33 13:20 13:40 0.33 FLOW N2LFT FLOW N2LFT FLOW N2LFT 13:40 14:40 1.00 14:40 15:00 0.33 15:00 15:30 0.50 FLOW N2LFT FLOW N2LFT 15:30 FLOW N2LFT DESCRIPTION RU MOC Flowback iron MIRU BJ Services N2 pump truck Pressure test lines to 2500psi Begin pumping N2 to annulus taking returns via 2" CT to an open top tank. Begin Pcirc=1000 psi at 500 scfm. Increase rate to 750 scfm wI Pcirc=1850psi See returns to tank. Returns stopped. SI flowback and overdisplace N2 to formation Pcirc=1800 psi at 1300 scfm. Total N2 pumped. 83800 scf (including cool down) Open returns to open top tank. Flow to atmosphere (- 20 min tc bId from 1400psi). Getting intermitent sandy water and gas slugs. Flow continues to weaken as Pwh decreases. MSA detects LEL indicating methane flow from well. Open jumper gas line at 1150psi to annulus. Pwh=O. Very little flow to atmosphere if any. SI well to RD from buster and RU to diffuser. WiI keep well to atmosphere over night. ~HA BHA ~O. I LE~~;; I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd , 1.9" NUE 10 rd x 1.625 DM x-style nipple, Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I ID I SHOE TEST CA~IN~ ~IIMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled: 4130/2003 10:06'43 AM MARATHON OIL COMPANY Daily Workover Report Optimize Lift System Page 1 of 1 WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Wayne Cissell FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS 1 MTS RIH tag fill out of tubing OPERATION COMMENTS RIH tag fill to verify if well open through the perforation intervals. SAFFTY SUI 'MARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT 0.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: KB IGL 66.00 124 HR PROG TMD TVD AUTH MD WBS I DFS I DOL I RPT " DATE 0 0 9 21-Apr-2003 SAPIWBS COST 21.0 RIG NAME & NO. RIG PHONE RW.03.07999.CAP MOC WI NRI I DAILY WELL COST 100.0000 92.2000 843.33 I NEXT CASING 0 (in) @ 0 (ft) I CUM WELL COST 100,901.49 I LEAKOFF COUNTYIOTHER Kenai Borough I LAST CASING @ 124 HR FORECAST RIH and tag fill I ~EGULATORY INSP? I LAST RIG INSPECTION FROM TO HRS 09:00 09:45 0.75 09:45 10:00 0.25 10:00 11 :45 1.75 11 :45 11 :50 0.08 FROM TO SUB OPERATIONS SUMMARY PHASE OP TRBL FLOW EQUIP FLOW EQUIP FLOW EQUIP FLOW WIRELN 11:50 12:50 1.00 FLOW WIRELN DESCRIPTION Drive from shop to KGF to get unit Move equipment to location at 41-7 RU wireline unit, PT lubricator to WHP. WHP= 0 psig. PT good RIH with 1" DD bailer, 1" tool string, Tagged fill @ 5157' KBD POOH with tool string OOH with tool string. sand in bailer, RD wireline unit, Move to 43-6XRD Unit moved over to next well 12:50 13:20 0.50 FLOW EQUIP RHA BHA ~o. I LE~~9TOH I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS I MTR HRS I SS HRS BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd . 1.9" NUE 10 rd x 1.625 DM x-style nipple. Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I ID I SHOE TEST CASIN~ SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled. 4/3012003 10.0645 AM WELL NAME KENAI BELUGA UNIT 41-7X SUPERVISOR Denise Titus FIELD NAME KENAI STATE/PROV Alaska CURRENT STATUS / MTS Lifting water to low P test sep. BJ SDFN. OPERATION COMMENTS Jet 18.5 bbl water from wellbore. Kick off lift gas using N2. Turn lift system to low pressure test sep making 360 bwpd. SAFFTY SUIIMARY ~N;RS WORKED I ~~~:ENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? ACCIDENT DESCRIPTION: MARATHON OIL COMPANY Daily Workover Report Optimize Lift System 21.0 IGL 66.00 RIG NAME & NO. GLACIER DRILLING 1 RIG PHONE Page 1 of 1 KB 124 HR PROG TMD TVD AUTH MD WBS I DFS IDOL I RPT # DATE 0 0 10 22-Apr-2003 SAPIWBS COST COUNTY/OTHER Kenai Borough RW.03.07999.CAP MOC WI NRI 1 DAILY WELL COST 100.0000 92.2000 6,825.71 1 NEXT CASING 0 (in) @ 0 (ft) 1 CUM WELL COST 107,727.20 1 LEAKOFF 1 LAST CASING (ã} 124 HR FORECAST Observe I LAST RIG INSPECTION SAFETY MTG TOPICS: FROM TO HRS 10:30 11 :30 1.00 11 :30 11 :45 0.25 11:45 11:55 0.17 11 :55 12:00 0.08 12:00 12:20 0.33 FROM TO SUB OPERATIONS SUMMARY PHASE OP TRBL FLOW CIRC FLOW CIRC FLOW CIRC FLOW CIRC FLOW CIRC 13:45 14:30 0.75 FLOW HANOVR DESCRIPTION MIRU BJ Services to CT annulus. RU flowback to gas buster. Begin N2 pump cool down. PJSM Pressure test N2 lines to 250/3000psi. Test good. Pump N2 at 1000 scfm down annulus taking returns to open top tank. See returns after 10 minutes. Returns break to pure N2 after 18.5bbl water recovered. Reduce circulating rate to minimum (500 scfm) and begin opening choke to drop N2 circulating pressure to 1100psi. Gradual drop to final state wI 380 scfm N2 rate @ 1050psi wI Pwh=300psi. Pressure up gas line to replace N2. Turn gas to annulus and SO N2 pump. Observe flowback to tank to ensure well will remain flowing with lift gas. Check for solids content in water. Limited solids. Line up production string to test separator. Produce 380 bwpd to the system with gas rate of -1.7MMcfd. Pcirc rate (from KTU 24-6h) 1.6MMcfd @ 950psi. 12:20 13:05 0.75 FLOW CIRC 13:05 13:45 0.67 FLOW MONITR ~HA BHA ~O, I LE~~9TOH I EFF WT. I PICK UP I SLACK OF1 ROT WT. I TORQUE (~axlmin) I BHA HRS I JAR HRS I MWD HRS MTR HRS I SS HRS BHA DESCRIPTION CT cxn weld x 1.90 NUE 10 rd , 1.9" NUE 10 rd x 1.625 OM x-style nipple, Steel straight sub wI tapered re-entry LAST BOP TEST: SIZE I 10 I SHOE TEST CA~IN~ ~UMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE BURST Pnnled. 40012003 10'06'48 AM ItA. Marathon MARATHON Oil Company 4 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519.6168 Telephone 907/561.5311 Fax 907/564.6489 April 7, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Meter 400 Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVAL for Marathon Meter replacement and installation at the 400 meter. We are requesting approval to replace the existing 16" Daniels orifice meter run. Are plan is to replace the 16" orifice meter with a new flow / calibrated 8" Multipath Ultrasonic Meter. The meter will be maintained according to AGA Report #9. If you need any additional information, I can be reached at 907-283-1308 or bye-mail at wecissell@marathonoil.com. Sincerely, ~ Wayne Cissell Engineering Technician RE(;E~\if:(' ß.PIi n '. - ¡~Iaska l"\!1 &~,) \.,OI~2-.1.. C,;¡í:I.:35101 A :1C'~ ~':;:',1'~ 01' G'NA~ O:\EXCEL \AOGCCsun400032003,xls ) ) VJ(flT- C¡/i/z..cc:S D~ <1-/ J STATE OF ALASKA ~ 7tqS ALASKA OIL AND GAS CONSERVATION COMMISSION '7f Ii! \+ ." APPLICATION FOR SUNDRY APPROVALS Suspend - Operation Shutdown Repair Well- Plugging- Pull Tubing - Variance x 5, Type of Well: Development ~ Exploratory - Stratigraphic - Service 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3, Address P. O. Box 196168, Anchorage. AK 99519-6168 4, Location of Well at Surface At top of Productive Interval At Effective Depth At Total Depth 12. Present Well Condition Summary Re-enter Suspended Well - Time Extension Stimulate Perforate Other X 6, Datum Elevation (DF or KB) feet 7. Unit or Property Name Kenai Gas Field 8. Well Number , II' ,., r/" ..¡ ~l - (. I"- 9, Permit Number / 202-025 10. API Number 50- 133-20510-00 11, Field/Pool Kenai Gas Field /' This Sundry has been sent to you to inform you of Marathons intent to replace the 16" Daniels meter at the 400 meter. The meter will be replaced with a new 8" multipaJh ù~onic meter. Our plans call for removal of the 16" Daniels meter during the LNG turnaround. The turnaround is scheduled fo,vMay 5th'through the 18th. During the installation of the 8" UM we will be flowing gas through the 4" by-pass /' line at the meter building. the15ý-pass line is disconnected but we intend to reconnect the by-pass during the construction period. We will be installing a 4" orifice meter to measure any gas that flows through the by-pass line during this time. We are requesting a variance to install the 8" ultrasonic meter and replace the existing 16" Daniels orifice meter. The Ultrasonic meter will be maintained according to AGA 9 and maintained utilizing API 14.2 for gas compressibility. This installation meets or exceeds the objective of the applicable minimum standard which should enhance royalty income accountability. /'. Packers and SSSV (type and measured depth) 13. Attachments Description Summary of Proposal ~ Diagram of proposal 14. Estimated Date for Commencing Operation 5/5/2003 16. If Proposal was Verbally Approved .RE(~.~,~~\lE') :,~, F r. ;,) .... ::' D U .) :\Iaska 0!~ & b~;:, 1_,:Jí!S. Cc!;¡mi3sion ,~.t~"':":G~1~ 15, Status of Well Classification as: Detailed Operations Program - BOP Sketch Oil Gas X Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed U '~U\'~'~ TiDe Engineering Technician \..- , FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test - Subsequent Form Required 10- - Lf c 4- Approved by Order of the Commission Form 10-403 Rev. 06115188 ~/7 IRBD~ B~ L APR 1 4 7.Wn ß--~ OR\G\NA- Suspended - Date 4/4/2003 Approval No. ::,,£:~..~ -.', -¡ Commissioner Daœ s~æiu'2 ) '~-r C ./~ I R,A..t~JS .~J\I.L\,D.A. C ..b"L i B R ,AT~ ()t\1 S .~*~'~~~;***~~Á~*~k):**~~'***}'~*~*:~:~!'~k~~ "A Ultrasonic F10w Meter Configuracion Information (Ul\lIFORN 1.4.1cl.l) 'þ -------------------.-------.------- . I Ins tronE~t. U 1 tra,sonic 'I'echne, 1 cJs.¡i e2; ,I; "'t 'þ * -,I; 1. -:'.: "lr: "1; ",'. .~. 7' ""r ",: ]I: "^ * .., 1( "'¡, 'A '* ;. ¡... of: .: *' .1. r ..," ,'; ~... 'X "': ~: .1 ... ,I. P J..l,¿ Name', Customer: UeteJ.- SiN: . B.=longs to 02-00..1,33 úelc Instromet 0 :2 - 0 0 4 3 - '~! ~) 0 3 0 64 C'2rti[icat.~# 791 UNIFO~I Settings: - ---- - ---- _.-- --- --- --- -------------- Ins t:CWl1E:n t'I'ype : 23 > "O-S...:mic:-3 SeJ.:ies-III QL ¡:'let-:::r (:"J,'fl CGl"l 3e t t.l:1g.3 . tHH FOPN pa int - Leo - pc. in t .1 8 () CJ , )\,1, (:~, 1 .3 PU) . PÐra@~~~r S~c-up. -. -- - -- ..... - - - - ... - -- _.- .. -. - .. - -. - -- - - - - - - - - - - ¡::, l)'~1 (~C)l'1- r J. I~\:m i' 'j (["oj r¿, t \ ,~n . LTJ;; tl:UI'Ii'2n t- Typ(~: ¿ ~I, :> 'Q.SC111c-2, S::'ri'=:.~-l~~~~ I)L ['!e:t.,.::r: !::.. ,:-J :=':,Pl) I! f; arëúller,'2 J: . . OxC10? (i .;':.P. 0 (I ;{ 3 1 ¿; C' ~~ar.aJ.T\et(~x l' P ë\ "C arrL E': t. f': 1. -,. f ÇI.( i.Jifi+:;. 'r~ +.~ j. ~ ¡-\ ,. t\ r.: , ....~ I J ' F'Ô[i'l[CI.;:::l-.er ::,: I) x.L O¿ t; ¡'¡j,xJ.111¿, Intu.1"mat.,lOf!: ;~eJ:ial t!WTÙ').;;'~:" 15110 ~;ir'/ '.JeL.:~i.()ll' '/~," 0':'; I j ;::; t I' i ú2 : :J (¡ 1 -.J ::, - lJ ~2 F ().:.: 2, l) :.: 1.'1 ( I J :: .. ,,) ,J U ¡:, ("I (.:J Spool Pi~ce Param2l'3r3: Di'=lIn.¿;L~l"' : Ll: P.3.tl1 Length. i3 E:-: 2.ITt f\. n s:Tl-= : 9)'/ Ln. '::: . ~.; ¡I':, i r! '::;(1, /1:2 '.k.CiJ ':':.3 1. I ._~ ~ Path L02n9tÌ1: P,~aI1l ;'.ng 1 E . L]: Pa th Len';Jth; B'~ãrn Þ,.ngl,=: 1 S . -!ll~' H~. ~,9 . c) 9 ,-lo?Çf i: ':? 'é:::; ~':~I . ~:' ~.~ I~' .L LJ . '~(I \)~, J,:;;.,;r;,:. '::- e ::: '" -['lCcdule F'ãram¿.t~rs: A9pli:at~0n-3pe=lfl: Pa~~~0t~r? ',; . ,::¡. S. Range: Lc,vJ'2r Limi t . Upper Limit: Gas Velocity Range: LO-,'Jer L1.mi t: Upper Limit~ De~ice-specific Param~cer3: S3.IClple Hate: Timing- Con3cant: Timing Constant ~. Timing Constanc ~: Puls,::: Length' 1 (; I:) (I . (t ¡: L:. :::: 1 tj 0 (: . I~I [' c., :,:-, - l~; ':1 . IJ f t, ::; 1 ?, (: '~I Ï c. .:;, ::C~, H: 1.14C ,~I (, S'~ ~I Profile Correction Parameters: Densi.ty: Dynamic Viscosity: Profile Correction Cüeff~~j_ents: Axial path(::;:): pi; p2: p3: p4: p5 : p6; S""irl P3ths. pI: p2 : p3 : p<l : p5: pó; Calibration Paræn~teI3: CÙcf[ici::-:::.,.t~¿: e:1 8=1: a.ISIS S=~): l).I'~OC S~3: 0.0500 s=~: G.OJOO ,S=":' : 0 , 0 (J I.H.' :::;:.: 6 : ], (Ii") (I (I .~,dJ us r r'óe to:!: ; Low P~S3 Filt~~: ott L'':'\J\f }' l")~N ',-"U I:. _. \.' t. ¡ '.,I[ t :: . 87 .Lb': ':: f J ,20e-ûU2 cP 2,-132.0000 1.0.0000 O,85Ó3 1. 0088 0.0404 -=i.17.Jl 2.J07.0000 65 0000 1-Oll,37 (¡ , 9966 IJ.0097 -::'.,ló70 . r. ':.: ~~ O<85~J (1 " Il :'! 00 n.ù060 o.ooon 1 (l1':~'7 (i n(JI'JC 0.0369 l) -- 0500 0,0000 0,0000 (¡ 03 (I C, (1 .O(),)O 1 , '...'.1. 1-.1. t"l:'r:~(..rlH:~nc~/ C)Ut:.PLlt.: 1,/1)1. b'.l'::li,I\! \ LJ.ll'::! ,.:,.,[I.-~ I Vol. Flow (Line Cond J pange: L ",)\,ÑF.:.r Linn c ~ UPP2l:" L..Lm:.i. t ¡.' :r,~~qll':::nc::, Rð.n';J~~. Lower LÜ.Üt: T.1 PP',:: "r.- Limj t . EITOÌ. F'i.:,?quençj": l'lr:::t'2.r Fa,: r':Jl: : 0 i) '.:' f. h .'i.~1\"'OGC) (¡ ...fL ~~.' l} 0 0000 Ij. LJOúC U.OOOI) 0.0000 :'\ 1-) G I-I (I ',-J IJ rj 0 0 ù ,I~i ;-¡ :: ':I(¡O(\ (1 H~c. COO(),t) H:! 1. .:0. (,(',0 1111pul::._::..:.s.'act -- ;~ - ,-- ,,/' - ~\ - L. . -=-:...- -~--. -- 2i'~S 3'~--'-~--------~--_u,--~---= ~/, (~\ r-::- / , ---------- é'5:.:~ 5/8' , '- . - '.', "',1, I,,~~_~ 7116' '2, 7/1~ X ":\?-!' -""/~I ",J/2' -- 6'-8', -~ -~J£.i,~ I"""'~-" 6'-8'___-1 h->-_.--.L:'¡' :-1 !-o 6'-3 !/2' ""-1 r-~'..J 2 -I -~ L- ~'-O''II,J ¡'--{¡ l'Þ~! r . '. I III : I I!" .-=.. ; -- 6"" f,' (,' 6' l ~ '¡ )'- lIe:' 1'-0 I/V ~-~ .1 '--c~1 j 1/ I I. t===::Il" C> ~ ' ¡' ¡oJ r-r:--;' ." -, ,. ,-¡;-,.IS ..... . J Ila.l1 (0\[/ "8-[ lilt 1 '':) ! ! i ¡,.'it wi ~.JI~'~ ~.;~ ~~' 1/l6'_;/4'~1 I I /~ 1/8' 1/8' ~ (;?)I 1/.8' , -=tf~~' r I¿ ¡"i-'l'~: r, . , ! - ~ '1 " 'J ! - Y 1:¡s , . ,¿ ,~¡i'~~(~f-~"f lJ'J(~i'I,.1)"JF~~ ,~.::~3iT~(-.,~./~~ (~)Jl:'- -~¡.~,- ~,ølø~ff(i (.~, ' (+ w.. 2:.1.-1... . ' ',_./ I' l . - . ',-,' -~ ~ --- '~ ' I ~ 1. " ..-' (Ì'.; \ (..1.Y.0 -1..... Iii) \\ '(110) ''-' i Ii) (><'-, 'I;'(--;';'v I--:-Y~-'i 1-::"(-;"'1---'':'''''''-. I,,~) ).!.!..ì (:\ ~) >-~ õ " (II) -- '-.-/........ - '_/ ..:.j '-......- '-' ",-- "--.' "--"' '-----"" _t>1~T£RTAL LIST, / ~) (~ I ..j J 'GENERAL NDTES . QU tJTIT'{ / I'1::TER i'tJÐf:S TO lie: lS£SLG/-'ED 11'1 ACCðRDr\NCe: \11TH ~~ISI/~SH£ B31 B ";~!I ¡¡E!~ r~O, DESCRrPJION_' - A ~ ANSI CLASS 600 USING A DrsIGU F'Ac:m~ .=0'50. ALL PIPE ~T ¡;~ A"W ,,106 0.<;: API 5L GRADE: B D~ HIQ-¡t:R YrELD STRENGTH SEAJ.V..ESS m CDJ.-'PLi VIT;.I DESj(j'l R-EatriF<:¡.,rms, ALl. mTß\lGS HUH £IE ASHi Al05 DR HIGHER 'fIElD S7P.E/.IG",- ,!, omRE ASSe:r-IB\.Y T[J E£ H,()~STA7ICAI.l.Y TE~e:D m ,!¡ tllNiltU.l-l PRE:SS1JR£ tlCrED L; ,¡.,i ¡..:9LE' VI"; T¡.it. HAXlHlofi M£SSl1l<E HIlT TO E"¡(ŒED 9G ;: or TI1E SPECIFIED HitJIHt:iJ YiELD STf'i£N(¡TCi ü'" ,<lW PIH': ¡:.... rlTTINû 'm THE ASSEHBL Y. rEST m BE h£:LD FßJR ¡.;[Ju.~s './JrH I,,',HF.:!<: TEi1PÐ"A}'u¡:,z "-'JD I'RESSURE CHART Re:C~lJê:D.. .:- FUlLY RADIlJGR,!.PH AU. ûlRfH œuTn Wi:L.DS 100:( QUALITY TD /'.ECi ûi< D:CE<:iJ API C!E£ .104 (ALL I-'1TTlt.¡j$ VElCJF:D Ta MErER RUN PIPII~ SJ-IAlL liE fULL PDJr:TR:ATIDN \,irLDS~ ALl.. M1N-ûIRTH \-lEU).; ARE TI] BE nISPEt:T£D BY MAG/IETfC PARTIClE: EXAMIrlAntlN PER AgME ¡¡LIllER AND ?P£~~J¡;;': VE~5EL c¡:¡O[ :::t:CTlûN v, "NQHr.<:STRucrrVE EXAHINATlûN' (CRACI<S ARt: lJl-lACCEf'T ABLD. 4, ruBES ilJ lit HACl-lINED nmSl-iED INSID£: finER COHPL£'1'ION £1.-""' ';/Q_DJr.G Hë:TC:P. "'-ulii; INTERNAL SURFACF:S Husr BE: fW~NISHED VïTH Po tI,./¡;(IHUM SURrAct: P.Ol!GHI/C:SS IX. 300 HlcrdJWC-HES ;:. HE1ER TUBES TO liE SANDBLMiTED OOtRIIALL.\' 10 ":HlTE MrT.IJ.L. CIl"'ï¿Ð \!Jr¡-! rt¡D.'tGANC '!Il:C F',~WE~ ."'U: S?ECrF,C~TIClNS MID S:TAr~ED vlTH fU]V DlR£CTIDU ARRDVS MID Nu:-'BERED c¡, SPACER PLATE 1-1.\'( BE mSTALLED UPSTREAM OR DO\IN:oTREAI1 ûI'" THE I".t: iER TLlD£', Tl-iE l(<:.': r.Jt IM~\JLAmlG (¡"SKU SETS lPSTièEAM NlD DmlNSTRUlt.I LA THE NEiER ¡USE IS REcurf:é]). ÐlMENSIONS AND TüLCRANCES rIOT Sf'E'elnCO¡lL I' DESCRI3ED It I THr SPEC¡F jcurm~S 11:.151 L'¿ ',fTnlm Uii! 'IS ALUJ'JED fJ'( AGA REPCRT fiCl 9, S. STAMP ACTUAL BnRE SIZE MID SERIAL IUMBE.R ON EACH S£Cï!rjl~ F1.M'E ~I..IQ,.J EC.<E AHIJ .:;£'r<r&!.L tJUMRU, Dt 1I)£NT1F1CATIOI TAG ATTACI-IED m H(TER S?OOL. ?IECL <> AF'TER HICRD/oIETER I£A~URe:ME:~HS, ALL INTERlIAlS ARE TQ BE COATE!] \/ITH \I~ïë:¡; j:iS?'-"",::I,'::¡ RuST 1ri;~i3iTC!':: \0, F'A¡¡RICATtJR TO BDLI 3/4" PL'fIJOOD TO kLl. fLANGES BEfORt' St11PMO-rt, f'MCIi ~=:Tffi nre~ Hi ~ SJ;IPP£TJ IN SECTlIJNS, UtIASSEJ1BLED ArlO PAllEirZ£D. 'I. f"iJ~nSH IrtSPŒTmu RLPDRTS, tÞJ.JBIVoTIWI SHë:£TS, ¡(--F.A\' P.EPOR';' " , EïC. ïO CUli?Mh' k,?RE!;£.'!T~ìr..'~ 12. OUAl.!FICATICNS DF VEUIIIJRS \lILL BE: COCRDIMTED B ( EL ?~,:m HE~.suRt~£'iT xfìv ICE~ !"p.rG~ TO PLACEMENT ON APPROVED I/£iIDCR L Isr, D. t<ETE.~ TlJaE SHALL 11£ F'ABRICATED [N ACCORDANCE WiTH E::1. F'~W ''''EiË~ ~HïI(jN iJ:::SI(iP. S¡:'ECIf"ICATlú;-!,;.', DrslGN DESIGN ------;m-['~~L "i~~~~Ct(NESS I-NO'\illï'~ 11:510£ If~;;::m; (4H;)- PRLSSURE (p5Ia) T£ljf>£RATUilE ':'f) OHCHrS) ú;M-IETi1' (INCH¡:~) P~£~UR£ tf-$iG) 100 G¡tpOE X-4~ .--~- - f-- "1.0 - T OR.""" ~ '''' .~~ ;';5= l I - I -' -~F~' 'I ~ ..I It~,R1J:1:::T 8' ,'Wl T!-PAiH lJ...TRAsorl!C ¡.¡::n:R, ANSI 6i¡D. 7 '181' ID (~Ef. TAflLC 5" GA'-LQGHER f'LQ\.I ¡;O¡¡DI7IDHER, MlJDt:L 'Üf"C SYSTE/i I VAS fP['. 304SS ;:>;'Ci;¡;¡ ?t.AT-Ë 'JI íl-i PADDLE: HA/I[I\.E, \.'2', T¡'¡IDi. CAP.!I[)t STEEL ;~,¿25' o.D.. -. ;;1106' BORE i'LHIGE, LARC.~ fEi1ALE: r~Œ WELD tltCr:, S', STEEL, .,tlS. /,OLl ~ü /-IAiCH R¡;ISEIJ f.~CE (¡rl H£IER, BaRE::' 7.981' BORE: 1r'\.'1E,t,¡¡QET, :', STEEL, :;00011 \OiJG. 'J£UJED VERTICAl 011 loP ,! DF" TUilE Hun BOLTS, 1 lIS' DlA. ( 8' LOr/G, A!:TH Al'::i:i GRADE B-7. ',ITH 2 H£:X IIUTS ElICH PE:R Sf'E:CIF"lCATlDtl EP-COATBOL T ~TLJíJ SOLTS, I liS' DIA. :C 9' LruJú, ASTH AI93 GRADE B-7 U!H 2 HEX t:LlTS EA~ PER !FEC1F"lCATIDlf EP-aJATBOLT G.t,S¡(!: '0" , RAISED rACE, 10 5/~' [jl).:. 13/4' ID, tION-ASaE:;rOS Rlrl,j, :,1'5' îf-lIC~:, f"ß'i lTZH .. ¡ !!'!:. .....2'5' j ü. ¡( 0 :¡-æ' \.'.T.. :;EE I~DTE 1 AUD TAaLE: :r~Aj)~.£T. 3/~'. iiT£EL., 3.001; 'JaG. VELDElI VERTICAL iJll 10P E. Of'" IUBë:. ,l'>'/¡G£, Rf" \¡N , e', STEEL, AlSI ':00, 1,981' BOt'<€: G¡'~KE:T, RAI~E.¡ rACE, 12 5/S' CD. x g 7/64' ¡D. SPII?f\L VOlNj) Hn~lLlC, ¡ '8' ro.HCi<, ''//[lnlffi RU!G FOR iTEM II ïŒ. \-IElD, 9f¡?S' [¡iJ ). ,322' \, I. srL, HSS SP-75 ".42 (~) F!...~¡¡;E:, tLIiID, PF, ¡-', STEEL, nISI (;1)0, (~) Nvrr ÞS51:H9L. f BElD'1) 2 ~8 j& IEi'-':" h tlj 1:;: \:; ¡"-" <.: lUG ------ DRAI'1" lif: Ol'AWlI/G ~.r.1tJ.. - =~t. Id" SIJRI.'EY DATE'¡ ~ sCALE: N 6 N e: ~vl,.O A;P1/ PROJa:T IC~ ---:- m£ tWIt: 9!' 4OQ01 Rio! r.o.TE éØPlpo¡:"o G::",~ '/3S 8" ULTRASONIC METER TUBE W /GALLAGHER FLOW CONDITIONER 10/99 ~,ù. REC.,jRl) --~-- --- L D/O.AI'/'"~O) 110, ' rm..e: REF"!;;,RENCE DRAWING~ t':';>\I;:'-7 (R.-.., ~/!i') ~ - J/0'2 "'~I PER ~ùQ:t IdSD'S ~ICES -. ~ NO. c,o,l"E er DESCRiP1lO-N - ------=.~--~--~- RE:VISlONS- -'- ~~~. EPB-A-E2-82 I~ .J KBU 41-7X (202-025) Surface Location change Subject: KBU 41-7X (202-025) Surface Location change Date: Mon, 07 Apr 2003 14:57:42 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Gary Eller <jgeller@marathonoil.com>, Pete Berga <PKBerga@marathonoil.com> CC: Denise Titus <dmtitus@marathonoil.com> BCC: Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Gary and Pete, Denise submitted the Completion Report (407) for the subject well at the end of March. "Completion" in this case might be inaccurate since it appears Marathon is still planning work to get the well to produce. Denise noted in her cover letter that there had been a change in the surface location of the well and that the change was necessary to accommodate the rig footprint. I have checked our well file and do not find any information relating to the need to change the surface location. 20 AAC 25.015 provides regulations if changes are necessary in a permit to drill. (a) provides for changes before a well spuds and (b) provides for changes after a well spuds. It appears that the need to change the surface location was known in advance of spud and the Marathon should have followed the requirements of (a) (1) and submitted a revised permit application reflecting the new surface location information. We would appreciate your submitting any future changes regarding permits to drill as guided by 25.015. With regard to this well, we have made the necessary changes in our files and database. In order to complete our files, it would be appreciated if you would send us a copy of the as built survey for the well. Please contact me if you have any questions. Tom Maunder, PE AOGCC ------- ---- ------- - -------------------------- -- ______m -- --- - -----------~-----._--------------------------- ------- -- - - - - ---- n- ----------------- ---- --~-------.- -- ------------- ------- ._n_____-. --. -- - -.------------------- - - - ------- --. i Tom Maunder <tom maunder~admin.state.ak.us> ~ : Sr. Petroleum Engineer ; Alaska Oil and Gas Conservation Commission ---" ---------.------ ------- -"---- -- --- ----_._---~_. ----_...._----.-. . ----~-- --- ----"- ~~ --.- 1 of 1 4/7/20032:57 PM ,. , Nt Marathon MARATHON Oil Company ~ Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 27, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 41-7x Dear Mr. ~~r: Enclosed is the 10-403 Application for Sundry Approvals for Kenai Gas Field well KBU 41- 7x. The proposed work is to install a 2" coiled tubing lift string in the cemented well bore. Gas from a nearby higher pressure Tyonek well will be metered and used as lift gas. ,/ The well was drilled to TO on 3/5/2002, but has not yet produced to sales. Included in the packet is a summary of the coiled tubing procedure, a well bore diagram, a tree diagf.am, and :;..- a lift gas supply sketch. We would like to mobilize onto this well arou~a'4/~L2Ð03 ~ If you need any additional information, I can be reached at 907-283-1333 or bye-mail at d mtitus@marathonoil.com. Sincerely, ,..t , .' (, ~ '''-t. '-: ' '¡ -+" f "-. \.,:""-", J ...~ L '~""::> Denise M. Titus Production Engineer Enclosures RECEIVED MAR 3 1 2003 AJa~ka 0;; & Gas Coi:~. vJmrrusMm .i\nchcnge OR\G\t\AL .. 0 IEXCELIAOGCC""und G"",, L,rl.XLS ) ~0.f\- 'f/3¡ Lces 17/t7J c 4-/ (J j It';' '"? STATE OF ALASKA "'r ,(? h ~ ALASKA OIL AND GAS CONSERVATION COMMISSION J '1 ') C / APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3 Address P. 0, Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface '238' FNL, 4346' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval Suspend - Repair Well - Operation Shutdown Plugging - Pull Tubing - 5, Type of Well: Development ~ Exploratory - Stratigraphic - Service Variance At Effective Depth Install CT velocity string with / annular gas source to lift water At Total Depth 191' FNL, 3837' FWL, Sec. 7, T4N, R11W. S.M. 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length 68 ppf 23 ppr 99 1514 9.3 ppf 5292 4892'-4910', 4913'-4922', 4942'-4951', 4992'-5002', 5012'-5026', 5038'-5056' measured true vertical 4831'-4849',4852'-4861',4881'-4890', 4931'-4941', 4951'-4965', 4977'-4995' ~~ECE\VEO Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Re-enter Suspended Well - Time Extension Stimulate Perforate Other X 6, Datum Elevation (OF or KB) 14 feet 7. Unit or Property Name Kenai Beluga Unit 8, Well Number KBU 41-7x 9, Permit Number 202-025 /" 10, API Number /' 50- 133-20510-00 11, Field/Pool Kenai Gas Field, Beluga Pool 5300 feet Plugs (measured) 5239 feet 5228 feet Junk (measured) 5267 reet Size Cemented Measured Depth True Vertical Depth 13-3/8" Driven 99' 99' 7" 140 sks 1514' 1511' 3-1/2" 700 sks 5292 5231' N/A Description Summary of Proposal ~ 15. Status of Well Classification as: Detailed Operations Program ~ Aiaak~ Oil & Gas Gon~. Gümmiaon . BOP Sketct/41cbOf8g0 14. Estimated Date for Commencing Operation 4/9/2003 / 16. Ir Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. PI" . i~,~~ Signed ~\.,""-' ~ vt... ~ ¿¡". Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity - BOP Test X. Location Clearance - Mechanical Integrity Test - Subsequent Form Required 1 0- '1(,,: 4- Approved by Order of the Commission Form 10-403 Rev, 06115188 ¡;~ - 5 ~--L-- ~ ~BOMS BFL ORIGINAL MAR ~ 1 L003 v Suspended - Date 3/27/2003 Approval No, ""...<, ,- ./ C ,:::/ . ...L.'.) ~ ') 1V:.t ß ~"E f¡: "2..S"CC P~('. Dat~ši~Plicale Commissioner tJQI!~1 J - -,~ ¿M) !\Iarathon Oil Company Alaska Region IffiU -41-7x Kenai Gas Field, Pad 41-7 Lift String Procedure '''BS # R\V.03.07999.CAP / History: Gas production has not been established in KBLT -t1-7x. Communication with water bearing coals is the suspected cause of water loading which subsequently kills the \\"dl. Additionally~ solids (coaL silt, and sand) in the 3- l,'2" monobore have been probleJTlatic. A mechanism is required to prevent or handle the water and soltds that are produced in hopes of ~stablishing production. ('()nsistent \\"ith other Be luga sand ('ol11pletions in the Gas Fièld, I<BU -1-1-7x is expected to sho'.v a trend of dewatering and increased gas production once production i3 established. SBHP== 1890psi. ./' Ohjective: Instal! temporary gas lift Ii1 an attempt ii' dewater Upper Beluga p(~rforations. The mechanisn1 used will include a packerless velocity string ~md a gas source to re\'erse circulate /' ".yater out of the \vellbore through the smaller string and through the production system. Procedure: 1. Bleed off any wcllhead pressure and ensure \\'ell is dead. Sen'ict' tree \'ah'~s paying close attention to botlom master \"al\'e-. Clost' bottom master \'ah"e. Bleed d(\'.vn and disassen1blc sw'face flowlines}.! tre(:. NO tree between bottom and sècond master yalves. NU Tru-Set CT hanger spool on top of bottom master \'ah'e of existll1g tree tC~')tbldt Tom Davis regarding positioning or hanger). Record dimensions ofTru-Set spool and modify tree flowlines to accOtTImodate taller tree. Remaining tree \'al\'cs will not be replaced until after the "clacity string is installed. i~" ~ ~) fvlIRlJ BJ CT unit with 2" pipe. l\JU BOPs on 3- l,'W' 31\1 flanged CT hanger. RU tlo\\'back line from side outlet on CT hanger spool (2-1/16" 5~..I llange), 3. Prep and weld CT BHA connection and test per procedure. Use 2"' CT straightener to remove nlemory bend in CT (to pre\'ent nlllning il)to chemical injection port). Fill CT and pressure/function test BOPs to 250/2500psi./Break lubricator and install profile nipple with plug installed. l\lU lubricator and line up kill line to BOPs for body test 250/2500psi. 4. RlH slowly w,' 2"' \'elocity string watching weight indicator closely (note-hanger ID=~- 3/16"). Run string to depth of ~890'KB --confirm depth based on 21' RT -GL measurement. 5. Once on depth., tunl operating screw on CT hanger about I.::! tml1 to position n1arked on hanger. Lower tubing until weight indicator reads zero and hanger is sUPPoI1ing the tubing. Tighten the gland nut on the operating screw. 6. Energize the packoff assembly by tightening the four packoiT screws one half turn each, equally repeating until all four are tight. Tighten all four gland nuts on the packoff screws. 7. Pressure test CT hanger seal once packoff is thoroughly engaged, Pressure up abo\'e seal through kill line to 1000 psi. Care must be used to not exceed test pressure (-1300 psi CT collapse pressure). lvlainrain pressure for 5-10 minutes. S. Once packoff is \'erified holding, bleed off test pressure and fluid. Cut pipe \\lith BOP shears. Rig injector head and BOPs back from CT spool. Rc-cut the coil tubing 6'~ abo\"c the tubing head asseo1b1y, RDl\10 BJ CT" l} NU remaining tree vah'es and test. Prep for surface tlowlinc tie-.in. ! 0 r\!HP.U slickline to pull running plug in \,'cloclI-y string. ROIV[O s!1ckline. Ii. ~~nRU BJ Nl truck to CT annulus flang~. Rig up tlowback to open top tank through tree wing nangt or lrec cap, Pump 'N1 to void annulus and tubing taking returns tù tank. Tubing will be considered cle31~nce watcr remrns slow or tubing load volume (CT -I- annulus} of 38bblls reco\'ered. Shut In fJo\vback and o\"er-displace \\'ilh nitrogen. Lea\'t' N2 cap on well to prevent \vellbore influx. RDJ\lO B1 SCtTices. ¡ l, Complett surta~:c' tie-ins. Configure so that met(~red gas line from KTU 24-6h ties into tht CT hanger annulus. The wing abo\'e the second master will tie in to the 10\"/ pressure system as bcfon~, i3. Line up lin gas to CT annul.us, .\Vith injection gas on, open \"el~lt): ~tring to low pressure test separator. 1\1all1tall1 now at or above O.SI\:f.l\:,lscfd. 1\''ÎOnltor annu1us gas rate and pressures at stable \Veil flo\\'rates. ( +-'/ W Ð IÞbl /h,ð I d \l e :7 CA., "\. ' Evv,c;.~ ~~t",\) ? ~ ~~ dM y,~~~-t.~ ,~-\ rJ C lJ.r~ (' \ - "r-'~- ;¡". \" ..I .:.:~.. ... ~ " ~ \'''-..., ~ t- -. , r~~'t." \ .,1) '-I . ,- . .J M.1.I !'" Ç. (j f \ "t.~ /,JJ6Jr 4/ ~I 0 ~ API' 50-1:¡"3-20510-00 AOGCC.202-025 RT -GL: 21.0' '179' FNL, 4353' FWL Sec. 7. T4N, R1'IW, S,M, ~ Tree cxn: 4-3/..\" OtiS Hanger lift threads: 3.ì2S" MCA Chemical Injection Mandrel @ 1-1-61' . 1/4",0.049" wall, S5 control line - 1" side pocket Injection v31ve Proposed Velocity String. / 2" wi O. 109"' wall, grade 70 CT to 4890' OLIS >: rJlpple @ -t933' 10=2.813" ¡,IOIe:' E-hnr. sho'",,::, :~-nl¡Jpl0. at .1923' IVID Directional KOP-2217' DOP - 3418' l\1a>: hûle angle 17.8 deg All doglegs less than 3 deg/l 00' Well Name & Number: County or Pan::h: FWHP: I I Date Completed. Prepared By: I KBU41-7x I Kenai Borough FBHP: Gary Eller Ã API# KBU 41-7x M ¡::::1 H i:,¡~ ¡ .~ ~, ~ ~, 11'1 k~ ~¡! ~,¡!,:! f.~~ trf[ t)' " ' 'i~¡ ~::',¡,¡ ~ \~ ~: ~,L r¡ A , 'I i't f",J ¡j ,. I ~. \ :1 I ~ !'A 'I }, :~~ I~' '~~!, ¡ \ , ! :I :it :III .:~!1;, X;:::~ . "' J I . :fl :111 ];I :u )¡ :11 ) :t :III :II A ... PBTD: 5228' MD TO 5300' MD State/Prov FWHT' .. 13-3/8",68 ppf, J-55 Drivepipe @ 99' ... 7",23 ppf, L-80, BTC Casing @ 151..\' cemented w/l"¡O 3X Upper Reluqa Perfs: ( Pet I:; U5 - 4892'-4910'.6 spí, 60 deg, 6/16/02 U5 - 4913"..492~', 6 spf, 60 o<::g. 8116/0? U6 - '~942'-<1951', 6 spf, 60 deg, 8/16/02 U7 .4992'-5002',6 spf, 60 deg, 5/5/02 U7 - 5012'-5026', 6 spf. 60 deg, 5/5/02 US - 5038'-5056', C sJjf, 60 deg, 5/5/02 It It r.:: I( It II: [ IC II: It: [M\ \ .......... ..un, 3-1/2", 9.3ppf, L-80, EUE 8rd (~:lod) at 5292' Cemented wllh 530 S\S oj class G Kenai Gas Field, Pad ..¡ 1-7 Countr~¡: USA Other. Lease I AK I I FBHT: Last Revision Date: KB-GL: KBll ~ll 7. '"" - :\ i Ja ~ L. f ,. " sit / n ~ --l -~~-- / . ... "- ( I ~' ", ) 1-." ¿' r I L- ----IÞ- To ProcJuctiûn Lin (';'~I':' T, I '-' ...,~ ill ...-- -- - ---1 .----- - 3-.1:'2"' Cemented T b. ----------- u mg ----- ")" f -, ~. ).109" wall / \' elocitv St . ~ nng I To lo\\' pressure productIon header Gas Lift Gas FIo\v / Diagram For 41- 7X / I Cìas Ii fI meter Qas I ~ ~ c Portion of gas strean1 produced from KTlJ 24-6h Return gas meter From r\leter 41-.7X ----~ I] I . ~¡:::: ('¡'H,' r ;1'1 ,}"'\\'!"! '.'I'lf',."}'" ':11"¡.\-!\Ò 'It-I~-I'l~!''': "" c. l .' l.. ~ ~ . Iol. I ~. ....' ,,," l .. ,þ ..:' '.. .~ ~ . ... \ . " ~.reIl41-7X _1 I~ .~---- n~_- - ~----------------- ( .,.., I "f t r:-- ... ---- "Vater and Gas '" ~ Nt Marathon MARATHON Oil Company - ~ Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 March 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 41-7x Dear Mr. Maunder: Enclosed is the 10-407 Well Completion or Recompletion Report and Log. One item that has changed from the permit is the surface location. The original surface location recorded on the drilling permit was from the initial staking. A small change was made to accommodate the rig footprint on the drilling location in relation to the other wells on Pad 41- 7. The directional plan was unchanged, resulting in a small difference in bottom hole location. The well has not been capable of sustained flow since being perforated. Attempts to isolate zones and jet the well in have been unsuccessful. Currently the well is being evaluated for a velocity string with gas being injected down the coil tubing annulus to lower bottom hole pressure and encourage flow from the perforations. All perforations are open to the wellbore as shown in the wellbore diagram. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, 1 Wv~ . j.-- Denise M. Titus Production Engineer R r' 0, r- f', f í -:. d-"" ~ -- ~~:~ \\'Y': ~~~.. '. '.:~ ~ ,: Enclosures U,;:'.:l :: ~ '. .' ~'~,:,.~,;':'::~':; ,: 'a':'''::- .-_. . , Ol,G.NA~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1, Status of Well OILD GAS[I] 2, Name of Operator MARATHON OIL COMPANY SUSPENDEDD ABANDONEDD 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 238' FNL, 4346' FWL, Sec, 7, T4N, R11W, S,M. At top of Producing Interval 192' FNL, 3845' FWL, Sec. 7, T4N, R11W, S.M. At Total Depth 191' FNL, 3837' FWL, Sec. 7, T4N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) DF-GL: 20,5' GL - 66' , , _.61 If) 62- ;.-.;',~.~.- ,.' Classification of Service Well SERVICED 7. Permit Number 202-025 8. API Number 50-133-20510-00 ,'~I,','~tOt."~' iS1 "';""'.;W~.n 'ø::.' ~, .1 1'.' 'F~t\¡.f$;~ i£:~:. r . ~.~ . ',; 9, Unit or Lease Name Kenai Beluga Unit 10, Well Number KBU41-7x 11. Field and Pool 6. Lease Designation and Serial No. A-028142 12. Date Spudded 2/27/2002 17, Total Depth (MD+TVD) 5300' MD/5239' TVD 13, Date T.D, Reached 3/6/2002 14 Date Comp., Susp, or Aband, 6/4/2002 Kenai Gas Field, Beluga 15, Water Depth, IF offshore N/A feet MSL 16, No. of Completions ~ 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 5228'MD/5167TVD Yes~No D N/A feel MD 22. Type Electric or Other Logs Run PEX-DSI 23 21, Thickness of Permafrost N/A CASING SIZE WT. PER FT. GRADE 13-3/8" 68 K-55 7" 23 L-80 3-112" 9.3 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM surf 99' surf 1515' surf 529Z AMOUNT PULLED NIA N/A N/A 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Beluga Sand MD: 2-1/2" HSD 6SPF 4892'-4910',4913'-4922',4942'.4951' I 2-1/2" HSD 12 SPF 4992'-5002',5012'-5026',5038'-5056' TVD: 4831' - 4849',4852' - 4861',4881' - 4890',4931' - 4941', 4951' - 4965',4977' - 4995' 27. Date First Production N/A Date of Test HOLE SIZE Driven 8-1/2" 6-1/8" 25. SIZE N/A CEMENTING RECORD N/A 140 sx (to surf) 530 sx TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flow Tubing Pres PRODUCTION FOR TEST PERIOD -. Casing Pressure CALCULATED 0 24-HOUR RATE-' Hours Tested OIL-BBL 0 OIL-BBL 0 GAS-MCF 0 GAS-MCF 0 WATER-BBL CHOKE SIZE GAS-OIL RATIO 0 NIA WATER-BBL OIL GRAVITY-API (corr) 0 N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips. no cores taken Form 10-407 Rev 7-1-80 ~ R n ~f ~ R r: I. CONTINUED ON REVERSE SIDE f~:í"'" ........- ' ~. .,1.-:.:'" ~: Ra~ ..... D' r-~ - ~ . if"" i \¡t1!t"¡, ~ 'Ii' ~.~ 0.",... ,-="y 2 ~~ L k) MAR 3 1 2003 .I"::",,!.,.,, 'h.~" ,... - ~ -. ~, J..' 0 ~.;\,:) L.\.\¡~~, ~-,{.'mmj~~it in Tnplicate l\.1choregß :1 t't:.' ORIG NAL N.\drlglkgflwe:IISIKBU33.6\AOGCC CompletIon 10"'¡07.xls . ~ G¡::- 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. Sterling 3626 3582 N/A Upper Beluga 4729 4668 N/A 31. LIST OF ATTACHMENTS 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 1\': ] ~~'- /~l'I'¡" V ~) { 1~''''V0 Denise Titus Title Production Engineer Date 3 ¡;'J.-lu / ~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal. water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 N '.drlglslt';rl,ngI,SlJ32-9'AOGCC Completion 1Q-4Q7,xIS Dailv Summary for Well: Report Date Drilling Event: 23-Feb-02 24-Feb-02 25-Feb-02 26-Feb-02 27 -Feb-02 28-Feb-02 01-Mar-02 02-Mar-02 03-Mar-02 04-Mar-02 05-Mar-02 06-Mar -02 KENAI BELUGA UNIT 41-7X Report MD TVD Summary Number 2 3 4 5 1,515 1,512 6 1,515 1,512 7 1,515 1,512 8 3,500 3.463 9 4,850 4,790 10 5,208 5,147 11 5,208 5,147 12A 5,300 5,239 Completion Event: 06-Mar-02 12B 5,300 5,239 07 -Mar-02 08-Mar-02 04-Jun-02 05-Jun-02 06-Jun-02 07 -Jun-02 1 of 5 13 5,300 5,239 14 5,300 5,239 15 5,300 5,239 16 5,300 5,239 17 5,300 5,239 18 5,300 5,239 Release rig from KBU 44-6 / Start rigging down for move Move and set modules / continue rig up 0 Accept rig @ 0600 on 2/25/02 / Rig up diverter / Pick up pipe and BHA / Prep to spud Drilled 1515' - 8 1/2" surface hole Ran and cemented 7" / nippling up Nipple up and test BOP's / Perform L / 0 test / drill from 1535' to 3500' Drill to 3983' / Short trip / drilling @ 4850' T.D. hole / attempt to log / picking up BHA for clean- out trip Wash and ream to bottom / Condo mud / try to cure losses / P.O.H. / log hole RIH. CIRC. Drill F/5208 to 5300'. CBU. Short trip to 4317'. RIH. CBU. Drilling Subtotal POOH LID DP and BHA. Pull wear bushing. R/U CSG tools. Run 3 1/2" CSG. Cement 3 1/2" CSG. wac R/D lines prepare to N/D. N/D BOP. Install pack off and N/U tree. Test tree void and tree. Test CSG. Clean mud pits. RIH on B/L w/ 1 Swab Mandrel w/2 Cups (3"), initial Fluid Level 20' MD, continue Swabbingo Tagged Fluid @ 2025' KB Gun #1 w/ 2-1/2" HSD guns loaded with 6 spf,60 deg phase, 10.7 gm charges. RIH w/ gun #2. Shoot U7 5012'-5026'. Gun #3. Correlate and shoot on depth 4992'-5002. RIH w/ Swab Mandrel & 2 Cups, tag water @ 815' WLM to 1000' WLM, make pulls as per Swab report, 0 continue to Swab thru 1900' well wouldn't kick off, lay down for night, secure wellhead. RIH wI Swab Mandrel + 2 Swab Cups, 1 st pull from 2000' / 900' water returns. W/L Unit Hydraulic System to hot, shut down to cool off. Going to RIH, wouldn't fall. make 1 pull, making 2nd pull from 2500', something pulled free. Knuckle Joint parted. " ~ ~"'""" \- Q, W'~~ J 1";)\ -0 J +- Printed - 3/26/2003 Dailv Summary for Well: KENAI BELUGA UNIT 41.7X Report Date Report MD TVD Summary Number 10-Jun-02 19 5,300 5,239 11-Jun-02 20 5,300 5,239 18-Jun-02 21 5,300 5,239 05-Jul-02 22 5,300 5,239 11-Jul-02 23 5,300 5,239 14-Jul-02 24 17-Jul-02 25 18-J u 1-02 26 19-Jul-02 27 24-Jul-02 28 25-Jul-02 29 29-Jul-02 30 09-Aug-02 31 14-Aug-02 32 15-Aug-02 33 16-Aug-02 35 21-Aug-02 36 2 of 5 Swabbing: RIH w/2 @ 3 1/2" Swab Cups to 900', Fluid level @ 330. Worked tools in and out of hole until Fluid level is @ 1300'. RIH wi New Swab Cups to 2300', pulled load to 1430', hit Injection Mandrel and pulled out of Rope Socket. Pulled 250' of BIL. RIH wI 2" Split Skirt JDU to 4933', latch Fish, POOH very slow I] OOH wI Fish, RID Nitrogen jetting: Jet from bottom at 750 scfm. See returns of grey mud and small pieces of coal. At 2000', change configuration to continue pumping N2 down CT annulus. Continue to pump N2 leaving a 2500psi N2 cap in wellbore. R/U WIL, twist test - OK, P. T. to SITP - 2100# - OKO Ran 2.750" GR, Fluid @ 4431' KB, tagged fill @ 4952' KB, POOH, Gauge full of gray mud, RID W IL RIH wI 2.50" DO Bailer to 4938' WLM, wIt, POOH wI approx pint of mud (thick clay like). RIH wI 2" DO Bailer to 4940' WLM, wIt, POOH wI little mud. RIH wI 2.5" to 4940' WLM, wIt, POOH, empty. RIH wI 2.25" DO Bailer to 4941' WLM, wIt, POOH, empty. 0 0 0 WELL DRAWDOWN TO BE LIMITED TO 200PSI (10% DO) TO OBSERVE WHILE WAITING TO ADD UPHOLE PERFS R/U, shoot Fluid Level on Tubing R/U, shoot Fluid Level @ 3512 RIH WI 2.25" GAGE TO 5192 WLM POOH Reperforated Beluga Sands 5038'-56', 5012'-26', & 4992'-5002' with estimated 40% underbalance. SITP dropped from 560 psi to 520 psi after shooting deepest interval. Secure well, SDFN. Perforate U5 & U6 4942'-4951',4913'-4922',4892'- 4910'. RDMO e-line Shoot 3 Fluid Levels: 0 #1 Fluid level @ 1822'0 #2 Fluid level @ 1826'0 #3 Fluid level @ 1830' Completed multiple swab runs. Recovered -30bbl water. Swabbed to max depth 2000' (to not exceed 30% drawdown) Printed - 3/26/2003 Daily Summary for Well: KENAI BELUGA UNIT 41-7X Report Report MD TVD Summary Date Number 22-Aug-02 37 Resumed swabbing. Recovered -50 bbl fluid. 23-Aug-02 38 Swab to lift fluid. Seeing decreasing gas returns. Total fluid recovered -55bbl 26-Aug-02 39 Continue swabbing wI 2400' limit (40% drawdown). Recover -55bbl water wI limited gas returns. 27 -Aug-02 40 Resume swabbing. Recover -40 bbl water. Limited gas returns. Seeing decreasing water influx in well. 28-Aug-02 41 Stuck A-Slip Stop tool in lower U6 perfs @ 4948'. Attempt to cut braided line. Dropped 2 cutters and 2 weight bars wI no success. 29-Aug-02 42 0 04-Sep-02 43 Cutting B/L wI Kinley Cutters 18-Sep-02 44 Set BPV. Move in and begin rigging up rig. 19-5ep-02 45 Finish rigging up rig. 20-Sep-02 46 Rig on standby, waiting on specialty tools and ~~ .-dSCa equipment delivery for workover. N/U BOP stack. 21-Sep-02 47 N/U & test BOPE. Picking up and standing back workstring in derrick. 22-Sep-02 48 Make first attempt to fish wireline tools and braided line lost in hole. 23-Sep-02 49 Continue fishing for wireline tools and braided line, lost in hole. Recover 2 Go-Devils, last 24 hours. 24-Sep-02 50 Continue fishing for wireline tools and braided line, lost in hole. Recover Kinley Snepper, and 1 wireline cutter bar, last 24 hours. 25-Sep-02 51 POOH wI overshot/int wireline grab assy. No catch. RIH w/wireline spear assy. Engage fish. POOH. Recovered 4-6- of 3/16" braded line. RIH w/overshot/int. wireline grab assy. Engage fish. POOH. 26-Sep-02 52 POOH w/overshot/int. wireline grab assy. LID overshot/into wireline grab assy. M/U wireline spear. RIH. Engage fish. POOH recoved l' of line. RIH w/wireline spear. Engage fish. POOH. 27 -Sep-02 53 POOH w/spear assy. No recovery. RIH w/Alligator spear/grab assy. Engage fish. POOH. No recovery. RIH w/overshot assy. Engage fish. Reverse circ and wash down 4830' to 4840'. Circ. long way and wash down 4840' to 4865'. 28-Sep-02 54 Circ. well clean. POOH. LID overshot/into grab assy. P/U 2.81 impression block. RIH w/2.81 impression block. Tag @ 4867'. POOH w/impression block. Test BOPE. 3 of 5 Printed - 3/26/2003 Dailv Summary for Well: KENAI BELUGA UNIT 41-7X Report Date Report MD TVD Summary Number 29-Sep-02 55 Prepare BHA. RIH w/spear assy. Engage fish. POOH w/spear assy. Recoved ball of 3 /16" braided line( +/- 10'). Slip and cut. RIH w/wireline spear. Engage fish. POOH w/spear assy. Recovered 28' of 3/16 braided line. RIH w/Alligator/int grab assy. 30-Sep-02 56 RIH w/Alligator/int.grab assy. Engage fish while reverse circ. and circ. long way. Reverse circ. clean. POOH. No recovery. RIH w/wash shoe and wash pipe. Wash F/4877' to 4898'. Reverse circ. clean. POOH. No recovery. RIH w/Wireline spear. Engage fish. POOH. Recoved 4' 3/16" braded line. RIH w/wireline spear. Engage fish. POOH. No recovery. LID wireline spear M/U 2 3/4" wash shoe and wash pipe. RIH. Circ. and work F/4899' to 4901'. Rev. circ. and work 4901 to 4903'. POOH. 0 1-0ct -02 57 02-0ct-02 58 POOH w/wash pipe and shoe. LID wash pipe and shoe. M/U wireline spear. RIH. Engage fish. POOH. Recovered 3' of 3 /16" braided line. C/O wireline spears. RIH. Engage fish. POOH. Recovered 2' of 3/16" braided line. RIH w/wireline spear. 03-0ct-02 59 RIH. Engage fish. POOH. No recovery. C/O spears. RIH. Engage fish. POOH. No recovery. Dress 2.81" Imp. block. RIH. Engage fish. POOH. POOH w/2.81" imp. block. RIH w/2 3/4" Washpipe and drag shoe. Wash over fish F/4898' to 49101. CBU. POOH. RIH w/overshot assy. Engage fish. POOH. 100% recovery of fish. B/O overshot assy and LID fish. 04-0ct-02 60 05-0ct-02 61 Repare power tongs. RIH to 4812' w/2.75" mill. Wash f/4812' to 5216'. Circ. shakers clean. Displace well to 6%KCL. POOH. LID 2.75" mill and M/U 3.5" WRP. RIH. RIH w/3.5" WRP. Set WRP @ 4980'. POOH LID 2 1/16" TBG and setting tools. RID tubing running tools. Set BPV. Flush lines and surface equipment. N/D BOPE. N/D BOPE. N/U Tree. Test tree to 3000psi/30min. Pull TWC. Install BPV. Clean pits. Organize rig and clean cellar. Caliper log completed. No casign damage shown. Recover 69 bbl fluid. Leave 2050 psi N2 pressure on well. Bleed wellhead pressure down to about 700psi (x2). 06-0ct-02 62 07-0ct-02 63 09-0ct-02 64 11-0ct-02 65 12-0ct-02 66 4 of 5 Printed - 3/26/2003 Dailv Summary for Well: Report Report MD Date Number 13-0ct-02 67 14-0ct-02 68 15-0ct-02 69 07 -Nov-02 70 08-Nov-02 71 16-Nov-02 72 18-Nov-02 73 19-Nov-02 74 01-Dec-02 75 05-Dec-02 76 5 of 5 KENAI BELUGA UNIT 41-7X TVD Summary Shoot fluid level @ -4600'. Level is suspect given Pwh=875psi. RU Pollard to run static survey, BHP=1890psig, Fluid level is found to be at 2700'. Bleed off existing WHP based on fluid level of 2700' to encourage more water into wellbore. Recover 53 bbl wI estimated tubing volume of 35bbl. Well was not able to lift fluid without N2 assist. Leave well balanced wI N2 pressure. Injected 121000 scf N2 into U5 from surface. Flowback to tank to lift water. Recovered -42bbl. Continued allowing well to flow to atmosphere via gas buster. Water rate tapering from 6 bbl/hr to less than 1 bbl/hr wI Pwh<50psi. SI well at 15:00. Recovered -93bbl total (including yesterday). RIH and tagged fill with 2.25" sample bailer. Tagged clay at 4844' and worked to 4846'. RIH to fill. Wash fill taking returns to gas buster. Engage plug and pull once returns are clean. Leave well balanced with N2 pressure. Rig back for night. RIH wI CT to bottom and ensure all perfs are clean. Overdisplace with nitrogen. POOH and RDMO CT. Well flowing back to tank making 18 bwph. Well flowed small volume of gas and up to 300bwpd for about 10 days. Soap sticks were dropped and gas was injected down the chemical injection line in an effort to assist fluid lift. The well first stopped making water and then gas ceased. Well is SI Tagged fill at 4920 wlm. Pulled sample of coarse coal/sand. Completion Subtotal Printed - 3/26/2003 API: 50-133-20510-00 AOGCC: 202-025 RT-GL: 21.0' 179' FNL. 4353' FWL Sec. 7, T4N, R11W, S,M, .. Tree cxn: 4-3/4" Otis Hanger lift threads: 3.725" MCA Chemical Injection Mandrel @ 1461' - 1/4", 0.049" wall, SS control line - 1" sidepocket injection valve Proposed Velocity String: 2" wI 0.109" wall, grade 70 CT to 4890' Otis X Nipple @ 4933' 10=2.813" Note: E-line shows X-nipple at 4923' MO Directional KOP - 2217' DOP - 3418' Max hole angle 17.8 deg All doglegs less than 3 deg/100' Well Name & Number: County or Parish: FWHP: I I Date Completed: Prepared By: I KBU41-7x I Kenai Borough FBHP: Gary Eller KBU 41-7x .. . J ::I JI 1': ~}'~ ", :: . . J I: :I I: :II II: J :I 31 ] :J :I :I .. .. PBTD: 5228' MD TO: 5300' MO State/Provo FWHT: API# M MARATHON .. 13-3/8", 68 ppf, J-55 Drivepipe @ 99' ~ 7",23 ppf, L-80, BTC Casing @ 1514' cemented w/ 140 sx Upper Beluga Perfs: J: I: I: U5 - 4892'-4910',6 spF, 60 deg, 8/16/02 U5 - 4913'-4922',6 spf, 60 deg, 8/16/02 U6 - 4942'-4951',6 spf, 60 deg, 8/16/02 U7 - 4992'-5002',6 spf, 60 deg. 5/5/02 U7 - 5012'-5026', 6 spf, 60 deg, 5/5/02 U8 - 5038'-5056', 6 spf, 60 deg, 5/5/02 I: 1£ I: I I: I: I: 3-1/2", 9.3ppf, L-80, EUE 8rd (Mod) at 5292' Cemented with 530 sxs of class G Kenai Gas Field, Pad 41-7 Country: USA Other: KB-GL: Lease I AK I I FBHT: Last Revision Date: MARATHON Oil Company Pad 41-7 KBU41-7X slot #KBU41-7X Kenai Gas Field Kenai Peninsula. Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: MHD <0-5300> Our ref: svy671l License: Date printed: 26-Mar-2003 Date created: 27-Feb-2002 Last revised: 19-Mar-2002 Field is centred on n60 27 33.151,w15l 16 7.223 Structure is centred on 270908.300,2362070.010,999.00000,N Slot location is n60 27 31.944,w15l 14 42.248 Slot Grid coordinates are N 2361771.214, E 275251.277 Slot local coordinates are 215.06 S 4348.10 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company Pad 41-7,KBU41-7X Kenai Gas Fie1d,Kenai Peninsula. Alaska Measured Inc1in Azimuth True Vert Depth Degrees Degrees Depth 0.00 139.00 287.00 378.00 438.00 530.00 626.00 687.00 750,00 813,00 877,00 940.00 1003.00 1065.00 1128.00 1191. 00 1254.00 1317.00 1380.00 1444.00 1471,00 1523.00 1585.00 1647.00 1712.00 1775.00 1837.00 1900.00 1964.00 2029.00 2092.00 2154.00 2217.00 2278.00 2341. 00 2404.00 2466.00 2530.00 2593.00 2656.00 2720.00 2785.00 2849.00 2912.00 2976.00 3040.00 3103,00 3166.00 3229.00 3293.00 6.00 7.50 8.70 9.80 10.60 12.10 13.20 15.00 16.40 17.50 17.80 17.70 17.50 17.20 17.10 0.00 0.40 1. 05 0.90 0.60 0.00 61.10 49.50 45.30 66.40 1.10 3.10 3.60 5.40 6.10 142.70 150.80 148.00 153.60 152.50 6.20 6.30 5.90 5.50 4.70 158.20 166.60 177.80 195.10 208.80 3.70 2.50 1. 70 1. 70 2.10 221. 40 241.10 286.50 308.60 303.70 2.10 1. 90 1.80 2.00 2.00 306.90 298.40 297.00 297.70 297.40 2.10 1. 90 1. 90 1. 70 1. 90 302.60 296.70 289.60 292.10 281.60 1. 90 2.30 2.60 3.80 5.00 281.90 278.70 285.10 290.00 291. 40 290.70 291. 40 290.00 289.60 285.80 281.20 277.70 279.40 278.40 278.80 279 .10 279.80 280.10 280.10 278,70 0.00 139.00 286.99 377 . 97 437.97 529.96 625.89 686.79 749.59 812.27 875.90 938.53 1001.18 1062.87 1125.63 1188.46 1251.37 1314.33 1377.30 1441.27 1468.25 1520.22 1582.18 1644.15 1709.11 1772.07 1834.03 1897.00 1960.97 2025.93 2088.90 2150.86 2213.80 2274.70 2337.52 2400.23 2461.80 2525.16 2587.34 2649.34 2712.09 2775.51 2837.58 2898.23 2959.45 3020.43 3080.43 3140.49 3200.62 3261.77 5URVEY LI5TING Page 1 Your ref: MWD <0-5300> Last revised: 19-Mar-2002 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 5 Deg/100ft 5ect O.OON 0.23N 1.36N 2.41N 2.87N 2.36N 0.645 3.715 8.045 13.665 19.895 26.415 33.015 39.065 44.245 48.035 50.215 50.615 49.775 48.525 47.955 46.975 46.045 45.095 44.045 42.925 41.845 41.025 40.315 39.735 39.305 38.905 38.345 37.295 35.575 33.415 30.795 27.615 24.185 20.805 17.905 15.585 13.255 10.615 7.825 4.805 1.655 1.64N 4.94N 8.02N O.OOE 0.42E 1.91E 3.05E 3.67E 4.65E 6.47E 8.29E 10.66E l3.52E 16.38E 18.44E 19.37E 18.72E 16.69E 14.10E 11 . 55E 9.45E 7.83E 6.11E 5.30E 3.78E 2.01E 0.18E 1.83W 3.78W 5.65W 7.57W 9.45W 11 . 4 OW 13.44W 15.68W 18.31W 21. 54W 26.06W 31.70W 38.49W 46.93W 56.46W 67.09W 79.33W 93.37W 108.78W 125.63W 144.07W 163.24W 182.19W 200.95W 219.45W 238.06W 0.00 0.29 0.45 0.18 0.67 0.00 -0.39 -1. 73 -2.75 -3.31 G RID COO R D 5 Easting Northing 275251.28 275251.71 275253.21 275254.37 275255,00 275255,97 275257.74 275259.50 275261.78 275264.54 275267.27 275269.21 275270.00 275269.24 275267.11 275264.45 275261.86 275259.75 275258.14 275256.45 275255.65 275254,15 275252.40 275250.59 275248.60 275246.67 275244.82 275242.92 275241.06 275239.12 275237.08 275234.85 275232.24 275229.02 275224.54 275218.94 275212.20 275203.82 275194.36 275183,80 275171.62 275157.63 275142.26 275125.47 275107.08 275087.98 275069.10 275050.40 275031,97 275013,42 2361771.21 2361771.44 2361772.54 2361773.56 2361774.01 2361773.48 2361770.45 2361767.35 2361762.97 2361757.29 2361751.01 2361744.45 2361737.84 2361731.80 2361726.66 2361722.93 2361720.79 2361720.43 2361721.31 2361722.58 2361723.17 2361724.18 2361725.15 2361726.13 2361727.22 2361728.38 2361729.49 2361730.35 2361731.10 2361731. 71 2361732.18 2361732.62 2361733.23 2361734.35 2361736.15 2361738.42 2361741.18 2361744.52 2361748.13 2361751.71 2361754.85 2361757.44 2361760,07 2361763.02 2361766.17 2361769.56 2361773.07 2361776.73 2361780.38 2361783.82 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU41-7X and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 512.24 on azimuth 275.21 degrees from wellhead. Vertical section is from wellhead on azimuth 276.77 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1.22 2.10 0.86 2.94 1.12 -4.34 -6.51 -8.67 -11.53 -15.04 0.97 1. 46 1. 99 2.83 2.30 -18.61 -21.43 -23.12 -23.19 -21. 78 2.15 2.52 2.83 1. 03 0.67 -19.66 -17.39 -15.35 -13.63 -11.78 0.43 0.69 0.18 0.32 0.02 -10.91 -9.29 -7.42 -5.49 -3.37 0.34 0.46 0.37 0.34 0.59 -1. 31 0.68 2.68 4.63 6.64 0.02 0.67 0.64 2.02 1. 91 8.72 10.98 13.66 17.00 21.69 1.59 2.42 1. 90 1.75 1. 66 27.54 34.60 43.35 53.22 64.17 2.74 2.06 2.89 2.26 1. 73 76.67 90.89 106.47 123.50 142.15 0.49 0.37 0.35 0.48 0.66 161.54 180.73 199.75 218.50 237.35 MARATHON Oil Company SURVEY LISTING Page 2 Pad 4l-7,KBU41-7X Your ref : MWD <0-5300> Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 19-Mar-2002 Measured Inclin Azimuth True Vert RECTAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R D I NATES Deg/100ft Sect Easting Northing 3356.00 17.00 277.30 3322.01 10.59N 256.36W 0.67 255.82 274995.18 2361786.74 3418.00 16.70 275.20 3381.34 12.55N 274.22W 1. 09 273.79 274977.36 2361789.04 3481.00 16.40 275.90 3441.73 14.28N 292.08W 0.57 291.73 274959.54 2361791.12 3542.00 14.90 275.60 3500.47 15.93N 308.45W 2.46 308.18 274943.20 2361793.09 3603.00 14.00 276.60 3559.54 17.55N 323.59W 1. 53 323.40 274928.10 2361794.99 3666.00 13.50 276.60 3620.73 19.27N 338.46W 0.79 338.37 274913.26 2361797.00 3729.00 13.60 279.10 3681.98 21.28N 353.08W 0.94 353.13 274898.69 2361799.30 3792.00 13.50 280.90 3743.23 23.85N 367.61W 0.69 367.86 274884.21 2361802.14 3855.00 13.40 280,10 3804.50 26.52N 382.02W 0.34 382.49 274869.85 2361805.09 3918.00 13.50 279.80 3865.77 29. 05N 396.45W 0.19 397.12 274855.47 2361807.90 3980.00 13.20 282.60 3926.10 31.83N 410. 49W 1.15 411.39 274841.49 2361810.94 4043.00 12.00 283.30 3987.58 34.90N 423.89W 1. 92 425.05 274828.16 2361814.28 4106.00 11.10 283.30 4049.30 37.80N 436.16W 1. 43 437.58 274815.94 2361817.41 4169.00 9.70 278.40 4111. 27 39.97N 447.32W 2.63 448.91 274804.83 2361819.80 4232.00 8.80 278.40 4173.45 41.45N 457.34W 1. 43 459.03 274794.84 2361821.47 4294.00 7.80 279.80 4234.80 42.86N 466.17W 1. 65 467.98 274786.04 2361823.05 4357.00 6.50 280.50 4297.31 44.24N 473.89W 2.07 475.80 274778.34 2361824.58 4419.00 5.30 279.10 4358.98 45.33N 480.17W 1. 95 482.17 274772.09 2361825.79 4483.00 4.20 276.60 4422.76 46.07N 485.42W 1. 75 487.46 274766.86 2361826.63 4546.00 3.20 274.20 4485.62 46.46N 489.46W 1. 61 491.53 274762.82 2361827.10 4608.00 2.50 273.50 4547.55 46.67N 492.54W 1.13 494.61 274759.75 2361827.37 4669.00 1. 80 261. 20 4608.50 46. 61N 494.81W 1. 37 496.86 274757.47 2361827.34 4736.00 1. 90 260.50 4675.47 46.26N 496.95W 0.15 498.94 274755.33 2361827.04 4799.00 1.60 270.00 4738.44 46.09N 498.86W 0.66 500.81 274753.42 2361826.91 4862.00 1.30 273.80 4801.42 46.14N 500.45W 0.50 502.40 274751.83 2361826.98 4927.00 1.30 267.50 4866.40 46.15N 501.92W 0.22 503.87 274750.36 2361827.03 4988.00 1.40 272.10 4927.39 46.15N 503.36W 0.24 505.29 274748.92 2361827.05 5051.00 1.50 270.00 4990.37 46.18N 504.95W 0.18 506.88 274747.33 2361827.11 5114.00 1. 70 275.90 5053.34 46.28N 506. 7lW 0.41 508.63 274745.58 2361827.24 5143.00 1. 00 273.80 5082.33 46.34N 507.39W 2.42 509.31 274744.90 2361827.32 5300.00 1. 00 273.80 5239.31 46. 52N 510.12W 0.00 512.05 274742.17 2361827.55 All data in feet unless otherw~se stated. Calculation uses minimum curvature method. Coordinates from slot #KBU41-7X and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 512.24 on az~uth 275.21 degrees from wellhead. Vertical section is from wellhead on azimuth 276.77 degrees. Grid is alaska - Zone 4. Gr~d coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 4l-7,KBU4l-7X Kenai Gas Field,Kenai Peninsula, Alaska Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 5300.00 5239.31 46.52N 5l0.l2W Projection to TD Casing positions in string 'A' SURVEY LISTING Page 3 Your ref: MWD <0-5300> Last revised: 19-Mar-2002 Top MD Top TVD Bot MD Bot TVD ------------------------------ ------------------------------ Casing Rectangular Coords. Rectangular Coords. ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE 123.00 123.00 O.OOE 1512.00 1509.22 O.OOE 5300.00 5239.31 0.18N 47.155 46.52N 0.33E 13 3/8 Conductor 4.10E 7 Casing 510.12W 3 1/2 Liner Target name T.V.D. Targets associated with this wellpath Revised ------------------------------------- ------------------------------------- Geographic Location Rectangular Coordinates KBU 41-7X tgt-TE 12/ KBU 4l-7X tgt-TD 12/ 4700.00 5150.00 ----------------------------------------------------------------------------------------------------------- 494.l3W 26-Dec-2001 494.13W 26-Dec-200l 58.62N 58.62N Alaska ,hess Unit doa-oa 5 / /51.og Marathon Oil Company P.O. Box 196168 Anchorage. AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 5, 2003 Lisa Weepie Alaska Oil & Gas Conservation Conm1Ìssion 333 'vV. th Avenue, Suite 100 Anchorage, AK 9950 I Via Certified ~fail RE: KBU 41-7x Digital data for the above referenced well is enclosed, A description of the CD contents, including the digital survey, is listed below. CD Contains: . ¡ Neme I J ~IA[~ - rLD'_MCfL_C~l_05.7;.UP les ] : ~ComÞlneC_TCOr~ PDS : .L 1 Co",b",ec_TVD PDS , ~ICbL'_41.'r_dl'les : ~MII'" Log DSI_DIRJrICL_OÙ~.PDS , ::J S"nl,Ccmc'nec hr,el PDS SllS I Typs Z,I51 ~B LAS F,le 2, 952 ~B ç DS"le.. DctlJmer,t :::, SS6 K a PDSVle.. DútlJment f IJj lAS File 11 ICB PDSvle" Document 1,697 ~¡; PDS'/lew Dcturr,snt J Mcdlfllld )/512002 5:05 At,' J/6/200~ 7:S0 AM JI612ù02 B:15 Ar" 2/5/2(0) B'ù6 AM 3/5/2002 6'11 A~' J/6/2C102 6 10 AI1 Please sign and return confirming you have received this data. Thank you, rvIARA. THaN OIL CaMP AN'%'" ~~~ (?s~Þ,-- Kaynell Zeman Technical Assistant RECEIVED Endosures Certified R('ceipt: 700005100003 1110 1143 Received ~ FEB 0 5 2003 Als8fœ Off & Gt1ø Cons. CoIllfDi8l8on Andlfnge (ß G¥= Date: Environmentally aware for the long run. , ~ #Ii Marathon M~RATHON Oil Company t ~ Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 17, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 41-7X Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for Marathon well 4.1- lX. I have enclosed a Sundry and a diagram of our intentions to try and get the well to flow gas. We plan to use flow from a Beluga or Tyonek gas well to lift the water off of the Beluga formation. We do not know how long this will be required. After we have produced the water off of the formation, we would place the well into production at a sustained rate. We intend to measure the gas lift gas and deduct that volume from the total Beluga gas metered. Our intent is to try to extend the life of this Beluga well and increase the deliverable gas from the formation. We will follow this Sundry with an operational Sundry. If you need any additional information, I can be reached at 907-283-1308 or bye-mail at wecissell@marathonoil.com. Sincerely. '"'\ l/lç0VkL Wayne C~sell Engineering Technician R E .T'~ !'" ( \ t- ,- ['. l r ~ HI'" ,; ~. l . L &,{l~tf : Ù! I .~' "..J I,. - ~}! I) ,~: Alas!(3, OJ¡ S, Gas cons. '~'.' -,\~~rii%.':!r. ,ð,nc:r.cr ,:"¡Ilt , ' . -. 0 'E:,CEL AOGCCsun-l!':'\ 12003 >-:LS 1+ '{.~ \ /'II¿.fJ 2/J/o 3 £TJ:; (~'¿¡£/-iYC<~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface.J V J 179' FNL, 4353' FWL,Sec 7, T4N, R11W, SM At top of Productive Interval Suspend - Operation Shutdown Repair Well - Plugging - Pull Tubing - Variance 5. Type of Well: Development ~ Exploratory - Stratigraphic - Service At Effective Depth Proposal to use Tyonek gas to lift Beluga gas At Total Depth 226' FNL, 3844' FWL,Sec 7, T4N, R11W, SM 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor SunGlce Intermediate Production Liner Perforation Depth: Length 68 ppf 23 ppi 99 '¡51... 9.3 ppf 5292 4892'-4910',4913'-4922',4942'-4951', 4992'-5002',5012'-5026',5038'-5056' measured true vertical 4831'-4849',4852'-4861',4881'-4890', 4931'-4941', 4951'-4965', 4977'-4995' R ~ r'" f ,¡ ~ [ \""" ['.'~\ it". .1 .. \1 ~ ¡ ~~ ~, ~ . 't. L \.... n ~ \: L' ,i' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Re-enter Suspended Well - Time Extension Stimulate Perforate Other X 6. Datum Elevation (OF or KB) 14 feet 7. Unit or Property Name Kenai Beluga Unit 8 Well Number KBU 41-7x 9, Permit Num~7 202-025 10. API Number / 50- 133-20510-00 11, Field/Pool Kenai Gas Field, Beluga Pool 5300 feet Plugs (measured) 5239 feet 5228 feet Junk (measured) 5267 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" Driven 99' 99' ì"1 î 40 sks î5i4' 1511' 3-1/2" 700 sks 5292 5231' N/A Ij} 1'.1 ~) " 'Jorl"l ... .\,. r.. '.. L ,..J _~,q~;k~ OJ¡~:j; '::;::-1-:' L"1W;; '\.r!',rl:,';¡(...~~i'i Detailed Operations Program - BOR.t,5k~t£h::'I~ Description Summary of Proposal ~ Diagram of proposal X 14 Estimated Date for Commencing Operation 1/16/2003 16 If Proposal was Verbally Approved 13. AUachments 15 Status of Well Classification as: Oil Gas X Suspended - Name of Approver Date Approved Service 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed U k e ~~t{) Title Engineering Technician I - FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Approval No. Plug Integrity BOP Test Location Clearance .-:" ~- ~::' . ::. :;.-:: Mechanical Integrity Test Subseque~t Form Required 10- -~ \:) ~ ~ \ 't...... '" \u \ \.... "'é"-. ~ <;,.'\ ",\.c) ~ "> ~':"~ "->\\ \ ~ è) 0 ~~ w- ,a ~? ~-:.<:. Approved by Order of the Commission ~ ?-~ Commissioner Date O;L /03/03 Fe,rm 10..O3 Rev ('615,ee. Submit In Tnpllcate -. ~ f' M S B F l Date 9/16/2002 FEe LI ~'! !~J:, ,.Gas Lift Gas Flow Diagram For41-7X ..... I To low pressure production header / I Gas lift meter Qas I .. c GAS From Group Separator Or Gas Tied to a Tyonek gas Well \ì~\- S~S Lv---.öwV\. Return gas meter From Meter 41-7X ~ I I I '", ~\ ~~~ -'I- ~roDùC"\..'ô"-'" ... * * Gas Lift down tubing or annulus I We1141-7X . . -.J .J . ~~~ I ~ ~ "> \-", "\ (\' ,\u:, "-¡ <Ò.\') /' ~ \ / ð \ \ "', \\ \¡......~~ b~~0~U ~ t . ~ I Gas for zone I (' ras for zone ~IP. From-MARATHON. ,~~ )," ". +9155646489 T-894 P,D6/DT F-131 'f l " .. , --II¡ M MAUTHDI ~ ., .. l ,// i' /' / -,' ... .. 13-3/8" Drivepipe @xxx' / KBU 41-7x Pad 41-7 A . .. 7" Casing shoe @ 1514' cemented w/140sx .... . ..- --'. .. ~//" _.~~\~.. Þ;~':~~~. I ~ - - \ . I .J ( ~Q..)(.':. \1 .%" ~ 3\}~ \ \\~ ~'- ~~, \,~'" = \~ ~ ,;) .' " ~ ~ """"''''.'',.",--- -".-. ...,..-- .....,,,.,... .' rcv.6/02 Chemical Injection Mandrel @ 1460' "'r~\)~' - \Oe J. 5;',\' ~ c..~", W''C'Q. - .. -- ~ ......,.t..v.~ ,. I , . , ' .1' . 4. . . ~ i ~' , ' , , , . . . \ ' AC\.~.~ - ..~. -5\'f ~~.g~ - .'!p: 1nr~~:rp~r.~'UI , Upper Beluga: U7 Perforated (5/5/02) w/2-1/2" HSD, :J .,' 6 spf, 60 deg, 10.7 gm charges 49921-5002' 5012'-5026' -~ \'J~~~,"- (0 v,'''', j.. ..)'1 ":)'~"'::, o;~~ \' ~ '\) , (".:!-.... ,\ \ \c.. ~ ~~.rv( (,i....-> ~ ""'".,~( I.t ~!o . (\ ~ Q\ \)(. rp, \.... ... \.. ~ \ ~\\~'2..., ~~'r-;...ð.. ,,,,,,,". .-r .,..\ . \., SQ"o...è.. "'.... "'J , ... '- '.v \J"" ~ " . ""..:. \l...'~\L'f ~ .l'''\''4.,-.... ¿"...~....)..., .... ~~~: . . ... y.\. .. .:.;. ;~-."~:.~~~~'~I~'d'.~:-I":_. :':~:~:~.:~I."~~:+ IJ'I~" '~." ."':t~.t....I. ;".. I'" ", :,..::'.'. )';: ->".'" .', ~;';t.:: :'- ~';'11I,.:r'::;.:, Upper Bsluga: U8 ..~~ ~',:',:~,~;~:'J'!~- ~,.~-;, "~''''. '.:'-!~l "/: Perforated (5/5/02) w/2.1/211 HSD, . ~: (.;.;;.,' ~', , ...;;.: '.-.'. ~.:\: : ; ;::'.., '.;. r 60 d 0 7 ;-. .;.. .~~ -".: . ..' .-;.. .' :"', .,..:~ .I.-"'.:F ,,,,, 6 spf. eg. 1 . gm charges 5038'-5056' .. .. 3 1/2" 9.3ppf, EUE 8rd, cemented PSTD: 522S'MDI 'TVD TD: 5292'MDI 'TVD KBU 41-7x BOP Modification Subject: KBU 41-7x BOP Modification Date: Thu, 19 Sep 2002 14:26:17 -0800 From: "Eller, J Gary" <JGEller@MarathonOil.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Tank, W J (Will)" <WJTank@MarathonOil.com>, "Ratliff, Randy E." <RERatliff@MarathonOil.com> Tom - Please see attached a proposed modification to the BOP stack for KBU 41-7x as per our conversation this morning. We are adding a rotating head plus a tee and a 2", 5M valve on the choke line. This valve and tee on the choke line will be used while we trip in the hole. so that displaced fluids during tripping are sent down the flowline. Two other items: (1) we are building a couple of bleeder cocks to use while we trip in to keep the fluids contained in the workstring. I couldn't find a better solution available. (2) the rig is nippling up BOPs later today on KBU 41- 7x. We expect to test after midnight. Please call if you have questions. You can fax the approved sundry to 564-6489. «BOP.xls» J. Gary Eller Operations Engineer Alaska Region, Marathon Oil Company 907-564-6315 - .--------.-... --- -----------.------..-------.------------------__.___n- - ---- .-'''--.--'-, i Name: BOP.xls I : r~ BOP .xls i T~pe: Microsoft Excel Worksheet (applicationlvnd.ms-excel) : I LJ ) Encoding: base64 ! ~.._--------------~~sc_~iption: BOP.xls ---------- --- .-- ---- -------- - - - --- -------- ---j T..", o~~ ~ -\-0 \U'è. ,\ $l: ~ '"""'" ~ ~ ~ "Ct. ~ \" \ \-\ \-\~\--\.....o\-- ~~~~<'c-s. -\0 c2ð~ ~~\I\ O-~ Û 0Ö'\Ù'C~<b~ \-~Q-\~C~\C~ \';"'<è- \0 h \\ ~ 1 \ ~~ -\-0 -\\'CL\ r--\ \a~ \ \~. T~~~~~~~~~~~~s~~~~ ~ ~~ ~\.\-~,^,-c:Å--\-~ ~\CO~~ ~~, 1:"" ö~ Cc ~.\.o '<è CO ---:J(è \ -\- \-Q '\ I ~.., ~ hø-~~~t-- ''l~ ,'-{ ~C£@ So Yo \(£I,JQ~ c,,~ '-l~ t-Qk-i.-'\:<r-- ~ ~~ ~ '-< ~ ~ Cjt--0&:: \\-.e~ C... ~0.- $ \ \. ~ -lo S <L 4 \. ú... + ~""=~ (Ç, '- ~<:9-~ cJ~~ ~ '.:) Q P'\PQ ~ T N:c~o ~K.€' ~ G\>~ro0lL Q ~ ,c:--\-- ~ '\ -ç- Iì \ CU'--- (/" -'1 ' r /':)~(' ) r./1 / " -\7"7 /;/ q /- . - ,;.,,.....-- I J L I, ~ - 0 > /' - 9/19/20022:45 PM 1 of 1 Sep-1S-02 Oa:51pm From-MARATHO~' 't +9155646489 ~ T-894 P,OI!07 F-lal Arab...... Region Domestic Production ~~ Marathon .MARATH~N Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER. LETTER .... - ~~T~: - ~\-\\~\ C\~ - - " Name: , Compa~y~- Fax No.: PLEASE DELIVER THE FOLLOWING TO: --.- . -. .- - u_- - T~ '\No... ""O\.'V-~~\.\t"" ~"- G _C~ -.. ~ ... .. __"__n__- - . -- - ~!Jmber of Page~ (including cover f?!J9Ø): ~ FROM: Name: Location/Extension: Fax No.: -- C'" ~"""'1 t. \ \11 -- ---- 5~~... ~~\S 907/564-6489 .. n -- -- .- -. ---- --..u I -. ,--.- ---- -, . -,--- _. . . . - ... -. -. . . -. - NOTE: . \_~~- ~o\-'L ~. <{~~~c.~ "",àc \..~~ ¡. - u~ \ '- ò"" . '\ ~ ""...-- ~..--.._,~ ~~~ ~~~ \s "'~ ,""" S' ' , ...\:., 'ð. . . - -- - ____n W" . ... -- --- -- . - . -- -- --- . .... " transmission is not complete, please call 907/561-5311. Environmentally aware for the long run. Sep~16MOZ 03:51pm Frcm-MARATHO. t +9155646489 T-894 P.OZlO7 F-131 ~ . q{\~ ~ ~~ ' /d- e STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon Suspend - Operation Shutdown After Casing Repair Well- Plugging - Change Approved Program Pull Tubing -:- Variance 5~ Type of Well: Development X E;xploratory - Stratigraphic - Service - 2, Name of Operator MARATHON OIL COMPANY 3. AddrØ$s P. O.l!ox 196168, Anchorage, f.K 99519-6168 4:- Location of Well at Surface - 179' FNL, 4353' PWL,Sec 7, T4N, R11W, SM At top of Productive Interval At Effective Depth At Total Depth 226' FNL, 3844' FWL,Sec 7, T4N, R11W, 8M 12, Present"Well Condition Summ~ry "" - Total Depth: measured true verticøl Effective Depth: measured ttue vertical Casing Structural Conductor Surface Intermediate Production Uner Perloration Depth: Length 68 ppf 23 ppf 99 1514 9.3 ppf 5292 4892'-4910',4913'.4922', 4Q42'-4951', 4992'.5002', 5012'-5026', 5038'.5056' RECEIVED measured true "ertical 4831'-4849'.4852'-4861',4881'-4890',4931'4941', 4951'-4965', 4977'-4995' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 5300 feet Plugs (measured) 5239 feet 5228 feet JunK (measured) 5267 feet Size Cemented Measured Oepth 13-3/8" Driven 99' 7" 140 sks 1614' 3-1/2" 700 sks 5292 Workover to Recõver. Fish NJA 13. Attachments Description Summary of Proposal.2L 15, Status of Well Classification as: Detailed Operations Program - BOP Sketch X Name of ApproveI' Date Approved Serviœ .'7, I hereby ~fy lI1a! 111. ':!ng IS bu. and ccrrect to the best of my. knowledge. . ..".- . Si~_neCl ~~~~~-- Gtn..~~ ~\t". TI.~~...- Production En9Inee~" \ FOR COMMISSION USE ONLY 'ConClitiõñs of Approval: 'fy Commission so represe"ri"tative may witness - --- "-- IAPProval No,~ _. ',~ ~ Q~- Plug Integrity BOP iest Location Clearance ~ ...:JO, - ~,tp - . MeChanlcallnië9Mty Test SUDSequent Form Required 1Q. ~a'1 ~~" ù " - 0ngmal ~IWIIQ"'..o ~Ç-c~<i~~~t'---~ Cammy Oechsll Taylû /) Gû 11'1 Comf!1Jssioner Date vI (7\ UM. Sub". It In T-iplicate 14 Estimated Date for Commenciñg. OPeration 9/19/2002 c1e. If PrOposal was Verbally Approved Approved by Otder of the Commission r:orm '00403 Rev, 06116t8S Oil Gas X f....-' f~"\ r -', g ". ~ J P r . ': " ' 1 ,\ ¡ , f r ~ I' , ,- " \...,:' , ... ~ l . L ~ i: ..~ ,~" -I \.:, ~L- Re-enter SU$pended Well- Time Extension - Stimulate - Perforate Other X - - 6. Datum Elevation (DF or KS) - 14 feet 7. -Unit or Propetty Name ~enai Beluga Unit 8. Well Number KBU41-7x V . a. Peimit Number 202-025 J 10. AP-I Number -- 50- 133-~O~1O"()O ,/ 11. FieldIPool ". Kenai Gas Field~ Beluga POOL Tl'ue Vertical Depth 99' 1ô11' 5231' SEP 1 6 200Z AlaskaOit & Ga& Cons, Commission A~~ Suspended - Date 9/1_~OO2 Sep~16-02 03:51pm +9155646489 T-894 P.03/07 F-131 UMI:I NO. 1004.0135 , (August 1 gee) F r om-MARA THO~' ~ - ... . -.. DEPARTMEN r OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for propo$als to drill or to re..enter an . abandof)éd well. Use Form 3160-3 fAPD) '0,. suCh DroDosals. - ¡\~~.:~ :.~. :'~'j~,~ ::"I;~"','~ ~B~ïr.;/fl1!r~~4~~ r~::r. O~hf,(in~tf~~t!on~ l O~ .f~v.e~~ ~l,!~';;~'::~ ~~~:.~~ -" "I~~". Î~~ : n.'r.r: J,J:«\ .~¡\. ,~!, ..À. ':. 't, ¡II!: ~ ,I, ~ ';:'I~y:.. ~¡ I I,~\.".. ;,..' . '!~~.ot~ ,~¡ ~,j'J ,', . I ."'.J. I ','., '..~;, E ~ 1. Type of Well -- .-- 0 Oil Well 0 Gas Well 0 Other 2. Name of Operator _.n Marathon 011 ~mpany 3a. Address 13b: -Telephone No. (include area COCle) PO Box 196168 Anchofage AK 99519 (~7) 561.5311 . 4. Location of ,,"lell (Footage. Sec" T.. R., M., or Suvey OesCriPtion) - õp:r~; Nov8moer 30, 2000 -- 5. Lease Serial No. A-028142 6. If Indian, Ãllottee or Tribe Nãme NA 7. If Unit Or CN Agreemen~ Name and/or No. 179' FNL. 4353' FWI..Sec7, T4N. R11W, SM Kenai Unit- 8. Well Name and No. KBU 41-7x 9. API Well No. 50-,33.20510.QO -. 10. Field and Pool. or Exploratory Area Kenai Gas Field. Beluga Pool 11. County or Parish. Statë- Kenai Penninsula Borough -- .- -. 12. CHECK APPROPRIATE BOX(ES) TO INDICAfe NATURE OF NOTJCE~ REPORT, OR OTHER DATA .. - -. .- TYPE OF SUBMISSION TYPE OF ACTION 0 Subsequent Report 0 Acidize 0 Alter CaSing 0 Casing Repair 0 Change Plans 0 Convert to Injection 0 Deepen 0 Fracture Treat 0 New Construction 0 Plug and Abandon 0 Plug Back 0 Production (start/Resume) D Redamation 0 Recomplete 0 Temporarily Abandon D Water Disposal 0 Water Shut-off D Well Integrity [2] Other 0 Notice of Intent fishing operation 0 Final Abandonment Notice - . 13. Describe Proposed or Completed Opel'ations (clear1y state all pe,1inent details. including estimated starting date of any proposed worK and approximate duration thereof. If the proposal Is to deepen directionalJý or recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones. AttaCh the Bond under which the work will be performed or prOvide the Bond No. on file with eLM/alA. Required subsequent reports shall be filed within 30 daY5 following completion of the involved operations. If the operation resultS in a multiple completion or recompletion In a new interval, a Form 3160-4 shall be filed once tsstlng has been completed. Final AÞandonment Notices shall be filed only after all requirements, Including reclamation. have been eompleted. and the operator has determined that the sJte Is ready for final inspection.) This sundry is to notify the BlM of marathon's intent to mobilize a rig onto well KBU 41.7x in the Kenai Gas Field to fish out stuck wireline tools. The well was drilled to TD on 3/5/2002. but has not yet produced to sales. Included in the packet is a summary of the proposed operations and a BOP schematic. Marathon recommends a BOP test pressure of 250/3000 psi, which is consistent with the test pressures up when the well was drilled. Marathon would lil<e to mobilize onto this well as soon as 9/19/2002. .. 14. I hereby certify that the foregoing is true and correct Name (PrintedITyped) - ~ary f \~ - TiUe - Operations Engineer -- ,.-.. Signature ~ \..- ..Date 9/16/2002 , r~:,.~~: i¿:~~'~1/~-;~rt ~&;:'J~¡' ~,; .;'tl'AiíSV~P~ÇEi9-~Ò~~Þ~~~r~r.E~F.~I~~:u~~t<)~7~~i;'~~:~\)'$r.~¡~~:] .~ep!~~~~- ~}'-- -- -- - --.... ~.. n~-.-.~ ~ ......... n...n~ -"~~--- - - -- --- - -- -- Title - .. : 'Date - - COnchl,OI'I:! af 3PFI'O~. if ':InY. ::Ire .:Ilt.:IchccI. A!)prOIrQI Of rnl& notice doEI8 not W3rn1n! or Cat1lfy !h.1! !he ~ppli~"1 "OId~ ICQ.:II or CClIoII\able ",Ie 10 IDose r1!1nlS In 1118 SUbject 1t:s&!Ie WT1icn would entllle Ihe Office BOOIICSn\ to condUCt ooeI'8lJOI'\S 1I11!:reDl1. Tille' e u S.C. 5eCU0I1 1001 ana T,ue 43 U.S.C. Sc!c:uon 1212. ~ II ¡ çnmc,or GIn)' por:.on AAOWInolý and Io\oillfully 10 maka 10 II"Y at7~rtme=rl1 or ~gency of mc UOJIcø States 8ný f8l&8. fi~~O"':S or froNd,I~1 5~'cmcrIlS or roorar.entall0n5 8& 10 8th' mailei' wI1nin itS luri!>C!ld.cn. -- O:\EXCEL\FoRMSlBLMSuNOJu.S ~ SBP~16-0Z OS~5tpm From-MARATHO~ ~IL , +9155646489 T-894 p.04/0r F-131 Well kBU 41-7x Kenai Gas Field Workover to Fish Braided Line Tools September 16, 2002 SUrnIl'!arv - Marathon proposes to mobilize the Glacier Rig #1 onto well KBU 41-7x in order to :fish a braided line tool string that is stuck in the wellbore. The braided line tool string became stuck in the Course of swabbing operations. Marathon intends to fully recover the fish and produce the existing perforation to sales. The rig could be mobili2ed onto well KBU 41..7x as early as Septembt..1' 19,2002. Marathon recommends a BOP test pressure of 250/3000 psi, which is consistent with the test pressure used during drilling operations. Marathon will submit the requ ired completion notices once the well is sllccessfully placed on production. Attachments: . Wellbore schematic . BOP schematic . Sketch of lost tool string ~~~~ S8P~16-02 03; 51 pm F rom-MARATHO' ,1 r +9155646489 Marathon Oil Well KBU 41.7X BOP Stack rFI?W Nipple I ~ .. 7-1/16" 5M Annular Preventer .... '>- I - > ... 7-1/16" 5M Double Ram Preventer ....... -.. .... 2 1/8" 5M Mañùally Operated Valves ""- ) ~~ :." rXIIXl]'~!II.i ~:/ 17~1/16" 5M Cross I - > 7.1/16" 5M- Single Ram Preventer .. --- )-- I I """'- \ L~ I ~ 'Vj~~~\~ ïFlow lin~ '.-' --( J ,r) Ji IChOke(J0[]: X 1 t 3 1/8" 5M Måñ-ually Operated Valve / I J "" (,- IPipe_~am I IBlin~ Ram I - - ...... - I .-( J ~.ipe Ram I < J I -- ( T-894 p.05/0r F-131 ........,. --I -1 3 1/8" 5M Hydrau-'Ically Operated Valve J Sap-J6-02 03:51pm From-MARATHON OIL ) +9155646489 T-894 P.D6/0T F-131 " .-' .." M MARAlltO. . ~ .. .. 13-3/8" Drivepipe @ xxx' KBU 41-7x Pad 41-7 A 81 .. 7" Casing shoe @ 1514' cemented w/140sx ... - 1-- .. ...- --. ... ._11 .'..-..-.. I/'.~~ \\~\Q.., ~-.':o.\I. ,/ -''''-._" -,)-- . ( ~o.><.~ \1 .%- Ii! 3~~ \~..... t" (;.1... \,~'" = \, 5 ..~ ~ . ........'............---- _.n_.. ......-. .......,...- .' rev, 6/02 Chemical Injection Mandrel @ 1460' 4r"è~'o' - \O~ J.. ~.\" ~ c.-.,.-\ w'~Q. .- -- n .- ~ ,""v' to,..... '" .. I . ~\\~ - T~ ~~ -¿~~ G---QQ.""..\ \0\') I' . \-~<.:i - \õf J,¡ i...2.. c.~- \.:)~~\\ \'i) . . \ . Upper Beluga: US 4812'4850' (lVD gross) C\''l..4' - \õ-e Jr ¥...;.....\..., SV--Q tr.$ \;;.;~¡. ~;~i"!~~!f.: ;. .:~~~.. \;I~r,~ ,l7H:1 Perforated (08/16/02) w/2-1/2" HSD, Aa. "-r- ,.,' (" - "" ~ :r.~~~ ~~~~ ~;,&:-, "'"'. \ ~:. ~'~I¡~ 6 spf, 60 deg, 10.7 gm charges ""'"~ '2...\0 - 'O~ Q"f' '" '-"" (1,,,,- "'v -. .(~tf"~ (\!,.'f~~~..;~t~~ j' .' 'tJ.~ 48921-4910' AOß-¿'- \0 ~ ~ -" _." , fftif.~1~~~t~~I~'~~1?'~:~ ~~~ !:lti~ 4913'-4922' r . ~ ~ 1.\.. -.. - _n Otis x~rp~e @~9:3'j, '" ; ()"".r"":;:;,,,,"J~ , "'\. . IÐ . ,., .~. \. \~ lOt. \ II s" <:::> C) t t^.Go... ~~": z..""r~) ~~~~-i~~i~" '" .~' '~~~. ,-' ,~~;r Upper Beluga: U6 4850'-4898' (TVD gross) . "'-., ~~~ll~~q~,,; j "',~t~~.~\'.: :~~\,. '~f.~ Perforated (08/16/02) w/2-1/2" HSD, 4'=\t\,'è - \X ~\.~ ...~...~ ,'. ~~~~~",~~~~".,"¡~':~f-ì\8~6$Pf.60deg,10,7gmCharges :>J!. ,..:.rJ -' . ..A..;..-. ~ .,. ..~ 4942'-4951' ( "11 . . ~ i ~' .~oj!.t1'¡}I:'ñ~z¡¡:æ.ø ~~'fl L -- . , Upper Beluga: U7 I Perforated (5/5/02) wI 2-1/2" HSP. , ,6 spf, 60 deg, 10.7 gm charges 4992'-5002' 5012'~5026' -~ \)~~~~ (0 'Ç,..,..'. ,). ..\ '-:¡.~,;::, o;~-'"' \' : '\) , (~) ~~.,~\r 1I~<'.Ct.... \à~(.\.. ..~ ~'t.l\..\, , ,,' '\ \.. ~ \ ,\\l"'oz..'\ ~~'~....ð-- .,..""~C'. ,"- .,.. . \,. So-""~ "'.... "'J'r-'-. ,,_v 'oJ" ~ ~ . ""<oj ~'~II.'f f l'o'Ì:'",-"" ~\"""-'''')..''f ';¡\'.""Y.~~ .:~. -:,,,"",:,~~'.~~~. =~J'.~:':.:, .::::"'~:"~~"::.':~ \~:. .~. ".:i;'"o.. ;~.: .~ :,.,.:,:". )'; "1_>"",, .', ';';1.:.,. ~';:'11. ,.;.;:' Upper Beluga: U8 ,.~~ ~"I:"~:<~; ~!,.;,.!~- ~'.~-" ",~,,:. .': -!.~i ",.' Perforated (5/5/02) w/2-1/2" HSD. I /I\,::..I'''~''':'II~''"\';'.''.''.~~.,~:I'~;::.:~''~.~: 0 07 .~';"'~~-"". ".~.," :~ ""':'..,.-",;:1:',,, 6spf, 6 deg,' , gmcharges 5038'.5056' A .. 3 1/2" 9.3ppf. EUE 8rd, cer'n~nte:d paro: 5228'MDI 'TVD TD: 5292'MDI 'TVD Sep-l,6-02 03:51pm From-MARATHON "III ; *~ ~lì~\Jeð. fjN~' ; ~'';'')''', \ \ \ , ,! ¡ . I; I~ I,r .~ ¡~ t~ 0 ~ -~~;) I, t"~' ~~ \ P,' ..:cr ~.~}.1 ~~ .,;i \ I J f ,,1)'" ¡.IS ': ? ~ y '~~~:I( ~ [. ~ ~\...z.\A.~. , ' ; T¿-S "" I ... 1 , \ 1 I rs' ~ ) J. 7f( ¥t.~(.- 'I' ,~ . 1 C-J :~ y~1 r ,.,.. -" ~: I.;. _~,r I' <,: '.__, 1! s~~:~....':.~~ D ~;) :1 ~~ 1\ ::1- J1 - I~""'" ' ~I I "~I " .i - .¡ ~\o.:~-d~ '? \ .". i I f; ~~-~~~:;~~ . \ .-- / la" \" kll C'\ "I \ '~,1U 'ItC¡54 ".,...(.J.,. ,.....1 ,\'\L.r."\ . ~,lr1 L/ '\ r / ...~ .~.. A ~ ,- < 11..,... ~ '- /~ , - ';L1.1~ ':. '- Ire., 1. ~ \ +9155646489 L t ) T-894 p.or/or F-131 / - 'U -..... f? -.., i t 1 , ) . j : l Qd. I ,l¿ (.£.1/ 'j / . ~ 3~(J"( X 1'8' /Y; P, ¡u . (:!.~ - ~c. ',' \ , I , i ; 1 ~ ) ~~ g"'?~ I'. fJ "r ;;! ,t"<.r;). oS>. I~f I ~V F.l". \;11;)- ~C(....\\ .,,) ..IY'I"""''' ç" r: \ , t, tï' ¡ n" a.. }t û- 0». ~1 F. /J. '(-",,,,\o,\ S -.~ ~~"./ S1"";) , ~,,~'\ ~ ~' x. \ ~ O't l "'1¡ !~r ~ N . ! '; c v." ~ H" ~\I','" , ; , I' i ",' ¿ ~ ~ ~r t ' hI ) \'4,~ il ~ It I f' ,..--- ,. I I to ..!!.¡u \ ~ ,.. J ~ .....~~ 1 t..; i,)" r.....'I:J'J i:....' ,. .r....,- '~:" H Clt....{\é.~1.... ~~~" V.:ï',', f' ~f\;. '1.',)01' \)"~P r t ~. I ( o. ~ ) (0 'I ø ø ~ 51;J .& Ml\f : )I\\.f. ~)v'L-,- _~I.('L0_- \\"¡~ ( "I J,;' 1, t." ( J ( I V,,f: \. 'JOÞ I,t t Þ Ç') lj '0 c;') ;; ) 20 'd 9LI9 £92 LOe 'ON X~j ANijdWOa 110 NOHlijMijW Wij SÞ:80 flHl GOOZ-B2-Ðnij 7-1/16", 3M Rotating Head, 1000 psi WP 7-1/16" 5M Annular I Preventer 7-1/16" 5M Double Ram Preventer c .. C . "> I ) I Pipe Ram I I Blind Ram I 2 1/8" 5M Manually Operated Valves ) ~~ I~- []Iß]J[lliJ]llJ Œ[] 7-1/16"5MCross I ~I~ C 7-1116" 5M Single Ram Preventer ..... I ( I Pipe Ram I t ) I I "\ < I -- , í Marathon Oil Well KBU 41.7X BOP Stack ~ I ( ,J .I ./ _. , > ,'- [' ----------- \ I to flowline I t ~ ~ l I ( \ '\ / / ( ----- ( , -, /' 21/16" 5M Manually Operated Choke I '" -.. I to choke manifold I \ I 3 1/8" 5M Manually Operated Valve 31/8" 5M Hydraulically ~ Operated rive '''---. - - ~ - - ------ - - --on ( ---- ~-- ~"~&~E ~. ,...,-~ .....~~- ~'~ ð ð ð ~ J 11., ...::J JL J\., OFFICE OF THE GOVERNOR TONY KNOWLES, GOVERNOR OFRCEOFMANAGEMENTANDBUDGET DIVISION OF GOVERNMENTAL COORDINATION a SOUTHCENTRAL REGIONAL OFFICE 550 W 7TH AVENUE. SUITE 1660 ANCHORAGE. ALASKA 99501 PH: (907) 269-7470/FAX: (907) 269-3981 a CENTRAL OFFICE P.O. BOX 110030 JUNEAU. ALASKA 99811-0030 PH: (907) 465-35621FAX: (907) 465-3075 iIJ PIPELINE COORDINATOR'S OFFICE 411 WEST 4TH AVENUE, SUITE 2C ANCHORAGE. ALASKA 99501-2343 PH: (907) 271-4317/FAX: (907) 272.3829 February 13, 2002 Charles A. Undenvood, Jr. Marathon Oil Company P.O. Box 196168 Anl:Ílorage, Alaska 995 i 9 SUBJECT: REVIE\V NOT REQUIRED KBU-41-7X and KTU 32-7H L..~Od-OJS- ~ Dear Mr. Undenvood: " ;> Dê)-a \-\ ~ The Division of Governmental Coordination (DGC) revie\ved the Coastal Project Questionnaire (CPQ) and other information regarding the above referenced project. Based upon the information you provided, your proposed project does not require a state revie\v for consistency with the Alaska Coastal Management Program (ACMP). You are IIOt relieved from obtailling required peFlnits and approvals froln state, federal or local agellcies, before )'OU begin the proposed work. Nothing in this letter excuses YOII fron, cOlnpliallce witll otller statutes, ordinallces, or regulations tllat IlIay affect any proposed work. This decision is ONLY for the proposed project as described. If there are any changes to the proposed project, including its intended use, prior to or during its siting, construction, or operation, contact this office immediately to determine if further revie\v and approval of the "Q~rl'C'"ed P~~ie,...t :C'" nQ,"'O':'o;:.~r"I' I~t '" 1.VJ ~ I'" "'~~~J...a.1J' Thank you for your cooperation \v1th the ACMP. Sirn:erely,- ':~~:~ï:YI¥~tÍJ~~.7~ ~\ . i " Kaye Laughlin Project Revie\v Coordinator RECEIVED Cc: Daniel Bevington. Kenai Peninsula Borough Matt Rader. ADNR (DO&G) Mark Fink. ADF&G Tom Maunder. AOGA Bob Blankenberg, ADEC APR l' 5 :(/:)O'~ Al8klOU&Ga&ConI.CûlI8Rør, AncboJage 01-A35LH 0 pnrnea on recvclea paper ~~]~E:F !Æi~!Æ~~~!Æ / ¡ ;' AlASKA OIL AND GAS I CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. T" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steven S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519 Re: Kenai Unit 41- 7X Marathon Oil Company Permit No: 202-025 Sur Loc: 179' FNL, 4353, FWL, Sec. 7, T4N, Rll W, SM Btmhole Loc. 179' FNL, 3853, Sec.7, T4N, Rll W, SM Dear Mr. Lambe: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting detenninations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kenai Unit 41- 7X. Blowout prevention equipment (BOPE) must be tested in accordance \vith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to \vitness 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. Sincerely, r.. . .~, I ,. ~ r Ut 'rvvl'ŸlA.~~\ ll:c:..ct'L' ~LL .JtLL.1L.:r" Cammy dechsli Taylor i Chair BY ORDER OF THE COMMISSION DATED this 21st day of February, 2002 jjc/Enc losures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environn1ental Conservation wlo encl. Alêt Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 4, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Attached is the Permit to Drill for Well Number KBU 41-7X, the accompanying Drilling Program summary, schematics and procedure. If you would like any other information, please contact me at 564-6332 or sslambe@marathonoil.com. Sincerely, ,'" I .. . ./ .' ¿ C _._-.......::..--........~~._.. ,. Steven S. Lambe Senior Drilling Engineer Enclosure bjv RECEIVED JAN 07 ?tv\') Alaska Oil & Gas t~lIlì~ ~'''1''1I1ISSIOr, Anchorage 0 r1 1 G " ~ » rt K ¡ ¡ !\,j /-\ t.. Environmentally aware for the long run. " STATE OF ALASKA i 9 ,:rr.r'Qrl'~~~4A'1Ü ~rllí7f/~ Atn0KA OIL AND GAS CONSERVATION COIVIIv1ISSION k ~/ ¡)O ..~~ PERMIT TO DRILL 210 AAC 25.005 1a Type of Work Drill[8] Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 179'FNL, 4353'FWL, Sec. 7, T4N, R11W, S.M. Re-DnIlD DeepenD 1b Type of well Exploratou Stratigraphic TesD serv'CE:D Development Ga{I] Single lonG 5. Datum Elevation (DF or KB., 10. Field and Pool 81' KB feet Kenai Gas Field/U.Beluga Development OlD Multiple Zone0 6. Property Designation A-028142 7. Unit or Property Name Kenai Unit U5 & U6 At top of Productive Interval 179'FNL. /aæ'FWL, Sec. 7, T4N, R11W, S.M. 1~53 At Total Deptlí I' ~.; )'1 1ì9'FNL. ~FWL. Sec, 7, T4N. R11W, S.M. 8. Well Number KBU 41-7X 9, Approximate Spud Date 3/4/02 11. Type Bond Blanket Surety Number 5194234 ISe--? 20 ~Þ.C 250251 12. Distance to Nearest Property Line 9950 feet 16, To be Completed for Deviated Well Kickoff Depth 2200 feet Maximum Hole Angle 18. Casing Program Size 13. Distance to Nearest Well 14, Number of Acres in Property Amount $200,000 15, Proposed Depth IMO and T ,'01 500 feet 6000 17. Anticipated Pressure 12':;':; 20 AAC 250:;51':;11211 5208' MD/5150' TVD feet ,.¿: /' ' / 481 2' 17,6" Ma. ,murro Surtac.:; 1891 pSlg at Tolal O.:;pth IT','O, Hole Casing Weight Driven 133/8" 61 8-1/2" 7" 23 6-1/8" 3-1/2" 9.3 Specilica tions Grade Coupling K-55 BTC L-80 BTC L-80 BTC Top Setting Depth Bottom Length 120 1500 5208 MD 0' 0' 0' TVD 0' 0' 0' MD 120 1500 5208 TVD 120 1498 5150 Quantity 01 Cement (including stage data) 142 sx 456 sx R[CFIVFf) JAN 07 20D? Kenai Unit well KBU 41-7X will be directionally drilled to an estimated total depth of 52~~~~~§asr'JmSfrgMlthiesjor. existing Kenai Gas Field pad 41-7. The production interval will be completed with a 3.5" casing ce~~R~~m place and run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. ' ~ 'i' \ ~ ' I~.. ~ i ~. .-. L 20. Attachments Filing Fee[8J Property Pla[8] BOP Sketch[IJ Drilling Fluid Prograrr-0 Time vs Depth PloD Refraction AnalYSi{] 21, I hereby certify thatt~eZf regOin~ i~ :~~ correct to the best of my knowledge ,L.. .....-'" .-. Signed S. S. Lambe Title Senior Drilling Engineer Diverter Sketc{:8] Seabed ReporD Drilling prograrn[8J 20 AAC 25,050 RequirementO Date 1/4/2002 Commission Use Only Permit Number . -- API Numbe~ . - Approval Date I \ See Cover Letter 2-C' Z. - CJ 2.5 50-- 133- 2.Þ SI() .DD ~ \ \ a ~~n For Other Requirements Conditions of Approval Samples Requi red DYes [Z] No Mud Log Requi red DYes ~ No Hydrogen Sulfide Measures DYes [K]No Directional Survey Required ŒJYes DNo Required Working Pressure f~ BOPE D2M ÇJ3rvl D5M D 10M D 15M Other: Te s t ß fJ P t: ~ 5 (ì()O f J i. \.J £/t¡ Mf1YI Original Signed B\' Cammy Oechsli Approved by Commissioner by order of the Commission Date " ~ ¡/O?- ~Lbmit irl Triplicate f:,:,rm 1(,.Joj1 R-=, ,:,,'.e.s Marathon oil Compa~-.z' Alaska Region Drilling Program ~"e 11: KBU .J 1- ì X Area: Kenai Gas Field t='repared B:,.': .:;ppro'.'.::-d B~': Date: s. S - Lam1::',e 1-(1.:1-02 .;FE: 920830: Drilling Contractor: Inlet Drilling Company Geologic Program Target Locations FNL Fv-lL Surface 179' 4353' Sterling 16' 332' North West Uppel." Beluga 0' 500' South West Target Entr:,.' 0' 500' South West Bottom Hole 0' 500' Sout.h West. RKB Ele',"a t ion: 21' Total Depth: TVD 5150' Abnormal Pressures: Rig: Glacier Drilling Rig No.1 Depth Block Sec. 7, T4N, R11W Coordinates from vJellhead T1.,'D 2 1 ' R l<:B Tolerance [.m 2 1 ' Rr:S 3618' 3577' Coordinates from I¡Jellhead 4709' 4651' Coordinates from Wellhead 4700' 150' Radius .:1758' Coordinat.es from wellhead 5208' 5150' l.lD 5208' .:'.~..g. .'illgle 0 Course (I Subnormal Pressures: Possible depletion in Sterling, and Upper Beluga Coring and DST's: I'Tone I.Iud Logg i ng : Ser',"ice3 : Epoch Start Depth: Below Surface Basic with GC.;, shale densit~., temperature in and out, sample collection. Monitor gas below surface. 10' samples below intermediate Contractor: Logging Program: Contractor To be determined Surface Inter. LV.JD 1,1.::'. [L~. IT.:'" production FBU ~1-7X Drilling Program v.Jireline Logs GF. PE:': lIGT DSI P3.ge 1 () f 8 Drilling Program Summary Dri'.'e Pipe: Dri':~ 13-3 8" to refu.;al. Slif.' on and Secure 13-3 8" ada¡;:,ter flõnge. rnJ 13-3 '8" x ::::1-1 .1" :21-1 DS.;. I.IIEU Glacier Drilling Rig rIa. 1. InJ and test 21 l~" 2[.] di".'erter ./' SJ's tern. Surface: Dr illS - 1 .2" ho 1 e to +.. - 1500' T':D per cement 7" casing. WOC. Cutoff 7" and wellhead. ['IU 11" sr.] x 13 5 8>51-1 DSÞ.. bushing. Test casing to 1500 psi. the attached directional program. Run and 13-3.. 3" casing. Weld on 7" SCiIJlJ :\ 11" sr.] HU BOPE and te3t to 250 ~ psi. Set wear -; 0 0 c \¡JcA- Production: Drill out float equipment and make 20'- 25' of new hole. CEU. Test shoe to leak off (15.6 PPG anticipated). Drill 6-1 8" hole to 5208' HD.. 5150' T?D as per the attached directional program. Lost circulation is possible through this entire inter?al. Make a wiper trip. Pull wear bushing. Run and cement 3-1,'2" casing per the attached program. WOC. IJD BOPE. Set slips and pack off. Test pack off to 2500 psi. ND EOPE and NU tree. Test tree to 5000 ps i. :RDHO drilling rig. Casing Program API \..'alues Casing Casing Hole Size Set Set To vJeight Casing Conn Size Burst Collapse Tension (in) From (ED) (ppf) Grade T:,rpe (in) (psi) (psi) IK Ibs) (1-1D) 13 3..3" 0' 120' 61 E-S5 Dr i ',ren 3090 1540 1169 7" 0' 150(1' 2 3 ,,- ,:,&V L-80 BTC S ~ ~" 6340 3830 588 3 ~ z" 0' 5208' 9.3 L-SO 3rd EUE 6 l.¡," 10160 10540 207.2 Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Fac tors Size Weight Casing Depth at Shoe at Shoe [-L;:'.SP (in) (ppf) Grade (TVD) (ppg) (ppg) Ipsi) Burst Collap.;e Tension 13 3 8" 61 1<':-55 120' IT .. 7" 23 L-30 150(1' 15.6 9.0 1122 4.5 .J..J 2.9 / 3 1 ~" 9.3 L-30 5150' 13.2 9.0 1813 2.9 3.3 3.9=. ~BU Jl-~~ Drilling Program Page :::: c,t: 8 Directional Program Directional Co: Baker Hughes Inteq GJ'ro Co: To be determined EO P : ~:¿oo Direction: 265 Build Eate: ~.o Drop Depth: 3587' r.ll.. 35.,17' TTD Drop Rate: 1.5 To: lï. 6 deg @ 3062' T".T' To: 0 deg @ 4ìÜO' T'.:'D Gyro Sur'.'e:,' Required: none Hagnetic Hultishots Eequired: Use r.1WD sUr\'eys be 1m",' dri':e pipe General Calculation of Maximum Anticipated Surface Pressures The Haximum Anticipated Surface Pressure (~~.SP) for the surface and intermediate casing is based on the fracture pressure at the shoe, including a safety factor, less the hydrostatic pressure of gas. The }~.SP for the production casing is based on pore pressure less the hydrostatic pressure of gas. Surface Casing @ 1500' TVD I.E~SP = (FG + SF) * 0.052 .. T~.'Ds - (GG * T'JDs) HÞ.S P = (1 5 . 6 + 1. 0 ) .. O. 0 5 2 " 1 5 0 0' - (Ü. 11 5 " 1 5 0 0 ' ) I.E~SP = 1122 psi Production @ 5150' TVD lL~SP = PP .. 0.052 " TVDf - (GG * TVDf) lU\S P = 9. Ú .. û. Ú 5:¿ * 515 (I' - (0. 115 " '315 ú ' ) ['L~SP = 1818 psi / nt L, &) F' ,'1 f ) ,"l n";',- .:: l PC¡, ,} s. ( (~' ,. (L' ,hi GÆ . . ~ "'-' (' / "'II " . , ..' ~,' i fEU 41-7X Drilling Program Page 3 of S Cementing Program Surface Casing S i z e: 7" Tail Slurry: Top of Cement: Specifications: Compress Strgth: Total '--TO 1 ume: Production Casing Size: 3-1 2" Lead Slurr:/: Top of Cement: Specifications Compress Strgth Tail Slurr~': Top of Cement: Specifications: CompJ::ess Scrgth: Total 'lolume: fEU ~1-7X Drilling Program Cc,ncractc,r: E'J Ser'.' ices Setting Depth: 1500' HD' 1.J98' T'lD tillnular ',..'e,hlme to O. wi th 3-1:;::" gauge hole: 207 ft3 /" / Densit~,: 1:2.0 ppg, "{ield:~ ft3 s,x. Sx: 1.J2 0' HD.. 0' T\TD ./ Class G + additives sx. cf: 3.JO ft3 Mixed with fresh water >500 psi in 8 hrs 340 ft3, 50% Open Hole Excess, WOC Time: 8 hrs Setting Depth: 5208' [.1D' 5150' TVD Annular Volume to 3120' with 6-1 8" gauge hole: 290 ft3 Oensit:z,:- ppg, 'lield:- , T',..rD + additives fresh water ft3""sx, Sx: sx, cf: ft3 'HD' Class G I.li xed w, psi in hrs, psi in hrs ,,/ ,¡' Densit~,:~ ppg, J.'ield:~ ft3 sx, Sx: 456 1000'HD,' 1000' TVD ~/ Class G + additives Mixed w fresh water sx, cf: 838 ft3 500 psi in psi in 2'-1 hrs 6 hrs, 2500 838 ft3, 50% Open Hole Excess, WOC Time: 6 hrs Pags- ..J. 0 f ::' Diverter and BOP Program The di':erter s~'stem will consist of a :0 )~", 3000 psi annular pre',:entor and a 16" O.D. nonbifurcated ~ent line. The vent line will be full opening and integrated with the annular in the fail safe design a.s st ipulated in 20J.._;C 25.035. The '..ent line wi 11 be a minimum of ì5' ft-om an~' SOUl"Ce of ignition. / The blowout preventer stack will consist of a 13 5 8", 5000 psi annular. a 13 5 3", 5000 psi double ram pre-!entor with blind rams on botte,m 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 pre~enter with pipe rams. The choke manifold will be rated 3 1 3", 5000 psi. It will include a remote h~'draulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Size l-l;SP Test Casing (in) (psi) (psi) Dr i ':e Pipe 13 3,8" n a n.-a 1122 1500 Surface ì" (9.0 ppg mud) BOPS Size & Rating Test Low 'High (psi) (1 ) 20- 3," 4" 3H Annular w' HCR ~lal',.e Func t icon (1) 13-5,'8" 5H Annular (1) 13-5 8" 5H Blind ram (1) 13-5 '8" 5H Pipe ram 250,3000 / 250..3000 250"3000 Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) ~~SP, or (2) 70~ of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG backup. In addition, it is necessary to test to at least 50% of the required working pressure of the BOP stack. This well is required to have a working pressure of 3000 psi. ~, 711 Surface Casing at 1500' TVD CTFHASP = 1122 CTPBL.icsr: = 6340 " 0.7 - ((9.0 - 8.3) 1< 0.052 " 1500) = .:138..1 Test to 1500 psi 3-1/2" production at 5150' TVD CTPB'.lrst 1822 psi = 10,160 .. O.ì - ((9.0 - 8.3) .. 0.052" 5150) = 69::5 ,/ Test to 2800 psi' C'T PUA::- P Due tc, tubing less completion, '..je will test to [.L::'.SF c,f production inter:al while burnpin9 the plugs. The calculation assumes top of the 13.5 f"P9 cement @ 1000' T'.T)' Mud Program Contractor: [n Dr illing Fluids In t er...al ( T~:D) [-Iud \',]e igb t Fr::;,m Te, (Ppg) \'Ja ter L,::-,ss 1 ~,O (I' 515(1' + - 9.0 ,/l < 8 Bud T:,"pe Hi '~el FL':-' PEC' }:C 1 0' 1500' 8.6 - 9.0 IT C KEU ..11-~X Drilling Program Page 5 of 2: Wellhead Program I.1anu facturer Hodel Tubing Head Tubing HangeL- ABE Vetco Gre-:/ 13 - 3 '8" x 7" x 3 -1 ' :2 ", :" 0 0 0 ps i Per attached Slip T~~e w Manual Seals Detailed Drilling Procedure Formation Leak off Test / Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out oE casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record ~olume required on the drilling report. Leak-oEf tests (LûT) 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. Eegin slowl~' pumping fluid down the drill string at 1,2 bpm while recording casing and drill pipe pressures at l' 2 bbl inter.'als. .-:... running plot of pressure '.'ersus 'v'olume should be kept b:: the dri 1 ling foreman while the test is in progress. 4. Stop pumping when the pressure cup'e departs form a straight 1 ine su E Eicierlt 1::,' to indica te 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 Eor 10 minutes or until the shut-in pressure stabilizes. Bit Program The following guidelines are recommended Ear use on grading should be used to select the proper bit for tooth bit Eor drill out of 20" shoe track. this well. Actual drilling conditions and dull the next interval. Insure to ha~e 8-1,2" mill Inter:al (HD) Bit Size lADC WOE EPr-I (in) Bit [.Iodel Code (k 1bs) 8 l~" TED TBD 5 .J,O 60 - 200 6 1 8" TED TBD 5 35 60 - 20ü 0' - 1500' 1500' - '52ü8' Drill String Item 4", 8-135, HT 38 5 ~/2" HWD P , 41/2" IF Ppf Makeup Torque Max Pull - Premium 15.53 13,500-19,800 403,500 lbs. ft.-lbs. ./ 49.3,/53.6 29,000 543,000 lbs. ft.-lbs. KEU ~1-7X Drilling Program Page':; e,f S Hydraulics Program Pig mud pumps ë':I'lailable are she".m J:,elow. InstallS" liner-::, in all mud pumps. Liner ID Stroke ¡.Iax Press Gal Stroke I'lax P.ate Þ.mt I.lake Hodel (inl I. in) (9"7~j ef f) (spm) ..., ûihJell A 600 PT 5.0 3" 2597 1.9788 175 Oi lwell ...... 600 PT 5 l,:" 8" 21,*7 ~.3959 1""1: 2 I..) Tabulated below are the expected flow rates and annular velocities for the hole sections. Pump Standpipe IJozzle Depth Hole Size Rate Pressure ]..v ECD Size (HD) (in) (gpm) (psi) (fpm) (ppg) (32"s) Remarks 1500' 8 l~" 450 196 TED TBD Hotar Drilling 5208' 6-1/8" 250 280 TBD TBD Hotor Drilling lTote: 5" 1 ineI:s are recorrunended for all hole sections. OPERATIONAL PROCEDURE 1. IUEU the drilling rig. Im 21 14", 2I.! c;:i'iverter s:,rstem. Function test di'.rerter and HCP. '.Tal':e. P.ecord test on H~DC book. Install 5" "liners in both mud pumps ~, PU and stand back 68 stands 4" DP, and 13 stands of 5" HWDP. note: drift pipe while picking up. PU BHA #1 as per the attached. Pump through motor, HWD, and bit at 450 GPH. Record standpipe pressure. Directionall'1r drill 8 l~" hole to 1500' 1-1D' 1498' 'rVD per the attached directional program. Back ream each stand. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps to clean the hole. 3. At TD, pump a hi-vis sweep and circulate the hole clean. POOH LD 5" HWDP and BHA. ./ 4. RU and run 7" casing as follows: a). (3) jt 7", 23 ppf. L-80, ETC "dtb float shoe. b). Check float and circulate thru shoe cl. HU 7" Float Collar. (Eakerl,:..:k all connections to top of float collar) d). Circulate through float collar. e). Run sufficient 7", 23 ppf, L-80, BTC to run pipe to TD f). ~ru circulating head and test lines to 3000 psi. g). Circulate and condition mud. Casing to be centralized as follows: Middle of bottom 5 jts, 1 e~er~. 3 jts up to 250' MD, 1 inside 13-3 8" conductor, and 1 just below the wellhead. Total 16 centralizers 5. PU Cementing head and test lines to 3000 psi. Cement per the attached program. Drop wiper plug v and displace to float collar (de. not a-o'er displace more than l~ of shoe joint 'mlume). Bump plug to 1500 psi. Bleed pressure to ensure floats are holding. WOC. 6. lID di~erter. Rough cut 7" casing. Cut 13-3 8" starting flange off. Finalize 7~ cut. Weld on 7" S()\v:-: 11", SIr casing head. 1m 11~ 5I-l :-: 13 5 8" 5H spool. [ru and Test BCoPE. ""--Test casing to 1:,00 ;" psi. Install wear bushing. ; . PU 6-1 8" bit and BH;'. f:t.2. Pump thru bit, moto:.r, and [,IVJD at drilling rate. F-=cord pre.38Ure and. rate. TIH to float collar. Drill float equipment and 20'-~5' of new formation. Circulate hole clean. Test shoe to leak off."/' Estimated EIl\,'.] is 15.6 PPG.""'" Displace to FLû PF.O mud s'./stem. /' s. Drill 6-1 '3" directional hole to 5203' [ID 5150' T~TI. Lost circulation is possible throughout this inter~al. Back ream as required. At TD, short trip to the Ehoe. TIH and circulate the hole clean. POOH LD BHA. Log well as per the program. 9. / 10. P.etrie'"e '~lear J::.ushin.;¡-. Install 3-1 ~" casing rams in upper ram. Test door seals to 250 3000 psi. 11. PU and run 3-1 2~ casing ~s follo~s: ~BU ~1-7~ Drilling Program Page 7 clf E ::1). III jt 3-1 :::", 9.3 \, L-SO, BTC '.-Jith fle,at .;h':"02. bl. (:::) jt3 3-12", 9.3 Pp£. L-80, BTe ':Jith fle':;at c,::,ll:lr on top. Bakerlock all connection~ to top of float collar C). Check floats and circulace thru shoe d). Run sufficient 3-1 2", 9.3 ppf, L-BO, ETe to run pipe to TD e). !-IU circulating h8ad and test lines to 3000 psi. f¡. Circulate and condition mud. Reciprocate pipe while circulating. Casing to be centrali=ed as follows: 1 e~er~' joint to 4800', 1 e~ery third joint from ~800' to 3600', and 1 every 5th joint to 1400', Total - 32 12. RU cementing head. Test lines to 5000 psi. Cement 3-1,2" casing per the attached program. Reciprocate pipe as long as possible while cementing. Do not over displace more than ~ of shoe joint ':olume. Bump plug w' +23052- psi total. Check floats. IrJOC 13. [m BOP stack. Set 3-1 '2" slips and pack off. Test pack off to 2500 psi. NU 11" 5H Z 7" 51-1 tubing adapter. NU Tree and test to 5,000 psi. 14. F.elease rig. ,,/' Well will be perforated at a later date. }:8U ~1-7:.: Drilling Pl-'::'9ram Pa.;¡e ::;: c,t :3 \ MARATHON Oil Company Created Dy Sutnerlano For: S. Lambe Dole oJ.:>lt8C!, J-,on -200:1 1"01 R.r..","ce :. ~Bu .1 -7X Vo...O" 17, Structure: Pad 41-7 Well: KBU41-7X eoorg.nOI.. 0'11 .n '.81 ""erenc. .'ot 1~8U'1 -7X. 1"wG vertical DeøtJ"l8 arw referel"'CG rilL R"B. R;:¡. ! -=- 200 - 0 - 200 - 400 - 600 - 800 - 1000 - ,........ -to- a.> 1200- a.> '+- .......... .£: 1400 - -to- a. a.> 0 1600- C u += 1800- 10.... a.> > a.> 2000 - ::::J 10.... I-- I 2200 - V 2400 - 2600 - 2800 - 3000 - 3200 - 3400 - .3600 200 Field: Keflal Gas Field Location: Kenai Peninsula, Alaska INTEQ 520 480 400 360 <- West (feet) 200 280 240 I 320 440 Š 7S" 8 J:l 0.00 1.3 .3/8 Conductor b b f;:'b ~~ f;:'ò b ~b ~b 0" 0" ";J° ";J° ";J° cf c,° cJ> '? C?,. ,. ,. '? ,. ,. ,. ,." ,O_en ~ '" n.,'\. <ò"~" ~ ,... ~ <ò v "".9 ~ , 'Ì s.0' o?o- 0,.... ~ ~ Dr', Nudge o"b '? ""c..'" <ò":J" J',('\ , )' 0,... g~1 7.50 Begin Drop 6.00 Begin . 0.00 2.00 4.00 6.00 2600 - 4.50 3.00 DLS: 2.00 deg per 100 ft DLS: 1.50 deg per 100 ft 2800 - 1.50 . 0.00 .3000 - J.l 7 Casing 0.00 WELL PROFILE DATA 3200 - --- ~ ---- -- . ~ 0.,/" -....- ..-- +- a.> 3400 - a.> - '--" .£: 3600 - +- a. a.> 0 3800 - 0 U - 4000 - '- (J > (J 4200 - ::::J '- I- I 4400 - V 4600 - 4800 - 5000 - ..... IIIUII-- .....- '.. .maøI "'UtI OaD .DØJII 1V2J8I lUll aua ,III" .,... ,ItUII ..... JlI..IJ ...... '.... I,JP ... ...., 1118 -.mID' .D:I.AJ """'''''..'''''111'''' .".1 ""'-«IIJD - ..... .... ........ . 0.00 KOP 2.00 4.00 DJII .I1"IIQIIII IIID.. IIJIII .-110 IIIII.ØII l'a.~""I-" _.1 6.00 DLS: 2.00 deg per 100 it 8.00 10.00 12.00 14,00 16,00 17.57 HOld \ 0 200 400 600 800 160 80 0 40 40 120 - 120 ~ò 0 - 80 I () 0'< 0'" <::),- ~ ." ~ ~flJ Begin Or' Nudge - 40 : -: c - 0 c ..: - 40 10.00 12.00 14,00 DLS: 2.00 deg per 100 ft 16.00 17.57 Hold 17.57 End 17.37 A9 - Sand Ala - Sand All - Sand 81 - Sand 82 - Sand 83 - Sand 84 - Sand of Hold DIS: 1.50 dD\ ~"r , DO 8..3 7 : 6.87 . 85 - Sand 5..37 " 3.87 . C 1 - Sand 2..37 " 0.87 : TE Target 0.00" U4 - Sand Ii u6 - Sand: C2 - Sand UI - Sand u2 - Sand u.3 - Sand u5 - Sand U7 - Sand Hold U8 - Sand D u9 - Sand Jol fD .3 1/2 Liner 5200 - 200 0 200 400 600 800 1000 Vertical Section (teet) - > Vertical Section (feet) -> Azlmutl1 270.00 with reference 0.00 N. 0.00 E from slct IIK8U41-7: Aziml.ltl1 270.00 witl1 reference 0.00 N, 0.00 E from slot #KBU41-7X r.1ARATHON Oi 1 Company Pad 41-7 KBU41-7X slot #KBU41-7X Kenai Gas Field Kenai Peninsula. Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref: KBU 41-7X Version #2 Our ref: prop5048 License: Date printed: 3-Jan-2002 Date created: 26-Dec-2001 Last revised: 3-Jan-2002 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 32.522.w151 14 42.131 Slot Grid coordinates are N 2361829.704. E 275258.275 Slot local coordinates are 156.44 S 4353.97 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ~1ARATHmJ 011 Company PROPOSAL LISTING Page 1 Pad 41-7.KBU41-7X Your ref: KBU 41-7X Verslon #2 Kena1 Gas Field.Kenai Peninsula. Alaska Last revised: 3-Jan.2002 Measured Inclln. Azimuth True Vert R E C TAN G U L A R Dogleg Depth Degrees Degrees Depth COO R DIN ATE S DegllOO ft 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 100.00 0.00 320.00 100.00 0.00 N 0.00 E 0.00 200.00 0.00 320.00 200.00 0.00 N 0.00 E 0.00 300.00 0.00 320.00 300.00 0.00 N 0.00 E 0.00 400.00 0.00 320.00 400.00 0.00 N 0.00 E 0.00 Begin Dr'l Nudge 500.00 2.00 320.00 499.98 1.34 N 1.12 W 2.00 600.00 4.00 320.00 599.84 5.35 N 4.49 W 2.00 700.00 6.00 320.00 699.45 12.02 N 10.09 W 2.00 775.00 7.50 320.00 773.93 18. 77 N 15.75 W 2.00 Begin Drop 875.00 6.00 320.00 873.23 27.78 N 23.31 W 1. 50 975.00 4.50 320.00 972.81 34.79 N 29.19 W 1. 50 1075.00 3.00 320.00 1072.59 39.80 N 33.39 ~ 1. 50 1175.00 1. 50 320.00 1172.51 42.81 N 35.92 W 1. 50 1275.00 0.00 320.00 1272.50 43.81 N 36.76 W 1. 50 1300.00 0.00 264.60 1297.50 43.81 N 36.76 W 0.00 1400.00 0.00 264.60 1397.50 43.81 N 36.76 W 0.00 1500.00 0.00 264.60 1497.50 43.81 N 36.76 W 0.00 1600.00 0.00 264.60 1597.50 43.81 N 36.76 W 0.00 1700.00 0.00 264.60 1697.50 43.81 N 36.76 W 0.00 1800.00 0.00 264.60 1797.50 43.81 N 36.76 W 0.00 1900.00 0.00 264.60 1897.50 43.81 N 36.76 W 0.00 2000.00 0.00 264.60 1997.50 43.81 N 36.76 W 0.00 2100.00 0.00 264.60 2097.50 43.81 N 36.76 W 0.00 2200.00 0.00 264.60 2197.50 43.81 N 36.76 W 0.00 KOP 2300.00 2.00 264.60 2297.48 43.64 N 38.50 W 2.00 2400.00 4.00 264.60 2397.34 43.15 N 43. 71 W 2.00 2500.00 6.00 264.60 2496.96 42.33 N 52.38 W 2.00 2600.00 8.00 264.60 2596.20 41.18 N 64.52 W 2.00 2700.00 10.00 264.60 2694.97 39.71 N 80.09 W 2.00 2800.00 12.00 264.60 2793.13 37.91 N 99.08 W 2.00 2900.00 14.00 264.60 2890.56 35.80 N 121. 48 W 2.00 3000.00 16.00 264.60 2987.15 33.36 N 147.24 W 2.00 3078.56 17.57 264.60 3062.35 31. 22 N 169.83 W 2.00 Hold 3500.00 17.57 264.60 3464 . 13 19.25 N 296.49 W 0.00 3586.78 17.57 264.60 3546.87 16.78 N 322.57 W 0.00 End of Hold 3600.00 17.37 264 . 60 3559.47 16.41 N 326.53 W 1. 50 3618.35 17.10 264.60 3577.00 15.89 N 331. 94 ~ 1.50 A8 - Sand 3649.70 16.63 264.60 3607.00 15.04 N 340.99 W 1. 50 A9 - Sand 3691. 38 16.00 264.60 3647.00 13 . 93 N 352.65 W 1. 50 AID . Sand 3700.00 15.87 264.60 3655.29 13 . 71 N 355.00 W 1. 50 3767.11 14.87 264.60 3720.00 12.04 N 372.71 W 1. 50 All - Sand 3800.00 14.37 264.60 3751.83 11. 26 N 380.98 W 1. 50 3825.96 13.98 264.60 3777.00 10.66 N 387.31 W 1. 50 Bl - Sand 3887.68 13.06 264.60 3837.00 9.30 N 401. 67 W 1. 50 B2 - Sand 3900.00 12.87 264.60 3849.01 9.04 N 404.42 W 1. 50 3951.20 12.10 264.60 3899.00 8.00 N 415.45 W 1. 50 B3 - Sand 4000.00 11.37 264.60 3946.78 7.06 N 425.33 W 1. 50 4032.84 10.88 264.60 3979.00 6.46 N 431. 64 ~ 1. 50 B4 . Sand 4100.00 9.87 264.60 4045.06 5.33 N 443 .68 ~ 1. 50 4200.00 8.37 264.60 4143.79 3.83 fJ 459 .4 7 \~ 1. 50 All data is in feet unless otherwise stated. Coordinates from slot #KBU41.7X and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole dlstance 1S 500.00 on azimuth 270.00 degrees from wellhead. Total Dogleg for well path is 50.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes It/TEQ t.\ARATHON 011 Company PROPOSAL Ll STI NG Page 2 Pad 41-7.KBU41-7X Your ref: KBU 41.7X Version #2 Kenal Gas Field.Kenai Peninsula. Alaska Last revlsed: 3-Jan-2002 Measured Inclin. AZlmuth True Vert R E C TAN G U L A R Dogleg Depth Degrees Degrees Depth COO R DIN ATE S DegllOOft 4223.45 8.02 264.60 4167.00 3.52 N 462.80 W 1. 50 B5 . Sand 4300.00 6.87 264.60 4242.91 2.58 N 472.67 W 1. 50 4400.00 5.37 264.60 4342.33 1.58 N 483.29 W 1. 50 4494.98 3.95 264.60 4437.00 0.85 N 490.98 W 1. 50 C1 - Sand 4500.00 3.87 264.60 4442.01 0.82 N 491. 32 W 1. 50 4600.00 2.37 264.60 4541.85 0.31 N 496.74 W 1.50 4665.18 1.40 264.60 4607.00 0.11 t, 498.87 W 1.50 C2 . Sand 4700.00 0.87 264.60 4641,81 0.04 N 499.56 W 1.50 4709.19 0.74 264.60 4651.00 0.03 N 499.69 W 1. 50 U1 . Sand 4757.19 0.01 264.60 4699.00 0.00 N 500.00 W 1.50 U2 - Sand 4758.19 0.00 264.60 4700.00 0.00 N 500.00 W 1.50 KBU 41-7X tgt-TE 12/26/01 4758.29 0.00 270.00 4700.10 0.00 N 500.00 W 0.00 Hold 4800.00 0.00 270.00 4741.81 0.00 N 500.00 W 0.00 4804.19 0.00 270.00 4746.00 0.00 N 500.00 W 0.00 U3 - Sand 4822.19 0.00 270.00 4764.00 0.00 N 500.00 W 0.00 U4 - Sand 4870.19 0.00 270.00 4812.00 0.00 N 500.00 W 0.00 U5 - Sand 4900.00 0.00 270.00 4841.81 0.00 N 500.00 W 0.00 4908.19 0.00 270.00 4850.00 0.00 N 500.00 W 0.00 U6 - Sand 4956.19 0.00 270.00 4898.00 0.00 N 500.00 W 0.00 U7 - Sand 5000.00 0.00 270.00 4941.81 0.00 N 500.00 W 0.00 5015.19 0.00 270.00 4957.00 0.00 N 500.00 W 0.00 U8 - Sand 5045.19 0.00 270.00 4987.00 0.00 N 500.00 W 0.00 U9 . Sand 5100.00 0.00 270.00 5041.81 0.00 N 500.00 W 0.00 5200.00 0.00 270.00 5141.81 0.00 N 500.00 W 0.00 5208.19 0.00 270.00 5150.00 0.00 N 500.00 W 0.00 KBU 41-7X tgt-TD 12/26/01 All data lS in feet unless otherwlse stated. Coordinates from slot #KBU41.7X and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 500.00 on aZlmuth 270.00 degrees from wellhead. Total Dogleg for well path is 50.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~ ~~RATHON Oil Company Pad 41-7.KBU41-ìX Kenal Gas Fleld,Kenai Penlnsula, Alaska PROPOSAL LISTING Page 3 ~our ref: KBU 41.7X VerSlon #2 Last revised: 3-Jan-2002 Comments ln wellpath -- r'1D TVD Rectangular Coords. Comment .. .-- --- ----.. .........-...............- ..-- ..----- -..-- -..- -..---..... --- ---------..... -..--......... -..--- ----..- --.....-.. ---. -"----."-.. 400.00 400.00 0.00 N 0.00 E Begin Dr'l Nudge 775. 00 773.93 18.77 N 15.75 W Begin Drop 2200.00 2197.50 43.81 N 36.76 W KOP 3078.56 3062.35 31. 22 N 169.83 W Hold 3586.78 3546.87 16.78 N 322.57 W End of Hold 3618.35 3577.00 15.89 N 331.94 W A8 - Sand 3649.70 3607.00 15.04 N 340.99 W A9 - Sand 3691. 38 3647.00 13 . 93 N 352.65 W A10 - Sand 3767.11 3720.00 12.04 N 372.71 WAll. Sand 3825.96 3777.00 10.66 N 387.31 W B1 - Sand 3887.68 3837.00 9.30 N 401. 67 W B2 - Sand 3951.20 3899.00 8.00 N 415.45 W B3 - Sand 4032.84 3979.00 6.46 N 431. 64 W B4 - Sand 4223.45 4167.00 3.52 N 462.80 W B5 - Sand 4494.98 4437.00 0.85 N 490.98 W C1 - Sand 4665.18 4607.00 0.11 N 498.87 W C2 - Sand 4709.19 4651.00 0.03 N 499.69 W U1 - Sand 4757.19 4699.00 0.00 N 500.00 W U2 - Sand 4758.19 4700.00 0.00 N 500.00 W KBU 41-7X tgt-TE 12/26/01 4758,29 4700.10 0.00 N 500.00 W Hold 4804.19 4746.00 0.00 N 500.00 W U3 - Sand 4822.19 4764.00 0.00 N 500.00 W U4 - Sand 4870.19 4812.00 0.00 N 500.00 W U5 - Sand 4908.19 4850.00 0.00 N 500.00 W U6 - Sand 4956.19 4898.00 0.00 N 500.00 W U7 - Sand 5015.19 4957.00 0.00 N 500.00 W U8 - Sand 5045.19 4987.00 0.00 N 500.00 W U9 - Sand 5208.19 5150.00 0.00 N 500.00 W KBU 41-7X tgt-TD 12/26/01 Casing positions in string 'A' ------------------------------ ------------------------------ Top t'ID Top TVD Rectangular Coords. Bot t'ID Bot TVD Rectangular Coords. Casing ---........--...... _.....-._--.... --- ......--.. ------ ---.... --...... ..----.... ---..-.. ---.. -----.. ---- ------ ----....-.. ----.... -- ....------.... 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE 5208.19 5150.00 O.OOE 4758.19 4700.00 O.OOE 1500.00 1497.50 O.OOE 120.00 120.00 O.OON O.OON 43.81N O.OON 500.00W 3 1/2 Liner 500.00W 7 Casing 36.76W 9 5/8 Casing O.OOE 13 3/8 Conductor Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T,V.D. Rectangular Coordinates Revised ........ --.............. -''..................''''''''''''''''o808 - - - - -- --o808 -o808'' -- - o8_-o8 -- - --o8 - -o8o8 _o8" -- - - - - -.. - - -o8 - - -o8''o808o8 -o808''o8o8''o8 -o8 - - - --o8 - -- KBU 41-7X tgt-TE 12/ KBU 41-7X tgt-TD 12/ 4700.00 5150.00 O.OON O.OON 500.00W 26-Dec-2001 500.00W 26-Dec-2001 Structure: Pad 41-7 Creoted by S"t"ertcno For: S. Lambe Dote oloIU" 3-.Jo" -2002 MARATHON Oil Company D 2800 2 1 0 ~~~;oo 500 ~ Travelling Cylinder - Feet Pial Rere","ce ;1 <Bu £' - 711 Ve..."", '2. Coord,noto. .'" ;n le8\ rel.","c. .'al '(BU£ 1- lX, T",e Vert'col 0.0\111 ... ...'erence Ell F¡o(B. Drfl..l .... lNTEQ ill ill 330 34") 1300\. 320 310 280 270 260 250 240 230 20 m ~'~ormal Plane Well: KBU41 -7X Field: Kenai Gas Field Location: Kenai Peninsula. Alaska 350 40 50 70 80 100 11 0 120 130 140 00 ,'V 1 50 !:)c ,") cP ,1:14. II<DUI2 > 160 190 All depths shown are Measured depths on Reference Well MARATHON Oil Company Creoted Oy SutnS'lono For: S Lambe Do.. DIOlled' J-.JO"1-2002 P'ot ~OIO"'"ce :. KBU '" -7X va........ '2, Structure: Pad 41-7 Well: KBU41-7X Coorø'"DIOI 0'" .n 'alii ",Ioranco "01 'I(BU4 1 - 7X r",o VO.uc:ol De¡>\I'D ora ",'.....nco E.L ~I(B. G:.t.l Field: Kef'lal Gas Field Location: Kenol Peninsula. Alaska .... rNTEQ <- West (feet) 560 520 480 440 400 .360 .320 280 240 200 160 120 80 40 0 40 80 I '[lj 360 - I t - 360 1400D .320 - - 320 260 - 13001.. - 280 240 - \ - 240 200 - - 200 160 - - 160 ^ ^ I 120 - -è- - 120 I ........... Z - 0 Q) Q) 80 - - 80 ., -+- \f- ::r ......... ..c ---- ~Ç) ~ - 40 - cÇ) cÇ) - 40 CD L cÇ) Ç)Ç) -.f 0 !::)Ç) "'J'd "J':i CD Z ~p <)Ç) þl.a "'JOj ":J" ,,700 -+- ¡""'-"L þI.'d þI.'); ......... 0 - - 0 ........... <o:1Ç) (/) - '0' 0 Q) Q) - 40 ~ \f- 40 - -+- ......... ::r ..c ---- - ~ ::J 80 - CD 0 CD -+- (/) '-'" I 120 - - 120 I V V 160 - - 160 1000 KQul2 >- 200 - - 200 240 - tgo 500 260 - - 280 '" 600 .320 - ~ 700 - .320 .360 - ~. BO,O - 360 , 560 520 480 440 400 .360 320 280 240 200 160 120 80 40 0 40 80 <- West (feet) MARATHON Oil Company Pad 41-7 KBU41-7X slot #KBU41-7X Kenai Gas Field Kenai Peninsula. Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: KBU 41-7X Version #2 Our ref: prop5048 License: Date printed: 3-Jan-2002 Date created: 26-Dec-2001 Last revised: 3-Jan-2002 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 32.522.w151 14 42.131 Slot Grid coordinates are N 2361829.704. E 275258.275 Slot local coordinates are 156.44 S 4353.97 E ProJection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ~1ARATHON 011 Company PROPOSAL LISTING Page 1 Pad 41-7.KBU41-7X Your ref: KBU 41-7X Version #2 Kenal Gas F1eld.Kenai Pen1nsula. Alaska Last revlsed: 3-Jan-2002 f'1easured Inclln AZlmuth ~rue Vert R E C TAN G U L A R Dogleg Vert G R J D COO R D S Depth Degrees Degrees Depth COO R D J N ATE S DegllOOft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 275258.27 2361829.70 100.00 0.00 320.00 100.00 O.OON O.OOE 0.00 275258.27 2361829.70 200.00 0.00 320.00 200.00 O.OON O.OOE 0.00 275258.27 2361829.70 300.00 0.00 320.00 300.00 O.OON O.OOE 0.00 275258.27 2361829.70 400.00 0.00 320.00 400.00 O.OON O.OOE 0.00 275258.27 2361829.70 500.00 2.00 320.00 499.98 1.34N 1.12W 2.00 275257.18 2361831.06 600.00 4.00 320.00 599.84 5.35N 4.49W 2.00 275253.89 2361835.14 700.00 6.00 320.00 699.45 12.02N 10.09W 2.00 275248.42 2361841.92 775.00 7.50 320.00 773 . 93 18.77N 15.75W 2.00 275242.89 2361848.78 875.00 6.00 320.00 873.23 27.78N 23.31W 1. 50 275235.51 2361857.93 975.00 4.50 320.00 972.81 34.79N 29.19W 1. 50 275229.76 2361865.05 1075.00 3.00 320.00 1072.59 39.80N 33.39W 1.50 275225.65 2361870.14 1175.00 1. 50 320.00 1172.51 42.81N 35.92W 1.50 275223.19 2361873.19 1275.00 0.00 320.00 1272 . 50 43.81N 36.76W 1.50 275222.37 2361874.21 1300.00 0.00 264.60 1297.50 43.81N 36.76W 0.00 275222.37 2361874.21 1400.00 0.00 264.60 1397.50 43.8UJ 36.76W 0.00 275222.37 2361874.21 1500.00 0.00 264.60 1497.50 43.81N 36.76W 0.00 275222.37 2361874.21 1600.00 0.00 264.60 1597.50 43.81N 36.76W 0.00 275222.37 2361874.21 1700.00 0.00 264.60 1697.50 43.81N 36.76W 0.00 275222.37 2361874.21 1800.00 0.00 264.60 1797.50 43.81N 36.76W 0.00 275222.37 2361874.21 1900.00 0.00 264.60 1897.50 43.81N 36.76W 0.00 275222.37 2361874.21 2000.00 0.00 264.60 1997.50 43.81N 36.76W 0.00 275222.37 2361874.21 2100.00 0.00 264.60 2097.50 43.81N 36.76W 0.00 275222.37 2361874.21 2200.00 0.00 264.60 2197.50 43.81N 36.76W 0.00 275222.37 2361874.21 2300.00 2.00 264.60 2297.48 43 . 64f~ 38.50W 2.00 275220.63 2361874.08 2400.00 4.00 264.60 2397.34 43.15N 43. 71W 2.00 275215.41 2361873.69 2500.00 6.00 264.60 2496.96 42.33f'l 52.38W 2.00 275206.72 2361873.03 2600.00 8.00 264.60 2596.20 41.18N 64.52W 2.00 275194.57 2361872 .12 2700.00 10.00 264.60 2694.97 39. 7lN 80.09W 2.00 275178.97 2361870.95 2800.00 12.00 264.60 2793.13 37.91N 99.08W 2.00 275159.94 2361869.52 2900.00 14.00 264.60 2890.56 35.80N 121.48W 2.00 275137.51 2361867.83 3000.00 16.00 264.60 2987.15 33.36N 147. 24W 2.00 275111.71 2361865.89 3078.56 17.57 264.60 3062.35 31. 22N 169.83W 2.00 275089.09 2361864.19 3500.00 17.57 264.60 3464 . 13 19.25N 296.49W 0.00 274962.22 2361854.66 3586.78 17.57 264.60 3546.87 16.78N 322.57W 0.00 274936.10 2361852.70 3600.00 17.37 264.60 3559.4 7 16.41N 326.53W 1. 50 274932.14 2361852.40 3618.35 17.10 264.60 3577.00 15.89N 331.94W 1. 50 274926.72 2361851.99 3649.70 16.63 264.60 3607.00 15.04N 340.99W 1. 50 274917.65 2361851.31 3691. 38 16.00 264.60 3647.00 13 . 93N 352.65W 1.50 274905.98 2361850.43 3700.00 15.87 264.60 3655.29 13.7lN 355.00W 1. 50 274903.61 2361850.25 3767.11 14.87 264.60 3720.00 12.04N 372.71W 1.50 274885.88 2361848.92 3800.00 14.37 264.60 3751.83 11. 26N 380.98W 1. 50 274877.60 2361848.30 3825.96 13.98 264.60 3777.00 10.66N 387.31W 1. 50 274871. 26 2361847.82 3887.68 13.06 264.60 3837.00 9.30N 401.67W 1. 50 274856.87 2361846.74 3900.00 12.87 264.60 3849.01 9.04N 404.42W 1. 50 274854.12 2361846.53 3951. 20 12.10 264.60 3899.00 8.00N 415. 45W 1. 50 2748"¡3.07 2361845.70 4000.00 11. 37 264.60 3946.78 7.06N 425.33W 1. 50 274833.17 2361844.96 4032.84 10.88 264.60 3979.00 6.46N 431.64W 1. 50 274826.86 2361844.49 4100.00 9.87 264.60 4045.06 5.33N 443.68W 1. 50 274814.79 2361843.58 4200.00 8.37 264.60 4143.79 3.83N 459.47W 1. 50 274798.98 2361842.39 All data In feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU41-lX and TVD from Est. RKB (87.00 Ft at'ove mean sea level). Bottom hole distance is 500.00 on aZ1muth 270.00 degrees from wellhead. Total Dogleg for wellpath is 50.14 degrees. Grld is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spherold Presented by Baker Hughes JtITEQ ~~RATHON 0,1 Company PROPOSAL LIST 1 NG Page 2 Pad 41-7.KBU41-ìX Your ref: KBU 41-7X Version #2 Kenai Gas Field.Kenai Peninsula. Alaska Last revised: 3.Jan-2002 ~'easured Incl, n Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting ~orthi ng 4223.45 8.02 264.60 4167.00 3.52N 462.80W 1. 50 274795.65 2361842.14 4300.00 6.87 264.60 4242.91 2.58N 472. 67W 1. 50 274785.76 2361841.40 4400.00 5.37 264.60 4342.33 1.58N 483.29W 1. 50 274775.12 2361840.60 4494.98 3.95 264.60 4437.00 0.85N 490.98W 1.50 274767.43 2361840.02 4500.00 3.87 264.60 4442.01 0.82N 491. 32W 1. 50 274767.09 2361839.99 4600.00 2.37 264.60 4541.85 0.31N 496.74W 1. 50 274761.65 2361839.58 4665.18 1.40 264.60 4607.00 0.11N 498.87W 1. 50 274759.52 2361839.42 4700.00 0.87 264.60 4641.81 0.04N 499.56W 1.50 274758.83 2361839.37 4709.19 0.74 264.60 4651. 00 0.03N 499.69W 1. 50 274758.70 2361839.36 4757.19 0.01 264.60 4699.00 O.OON 500.00W 1. 50 274758.39 2361839.34 4758.19 0.00 264.60 4700.00 O.OON 500.00W 1. 50 274758.39 2361839.34 4758.29 0.00 270.00 4700.10 O.OON 500.00W 0.00 274758.39 2361839.34 4800.00 0.00 270.00 4741. 81 O.OON 500.00W 0.00 274758.39 2361839.34 4804.19 0.00 270.00 4746.00 O.OON 500.00W 0.00 274758.39 2361839.34 4822.19 0.00 270.00 4764.00 O.OON 500.00W 0.00 274758.39 2361839.34 4870.19 0.00 270.00 4812.00 O.OON 500.00W 0.00 274758.39 2361839.34 4900.00 0.00 270.00 4841.81 O.OON 500.00W 0.00 274758.39 2361839.34 4908.19 0.00 270.00 4850.00 O.OON 500.00W 0.00 274758.39 2361839.34 4956.19 0.00 270.00 4898.00 O.OON 500.00W 0.00 274758.39 2361839.34 5000.00 0.00 270.00 4941. 81 O.OON 500.00W 0.00 274758.39 2361839.34 5015.19 0.00 270.00 4957.00 O.OON 500.00W 0.00 274758.39 2361839.34 5045.19 0.00 270.00 4987.00 O.OON 500.00W 0.00 274758.39 2361839.34 5100.00 0.00 270.00 5041.81 O.OON 500.00W 0.00 274758.39 2361839.34 5200.00 0.00 270.00 5141.81 O.OON 500.00W 0.00 274758.39 2361839.34 5208.19 0.00 270.00 5150.00 O.OON 500.00W 0.00 274758.39 2361839.34 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU41.7X and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 500.00 on azimuth 270.00 degrees from wellhead. Total Dogleg for wellpath is 50.14 degrees. Grid is alaska. Zone 4. Grid cool'dinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~~RATHON Oil Company Pad 41.7.KBU41.7X Kenal Gas Field.Kenal Peninsula. Alaska PROPOSAL LISTING Page 3 Your ref: KBU 41.7X VerSlon #2 Last revised: 3-Jan-2002 Comments in wellpath -- t.1O TVD Rectangular Coords. Comment ....----.......----.----..-------........---.....------.......-----."""---"""-"-"----"-"-"----""..".-"--------".""""...... 400,00 400.00 O.OON O.OOE Begln Dr'l Nudge 775.00 773.93 18.77N 15.75W Begin Drop 2200.00 2197.50 ~3.81N 36.76W KOP 3078.56 3062.35 31.22N 169.83W Hold 3586.78 3546.87 16.78N 322.57W End of Hold 3618.35 3577.00 15.89N 331.94W A8. Sand 3649.70 3607.00 15.04N 340.99W A9 - Sand 3691. 38 3647.00 13 .93N 352.65W AI0 - Sand 3767.11 3720.00 12.04N 372.71W All - Sand 3825.96 3777.00 10.66N 387.31W B1 - Sand 3887.68 3837.00 9.30N 401. 67W B2 - Sand 3951.20 3899.00 8.00N 415.45W B3 - Sand 4032.84 3979.00 6.46N 431.64W B4 - Sand 4223.45 4167.00 3.52N 462.80W B5 - Sand 4494.98 4437.00 0.85N 490.98W C1 . Sand 4665.18 4607.00 O.llN 498.87W C2 - Sand 4709.19 4651.00 0.03N 499.69W Ul - Sand 4757.19 4699.00 O.OON 500.00W U2 - Sand 4758.19 4700.00 O.OON 500.00W KBU 41-7X tgt-TE 12/26/01 4758.29 4700.10 O.OON 500.00W Hold 4804.19 4746.00 O.OON 500.00W U3 - Sand 4822.19 4764.00 O.OON 500.00W U4 - Sand 4870.19 4812.00 O.OON 500.00W U5 - Sand 4908.19 4850.00 O.OON 500.00W U6. Sand 4956.19 4898.00 O.OON 500.00W U7 - Sand 5015.19 4957.00 O.OON 500.00W U8 - Sand 5045.19 4987.00 O.OON 500.00W U9 - Sand 5208.19 5150.00 O.OON 500.00W KBU 41-7X tgt-TD 12/26/01 Casing positions in string 'A' ------------------------------ ------------------------------ Top nD Top TVD Rectangular Coords. Bot HD Bot TVD Rectangular Coords. Casing .....------..--..---..--....-----..--..----..---------....--..--..--...-..-..--..--------........----------.-----------------.......- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE 5208.19 5150.00 O.OOE 4758.19 4700.00 O.OOE 1500.00 1497.50 O.OOE 120.00 120.00 O.OON O.OON 43.81N O.OON 500.00W 3 1/2 Liner 500.00W 7 Casing 36.76W 9 5/8 Casing O.OOE 13 3/8 Conductor Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Locatlon T.V.D. Rectangular Coordinates Revised -- ....--- ---........... -....-.. ..-- ----.... -----_....- --...... -- --- --.. ..- ---"----o8--o8-----"o8 -- --------....-o8 o8-"o8....---o8- o8--- .o8- -o8 KBU 41-7X tgt-TE 12/ KBU 41-7X tgt-TD 12/ 4700.00 5150.00 O.OON O.OON 500.00W 26-Dec-2001 500.00W 26.Dec-2001 t.IARATHON Oi 1 Company Pad 41-7 KBU41-7X slot #KBU41-7X Kenal Gas Field Kenai Penlnsula, Alaska 3-D M I N I MUM D 1ST A N C EeL EAR A N C ERE P 0 R T by Baker Hughes INTEQ Your ref: KBU 41-7X Version #2 Our ref: prop5048 License: Date printed: 3-Jan-2002 Date created: 26-Dec-2001 Last revised: 3-Jan-2002 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 32.522,w151 14 42.131 Slot Grid coordinates are N 2361829.704. E 275258.275 Slot local coordinates are 156.44 S 4353.97 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet DECREASING CLEARANCES of less than 1000 feet are lndicated by an asterisk. e.g. 487.4* Object well path MMS <0-7910'>. .KBU33-7.Pad #?? GMS <0-5820'>. ,KU24-7,Pad I?? KU21-6X Version#4, ,KU21-6X,Pad #? PGMS <778 - 5567'>. ,KU21-6X.Pad #? MWD <3452 - 5650'>. .KU21-6X.Pad #? MSS <0 - 5678'> Depth Shifted. .KU21-6X.Pad #? PGMS <0-3300'>. .WD-1,Pad #? MSS <0-4459'>, ,KU11-6.Pad #? Incl. only <0-5809'>, ,KU34-31.Pad #? GMS <0-10502'>. .KDU5.Pad #? PG~IS <0 - 5700' >. , KU14- 32, Pad #? GMS <0-11095'>. ,KDU6,Pad #? MSS <0-4453'>. .KU21-7,Pad 14-6 PMSS <0 - ????>..KBU24-6.Pad 14-6 GHS <0-7375'>. .KBU31-7,Pad 14-6 PMSS <5814 - 7575'>.,31-7Rd.Pad 14-6 WD-2 Version #1, .WD.2,Pad 14-6 INCLINATION ONLY, .KU14-6.Pad 14-6 GHS <0-6950'>. .KBU23X-6.Pad 14-6 MSS <0-5500'>. ,KU13-6,Pad 14-6 MSS <0-9895'>, .KDU-1.Pad 14-6 GMS <0-10225'>. .KDU-8,Pad 14-6 MSS <0-6530'>. ,KU43-12.Pad 14-6 PMSS cOo???'>. .KU 31.7,Pad 14-6 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 31-May-1995 3454.2 5208.2 5208.2 31-May-1995 5274.1 4745.2 4745.2 24-Aug-2001 5336.2 4956.2 4956.2 18-0ct-2001 5338,2 4870.2 4870.2 18-0ct-2001 5327.6 4956.2 4956.2 18-0ct-2001 5201.7 4956.2 4956.2 30-May-1995 7421.7 4059.7 4059.7 30-May-1995 5966.5 4495.0 4495.0 30-Hay-1995 7454,9 4665.2 4665.2 30-May-1995 5543.0 5208.2 5208.2 30-May-1995 6525.7 4956.2 4956.2 30-Hay-1995 7686.3 1075.0 3778.1 12-May-1995 2204.5 4542.9 4542.9 12-Mar-2001 1692.9 5208.2 5208.2 14-Sep-1995 1724,6 5208.2 5208,2 28-Sep-1995 1724.6 5208.2 5208.2 26-Mar-1999 3106.2 4086.6 4086.6 26-Mar-1999 2951.2 4721.2 4721.2 12-May-1995 2893.3 4021.9 4021.9 12-May-1995 3114.5 860.7 860,7 12-Hay-1995 2953.7 5208.2 5208.2 12-May-1995 2751.3 5208.2 5208.2 12-May-1995 3393.4 0.0 875.0 10-Jan-2001 898.4 4542.9 4542.9 KU43-6Rd Version #2, ,KU4! ,J,Pad 41-7 MSS <0 . 5701'> Depth Sh,fted. ,KU43-6RD.Pad 41 PMSS <0-8864>..KTU32-7,Pad 41-7 KU24-5Rd Version #4a. .KU24-5Rd.Pad 41.7 GMS <0 . 5893'> Depth Sh,fted, .KU24-5,Pad 41.7 MSS <0-5707'>. .KU 43-7.Pad 41.7 MSS <0-5300'>,,43-6A.Pad 41-7 KTU43-6XRd Ver.7.,43-6X Rd.Pad 41-7 PGMS <0.8370'>, ,43-6,Pad 41-7 PMSS <7670-9464'>. .43-6X Rd.Pad 41-7 PMSS <0 - 7570>, ,KBU42-7.Pad 41-7 GMS <0-7010'>. ,KBU41-7.Pad 41-7 PMSS <8846 - 10960>. .KTU24-6H.Pad 41-7 ~ISS <0-10522'>, .KDU#2.Pad 41-7 GMS <0-5350'>, ,KU11-8.Pad 41-7 GMS <0-5549'>. .KDU4,Pad 41-7 MSS <4320 . 10810'>. .KDU4Rd.Pad 41-7 GMS <0-8120'>, ,KUI3-5.Pad 41-7 GMS <0-7902'>. .KBU33-6.Pad 41-7 KBU 44-6 Vers,on #I..KBU 44-6.Pad 41-7 MSS <0-5706'>, .KU43-6.Pad 41-7 GMS <0-5900'>, ,KU24-5.Pad 41-7 25-0ct-2001 25-0ct.2001 31-Aug-2000 9.0ct.2001 2-Dec-2001 21-Jan-1994 20-Jan-1994 20-Apr-1999 23-Jul-1995 16-Aug-1995 9-Feb-2001 21-Jan-1994 1-Aug-2000 21-Jan-1994 21-Jan-1994 5 - !'lay.1995 5-May-1995 21-Jan-1994 22-Jun-2000 25-0ct-2000 20-Jan-1994 21-Jan-1994 1885.6 94.0 146.6 1481. 0 152.3 265.1 36.6 4368.9 181.7 181. 7 132.7 56.0 103.1 183.4 226.3 172.5 172.5 113.8 304.2 103.3 94.0 152.2 356' 903.6 1217.9 2775.0 737.5 200.0 1032.1 5208.2 1400.0 1400.0 1700.0 2712.5 3260.0 412.5 587.5 100.0 100.0 1132.1 917.9 1500.0 903.6 737.5 3560.0 903.6 2000.0 2775.0 737.5 200.0 1032.1 5208.2 1400.0 1400.0 1700.0 5208.2 5208.2 412.5 587.5 100.0 100.0 1132.1 917 .9 1500.0 903.6 737,5 101-1/2- 27-1/2- ALL DIMENSIONS ARE APPROX. j~ .... ,.,.... -....- ABB V8Ico Gray þRAWN BY: C. RICE k NG. APPR. : 46-1/:r ~ .. " ~IÌ~ I ~-~ -:!~ ~~~~~J r ~ -J \ ~Iß6" I I - 13- 3/8- OD CASING ~ 7- OD CASING "---- 3-1/2- OD TUBING SWE & FCE ENGINEERING 13-3/8 X 7 X 3-1/2 OD. 5M MSP ASSY IDATE: 02 JAN 2001 I~IREFERENCE: MARATHON; DATE: Xlv-r ISCALE: NA þROJECT NO.' OPTION /11 ACAD DRAWING NO. SP-4574 I Flow Nipple I - 13 S/811 SM Annular Preventer 13 S/811 SM Double Ram Preventer 3 1/811 SM Manually Operated Valves Marathon Oil Well KBU 41-7X BOP Stack I Flow Line I I I ~ I .. "> I '..... ./ / I I < I Pipe Ram I I Blind Ram I 3 1/811 SM Hydraulically Operated Valve ) ,,~ :~ IXIIXI)KiII I ~I/ 113 S/811 SM Cross I I) < I /1 ,¡ IChoke(J@[I Xl t 13 S/811 SM Single Ram Preventer I .---.-. '- I I < I Pipe Ram I ) I I, < I I í 3 1/811 SM Manually Operated Valve ITO Gas Buster I ~J@[~ \ "~J@[~ ( ~ ~~ ~ ø J@[J@[ 0 J@[J@l. '- I ~_II I I 13" 5M Valves I i ~ I' ~ ~I r-'1 ~ t Marathon Oil Well KBU 41-7X Choke Manifold To Blooey Line Bleed off Line to Shakers I , ~ ,I ( ~ ~,I r-'1 2 9/1611 10M Swaco Hydraulically Operated Choke ~ IFrom BOP Stack I 3 1/811 5M Manually Adjustable Choke 1203/4" 3M Diverter 1---. I Diverter Spool Marathon Oil Well KBU 41-7X Diverter "> I I "' ~ ./ I I '\ I Flow line / I I " "- I I ( 116" Automatic Hydraulic Valve I ¡ \ :::0: 116" Diverter Line 1 r-<r - - t.. 1"'1"'" I I 1 I L______-- I I I I I I r I 1 f t ,,--...., ~lPoœŒJY\ IŒ6ASSER) I' I , " I ,-- I ~ II ~-----i ~-----~1 , L__~ U t i I r--' " I r I I~ I t I II ) I r ~þ I 11 I Œ '>1 -= II ! ~ t. J W II . <II[ I I I II 1 ~ t t M t. ~ ~ i"l U J Pi : : I i: L____J L-----.JI r---~----;ì I . 811P\." ...,,' I I I ..I ..,¡III I I r-----ì r I ~ I CENTRIFUGE! I UNIT I I 4' X 10" I I I I I I I I I I DtI4P I t ,-, I 1 ,,-, I I I \.._---_.J KODNY 3~ X 12# ¿ ¡ i ~ , I . I :[ ~ ' GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT -46''''- ~ ~ 0 ¡I' I. : 75 HP 751-P 75 HP 75 loP 6 X 5 6 X 5 '6 X :5 i 6 X 5 ~ ! 11. 11. n- U. .. :..2 t .. - _2 :. ,.t ~. ... ... I II . ,--. r '\ , - 111:1&{ . r"1 ~ J 1 I f r 1 I I I 1 I I I I I I L. DE&USEI " ./ " '--e .-c: ( till 1IIUiH '" ! . .. ~ " .. .. . I~TDI J ,- . .. . , , 5'J 9l. 11-600 PT ' & r ';.1. J 5\8' 9l . A-60D Pi ' ~ I ~ T -- ;;¡;: '.. a, ..... . . T ~ ~,-,,-, . 8- U ... flU. PtT ~ ,w. :1- :< ,.....: ::J: . I I I I I I I I I I I I I I , I . I I I - J tr~ R; >: 'X. 14"""" DITA ~- !3"-ir' ~ 1.:r:.1 '):(-1 ; ,~ SURFACE USE PLAN FOR KENAI UNIT KBU 41-7X Surface Location: NE 1/4 of NE 1/4, Sec. 7, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KBU 41-7X are shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access KBU 41-7X. 3. Location of Existing Wells Well KBU 41-7X will be drilled on pad 41-7. A pad drawing is attached that shows existing wells and the proposed location for KBU 41-7X. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. These facilities will be upgraded to handle the additional gas production. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a / Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). M:'Wells\Kenai\~ 1-ìX\SURFUSE,doc Su rface Use Plan Kenai Unit KBU 41-7X Page ~ 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). f' 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 KBU 41-7X will be drilled from an existing pad. Reclamation of the pad will occur after abandonment of KBU 41-7X 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. 11. Operator's Representative and Certification Surface Use Plan Kenai Unit KBU 41-7X Page 3 I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: ¡!./ /t;o¿ Name & Title: ¿I"~ ./ ./ .. r /..oL --:::~:~-~----- Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 ) L,,----I~1!:!t 1,1 W .. - .- t-. ,.--.-.-....--- ~, L... i UN1T ~ .'-,. ,a.../OUNDARV. ! \ t.. ~ .i.. ,I ~ ..~-. Ii ~~. ! ~ ~ -., ~ 2 ,x " , ~ '/' ,.,. 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J. ~'V ' , ,? to ">.33'" ,: " ~ 0 /í ..,' .' . ,;'" lYl{ "? Q '\.., G' ',', ,.-/' t ,:' ",., . -is 'I 'I L _26 ,,' .28.../'" .I{ ~7rr:,(",,'''''.,,~:~,,_/,..>' ," . ,- 1 '! LY I ~ I"" ',' ,'l- .,' I ,.~ 1'\" ~ . I . ' '. .':.' ,00 ; .. » .JJ" MARATHON OIL COMPANY -{ , ,', .1J" ..I,.'¿'-------... , ,"---" -"'- "... ._..~"~--;-----/ ---..- )(~ ;' KENAI GAS FIELD :" " o,'. U,.' l :.. I :.;.<,::.;1 , ,-- ¡')....",y:" FIGURE 1 I Ret7.ectwn ':, '-:.~~, j3 Lake. , ' (I Ø1..,W '>"",~I .\c: 0 0 CJ T 4 N :p , , . f, " j, /, " " , '.' 24 I, K.alitOnsk~:!~ - - - - - --:-- , I '. I' , , /' \\ :'. ,\. ,i:'''\,- - - , \ . ,~ ., "'1 "'.." \ '~~'\ \ 25 30 29 '. ."~ ''II.. - (, .:-> "-~-I 31 32 '!kfì I..~ ., ~1.~!jJ8 ~I'._~ ~.~ '~_\.1:_IIJ~ 1_- ~i:~'~'i:.~;~~I~[;¡ ;~U~I~-:' ~ I~ì:.\ ~ 1m ~Ij:t ~J_~~ :(~ ;l~î~l ~.I ~Y} ;1.:tÏI~~;j [~] ~ ~ ~,,~~.!.~!t~!3:t:\'~~~ ~'}~. ,~, ~(:1\' j !~ I J I::'¡ t .' - ':.1:. I F'I: ~ ~ I ~II') , '" ',,, "," ::'\: ','" ;:"",":\ ~ ',\"::" "~ ",~,." ~,:',...,;. '~,;,~i.'¡',~:),: 3723 Marathon Oil Company 639 South Main Street Findlay, OhIo 45840 ,,"', , ,i: /,,;';i:: ;":':;':';:::!':':"" :;¡//!;::::'\¡" :~<~:i'~:~,~:'::,':, ", '" ',CHEq,K"D~1E '''::/I,'¡':it¡/~HE,(ik';:I'IUMB¡:f\ " ' 12'1 '1.',7"1:,2 0 o:t'¡:i':h,;:, ~j'ij'3'3"1Ó",'.i,:'i,:,::" . .' "',' ")'!'" :¡~!¡, ~~H~j~h¿¡~:!1; ,.,,::"~;:$tt:)1 ',""',',,"",',',' _. '~~~~§~~ï:: Q1fi:f[ifW~ir~~!1~~j~~~:~~}!'~Øi~~~!iz{~~~'~:~:§:',: , , " ,;" , " ACCOUNTS PAYABLE CHECK , , PA Y TO THE ORDER OF: ' ~'.:.'.~.:.~~f.:.'/':'\'ICtI{'Ul¡'y~ ' 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501-3539 U.S. Funds PNC BANK, NATIONAL ASSOCIATION, JEANETTE, PA ~y: , :":~Æ~~. " . ", ";,', .'~..':; ,':, " 'II ' I I' AUthorIZed Representative I "I '. " , .. IIli ~ [~ì ':IJ~ ~4: i'1 ~ I ~ :(.i-".: 1[,'11 ~'Ú~Ij-~t ~~.] ~!'Ú~, ì ~ ~11~j ;:.';1 ~~ ~ I~~:.,'~'~-dl :'[~i ~';,'i~~ ~r~: ~'~(;;~Î~;:'~ì ~I~-I\I Ú;~';I~;j-;a-J'~~¿;I~;~í[;~{~'~~h -,~;¡¡¡¡ 118[:~ 7 :1 :1 7 0 III I: 0 ~ ~ ~ 0 . b 2 71: 000 2 B B 0 ¡. ~ ~ III CHECK 1 STANDARD LETTER DEVELOPMENT / DEVELOPMENT RED RILL EXPLORA TION INJECTION 'VELL INJECTION 'VELL RED RILL ) ) TRANSIVUT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER \VELL NA1\1E /~PJ ¿J 1//- 7)( CHECK 'VHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL ~o ANNlJLAR DISPOSAL L-> YES ANNULAR DISPOSAL THIS "'ELL "CLUE" The permit is for a Dew well bore segment of existing weD ---' 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 L-> YES + SP ACING 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. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY Æ{~;'{ '¡~ELL NAME kßíi.. , '11-7 X PROGRAM: Exp - Dev ~Redrll- Serv - Wellbore seg - Ann. disposal para req - FIELD & POOL ;I'-I~çY¡ INIT CLASS ~v /. ~ ~):::, ~ C3EOL AREA ß 7/~ UNIT# ð ç //2.6 ON/OFF SHORE {)'1 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . ., .~ 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . ..,N 3. Unique well name and number. .. . . . . . . , . . . . . . . . Y N L' J ./' I '?' . 4. Well located in a defined pool."* . . . . . . . . . , . . . . . yW "f- k<2...K4.....c... ~lÅð<L ~q t~ t,J i.-lA~\. 5. Well located proper distance from drilling unit Qoundary.~. ' N .' /Î. - _. -? ~ 6. Well located proper distance from other well~. . . . . . . ,N ~* II.-!.¿~( ~ ~ 1"-:> ~~ ~ c!v / /.:::" / /.?~. ¿ - .010 ..:::f",¡p~c.. #~ . 7. Suffic~ent a~reage availabl~ in drilling unit.. . . . . . . . . . . : N ~/~'h~> ..z...x..c.y.,t: ,'1c ~ /~ I.~ c"./c.~ ~ /.~' 8. If deviated, IS wellbore plat Included.. . . . . . . . . . . . . . N -þ ~~ " ~ k,...-.d~ 9. Operator only affected party.. . . . . . . . . . . . . , . . . , Y '~N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N APPR DA!E ,"" 12. Permit can be issued without administrative approval.. . . . . a~ N X~ Z ,I-ö~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . (j)N (ÑGINEERING 14. Conductor s.tring provided. . . . . . . . . . . . . . . . . . . diN ()~ "~'1- f-.c - I ZO I rV f) . '.. iJ ¿" / .~. / / / - - 15. Surface casing protects all known USDWs. . . . . . . . . . . (1) N All ¿fJt:J,iA~> ó<-f~ I ~ ~1.~ ¡c..¿...¡\P-<., ';>~-<1 rl¿l¿ ~ 16. CMTvol adequate to circulate on conductor & surfcsg. . . . . ~N ./¿ß.P-4\,-¿1 ~~~ ~ ¥v CFK. ¡¿¡,7. /D2. (.b)(/)lc), .4- 17. CMTvol adequate to tie-in long string to surfcsg. . . . . . . . N M~ll.CL1...A~ e(..cpçS(fÛ:'vK.£""'l.t'.d\....o~~~~~\.(.)..,..~~~~Q..~"""-L~~.\"""'\.-U 18. CMT will cover all known productive horizons. . . . . . . . . . N <;.~~ ('( ~~,~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N . '1 ' 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N C.., 1C\..t.-U=1i' 'Vtj l 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N"" ¡..1/A 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ~ N 23. If diverter required, does it meet regulations. . . . . . . . . . , N q tl i 24. Drilling fluid program schematic & equip list adequate. . . . . N" 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . "&J Nil, 26. BOPE press rating appropriate; test to 3000 psig. ~ N fL4,s r :: I 1(9( f ~. MeAt- C.'~I iës t ::. lfcc r.J L~ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . (j) N 31. Data presented on potential overpressure zones. . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . .~. . þ.. Y N AP~R DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ---i!iJL 1- It .(;)"],- 34. Contact name/phone for weekly progress reports [explo ry only] Y N ANNULAR DISPOSAL 35. 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 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: TEMtl~'1A1XJ WGA ~r\ APPR DATE vJt¡A llill () ¿ A1~ ~/70-o;J GEOLOGY APPR DATE .,:$'~Aö-r~~ ~(..~ ~~¿¿;- r/ '4-<- .¿4L.j ~&/~. Y N Y N No Ctl-,v\.,J.a.. ct~ ~'I2cc..- ( tt f W' sf: d ' Com mentsllnstructions: RPC- SF~~ COT DTS (}"LJ /'C/C L JMH .)1\.\ tt ~1-CI(;.¿ G: \geology\perm its\checklist. doc