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165-008
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: Leak Detect Log Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 4,453 feet 3904 & 4009 feet true vertical 4,366 feet 3,814 feet Effective Depth measured 3,904 feet 3,928 feet true vertical 3,827 feet 3,814 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 N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker D Pkr; N/A 3,928' MD 3,850' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 48' 1,195' 3,904' 0 Oil-Bbl measured true vertical Packer 7-5/8" 5-1/2" 4,417'4,330' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling Gas Pool 3N/A measured TVD Tubing Pressure 1,5800 Kenai Unit (KU) 21-07 N/A FEDA028142 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 165-008 50-133-10092-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-378 500 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 220 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 39-4 0 3,827' 0 Representative Daily Average Production or Injection Data 48' 1,195' 4,417' Conductor Surface Intermediate Production 6,390psi 2,890psi Casing Structural 20" 10-3/4" Length 1,820psi Collapse 840psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 7,740psi Burst 4,140psi 48' 1,189' 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 11:08 am, Jan 19, 2021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.18 09:45:58 -09'00' Taylor Wellman Leak Detect Log SFD 1/26/2021 gls 2/4/21 RBDMS HEW 1/27/2021 DSR-1/19/21 SFD 1/26/2021 Rig Start Date End Date 11/19/20 1/4/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KU 21-07 50-133-10092-00-00 165-008 11/19/2020 - Thursday PTW and JSA with AKE-Line. SIMOPS with Co. pump /crew. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 2,500 psi high. Also tested hard lines to 250 psi low and 3,000 psi high, RIH with 4.58" GR/JB and CCL/GR and tag top of Owen Patch at 3,650'. Ran a deep correlation log and a shallow log. Send the logs to town and pull out of hole. This was a drift run for the patch. RIH w/spinner down to 3,619' for a base log. We had to run a 1/2" line from tubing to blow down trailer to control the IA pressure as we pumped down the IA logging up at 120 fpm. Stop log at 22' and bumped up in lubricator. Bled down lubricator and closed swab. Pressured up IA from 0 psi to 2,500 psi - slow -med -fast and started pumping away like it did about a month ago. Started pumping and logging down hole and stop log at 3,621'. Started doing 200' station stops starting at 3,621'. Ran out of water and waited on vac truck to bring a load. Continue with station stops every 200' and stop at 800', ran out of water. Log out of hole. Couldn't keep a light leak rate going to determine hole. AKE-Line is going to make an overlay or something and go over it with OE in town. Rig down lubricator and equipment. Secure well and turn it over to field. The field is going to freeze protect the IA. 01/04/2021 - Monday Discussed results of pressure / temperature logging performed on 9/1/20 and spinner profile performed on 11/19/20 with READ cased hole engineer. Decided against plan to run Archer LeakPoint leak detect log. We will have to try to come up with a different strategy to fix the T x IA communication on this well at a later date. Daily Operations: Discussed results of pressure / temperature logging performed on 9/1/20 and spinner profile performed on 11/19/20 with READ cased hole engineer. Decided against plan to run Archer LeakPoint leak detect log. We will have to try to come up with a different strategy to fix the T x IA communication on this well at a later date. Leak detect log was inconclusive. gls 2/4/21 _____________________________________________________________________________________ Updated by CMT 1-16-2020 SCHEMATIC Kenai Gas Field Well: KU 21-07 Last Completed: 05/2004 PTD: 165-008 TD = 4,453’ PBTD = 3,906’ 20” 10-3/4” 1 3 4 7-5/8” 5-1/2” 2 A11 A10 A8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / H40 / Drive pipe 19.124” Surf 48' 10-3/4” Surface 32.75# / H-40 / STC 10.192” Surf 1,195’ 7-5/8” Production 26.4 # / J-55 / LTC 6.969” Surf 4,417’ TUBING DETAIL 5-1/2" Tubing 17# / L-80 / Hydril 511 4.892” Surf 3,905’ JEWELRY DETAIL No Depth Item 1 4,009’ – 4,055’ Cement Plug 2 3,928’ Baker Model D Packer 3 3,906’ Cement Retainer 4 3,649’ – 3,742’ Owen Stackable Casing Patch (w/ isolation squeeze 28 bbl 15.8# cmt) ~3,500’ TOC (7-5/8” Casing, CBL) 3,091’ TOC (5-1/2” Casing, Calculated) OPEN HOLE / CEMENT DETAIL 10-3/4" Cmt w/ 800 sks 7-5/8" Cmt w/ 550 sks (original hole size 9-7/8”) 5-1/2” Cmt w/ 100 sks of class G (6 bbls lost during cementing) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Pool 3 Sterling 3,576’ 3,578’ 3,508’ 3,510’ 2 12/81 Isolated Sterling A8 3,593’ 3,618’ 3,523’ 3,547’ 25 12/81 Isolated Sterling A10 3,661’ 3,736’ 3,589’ 3,663’ 75 12/81 Isolated Sterling A11 3,756’ 3,802’ 3,682’ 3,727’ 46 12/81, 01/06 Open Pool 3 Sterling 3,808’ 3,810’ 3,733’ 3,735’ 2 12/81 Isolated Longstring Perfs Isolated B-3 3977'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (covered with fill) 4072'-4102' (covered with fill) 4128'-4160' (covered with fill) B-4 4162'-4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 4307'-4329' (Sqzd 11/23/81) 4361'-4363' (Sqzd 11/21/81) 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,453'3,814' Casing Collapse Structural Conductor Surface 840psi Intermediate Production 2,890psi Liner 6,390psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 20, 2020 3,904'3,904' N/A 3,827' 4,417' Perforation Depth MD (ft): See Attached Schematic 4,417' 5-1/2" 4,330'7-5/8" 20" 10-3/4" 48' 1,195'1,820psi 48' 1,189' 48' 1,195' N/A TVD Burst N/A 4,140psi MDLength Size CO510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 165-008 50-133-10092-00-00 KENAI UNIT (KU) 21-07 Kenai Gas Field / Sterling Gas Pool 3 COMMISSION USE ONLY Authorized Name: 7,740psi Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 4,366'3,904'3,827'~1111 3,904'; 4,009' Baker "D" Pkr; N/A 3,928' MD / 3,850' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:40 pm, Sep 14, 2020 320-378 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.14 14:27:40 -08'00' Taylor Wellman Perforate Plug Perforations N2 X gls 9/17/20 patch tubing DSR-9/15/2020 10-404 DLB 09/15/2020 Comm q 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 Well Prognosis Well: KU 21-07 Date: 09/02/2020 Well Name: KU 21-07 API Number: 50-133-10092-00-00 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: 165-008 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: ~ 1,445 psi @ 3,337’ TVD (Based on normal gradient) Max. Potential Surface Pressure: ~ 1,111 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Brief Well Summary KU 21-07 was drilled and completed as a dual string to the Sterling formations in pools 5.1 and 5.2 in 1965 by Union Oil Company. In 1982, water production from Pool 5.2 led to a workover to abandon Sterling pool 5.2 and recomplete as another dual string in pool 5.1. In 2004, a workover recompleted the well to a 5-1/2” monobore Sterling Pool 3 producer. The well cum’d just under 115 BCF before it was shut-in in 2014. In January 2020, in prep for possible perf add to the Upper Sterling zones, an MIT was performed and failed. On 9/1/2020, a poor boy leak detection log (injection/temp survey) was run to help identify the culprit of the failed MIT showing a hole @ 850’ in the tbg. The purpose of this work is to pinpoint the leak depth in the tubing, run a patch across the leak, perform an MIT- IA, set a plug and dump cement above the existing perf intervals, and add new perfs in the Sterling A5 and A6 sands. Notes Regarding Wellbore Condition x The well is currently shut-in x Minimum ID is 4.992” x Last tag @ 3,748’ KB w/ 2.80” GR on 9/1/2020 Safety Concerns x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). x Ensure all crews are aware of stop job authority. E-Line Procedure 1. MIRU pump truck. Rig up to be able to pump down the IA with the tubing shut in. Fluid will travel from the IA into the tubing and then be injected into the formation. 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 3. RIH with junk basket / gauge ring and drift for patch assembly. 4. MU BHA including gr / ccl / spinner / temperature / pressure a. Begin pumping down the IA b. Monitor WHP while pumping, do not exceed 1250 psi WHP once you catch fluid Well Prognosis Well: KU 21-07 Date: 09/02/2020 c. Make a down pass from surface to PBTD while pumping. Follow that with an up pass to surface while continuing to pump. Contact operations engineer with results to determine if any additional passes are required. Spinner overlays should clearly indicate position of leak near 850’. 5. RIH with 5-1/2” x 7” x 25’ patch assembly and patch across leak. 6. Perform MIT-IA to 1500 psi for 30 minutes and chart results. 7. RIH with RIH GPT tool and find fluid level. Fluid will most likely be way above the depth of the new perfs, MIRU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 8. RIH and set spiral plug at ~3,530’. 9. Make dump bailer runs to place beads and 35’ of cement on top of plug. 10. WOC - check samples. 11. RIH and perforate the following intervals: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling A5 +3,400' +3,414' +3,337' +3,351' +14' Sterling A6 +3,440' +3,450' +3,376' +3,386' +10' a. Trap 1100 psi on tubing before perforating first run (A6). Contact operations engineer for shut-in / flowing instructions on next run (A5). 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 (Trudi Hallett), and Geologist (Ben Siks) for confirmation. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Sterling 3 Gas Pool based on Conservation Order No. 510A. 12. RD e-line and pumpers. 13. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) New perfs. (Produced water?) Sand Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Sterling A5 +3,400'+3,414'+3,337'+3,351'+14' Sterling A6 +3,440'+3,450'+3,376'+3,386'+10' Patch MIT-IA plug perfs 3530 ft (forward MIT chart to AOGCC by email) LDL N2 displace _____________________________________________________________________________________ Updated by CMT 1-16-2020 SCHEMATIC Kenai Gas Field Well: KU 21-07 Last Completed: 05/2004 PTD: 165-008 TD = 4,453’ PBTD = 3,906’ 20” 10-3/4” 1 3 4 7-5/8” 5-1/2” 2 A11 A10 A8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / H40 / Drive pipe 19.124” Surf 48' 10-3/4” Surface 32.75# / H-40 / STC 10.192” Surf 1,195’ 7-5/8” Production 26.4 # / J-55 / LTC 6.969” Surf 4,417’ TUBING DETAIL 5-1/2" Tubing 17# / L-80 / Hydril 511 4.892” Surf 3,905’ JEWELRY DETAIL No Depth Item 1 4,009’ – 4,055’ Cement Plug 2 3,928’ Baker Model D Packer 3 3,906’ Cement Retainer 4 3,649’ – 3,742’ Owen Stackable Casing Patch (w/ isolation squeeze 28 bbl 15.8# cmt) ~3,500’ TOC (7-5/8” Casing, CBL) 3,091’ TOC (5-1/2” Casing, Calculated) OPEN HOLE / CEMENT DETAIL 10-3/4" Cmt w/ 800 sks 7-5/8" Cmt w/ 550 sks (original hole size 9-7/8”) 5-1/2” Cmt w/ 100 sks of class G (6 bbls lost during cementing) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Pool 3 Sterling 3,576’ 3,578’ 3,508’ 3,510’ 2 12/81 Isolated Sterling A8 3,593’ 3,618’ 3,523’ 3,547’ 25 12/81 Isolated Sterling A10 3,661’ 3,736’ 3,589’ 3,663’ 75 12/81 Isolated Sterling A11 3,756’ 3,802’ 3,682’ 3,727’ 46 12/81, 01/06 Open Pool 3 Sterling 3,808’ 3,810’ 3,733’ 3,735’ 2 12/81 Isolated Longstring Perfs Isolated B-3 3977'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (covered with fill) 4072'-4102' (covered with fill) 4128'-4160' (covered with fill) B-4 4162'-4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 4307'-4329' (Sqzd 11/23/81) 4361'-4363' (Sqzd 11/21/81) hole in tubing at 850 ft TOC approx 3300 ft. _____________________________________________________________________________________ Updated by TCS 9-2-2020 PROPOSED SCHEMATIC Kenai Gas Field Well: KU 21-07 Last Completed: 05/2004 PTD: 165-008 TD = 4,453’ PBTD = 3,906’ 20” 5 A6 10-3/4” 1 3 4 A5 7-5/8” 5-1/2” 2 A11 A10 A8 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / H40 / Drive pipe 19.124” Surf 48' 10-3/4” Surface 32.75# / H-40 / STC 10.192” Surf 1,195’ 7-5/8” Production 26.4 # / J-55 / LTC 6.969” Surf 4,417’ TUBING DETAIL 5-1/2" Tubing 17# / L-80 / Hydril 511 4.892” Surf 3,905’ JEWELRY DETAIL No Depth Item 1 4,009’ – 4,055’ Cement Plug 2 3,928’ Baker Model D Packer 3 3,906’ Cement Retainer 4 3,649’ – 3,742’ Owen Stackable Casing Patch (w/ isolation squeeze 28 bbl 15.8# cmt) 5 ~3,550’ TTP w/ 35’ of cement on top 6 ~950’ 3-1/2” x 5-1/2” x 25’ Patch (minimum ID 2.992” Installed x/x/2020) 3,530’ TOC (7-5/8” Casing, CBL ran 6/13/1965) 3,300’ TOC (5-1/2” Tubing, CBL ran 5/16/2005) OPEN HOLE / CEMENT DETAIL 10-3/4" Cmt w/ 800 sks 7-5/8" Cmt w/ 550 sks (original hole size 9-7/8”) 5-1/2” Cmt w/ 100 sks of class G (6 bbls lost during cementing) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Pool 3 Sterling 3,576’ 3,578’ 3,508’ 3,510’ 2 12/81 Isolated Sterling A5 ~3,400’ ~3,414’ ~3,337’ ~3,351’ ~14 TBD Proposed Sterling A6 ~3,440’ ~3,450’ ~3,376’ ~3,386’ ~10 TBD Proposed Sterling A8 3,593’ 3,618’ 3,523’ 3,547’ 25 12/81 Isolated Sterling A10 3,661’ 3,736’ 3,589’ 3,663’ 75 12/81 Isolated Sterling A11 3,756’ 3,802’ 3,682’ 3,727’ 46 12/81, 01/06 Open Pool 3 Sterling 3,808’ 3,810’ 3,733’ 3,735’ 2 12/81 Isolated Longstring Perfs Isolated B-3 3977'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (covered with fill) 4072'-4102' (covered with fill) 4128'-4160' (covered with fill) B-4 4162'-4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 4307'-4329' (Sqzd 11/23/81) 4361'-4363' (Sqzd 11/21/81) MIT-IA 1500 psi Eline set tubing patch STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Gas Field, Sterling Gas Pool 3, KU 21-07 Permit to Drill Number: 165-008 Sundry Number: 319-577 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w-aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jeremy M. Price Chair DATED thisI day of January, 2020. RBDMS«✓ JAN' 2 41020 STATE OF ALASKA DEC 18 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A®GC C 20 AAC 2K 0on 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 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: N2 2 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development Q Stratigraphic6. ❑ Service ❑ 165-008 3. Address: 3800 Centerpoint Drive, Suite 1400 API Number: Anchorage, Alaska 99503 50-133-10092-00-00 ' 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 Q r KENAI UNIT (KU) 21-07 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028142 Kenai Gas Field / Sterling Gas Pool 3 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): 4,453' 4,366' 3,904' 3,827' —1,125 3,904';4,009' 3,814' Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 20" 48' qg Surface 1,195' 10-3/4" 1,195' 1,189' 1,820 psi 840 psi Intermediate Production 4,417' 7-5/8" 14,417' 4,330' 4,140 psi 2,890 psi Liner 3,904 5-1/2" 3,904' 3,827' 7,740 psi 6,390 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:ing Tub 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): Baker "D" Pkr; N/A 3,928' MD / 3,850' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 11 Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 24th, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Christina Twogood Authorized Name: Bo York 777-8345 Contact Email: ctwogood@hilcorp.com Authorized Title: Operations Manager Contact Phone: 777-8443 1� Authorized Signature: Date: I " r�t , 1 -1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 11 Test Mechanical Integrity Test Q Location Clearance ❑ dBOP �© Other: i r — �O1 't*� i s-�c? �+5:, l �C� �7a,,,.64-4"7`46') ,BDMS-(r`J JAN 2 4 202 Post Initial Injection MIT Req'd? Yes 0 No ❑- / Spacing Exoe tion Required? Yes Q No [g Subsequent Form Required: I 0 -- Ll ©g b Approved by: COMMISSIONER THE COMMISSIONAPPROVEDBY Date: F 10-403 R.1 4W/2� �� Approved ap licat®i li� tpr711 r nsyt the date of a ov I. Submit Form and V /rill tt�� j�� Attachments in Duplicate i,E+ P/114 '!!. 1 -2-h e7 %l d Well Prognosis Well: KU 21-07 Date:12/12/2019 Well Name: KU 21-07 API Number: 50-133-10092-00-00 Current Status: Shut -In Gas Producer Leg: N/A Estimated Start Date: December 241h, 2019 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 165-008 First Call Engineer: Christina Twogood (907) 777-8443 (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 (C) AFE Number: Current BHP: Max. Expected BHP (new perfs): Max. Expected BHP (existing perf): Max. Potential Surface Pressure: Brief Well Summary "' 100 psi @ 3,696' TVD 1,458 psi @ 3,337' TVD -1,550 psi @ 3,547' TVD "' 1,195 psi (Calculated from Static BHP Survey on 1/7/2014) (Based on normal gradient) (Based on normal gradient) (Based on expected BHP with existing perf and gas gradient to surface (0.10psi/ft)) In 1965, KU 21-07 was drilled and completed as a dual string to the Sterling formations in pools 5.1 and 5.2 by Union Oil Company. In 1982, water production from Pool 5.2 led to a workover to abandon Sterling pool 5.2 and recomplete as another dual string in pool 5.1. In 2004, a workover recompleted the well to a 5-1/2" monobore Sterling 3 producer. The well was shut-in in 2014. The purpose of this work/sundry is to set a CIBP above the existing pert intervals and add new perfs in the Sterling AS and A6 sands. Notes Regarding Wellbore Condition • The well is currently shut-in. • Minimum ID is 4.992". • Last tag @ 3,814' KB w/ 2.75" GR on 1/23/2014. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. K tIileorp Alwka, Lb E -Line Procedure C (�('L ` K' I ) MIT- (11 -/Z) IjvD P{� 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Well Prognosis Well: KU 21-07 Date: 12/12/2019 Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RIH with 5-1/2" CIBP and set at±3,530'. Dump bail 35' of cement on top. POOH. S. RU pert guns. 6. RIH and perforate the following interval: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling AS +3,400' +3,414' +3,337' +3,351' +14' Sterling A6 +3,440' +3,450' +3,376' +3,386' +10' a. Pressure up well to 1240 psi before perforating. 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling 3 Gas Pool based on Conservation Order No. 510A. 7. POOH. 8. RD a -line. 9. Turn well over to production. (Test SSV with -in 5 days of stable production on well - notify AOGCC 24hrs before testing) E -line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 3. RIH and set 5-1/2" Casing Patch or set 5-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure- N2 Operations Hilcorp Alaska, LLC Recompletion: 5-1/2", 17ppf, L-80 Hydrill 511 Cmt w/ 100 sx 15.8ppg Class G (full returns) KU 21-7 Kenai Gas Field Pad 14-6 PROPOSED SCHEMATIC 20"'94#, H-40 Drivepipe @48' 10-3/cesing 5", H-40, STC @ 1195'Cmt x spf) 3682'-3727' 3808'-3810' block sqz ('82) Baker Cement Retainer @ 3904' MD / 3827' TVD (5/29/02) Baker Model D packer @ 3928' Plug 4009'-4055'(11/14/97) 7-5/8" 26.4 ppf, J-55, LTC Casing4417' 9- Cmt w/ 550 sx (original hole size N') Updated by TRH 11Dec2019 KU 21-7 Kenai Gas Field Pad 14-6 squeeze w/ 28bb1 15.8ppg cement. Recompletion: 5-1/2", 17ppf, L-80 Hydrill 511 Cmt w/ 100 sx 15.8pp Class G (full � ? Pool �- M �n�n+oM 20", 94#, Drivepipe S1 ' , %76%11-1-40, 75 ,1H-40 , as@ 195' /800sx 3 perforations (12/81) 3576'-3578' block sqz ('82) MDs TVDs spf)-4523' 3547' isolated sqz 10/04 1 3756'-3802' (6 spf) 3682'-3727' \N81 0' block sqz ('82) Baker 3978'-3988'(8/16/81) 3991'-4022' (Cmt plug@ 01109') Baker Model D pac r @ 3928' 4036'-4048' (so. w/ cmtplug) 4056'-4070' (covered v/ith fill) 4072'-4102' (covemd:with fill) Cement Plug 4009'-405 ' (11/14/97) 4128'-4160' (covered with fill) B-4 4162'4172' (cove d with fill) 4180'-4202' (cov ed with fill) 11/ B-5 4256'-4260'(S d 18/81) 4307'-4329' ( zd 11/23/81) 4361'-4363' qzd 11/21/81) 7-5/8" 26/4 ppf, J-55, LTC Casing @_4417' Cmt w/ 550 sx (original hole size 9--7/8") H n.,p Alaeks. LL( TD = 4,453' PBTD = 3,906' SCHEMATIC CASING DETAIL Kenai Gas Field Well: KU 21-07 Last Completed: 05/2004 PTD: 165-008 Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94#/H40/ Drive pipe 19.124" Surf 48' 10.3/4" Surface 32.75#/H40/STC 10.192" Surf 1,195' 7-5/8" I Production 26.4#/J-55/LTC 6.969" Surf 4,417' TUBING DETAIL 5-1/2" Tubing 17#/L-80/Hydri1511 4.892" Surf 3,905' JEWELRY DETAIL No Depth Item 1 4,009'-4,055' j Cement Plug 2 3,928' Baker Model D Packer 3 3,906' Cement Retainer 4 3,649'-3,742' 1 Owen Stackable Casing Patch (w/ isolation squeeze 28 bbl 15.8# cmt) Isolated -3,500' TOC (7-5/8" Casing, CBL) 3,618' 3,091' TOC 15-1/2" Casing, Calculated) OPEN HOLE/ CEMENT DETAIL PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btm (ND) FT Date Status Pool 3 Sterling 3,576' 3,578' 3,508' 3,510' 2 12/81 Isolated Sterling AB 3,593' 3,618' 3,523' 3,547' 25 12/81 Isolated Sterling A30 3,661' 3,736' 3,589' 3,663' 75 12/81 Isolated Sterling All 3,756' 3,802' 3,682' 3,727' 46 12/81,01/06 Open Pool 3Sterling 3,808' 3,810' 3,733' 3,735' 2 12/81 Isolated Lonastdnc Peds Isolated B3 3977'-0022'(10/15/97) 3978'-3988'(8/16/81) 3991'-4022' (Curt plug @ 4009') 4036'-0048' (Iso. w/ curt plug) 4056'-0070' (covered with fill) 4072'4102' (covered with fill) 4128'-4160' (covered with fill) BA 4162'-4172' (covered with Till) 4180'-4202' (covered with fill) BS 4256'-4260' (Sgzd 11/18/81) 4307'-4329' (Sgzd 11/23/81) 4361'-4363' (Sgzd 11/21/81) Updated by CMT 1-16-2020 M, PROPOSED SCHEMATIC TD=4,453' PBTD=3,906' CASING DETAIL Kenai Gas Field Well: KU 21-07 Last Completed: 05/2004 PTD: 165-008 Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94#/H40/Drive pipe 19.124" Surf 48' 10-3/4" Surtace 32.75#/H-40/STC 10.192" Surf 1,195' 7-5/8" Production 26.4#/J-55/LTC 6.969"1 Surf 4,417' TUBING DETAIL 5-1/2" Tubing 17#/L-80/Hydri1511 1 4.892" 1 Surf 1 3,905' JEWELRY DETAIL No Depth Item 1 4,009'-4,055' Cement Plug 2 3,928' Baker Model D Packer 3 3,906' Cement Retainer 4 3,649' —3,742' Owen Stackable Casing Patch (w/ isolationsqueeze 28 bb115.8# cmt) 5 +3,530' Cement Retainer w/ 35'of cement on top "3,500' TOC (7-5/8" Casing, CBL) 3,091' TOC (5-1/2" Casing, Calculated) W OPEN HOLE/ CEMENT DETAIL 10-3/4" Cmt w/ 800 sks 7-5/8" Cmt w/ 550 sks (original hole size 9-7/8") 5-1/2" Cmt w/ 100 sks of class G (6 bbls lost during cementinet PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Pool3 Sterling 3,576' 3,578' 3,508' 3,510' 2 12/81 Isolated Sterling AS SD Proposed Sterling A6 ± , Tan Proposed Sterling AB 3593' 3,547' 25 12/81 Isolated Sterling A10 3,661' M3,802'3,682' 3,663'12/81 Isolated Sterling All 3,756' 3,727' 46 12/81,01/06 Open Pool3 Sterling 3,808' 3,735' 2 12/81 Isolated 3978'-3988'(8/16/81) 3991'4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (wvered with fill) 4072'-4102' (covered with fill) 4128'-4160' (covered with fill) 84 4162-4172' (covered with fill) 4180'-4202' (wvered with fill) B-5 4256'-4260'(Sgzd 11/18/81) 4307'-4329' (Sgzd 11/23/81) 4361'-4363' (Sgzd 11/21/81) Updated by CMT 1-16-2020 IA, Upper Swab Lower Swab Updated by CMT 1/16/2020 KU 21-07 Wellhead Drawing Wing Surface Safety Valve STANDARD WELL PROCEDURE nuw»rp:ilaka,LIA NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vi Page 1 of 1 • • Marathon Oil Company Alaska Asset Team Marathon ~~~;~ h` ~r~~~ ~;; KeOnaB AK 99611 MARATHON 0~~ COmpany ~~1~'~~'~~" ~~~ Telephone 907/283-1371 ~AY ~ ~ 200$ Fax 907/283-1350 d~~v b~ ~i0f1S• ~`i0i°11`P~1 ~ f a :~b~S~~ o!b ~ ~~ ~I/ May 15, 2008 ~nchor~~ ~ Mr. Tom Maunder --~~~S~qQ ~~~~~ ~~~~ Alaska Oil & Gas Conservation Commission ~~ ` 333 W 7th Ave ~ ~ (`" ~ ~~` ' '~~,,~ ,~ Anchorage, Alaska 99501 9~~ ~L-`A~~i ~'~~ ~ 5 Reference: 10-404 Sundry Submittal List ~~ ~ ~~~~ ~.~C~~~ ~5~ ~4J ~~' ~o ~..p°~ ~~-5~~~ r.~cccJr~eJ~+~~'~-~ Dear Mr. Maunder. c~c.~- ~e~ ~ v~o r-j ~- c~.~~ ~~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to ~/ ,~- ~ P P 9 close out 10-403 Sundry approved well work activities. Work has been ongoing to `~'~~'~`~ identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a(ist of the completed reports along with the indicated 10-4Q4 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, '~~ ~ Kevin J. Skiba Engineering Technician ~.~~ ~~~~~~:~ ~ ~~ ~;~ ~~ _~ ~ ~"1t~~ Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon MARATHON Oil Company January 23, 2008 ~~.~~~~~.~ C~A~ ~. ~ ci;(~'~ • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder Qii ~ G~s ~:or,~. ~orrErr~4ssti~r~ Alaska Ohl & Gas Conservation Cc~~`~sion An~~Qrage 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: KU 21-7 Dear Mr. Maunder: Attached for your records is the 10-404 sundry report for well KU 21-7. This work is covered under sundry #302- 138. We removed the original dual 2-7/8" tubing strings and the dual packer; we left the single D packer in the well. A packer-less string of 2-7/8" jointed pipe was added as a velocity string. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~ Wayne E Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operation Summary Kenai Well File Current Well Schematic KJS KDW L~~~ ~~~ ~ 0 y a~ ~ STATE OF ALASKA S°'~~ ~~ ~ ~~ ALA~OIL AND GAS CONSERVATION COMM~ON ~~~ ~~ L~~~ REPORT OF SUNDRY WELL OPER~,~~~j ~& Gas Cons• ~ommiSSiora Anchorage 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ Install PerFormed: Alter Casing ~ Pull Tubing Q Perforate New Pool [] Waiver~ Time Extension ~ Velocity " Change Approved Program ~ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well [] String 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: rvame: Marathon Oil Company Development ~^ Exploratory^ 165-008 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-10092-00-00 7. KB Elevation (ft): 9. Well Name and Number: 8T KU 21-7' 8. Property Designation: - 10. Field/Pool(s): FED A- 028412 Kenai Gas Field / Sterling Pool 3 11. Present Well Condition Summary: Well was recompleted with a single 2 7/8" string of tubing installed as velocity string Total Depth measured 4,453 - feet Plugs (measured) Cement Plug @ 4009' - 4055' true vertical 4,366 - feet Baker Cement Retainer @ 3904' Effective Depth measured 3,904 feet Junk (measured) N/A true vertical 3~gy~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 4g' 20" 48' 48' SurFace 1195' 10-3/4" 1195' 1189' 1820 psi 840 psi Intermediate Production 4q17' 7-5/8" 4417' 4330' N/A N/A Liner Perforation depth: Measured depth: 3593' - 3802' True Vertical depth: 3523' - 3727' Tubing: (size, grade, and measured depth) 2-7/8" L-80 3688' Packers and SSSV (type and measured depth) Baker model "D" aacker 3928' 12. Stimulation or cement squeeze summary: Intervais treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 3,300 N/A N/A N/A Subsequent to operation: 0 N/A N/A N/A N/A 14. Attachments: 15. W ell Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~^ Service ~ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exem t: 302-138 Contact Kevin Skiba (907) 283-1371 Printed Name W ne E. Cissell Title Well Work Over Supervisor Signature Phone (907) 283-1308 ~~~.'~ Date 1/23/2008 Form 10-404 Revised 04/2006 "~~~! ~i"t~, ,;Ul_ `~ ~ 2~~~ Submit Original Only ~ • Marathon Oil Company Page ~ of 3 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Weil Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 4/30/2002 End: 5/30/2002 Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To J Hours J Code I Code I Phase ~ Description of Operations ~ ~ 4/30/2002 08:00 - 12:00 12:00 - 12:15 12:15 - 12:25 12:25 - 13:15 13:15 - 13:20 13:20 - 14:30 14:30 - 15:15 15:15 - 15:45 15:45 -17:00 5/1/2002 08:00 - 09:30 09:30 - 09:45 09:45 - 10:00 10:00 - 13:00 5/21 /2002 18:00 - 06:00 5/22/2002 06:00 - 00:00 5/24/2002 12:00 - 06:00 5/25/2002 06:00 - 03:00 03:00 - 04:30 04:30 - 06:00 5/26/2002 06:00 - 10:00 10:00 - 11:00 11:00 - 12:00 12:00 - 14:30 14:30 - 17:30 17:30 - 20:30 5/27/2002 20:30 - 21:00 21:00 - 21:30 21:30 - 05:00 05:00 - 06:00 06:00 - 06:30 4.00 RURD_ SLIK 0.25 TEST_ EQIP 0.17 RUNPU EQIP 0.83 CUT_ TBG_ 0.08 TRIP_ TOOL 1.17 RURD SLIK 0.75 fZUNPU EQIP 0.50 MILL FISH 1.251 RURD I SLIK 1.50I RURD ~ EQIP 0.25 SAFETY SMTG 0.25 TEST_ EQIP 3.00 CIRC_ MUD_ 12.00 RURD_ RIG 18.00 RURD RIG 18.00 RURD_ RIG_ 21.00 RURD RIG_ 1.50 NUND UBOP 1.50 4.00 CIRC_ MUD_ 1.00 ~ CIRC_ ~ MUD_ 1.00 CIRC_ MUD_ 2.50 CIRC MUD_ 3.00 ~ MILL_ ~ FISH 3.00 ~ CIRC_ ~ MUD_ WBPREP Get wk permit from operator. Meet w/ crews WBPREP P-test w/ well fluids. Test good WBPREP RIH to packer at 3928'. CMPPUL Correlate to packer and sliding sleeve. Cut tubing @ 3915'. CMPPUL POOH. Prepare for radio silence at surface. CMPPUL At surface. RD lubricator from long string. CMPPUL RIH to sliding sleeve at 3509'. CMPPUL Correlate and shoot circulation holes at 3533'-3535'. POOH. All shots fired. CMPPUL Bring on pad communications. Begin RDMO. Off location CMPPUL Get wk permit from operator. Begin RU BJ Services. Notice KCI water was delivered to wrong tank (flowback). RU to pull off of flowback tank. Vac truck with HEC (kill fluid) on location w/ pill mixed at rig. CMPPUL PJSM. CMPPUL Fill surface lines. Pressure up to 200 psi. Check lines. Spot leak. Bleed down and tighten connection. Pump up to 1250 psi. Good hold. Finish test to 200 psi. Test good. Open wellhead to pump. CMPPUL Begin pumping HEC - 3bpm. Pump away 30bb1. Ppump-Opsi Q-3.5bpm. Swap to KCL MIRU RDMO Glacier Drilling Rig 1 from KTU 32-7H MIRU Moving rig. Rig off moving rate at 00:00 hrs, 5/22/2002 for scheduled rig maintenance. MIRU Finish scheduled rig maintenance @ 12:00 hrs, 5/23/2002. MIRU drilling rig. Notify AOGCC & BLM for BOP test. MIRU Finish RU drilling rig. WBPREP SICP 270 psi. Install lubricator on long string. Retrieve BPV. lS SITP 270 psi. Dry rod retrieve BPV in short string. ST SITP 0 psi. WBPREP Install bales. Clean floor while analyzing pressures & kill weight fluid. WBPREP RU on SS. Pump 16 bbls, string on vacuum, SD. Mix 40 bbl HEC pill, pump pill & chase w/ 5 bbl 3% KCI. Max pressure 470 psi. Stop pumping, pressure went to 0 psi. String on vacuum. SI SS. 61 bbls pumped into formation. WBPREP RU on LS. Bleed annulus to 0 psi. Gas at surFace. No pressure decrease on LS. WBPREP Monitor well pressures. LS SITP 270 psi, SS SITP 0 psi , SICP 0 psi. CMPPUL RU on LS. Bleed LS to 0 psi. Gas at surface. Monitor well pressures while WO perforators. CMPPUL RU wireline truck. PJSM. RIH w/ 1-11/16" tubing punch & CCL. Run strip log, correlate & perforate 8 holes f/ 3472' - 3474' WL depth. RD loggers. CMPPUL RU on LS to circulate. Pump 20 bbls, no communication w/ annulus, string on vacuum, SD. Mix 40 bbl HEC pill, pump pil & chase w/ 4 bbls 3% KCI. Max pressue 1125 psi. Stop pumping, pressure went to 0 psi. String on vacuum. SI LS. 64 bbls pumped into formation. Well dead. Check LS, SS & annulus, none on vacuum, 0 psi all around. 0.50 NUND DTRE CMPPUL Install BPV in LS & SS. 0.50 NUND DTRE CMPPUL ND production tree. Inspect hanger threads OK. 7.50 NUND UBOP CMPPUL NU BOPE. 1.00 NUND UBOP CMPPUL Install 2-7/8" dual rams. 0.50 RUNPU WBSH CMPPUL Pull BPV's in both strings. Install two way check valves in both strings for testing BOPE. Printed: 1/7/2008 229:42 PM • • Marathon Oil Company Page 2 of 3 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 29-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 4/30/2002 End: 5/30/2002 Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 5/27/2002 06:30 - 09:30 3.00 TEST EQIP CMPPUL RU & test BOPE. Test dual pipe rams blind rams, kill & choke line 09:30 - 10:00 0.50 RUNPU WBSH CMPPUL 10:00 - 12:00 2.00 CIRC MUD CMPPUL 12:00 - 14:00 2.00 CIRC MUD_ CMPPUL 14:00 - 17:30 3.50 RURD EQIP CMPPUL 17:30 - 22:00 4.50 RUNPU EQlP CMPPUL 22:00 - 06:00 8.00 RUNPU TBG CMPPUL 5/28/2002 06:00 - 21:00 15.00 RUNPU TBG CMPPUL 21:00 - 22:30 1.50 RURD EQIP CMPPUL 22:30 - 23:30 1.00 NUND UBOP CMPPUL 23:30 - 00:00 0.50 NUND UBOP CMPPUL 00:00 - 01:30 1.50 NUND UBOP CMPPUL 01:30 - 06:00 4.50 CLNOU PLUGAB 5/29/2002 06:00 - 08:00 2.00 CLNOU PLUGAB 08:00 - 09:00 1.00 SLPCUT DLIN PLUGAB 09:00 - 12:00 3.00 CLNOU PLUGAB 12:00 - 14:30 2.50 SETREL PKR PLUGAB 14:30 - 17:00 2.50 PUMP CMT PLUGAB 17:00 -17:30 0.50 SETREL PKR_ PLUGAB 17:30 - 19:30 2.00 SETREL PKR PLUGAB 19:30 - 21:30 2.00 NUND DBOP PLUGAB 21:30 - 02:00 4.50 NUND UwLH PLUGAB 02:00 - 04:30 2.50 NUND UBOP PLUGAB 04:30 - 05:00 0.50 TEST EQIP PLUGAB 05:00 - 05:30 0.50 RUNPU WBSH PLUGAB 05:30 - 06:00 0.50 SETREL PKR PIUGAB 5/30/2002 06:00 - 10:30 4.50 PULD DP PLUGAB 10:30 - 14:30 4.00 PULD DP CMPRUN 14:30 - 20:30 6.00 RUNPU TBG CMPRUN ~ valves, choke manifold valves 1-12, top drive valves, dart valve & 2 safety valves to 250 psi low/3000 psi high, OK. RD. Pull two way check valves. Both strings on vacuum. Took +/-60 bbls to fill hole. Mix 60 bbis Flovis pill while monitoring well. Hole took +/_35 bbls while mixing pill. RU on LS. Pump 30 bbl Flovis pill (had circulation up ST). Install BPV in ST. Finish pump pill. Chase pill w/ 12 bbis 3% KCI. 42 bbls fluid in hnn. Max pressure 585 psi. Remove BPV. RU on ST. Instal! BPV in LS. Pump 30 bbls Flovis pill. Chase pill w/ 8 bbls 3% KCI. 38 bbls in fmn. Max pressure 860 psi. Remove BPV. Bleed casing annulus pressure (150 psi). Hole standing full, all strings dead. RU tubing tools. Install landing joints. Back out lock down lugs. Work pipe from 150K Ibs to 205K Ibs string pull w/ no success. RU wireline unit. RIH w/ freepoint tool. Tool indicates pipe movement below dual packer. Pull 220K Ibs, pull packer free. Work pipe. POOH w/ wireline. RD wireline unit. Pull dual tubing hanger, LD same. Fill trip tank, make up safety valves. PJSM. POOH LD 2-7/8" tubing. POOH LD 2-7/8" tubing dual string. LD pkr. Change tongs, elevators & slips to singles. FPOOH w/ LS 2-7/8" tubing. RD casing crew, LD long bales. Change dual rams to VBR's (2-7/8" - 5-1/2"). MU test joint, install test plug. Test BOPE. Test annulur preventer & VBR's to 250 psi low/3000 psi high, OK. Make scraper run to top of LS cut @ 3915' WL depth. MU bit & scraper. Rack, strap & rabbit 4" DP while PU & TIH. +/-1800' in hole @ rpt time. FTIH w/ biUscraper. Tag top of tubing cut @ 3908' DP msmt. Slip & cut drilling line. POOH w/ biUscraper. LD same. MU cement retainer & TIH to 3908' DP msmt. Set retainer @ 3906'. PBTD 3904' DP msmt. RU cementing lines. PJSM. Test surface lines to 3500 psi. Unable to breakdown formation. Maximum pressure 3245 psi. Pressure up to 3165 psi & chart for 30 minutes. Final pressure 3076 psi. Bleed pressure. POOH 10 stds. MU Rl"TS tool. Set 1 joint below wellhead. ND BOP stack. Remove Cameron tubing spool. Install Vetco tubing spooi. Test seais to 2000 psi for 15 minutes. NU BOP stack. Run test plug. Close blind rams, choke manifold valve & outside kill valve. Test BOP body to 250 psi low/3000 psi high OK. Run wear bushing. Release RTTS, POOH, LD same. POOH LDDP. LD retainer setting tool. Pull wear bushing. Rack, strap & drift 136 joints 2-7/8", 6.5 ppf, L-80, 8RD EUE & 8RD EUE MOD production tubing. RU tubing tools. PJSM. PU & TIH w/ 2-7/8" completion equipment & tubing, MU tubing hanger. Land & lock down tubing hanger. Bottom Printed: 1/7/2008 229:42 PM ~ • Marathon 0il Company Page 3 of 3 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 4/30/2002 End: 5/30/2002 Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILL ING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 5/30/2002 14:30 - 20:30 6.00 RUNPU TBG CMPRUN XN nipple @ 3688', upper XN nipple @ 3593'. 20:30 - 21:00 0.50 RUNPU WBSH CMPRUN Install BPV in tubing. 21:00 - 23:00 2.00 NUND DBOP CMPRUN ND BOP. 23:00 - 00:30 1.50 NUND UTRE CMPRUN Install Vetco 11" 3M psi x 7-1/16" 3M dbl valve w/ single wing production tree. 00:30 - 01:00 0.50 TEST_ EQIP CMPRUN Test hanger seals to 3000 psi. 01:00 - 01:30 0.50 RUNPU WBSH CMPRUN Retrieve BPV, install 2 way check valve. 01:30 - 02:00 0.50 TEST_ EQIP CMPRUN Test tree to 3000 psi. Pull 2 way check valve. 02:00 - 03:30 1.50 CIRC MUD CMPRUN RU to displace tubing & annulus. Displace wellbore to 6% KCI, reverse circulate. Final pump pressure 270 psi @ 4 bpm. 03:30 - 04:00 0.50 RUNPU WBSH CMPRUN tnstall BPV in tubing. Flush & RD circulating lines. 04:00 - 06:00 2.00 NUND UTRE RDMO Clean pits. NU BOP's to single gate rams & set on rack. Release rig to Susan Dionne #3 @ 06:00 hrs, 5/30/2002. 5/31/2002 06:00 - 18:00 12.00 RURD RIG RDMO Release rig to Susan Dionne #3 @ 0600 hrs, 5/30/2002. RDMO. 6/25/2002 09:30 - 12:00 2.50 CIRC MUD_ WBPREP MIRU BJ nitrogen pumping unit onto annulus. RU to take returns off of 2-7/8" tubing. Conduct prejob safety meeting, test lines. 12:00 - 13:00 1.00 CIRC MUD_ WBPREP Circulate nitrogen down annulus, taking completion fluid returns up tubing. Continue until wellbore purged. Shut well in. RDMO nitrogen unit. Prinled: 1/7/2008 2:29:42 PM , ~ M M~w-rnoN Kenai Gas Fie KU 21-7 Pad 14-6 ~ Velocity String: 2-7/8", 6.4ppf, EUE 8rd I D=2.441 " ~ 20", 94#, H-40 Drivepipe @48' 10-3/4", 32.75", H-40, STC casing @ 1195' Cmt w/ 800 sx TOC -3500' (CBL) Pool 3 perforations (12/81) 3576'-3578' sqzd NDs A-8 3593'-3618' (8 spf) 3523'-3547' A-10 3661'-3736' (8 spf) 3589'-3663' A-11 3756'-3802' (8 spf) 3682'-3727' 3808'-3810' sqzd Baker Cement Retainer @ 3904' MD / 3827'TVD (5/29/021 Baker Model D packer @ 3928' Cement Plug 4009'-4055' (11/14/97) 7-5/8" 26/4 ppf, J-55, LTC Casing @ 4417' Cmt w/ 550 sx ). . . Alaska Region Domestic Production 4. ~ M ~ Marathon MARATHON Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 September, 25 2006 RECEIVED Winton Aubert AOGCC 333 West ¡th Ave Suite 100 Anchorage, AK 99501 OCT 0 2 ('006 Alaska Oil & Gas Coos. Commi$sion Anchorage cf 6. ~N~¿':\U \J~!i'i,~ \,1., òW~";;,- i!'.' (: t~ Dear Mr. Aubert: Attached and submitted for your records is the Form 10-404 for the completion of the Kenai Gas Field Well KU 21-7, work over·permit #304=159, on drilling permit #165-008. The Pool 3, A-8 and A-1 0 sands have been squeezed and abandoned because of water. The Pool 3, A-11 sand was re-perforated and has been producing since January 12, 2006. Also attached for your records is the current well schematic and operational history of the work performed. If you would like any other information, please contact me at 394-1308 or WECissell@marathonoil.com. S~inCerelY' ~I !' I ':, i'vLR.- / d / Wayne issell Advanced Engineering Technician Enclosures: 10-404 Completion report WBD Operational history Copy of Original Sundry Approval form I~)S- -CO~ 1"\..... \.I...., v.....""" ., I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COMM. N REPORT OF SUNDRY WELL OPERATIONS OCT 0 2 2006 1. Operations Abandon U Repair WelU Plug Perforations L:J Stimulate U Other U Performed: Alter Casing 0 Pull TubinD Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdowD Perforate 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory 0 165-008 3. Address: P. O. Box 196168, Anchorage, AK 99519- Stratigraphic 0 Service 0 6. API Number: 6168 50-133-10092-00 7. KB Elevation (ft): 9. Well Name and Number: 14' KB KU 21-7 8. Property Designation: 10. Field/Pool(s): Kenai Unit Kenai Gas Fieldl Sterling Pool 3 11. Present Well Condition Summary: Total Depth measured 4453 feet Plugs (measured) Cement retainer set at 3904' true vertical 4366 feet Junk (measured) 0 Effective Depth measured 3904 feet true vertical 3827 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 20" 48' 48' N/A N/A Surface 1195' 10-3/4" 1195' 1189' Intermediate Production 4417' 7-5/8" 4417' 4330' Liner Perforation depth: Measured depth: A-8, A-10, AND A-11 SANDS:3593'-3618', 3661'-3736', 3756'·3802' True Vertical depth: A-8, A-10, AND A-11 SANDS:3523'.3547, 3589'-3664', 3682'-3727' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Baker "0" 3928' 12. Stimulation or cement squeeze summary: The A-8 was isolated by running 5.5" casing to 3904'MD/3827' TVD. 100 sx "g" cement was squeezed Alaska Oil & Gas Cons. Commission Anchorage A-10 was squeezed after reperforating and found wet. A Owen stackable casing patch was used to isolate from the A-10 from 3649' - 3742'. The A-11 was reperforate and production was restored to the well. Treatment descriptions including volumes used and final pressure: NIA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 Subsequent to operation: 2000 125 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations x 16. Well Status after proposed work: Well bore diaQram X, Copv of Approved Sundrv 304-159 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 304-159 Contact Wayne Cissell Title Advanced Engineering Technician Signature Phone 907.283.1308 Date 9/24/2006 Form 10-404 Revised 04/2004 ORIGINAL RBDMS BFl OCT ~ 2006 Submit Original Only J 120'" 94#, H-40 ~rivePiPe @48' Kenai Gas Field KU 21 Pad 14-6 10-3/4",32.75", STC casing @ 1195' Cmt wi 800 sx Lonostrino Perfs Isolated B-3 3977'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ Gmt plug) 4056'-4070' (Govered with fill) 4072'.4102' (Govered with fill) 4128'·4160' (covered with fill) B·4 4162'.4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 4307'·4329' zd 11/23/81 Pool 3 perforations (12/81) 3576'-3578' block sqz ('82) Owen stackable casing patch ID=3.795" 3649'-3742' Isolation squeeze wi 28bbl 15.8ppg cement. Recompletion: 5-1/2", 17ppf, L-80 Hydril1511 Cmt w/1 00 sx 15.8ppg ClassG (full returns) 3808'-3810' block sqz ('82) Baker Cement Retainer @ 3904' MD I 3827'TVD (5/29/02) Baker Model D packer @ 3928' Cement Plug 4009'-4055' (11/14/97) 7-5/8" 2614 ppf, J-55, LTC Casing @4417' Cmt wi 550 sx (original hole size 9-7/8") · Marathon .Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Event Name: WORKOVER Contractor Name: Rig Name: GLACIER DRILLING Date From.. To C Sub Phase Hours . ode COde 10/3/2004 07:30 - 08:00 0.50 SAFETY MTG_ PLUGAB 08:00 - 10:00 2.00 RURD_ ELEC PLUGAB 10:00 - 10:30 0.50 RUNPU ELEC PLUGAB 10:30 - 10:40 0.17 LOG_ CSG_ PLUGAB 10:40 - 11 :00 0.33 RUNPU ELEC PLUGAB 11:00 -11:15 0.25 PULD_ EQIP PLUGAB 11:15-12:45 1.50 CUT_ WIRE PLUGAB 12:45 - 13:15 0.50 PULD - PKR_ PLUGAB 13:15 - 14:30 1.25 REPAIR EQIP PLUGAB 14:30 - 14:45 0.25 PULD - PKR - PLUGAB 14:45 - 15:00 0.25 RUNPU ELEC PLUGAB 15:00 - 15:30 0.50 PULD_ PKR_ PLUGAB 15:30 - 16:00 0.50 RUNPU ELEC PLUGAB 16:00 - 17:30 1.50 REPAIR EQIP PLUGAB 17:30 - 17:55 0.42 RUNPU ELEC PLUGAB 17:55-18:15 0.33 SETREL PLUG PLUGAB 18:15 - 18:40 0.42 RUNPU ELEC PLUGAB 18:40 - 19:15 0.58 PULD - EQIP PLUGAB 19:15 - 19:45 0.50 RUNPU ELEC PLUGAB 19:45 - 20:00 0.25 SPOT_ SAND PLUGAB 20:00 - 20:30 0.50 RUNPU ELEC PLUGAB 20:30 - 22:30 2.00 RURD_ ELEC PLUGAB 1017/2004 09:00 - 16:00 7.00 RURD_ COIL PLUGAB 10/8/2004 07:30 - 09:00 1.50 RURD_ COIL PLUGAB 09:00 - 09:30 0.50 SAFETY MTG_ PLUGAB 09:30 - 10:30 1.00 TEST_ BOPE PLUGAB 10:30 - 11 :40 1.17 RUNPU COIL PLUGAB 11 :40 - 12:30 0.83 MIX_ PILL PLUGAB 12:30 - 13:00 0.50 PUMP - CMT_ PLUGAB Page 1 of 18 Start: Rig Release: Rig Number: Spud Date: 5/25/2002 End: Group: 10/3/2004 5/30/2002 1 Description of Open:itÏons Sign in at office. Discuss procedures. Hold safety meeting. Make note of gusty wind and agree to shut down crane operations if wind becomes problematic to lifting operations. Spot trucks and rig up 5-1/2" lubricator. RIH wI CCL and 4.5" GR. Hanging up in top 15 feet of perfs 3661'-3676'. Run through until GR passes easily. Tag bottom at 3897'. Run correlation pass. POOH wI CCL-GR. At surface, break out GR and prepare to run packer. Detect short during line check. Suspect line problems as a result of SD2 line issues from previous work. Cut -3000' e-line at surface to get past bad spot. Hold safety meeting and enact radio silence. PU Weatherford 5-1/2" WRP and MU to Expro tool string including CCL and Baker 20 setting tool. Weight indicator not working. Trouble shoot and send crewmember for hydraulic replacement indicator. Install weight indicator. Confirm radio silence and PU plug, setting tool, and CCL. RIH. CCL not picking up collars. POOH. LD tool string. Swap CCL. RIH wI new CCL. Again not detecting collars. POOH. Troubleshoot CCL problem. CCL will detect about 20 collars and then quit. Problem repeated in three different CCLs. Find functional CCL and install. MU tool string and RIH. Collar detection weak, but useable. Correlate on depth and fire plug. Plug successfully set and released at 3750' (FN at 3748'). Tagged to be certain. POOH wI setting tool. LD WRP setting tool. PU 20' 3-1/2" dump bailer. Fill bai/erwith 10gal 20/40 mesh sand and silica flour (100 mesh sand). RIH wI dump bailer. Spot sand above WRP. RIH and tag at 3744' (correlated). POOH wI dump bailer Rig down electric line. Rig up BJ CTU, cement pump, and N2 pump. RU MOC flowback lines and iron through BJ choke to open top tank. Arrive at gas field. Discuss rig up and procedure. Obtain work permit. Warm up equipment and PU injector head. Hold tailgate safety and procedure meeting discussing fall protection and scaffold certification. Request scafolder to tie off and certify scaffolding. Shell test BOPs to 250/2500psí. Pressure test pumping iron to 4500psí. All tests good. Open well and RIH wI 1-3/4" CT pumping 0.4 BPM. Shut down pumps at 3700' and RIH to tag. Tag top of sand at 3755' CTM and PUH 1'. Adjust CTU measure to reflect wireline tag. Blend cement and prepare to pump pill. Pump 4bbl fresh water spacer and follow with 14 bbl16.2ppg cement. Follow cement with spacer and displace with KCI. Pump until 4bbl cement around nozzle at a depth of 3740'. PUH at 60'/min until 9bbl displaced. Begin PUH at 100'/min. CT nozzle at 3140' when flush stage at nozzle. Stop pumps. 0.50 RUNPU COIL PLUGAB POOH to surface with CT. 13:00 - 13:30 Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 2 of18 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 1 0/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Description of.Operations . Code 10/8/2004 13:30 - 14:15 0.75 CIRC_ CFLD PLUGAB At surface, close master valve. Break lubricator and change to wash nozzle. Circulate pipe volume to ensure no cement remains in CT. 14:15 - 16:45 2.50 CIRC_ CFLD PLUGAB RIH wI CT to 3000' attempting to break circulation. See no returns after 80 bbl with pump rate -450psi. Pump Biozan contaminant and RIH to 3140'. Circulate contaminant across perfs x2. 16:45-17:15 0.50 RUNPUL COIL PLUGAB Stop pumps and POOH wI CT 17:15 - 18:30 1.25 RURD_ COIL PLUGAB Rig back equipment for night. Will reattempt squeeze tomorrow. 10/9/2004 08:00 - 08:30 0.50 RURD - COIL PLUGAB Sign in, obtain work permit, warm up equipment. 08:30 - 09:30 1.00 SHOOT _ FLVL PLUGAB Have Pollard shoot fluid level. Detect top of fluid at about 3200'. 09:30 - 10:00 0.50 SAFETY MTG_ PLUGAB Hold safety and procedure meeting. 10:00 - 11 :30 1.50 TEST_ BOPE PLUGAB Shell test BOPs to 200/2500psi. Pressure up pumping iron to 5000psi. Have leak at union near inner reel valve. Make repairs and find small chunk of set cement in union. Make repairs and retest to 250/5000 psi. 11 :30 - 12:30 1.00 PUMP _ WTR_ PLUGAB Elect to circulate CT volume to tank at surface as a result of debris in real valve. Circulate 30 bbl and break lubricator to check nozzle. All clear. 12:30 - 13:15 0.75 TAG_ BOTM PLUGAB RIH tagging bottom within l' of CT marker. PUH 1ft. 13:15 - 14:35 1.33 PUMP - CMT_ PLUGAB Mix 15.8 ppg cement slurry. Fluid loss was increased slightly from yesterday. Pump at 1.4 BPM spotting cement across perfs while PUH wI CT. 14:35 - 15:00 0.42 RUNPUL COIL PLUGAB Once out of cement top, POOH wI CT to surface. 15:00 - 15:30 0.50 PUMP - WTR_ PLUGAB Close master valve and circulate pipe clear of cement. Change out CT cement nozzle for wash nozzle. 15:30 - 17:00 1.50 WAlTON CMT_ PLUGAB Wait on cement. 17:00 - 17:30 0.50 RUNPUL COIL PLUGAB Run in hole to 3000'. 17:30 - 19:00 1.50 CIRC_ CFLD PLUGAB Bgin pumping at 1 bpm in attempt to break circulation. Pump rate increasing steadily. See returns to surface. Flowback at 1 bpm. Pump Biozan gel pill at 2bpm. Run through perfs dispersing cement, then lightly tag plug and circulatex2. Getting good returns. Displace 30bbl Biozan with KCI. 19:00 - 20:00 1.00 RUNPUL COIL PLUGAB With all biozan is out nozzle, POOH pumping KCI. Returns of green cement biozan and sand (from top of plug) to tank. 20:00 - 22:00 2.00 RURD_ COIL PLUGAB At surface. Rig back CT BOPs. Secure well for night. 1 0/1 0/2004 10:00 - 13:30 3.50 RURD - SLlK PLUGAB Arrive, obtain permits, hold safety meeting and discuss job. MI PWS slickline. Use boom truck to remove tree cap from KU 31-7x to use on 21-7 for wireline operations. 13:30 - 14:15 0.75 RUNPUL SLlK PLUGAB RIH wI 4.55" gauge ring. Tag at 3638' KB. (first run on new truck. Finding SLM somewhat unreliable). POOH. 14:15 - 15:00 0.75 RUNPUL SLlK PLUGAB RIH wI 4.50" LIB. Appeared to have tagged higher at 3690' KB. POOH. 15:00 - 15:45 0.75 RUNPUL SLlK PLUGAB RIH wI 4.5" LIB again. Rag at 3640'. Did not see any distinct impression. Surface was a little gritty which may indicate presence of sand top. 15:45 - 16:30 0.75 RUNPUL SLlK PLUGAB PU 2.0" DO bailer. RIH and grab sample. Get sample of green cement mixed with gel. 16:30 - 17:00 0.50 RURD - SLlK PLUGAB RD slickline truck. 10/11/2004 09:00 - 10:30 1.50 RURD_ COIL PLUGAB Arrive at gas field. Sign in, warm up equpment. Obtain work permit. PU BOPs and injector head. 10:30 -11:00 0.50 SAFETY MTG_ PLUGAB Hold safety and procedure meeting. 11 :00 - 11 :30 0.50 TEST _ BOPE PLUGAB Pressure test BOPs and puming lines to 250/2500 & 200/4500 respectively. 11 :30 - 12:00 0.50 RUNPUL COIL PLUGAB RIH pumping .4 BPM. Increase rate to 2BPM at 3500'. Tag solid at 3665'. Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 30f18 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 10/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From -To Hours Code Sub Phase Description of Operations Code 10/11/2004 12:00 - 15:00 3.00 WASH_ FILL PLUGAB Sit and wash at 2BPM. Break through top and wash 40'. Encounter second solid tag at 3702'. Sit and wash at 2BPM wI no luck. Attempted repeated tags and circ rates to no avail. 15:00 - 15:30 0.50 RUNPUL COIL PLUGAB POOH for nozzle change. 15:30 - 16:00 0.50 PULD BHA_ PLUGAB Change wash nozzle and PU Flapper chisel nozzle. 16:00 - 16:30 0.50 RUNPUL COIL PLUGAB RIH to 3702'. 16:30 - 17:30 1.00 WASH_ FILL PLUGAB Wash past 3702' with little trouble. Wash to solid tag (suspect top of plug). CBU. See cement and sand from top of plug in returns. 17:30-18:15 0.75 MIX_ FLD - PLUGAB Set up valves to reverse circulate up CT. Refill tank with water. 18:15 - 20:30 2.25 CIRC_ CFLD PLUGAB CBU taking returns up CT. At about 1000psi tubing pressure, lost returns. POOH wI CT at 25% returns. At surface, close swab valve and circulate 40bbl water through CT. 20:30 - 21 :30 1.00 RURD - COIL PLUGAB RD CT for night. 10/12/2004 09:30 - 10:00 0.50 SAFETY MTG_ PLUGAB Sign in at office. Obtain work permit. Hold safety and procedure meeting. 10:00 - 11 :30 1.50 RURD_ SLlK PLUGAB Rig up PWS slickline truck with 5-1/2" lubricator. 11 :30 - 12:30 1.00 TAG_ BOTM PLUGAB RIH wI 4.5" LIB. Tag high at 3665'. POOH. No distinct markings on impression block. 12:30 - 13:30 1.00 RUNPUL SLlK PLUGAB RIH wI 2" bailer to grab sample of fill material. After 3 taps down, unable to PUH. Stuck at 3675' 13:30 - 00:00 10.50 WORK_ SLlK PLUGAB Work slickline with no jar or spang action. Bleed 100psi off of tubing. Pressure up on tubing from production header with 180psi. Bleed pressure in attempt to move fill with no response. 10/13/2004 00:00 - 13:30 13.50 WORK_ SLlK PLUGAB Continue to work tools on slickline. Discuss path forward and wait on slickline cutter. 10/14/2004 12:30 - 15:00 2.50 CUT WIRE PLUGAB Cut wire with Kinley crimper/cutter. 15:00 - 15:30 0.50 RUNPUL SLlK PLUGAB RIH wI LIB. Find top offilllwire at 3615' WLM. 15:30 - 17:00 1.50 RURD - SLlK PLUGAB Rig back slickline and lubricator. 10/15/2004 06:00 - 11 :00 5.00 RURD - COIL PLUGAB Sign in, hold safety meeting, obtain permit and start equipment. Rig up BJ CT. PU BOPs and 45' 4" lubricator. Hold additional safety and procedure meeting. 11:00 -12:00 1.00 PULD_ BHA_ PLUGAB PU BHA including Weatherford MHA wI DFCV and hydraulic disconnect, Bowen upldown jars, XO, BJ disconnect, circ sub, and PWS 3 prong wire grab. 12:00 - 13:00 1.00 RUNPUL COIL PLUGAB Attmempt to RIH, but keep tagging up at surface. Break connection and examine tool. One prong bent outward on the wire grab from catching on a WHA shoulder. LD fishing tool. 13:00 - 15:00 2.00 WAlTON OTHR PLUGAB Modify threads on additional Pollard tool to use as a wire grab. This tool does not have flexible prongs. 15:00 - 16:00 1.00 PULD - BHA_ PLUGAB Make up new tool and have to guide through BOPs and crossovers. Re-connect lubricator and open tree valves. 16:00 - 18:00 2.00 WORK_ COIL PLUGAB RIH to fill depth at 3628'. Attempt to work and wash with very little gain. 18:00 - 18:45 0.75 RUNPUL COIL PLUGAB POOH wI new wire grab. 18:45 - 19:30 0.75 PULD_ BHA_ PLUGAB At surface. PU 2-1/8" chiselljet nozzle with plan to RIH and wash. 19:30 - 00:30 5.00 WASH_ FILL PLUGAB RIH and wash to 3681' circulating at 2BPM. Complete perf passes x5. At one point, lose 20bbl returns. Regain circulation and continue to wash. Drop ball to shift to upward washing jets and POOH slowly. See intermittent returns. Appears to be problem with BJs injector head gooseneck 00:30 - 02:00 1.50 RURD - COIL PLUGAB Rig back for night. 10/16/2004 10:00 - 14:00 4.00 REPAIR EQIP PLUGAB Replace bent injector head frame with cage from backup injector head. Replace bent gooseneck strut. 14:00 - 15:30 1.50 REPAIR EQIP PLUGAB Work on crane. Printed: 9/26/2006 5:02:44 PM . . Page 4 of.18 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Event Name: WORKOVER Contractor Name: Rig Name: GLACIER DRILLING Date From ··-To Hours Code Sub Phase ... Code 10/16/2004 15:30 - 19:00 3.50 WAlTON EQIP PLUGAB 19:00 - 19:30 0.50 PULO - BHA_ PLUGAB 19:30 - 21 :45 2.25 WORK_ COIL PLUGAB 21 :45 - 22:00 0.25 PULD - BHA_ PLUGAB 22:00 - 23:00 1.00 RUNPUL COIL PLUGAB 23:30 - 00:00 0.50 PULD_ BHA_ PLUGAB 00:00 - 02:00 2.00 RUNPUL ANCH PLUGAB 02:00 - 03:30 1.50 PULO - BHA_ PLUGAB 03:30 - 04:30 1.00 SECURE WELL PLUGAB 10/19/2004 05:00 - 13:30 8.50 RURD - COIL PLUGAB 13:30 - 14:30 1.00 PULO_ BHA_ PLUGAB 14:30 - 15:15 0.75 TEST_ BOPE PLUGAB 15:15 - 16:00 0.75 RUNPUL COIL PLUGAB 16:00 - 18:30 2.50 REPAIR EQIP PLUGAB 18:30 - 19:30 1.00 RUNPUL COIL PLUGAB 19:30 - 20:30 1.00 PULD_ BHA_ PLUGAB 20:30 - 21 :00 0.50 RUNPUL COIL PLUGAB 21 :00 - 23:00 2.00 PULD BHA_ PLUGAB 23:00 - 03:00 4.00 WASH_ FILL PLUGAB 03:00 - 04:30 1.50 PULD - BHA_ PLUGAB 04:30 - 05:00 0.50 PULO - BHA_ PLUGAB 10/20/2004 05:00 - 05:30 0.50 RUNPUL COIL PLUGAB 05:30 - 07:45 2.25 REPAIR EQIP PLUGAB 07:45 - 11 :30 3.75 PUMP - N2_ PLUGAB 11 :30 - 13:00 1.50 PULL_ EQIP PLUGAB 13:00 - 14:30 1.50 RURD - COIL PLUGAB Start: Rig Release: Rig Number: Spud Date: 5/25/2002 End: Group: 1 0/3/2004 5/30/2002 1 Description Of Op~rations Build circulating wire spear (straightbar with 9 points upward) at G&G Machine PU wire spear and chisel nozzle. RIH washing at 1.8 BPM to 3680' and work. See brief 2000lb overpull. POOH. At surface, no wire in spear. One upward tine is bent outword. Repair tine and make up lubricator for second run. RIH washing at 1.8 BPM and work to 3682'. POOH. At surface without wire or indications of tool contact. Breakout spear and RU overshot with internal teeth. RIH to 3668' and attempt to make footage. Fire jars several times with no indication of overpull upon pickup. Make no downward progress. POOH. Have entire PWS fish at surface. Wire in tact all the way to cut end. Break out tool and LO lubricator. Secure well for night. Sign in and obtain work permit. Hold safety meeting. Thaw out equipment, CT and flowcross with heaters due to previous night's freeze. Circulate fluid through CT. Break Weatherford MHA and install BJ dimpleon CT connector and 4.60" nozzle. Install nozzle beneath BOPs due to 4" stack drift. Function test and shell test BOPs to 250/2500psi. Test ground lines to 4500psi. RIH wI CT. Pump 1.7 BPM, tag up at 3685'. Work and wash with little progress. Stop pipe and make repairs at injector head while continue circulating. Continue washing attempts with no signs of progress. POOH for new BHA. Break lubricator, cut off BJ connector and install Weatherford MHA. PU motor and mill. Note that Weatherford brought 4.80" mill (above drift). Attempt to RIH. Have drift problems at 85'. Elect to POOH and PU different mill. Weatherford is bringing appropriate mill from Anchorage. PU Weatherford 4.70" burnover shoe shell test BOPs and RIH. Washlmill through green cement with 1.7BPM KCI to 3739' CTM. Light tag on what should be WRP plug. Pump 5 bbl Biozan viscous pill for hole cleaning and CBU. See good returns at surface laden with cement solids. POOH pumping. At surface, elect to run BJ CT connections to allow reverse circulation. Break stack to access large tools. Cut off Weatherford MHA to dimpleon BJ cxn. PU circ sub and crossovers to pulling tool. Stab assy and flange up wellhead. Shell test and RIH. Tagging up in WHA crossovers. PU at Bowen cxn with tree valves closed. and guide tool through flanges. Reconnect Bowen and open valves. RIH wI WRP pulling tool. Begin to cool down N2 unit to begin reverse circulation. N2 unit needs repairs. Work on N2 unit. RIH reverse circulating N2 to purge wellbore. With fluid reversed, RIH in attempt to fish plug. Unable to latch fishing neck after many attempts. Pump 5 bbl of fluid to wash any fines from around fishing neck with no response. POOH. RD CT and demob to SO 2 frac Printed: 9/26/2006 5:02:44 PM . . Marathon OilCompçmy Page 5 of 18 Operations Summary R~port Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 1 0/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Description of Oper¡:3tions Code 10/21/2004 08:00 - 11 :00 3.00 RURD SLlK PLUGAB Sign in obtain permit and hold safety meeting. Rig up PWS slickline. 11 :00 - 11 :45 0.75 RUNPUL SLlK PLUGAB RIH wI 4.71" LIB. Tag at 3733' WLM. POOH wI no discernible impression on LIB. 11 :45 - 12:30 0.75 RUNPUL SLlK PLUGAB RIH wI 2" bailer. Break through bridge at 3733' and fall additional 12' to 3745'. POOH. Bailer contains green cement and hard cement pieces. See impression of fishing neck on shoe of bailer. 12:30 - 18:00 5.50 BAIL_ FILL PLUGAB RIH repeatedly with 3" getting about 1-2 gallons of green cement and hard cement rocks. 18:00 - 18:30 0.50 RURD - SLlK PLUGAB Rig back slickline for night and agree to machine design to alter retrieving tool to run plug to bottom. 10/22/2004 07:30 - 09:30 2.00 RURD SLlK PLUGAB Rig up slickline 09:30 - 13:30 4.00 RUNPUL SLlK PLUGAB RIH wI 3" pump bailer picking up fewerlsmaller cement rocks. Eventually no more rocks. 13:30 - 14:15 0.75 RUNPUL SLlK PLUGAB RIH wI Weatherford pulling tool. Omit colletts so tool will shift equalizing sleeve. 14:15-17:00 2.75 RUNPUL SLlK PLUGAB RIH wI PWS modified shear-up grabber. Work tool string catching fishing neck and shearing off without releasing plugx2. 17:00 - 21 :00 4.00 RUNPUL SLlK PLUGAB RIH wI modified shear-up grabber a third time. Work tool without shearing retrieving tool pin. Attempt to shear off tool with no success. Stuck in hole latched onto plug with slickline. Repeat jar licks in attempt to free tool or plug without success. 21:00 - 23:15 2.25 WAlTON EQIP PLUGAB Cutter bar arrives from PWS with improper stop ring. Send back to shop to modify. 23:15-01:15 2.00 CUT_ WIRE PLUGAB Drop modified cutter bar. Bar did not cut wire. Pick up Kinely timerlcutter. Drop Kinley cutter and wait 64 minutes. Cutter fired. 01:15 - 02:00 0.75 RUNPUl SLlK PLUGAB POOH wi slickline. Recovered Kinley cutter. Left +1-40' of wire. 02:00 - 03:00 1.00 RURD - SLlK PLUGAB Retie slickline head and rig back for night. 10/23/2004 10:30 - 11 :30 1.00 RURD SLlK PLUGAB Sign in, obtain permit, and RU slickline unit. 11:30-12:15 0.75 RUNPUl SLlK PLUGAB RIH wI 4-1/2" impression block. No impression at surface. 12:15 - 13:45 1.50 RUNPUl SLlK PLUGAB RIH wI 2" bailer. Bail small amounts of cement solidsx2. 13:45 - 14:15 0.50 RUNPUL SLlK PLUGAB RIH wI 4-1/2" impression block. Tag 6' deeper. See image of wire and fishing neck. 14:15 - 14:45 0.50 RUNPUL SLlK PLUGAB RIH wI pulling tool. Grab cutter bar and POOH. No wire. 14:45 - 15:15 0.50 RUNPUL SLlK PLUGAB RIH wI impression block. See wire marks. Elect to let CT fish wire as it may be connected to stuck tool and plug. 15:15 - 16:30 1.25 RURD - SLlK PLUGAB Rig down slickline. 11/6/2004 06:00 - 12:00 6.00 RURD_ COIL PLUGAB Exact timing not known. Spotted equipment and began rig up. 11/7/2004 06:00 - 07:00 1.00 RURD - COIL PLUGAB Continue RU. PU BOPs and lubricator. Attempt to pressure test. Pressured up with methanol in reel indicating ice plug. Gather equipment to thaw out reel. 11/8/2004 06:00 - 09:40 3.67 RURD - COIL PLUGAB Thaw CT and circulate 45 Bbls MeOH Water. 09:40 - 10:10 0.50 TEST_ BOPE PLUGAB PT BOP to 2500 psi. Good. Ready to purge CT with N2. 10:10-11:03 0.88 RURD COIL PLUGAB Thaw N2 unit 11 :03 - 11 :30 0.45 BLOWor COIL PLUGAB Purge CT 11 :30 - 15:50 4.33 PULD - BHA_ PLUGAB PU additional lubricator and fishing tools. Work tool string thourgh BOP and tree. 15:50 - 16:40 0.83 RUNPUL COIL PLUGAB RIH fishing tools 16:40 - 17:10 0.50 WORK_ COIL PLUGAB work to catch fish. Tagged at 3719 and worked down to 3725' solid tag. Suspect wire above WL tool string. 17:10-18:00 0.83 RUNPUL COIL PLUGAB POH 18:00 - 18:45 0.75 SECURE WELL PLUGAB Rig back for night 11/9/2004 08:30 - 11 :00 2.50 RURD_ COIL PLUGAB Sign in, obtain work permit. Hold safety meeting. Pick up lubricator Printed: 9/26/2006 5:02:44 PM . . Page 6 of 18 Marathon OH·Company Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Event Name: WORKOVER Contractor Name: Rig Name: GLACIER DRILLING Date From -'To Hours Code Sub Phase Code 11/9/2004 08:30 - 11 :00 2.50 RURD_ COIL PLUGAB 11 :00 - 11 :30 0.50 TEST BOPE PLUGAB 11 :30 - 12:00 0.50 RUNPUL COIL PLUGAB 12:00 - 12:15 0.25 ENGAGE FISH PLUGAB 12:15 - 13:00 0.75 RUNPUL COIL PLUGAB 13:00 - 13:45 0.75 PULD BHA PLUGAB 13:45 - 15:15 1.50 RUNPUL COIL PLUGAB 15:15 - 16:15 1.00 PULD_ BHA_ PLUGAB 16:15-17:00 0.75 RUNPUL COIL PLUGAB 17:00 - 17:40 0.67 ENGAGE FISH PLUGAB 17:40 - 18:20 0.67 RUNPUL COIL PLUGAB 18:20 - 18:40 0.33 INSPCT BHA_ PLUGAB 18:40 - 20:00 1.33 PULD BHA_ PLUGAB 20:00 - 23:30 3.50 ENGAGE FISH PLUGAB 23:30 - 00:15 0.75 REPAIR EQIP PLUGAB 00:15 - 00:45 0.50 ENGAGE FISH PLUGAB 00:45 - 01:15 0.50 RUNPUL COIL PLUGAB 01 :15 - 02:00 0.75 PULD_ BHA_ PLUGAB 02:00 - 03:00 1.00 SECURE WELL PLUGAB 11/11/2004 12:00 - 16:00 4.00 CUT_ COIL PLUGAB 11/12/2004 07:30 - 08:00 0.50 SAFETY MTG_ CLNOUT 08:00 - 13:00 5.00 RURD - CMT_ CLNOUT 13:00 - 13:30 0.50 PULD_ BHA_ CLNOUT 13:30 - 14:00 0.50 TEST BOPE CLNOUT 14:00 - 16:30 2.50 RUNPUL COIL CLNOUT 16:30 - 21:30 5.00 WASH_ FILL CLNOUT 21 :30 - 22:30 1.00 WAlTON EQIP CLNOUT 22:30 - 00:15 1.75 WASH_ FILL CLNOUT 00:15 - 01:00 0.75 RUNPUL COIL CLNOUT 01:00 - 01:15 0.25 CIRC_ CFLD CLNOUT 01 :15 - 02:00 0.75 PULD_ BHA_ CLNOUT Start: Rig Release: Rig Number: Spud Date: 5/25/2002 End: Group: 10/3/2004 5/30/2002 1 Description of OperatiolJs and injector head. MU BHA. Shell test WHA via kill line to 1000psi. No visible drips. RIH wi barbed wire spear. Tag at 3715'. Work down and PU with brief -20001b overpull. RIH again. Experience solid tag up. PU without overpull. POOH wI spear. PU 3.83" LIB. MU to end of spear. RIH and tag with 2000lbs to get impression. POOH wI LIB & spear. Break out LIB and examine. Far edge of impression block shows far edge of fishing neck. Unable to detect wire which may exist outside of impression block tag. Elect to retry Weatherford pulling tool with 4" skirt. Dress tool and put bend in CT in effort to better centralize tags. RIH wi pulling tool. Tag tool x2 wi no overpull. PUH -50' and RIH. Set down 5klbs. PU wI overpull. Fire jars wit 3000lb overpull. See small tool movement suspected to be Pollard toolstring spangs. Continue to increase overpull by 1000lbs to 20,000Ibs. RIH to cock jars. Wait on bottom for down fire. With no downfire, PUH. No longer latched to fish. Tag once more and PU wlo overpull. POOH wI fishing assy Inspect fishing equipment. See slight marks which may indicate wire was in tool, but may have prevented grapple hold. Change out leaking flapper check valves. PU Baker overshot. RIH w/O-shot. Engage fish on first attempt. Jar up and down x45 with no luck. Blow hydraulic hose on injector head. Close rams and repair. Resume upldown jarring. Break free after -10additional cycles. POOH wI fish. At surface. Recovered partial slickline toolstring including FN, 2x5' wt bars, and knuckle jt. Break out tools. Rig back equipment for night. Well secure. Cut 200' of CT off of reel to prevent repeated wear at the gooseneck. Arrive on location. Obtain work permit. Hold safety meeting. Location is very icy. Pick up injector head and lubricator. CT is out of round. Cut 600 ft of pipe from reel. MU 16' of 3.125" fishing wash pipe with carbide tipped shoe. Shell test BOPs with 6% KCI. RIH to reverse circulate over stuck tools with wash pipe. Circulate at 1 BPM. Increase ciruclation to 2BPM and lose circulation at 600psi. PUH and stop pumps. Resume pumping at .5BPM. Keep close eye on returns rate. Elect to wash down CT to improve rate. Wash and make 9' from 3725'-3734'. Re-align to reverse pump for circulating out solids. Transfer pump from returns tank to supply tank failed. Wait for vac truck. Continue reversing to wash fill. Losing returns to surface with pump pressure at 300psi. Only able to reverse down to 3731'. Attempt to CBU before POOH. Elect to POOH. At surface. Pump CT volume to tank to ensure no solids in string. Break out washpipe and Install flapper above jars. MU overshot for 1-3/4" tool string. Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 7 of 18 Operations Summary Report . Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 1 0/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date .. From - To Hours Code Sub Phase Description of Operations Code 11/12/2004 02:00 - 02:45 0.75 RUNPUL COIL CLNOUT RIH wloverhsot. 02:45 - 03:30 0.75 WORK_ COIL CLNOUT Work to engage tool. Repeated several times. Pump down CT and attempt to latch 1-3/4" wireline jars. 03:30 - 04:00 0.50 RUNPUL COIL CLNOUT POOH wI CT 04:00 - 04:45 0.75 PULD_ BHA_ CLNOUT At surface. No wireline tools. See marks on shoe edge which indicate overshot was at tool string. Do not see any marks on painted surface inside tool. 04:45 - 05:30 0.75 PUMP _ TRET CLNOUT Freeze protect CT wI methanol & N2. 05:30 - 06:00 0.50 RURD_ COIL CLNOUT Rig back equipment for night. 11/16/2004 08:00 - 08:30 0.50 SAFETY MTG_ CLNOUT Hold brief safety meeting. 08:30 - 11 :00 2.50 RURD_ COIL CLNOUT Sign in, obtain work permit. Rig up equipment. 11:00 -12:00 1.00 PULD_ BHA_ CLNOUT PU BHA including XO, DFCV, KJ, XO, Dual acting OJ, Hyd Disc, 9' 3.125" wash pipe wI overshot wI 4" skirt. Guide skirt through tree. 12:00 - 12:30 0.50 RUNPUL COIL CLNOUT RIH wi BHA to depth. Begin pumping to load CT. Short on KCI, waiting on vac truck. 12:30 - 14:00 1.50 WORK_ COIL CLNOUT Tag high at 3712' (previous tags were at +1- 3730'). Sit down and jar a couple times. Continue to wait for KCI fluid. Pumping at 1bpm without washing or making depth. 14:00 - 14:30 0.50 CIRC_ CFLD CLNOUT With additional KCI, circulate fluid. Unable to get to >1.2bpm wlo losing prime (due to low hydrostatic in tank?). Attempt to circulate. See no additional pressure or progress in depth. 14:30 - 15:15 0.75 RUNPUL COIL CLNOUT POOH wI wash pipe and overshot. 15:15 - 15:45 0.50 PULD_ BHA_ CLNOUT At surface. No marks on tool. PU LIB. Counterhead was off 17'. CORRECT PREVIOUS TO to 3729'. 15:45 - 17:15 1.50 RUNPUl COIL CLNOUT Run LIB. Hit down to get an impression and POOH. 17:15 - 18:45 1.50 PULD_ BHA_ CLNOUT At surface with no discernable impression on block. Elect to drop knuckle jt and put reverse bend in CT. PU Grapple overshot with 6' wash pipe and 3.625" shoe. Stab on injector. 18:45 - 19:25 0.67 RUNPUl COIL CLNOUT RIH CT. Tag fish at 3740'. 19:25 - 19:50 0.42 WSHOV ~ISH CLNOUT Attempt to wash over fish. Unable to make progress. 19:50 - 20:20 0.50 RUNPUL ANCH CLNOUT POH CT. 20:20 - 20:50 0.50 PULD BHA_ CLNOUT LD 5' of wash pipe and PU 2-7/8" Motor. 20:50 - 22:00 1.17 RUNPUL COIL CLNOUT RIH CT and tag fish at 3738" 22:00 - 23:35 1.58 WSHOV ~ISH CLNOUT Work to rotate down over fish. attempt rates from 0.5 to 1.5 BPM. Latch fish and jar down to set grapple. 23:35 - 03:50 4.25 WORK_ COIL CLNOUT Jar up and down on fish to shear pins from WL overshot. WL spang jars are working freely. Jar up 83 times from 17,000# to 24,000# overpull. Attempt to rotate motor to release grapple. Unable to release or free fish. 03:50 - 04:30 0.67 SETREL TOOL CLNOUT Drop disconnect ball And pump down to BHA. Disconnect from BHA. 04:30 - 05:05 0.58 RUNPUL COIL CLNOUT POH CT 05:05 - 08:00 2.92 CUT_ COIL CLNOUT LD tools and cut 200' CT to change stress area. 11/17/2004 06:00 - 00:00 18.00 WAlTON EQIP CLNOUT Waiting on jars and accelerator. Cut 200' CT while waiting. 00:00 - 02:20 2.33 PULD BHA_ CLNOUT Pick up fishing assy including accelerators 02:20 - 03:30 1.17 RUNPUL COIL CLNOUT RIH CT. Tag fish at 3727' and latch. 03:30 - 05:30 2.00 WORK_ COIL CLNOUT Hit jars 55 times at 15K to 24K overpull. Pull fish free. 05:30 - 06:00 0.50 RUNPUL COIL CLNOUT POH with fish. 11/18/2004 06:00 - 09:00 3.00 WAlTON EQIP PLUGAB Wait on appropriate clamp and mast truck to pull tool from hole. 09:00 - 10:30 1.50 PULD_ BHA_ PLUGAB LD fish. Recovered remainder of BHA from prevous run and slickline Oil jars. Spangs, a crossover, a Pollard RJ retrieving tool (shear up) and the WRP remain in the hole. 10:30 - 11 :30 1.00 WAlTON ORDR PLUGAB Standby CT and decide to fish remaining tool with drilling rig. 11 :30 - 16:30 5.00 RURD - COIL PLUGAB RDCT. Printed: 9/26/2006 5:02:44 PM . . Page 8.of18 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Event Name: WORKOVER Contractor Name: Rig Name: GLACIER DRILLING Daæ From - To Hours C Sub Phase ode. Code 11/24/2004 06:00 - 12:00 6.00 RURD_ RIG_ MIRU 12:00 - 00:00 12.00 RURD_ RIG_ MIRU 00:00 - 06:00 6.00 RURD_ RIG_ MIRU 11/25/2004 06:00 - 12:00 6.00 RURD_ RIG_ MIRU 12:00 - 00:00 12.00 RURD_ RIG_ MIRU 00:00 - 01 :30 1.50 NUND TREE WBPREP 02:00 - 06:00 4.00 NUND BOPE WBPREP 11/26/2004 06:00 - 08:00 2.00 NUND BOPE WBPREP 08:00 - 09:00 1.00 TEST_ BOPE WBPREP 09:00 - 12:00 3.00 TEST_ BOPE WBPREP 12:00 - 14:30 2.50 TEST_ BOPE WBPREP 14:30 - 15:00 0.50 TEST_ BOPE WBPREP 15:00 - 19:00 4.00 REPAIR RIG_ WBPREP 19:00 - 20:30 1.50 TEST_ BOPE WBPREP 20:30 - 02:00 5.50 PULD_ DP - WBPREP 02:00 - 03:00 1.00 RURD_ OTHR WBPREP 03:00 - 04:00 1.00 CIRC_ CFLD WBPREP 04:00 - 04:45 0.75 SPOT _ PILL WBPREP 04:45 - 06:00 1.25 TRIP - DP - WBPREP 11/27/2004 06:00 - 06:30 0.50 CIRC_ CFLD WBPREP 06:30 - 07:00 0.50 SQUEZE OTHR WBPREP 07:00 - 11 :00 4.00 SQUEZE OTHR WBPREP 11 :00 - 13:00 2.00 TRIP _ DP_ WBPREP 13:00 - 13:30 0.50 PULD_ BHA_ WBPREP 13:30 - 17:30 4.00 PULD BHA CMPPUL 17:30 - 19:30 2.00 WSHOV ~ISH- CMPPUL 19:30 - 21 :30 2.00 CIRC_ CFLD CMPPUL 21 :30 - 01 :00 3.50 TRIP_ BHA_ CMPPUL Start: 10/3/2004 Rig Release: 5/30/2002 Rig Number: 1 Spud Date: 5/25/2002 End: Group: Description of Operations Accept rig FI KBU42-6 06:00hrs 11/23/2004. Move sub base, pit house, pump house, geneartors, boiler, water tank, mud boat and carrrier. Spot sub and pump house. Cont. spot sub, mud boat, carrier, generator house, boiler house, water tank. Pull pits together and RlU. Crane work: Set choke and dog house, stairs, flow line. Fill pits. Raise mast. RlU drillers console. RlU steam, hydraulic and electric lines. RlU gas buster. Run wires. Spot catwalk. Adjust guide wires. Warm up motors and prep to scope up mast. RlU Drilling console, Degasser, String elect. conds, RlU flowline. Install back wind walls. Finish RlU pits. Scope up derrick. RlU cylinders and winterizing tarps. Trouble shoot drawworks clutch. RlU racking board. RlU mud manifold, kill line, choke line, and panic line. Hang torque tube and top drive. Set Bop's for N/U . Accept rig for workover 00:00 hrs. 11/25/2004. PJSM: N/D tree. PJSM: Set in and N/U 11"3M X 13 5/8" 5m DSA. N/U S,Rd,A 13 5/8" 5m BOP. Rack 2 7/8"DP. N/U BOPE. Function test BOP. Pull BPVand install TWC. Fill stack. Test blind rams, outside kill, and choke manifold valves 10,11,12 20/2000psi 10min. Choke manifold valve#3 failed. Test inside kill, choke manifold valve 6,8,9 250/2000psi 10min. Test kill line check valve and choke manifold valve 2,5,7. While pull TWC and completion bushing C/O CMV#3. Instal test plug and 2 7/8" test joint. Test annular, variable rams, IBOP, TIW, choke HCR, manual choke line valve and CMV 1,3,4 to 250/2000psi 1 Omin(upper TO valve failed). Pull test plug and install wear bushing. CIO TO valves. Test TO valves to 250/2000 psi. for 10 min. OK . RID test tools PJSM: P/U and rih with 2.875" drill pipe from racks to 3746' tag. RlU Circulating head Circulate well bore to 8.65ppg. 6% KCL 100% returns(took 4bbls to fill the well). PJSM: BJ mix pump and put in place 10 bbl. M-I Form-A-Set pill 9-bbl. 6% KCL,5sxs Form-A-Set AK, 1/2sx FloVis, 1sx Form-A-Set XL. Pill in place @ 0445 hrs. 11/26/2004, 100% returns while pumping @ 2 bbl. per min 225 psi. Pooh to 3226' Circ. @ 3226'(no losses). Squeeze w/200psi(squeeze away 1bbl Forma seal). Hold 200psi on CSG. POOH w/2 7/8" DP. Prep to P/U washover tools. P/U 4 1/2" wash over assy. and RIH to 3206' Wash & Circ down from 3206' to 3752' . Wash over fish FI 3752' to 3759' ( Unable to make forward progress.)100% returns Circ well bore and Mix and pump Hi-Vis sweep 10 bbls Returns clean. Returns 100%. (Flow check) POOH, Recovered Spang Jars, Pollard RJ pulling tool,10" of .125" wire,Retainer left hand thrd nut off top of WRP (Note: this nut keeps the pulling sieve on when pulling pkr. RJ pulling tool was packed full of cmt at top, Tools recovered by friction hold on pulling Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 9 of 18 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 10/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Description of Operations Code 11/27/2004 21 :30 - 01 :00 3.50 TRIP - BHA_ CMPPUL tool and washover shoe. LH nut was stuck in cmt in top of RJ pulling tool. 01 :00 - 02:00 1.00 TRIP_ BHA_ CMPPUL M/U Bha # 2 02:00 - 04:00 2.00 TRIP_ BHA CMPPUL RIH To 3740' , M/U top drive and circ down to 3759' 04:00 - 04:30 0.50 WSHOV ~ISH- CMPPUL Wash over F/3759' to 3761' 04:30 - 06:00 1.50 CIRC_ CFLD CMPPUL Circ Hi-Vis Sweep 11/28/2004 06:00 - 06:30 0.50 CIRC_ CFLD CMPPUL Circ. out hi vis sweep. 06:30 - 07:30 1.00 RURD - OTHR CMPPUL RJU to UD 2 7/8" DP and BHA. Blow down surface equipment. 07:30 - 13:00 5.50 PULD - DP_ CMPPUL UD 2 7/8" DP and BHA. 13:00 - 00:00 11.00 RURD - COIL CMPPUL PJSM. RJU BJ coil tubing unit w/1 3/4" coil. Pull wear bushing and run completion bushing. Install TWC. 00:00 - 02:30 2.50 NUND EQIP CMPPUL Install 7 1/16" 3000psi. master valve on top of annular preventer. 02:30 - 04:00 1.50 TEST _ BOPE CMPPUL PJSM: Test riser and all BJ coil tbg preventers and valves to 2001 2000 psi. 04:00 - 05:00 1.00 PULL_ EQIP CMPPUL Break fig @ lubricator top and pull twc and M/U and test fig to 2001 2000psi. 05:00 - 06:00 1.00 BLOWD CSG_ CMPPUL Rih with 2" Bull nose Jet on coil tbg. Could not get below compl. bushing. POOH to bend coil. 11/29/2004 06:00 - 07:00 1.00 BLOWD COIL CMPPUL Attempt to RIH w/Coil and nozzle(try bending coil). Can not pass completion bushing. POOH. 07:00 - 09:30 2.50 RURD_ OTHR CMPPUL Cut 40' CT. RJU CT lubricator(bowen connections in poor condition with no thread prtectors, had to file on some of the connection to get them to M/U). 09:30 - 10:30 1.00 TRIP_ EQIP CMPPUL Attach Baker CT connector to CT and pull test to 20K. P/U Baker fishing string w/Weatherford retrieving tool. 10:30 -11:00 0.50 TRIP - EQIP CMPPUL NID 7 1/16" flanged connection to be able to M/U 4 1/2"retrieving tool. N/U connection. 11 :00 - 12:00 1.00 TEST _ BOPE CMPPUL Shell test riser and CT lubricator to 900psi(max poss without collapsing coil). 12:00 - 14:30 2.50 TRIP - EQIP CMPPUL RIH wlFishing assy to 3726 eirc. w/N2 while RIH(had to work tools past 71/16" valve and completion bushing). 14:30 - 15:30 1.00 JET_ N2 - CMPPUL Cont. to eirc. w/increased rate @ 3726'(recovered 96bbls of 107bbls 6% KCL). Shut down and hold 550psi. RIH to 3739'(tag). Attempt to equalize the RBP and retrieve the fishing neck(no indication). 15:30 - 17:00 1.50 TRIP_ EQIP CMPPUL POOH(no catch). 17:00 - 21 :00 4.00 WAlTON EQIP CMPPUL Wait on Expro E-Line truck. 21 :00 - 22:00 1.00 RURD ELEC CMPPUL PJSM: RJU Expro E-line. 22:00 - 23:00 1.00 RUNPUL BRDL CMPPUL RIH With 4.5" LIB to 3760', POOH and Impression showed top of RBP retrieving sleeve. (Note:Fluid level @ 3300'). 23:00 - 00:00 1.00 RUNPUL BRDL CMPPUL RIH with 4.5" magnet to 3758' WLM. POOh and rec .31" of .125" wire. 00:00 - 00:30 0.50 RUNPUL BRDL CMPPUL Run 4.5" magnet to 3760' WLM and recover RBP retrieving sleeve. 00:30 - 01 :30 1.00 RUNPUL BRDL CMPPUL RIH with 4.5" LIB to 3760' Pooh, Impression of setting stud (clean for a good catch). 01 :30 - 03:00 1.50 RUNPUL BRDL CMPPUL Run 4.5" magnet to 3760' and had no recovery. 03:00 - 06:00 3.00 WAlTON EQIP CMPPUL Clean and organize rig. Wait on BJ Coil employees to get rest. 11/30/2004 06:00 - 06:30 0.50 WAlTON OTHR CMPPUL Wait on BJ coil tubing crew to get rested. 06:30 - 07:00 0.50 SAFETY MTG_ CMPPUL Safety meeting prior to starting up CT oprations for the day. 07:00 - 08:30 1.50 PULD_ BHA_ CMPPUL M/U 3 1/4"grapple w/4 1/2"cut lip guide. Shell test BOP and riser to 850psi. 08:30 - 10:00 1.50 TRIP - EQIP CMPPUL RIH and tag @ 3722'(had to work coil past compo bushing). Work overshot to 3740' and engage fishOar down several times). Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 10 of 18 QperationsSÚmmary . Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 10/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From -To Hours Code Sub Phase Description of Operations Code 11/30/2004 10:00 - 11 :00 1.00 TRIP - EOIP CMPPUL POOH. Recovered equalizing sleave and a l' and a 3' piece of wire. 11 :00 - 12:30 1.50 TRIP_ EOIP CMPPUL M/U 2" grapple and 4 11/16" cut lip guide. RIH and tag@3744'. Engage fish 2 times and overpull 7K to pull WRP free. 12:30 - 13:30 1.00 TRIP_ EOIP CMPPUL POOH UD fish and tools(recovered 100% of WRP). 13:30 - 19:00 5.50 RURD - COIL CMPPUL RID CT. 19:00 - 20:00 1.00 TAG_ BOTM CMPPUL RlU Expro and rih with 4.3" GRlJB to 3808' WLM. POOH. 20:00 - 21 :30 1.50 SETREL PLUG CMPPUL RIH and set Baker 5.5" 17# Retrieveable Pkr. @ 503' POOH and rig dn Expro. 21 :30 - 22:00 0.50 TEST_ PLUG CMPPUL Test pkr to 1000 psi. 22:00 - 22:30 0.50 SETREL PLUG CMPPUL Run and set TWC. 22:30 - 00:00 1.50 NUND BOPE CMPPUL Nipple dn 7 1/16" Riser. 00:00 - 05:00 5.00 NUND BOPE CMPPUL Nipple dn 13 5/8" Bop's, and set in cradle, freeze protect dwks. clean pits. 05:00 - 06:00 1.00 NUND TREE CMPPUL Nipple up tree. 12/1/2004 06:00 - 07:00 1.00 NUND TREE CMPPUL N/U tree and test to 300psi. 07:00 - 07:30 0.50 NUND TREE CMPPUL Remove TWC and install BPV. 07:30 - 12:00 4.50 RURD - RIG_ RDMO RID tongs. Adjust counter weights for the large tongs. UD subs and handling tools. RID choke and kill line hoses. RID mud manifold. RID choke line to gas buster and panic line. Load trailers. Pickle pumps. Remove dresser sleeves in pits. Pull wires. 12:00 - 00:00 12.00 RURD - RIG_ RDMO RID top drive and torque tube. RID racking board. RID cylinder tarps and Tarp for carrier. Blow down steam and water lines. Retract derrick. Cont. RID pits. Weld O-rings on derrick board for mule line. UD beaver slide. Crane down stairs and panic line. 00:00 - 06:00 6.00 RURD - RIG - RDMO PJSM. Crane off choke house, flowline and stairs for BOP conex. Crane down dog house, windwalls, out riggers and derrick house. Lower derrick, pull wires, split pits and pump room. Prep to move rig. Rig released to SD#4 @ 06:00 hrs 12/01/2004. 12/29/2004 08:00 - 10:00 2.00 MI RU wireline unit. Held PJS Discussed procedure with wire line operator and assistants. 10:00 - 12:00 2.00 MU 2.0" bailer, RIH tagged fill at 3794' KB, (KB at 17'). 31 feet of open perforations. POOH 12:00 - 15:00 3.00 MU tandem pressure gauges, RIH making 3 minute stops at the following depths. 3730',3700', 3650', 3600', 3000', 2500', 2000', 1000', lubricator. Lay down lubricator check pressure gauge data. 15:00 - 17:30 2.50 Continue to bailout sludge from well bore. Made several bailer runs. Bailer broke through a small bridge and was able to tag fill at 3801' KBD. Bailer tagging hard with nothing but water in bailer. RD wire line unit. Note: recieved gradient survey shows water level at 1790' KB 1/10/2005 10:00 - 19:00 9.00 MIRU Ct flow back tank, pump, crane, & coil unit. 1/11/2005 07:00 - 10:30 3.50 Continue with riigging up Coil. MU BHA 2.1/8" nozzle with stright bar, double check and cross over to 1 3/4" coil. Held PJSM and discussed safey issues. 10:30 - 13:50 3.33 PU injector head and stabbed on well. PT shell to 250 psig low 2800 psig high. No problems. Tested Rams @ 290 psig low and 2900 psig high. no problem closed in tubing rams. tested low pressure at 35 Psig on wellhead. Pressured up to 2000 psig, tubing went to 1900 psg. BOP test failed. blew down BOP's and lay down BOP's. 13:50 - 15:00 1.17 Replaced the BOP tubing rams. Picked up after repair tired to test BOP's second time. Tubing rams would not hold. Blew down and sat Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company OperatiQn$ Summary Report Page 11 of18 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI UNIT 21-7 KENAI UNIT 21-7 WORKOVER Start: Rig Release: Rig Number: 1 0/3/2004 5/30/2002 1 Spud Date: 5/25/2002 End: Group: Date GLACIER DRILLING C Sub From - To . HQUrs ode Code Phase Description of Operªtions 1/11/2005 13:00 - 13:40 0.67 down the injector, secured and pulled the BOP's. Changed the equalizer valve with the blind rams to try and see if valve had failed on the tubing rams. After repair PU the BOP, set the injector back on well head. tried to pressrue up the tubing rams, same problem as previous two times. Decided to pull the BOP's and repair in the shop. Shut down for night. BJ CT operators arrivee with shop rebuilit and tested BOP's. MU to tree. Held a tail gate safety meeting prior to commensing work and secured a work permit. PU injector head and started PT the tubing rams. Accumaltor blew on the BOP's. Shut down and BJ brought out a new power pack. Reconnected the hoses and picked up the injector to continue with the PT. Seond power back accumalator bottles blew. One set of accumaltor bottles left at BJ shop. BJ pulling the bottles a shop to bring out field and install in the field. Continued with the BOP test. Tested the shell, blinds and tubing rams. Everything tested good for early morning start. BJ left lease. BJ Coil crew arrived on location. Pu Injector head and stabbed on well. Held PJSM and discussed safety issues and discussed procedure. PT shell to low @ 350/ high at 2500 psig, all tested. RIH with coil 1 3/4" Ct with double check, x -over and 2 1/8" jet nozzle. WHP= 50 psig. Continue down hole with coil, N2 pump in rate at 350 SCFM, When CT at 2000', increased N2 rate to 750 SCFM. Watched tank for returns, no returns to tank. note:Wire line gradient indicated that the water level at 1780' in tubing. No returns after N2 around the coil to surface. PU coil to 1900' still no returns to tank. Continue running coil in well. When coil at 2550' started getting returns to flow back tank. WHP= 75 psig, pip= 716 psig, N2 @ 750 SCFM. Continue moving coil down hole. Good returns to tank. CT at 3250', WHP = 170 psig, 12.5" H20 returns to tank (35 bbbls). PIP= 780 psig, water dirty and heading to flow back tank. Ct at 3670', pip = 790 psig, WHP= 260 psig, N2 rate at 750 SCFM. 36.1 bbls total returns to the flow back tank. Continue with working coil down hole, coil tagged at 3723' CT KBM. PU coil and run in hole tagged up at the same spot at 3725'. PU coil to 3600' , cut N2 rate to 350 SCFM while waiting on KCL to mix with foam to help lift fill. Vac truck brought a load of dirty water had to have him dump his load and take on another load of water. Continue pumping N2 at lower rate. 3% KCL water ready with foam. Started pump rate at.7 BPM and N2 at 750 SCFM. PIP= 890 psig, WHP= 0 psig. no returns to flow back tank. Increases N2 rate to 1000 SCFM, no change to ability to wash out fill. Leveled out N2 to foam and water rate, RIH pumping foam. WHP= 11 psig, pip, 1360 psig, N2 at 750 SCFM. Stacked out at same depth of 3725', set 2000 Ibs of weight on coil, nozzle would not wash through fill. made several up and down passes to try and wash out fill. No progress with the foam. There are good foam returns to tank. Shut down water pump, N2 down, PIP= 1510 psig, WHP = 300 psig. POOH with coil OOH with coil, fill real with Methanol to frreeze protect coil. Shut well in and lay down injector and secure to unit. Shut all equipment down. BJ coil operators left lease. 13:50 - 15:00 15:00 - 23:00 1.17 8.00 1/12/2005 06:00 - 16:00 10.00 16:00 - 17:00 1.00 17:00 - 17:50 0.83 17:50 - 18:00 0.17 1/13/2005 07:00 - 09:00 2.00 09:00 - 11 :00 2.00 11:00 -11:10 0.17 11:10 -11:40 0.50 11 :40 - 12:00 0.33 12:00 - 12:20 0.33 12:20 - 13:00 0.67 13:40 - 14:30 0.83 14:30 - 16:20 1.83 16:20 - 17:00 0.67 17:00 - 18:30 1.50 Printed: 9/26/2006 5:02:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Marathon Oil Company QperationsSummary Report Page 12 of18 KENAI UNIT 21-7 KENAI UNIT 21-7 WORKOVER Spud Date: 5/25/2002 End: Group: Start: 10/3/2004 Rig Release: 5/30/2002 Rig Number: 1 Date GLACIER DRILLING C d Sub From - To Hours oe Code Phase Description .of 0perations 1/13/2005 17:00 - 18:30 1/14/2005 07:00 - 11 :00 11 :00 - 12:20 12:20 - 13:10 0.83 13:10 - 13:20 0.17 13:20 - 13:40 0.33 13:40 - 13:55 0.25 13:55 - 14:20 0.42 14:20 - 14:40 0.33 14:40 - 14:50 0.17 14:50 - 14:58 0.13 14:58 - 15:15 0.28 15:15 - 15:30 0.25 15:30 - 15:35 0.08 15:35 - 15:40 0.08 15:40 - 15:45 0.08 15:45 - 15:50 0.08 15:50 - 16:05 0.25 16:05 - 16:30 0.42 16:30 - 16:40 0.17 16:40 - 16:50 0.17 1.50 4.00 Plans are to pickup a mill and motor to try and mill through fill and clean out the fill in am. BJ coil on location, started up equipment added lubricator to extend above the BOP's. Held a PJSM and discussed envirionmental and safety issues. disscussed sliping issues with new snow on ice around the well head. MU 1 3/4" coil with the following BHA. Double flapper checks, 2 7/8" motor head assy. Hyd disconnet, hyd sub, 2 7/8" CTD motor, Bx X Pin x over, junk mill 4.75". Strapped tank prior to running in well. Mixed 400 BBls 3% KCL for washing out fill. Did pull test on the BHA assemble with no issues. Shell tested to 300 psig low/2500 psig high. Opened well to coil. WHP= 145 psig. RIH with coil when coil at 750' slobber line frozen up had to shut down and clear frozen slobber line. Continue running in hole with coil. WHP down to 0 psig. When CT @ 950' CTKB, WHP = 0 psig. PIP= 0 psig. Ct @ 3500' CTKB, WHP= 0 psig, PIP= 150 psig. PU coil prior to running down to tag, PUW= 10900 Ibs. Tagged fill at 3730' CTKB, PIP= 160 psig, increased pump rate to 2.1 BPM. Problem getting the pumps to stabilize at constant 2.1 BPM. Lost prime on pumps. RIH with while pumping at 2.1 BPM, PIP= 1250 psig, CT@ 3704' CTKB. WHP = 4 psig, good returns to tank. Continue working coil down hole, CT at 3730' Mill working at this depth, work mill down 20' to 3750' CTKB, PPU 3698' CTKB. Having problems reducing N2 rate below 480 SCFM, ideally would want rate at or below 350 SCFM. Continue workig coil down hole CT @ 3780' CTKB, pip = 2966 psig, WHP= 86 psig, PIR= 2.1 BPM. good returns to flow back tank. Work coil down to 3788' CTKB, tagged up on fill, pip= 3200 psig, WHP= 95 psig, pir= 2.08 BPM, N2 rate at 440 SCFM. PU coil to 3750' CTKB, pip= 3120 psig, WHP = 89 psig, good returns to flow back tank. Continue working coil down hole with motor. Worked coil down to 3808' CTKB, pip = 3614 psig, WHP = 127 psig, N2 At 248 SCFM, water rate at 2.1 BPM, good returns to FBT. PU coil to 3417' CTKB. PUW= 10508' CTKB, PIP= 3417 psig, WHP= 160 pSig, N2 rate at 268 SCFM, Water at 2.1 BPM. Move coil down to 3831', PIP= 3413 psig, Pir =2.1 BPM, n2 @ 280 SCFM, WHP= 149 PSIG Pu COIL TO 3410', pu weight good at 14900 Ibs., continue down hole with motor and mill. CT at 3865' CTKB, Stacked out motor and mill. Shut down pumps and picked up coil to 3811' C TKB, pip = 2700 psig, PIR 2.1BPM RIH with coil tubing and mill down to 3856' CTKB, pip= 3208 psig, WHP = 268 psig, good retunrs to tank, Pump bottoms up from here. PU coil above perforations to 3720' DTKB, RU to drop 3/4" ball to isolate motor and go to staight N2. WHP = 11 psig, pip= 2062 psiig, CT pu weight= 11653 Ibs Continue picking up coil, after 5 bbls fluid pumped switched to straight N2. Coil at 3605' CTM, WHP= 93 psig, Ball at motor indicated by pressure spiked up to 3600 psig. Increased N2 rate to 1000 SCFM. RIH with coil to 3850' CTKB, no fill in well bore. WHP= 101 psig, PIP wtih N2 only @ 1430 psig. PUH with coil. No fil accross perforatios. 1.33 Printed: 9/26/2006 5:02:44 PM . . Marathon Oil Company Page 13 of 1a Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 10/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From -To Hour's Code Sub Phase Description of Operations .. Code .. 1/14/2005 16:50 - 17:00 0.17 Coil at 3640' decided to pull coil out of hole. WHP= 235 psig, PIP= 1612 psig, N2 rate at 1000 scfm 17:00 - 17:10 0.17 CTa t 3562', cut N2 rate to 750 SCFM, WHP= 313 psig, good returns with some N2 to tank. 17:10 - 17:20 0.17 Continue OOH with coil, when coil at 3490' Cur N2 to 600 SCFM, PIP= 128- psig, Still good returns to flow back tank. 17:20 - 17:30 0.17 CT at 3060' CTM, went to recerculation on N2, Good steady returns to tank with N2. WHP= 190 psig, pip= 200 psig 17:30 - 17:45 0.25 CT at 2100' Returns N2 with some watre stringers, Shut down N2 unit. 17:45-18:10 0.42 Coil at surface, continue blowing down well. Well head pressure slowly bleeding down to 130 psig. Shut well in no gas indication to flow tank on gas meter. 18:10 - 22:00 3.83 RD coil unit, lay down injectors and bops. BJ left lease 1/15/2005 11 :00 - 17:00 6.00 BJ CT arrived on location, continue with racking up coil and moving to another well. Water produced to tank estimated at 30 BBLS from the cleanout of the fill. No gas was detected in the well while rigging down the coil. 1/18/2005 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP Sign in. Obtain work permit. Hold safety meeting and discuss job. 08:30 - 10:30 2.00 RURD - SLiK WBPREP Rig up unit to tree at 21-7. 10:30 - 11 :00 0.50 PULD - BHA_ WBPREP PU 3.45" GR. 11 :00 - 13:30 2.50 TAG_ BOTM WBPREP Tag ice in tree. Pump methanol and work ice. Able to move to 220' SLM. Continue working until able to RIH. Tag fill at 3877' KB. 13:30 - 14:00 0.50 RUNPUL SLiK WBPREP POOH wI gauge cutter. 14:00 - 14:15 0.25 PULD BHA_ WBPREP Program and PU gauges. 14:15 - 17:00 2.75 RUNPUL SLiK WBPREP Run static survey making stops at 3825',3800',3775',3750',3700', 3500',3000',2000', & 1000'. POOH. 17:00 - 18:00 1.00 RURD - SLiK WBPREP Download gauges and rig down equipment 2/8/2005 08:30 - 09:00 0.50 SAFETY MTG_ WBPREP Arrive at gas field. Sign in, obtain permit, hold safety meeting. 09:00 - 11 :30 2.50 RURD - SLiK WBPREP RU wireline unit. Find ice in tree. Talk to operators, modify permit, designate fire watch, and apply heat to tree. 11 :30 - 13:00 1.50 TAG_ BOTM WBPREP RIH with 3-1/2" GR. Tag fill at 3787' WLM. POOH. 13:00 - 15:00 2.00 LOG_ CSG_ WBPREP RIH wI gauges making stops at 3775',3750',3700',3500',3000',2000', 1000', Lub 15:00 - 16:30 1.50 RURD - SLiK WBPREP RD wireline unit and RU to KBU 23-6 5/17/2005 08:45 - 09:00 0.25 SAFETY DRIL WBPREP Sign in at office, fill out permit and hold safety meeting. 09:00 - 09:35 0.58 SAFETY DRIL WBPREP Fill out JSA and hold location safety meeting. Issue permit. 09:35 - 12:40 3.08 RURD - ELEC WBPREP RU to tree. Determine need for man lift and have delivered. Unflange cap and flange up tree connection. 12:40 - 14:20 1.67 TAG_ BOTM WBPREP RIH wI 4.72" GR. Tag bottom in middle of A-11 perfs at 3775'. Pull heavy to top of fluid at 2530'. Have small amount of black sticky formation material on tool. 14:20 - 16:00 1.67 LOG_ CSG_ WBPREP PU CBL tool. Log repeat pass and main pass from 3760'-2530'. Bond looks very good in A-11. Has void in A-10 zone. 16:00 - 17:30 1.50 RURD - ELEC WBPREP Complete logging passes and POOH. 10/27/2005 07:30 - 08:00 0.50 SAFETY MTG_ CMPRUN Sign in at gas field, fill out and issue work permit, hold safety meeting. 08:00 - 09:00 1.00 RURD - ELEC CMPRUN RU e-line unit. 09:00 - 10:30 1.50 TAG - BOTM CMPRUN RIH wI GR and JB. Tag fill in A-11 perfs at 3772'. 10:30 - 11:30 1.00 PULD - PKR_ CMPRUN Layout bottom portion of patch including element and 10' section. 11 :30 - 12:00 0.50 WAlTON EQIP CMPRUN Wait on production operators to hold gun arming safety meeting. Block Printed: 9/26/2006 5:02:44 PM . . Pãge.14 of 18 Marathon Oil Company Operations Summary. Report CMPRUN pad entrances and shut down modems. CMPRUN Run bottom section, but determine CCL not functional. CMPRUN Wait on production operators for radio silence to pull and inspect tool. CMPRUN Test tool string, change out CCL and PU equipment. CMPRUN RIH wI bottom element wi glass disk extension and 10' patch section. Correlate and set bottom element at 3739'. POOH. PU 20' of patch and stackable elements. RIH and install section 3706'-3727'. POOH. PU 20' of patch and elements. RIH and install section 3684'-3706'. POOH. PU 20' of patch wI stackable elements. RIH and install section 3662'-3683'. Initiate radio silence, arm firing head, and PU 10' section and top element. RIH to top of previous section. Sting in, but see less overpuJl than expected. Repeat several times, decide to POOH to inspect elements. Initiate radio silence and inspect seals. Seals look good. Sting in with seals. Pick up to verify, get into neutral weight and fire. POOH wI sheared tool. RD E-line Spot CT equipment. RU BOPs. RU flowlines, BJ choke, chicksans, and tank. Sign in at gas field, hold safety meeting, issue work permit. RU CT. Load CT. Encounter problems with plugging at full CT volume. Find ice plug at nozzle and thaw. Attempt to test BOPs. BOPs not functioning. Wait on replacement BOPs. RU replacement BOPs. Test new BOPs to 250/2500psi. Cool down N2 unit and blow fluid out of CT and ground lines to flowback tank. Line up to pump down kiJlline taking returns up CT. RIH wI CT. Begin reversing N2 at 2600' (last known fluid level). RIH to glass flapper. Tag flapper to verify depth. PUH 5' and increase N2 rate to reverse fluid. Sit on bottom pumping N2. See occasional anomolous pressures, suspect plugging in CT or lines. Continue reversing. Recover 9-1/2" in flowback tank -21bbl. Returns remaining dry. Stop pumping N2. POOH wI CT while bleeding pressure off of wellhead and CT. Continue bleeding N2 from CT and wellhead. Rig down CT unit. "" Released drop bar wI 2.70" centralizer and stem previous evening"" MI RU wire line unit. Held PJSM, wait on line truck. MU 3.0" RS pulling tool, RIH to fish dropped 3' X 1.75" stem with 1.5" swedged. Taggged fish at 3730' , latch fish POOH OOH with spear, Dropped spear without centralizer. RIH to fish spear with a 2" JUS with 2.25" bell guide. Sat down at 3772', work tools, POOH OOH with spear. MU 3.6" GR to finish breaking glass disc at 3730' KBD. POOH OOH with GR, MU 2.5" bailer, RIH to grabe sample of fill. Sat down at 3772', POOH " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To KENAI UNIT 21-7 KENAI UNIT 21-7 WORKOVER GLACIER DRILLING H C· Sub ours . ode Code Phase 10/27/2005 11:30 -12:00 12:00 - 12:30 12:30 - 14:00 14:00 - 16:00 16:00 - 16:30 0.50 WAlTON EOIP 0.50 RUNPUL ELEC 1.50 WAlTON EOIP 2.00 PULD_ PKR_ 0.50 SETREL PKR_ 16:30 - 17:00 0.50 PULD - PKR_ CMPRUN 17:00 - 18:30 1.50 SETREL PKR_ CMPRUN 18:30 - 19:00 0.50 PULD PKR_ CMPRUN 19:00 - 20:30 1.50 SETREL PKR_ CMPRUN 20:30 - 21 :00 0.50 PULD _ PKR_ CMPRUN 21 :00 - 22:30 1.50 SETREL ANCH CMPRUN 22:30 - 23:15 0.75 PULD - BHA_ CMPRUN 23:15 - 00:30 1.25 RUNPUl ELEC CMPRUN 00:30 - 00:45 0.25 INSPCT BHA_ CMPRUN 00:45 - 02:00 1.25 SETREL PKR_ CMPRUN 02:00 - 03:30 1.50 RURD - ELEC CMPRUN 10/29/2005 09:00 - 18:00 9.00 RURD - COIL CMPFLW 10/31/2005 07:30 - 08:00 0.50 SAFETY MTG_ CMPFLW 08:00 - 11 :00 3.00 RURD_ COIL CMPFLW 11:00 -12:00 1.00 PUMP_ WTR_ CMPFLW 12:00 - 13:00 1.00 TEST - BOPE CMPFLW 13:00 - 16:00 3.00 WAlTON EOIP CMPFLW 16:00 - 17:00 1.00 RURD - COIL CMPFLW 17:00 - 17:40 0.67 TEST_ BOPE CMPFLW 17:40 - 18:30 0.83 BLOWD COIL CMPFLW 18:30 - 19:20 0.83 RUNPUL COIL CMPFLW 19:20 - 22:00 2.67 PUMP_ N2 - CMPFLW 22:00 - 22:30 0.50 RUNPUL COIL CMPFLW 22:30 - 23:00 0.50 BLOWor COIL CMPFLW 23:00 - 01 :30 2.50 RURD - CMT - CMPFLW 11/4/2005 08:30 - 10:00 1.50 10:00 - 11 :00 1.00 11 :00 - 12:30 1.50 12:30 - 12:35 0.08 12:35 - 13:55 1.33 13:55 - 15:00 1.08 Start: Rig Release: Rig Number: Spud Date: 5/25/2002 End: Group: 10/3/2004 5/30/2002 1 Description ofOperati<¡>n$ " . Printed: 9/26/2006 5:02:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/4/2005 11/10/2005 11/15/2005 11/17/2005 11/18/2005 . . Page 15 of 18 Marathon Oil Company Operations Summary Report .' KENAI UNIT 21-7 KENAI UNIT 21-7 WORKOVER GLACIER DRILLING Rrom ;. To Hours Code Sub Phase Code 15:00 - 16:00 16:00 - 17:30 17:30 - 18:05 1.00 1.50 0.58 18:05 - 19:10 1.08 07:45 - 08:00 0.25 SAFETY MTG_ CLNOUT 08:00 - 09:20 1.33 RURD - SLiK CLNOUT 09:20 - 10:00 0.67 SAIL_ FILL CLNOUT 10:00 - 10:30 0.50 SAIL_ FILL CLNOUT 10:30 - 11 :00 0.50 SAIL_ FILL CLNOUT 11 :00 - 11 :20 0.33 BAIL_ FILL CLNOUT 11 :20 - 11 :40 0.33 BAIL_ FILL CLNOUT 11:40-12:15 0.58 BAIL_ FILL CLNOUT 12:15 - 12:50 0.58 BAIL - FILL CLNOUT 12:50 - 13:30 0.67 BAIL - FILL CLNOUT 13:30 - 14:00 0.50 TAG - SOTM CLNOUT 14:00 - 16:00 2.00 RURD_ SLiK CLNOUT 09:00 - 09:30 0.50 SAFETY MTG_ WRLN 09:30 - 10:00 0.50 SAFETY MTG_ WRLN 10:00 - 11 :00 1.00 WAlTON EOIP WRLN 11 :00 - 12:30 1.50 RURD - ELEC WRLN 12:30 - 13:30 1.00 LOG_ CSG_ WRLN 13:30 - 14:00 0.50 SLOWD µrBG_ WRLN 14:00 - 17:00 3.00 LOG_ CSG_ WRLN 17:00 - 18:30 1.50 RURD - ELEC WRLN 09:30 - 10:00 0.50 SAFETY MTG_ CMPPRF 10:00 - 10:30 0.50 SAFETY MTG - CMPPRF 10:30 - 12:30 2.00 RURD ELEC CMPPRF 12:30 - 13:30 1.00 RUNPUL ELEC CMPPRF 13:30 - 14:00 0.50 PULD_ PGUN CMPPRF 14:00 - 15:00 1.00 PERF - CSG - CMPPRF 15:00 - 17:00 2.00 RURD - ELEC CMPPRF 08:30 - 09:00 0.50 SAFETY MTG_ WRLN 09:00 - 10:30 1.50 RURD_ ELEC WRLN 10:30 - 11 :30 1.00 RUNPUL ELEC WRLN 11 :30 - 12:00 0.50 PULD LOG WRLN 12:00 - 13:00 1.00 RUNPUL ELEë WRLN 13:00 - 14:00 1.00 WAlTON EOIP WRLN 14:00 - 15:15 1.25 RUNPUL ELEC WRLN 15:15 - 16:30 1.25 RURD - ELEC WRLN Start: 10/3/2004 Rig Release: 5/30/2002 Rig Number: 1 Spud Date: 5/25/2002 End: Group: Description of Operptions OOH with sample, sample black, sandy with contaminated cement. MU PIT tool string, RIH to take temperature/pressure log. Fluid level at 3200 ' KBD. determined by down pass. Make up pass, stop log at 2900'., continue POOH SHP::: 270 psig, 91 deg at 3778' KBD RD MO equipment, WHP::: 20 psig during operation, no change at surface Arrive at gas field, hold safety meeting, sign in and obtain work permit. RU Slickline unit to 7" tree wI 7" lub xo to 3" wireline valve and lub. PU 3" Bailer and RUH. Work from 3767'-3773'. POOH wI full bailer. Cant. bailing 3771'-3773'. POOH wI full bailer. Bail 3773'-3776'. POOH wi broken flapper and little sandlcement. Bail 3776'-3778', POOH wI full bailer. Bail 3776'-3779'. POOH wi full bailer. Bail 3778'-3780'. POOH wI full bailer. Sail 3780'-3787'. POOH wi full bailer. Bail at 3787' break through to 3865'. POOH wI full bailer. PU 3.74" GR to find fluid level. See fluid at 2610' WLM. RD slickline unit. Boom truck radiator hose split while departing field. Had spill on road. Reported spill and cleaned up. Sign out and depart. Sign in at gas field, hold safety meeting, issue work permit. Hold location safety meeting. Determien grease unit required to accommodate well pressure. Trip crane with grease unit from Falls Creek. RU E-line truck. Run PIT log with 600psi applied gas pressure. Find fluid level at 3420'. Tag fill at 3810'. PUH to 3200' Blow down well to 85psi. Make additional PIT passes with about 1hr between. See repeated fluid level at 3200'. POOH wI gauges. RD equipment and depart. Sign in at gas field, obtain work permit, hold safety meeting Speak with drilling, hold location safety meeting. Spot and RU equipment. Pressure up flowline with lease gas (slowly) up to -450psi. RIH wI PIT temp tool and see fluid level at 3414'. Hold safety meeting, clear work area, and arm radio safe gun. RIH w/6 shots squeeze perfs loaded in 3-3/8" HSC. Perforate over 1.5' interval 3800.5'-3802'. Leave stainless jumper gas line to tree. POOH. Rig back E-line for night. Sign in at gas field, hold safety meeting, obtain work permit. Hold location safety meeting, spread sand on slickl surfaces and RU E-line truck. Run PIT log. Find fluid level at 3450' and tagged fill 3774'. POOH. PU junk basket at 3.5" GR. RIH to fill. Work JS to 3775'. POOH. Find contaminated cement solids. Wait on 3" bailer from shop. RIH wI 3" bailer. Make about 7', bailed to 3782'. POOH wI bailer full of cement solids. RD Expro. Printed: 9/26/2006 5:02:44 PM . . .. Marathon Oil Company Page 16 of 18 Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Spud Date: 5/25/2002 Event Name: WORKOVER Start: 10/3/2004 End: Contractor Name: Rig Release: 5/30/2002 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From., To Hours Code Sub Phase D~scription of Operations Code 11/19/2005 09:00 - 09:30 0.50 SAFETY MTG_ WRLN Sign in at office, obtain work permit, hold safety meeting. 09:30 - 09:45 0.25 SAFETY MTG_ WRLN Hold location safety meeting. 09:45 - 11 :00 1.25 RURD_ SLiK WRLN RU slickline unit. 11 :00 - 14:00 3.00 BAIL_ FILL WRLN RIH wI 3" DD bailer. Tool string is falling slowly at 60fpm starting at 1500'. RIH through all perfs to 3815' KB. Pulling 800# over coming out of hole. Unit broke down mid-way out. Wait for mechanic with temporary fix. 14:00 - 14:45 0.75 RURD - SLiK WRLN POOH wI toolstring. 14:45 - 16:00 1.25 RURD - SLiK WRLN RD unit and return to shop for repairs. 12/2/2005 08:45 - 09:00 0.25 SAFETY MTG_ CLNOUT Sign in and obtain work permit. Hold safety meeting. 09:00 - 09:15 0.25 SAFETY MTG_ CLNOUT Hold location safety meeting, fill out JSA. Meet with tool pusher. 09:15 - 10:40 1.42 RURD - SLiK CLNOUT RU new slickline unit. 10:40 - 11 :20 0.67 BAIL - FILL CLNOUT RIH wI 3" DO bailer to 3795' KB. Work and POOH. Full of heavy, fluid. 11 :20 - 11 :45 0.42 BAIL - FILL CLNOUT RIH wI same to 3804' KB. POOH wI empty bailer. 11 :45 - 12:20 0.58 BAIL - FILL CLNOUT RIH wI same to 3805' KB. Work bailer and recover thick fluid. 12:20 - 13:00 0.67 BAIL - FILL CLNOUT RIH wI same to 3816'. Work bailer. Return with sand. 13:00 - 13:40 0.67 BAIL - FILL CLNOUT RIH wI same to 3830' KB. Work bailer and POOH wI sand. 13:40 - 14:20 0.67 BAIL_ FILL CLNOUT RIH wI same to 3833'. POOH wI sand. 14:20 - 15:10 0.83 BAIL_ FILL CLNOUT RIH wI same to 3841'. POOH wI sand. 15:10 - 16:30 1.33 RURD_ SLiK CLNOUT RD slickline unit. Clean up area. 12/3/2005 12:30 - 12:45 0.25 SAFETY MTG_ CMPPRF Sign in at gas field, obtain work permit. Discuss job. 12:45 - 13:00 0.25 SAFETY MTG_ CMPPRF Hold safety meeting and discuss work with drilling rig due to close proximity. 13:00 - 14:15 1.25 RURD - ELEC CMPPRF Wait on man lift. RU e-line unit. 14:15 - 16:00 1.75 LOG_ CSG_ CMPPRF Frun PIT from 3000'-3810'. POOH. 16:00 - 17:30 1.50 PERF _ CSG_ CMPPRF PU 2' 3-3/8" squeeze gun. RIH and correlate. Perforate 3780'-3782' (log indicates .45 fluid gradient). 17:30 - 18:30 1.00 RURD - ELEC CMPPRF RD e-line and leave location. 12/23/2005 12:00 - 12:30 0.50 SAFETY MTG_ WRLN Sign in at gas field, obtain work permit. Discuss job. 12:30 - 14:00 1.50 RURD SLiK WRLN RU slickline unit. THP = 650 psi from aUampted backflow. 14:00 - 14:50 0.83 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3490'. Did not see fluid level. Recovered 9.5 gal water. 14:50 - 15:30 0.67 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3640'. Did not see fluid level. Recovered 13.5 gal water. Blew down THP to 10 psi. 15:30 - 16:00 0.50 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3770'. Did not see fluid level. Recovered 14.5 gal water. 16:00 - 16:45 0.75 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3770'. Did not see fluid level. Recovered 15.5 gal water. 16:45 - 17:30 0.75 RURD - SLiK WRLN Rig back slickline and leave location. 12/28/2005 09:30 - 10:00 0.50 SAFETY MTG_ WRLN Sign in at gas field, obtain work permit. Discuss job. 10:00 - 10:30 0.50 RURD SLiK WRLN RU slickline unit. THP = 25 psi. 10:30 -11:00 0.50 RUNPUL SLiK WRLN RIH wI 3.5" liB and tag fluid level at 3490'. 11 :00 - 12:00 1.00 RURD_ SLiK WRLN Rig back slickline and leave location. 12/29/2005 10:30-11:10 0.67 SAFETY MTG_ WRLN Sign in at gas field, obtain work permit. Discuss job. 11:10 -11:40 0.50 RURD SLiK WRLN RU slickline unit. THP = 25 psi. 11 :40 - 12:00 0.33 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3690'. Did not see fluid level. Recovered 19 gal water. 12:00 - 12:30 0.50 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3690'. Tagged fluid at 3510. Recovered 21 gal water. 12:30 - 12:50 0.33 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3690'. Recovered 16.8 gal water. 12:50 - 13:10 0.33 RUNPUL SLiK WRLN RIH w/ 3.5" X 40' bailer. Stop at 3700'. Tagged fluid at 3540. Recovered 19 gal water. 13:10 - 13:35 0.42 RUNPUL SLiK WRLN RIH wI 3.5" X 40' bailer. Stop at 3690'. Recovered 16.8 gal water. Printed: 9/26/2006 5:02:44 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/29/2005 12/30/2005 12/31/2005 1/10/2006 . Marathon Oil Comþany Operations Summary Report KENAI UNIT 21-7 KENAI UNIT 21-7 WORKOVER Page 17 of1ª Start: Rig Release: Rig Number: Spud Date: 5/25/2002 End: Group: 1 0/3/2004 5/30/2002 1 GLACIER DRILLING From - To Hours Codê ¿~dbe Phase 13:35 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 16:20 16:20 - 16:35 16:35 - 17:30 08:45 - 09:15 09:15 - 09:45 09:45 - 10:15 10:15 - 10:45 10:45-11:15 11:15 -11:45 11:45-12:15 12:15 - 12:45 12:45 - 13:25 13:25 - 14:15 14:15 - 15:00 15:00 - 15:45 15:45 - 16:15 16:15 - 17:00 17:00 - 17:30 08:30 - 09:00 09:00 - 09:45 09:45 - 10:00 10:00 - 10:35 10:35-11:15 11:15 -11:35 11 :35 - 11 :45 11:45-12:10 12:10 - 12:45 12:45 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:45 15:45 - 16:30 0.42 0.50 RUNPU 0.50 RUNPU 0.50 RUNPU 0.50 RUNPU 0.33 RUNPU 0.25 RUNPU 0.92 RURD_ SLlK 0.50 SAFETY MTG_ 0.50 RURD_ SLlK 0.50 RUNPU SLlK 0.75 RUNPU 0.50 RUNPU 0.50 RUNPU 0.50 RUNPU 0.50 RUNPU 0.50 RUNPU 0.67 RUNPU 0.83 RUNPU 0.75 RUNPU 0.50 0.75 RUNPU 0.50 RURD SLlK 0.50 SAFETY MTG_ 0.75 RURD_ SLlK 0.25 RUNPU SLlK 0.58 RUNPU SLlK 0.67 RUNPU SLlK 0.33 RUNPU SLlK 0.17 RUNPU SLlK 0.42 RUNPU SLlK 0.58 0.75 RURD_ SLlK WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN WRLN Description of Operations RIH wI 3.5" x 40' bailer. Stop at 3700'. Tagged fluid at 3555. Recovered 19 gal water. RIH wI 3.5" X 40' bailer. Stop at 3700'. Tagged fluid at 3577. Recovered 18.8 gal water. RIH wI 3.5" X 40' bailer. Stop at 3720'. Tagged fluid at 3600. Recovered 14.6 gal water. RIH wI 3.5" X 40' bailer. Stop at 3750'. Tagged fluid at 3615. Recovered 21 gal water. RIH wI 3.5" X 40' bailer. Stop at 3730'. Tagged fluid at 3630. Recovered 19 gal water. RIH wI 3.5" X 40' bailer. Stop at 3725'. Tagged fluid at 3643. Recovered 16.8 gal water. RIH wI 3.5" X 40' bailer. Stop at 3740'. Tagged fluid at 3660. Recovered 19 gal water. Rig back slickline and leave location. THP = 35 psi Sign in at gas field, obtain work permit. Discuss job. RU slickline unit. THP = 35 psi. RIH wI 3.5" X 40' bailer. Stop at 3720'. Tagged fluid at 3540. Recovered 19 gal water. RIH wI 3.5" X 40' bailer. Stop at 3750'. Recovered 19 gal water. RIH wI 3.5" X 40' bailer. Stop at 3750'. Recovered 14.6 gal water. RIH wI 3.5" X 40' bailer. Stop at 3770'. Recovered 14.6 gal water. RIH wI 3.5" X 40' bailer. Stop at 3775'. Recovered 11.2 gal water. RIH wI 3.5" X 40' bailer. Stop at 3775'. Recovered 4.2 gal water. LD 3.5" X 40' water bailer and pu 3" X 10' drive down sand bailer. RIH wI 3." X 10' DO bailer. Set down at 3784'. Work to 3790'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3790'. Work to 3799'. Recovered 2 gal sand. RIH wI 3." X 10' DD bailer. Set down at 3800'. Work to 3806'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3803'. Work to 3809'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3810'. Work to 3813'. Recovered 2 gal sand. Rig back slickline and leave location. Sign in at gas field, obtain work permit. Discuss job. RU slickline unit. THP = 17 psi. Well was blown down to 0 in the night. RIH wI 3.5" LIB. Set down at 3800'. Maybe tagged fluid at 3790. RIH w/3.5" X 40' bailer. Stop at 3790'. Recovered 2.1 gal water. RI H wI 3.5" X 40' bailer. Stop at 3790'. Recovered 2.1 gal water. RIH wI 3.5" X 40' bailer. Stop at 3790'. Recovered 1.5 gal water. LD 3.5" X 40' water bailer and pu 3" X 10' drive down sand bailer. RIH wI 3." X 10' DO bailer. Set down at 3803'. Work to 3809'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3810'. Work to 3813'. Recovered 2 gal sand. Rig back slickline and leave location. Sign in at gas field, obtain work permit. Discuss job. RU E-line unit. THP = 56 psi. RIH wI SRO Pressure I Temp tool. Set down at 3806'. Tagged fluid at 3798. Bottom perf at 3802'. Rig back E-line and leave location. Printed: 9/26/2006 5:02:44 PM . . \. ~ Page 18 oU8 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 21-7 Common Well Name: KENAI UNIT 21-7 Event Name: WORKOVER Contractor Name: Rig Name: GLACIER DRILLING Date From·- To Hours .COde6'o~e Phase 1/11/2006 08:00 - 08:30 0.50 SAFETY MTG_ WRLN 08:30 - 09:30 1.00 RURD - SLlK WRLN 09:30 - 10:05 0.58 RUNPU SLlK WRLN 10:05 - 10:45 0.67 RUNPU SLlK WRLN 10:45 -11:30 0.75 RUNPU SLlK WRLN 11 :30 - 12:05 0.58 RUNPU SLlK WRLN 12:05 - 12:40 0.58 RUNPU WRLN 12:40 - 13:15 0.58 RUNPU WRLN 13:15 - 13:45 0.50 RUNPU WRLN 13:45 - 14:30 0.75 RURD - SLlK WRLN 1/12/2006 08:00 - 08:45 0.75 SAFETY MTG_ WRLN 08:45 - 10:50 2.08 RURD_ ELEC WRLN 10:50 - 12:10 1.33 PERF_ CSG_ WRLN 12:10 - 13:00 0.83 FLOW_ TEST WRLN 13:00 - 13:47 0.78 PERF_ CSG_ WRLN 13:47 - 13:50 0.05 FLOW_ TEST WRLN 13:50 - 13:56 0.10 RUNPU WRLN 13:56 - 14:00 0.07 RUNPU WRLN 14:00 - 14:45 0.75 RUNPU WRLN 14:45 - 16:35 1.83 RUNPU WRLN 16:35 - 17:45 1.17 RURD - ELEC WRLN Start: 1 0/3/2004 Rig Release: 5/30/2002 Rig Number: 1 Spud Date: 5/25/2002 End: Group: Description of Operations Sign in at gas field, obtain work permit. Discuss job. RU slickline unit. THP = 35 psi. RIH wI 3." X 10' DO bailer. Set down at 3805'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3815'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3823'. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3832'. Worked down to 3842'. Recovered 2 gal sand. RIH w/3.J60" gauge cutter. Tag patch and tag bottom. TO tag at 3864' corrected to patch. RIH wI 3." X 10' DO bailer. Set down at 3850'. Worked down to 3851'. Hard Bottom. Recovered 2 gal sand. RIH wI 3." X 10' DO bailer. Set down at 3851'. Hard Bottom. Recovered 2 gal sand. Rig back slickline and leave location. Sign in at gas field, obtain work permit. Discuss job. RU E-line unit. THP = 4 psi. RI Hw/3-3/8" x 20' 6SPF perf gun #1. Reperforate 3756 - 3776' Stuck in patch, worked free and POH. Well built to 105 psi. Opened well. Flow is around 500 MCF/day. RIHw/3-3/8" x 26' 6SPF perf gun #2. Close well and reperforate 3776 - 3802' at 65 psi THP. Blew gun up hole. gun stuck in patch. THP = 65 psi to 85 psi in 3 minutes Worked stuck gun. 85 psi to 97 psi in 6 minutes Gun free. POH. THP = 103 psi. OOH well flowing at 68 psi, 1000 MCF/day Reheaded line and RIH PIT tool. THP = 79 psi, Top perforation (3756) = 88 psi. Tagged bottom at 3854' with 95 psi. POH PIT tool. Rig back slickline and leave location. Printed: 9/26/2006 5:02:44 PM ... . ~ Alaska Region Domestic Production "- ~ r'- (fJ\) Marathon MARATHOI Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ¡th Ave Anchorage, Alaska 99501 RECEIVED APR , Ð ¡OD4 Alaåa Oil & Gas cø1, C '. ARcho,," omm;SSlon April 30, 2004 Reference: KU 21-7WO Dear Mr. Aubert: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for a proposed workoverto Marathon well KU 21·7. The purpose of this workover is to pull the existing 2-7/8" velocity string and cement 5-1/2" casing over the perforated interval to isolate the ,/ A-8 sand. The A-10 and A-11 sands will be reperforated and returned to production. I have included a procedure and wellbore diagrams for your review. If you need any additional information, I can be reached at 907-564-6303 or bye-mail at dmtitus@marathonoil.com. Sincerely, t~ Denise M. Titus Production Engineer OR'G\NAL I¡,. . ... ~ ~ /'"""\ r'\. V'-lc:'~ IJ7S ~1~I2..ODf- sl3 / 'I--- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing 2l Variance Perforate Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) MARATHON OIL COMPANY Development L Exploratory _ 14 feet 3. Address Stratigraphic _ 7. Unit or Property name PO Box 196168 Anchorage. AK 99519·6168 Service Kenai Unit 4. Location of well at surface 362' FSL, 1024'FWL. Sec. 6, T4N, R11W, S.M. At top of productive interval 53'FNL, 1601'FWL, Sec. 7, T4N, R11W, S.M. At effective depth At total depth 101'FNL, 1672'FWL, T4N, R11W, S.M. 12. Present well condition summary Total Depth: measured drilling (approx) true vertical Effective depth: (approx) measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 48' 1195' 4417' Perforation depth: I W orkover KU 21-7 8. Well number ./ KU 21-7 9. Perm~mber 65-8 10. API number 50-133·1009200 ./ 11. Field/Pool Kenai Gas Field! Pool 3 4453 feet Plugs (measured) Cement Retainer at 3904' 4366 feet 3904 feet Junk (measured) 3827 feet Size Cemented Measured depth True vertical depth 20" Driven 48' 48' 10-314" 820 $X 1195' 1189' 7-5/8" 550 $X 4417' 4330' measured: A-a, A-1 0, and A-11 sands: 3593'-3618'; 3661'-3736'; 3756'-3802' true vertical: A.a, A-10, and A-11 sands: 3523'-3547',3589'-3664'; 3682'-3727' Tubing (size, grade, and measured depth) Velocity string: 2-7/8", 6.4ppf, N·aO, EUE ard to 3593' Packers and SSSV (type and measured depth) N/A 13. Attachments CE'~ED APRJ,J2004 Alaska Oil & Gas Cons. Co_sion Anchorage t date for commencing operation Description summary of proposal_ Detailed operation program L BOP sketch 16. I Name of approver 15. Status of well classification as: Oil Gas.JL Suspended _ Date approved ing is true and correct to the best of my knowledge. Signed Denise M. Titus Form 10-403 Rev 06/15/88 Title Production Engineer Date 4/30/04 Commissioner Date () ORIGINAL ,,-BFl MA'f ().4 ., ) ~ l )Ç ~OO.~ $uþjå~;:KQ:21~t:\ ' ",,"', ' .. ,," ,'. ", :Fr¿J?1i' Titus, DeniSe M.It <drrititus@marathonoiLcom> Dat.é:' W.ed,'t7..Nov..20Q416:49:38 ~O900' '. ~i15- øø'ð Winton, In May we received Sundry Approval #304-159 for a rig workover to recomplete well KU 21-7 with 5-1/2" pipe inside the existing casing. The original workover objective was to exclude the wet A-8 perfs. Production would be restored in the A-10 and A-11 perforations. Following the workover and associated facility work, the A-11 perfs were added and flow tested at 6-7MMcfd. This rate was lost after the addition of the A-1 0 perfs. The A-11 was isolated and a coiled tubing squeeze was completed to addresss a channel behind the 5-1/2" pipe to the wet A-8. To preserve the A-11 zone, a plug was set above the perfs which could be pulled following the squeeze job. Cement has been pumped and circulation achieved to indicate isolation of the A-1 0 perfs. Now, after several days of slickline and coiled tubing fishing, it appears that the plug beneath the squeeze is cemented in place. At this point, we have exhausted all of our CT fishing options and would like to mobilize the Glacier Rig to complete the work to fish the plug over the A-11 perfs. We have an opening in our rig schedule immediately following the rig completion of well KBU 42-6. This would be a good oportunity to complete the fishing and restore production to the A-11 for the winter deliverability season. Per our discussion today, we would proceed under the existing Sundry. Please let me know if you have any questions or concerns regarding the planned work. A 10-404 will be submitted upon restoring production to KU 21-7. Thank You, Denise Titus Production Engineer Marathon Oil Company 907.283.1333 5CANNEC! NOV 1 8 2004 I(,~ ..ooe Winton, 1°4 ~ ISq Earlier this year we obtained an approved sundry for a workover on KU 21-7 to isolate the A-8 sand from the producing A-10 and A-11 sands. A 5-1/2" liner was run the length of the well and cemented around the perforations. The A-11 sand was initially perforated and tested at 6MMcfd at 65psia. Upon adding the A-1 0 perfs, production fell to 1.5MMcfd. This loss in production is likely due to channeling to the A-8 behind the 5-1/2" pipe. Marathon intends to squeeze the A-10 perfs with a retrievable plug above the A-11 perfs. The squeeze is intended to remedy the water channel allowing restored production to the A-11 zone. Details of the squeeze will be included with the subsequent report for the KU 21-7 workover. A decision to reperf the A-10 will be made at a later date at which time, we will request a separate sundry approval. This work is anticipated to begin 1017/04. Please let me know if you have any questions or concerns. Thank You, Denise Titus Operations Engineer Marathon Oil Company Kenai, AK 907.283.1333 SCANNED DCï 0 9 2004 ~ ~ M Marathon ~: Oil Company t ~ Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ¡th Ave Anchorage, Alaska 99501 RECEIVED APR j Ð jDD4 AIBlka Oil & Gas C ..) ons. Commission AnChorage April 30, 2004 Reference: KU 21-7WO Dear Mr. Aubert: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for a proposed workover to Marathon well KU 21-7. The purpose of this workover is to pull the existing 2-7/8" velocity string and cement 5-1/2" casing over the perforated interval to isolate the /' A-8 sand. The A-10 and A-11 sands will be reperforated and returned to production. I have included a procedure and wellbore diagrams for your review. If you need any additional information, I can be reached at 907-564-6303 or bye-mail at dmtitus @ marathonoil.com. Sincerely, ~; vf#Þ Denise M. Titus Production Engineer OR1G\NAL ~ ~ /"""'\ ~ \fJ~ ft- ';) I "s { Z-f?D t- oE s / 3 / 1---- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown - Re-enter suspended well - Alter casing - Repair well - Plugging - Time extension - Stimulate- Change approved program - Pull tubing X. Variance - Perforate - Other - 2. Name of Operator MARATHON OIL COMPANY 3. Address PO Box 196168 Anchorage, AK 99519-6168 4. Location of well at surface 362' FSL, 1024'FWL, Sec. 6, T4N, R11W, S.M. At top of productive interval 53'FNL, 1601'FWL, Sec. 7, T4N, R11W, S.M. At effective depth At total depth 101'FNL, 1672'FWL, T4N, R11W, S.M. 12. Present well condition summary Total Depth: measured drilling (approx) true vertical Effective depth: (approx) measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 48' 1195' 4417' 5. Type of Well: Development l Exploratory - Stratigraphic - Service 6. Datum elevation (OF or KB) 14 feet 7. Unit or Property name Kenai Unit I Workover KU 21-7 8. Well number / KU 21-7 9. Permiywmber 65-8 10. API number 50-133-1009200 / 11. Field/Pool Kenai Gas Field! Pool 3 4453 feet 4366 feet Plugs (measured) Cement Retainer at 3904' 3904 feet 3827 feet Junk (measured) Size Cemented Measured depth True vertical depth Driven 48' 48' 820 sx 1195' 1189' 550 sx 4417' 4330' 20" 10-3/4" 7-5/8" measured: A-8, A-1O, and A-11 sands: 3593'-3618'; 3661'-3736'; 3756'-3802'LlECEIVED true vertical: A-8, A-1O, and A-11 sands: 3523'-3547', 3589'-3664'; 3682'-3727~~ Tubing (size, grade, and measured depth) Velocity string: 2-7/8", 6.4ppf, N-80, EUE 8rd to 3593' APRJ ,Jfõå4 Packers and SSSV (type and measured depth) N/A Alaska Oil & Gas Cons. Commission Anchorage Perforation depth: date for commencing operation Description summary of proposal - Detailed operation program 1L- BOP sketch - 13. Attachments 15. Status of well classification as: Oil- Gas--2L Suspended - Name of approver Date approved 17. I herebtrt~yr;¡$h t f oing is true and correct to the best of my knO~ledge. . Signed Title Production Engineer Denise M. Titus FOR CO mSSION USE ONLY Approved by the order of the Commission Form 10-403 Rev 06/15/88 Date 4/30/04 :APproval N°'364-ICSQ ./ Commissioner Daæ "sf r: r ORIGINAL RBDUS BFl MA'f ()4 ?""~ ,..-- ,~) ~ ~ Marathon Oil Company Alaska Region KU 21-7 Kenai Gas Field, Pad 14-6 Workover Procedure WBS # WO.O4.10475.EXP History: KU 21-7 is a low pressure Sterling Pool 3 well, completed in 7-5/8" casing with a 2-7/8" / jointed pipe velocity string. Recent diminished production and surface evidence of sand erosion indicate probable zone failure. There is a history of failure in the Pool 3 A-8 sand. In a nearby Pool 3 well, ,/" isolation ofthe A-8 sand was required to maintain production from KU 14-6. Objective: Pull current 2-7/8" tubing completion and run 5-112" pipe to surface. The pipe will be cemented inside the original 7-5/8" casing through the Pool 3 zones. The A-lO and A-11 / sands will then be re-perforated and the well returned to production. Procedure: ~ 1. Contact Kenai Gas Field Office daily for work permit, discuss safety and environmental - ~ - - ----- - concerns. -~~----?-- - ~""-~~~-~- -:.--... 2. Remove flow linesfó stô~d PLC control panel to the electrical shop. 3. Contact ABB Vetco wellhead representative, Set BPV in the tubing hanger and 6" VR plug in the tubing head side outlet. 4. MIRU Glacier Drilling rig #1. a. Remove BPV and pump high viscosity PIo-vis. Pump adequate pill to isolate all sands in first attempt. Circulate well to remove all trapped gas. Install two way check. b. ND tree. Inspect and verify hanger threads are (2-7/8" EUE 8rd, 2-7/8" EUE 8rd landing joint appro x 22' long will be needed). (11" 3M by 13 5/8" 5M DSA is needed to NU 13 5/8" stack) NU 13 5/8" 5M Weatherford BOPE equipped with 27/8" -5.5" VBR 5M rams in upper ram cavity, and test BOPE to 250/2000 Pull /' two way check. An additional single gate ram will not be used il):)his workover to allow more rig clearance and due to the low BHP of 233psi . 5. Rig up Weatherford Tubing services with 2-7/8" tubing tongs and equipment. Pu1l2- 7/8" velocity string. There is no packer to fish. TOH standing tubing in the derek, until 20K of pipe wt remains in well. 6. PU 4" HT drillpipe. RIH w/ 6.75" bullnose and string mill to bottom. 7. MU storm packer on drillpipe, RIH and set 3 stands below surface. POOH ND BOP /' stack. - ------- ~ c~ 8. Remove existing tubing head and install and pressure test replacement tubing head. Ny BOP stack and hydro-test to 250/2000 psi. TIH, engage RTTS. POOH, laying down remaining drill pipe. 9. RU Weatherford with hydraulic tongs and slips for 5-1/2", 17ppf, L-80, Hydrill 511 casing. Rabbit, number, and strap 5-112" 17ppf casing. MU float shoe, 2 stand shoe --- track, float collar and remaining casing to surface with centralizers on bottom 20 joints 10. MIRU BJ Cementing Services. Cement pipe per recommendation pumping drilling mud behind cement plug. WOC per BJ recommended hours. 11. Land slips with auto pack off in casing head per Vetco specifications. Install wear bushing. 12. Rlli with bit and 2-7/8" tubing. Drill cement to 3890'. Circulate 6% KCl and press~ test casing to 1000psi for 30 minutes. POOH laying down tubing. 13. Set BPV, nipple down BOPE. 14. NU and pressure test old tubing head with side outlets. 15. Pull BPV, set two way check, PT to 2000 psi. 16. RDMO Glacier Rig # 1 17. RU changeover/CT hanger spool from 7" 3M to 4 1/16" 10M above 7" tree valves. 18. RU ABB Vetco, pull BPV. 19. RU flow back tank, 2" chiksan and choke skid for CT operations. 20. RU BJ services to tree. a. RU CT with 4 1/16" 10M BOPE stack and 1.75" CT. b. PT BOPE to 75/2000 psi. c. MU BHA with no check valves to reverse circulate out 6% KCL. d. Rlli to PBTD, reverse circulate out by pumping nitrogen down CT annulus. e. POOH, pressure up on wellbore leaving 250 psi of nitrogen on casing. f. RD BOPE to 7" master valves. Rig down BJ Coiltech. / 21. MIRU electric line unit. a. RU 7" BOPE with 5-1/2" lubricator. b. Pressure test lubricator and BOPE to 75/2000 psi. c. Perforate A-10 & All with 33/8" hollow steel carries at 6 spf. d. Flow test well to production facility recording rates and FrP. e. Run BHP gauges to record static BHP. Rig down electric line. / ~ ,~ ,"- 22. RU BJ services to tree. a. RU CT with 4 1/16" 10M BOPE stack and 1.75" CT. b. PT BOPE to 75/2000 psi. c. MU BRA with jetting nozzle and double check valves to jet in well. d. Strap flow back tank to monitor fluid return volumes. RIH to PBTD, jetting in well to flow back tank. POOR 23. RD BJ Coiltech. 24. Should the well be unable to obtain a sustained flow rate without loading problems a separate procedure and sundry application will be written for a concentric CT velocity string installation. Contacts: Drilling Operations Geologist Reservoir Eng Will Tank Don Eynon David Brimberry Denise Titus Work Phone 564-6310 283-1337 564-6402 564-6303 Pa2er 268-4374 398-9954 529-0527 (cell) 394-2733 Gas 21 Pad 14-6 Proposed ¿t Lonqstrlnq Perfs B-3 3977'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (covered with fill) 4072'-4102' (covered with fiil) 4128'-4160' (covered with fill) B-4 4162'-4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 430T-4329'(Sqzd 11/23/81\ 20", 94#, H-40 Drivepipe @48' II... 10-3/4",32.75", H-40, SIC casing @ 1195' Cmt w/ 800 sx Pool 3 perforations (12/81) 3576'-3578' sqzd TVDs A-8 3593'-3618' (8 spf) 3523'-3547' A-10 3661 '-3736' (8 spf) 3589'-3663' A-11 3756'-3802' (8 spf) 3682'-3727' 3808'-3810' sqzd Baker Cement Retainer @ 3904' MD / 3827'TVD (5/29/02) Baker Model D packer @ 3928' Cement Plug 4009'-4055' (11/14/97) 7 -5/8" 26/4 ppf, J-55, LTC Casing @ 4417' Cmt w/ 550 sx Kenai Gas Field KU 21-7 Pad 14-6 ,i Velocity String: 2-7/8", 6.4ppf, EUE 8rd ID=2.441 " XN Nipple @ 3593' MD ID=2.205" wi 2.313" seal bore XN Nipple @ 3688' MDI 3615' TVD ID=1.790" wi 1.813" seal bore Lonqstrinq Perfs B-3 3971'-4022' (10/15/97) 3978'-3988' (8/16/81) 3991 '-4022' (Cmt piug @ 4009') 4036'-4048' (Iso. w/ cmt plug) 4056'-4070' (covered with fill) 4072'-4102' (covered with fill) 4128'-4160' (covered with fill) B-4 4162'-4172' (covered with fill) 4180'-4202' (covered with fill) B-5 4256'-4260' (Sqzd 11/18/81) 4301'-4329' (Sqzd 11/23/81 \ 20",94#, H-40 Drivepipe @48' 10.. 10-3/4",32.75", H-40, SIC casing @ 1195' Cmt wi 800 sx TOC -3500' (CBL) Pool 3 perforations (12/81) 3576'-3578' sqzd TVDs A-8 3593'-3618' (8 spf) 3523'-3547' A-10 3661 '-3736' (8 spf) 3589'-3663' A-11 3756'-3802' (8 spf) 3682'-3727' 3808'-3810' sqzd Baker Cement Retainer @ 3904' MD I 3827'TVD (5/29/02) Baker Model D packer @ 3928' Cement Plug 4009'-4055' (11/14/97) 7 -518" 26/4 ppf, J-55, LTC Casing @ 4417' Cmt wi 550 sx Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK.9g519-6168 Telephone 907/561-5311 FAX COVER LETTER DATE: PLEASE DELIVER THE FOLLOWING TO: Name: / · ~ ~.,~..~.~ ............... ~. - ........ , _ ..- ,, ,, I i 11 i iiii . i i i i .... ii Fax No.: Number ol Pages {Including coverpage): /J ...... ,;.,.:. .......... .~...,.._~..~. ........... , , ....., .- . , ,, .-- . ..-- ..- _, . .. :. - -. . ' _ _ ..... _ · "~ ,, ' . . , .... FROM' Locatlo./Exten$ion: ' !1 NOTE: ,RECEIVED ii. APR 2 3 ZOOZ iii ii i,-- ff transmission is not complete, please call 907/~61-5311. / 0 R/ '~?~%~/t ~,j/.1L Environmentally aware for the Ion9 [..~j, run. i768-.L 68~9'P8~i15+ qlO NOHJ. V~V~-moJd mdS~i:[O ZO-$Z-~dV iVl?athon Od Company Alaska Region Domestlo Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907156t-$3'1 t Fax 9071564-6489 April 23, 2002 Mr'. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t~ Ave Anch~,rage, Alaska 99501 Refe~mce: KU 21-7 Dear Mr. Maunder: An application has been submitted to workover KU 21-7 in the Kenai Gas Field. The recompletion is intended to have a 2-7/8" packerless velocity string in 7-5/8" casing. The flow path will be either up the velocity string to facilitate water lift, or up the annulus for deliverability. Annular flow from the low-pressure Sterling reservoir is currently approved in the Kenai (~as Field. A wellhead specifically designed for annular flow will be Installed. This tubing head will have dual 7-1/16" 3,000 psig valves on one side and a 2" 3,000 psig blind flange on the opposite side of the tubing head. Annular flow will only be through the 7- 1/16" outlet. Production will be controlled by a 7-1/16" 3,000 psig surface safety valve. This installation is specifically designed for annular flow due to the I~rge inside diameters exiting the tubing head. The erosional velocity and the wells predicted capability are outlined on the attached document. A 2,9/16" 3,000 psig tree will be installed on the tubing head. - If you need any additional information, I can be reached at 907-564-6317 or by e-mall at dmtitus@ marathonoil.com. Sincerely, Denise M. Titus Production Engineer RECEIVED APR 2 3 2'00~ Alaska Oil & Gas Cons. Commission 110 I~0HJ. V~tVV( M?rathon Oil Company Alaska Region Domestio Production P.O. Box 196168 Anchorage, AK 99519-6t 68 Telephone 907t56t-631t Fax 9071564-6489 April 23, 2002 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KU 2t-7 Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for a proposed workOver to Marathon well KU 21-7. The purpose of this workover is to puli the existing dual completion and recomplete as a tubingless Pool 3 well. If you need any additional information, I can be reached at 907-564-6317 or by e-mail at dmtitus@marathonoil,com, Sincerely, Denise M. Titus Production Engineer RECEIVED APR AlaskaOil &Gas Con~, Commission ~O-J ZO'd ~88-1 68~9k9~[8+ llO NOHIVaV~-moJ~ md00:Z0 ZO-~Z-JdV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request; Able,don .-. Suspend,_. Operation Shutdown__ Alter caslng_ Repair well ~ Plugging Change approved program ._. Pull tublng of Operator MARA'fHON Off. COMPANY 3. Address PO box 19616~ Anchorage, AK 99519-6168 4. Location of well at surf~-- ~'~ ~(- ~./ .... i' 362' FSL, 02,~ FWL, Sec. &T4N, R11W, S,M, At top of pr~ductiV~ interval 53'Ft~IL, I~01'l:WL, Se~. ?, T4N, R11W, At effective depth At tot~l depth 101'FNL,, 'II572'PWL, TaN, RI 1W, S.M. t5. Type ~f-Well= Development Exploratol~ Stratlgraphio ~ Sewioe ~ Re-enter suspended well_ Time extension - Stimulate_' Variance ~ Perforate ~ Other_ 8. Datum' elevation (D~ °r KB) Workover KU 21-7 and recomplete tubingless 7. Unit o~ Property name Kenai Unit Well number KU~ -7 _._6_5_-8 well ¢onaitlon summary v' " Tote! Depth; measured drilling 4453 feet Plugs (measured) Cement Plug at 4009' (approx) true vertical 4366. feet Effective depth: measured 4009 feet Junk (meast~red) (approx) true vertical 3928 feet 10, APl number ~ ..~50-] 33-1009200 11. Field/Pool Kenai Gas Field/Pool 3 Cesl~.)g Leng{h Size Cemented Measured depth Structural Cor~ductor 48' P-0" Driven 48' SUrf@ce 1195' 10-~4" 830 sx 11 ~' IrlLet[l~iat~ Production 4417' 7-~8" 5~ sx 4417' Liner 14 f~et ~ _ RECEIV :_D 4330' Perforation d e~-{h .' ' measured; A*8, A-10, and A.i t sands?' 35~6'-3802', B-3 and 8-4 sands: 3978'-4202' true vertical: A-8, A-10. and A-11 sands: 3526'-3727'. B-$ and B-4 sands; 3899'-4118' Tubir~g (si~e, grade, a~d measured depth) Long string: 2-7/8", 6,4ppi, N-80 to 3938' Short string; 2-7/8". 6.4ppi, N-80 to 3553' Paokel~ and $SSV (type and measured depth) ^-5 dual packer et 3S42', Model D packer at 3930', 13. Attachments Description summa~j of proposal i 1~. E~llmated d~ta for commencing operation Detallecl operation program Status of well classification aa: BOP sketch ~ 16. If p('oposel was verbslly approved Name of approver 'certify ,Signed OII ~ Date approved ~oregoing is true and correct to the best of my knowledge.~ Title Production Engineer Denise M, TJtue FOR COMMISSION USE ONLY Gas ~ Suspended Date 4/15/2002 iCondltic~nt,o¢ a.pp. roval: Notify Commissiort ~0 repr. e, sentatlve may witness ~[ug ~megrl~ _ BOP Test~ Loca~on clearance ~echan~cal Inte rtt Test Subse u ~ ' ' g Y _ q ant form requh'e I0-~~ 1A ~nal ~n~ ~~.~ the Commission C~my ~Mi Tay Fo~10-403 Rev 06/15/88 ~ ~ r,~ ?,,~ 68~8~96618+ Marathon Oil Workover KU 21 BOP Stack J-Flow Line__] j ~.,~r. eventer ipipe Ram I Marathon Oil Company Alaska Business Unit KU 21-7 WO Kenai Gas l~ield, Pad 14-6 Workover Procedure WBS # WO.02.06680.EXP History: KlJ 21-7 is a dual 2-7/8" completion in 7-5/8" casing. Lo~,g String: The long string provided access to the B-3, B-4, and B-5 zones (Pool 5.1 and 1'ool 5~2). The zone was producing excess water that could not be isolated (suspect behind corrmmnication in LS perfs). A plug set in the tubing (7/16/01) has questionable pressure pipe integrity. :;BHP-375psi from Pool 3 perforations. Them is also some Sh,rt String: The short string produces uni,e~rfo~'al~:d access to Pool 4. In 2001, the short string was converted to permit annular ijr~t~ctiO.n t-rom-th~sliding~sleev~e above the dual packer. The well presently produces about 3.2MMCFPD from the tubing and annulus. SBI-IP-300psi Oblecti~'e: KU 21-7WO will be a tubingless Pool 3 take point. The original tubing head will be replaced by a new tubing head w/a 6" side outlet. The existing dual tubing strings and dual packer will be fished from the wellbore. The single permanent packer will be left in the well and the pexf~ abandoned below a cement reta!,nen The re-completion will include the original A-8, A-10, m~d A-11 perforations in the 7-5/8' casing. A packerless string of 2-7/8" jointed pipe will be use, i as a velocity string. Note: Pool 4 potential is expected around 3825'-3850'. This should! be left accessible if possible. Proc~dttre: Remove KU 21~7 wellhouse. MIRU Pollard Wireline. RU on short string. RIH and close sliding sleeve at 3509' (ID=2.313"). POOH. RIH and set plug in Otis XN Nipple at 3552' (1D=1.791"). ND fi-om short string and RU on long string. Pull PX plug at 3893' (1I)=2.313"). If time pen~aits, shift sleeve open at 3893' (ID---2.313"). RDMO Pollard. Keep mast u~ck on location as it will be needed for APRS work. 2) MIRU APRS on short string. RIH w/tubing punch and perforate just above dual packer at -3530' (con'elate depth to XA sleeve at 3509' ID--2.313). RD short string and RU on long string. RIH and jet cut tubing at the 2~a half joint below the dual packer @ 3590' (correlate w/ CCL). RDMO APRS MIRU BJ Services pump truck to the long string. RU MOC chicksans, choke, gas buster, and flowback tank to the annulus.. Have rig mix up a 25 bbl kill pill (it will be important to contact the rig to agree upon the best time to mix the I-IEC pill per MI ~/O-d [l/~O'd k68-/ $skgk9~t6+ llO ~OHIV~y~-moJd m~OO:ZO ZO-~Z-~dV rec~,mmendation). Pump kill fluid down long string taking returns and gas out the ann alus. Watch for pressure increase and/or returns to indicate perforations are blocked. Che~k volumes. 4) RU to circulate fill from top of dual packer. Move ehicksans to pump down short string using fresh water. Inspect returns to flowback tank to determine presence of fill. If returns appear clean, RU to reverse. Pump down annulus taking returns through short string. If circulation cannot be established, it may be necessary to open short string slcew and retry. 5) Call out ABB Vetco to install BPVs and prep wellhead. Disassemble flowlines. Install new cellar. 6) t~rep location for drilling rig (including needed modifications to water well in immediate vicinity--may need to inform fire department of restricted access to well). MIRU GD ~ 1~ NU BOPs w/dual 2-7/8':, 5M rams. Test to 250/3000psi. (existing tubing head fl~mge is 8", 3M, R-49. New flange will be 11", 3M, R-53). The single gate ram will not b,: ttsed in this workover to allow more clearance. 7) Well should not be taking fluid. It is an objective of this workover to minimize amount of fluid lost to the 'formation. Consult mud recommendations if a fluid loss pill must be pumped. 8) RU to both strings in art attempt to pull dual packer (both strings are 2-7/8", 6.4ppf, N-80 Butt.). If packer comes loose proceed to step ~12. 9) If packer does not come free, RU APRS free point tool to establish long string stuck point. RIH w/jet cutter on short string to at least V2 jt above stuck point. RIJ:I and jet cut long string one jt above short string cut. Ii}) TOH w/both strings. Swap dual 2-7/8" rams for 4 W' drillpipe ram. Test doors to 250/3000psi. 11) Till w/overshot (see BHA below) to retrieve or jar as needed A5 dual packer and tubing. TOH. 9-12 6 5/8 Mill Shoe " 6 5/8 Bowen Ser. O'shot wi2 7/8 Basket Grapple w/MCP 6 5/8 Top Ext. 4 Fa OD Bowen Bumper Jar 4 ~ OD Bowen Oil Jar 4 % OD Drill Collars 4 ~A OD Bowen Acc. 12) If dual packer will not come free, PU washpipe and circulate to packer. 110 NOH£V~V~-moJd m~OO:ZO ~O-$Z'JdV 14) 15) I~'IH with overshot and jar as needed to get packer. over packer. If unsuccessful, RIH w/mill and bum O~ce dual packer is flee, RIH w/above BHA. Establish string weights and engage fish, Pn ~I long string wi blast joints. If long string including XA sliding sleeve comes free, p~',~ceed to step #14. If 1~ mg string does not come free, PU washpipe and wash to top of packer. Rerun overshot BHA to pull seals out of packer. TOH, MU Baker cement retainer. RIH to top of permanent packer, MIRU BI cementing services. Pump cement to isolate bottom pcrfs. Sting out of cement retainer and TOH, 17) PU storm packer, R1H to at least 500'. Set packer and trip pipe out of hole. ND BOP stack. 18) Remove existing tubing head and install and pressure test replacement tubing head. NU BOP stack and hydro-test to 250~3000 psi. TIH, engage RTTS. POOH. 19) ttabbit, number, and strap 2-7/8" EUE 8rd tubing string. There will be two nipples i,stalled in the string 0ewelry will be marked to correspond to where it is placed in the tubing string). One nipple will be at the bottom of the string at 3697'. The other will be' placed near 3585'. PU tubing and Rltt to 3697'. 20) Space out to land mandrel hanger, Run in lockscrews, ND BOP stack, NU tree and test to 250/3000psi. 21) RDMO GD#1 122) Bnng well on per instruction, · · Kenai Gas Field Wall KU 21 7, Pad 14-6 Marathon Oil Co., Alaska Region t4.0' Sholisu'ing Tubing: 2-7/g', 6.4#. N.80, Butt. Otis "XA" Sliding Sleeve (~3509' ID--- 2 313" ' Bal,:¢r A-5 Dual Paoker (q~ 3544' Otis "glq" Nipple ~ 3552' 1~} ~ 1.791" ~hortstrine 35'?6' - 3575' (Sqzd 11128/8! ) A-8 3593' - 3618' (8 sp[ I 1/30/81) A-10 3661'- 3736' (8 sp[ 12/1181) A-11 3956'- 3802' (8 spt; 12/3/81) ~808'- 3810' (Sq~ I !~4/81) Top of C,mem approx, 3500' CBL Plug 4009' - 4055' (I 1t14/97) 20", 94#, I.I40 Drive pipe ~48' 10-3/4". 32.75#, I-I40. ST(; Ca~ing ~ 1195' Cmt w/gO0 sks Longstm~g Tubing; 2-7t8", 6.4#, N-SO, Butt. Otis "XA" Sliding Sleeve (~3476' ID= 2.313" Blast Joints 3574' - 3833' Otis "XA" Sliding $1eevo (~389Y ID= 2.313" Baker Model D Pack,r (~ 3928' Bull Nose ~ 393¢ B-3 3977' - 4022' (10/15/97) 3978'. 3988' (8/16/81) 3991'. 4022' (Cmt plug (~ 4009~) 4036' - 4048' (Iso, w/~mt plug) 4056' - 4070' (Cowr,d w/fill) 4072' - 4102' (Co~ered wi fill) 4128' - 4160' (Covered w/fill) B-4 4162' - 4172' (Covercd w/flU) 4180' - 4202' (Covered wi fill) B-5 4256'-4260' (Sqzd 11/18/81) 4307'- 4329' (Sqzd 11/23181) 4361'- 4363' (Sqzd 11/21/81) 7-5t$", 26.4#, J-55, 'LTC Caging (~ 4417' Cmt w/550 sks Last Rev: JG'Z, 12/29/97 920~d tt/80'd 110 NOHg¥~¥~-mo~ mOlO:~O ~0-~-~¥ Pad 14.,-{~ TOG -~500' (OBL) l~mastrin~ Per~s,, I~-3 3977'.-4022' (101.15/g7) ~-4 t-5 3578'.3988' (8/16181) $9~1'-4022' (Cmt plug @ 4009') 4036'-4048' (Iso. wi cmt plug) 4056'-4070' (covered with fill) 4072'.4t0Z' (covered with fill) 4128'-4t60' (covered with 4162'-4172' (c. ove~ed with fill) 4180'4202' (covered with fill) ~2~$',,.4260' (Sqzd '1.1118/$1) 4,307'--43~'9' ($qz.d 1 '1t2318~ ) 436'1'-4353' ($q~ 1 20", 94#, H-40 LDdvepipe @48' 10-3/4", 32,75", H-40, STC casing @ 1t95' Cmt w/800 sx Pool 3 perforations (12/8t) 3576'-3578' sqzd A~8 3,5_93',361.8' (8 spf) A-10 36615~736' (8 spf) A-11 ~ (8 spf) 3808'~3810' sqzd Baker Cement Retainer 3920' ('proposed) Baker Model D packer (t~ 3928' Isolation Cement 3920'-4009' (proposed) Cement Plug 4009'-4055' (t 1/14/97) 7-5/8" 26/4 ppf, J-55, LTC Casing @ 4417' Cmt w/550 sx MARATHON OIL COMPANY ALASKA REGION KENAI GAS FIELD WELL KU 21-7 ;ANNULAR FLOW EVALUATION The KU 2'1-7 was designed to facilitate annular flow from the Iow-pressure (less than 400 psig) Kenai Gas Field Sterling reservoirs. The tubing head has a 7.1/16" 3,000 psig working pressure valve in addition to a 7-1/16" surface safety valve at the wellhead_ Based upt)n log evaluation, the Pool 3 reservoir's maximum predicted deliverability via annular flow is 22 M MCFG~.P__D_D. Erosional Velocity C¢~rrosiorl SUrfa~-~'~ty Cor~{'~ols Bursl/Collapse of Casing DISCUSSION · The highest potential for erosive flow exists at the BPV pr~)iiles in the 7-1/16" 3K flanged outlet of the tubing head. The BPV threads inside this outlet have an ID of 5-13/16" as the smallest restriction. The erosional velocity at the BPV threads is reached at rates greater than 34 MMCFGPD at 13_4 psis FTP (based upon APl RP14E). Nodal analysis indicates that Pool 3 is capabte of production of 2_~2 MMCFGPD at 154 p$1a:.FTP. · Marathon plans to produce the well below erosive limits.. · Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. The partial-pressure of COz is less than 1.0 psi. If the partial pressures of COz is less than 7 psi the gas is generally considered noncorrosive. Them is no HaS gas produced in the Kenai Gas Fietd. Corrosion of the casing is. hig_hlY unlike!y,. The annulus will be produced via two 3" flowlines. Surface safety controls will be similar to that of other Kenai Gas Field completions. Pressures imposed on the 7-5/8" casing during this procedure will not compromise the integrity of thecasing. Worst-case forces will not exceed 25% of lhe rated casing burst. Marathon MARATHON tlil Company August 26, 2008 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~I~f;, Mr. Tom Maunder /BUG 2 $ 2008 333 W OhlAve as Conservation Commission Af~ska Oii ~ Gas Oon' (~c~mm;s~ioz~ Anchorage, Alaska 99501 Anciial~a~e Reference: 10-407 Well Completion or Recompletion Report and Log Field: Kenai Gas Field 11,^,5 .Qb Well: Kenai Unit 21-7 Short `W ~~~~~c~~~F Noy ~ ~ zoa~ Dear Mr. Maunder: Attached for your records is the 10-407 Well Completion or Recompletion Report and Log for the annulus flow conversion of KU 21-7 short string. Flow was routed through the annulus, along with the short string, to improve gas deliverability. This work was performed in September of 2001 under Sundry # 301-176. This report is a reflection of the well arrangement at the time of work completion and does not represent the well's current configuration. Submission of this sundry is part of Marathon's ongoing effort to close-out the backlog of outstandin sundry reports. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ?, ~J ~ . Kevin J. Skiba Engineering Technician Enclosures: 10-407 Well Completion Report Operation Summary ~h~~ eac~CF~- , ~.~- ~, ~ P /~~ cc: Houston Well Kenai Well Fi ,~~~~ KJS STATE OF ALASKA ~ f~p AL/~ OIL AND GAS CONSERVATION CON1P~~ 20~~ WELL COMPLETION OR RECOMPLE~~~s~E,I~Ia~nI~nLOG Oil ^ Gas Q , Plugged ^ Abandoned ^ Suspended ^ A zo~v+czs.~os 2oaACZS.~~o GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 2 (h~n~~lass: Development ^~ Exploratory^ Service ^ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date Comp., Susp., or Aband.: 6/16/1965 12. Permit to Drill #: 165-008 Sundry#: 301-176 3. Address: PO Box 1949 Kenai Alaska, 99611-1949 6. Date Spudded: 5/27/1965 13. API Number: 50-133-10092-00-00 4a. Location of Well (Governmental Section): Surface: 362' FSL, 1,024' FWL, Sec.6, T4N, R11W S.M. 7. Date TD Reached: 6/11/1965 14. Well Name and Number: Kenai Unit 21-7S Top of Productive Horizon: 53' FNL, 1,601' FWL, Sec.7, T4N, R11W, S.M. 8. KB (ft above MSL): $7' Ground (fit MSL): 73' 15. Field/Pool(s): Total Depth: 101' FNL, 1,672' FWL, Sec. 7, T4N, R11 W, S.M. 9. Plug Back Depth(MD+TVD): 4,009' 3,929' Kenai Gas Field /Sterling Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- y- Zone- 4 10. Total Depth (MD +TVD): 4,453' 4,366'. 16. Property Designation: A - 028412 TPI: x- y- Zone- 4 Total Depth: x- y- 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): 22. CASING, L INER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 20" 78.6 H-40 0' 48' 0' 48' Driven None None 10-314" 32.75 H-40 0' 1,195' 0' 1,189' 17-112" 820 sks None 7-518" 26.4 J-55 0' 4,417' 0' 4,330' 9-7/8" 550 sks None 23. Open to production or injection? Yes 0 No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD 2-7/8" 3,552' 3,544' 2-7/8" 3,939' 3,928' 3,593' - 3,618' 3,525' - 3,549' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3,661' - 3,736' 3,590' - 3,663' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3,756' - 3,802' 3,682' - 3,727' 3,977' - 4,022' 3,898' - 3,942' 3,978' - 3,988' 3,899' - 3,908' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): flowing Date of Test: NA Hours Tested: Production for Test Period Oil-Bbl: 0 Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 100% gas Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 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. {__ n~- A.i~~~i~ ~q`~_~~c~ ~~~ i~~~ c.~-l~'~l c~.~~he. ~~~~~~~c~ ~~~O~s~o~i~ ~w-~c~ c rr~r,~~'~ h~c..c~~svMr.i-~l~`~ ` Tt~E ~~~\~~to~-~ v.ses-~ nc'~ ~c.~~~~ ~ o+~~.~ ~~•t~c~ ~c'~C~o~~ (~ ` Opened short string sliding sleav(e, directing flow up annulus and short string to improve c~eliverability. __ E~'C ~ `G ~j • ~ ~ a1 t ~ ~'~fc`GtL~ y O y ~\~ ii~SE.t ~- ~St~~Gl~~i N'~r~~ ~~~ ~9`~ ''~i~v~~ itl~~' Form 10-407 Revised 2/7~ { /', ~ ~ ~ ~ CONTINUED ON REVERSE 28. GEOLOGIC MARKERS (List all formations and ma s encountered): 29. FORMATION TESTS NAME M TVD Well tested? Yes ~ ff 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 Gas Zone 3,600' 4,376' Inbedded sand, shale & coal Formation at total depth: 30. List of Attachments: O erations Summa 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: Kevin J. Skiba Title: Engineering Technician Signature: ~ ~ Phone: (907) 283-1371 Date: Au ust 26, 2008 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 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 MARATHON OIL COMPANY ~ DAILY WELL OPERATIONS REP ~ PAGE 1 OF 1 DATE: 9/28/2001 FIELD: Kenai Gas Field WELL #: KU 21-7S -~_ FILL DEPTH/DATE: TUBING: 275 PSI CASING: 150 PSI DATE LAST WL WORK: TREE CONDITION: 2 7/8 WORK DONE: Open XA Sliding Sleeve BENCHES OPEN: PRESENT OPERATION: Complete WIRELINE CREW: Dille/Belden OTHER: Hrs. 7 SUMMARY OF OPERATIONS 08:00 11:00 11:15 13:00 14:00 15:00 MIRU, W/L equipment, call for Tree Connection, safety meeting Stand-by for Pad Operator and GLM to work on SCSV RIH w/ Shifting Tool to 3540' WL, sat down, P/U thru XA Sleeve, POOH RIH w/ same to 3540', to try to shift Sleeve @ 3490' WL, beat up, POOH, Pin scared Repin tool and rerun to 3490' WL, shift Sleeve, pressures from Anulus to Tubing equalized, POOH, check pin in tool -good ~'~ R/D, move over Vendor Equipment Daily Cost Cumulative Cost. Pollard Wireline Inc. Unit w/ 2 man crew Pollard Wireline Inc. Shiftin Tool DAILY COST: CUM: REPORTED BY: Bill Wolf KGF Annular Procedures Subject: KGF Annular Procedures Date: Mon, 30 Jul 2001 15:01:31 -0800 From: "Eynon, Donald E." <DEynon~MarathonOil.com> To: <j ane_williamson~admin, state.ak.us> CC: "Titus, Denise M." <DMTitus~MarathonOil.com> Jane: This email is to provide supplemental information on the 21-7S and 34-32L annular procedures. Attached are excel files for 21-7. The file named 21-7 Erosion Rate vs Press.xls provides a graph showing maximum annular rates out the annular outlets. This graph is identical to the one for 34-32L as the wellheads have the same size VR thread openings. The file named Circulating Pressures21-7.xls provides minimum and maximum pressures at the wellhead for the volume of water circulated from the wellbore. By circulating in this range of pressures the BHP will not exceed the test pressures used to verify casing integrity. I have also included the file for the circulation of 34-32L named 34-32L Circulating Pressures.xls. As soon as we can get the wellhead inspection data for KU 24-5S from ABB Vetco Gray it will be passed on to you. I will be out of the office Tuesday and Wednesday and will try to compile some of the daily rate data for 24-5SAnn flow path and the annular UTI' inspection data as soon as possible. <<Circulating Pressures21-7s.xls>> <<21-7 ErosionRate vs Press.xls>> <<34-32L Circulating Pressures.xls>> If you have any further questions feel free to call or email. Thanks Don Eynon Production Engineer Intern 907-564-6302 work 907-268-7868 pager 907-529-0523 cell Circulating Pressures21-7s.xls Name: Circulating Pressures21-7s.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: Circulating Pressures21-7s.xls ~21-7 ErosionRate vs Press.xls Name: 21-7 ErosionRate vs Press.xls ] Type: Microsoft Excel Worksheet (application/vnd.ms-excel)1 Encoding: base64 Description: 21-7 ErosionRate vs Press.xls ~ 34-32L Circulating Pressures.xls Name: 34-32L Circulating Pressures.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: 34-32L Circulating Pressures.xls 1 ofl 8/12/01 5:20 PM Short String Returns (bbls) 6 7 8 9 10 11 12 15 17 18 20 23 25 27 30 30 32 34 36 38 41 44 48 53 57 62 67 72 77 82 84 85 89 93 96 100 105 108 KU 21-7 Circulating Pressures Minimum Maximum Fluid Level Downhole Annulus Annulus Measured Total Pressure at Surace Surace Depth Vertical N2 Interlace Pressure Pressure (fi) Depth (fi) (psig) (psig) (psig) 200 200 88 88 238 226 226 100 99 249 256 256 113 112 262 285 285 126 124 274 315 315 139 137 287 345 345 152 150 300 374 374 165 163 313 474 474 209 206 356 535 535 236 232 382 594 594 262 257 407 654 654 288 282 432 740 737 325 317 467 801 801 353 344 494 860 859 379 368 518 950 948 418 405 555 980 978 431 417 567 1039 1036 457 441 591 1098 1094 482 465 615 1159 1154 509 490 640 1217 1211 534 513 663 1306 1297 572 548 698 1424 1413 623 594 744 1542 1528 674 640 790 1692 1674 738 698 848 1841 1820 803 755 905 1989 1964 866 811 961 2146 2118 934 870 1020 2325 2292 1011 936 1086 2473 2437 1075 990 1140 2622 2583 1139 1044 1194 2708 2666 1176 1075 1225 2738 2695 1188 1086 1236 2858 2812 1240 1128 1278 2977 2927 1291 1170 1320 3096 3042 1342 1211 1361 3214 3156 1392 1252 1402 3363 3300 1455 1303 1453 3476 3409 1503 1341 1491 Nitrogen Volume Pumped (Mscf) 0.2 0.3 0.3 0.4 0.5 0.6 0,7 1.2 1.5 1.8 2.2 2.8 3.3 3.9 4.7 5.0 5.6 6.3 7.0 7.7 8.8 10.4 12.2 14.6 17.3 20.1 23.4 27.3 30.8 34.6 36.8 37.6 40.9 44.2 47.7 51.3 56.0 59.6 Nitrogen Volume (liquid gals) 2 3 4 5 6 7 8 13 16 2O 24 31 36 41 5O 54 60 67 75 82 94 112 131 157 186 216 251 294 331 371 395 404 439 475 513 551 601 64O KU 2t-7S Maximum Allowable Flow Rate 11 10 9 8 7 5 4 3 2 1 0, 0 SAFE PRODUCTION RATES ARE BELOW CURVE 50 100 150 200 250 300 Pressu~'e (psig) ------ Rate for DuaI Outlets Example: At 100 psig Max Rate is 5.9 MMCFGPD KGF Annular Procedures Subject: KGF Annular Procedures Date: Thu, 19 Jul 2001 14:25:34 -0800 From: "Eynon, Donald E." <DEynon@MarathonOil.com> To: "Williamson, Jane" <jane_williamson~admin.state.ak.us> Hi Jane, This email is to address your concerns on the 21-7S and 34-32L annular procedures. The objective of the conversions is to provide higher deliverability than is currently available. The wells are typically produce at Iow rates or are inactive in the summer and are needed in the winter to provide higher rates to satisfy peak demand. Well Current Production Anticipated Rate MMSCF MMSCF MMSCF Incremental Deliverability 21-7S 3 7.4 to 12.2 4.4 to 9.2 34-32L 4.2 10 to 11 5.8 to 6.8 The range of incremental production is a function of bottlenecks in the gathering system. Production at each well will be limited by erosional velocity at the casinghead annular outlets. The annular conversions completed to date have had no problems with water or sand production and we anticipate no problems with these conversions. Annual UTT inspections will be conducted on the flowpaths to check for erosion. We are testing the casing to 400 psi to ensure casing integrity. Current reservoir pressure in Pool 3 (21-7S) is 290 psi which will have a surface shut in pressure of 270 psi considering a gas gradient to the perforations. Pool 6 (34-32L) reservoir pressure is 345 psi which will have a surface shut in pressure of 315 psi considering a gas gradient to the perforations. The attached excel file shows maximum production rates out the two annular flow paths to keep flow velocities below erosive conditions. <<Erosion RatevsPress.xls>> If you have any further questions feel free to call me at 564-6302 or email me back. Thanks Don Eynon Production Engineer Intern 907-564-6302 work 907-268-7868 pager 907-529-0523 cell ~ ErosionRatevsPress.xls Name: ErosionRatevsPress.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 Description: ErosionRatevsPress.xls I of 1 7/19/01 4:52 PM KU 34-32L Maximum Allowable Flow Rate 11 10 9 7 fAssumes flow throug q both 2" annular valves. Based on the MOC flow model using Salama et al. Based on a minimum fl~w area ,at V,R thread ID of 1.469" ISAFE PRODUCTION RATES ARE BELOW CURVE 50 100 150 200 250 Pressure (psig) Example: At 100 psig Max Rate is 5.9 MMCFGPD Rate for Dual Outlets 300 Date: 7/20/01 To: Julie Huesser From: Jane Williamson Subject: Approval for Annular gas flow in KGF Wells 21-7S and 34-32L Julie, You had requested that I look into the sundries for conversion of wells KU 34-32L and 21-7S to annular flow for gas. These wells have a very low SIBHP, but a high PI. At higher rates, the 4000' of tubing creates friction loss that bottlenecks the production. The attached fi.om Don Eynon provides an explanation of the rate benefits projected. As noted, potential deliverability increases predicted with their hydraulics models are 4.5-9 MMSCFD for 21-7S, and 5.8-7 MMSCFD for 34-32L. They want to produce up both strings and the annulus, as they will have to choke back the annulus a bit to stay under "safe" guidelines they are using for erosion. This should provide the higher overall delivery. I quizzed them quite a bit, and they have done their modeling and homework. They will ensure the annular production is below the "safe" erosional velocity rates. The production to date (begun in 1998) has seen no instance of wear in their inspection program. They recently pulled and inspected KU 24-5 wellhead (workover), which had been producing up the annulus since August '98. No wear was seen, and they will be re-using the head. They will forward that information later. The gas is very dry, 99.6% methane. There is no problem fi.om a commingling standpoint. In the case of KU 34-32L, B-3 production is left SI. Flow will be fi.om C-l, into long sting, out the long string XA sliding Sleeve at 4543', back and up the annulus, and up short string (through xa sleeve at 4564'). The short string has a plug at 4585' to prevent production from B-3 zone. Well KU 21-7 has the long string production from B-sand shut-off with plug. Proposed production is from Benches A-, A-10, A-11, through the short string, out the short string Sliding sleeve above packer, up the annulus and into the long string through the sliding sleeve above the packer. I recommend approval of both sundries. Jane Williamson Petroleum Engineer KGF Annular procedures Subject: KGF Annular Procedures Date: Thu, 19 Jul 2001 14:25:34 -0800 From: "Eynon, Donald E." <DEyn°n~MarathonOil.com> To: "Williamson, Jane" <jane_williamsOn~admin.state.ak.us> Hi Jane, This email is to address your concerns on the 21-7S and 34-32L annular procedures. The objective of the conversions is to provide higher deliverability than is currently available. The wells are typically produce at Iow rates or are inactive in the summer and are needed in the winter to provide higher rates to satisfy peak demand. Well Current Production Anticipated Rate MMSCF MMSCF MMSCF Incremental Deliverability 21-7S 3 7.4 to 12.2 4.4 to 9.2 34-32L 4.2 10 to 11 5.8 to 6.8 The range of incremental production is a function of bottlenecks in the gathering system. Production at each well will be limited by erosional velocity at the casinghead annular outlets. The annular conversions completed to date have had no problems with water or sand production and we anticipate no problems with these conversions. Annual UTT inspections will be conducted on the flowpaths to check for erosion. We are testing the casing to 400 psi to ensure casing integrity. Current reservoir pressure in Pool 3 (21-7S) is 290 psi which will have a surface shut in pressure of 270 psi considering a gas gradient to the perforations. Pool 6 (34-32L) reservoir pressure is 345 psi which will have a surface shut in pressure of 315 psi considering a gas gradient to the perforations. The attached excel file shows maximum production rates out the two annular flow paths to keep flow velocities below erosive conditions. <<ErosionRatevsPress.xls>> If you have any further questions feel free to call me at 564-6302 or email me back. Thanks Don Eynon Production Engineer Intern 907-564,6302 work 907-268-7868 pager 907-529,0523 cell ~ ErosionRatevsPress.xls Name: ErosionRatevsPress.xls Type: Microsoft Excel Worksheet (application/md.ms-excel) Encoding: base64 Description: ErosionRatevsPress.xls 1 of l 7/19/01 5:35 PM Marathon OilCompany Mr. Tom Maunder AOGCC 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 June 26, 2001 Re: KU 21-7S, Kenai Gas Field Dear Mr. Maunder: Attached is a Sundry application for KU 21-7S to convert the well to an annular and Iongstring producer. Sterling Pool 3 static reservoir pressure is now at 290 psig. Past annular conversions and modeling show a doubling of deliverability is possible by producing up the Iongstring and annulus simultaneously. We will pressure test the casing to 400 psig before displacing the hole with nitrogen to ensure integrity. Producing the well up the 7 518" annulus will not impart extraordinary erosion, corrosion, or burst / collapse stresses to the casing. The highest potential for erosion will take place at the tubing head annular outlets which we plan to produce below erosional velocities. Surface safety devices will be similar to other wells in the KGF. We have tentatively scheduled operations to start July 5th, 2001. Please contact me at 564-6302 if you have any questions. Sincerely, Don Eynon Production Engineer Intern 564-6302 RECEIVED JUN 2, 8 ZOO1 A/aska Oil & Gas Cons, Commission Anchorage ORIGINAL ~ ~ O~C~EL\SUNDRYANN.XLS "ECEIVED STATE OF ALASKA JUN ALASKA OIL AND GAS CONSERVATION COMMISSION 8 APPLICATION FOR SUNDRY APPROVALS '~/askao~l,~?~Co.s.~ 1. Type of Request: '~llCl;~)~;:tn,., ...... '~10 Abandonm Suspend__ Operation Shutdown Re-enter Suspendea vv~. Alter Casing Repair Well Plugging Time Extension __ Stimulate Change Approved Program Pull Tubing m Variance Perforate~ Other X Name of Operator MARATHON OIL COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 Location of Well at Surface v/' ~/' ~/' 362'FSL, 1024'FWL, SEC.6, T4N, R11W, S.M. At top of Productive Interval 53'FNL, 1601'FWL, SEC.7, T4N, R11W, S.M. At Effective Depth 5. Type of Well: Development X Exploratory Stratigraphic Service Convert to Annular Flow At Total Depth 101'FNL, 1672'FWL, SEC.7, T4N, R11W, S.M. 6. Datum Elevation (DF or KB) 14 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU21-7S 9. Permit ~umber 65-8 " 10. APl Number ,/ 50-- 133-1009200 11. Field/Pool KENAI GAS FIELD / POOL 3 12. Present Well Condition Summary Total Depth: measured true vertical 4453 feet 4366 feet Plugs (measured) Cement Plug at 4009' PBD. Effective Depth: measured true vertical 4009 feet Junk (measured) 3928 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth 48' 20" Driven 48' 48' 1195' 10 3/4" 820 sacks 1195' 1189' 4417' 7 5/8" 550 sacks 4417' 4330' A-8, A-10 and A-11 sands: 3596'-3802'. B-3 and B-4 sands: 3978'-4202'. true vertical A-8, A-10 and A-11 sands: 3526'-3727'. B-3 and B-4 sands: 3899'-4118'. Tubing (size, grade, and measured depth) Long string: 2 7/8", 6.4 ppf, N-80 to 3939'. Short string: 2 7/8", 6.4 ppf, N-80 to 3552'. Packers and SSSV (type and measured depth) A-5 dual packer at 3544'. Model D packer at 3928'. 13. Attachments Description Summary of Proposal__ Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 7/5/2001 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas .~X Service Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Production Engineer Intern Date 26-Jun-01 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- Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED BY J. M. Heu~r JApprova,~_t,..j [,~ Commissioner Date S-u~n~ it in/Triplicate ORIGINAL Well KU 21-7S Kenai Gas Field Convert to Annular and Short String Flow Cost Tracking AFE-04906101 Objective: Utilize flow up the short string tubing and tubing casing annulus to improve deliverability. Procedure: 1) MIRU Haskel pump on KU 21-7 tubing-casing annulus. Pressure test to 400 psi to ensure wellhead and casing integrity. Bleed off pressure. RD Haskel pump. 2) Open existing casing valve and remove blind flange on opposite side of tubing head. Check for VR plug in new outlet. Install new 2-1/16" 5M gate valve on the outlet, test against VR plug, and then remove VR plug, leaving valve open. Install VR plug on opposite side of tubing spool and remove old 2-1/16" 5M gate valve. Install new 2-1/16" 5M valve, test against VR plug, and then remove VR plug. Close annular valves. 3) SI LS and SS on KU 21-7. MIRU slickline unit on longstring. Test BOPs and lubricator to longstring shut-in pressure. Set PX plug in 2.313" ID XA sliding sleeve @ 3893' MD. Note: XA sleeve also present at 3476' MD, do not install plug in this sleeve. RD slickline unit. 4) Fill longstring with 3% KCL using a lubricate and bleed method 5) MIRU slickline unit on longstring. Test BOPs and lubricator to 500 psi. MU tool string with XA sleeve shifting tool, spang jars, and oil jars. RIH and locate XA sliding sleeve (ID 2.313) at 3476' MD. Shift sleeve open while monitoring casing and tubing pressure. POOH and check shifting tool to ensure it is not sheared and sleeve is opened entirely. RDMO slickline unit. 6) RU nitrogen unit on annulus and pump nitrogen down casing taking returns up longstring to catch tank. Continue until nitrogen is blowing around the end of tubing. Trap 200 psi on well and shut in. 7) MIRU slickline unit on short string. Test BOPs and lubricator to short string shut in pressure. MU tool string with XA sleeve shifting tool, spang jars, and oil jars. RIH and locate XA sliding sleeve (ID 2.313) at 3509' MD. Shift sleeve open while monitoring casing and tubing pressure. POOH and check shifting tool to ensure it is not sheared and sleeve is opened entirely. RDMO slickline unit. 8) As soon as possible, produce well at maximum flow rate up the short string tubing to clean up well and remove any remaining packer fluid from wellbore. Please test well recording flow rates and tubing pressures. 9) Shut in well. Install flowlines to produce through both annulus valves and 3" 5M ball valves symmetrically into a SSV and on into the long string flowline. Put well on test with both the tubing and annulus flowing simultaneously, recording rates and pressures. Note: Do not exceed maximum rate through annular flow lines for tubing head pressure per attached graph. When finished testing put on production as per instructions of Production Foreman. Well KU 21-7S Kenai Gas Field Conversion to Annular Flow Problems Addressed Discussion: KU 21-7S will be converted to annular flow to increase deliverability of gas from Sterling A-8, i0, and 11 perfs, Pool 3, currently at 290 psig SBHP. This will be accomplished by opening a sliding sleeve above the dual packer. Potential problems are addressed below: Potential Problems: Erosion Velocity: The highest velocity gas flow will occur at the 2 1/16" 3M flanged outlet on each side of the tubing hanger. Flow will be out both sides of the hanger to reduce velocity and minimize erosion. Erosion could potentially occur if flow out the annulus exceeds 8 MMCFD at 175 psig casinghead pressure. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Corrosion: Partial-pressure of CO2 is less than 1.0 psi. ff the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Additionally, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. Surface Safety Controls: The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Casing Integrity: Pressures imposed on the 7 5/8" casing during this procedure will not compromise the integrity of the casing. Worst case scenarios impart pressures at 52% of collapse rating and 43% of the burst rating. Kenai Gas Field Well KU 21-7, Pad 14-6 Marathon Oil Co., Alaska Region RT-GL: 14.0' Shortstring Tubing: 2-7/8", 6.4//, N-80, Butt. Otis "XA" Sliding Sleeve ~3509' ID= 2.313" Baker A-5 Dual Packer @ 3544' Otis "XN" Nipple ~ 3552' ID = 1.791" Shortstring Perfs 3576' - 3578' (Sqzd 11/28/81) A-8 3593' - 3618' (8 spf, 11/30/81) A-10 3661'- 3736' (8 spf, 12/1/81) A-Il 3756'- 3802' (8 spf, 12/3/81) 3808'- 3810' (Sqzd 11/24/81) Top of Cement approx. 3500' CBL Cement Plug 4009' - 4055' (11/14/97) TD ~, 4453' 20", 94//, H-40 Drive pipe ~48' 10-3/4", 32.75//, H-40, STC Casing @ 1195' Cmt w/800 sks Longstring Tubing: 2-7/8", 6.4//, N-80, Butt. Otis "XA" Sliding Sleeve ~3476' ID= 2.313" C[o$~,~ Blast Joints 3574' - 3833' Otis "XA" Sliding Sleeve @3893' ID= 2.313" e...le,~,~ Baker Model D Packer @ 3928' Bull Nose ~ 3939' Longstring Perfs B-3 3977'-4022' (10/15/97) 3978'- 3988' (8/16/81) 3991' - 4022' (Cmt plug ~ 4009') 4036' - 4048' (Iso. w/emt plug) 4056'- 4070' (Covered w/fill) 4072'- 4102' (Covered w/fill) 4128' - 4160' (Covered w/fill) B4 4162' - 4172' (Covered w/fill) 4180' - 4202' (Covered w/fill) B-5 4256'- 4260' (Sqzd 11/18/81) 4307'- 4329' (Sqzd 11/23/81) 4361'- 4363' (Sqzd 11/21/81) 7-5/8", 26.4//, J-55, LTC Casing @ 4417' Cmt w/550 sks Last Rev: JGE, 12/29/97 G:~CMN~DRLG~WELLS~2171404.XLS STATE Of ALASKA ALASKA ~L AND GAS CONSERVATION COhtm. ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging X Perforate X Pull Tubing __ Alter Casing Repair Well Other 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168 Anchorage, AK 99519-6168 4. Location of Well at Surface 362'FSL, 1024'FWL, Sec. 6, T4N, R1 lW, S.M. At top of Productive Interval 53'FNL, 1601'FWL, Sec. 7, T4N, R11W, S.M. At Effective Depth At Total Depth 101'FNL, 1672'FWL, Sec. 7, T4N, R11W, S.M. 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum Elevation (DF or KB) 14 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 21-7L 9. Permit Number/Approval Number 65-8 / 397-163 10. APl Number 50-- 133-1009200 11. Field/Pool Kenai Gas Field/Pool 5.1 12. Present Well Condition Summary Total Depth: measured true vertical 4453 feet Plugs (measured) 4009' PBTD 4366 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth 48' 20" Driven 48' 48' 1195' 10-3/4" 820 Sacks 1195' 1189' 4417' 7 5/8" 550 Sacks 4417' 4330' true vertical A-8, A-10 and A-11 sands: 3596'-3802'. B-3 sand: 3977'-4022'. A-8, A-10 and A-11 sands: 3526'-3727'. B-3 sand: 3898'-3942'. Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 0RI$1NAL Long string: 2-7/8", 6.4 ppf, N-80 to 3938'. Short string: 2-7/8", 6.4 ppf, N-80 to 3553'. A-5 dual packer at 3542'. Model D packer at 3930'. 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Added perfs 3977-4022' & 4029'-4043'. Treatment Description Including Volumes Used and Final Pressure Dump bailed cement from 4022-4055'. TOC was later tagged {~ 4009' MD. 14. Prior to Well Operation Subsequent to Operation OiI-Bbl Shut in. 0 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 5O9 1 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of Well Classification as: Oil Gas X Suspended Service 17. I hereby~hat t~oing is true an~ct to the best of my knowledge. Signed "~'~, ~,_~ ~ ~_'~_~,_,.,., Title Production Engineer Form 10-404 Rev. 06/15188~ '~ Date 26-Nov-97 Submit in Duplicate ,....~-~' Sheet2 Well KU 21-7L Summary of Operations October 13, 1997 to November 3, 1997 10/13/97 10/14/97 10/15/97 10/16/97 10/20/97 10/21/97 11/2197 11/3/97 RU Schlumberger. Hold safety meeting & test lubricator. Tag fill @ 4055' MD Dump bail 5' of cement from 4050' - 4055'. Tag btm @ 4044' instead of expected 4050'. Perf 4029-4043' & 3977-4022' with 2-1/8" strip guns. RDMO Schlumberger. MIRU slickline. Swab well, unable to induce flow. RDMO slickline. MIRU 1.5" coil tubing. Test BOPs, held safety meeting. RIH w/coil tubing. Jet well with nitrogen from 3700' CTM. Making significant water. Well unable to flow on it's own. RIH w/coil tubing. Dump 22' of cement in 7-5/8" casing, from 4022-4044'. RIH w/coil tubing. Jet w/nitrogen (~ 3940' CTM. Well blew dry. Turned well over to production to unload and produce. Page 2 Alaska ~gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 8, 1997 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RECEIVED Reference: Kenai Gas Field Wells KU J l-8L~and KU 21-7L Dear Mr. Johnston: Please find attached Sundry Applications for the coil tubing cement squeezes and perforating work in Wells KU 11-8L and KU 21-7L in the Kenai Gas Field. This work is scheduled to commence on September 24, 1997. Please advise if further information is required. W .C. 'Barron Operations Superintendent H:~WP\OPNS97~PKB981 Attachments · A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O:\EXCEL~SUNDRY. XLS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown Alter Casing Repair Well__ Plugging X Change Approved Program Pull Tubing Variance Re-enter Suspended Well ,, ,, Time Extension Stimulate Perforate X Other Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 362'FSL, 1024'FWL, SEC.6, T4N, R11W, S.M. At top of Productive Interval 53'FNL, 1601'FWL, SEC.7, T4N, R11W, S.M. At Effective Depth At Total Depth 101'FNL, 1672'FWL, SEC.7, T4N, R11W, S.M. 5. Type of Well: Development X Exploratory Stratigraphic__ Service ,, 6. Datum Elevation (DF or KB) 14 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU21-7L 9. Permit Number 65-8 10. APl Number 50-- 133-1009200 11. Field/Pool KENAI GAS FIELD/POOL 5.1 12. Present Well Condition Summary Total Depth: measured 4453 feet true vertical 4366 feet Plugs (measured) 4369' PBD. Effective Depth: measured feet Junk (measured) true vertical feet ORI$1NAL Casing Length Size Cemented Measured Depth True Vertical Depth Structural 20" Driven 48' 48' Conductor Surface 10 3/4" 820 sacks 1195' 1189' Intermediate Production 7 5/8" 550 sacks 4417' 4330' Liner Perforation Depth: measured A-8, A-10 and A-11 sands: 3596'-3802'. B-3 and B-4 sands: 3978'-4202'. ~'"-I-{'lt true vertical A-8, A-10 and A-11 sands: 3526'-3727'. B-3 and B-4 sands: 3899'-4118'. Tubing (size, grade, and measured depth) Long string: 2 7/8", 6.4 ppf, N-80 to 3938'. Short string: 2 7/8~,'~.gp~,~to~5~.~ Packers and SSSV (type and measured depth) A-5 dual packer at 3542'. Model D packer at 3930'. oEP 9 1997 AlaSEa Oil & Gas Cons. Commiss~' 13. Attachments Description Summary of Proposal .... Detailed Operations Program X BOP ~l~erag8 14. Estimated Date for Commencing Operation 9/24/97 16. If Proposal Was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil .... Gas X Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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- IApproval No. Approved by Order of the Commission Form 10-403 Rev. 06/15/88 dnginal Signed By Oa,:id iii Inh,ne+nn Commissioner Submit in Triplicate Date: 9/8/97 Field/Platform: Lease: Site: Sand: Marathon Oil Company Coil Tubing/Wireline Work Request Well KU 21-7L Kenai Gas Field A-028142 14-6 SS: Pool 3.0 A-8, 10, 11 (Sterling) LS: Pool 5.1 B-3, 4 (Sterling) KB: 14' Est Start Date: 9/24/97 Est Comp Date: 10/3/97 OBJECTIVE: Packer: Tbg: EOT: Min ID: Tubing Clear: Fill depth: Tree Connection: Dual Single SS LS SS LS SS LS SS LS SS LS 3541.66' 3930.00' 2-7/8" 6.4// N-80 2-7~8" 6.4// N-80 3553.46' 3938.00' 1.791" (3552.46') 2.313" (3475.65', 3893.21 ') OK 3920' (3/10/95) 4057' (3/10/95) 2 7/8" 8rd ? 2 7/8" 8rd ? Clean out fill, off B-3,4 perf, perf B-3. squeeze POTENTIAL PROBLEMS: I Sticking coil, multiple attemps may be required to get a good squeeze, explosives. L LAST WIRELINE WORK: A 2.25" GR was run on 3/10/95 and tagged fill at 4057'. SZP 9 !997' Alaska .Oil & Gas Cons. ~nchorage PROCEDURE: [1. Hold safety/environmental meeting. Review procedure. Ensure SS and LS are SI. 12. RU wireline unit on LS. Function test wireline BOPs and test lubricator against SI wellhead pressure. ~3 RIH w/2.25" GR and tag fill. POOH and RD. 41 Repeat step 1 w/CTU crew and stage PTS tank, Haliburton tank and BC tank. RU lines. MU 500 bbls 3% KCI water. MU 150 bbls WF120 gelled water. 5. PT tubing-casing annulus to 2000 psig while monitoring SS and LS pressure· 6. RU 1-1/2" CTU w/wash nozzle. PT lines to 4000 psig. 7. RIH pumping 1/4 bpm. Tag fill. PU 10' above fill. RIH and cleanout fill to 4225' using nitrified foam. POOH. 8. MU cementing nozzle and back pressure relief valve. Fill CT w/3% KCI. RIH pumping 1/4 bpm. Tag fill. 9. MU 23.5 bbls latex cement per Doweil design. Check fluid loss data. MU 50 bbls 1.2 #/bbl Biozan pill. 10. RIH to 4202' W/return line SI, pump 10 bbls 3% KCI water, 20 bbls cement. Displace w/Biozan. Spot 1 bbl out CT, then PUH to 3939' on a 1:1 ratio until cement is placed. 11. Note CT-Tubing annulus pressure. Perform hesitation squeeze in 250 psig increments every 30 minutes to a maximum squeeze pressure of 1000 psig over noted annulus pressure. Do not squeeze more than 7.5 bbls. Hold final squeeze pressure for 1 hour. 12. Open choke and launch ball. RIH contaminating cement at a 50% ratio. Make 3 down passes and 2 up passes at ~ 80 ft/min, slowing pump speed across perforations. Circulate hole clean w/20//gelled water and POOH slowing across XN and XA sleeve. Allow cement to set up for 2 days. 13. RU pump and PT cement plug to 1000 psig. If test fails, repeat steps 4 through 12. If test is good, RIH w/CT to insure there are no restrictions and tag fill. 14) PU to 4200' and pump N2 at maximum rate and circlute well dry. POOH.' 15. 16. 17. 18. guns 19. bore Blow well down to 100 psig and monitor WHP. RD CTU. Repeat step 1 w/E-line crew. RU E-line. PT to SI WHP. Perforate 4034-4048' (14'), 4007-4022' (15'), 3992-4007' (15'), 3977-3992' (15')w/ 1-11/16" Pivot · RD and flow well. RU CT/N2 as necessary to keep well unloaded or consider injecting gas to displace near formation water. QUESTIONS/COMMENTS? Pete Berga - 564-6319 APPROVALS: CO~j~ _ (W. C. Barron) Fax to KGF Foreman Gary Eller-564-6315 Mike Olson-903-509-5450 G :cmn\drlg\kgf\wells\ku21-7 I\ctprog.xls Form D-iOO1-A UNION OIL CO. OF CALIFORNI REPAIR RECORD LEASE KENAI UNIT WELL NO. 21-7 CONTRACTOR BRINKERHOFF SIGNAL #31 FIELD KENAI'GAS FIELD TYPE UNIT T-20 NATIONAL BEGAN: ll/lO/S1 COMPLETED: 12/9/81 ELEVATIONS: GROUND PERMIT NO. 68-5 SERIAL NO. A-028142 CASING HEAD COMPANY ENGINEER TUBING HEAD APPROVED ROTARY DRIVE BUSHING 14' above GL CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 10 3/4" 1195' 32.75# H-40 7 5/8" 4417' 26.4# 0-55 2 7/8" 3553' 6.4# N-80 2 7/8" 3938' 6.4# N-80 Cemented w/ 800 sxs Kaiser cement Cemented w/ 550 sxs Kaiser cement Tbg short string w/ dual pkr 8 3542' Tbg long string w/ prod pkr 8 3930' PERFORATING RECORD DATE INTERVAL E.T,D. REASON PRESENT CONDITION 6/13/65 4208-4209' 4369' WSO Holes are open 6/14/65 3970-3971' 4369' WSO Holes are open 6/15/65 3978-3989' " Production Open for production (Pool 5.1) " 3991-4022' " " " " 4036-4048 ' " " " " 4056-4070 ' " " " " 4072-4102 ' " " " " 4128-4160' " " " " 4162-4172' " " " " 4180-4202' " " " " 4219-4241!~~ " " Sqz'd w/ 200 sxs cmt " 4248-4260' " " " " 4307-4329' " " Sqz'd w/ 200 sxs cmt INITIAL PRODUCTION AFTER REPAIR DATE INTERVAL NET 0I[ CUT GRAV. C.P. T.R. CHOKE MCF GOR REMARKS (A-8) A-8, A-lC, A-11 3,57 MMSCFD w/ 475 psi tbg pressure 9.82 MMSCFD w/ 975 psi tbg pressure WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: LAST COMPLETION NO. 8/21/81 PRODUCING INTERVAL: Dual Pool 5.1 & 5.2 INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: c'UMULATIVE PRODUCTION: REASON FOR REPAIR: Water production in Pool 5.2. Abandon po°l 5.2 and recomplete as duel (Pool 5.1 & A-8~ A-lOp & A-il sends) 982 Cons. Comnli$$~ol~ Anchorag9 Form D-IOO1-B LEASE KENAI UNIT COMPLETION DATE 12/9/81 UNION OIL CO. OF CALIFORNIA REPAIR RECORD WELL NO. 21-7 FIELD APPROVED SHEET B PAGE NO. j- KENAI GAS FIELD DATE E.T.D. DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS DATE INTERVAL ETD Reason Present Condition 8/11/81 4307-4327' 4369' Reperf - DST 8/12/81 4249-4259' " " " 4220-4240' " " 8/16/81 4180-4202' 4369' Reperf " 4162-4172' " " " 4128-4160' " " " 4072-4102' " " " 4056-4070' " " " 4036-4048' " " " 3991-4022' " " " 3978-3988' " ~ " ...... :~i 11/18/81 4256-4260' " 'Isolation 11/20/81 4307-4329' " Production " 4361-4363' " 11/22/81 4307-4312' 4347' 11/24/81 ll/30/B1 12/1/81 12/2Z81 - 12/3/81 12/4/82 Isolation Production 3808-3810' 4212' (Ret) Isolation 3576-3578' 4212' (Ret) Isolation 3596-3618' 3893' (Junk) Production 3664-3736' " " 3756-3776t " " 3776-3802'~,:~ 4202' (Ounk) Production 3756-3802' " Reperf 3593-3615' " " 3661-3733' " " Sqz'd w/ 200 sxs Sqz'd w/ 200 sxs cmt Open for production (B-4) " (B-3) .,. Sqz'd w/ 200 sxs "G" Sqz'd w/ 200 sxs "G" (lower lobe B-5 sd) Sqz'd w/ 165 sxs "G" Sqz'd w/ 150 sxs "G" (lower lobe B-5 sd) Sqz'd w/ 160 sxs "G" (below A-11 sd) Sqz'd w/ 310 sxs "G" (above A-8 sd) Open to production (A-8 sd) Open to production (A-lO sd) Open to production (A-11 sd) Open to production (A-11 sd) II Open to production (A-lC sd) ,, WELU'H~AD'ASSEMBLY TYPE: CAMERON IRON WORKS CASING HEAD: 10" 3M SOW CASING HANGER: CASING SPOOL: TUBING HEAD: 10" 3M X 8" 3M DCB TUBING HEAD TUBING HANGER: DUAL 2 7/8" SPLIT HANGER TUBING HEAD TOP: 2 7/8" ~ MASTER VALVES: CHRISTMAS TREE TOP CONN.: A,,~','~Io.~... 0i~ & Gas Cons. Comrn!ssion Anchorago UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Kenai Unit WELL NO. 21J7 FIELD Kenai Gas Field DATE A 11/8/81 DALLY COST: ACC COST: AFE AMT: 8 11/9/81 DAILY COST: ACC COST: - - AFE AMT: 1 11/10/81 DAILY COST: ACC COST: AFE AMT: 2 11/11/81 DAILY COST: ACC COST: AFE AMT: 3 11/12/81 DAILY COST: ACC COST: AFE AMT: ETD 4453' TD 3913' ETD (A-5 RKR) 10 3/4" C. 1195' 7 5/8" C. 4417' 4,950 596,587 $1,060,000 4453' ID 10'3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 38 SEC $ '18.260 $1,060,000 4453' ID 10 3/4" C. ].195' 7 5/8" C. 4417' 64 PCF 46 SEC $ 28,350 $ 643,197 $1,060,000 4453' ID 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 46 SEC $ 16,115 $ 659,312 $1,060,000 4453' ID 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 38 SEC 17,590 676,902 $1,060,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Began operations 6 06:00 hrs 11/8/81. Moved BSCo Rig #31 f/ KU #21-5 to KU #21-7. Set in sub- bases & drawworks. Pinned up der- rick. Set in pump components & sup- port bldgs. NOW: Continue to rig up. Continued to rig up. Nixed gel- water kill fluid. RU Otis & opened "XA" sleeve in LS 8 4210' - could not get WL up past 3068'. Pumped kill fluid down DS and up SS. Lost 100 bbls of fluid during circulat- ing. NOW: Circ & build mud volume. Continued to circ & build mud vol. Worked Otis shifting tool - could not get above 3063'. Disp LS & an- nulus - LS had communication w/ an- nulus. Closed SS & bullheaded 20 bbls of mud. Closed in & blew down annulus. Circ down annulus & up LS. Unable to free Otis tools. Dropped mech WL cutter down LS & cut WL. POOH & RD Otis. Installed BRV's & removed tree. NOW: Installing BORE. Installed BOP. Broke 2" 5M flange out of mud cross while installing. Attempted to reweld in place - could not. Removed mud cross. Cut out 2" nipple & rewelded same. NOW: Reinstalling mud cross. Pulled up on landing its & pulled A-5 pkr loose. Pulled 30' of tbg - pkr was swabbing. Attempted to circ around pkr - could not. Pulled 270' of tbg while filling thru tbg. Circ down LS w/ returns up SS - had no oas to surface. RU Otis on SS & opened "XA" sleeve above A-5 pkr for drainage. POOH w/ no swabbing. LD A-5 pkr. NOW: Laying down blast its. S E P 2 1 FJBZ Cons. Commission ./',~chorage LEASE Kenai UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. 21-7 SHEET D PAGE NO. 2 FIELD Kenai Gas Field DATE 4 11/13/81 DAILY COST: ACC COST: AFE AMT: 5 ll/14/81 DAILY COST: ACC COST: AFE AMT: 6 11/15/81 DAILY COST: ACC COST: AFE AMT: 7 11/16/81 DALLY COST: ACC COST: AFE AMT: ETD 4453' TD 4369' ETD 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 36 SEC $ 28,216 $ 705,118 $1,060,000 4453' TD 4369' ETD' 10 3/4" C. 1195' 7 5/8" C. 4417' 64'PCF 36 SEC $ 23,815 $ 728,933 $1,060,000 4453' ID 4331' ETD JUNK 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 36 SEC $ 20,515 $ 749,448 $1,060,000 4453' ID 4347' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 36 SEC $ 23,431 $ 772,879 $1,060,000 ' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS NOW: POOH w/ packer picker. POOH w/ packer picker. RIH w/ 6 1/2" OD flat bottomeo mill & milleo 1.5' on top of model "D" pkr ~ 4279'. POOH w/ mill. RIH w/ pkr picker w/ 3 1/8" mill on 8' exten- sion. Milleo thru pkr bore (3 hfs) - could not get grapple to engauge fish. POOH - rec 1.5' long piece of packer bore. RIH w/ pkr picker & milled over remainder of model "D" pkr ~ 4280' (4 hfs). Packer fell out - POOH. NOW: POOH w/ packer picker. POOH w/ pkr picker - had no rec. RIH w/ 4 11/16" Bowen OS w/ 6 1/4" guide & i 7/8" grapple. Tagged TOF ~ 4319'. Worked down to 4323' & POOH. Rec 17' of sinkerbars & shifting tool. RIH w/ 4 11/16" OS w/ 6 1/4" guide & i 7/8" grapple. Tagged fish ~ 4323'. Washed & reamed to 4328' w/ high torque. POOH - had no rec. RIH w/ 5 3/4" OS w/ 1.9"~grapple & 4' of 6 1/2" mill shoe. NOW: RIH w/ fishing tools. POOH w/ mill. New strap showed 4328' ETD. RIH w/ 6 1/2" mill shoe w/ globe OB. Washed & milled f/ 4328' to 4347' - had high torque. POOH - no rec. RIH w/ 6 3/4" con- cave junk mill w/ 2" bore. NOW: RIH w/ 6 3/4" junk mill. Completed LD comp assy. Changed & tested pipe rams. RIH w/ pkr picker w/ mill shoe on ~ 1/4" DC's- tagged model "D" pkr ~ 4215' Milled over pkr & POOH. Lef[ guide ring to model "D" pkr in hole. RIH w/ packer picker & could not wozk into model "D" pkr ~ 4279'. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D -. PAGE NO, 3 LEASE Kenai Unit WELL NO. 21-7 FIELD Kenai Gas Field DATE 8 11/17/81 DAILY COST: ACC COST: AFE AMT: 11/18/81 DAILY COST: ACC COST: AFE AMT: 10 11/19/81 DAILY COST: ACC COST: AFE AMT: 11 11/20/81 DAILY COST: ACC COST: AFE AMT: ETD 4453' ID .4364' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 RCF 36 SEC $ 37,843 $ 810,722 $1,060,000 4364' ETD (OUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 40 SEC $ 34,760 $ 845,482 $1,060,000 4453' TD 4364' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 40 SEC $ 24,377 $ 869,859 $1,060,000 4453' TD 4364' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 63 PCF 39 SEC $ 28,985 $ 898,844 $1,060,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH w/ 6 3/4" junk mill w/ 2" bore. Milled f/ 4347' to 4357'. Swept hole w/ hi-vis pill & POOH. RIH w/ 6 3/4". mill on 7 5/8" csg scraper. Tagged junk ~ 4357'. Washed junk & sd f/ 4357' to 4364'. Circ viscous pill & POOH. RIH w/ 7 5/8" cmt ret.on DP & set ~4275'. Broke down lower B-5 perfs f/ 4307' to 4329' DIL w/ 4 BPM ~ ~ 1400 psi. Mixed & sqz'd w/ 200 sxs cl "G" w/ .75% D-31, .3% D-19, end .2% D-6. Displaced 195 sxs below ret w/ a final pressure of 2200 psi. CIP ~ 15:00 hrs. Rev out 5 sxs cmt. POOH w/ DP. RU Dresser Atlas. NOW: Prep to perf upper lobe of ~-B.--5-sand. Perfed upper 8-5 f/ 4256' to 4260'. Ran GR & OB to 4220'. Set cmt ret on WL ~ 4212'. RIH w/ DR. Broke down perfs f'/ 4256' to 4260' w/ 3.4 aRM ~ 1400 psi. Sqz'd perfs w/ 200 sxs CL "G" w/ .75% D-31, .3% D-19 & .2% D-6 mixed ~ ll8 RCF. Final press 3000 psi. CIR ~ 0900 hrs. "O±rc clean long way. Trip for 6 1/8" bit. NOW: WOC. WOC. RIH w/ 6 1/8" bit & drld cmt f/ 4200' to 4212'. Drld out ret ~ ~212' & cmt f/ 4214' to 4270'. Drld on ret ~ 4275'. Trip for bit chge. Tested BORE to 3000 psi - ok. RIH w/ new bit & drld ret 8 4275' & cmt f/ 4277' to 4330'. RIH to 4364' & circ clean. POOH w/ DR. NOW: RIH w/ bit & csg scraper. Circ clean ~ 4364'. Perfed lower lobe of 8-5 sd f/ 4307' to 4329' DIL w/ 4-1/2" HRF. RIH w/ RTTS pkr & aux valve & set pkr ~ 4280' DRM. Rut 1200 psi N2 cushion on DR & opened aux valve. Bled off N2 cush- ion & had gas & mud to surface in 20 min. Well initially was flowing 6 640 psi but gradually fell off to 50 psi. Well made + 1.5 MMCFD ~ 50 psi w/ 30 BWPH & large amts of sand. Released pkr & killed well. RIH to 4364' & circ clean. POOH. RU Dresser Atlas & perfed below B-5 sd f/ 4361' to 4363' DIL w/ 4-1/2" HPF for isolation squeeze. POOH w/ WL. RD Dresser Atlas. NOW: RIH w/ cmt ret on DP. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D ~AGE NO. LEASE Kenai Unit WELL NO. 21-7 FIELD Kenai Gas Field DATE 12 11/21/81 DAILY COST: ACC COST: AFE AMT: 13 11/22/81 DAILY COST: ACC COST: AFE AMT: ETD 4453' ID 4278' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. ~417' 63 PCF 39 SEC $ 38,200 $ 937,~044 $1,060,000 4453' ID 4347' ETD 10 3/4" C. 1195' 7 5/8" C. 4417' 67 RCF 40 SEC $ 24,270 $ 961,314 $1,060,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH w/ cmt ret on DP & set ret ~ 4347' DPM. Tested equip to 3000 psi. Pumped in w/ 2.6 BPM ~ 1800 psi~ Sqz'd parrs f/ 4361' to 4363' DIL w/ 165 sxs cl "G" w/ .75% D-31, .3% D~19, & .2% D-6 to 117 pcf. Displaced 140 sxs below ret w/ a f-inal rate of 4 BPM ~ 2000 psi. CIP ~ 03:00 hrs 11/21/81. Rev out 25 sxs cmt. POOH w/ DP. RIH w/ cmt ret on DP & set ret ~ 4278' DPM. Tested equip to 3000 psi. Pumped into perf's f/ 4307' to 4329' DIL w/ 4 BPM ~ 1300 psi. Mixed & sqz'd w/ 20ll.._SXS..Cl "G" w/ .75% D-31, .3% D-19, & .2% D-6. Displaced 180 sxs below ret w/ a final pressure of 2700 Psi. CIP ~ 08:15 hrs ~721~81 Rev out 20 sxs cmt. WOC. POOH w/ DP. NOW: WOC. RIBi~.w/ 6 1/8" bit. Tagged cmt ~ 4225'....Drld cmt f/ 4275' to 4278', ret e 4278'. Drld cmt f/ 4280' to 4334' & f/ 4339' to 4347'. Circ & POOH. RIH w/ bit & csg scraper to 4347' - circ clean & POOH. RIH w/ RTTS & aux valve. Tested lines to 3000 psi. Loaded DP w/ 1200 psi nitrogen cush- ien~,-Set pkr ~ 4284'. RU Dresser Atlas & tested lubricator to 2000 psi. Ran 2 1/16" rigid jet gun & perfed the upper portion of the lower lobe of the B-5 zone f/ 4307' to 4312', DIL. RD Dresser Atlas. Bled off nitrogen cushion & flowed well thru a 3/4" choke. Well stabilized G 1.54 MMCFD ~ 175 psi w/ 151BWPD & large amount of sand. NOW: Flowing well. SEP 2 1 1982 Oil & Gas Cons. Commission l\~]C!lora§o UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Kenai Unit WELL NO. 21-7 FIELD Kenai Gas Field DATE 14 11/23/81 ETD DAILY COST: ACC COST: AFE AMT: 15 11/24/81 DAILY COST: ACC COST: AFE AMT: 4453' ID . 4212' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. 4417' 63 RCF 38 SEC $ 19,506 $ 980,820 $1,060,000 4453' ID 3550' ETD (RET) 10 314" C. 1195' 7 5/8" C. 4417' 63 PCF 36 SEC $ 40,989 $1,021,809 $1,060,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Continued to flow top 5' of lower lobe of 8-5 sand f/ 4307' to 4312' DIL. Had stab rate of 1.75 MNCFD ~ 250 psi w/ 250 BWPD & lrge amt of sd. Killed well & RIH to 4315'. Circ well clean & POOH. RIH w/ cmt ret & set ret ~ 4212' DPM. Pumped into 8-5 perfs f/ 4361' to 4363' DIL & 4307' to 4312' DIL w/ 3 8RM ~ 1400 psi. Mixed & sqz'd w/ 150 sxs cl "G" w/ .75% D-31, .3% D-19, .2% D-6 to 119 pcf. Displaced 135 sxs of cmt below ret w/ a final Pressure of 1200 psi. CIR ~ 19:30 hrs. Rev out 15 sxs cmt. POOH w/ DP. NOW: Prep to sqz base of A-11 sd. RIH w/ perf gun - col failed. POOH & repaired same. RIH & perfed 4-1/2" HRF f/ 3808' to 3810' DIL (to isolate below A-11 sd). POOH w/ WL. Repaired WL unit. RIH w/ cmt ret on WL & set ret ~ 3830' PI1. POOH w/ WL. RD Dresser Atlas. RIH w/ cmt ret on DR & set ret ~ 3770' DRM. Tested lines to 3000 psi. Pumped into perfs f/ 3808' to 3810' DIL w/ 3.5 BRM ~ 1200 psi. Form held 800 Psi. Mixed & sqz'd w/ 160 sxs cl "G" w/ .75% D-31, .3% D-19, .2% D-6. Displaced 147 sxs below ret w/ a final pressure of 1000 psi. Sqz held 600 psi. CIR ~ 11:30 hrs. Rev out 13 sxs cmt. RU Dresser Atlas & tested lubricator to 1500 psi. Rerfed 4-1/2" HPF f/ 3576' to 3578' PI1 (to isolate above A-8 sd). POOH w/ WL & RD Dresser Atlas. Set cmt ret ~ 3550' DRM. Pumped in w/ 2.6 BPM ~ 1000 psi. Form held 800 psi w/ pumps off. Mixed & sqz'd w/ 160 sxs cl "G" w/ .75% D-31, .3% D-19, .2% D-6. Displaced 147 sxs below ret w/ a final rate of 3 BRM ~ 1100 psi. Sqz held 1000 psi w/ pumps off. CIR ~ 22:00 hrs. Rev out 13 sxs cmt. POOH w/ DR. NOW: POOH w/ DP. SEP 2 1 iS82 Oil & Gas Cons. Commission /\nchorafie UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Kenai Unit WELL NO. 21-7 FIELD Kenai Gas Field DATE 16 11/25/81 DAILY COST: ACC COST: AFE ANT: 17 11/26/81 DAILY COST: ACC COST: AFE ANT: 18 11/27/81 DAILY COST: ACC COST: AFE ANT: 19 11/28/81 DAILY COST: ACC COST: AFE AMT: ETD 4453' ID 3578' ETD (CMT) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 38 SEC $ 36,869 $1,058,678 $1,060,000 4453' ID 4208' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 38 SEC $- ~17,215 $1,075,893 $1,060,000 4453' TD 3615' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 37 SEC $ 18,095 $1,093,988 $1,060,000 4453' ID 3615' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 37 SEC $ 40,008 $1,133,996 $1,060,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS POOH w/ DP - WOC. RIH w/ 6 1/8" bit & 2 boot baskets. Drld ret ~ 3550' & cmt f/ 3552' to 3578'. Had high torque. POOH w/ DP. Tested BOPE. NOW: 'POOH w/ DP. RIH w/ 6" magnet to 3778'. POOH - no rec. RIH w/ bit #5 & drld ret junk 3578'. Drld cmt f/ 3580' to 3684'~ RIH to ret ~ 3770' & drld · "retS'-3770' Drld cmt f/ 3772' to '3780'. Trio for bit change. RIH w/ bit #6 & drld cmt f/ 3780' to 3820'. Dzld ret ~ 3830' & CO to 4208'. Circ clean. NOW: POOH w/ bit #6. POOH w/ DP. RIH w/ csg scraper to 4212'. Circ & POOH. RIH w/ cmt 'ret, & set ~ 3898'. POOH. RIH w/ RTTS pkr & aux valve. Set pkr ~ 3535'. Opened valve to dry test perfs f/ 3808' to 3810' DIL & 3576' to 3578' DIL - had it to mod blow. Killed well & reset RTTS ~ 3798'. Displaced DR w/ nitro· Bled off nitro to test perfs f/ 3808' to 3810' DIL - test was dry. Filled DR & POOH. RIH w/ cmt ret & set ret ~ 3615'. POOH. RIH w/ RTTS pkr. .! NOW: RIH w/ RTTS pkr. RIH w/ RTTS pkr & set ~ 3526'. Pumped into perfs f/ 3576' to 3578' DIL w/ 2 BPM ~ 1400 psi. Sqz'd perfs w/ 150 sxs c1 "G" w/ .75% D-31, .3% D-19, & .2% D-6. Dis- placed cmt below tool w/ a final rate of 3 BPM ~ 2300 psi. Press bled to 1000 psi. CIP ~ 04:00 hfs 11/28/81. POOH w/ RTTS. WOC. RIH w/ 6 1/8" bit & tagged cmt ~ 3570'. Washed soft cmt to 3575'. WOC. Drld fm cmt f/ 3575' to 3590' & C0 stringers to 3615'. Circ clean & POOH. NOW: POOH w/ bit. ~ ~ SEP 2 1SS? AI%',o O~A & fi:!s~.,~osCons, commission UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 7 LEASE KENAI UNIT WELL NO. 21-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 11/29/81 DAILY COST: ACC COST: AFE AMT: 21 11/30/81 DAILY COST: ACC COST: AFL AMT: 22 12/1/81 DAILY COST: ACC COST: AFE AMT: 23 12/2/81 DAILY COST: ACC COST: AFL AMT: 4453' TD 3893' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 PCF $ 20,897 $1,154,893 $1,060,000 4453' TD 3893' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 PCF~GRINE $ 26,128 $1,181,021 $1,060,000 4453 ' TD 3893 ' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 PCF BRINE $ 23,285 $1,204,356 $1,060,000 4453' TD 3893' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 PCF BRINE $ 16,665 $1,221,021 $1,060,000 POOH w/ bit. RIH w/ RTTS pkr to dry test sqz perfs. Set RTTS $ 3562'. Pressured up DP w/ 1400 psi nitro. Opened aux valve & bled off nitro- had no entry from BS parrs f/ 3576' to 3578' DI1. Had tool open 1 hr. Rev out & caught sample - no evi- dence'-of'-fluid entry. POOH w/ DP - LD~'t~. -RIH w/ 6 1/8" bit & drld ret~'~'5'. Pushed junk to 3893'. Circ~btms..up. POOH. Cleaned pits & .~PCF CaCL2 fluid. Disp~_~.~ed wellbore w/ CaCL2 fluid. NOW: Bldg volume. MIXED NEW CaCL2 COMPLETION FLUID. RIH W/ 6 1/8" BIT & 7 5/8" SCRPR TO 3~VER HOLE TO COMPLETION F~._~. RIH & SET TEST TOOLS ~~. -6ISPLACED FLUID W/ 1475 PS'I"N2'~'~ PERFED A-8 SAND F/ 3596' l~/ 650 PSI N2 CUSHION. HAU'~NU ENTRY. PERFED REMAINDER OF A-~,~F/ 3601' TO 3618' W/ 500 PSI~I~2'CUSHION. FLOWED WELL TO FLARE.~ N~NG A-8 SAND. T6s~-Bperfs f/ 3596' to 3618'. Stabilized rate 3.57 MMCFPD, no water, 475 psi tbg press. Inflow perfed 4 HPF the A-lO sd f/ 3664' to 3736'. NO~Pr.ep to perf A-11. Iq~-o~g~w~p.~rfed A-Il sd f/ 3756' to 37Ff~ould not get below 3780'- bridge. Attempted to spud thru b~~inker bars - no luck. Tested A-8, A-10 & A-11 perfs. Stabilized rate 9.82 MMCFRD, no water, ~ 975 psi tbg press. Killed well. Spot Dril-S & safe seal pill on btm. POOH. NOW: POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. 21-7 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 12/3/81 DAILY COST: ACC COST: AFE AMT: 25 12/4/81 4453' TD 4202' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 RCF 8PINE $ 33,528 $1,254,549 $1,060,000 4453' TD 4202' ETD (JUNK) 10 3/4" C. 1195' - Z-5/8'!~4417' 66 RCF BRINE DAILY COST: $ 89,645 ACC COST: $1,344,194 AFE AMT: $1,060,000 26 12/5/81 4453' TO 4202' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' 66 PCF BRINE DAILY COST: $ 18,49i ACC COST: $1,362,685 AFE AMT: $1,060,000 27 12/6/81 DAILY COST: ACC COST: AFE AMT: 28 12/7/81 DAILY COST: ACC COST: 4453' TD 4202' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' PKR FLUID $ 40,587 $1,403,272 $1,060,000 4453' TD 4202' ETD (JUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' PKR FLUID $ 36,188 $1,439,460 RIH w/ OB & 6 1/8" bit. Tagged junk ~ 3855' (did not see bridge ® 3780'). CO junk f/ 3855' to ret ~ 3898'. Drld out ret ~ 3898'. RIH to 4202'. Circ clean. Spot Dril-S & safe seal pill across perfs. POOH. RIH & set RTTS ® 3555'. Dis- placed DR w/ 1450 psi N2. Opened well to flare. Fluid to surf in 15 min, gas to surf in 30 min. Flowed well to clean up. Inflow perfed A-11 sd f/ 3776' to 3802'. Reperfed A-11 f/ 3756' to 3802' for a total of 8 HRF. NOW: Prep to reperf A-10 & A-8. Inflow perfed A-10 f/ 3593' to 3615' & the A-10 f/ 3661' to 3733' (8 HPF total now). Kill well. POOH. Run blt & scrpr to 4200'. Circ clean. POOH. Set Baker "D" pkr on WL $ 3930'. NOW: RIH to test pkr. RIH & tested perm pkr S 3930'. POOH LD DP. NOW: Running comp assy. Ran dual 2 7/8" tbg strings. Stabbed-into ~odel "D" pkr $ 3930' & tested - ok~ Landed tbg & set A-5 dual pkr ~ 3542'. Tested pkr - ok. Installed BPV's. Removed BOPE. In- stalled & tested tree. RU Otis on SS. Pulled "XN" plug & opened "XA" sleeve ~ 3509'. Displaced annulus w/ pkr fluid. Closed "XA" sleeve. NOW: Prep to flow well. Displaced tbg w/ nitro. Opened well to flow to clean up. Installed BRV's. Began rigging down. NOW: Rigging down. AFE AMT: $1,060,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. 21-7 FIELD KENAI GAS FIELD DATE ETD. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 12/8/81 4453' TD 4202' ETD (JUNK) 10 3/4" C.~1195'' 7 5/8" C. 4417' PKR FLUID DAILY COST: $ 13,530 ACC COST: $1,452,990 AFE AMT: $1,060,000 30 12/9/81 4453' ID 4202' ETD' (OUNK) 10 3/4" C. 1195' 7 5/8" C. 4417' PKR FLUID DAILY COST: $ 7.920 ACC COST: $1,460,910 AFE AMT: $1,060,000 Continued rigging down & moving rig to Brinkerhoff yard. NOW: Rigging down. , Continued to move rig to Brinkerhoff yard. Released rig e 19:00 hrs 12/9/81. Cleaned up location. Removed septic tanks. UNION OIL Cff PANY OF CALIFORNIA £LL }ECORD. LEASE I' ELLNO, li- " FIELD KGF DATE From 3553.46 3552.46 3543.66' 3511.76 3508.76 3476.76 3~72.76 1992.74 1988.74 1863.58 1859.48 1580.74 1576.74 94.21 92.00 28.59 15.19 13.78 Tol 3552.46 3543.'66 3511 ..76 :. 3508 .!76 3476 ..76 :. 3472.76 :. 1992..74 1988.74 1863 '58 1859.48 1580.74 1576.74 94~21 92 00 . 28~5S 1511~ 13 78 DETAILS OF' OPERATIONS,' DESCRIPTIONS & RESULTS Short String - Tbg Detail L.ength 1.00 8.80 31.90 1 3.00 32.00 1 4.00 1 1480.02 48 4.00 1 124.96 4 4.10 1 278.74 ~ 9 4.00 1 148Z'.53 48 2.21, 1 63.41 2 13.40 1.41 .. Landed below K.B Jts Description 2 3/8" "XN" nipple 7 5/8" x 2 7/8" x 2 3/8" Baker Model A-5 pkr 2 7/8" 6.4# Butt Otis 'XA' sliding sleeve 2 7/8" 6.40 N-80 Butt 2 7/8 "6.4# N-80 Butt pup 2 7/8" 6.40 N-80 Butt 2 7/8" 6.40 N-80 Butt pup , 2 7/8" 6.40 N-80 Butt 2 7/8" 6.4# N-80 Butt pup 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 Butt pup 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 Butt pup 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 Butt pup Tbg Hanger U[1IOI.I OIL Cg'?ANY CF CALIFOI ,iIA ELL RECORD S EET D PAGE i.b, --- LEASE DATE From 3938.70 3938.00 3928.00 3896.14 3893.21 3832.59 357~.26 3554.26 3541.66 3478.58 3475.65 3074.72 3072.'49 2825.89 2823.65 2701.32 2698.20 2513.36 2509.11 2261.85 2257.73 2199.19 2195.13 1388.69 1384.49 987.97 982.91 801.45 797.28 30.01 16.81 15.41 14.00 ETD To 3938.00 3928.00 3896.14 3893.21 3832.59 3574.26 3554.26 3541.66 3478.58 3475.65' 3074.72 3072.49 2825.89 2823.65 2701.32 2698.20 2513.36 2509.11 2261.85 2257.73 2199.19 2195.13 1388.69 1384.49 987.97 982.91 801.45 797.28 30.01 16.81 15.41 14.00 ELL NO, 21-7 FIELD KGF DETAILS, OF OPERATIOHS, DESCRIPTIO[IS & RESULTS. Lpng String Tbg Detail Length .70 10.00 31.86 1 2.93 60.62 258.33 13 20.00 1 12.60 Jts Descript,~pn, Bull Nose Model "D" pkr with seal assy 2 7/8" 6.4# N-80 Butt Otis "XA" sliding sleeve 2 7/8" 6.4# N-80 Butt 2 7/8" Blast jts. 2 7/8" 6.4# N 80 Butt pu Baker Model A-5 pk~ 63.08 2 2.93 400.93 13 2.23 1 246.60 8 2.24 1 122.33 4 3.12 1 184.84 6 4.25 1 247.26 8 4.12 1 58.54 4.06 806.44 26 4.20 1 396.52 13 5.06 1 181.46 6 4.i7 1 767.27 13.20 1.40 1.41 25 2 7/8" 6.4# N-80 Butt Otis 'MA' sliding sleeve 2 7/8" 6.4# N-80-Butt 2 7/8" 6.4# N 80 Butt pu 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 Butt pu 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 2 7/8" 6.4# N-80 pup 2.7/8" 6.4# N-80 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 2 7/8" 6.4# N-80 pup 2 7/8" 6.4# N-80 Butt 2 7/8" 6.4# N-80 Butt p~ XO Tbg hanger ed Below KB. -- . -iii i i i TUBING DETAIL Long String: 1. 2 7/8" Otis "XA" sleeve- 3476' 2. 7 5/8" X 2 7/8" X 2 3/8" A-5 pkr - 3542' 3. 13-2 7/8" Blast Joints f/ 3574-3833 ' 4. 2 7/8" Otis "XA" sleeve- 3893' 5. 7 5/8" Model "D" pkr- 3930' 6. Seal assy f/ 3938-3928' 7. 2 7/8" Bull_nose~939' 10 3/4'; C. 1195' Short String: A. 2 7/8" Otis "XA" sleeve - 3509' B. 2 3/8" "XN" nipple- 3552' Pool 3 -A-8, A-10, A-11 Sands 3596-3618' 3664-3736' Open to Production 3756-3802' L . Pool 5.1 - B-3 & B-4 Sands 3978-3989' 3991-4022' 4036-4048' 4056-4070'' 4072-4102' 4128-4160' 4162-4172' 4180-4202' Open to Production DATE KENAI UNIT #21-7 WO DAI~ UNION OIL COMPANY OF CALIFORNIA : 12 -~ ~ STATE OF ALASKA --~ ~ ~ ALASKA £ ~'AND GAS CONSERVATION COt,?IIsSION ~.~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS / ' 1. Drilling well [] Workover operation [] 2. Name of operator UNION' 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 362'N & 1024'E of SW corner, Sec. 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB B5' MSLI A-028!42 For the Month of DECEMRFR 7. Permit No. 68-5 8. APl Number 50- 133-1009200 9. Unit or Lease Name KENAI UNIT 10. Well No. KU ~t21-7 11. Field and Pool Kc'~,mT r,.c- FIELD 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Rigged down 12/7/81 & released rig ~ 19:00 hfs 12/9/81. 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None I 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed 3664-3736' 3756-3802' JAN 2 2 1.9S2 JVaska 0il & Gas Cons. Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE DIST DRLG SUPT DATE 1/15/82 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~ ,~,,, '7_1 .' ' /'"' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COiv, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] ,, COMPLETED WELL OTHER~I 2. Name of Operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA "'. ..... ~8-5 3. Address " 8. APl Number · PO BOX 6247 ANCHORAGE AK 99502 ' 50- 133-1009200 4. Location of Well ]. .'. 362'N & 1024'E of SW corner, Sec. 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 85' MSL A 028142 9. Unit or Lease Name KENAI UNIT 10. Well Number KU f121-7 11. Field and Pool KENAI CA% FTFI n 12. Check Appropriate Box To Indicate Nature of Notice, Report,' or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other r-I Pull Tubing [] Other [] Pulling Tubing j~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)_ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). (See attached) Verbal approval to squeeze B-5 perfs and perf A-8, A-10, & A-11 by Oim Trimble 11/24/81. DEC? 14. I he t rue and correct to the best of my knowledge. DIST DRLG SUPT Signed /7J,¢~,~i I% , Title Conditl~s//of APproval, if any: At~.s't':~ Oil & Gzs Cor~s. CorHrnissiou 12/18/81 Date Approved by By Order of COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Sundry Notice KU #21-7 12/18/81 1. Began moving Brinkerhoff Rig #31 over KU #21-7 ~ 06:00 hrs 11/8/81 & RU. 2. Kille~ well, installed BRV's, removed tree, installed & tested 80RE. 3. Rulled & stood back existing dual 2 7/8" tbg assy. 4. Cleaned out to 4364'. 5. Sqz'd lower B-5 perfs for isolation f/ 4307' to 4329' w/ 200 sxs. Rerfed upper B-5 f/ 4256' to 4260' & sqz'd w/ 200 sxs. 7. Cleaned out to 4364'. 8. Reperfed & tested lower B-5 f/ 4307' to 4329' & sqz'd w/ 200 sxs. Rerfed & sqz'd for isolation f/ 4361' to 4363' w/ 165 sxs. 10. Perfed & test lower B-5 f/ 4307' to 4312' & sqz'd w/ 150 sxs. 11. Perfed & sqz'd f/ 3808' to 3810' w/ 160 sxs for isolation. 12. Perfed & sqz'd f/ 3576' to 3578' w/ 310 sxs for isolation. 13. Cleaned out to 4212' & tested sqzd perfs. 14. Perfed A-8 sds f/ 3596' to 3618' & tested. 15. Rerfed A-lO sds f/ 3664' to 3736' & A-11 sds f/ 3756-3802' & tested. 16. Set Baker "D" pkr ~ 3930'. Ran dual 2 7/8" tbg string w/ A-5 dual pkr 3542' & tested. 17. Installed BPV's, removed BORE, installed & tested tree, & flowed well. 18. Installed BPV's & rigged down. ,, ,,...? p:' .. ,~-' STATE OF ALASKA ~, /f"~/~.., ALASKA ~L AND GAS CONSERVATION COMMISSION ~-~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION$" ' · Drilling well [] Workover operation [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 362'N & 1024'E of SW corner, Sec. 6, T4N, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) KB 85' MSL 6. Lease Designation and Serial No. A-n28142 7. Permit No. 68-5 8. APl Number 5o- 133-1009200 9. Unit or Lease Name KENAI UNIT 10. Well No. KU ~t21-7 11. Field and Pool KENAI GAS FIELD For the Month of. NOVEMBER ,19 81 · 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Began operations ~ 06:00 11/8/81. Retrieved completion assembly. Tagged fish ~ 4319' - retrieved. 13. Casing or liner run and quantities of cement, results of pressure tests Tested BOPE to 3000 psi - ok, 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed & sqz'd: 4256-4260' 4307-4329' 4361-4363' 3808-3810' 3576-3578' Perfed 3596-3601' 3601-3618' Sqz perfs 4307-4239' DEC2 1 1~8] 1 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,"-~'~'",.,,.~.,~ Oi) & Gas Cons, C0mrnjs S~GNE° /' ---, _ T~TLE. D~ST DRLG SUPT ~A~E ~2/~/8~ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate STATE OF ALASKA ALASKA ,.iL AND GAS CONSERVATION CL,.AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER)(~ ~ 2. Name of Operator Union Oil Company of California 3. Address P, O, Box 6247, Anchorage, Ak 99502 4. Location of Well 362' N & 1024' E of SW Corner, Section 6, T4N, RI'IW, Seward Meridian. 5. Elevation in feet (indicate KB, DF, etc;) 85' PKB I 6 . Lease Designation and Serial No. A-028142 12. 7'PermitN°: {~ 8. APl Number 50- 9. Unit or Lease Name Kenai Unit 10. Well Number KU #21-7 11. Field and Pool Kenai Gas Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ]f(-I Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ]~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROCEDURE' · 2. 3. 4. 5. 6. 7. 8. 9. 10. ll. 12.. 13. 14. Move Brinkerhoff Rig #31 over KU #21-7 and rig up. Kill well, install BPV's, remove tree, install and test BOPE. Pull and stand back existing dual 2 7/8" tubing assembly. Clean out to 4369' ETD. Squeeze lower B-5 perfs for isolation. Perf upPer B-5. Squeeze upper B-5 perfs for isolation. Clean out to 4369' ETD. Reperf and production test lower B-5 sand. Resqueeze for isolation as required by testing· Complete the well as a dual zone gas producer with perm pkrs Treat well wi th OH-AL. Remove BOPE & install and test tree. I EEEIVEO Place well on production and move. rig out. OCT 0 2 198! Subzcque:2 %Vc~'k Rc:~orted }~ A! oa Yo~m No. [~ Dated ~/Z~/ ~¥~ aska 011 & Anch0rageGaS Cons. Commission 14. I hereby ~;ertify that the foregoing is true and correct to the best of my knowledge. , Signed Title DISTRICT DRILLING SUPERINTENDErbl;te The s,~'belOw for Commission use Co di~ns/! of APproval, if any: 9/30/81 Approved Copy Returned BY [ON~tE C. sMITH By Order of Approved by COMMISSIONER the Commission Date Form i0-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Worm D-1001 UNION OIL CO. OF CALIFORNIA REPAIR RECORD LEASE KENAI .UNIT _WELL NO.. 21-7. CONTRACTOR_ SHEET A PAGE NO. .T-20 GROUND CASING HEAD TUBING HEAD FIELD KENAI GAS FIELD 3EG.&N: 8./5/81 COMPLETED: 8/21/21 · TYPE UNIT__ ELEVATIONS: ?ERMIT?O. 68-5 ^ SERIAL NO. A-02alZ[? , SOMPA~Y EI~GI~EER E~sh, .Bou]~a~t~ ~l 1 ister ,qPPROVED. {~ ~ ~ ~ '¢ -- -SIZE I DEPTI~ W4L~HT GRADEI ~EM~R~ S ~F:~ ~ e: ]0 3/4' ]]95' 32.75# H-40 Cemented w/ 800 sxs Kaiser cement. 7 5/8' 44]7' 26.4# 0-55 Cemented w/.550.sxs Kaiser cement. 2 7/8' 4292' 6.4# N-80 tubing long string. - 2 7/8' 3920' 6.4# ~-80 tubin9 shoot st~]~g , " with Model "O" pkr 0 4279' & 4215'& "AL5" dual pkr ~ 3908'. PERFORATTNG RECORD DATE .... INTER'V~L,, , E.T.D. BEASON ' PRESENT 6/13/65! 4208-4209' 4369'~ WS0 Holes are open 6/14/65 3970-3971 '~ 4369' WS0 Holes are open 6/15/65! 3978-3989'-- ,, Productioni Open for production " 3991-4022 '~ " " " " " " 4036- 4048'~ " " " " " " 4056-4070 ~ " " " " " 4072-4102 ~- " " " " " " 4128-4160 L " " " " " · " 41 62-4172'~ ".- ." " " " " 4180-4202'-~ " " " " " " 4219-4241' " " Sqz'd w/ 200 sxs cmt ' " 4248-4260' " " " "" " " " 4307-4329'- " " '' Open for production INITIAL PRODUCTIC DATE I INTERVAL NET OIL CUT GRAV. 8/27/81 4307-4329"~ ': 850 9.0 No sand.orwate.r.'..'- " 4180-4202'- " 416 2-417 2: '- ' " 4l 28-41.60'- ' II II · ~.' ' I1'.'[; ,. '" ~' ';'' ". " 4072-4102~ ., '. · " 4056-4070 ~'- " " " · " 4036-4048'~ I . ' ,, · ,, .' / ,,"-~ '~..."'.'.. · . . " 3991-4022~ -" " '" ' ' "- · " 3978-3988'~ " · " '" · · · · , . ~ . . · · . ', · WELL HISTORY pRIOR TO REPAIR LAST COMPLETION NO. ~OMPLETION DATE: PRODUCING iNTERVAL: iNITIAL PRODUCTION' ,LAST REGULAR PROD. & DATE: ']UMULATIVE PRODUCTION: Rbtgl¥ U REASON FOR REPAIR: ,..,, · ~a...~_ Onn,~. Commission . ,:,-: .... OIL CO.. OF CALl ;~:"" :Y'i.-:-!!i"",.':~!-::~:i;'i?,--~ '":!,';-.:/,,-,:~-~.:-'..,:'.':':,: REPAIR RECORD . ~ :'.;':i, PAGE: NO UNIT '" -" '": ~ WELL NO. 21-7 FIELD~ KENA'I' GAS' FIELD DATE: _ 8/21/81 &PPBOV~D DATE.._.~. E.T.D~ DATE:'] 'I I,NTE. RVAL 8/11/8] !4307..4327' 8/12/81 4249-425'9' 8/12/81 8/1 6/8I II : II 4220-4240' 41801~4202' 4162~41~72' 4128,41.60'-~ 4072,41021.~' 4056~40'70.' 40316~ 4048 ~'. 39911~_~02'2,~ 3.978L3988'~ _ DETAILS OF OI~ERATIONS, DESCRIPTIONS & RESULTS ETD 4369' . . II II II -, , ,' 4369' Reperf . . Ii ' ' ' ' II II ' . II ' II ' "' ' ;' :' -;-II . Ii ' '' - II II ' ' II : II ' -.- II '. . II - REASON PRESENT' CONDITION Reperf.-DST Open for production '" Sqz'd w/ 200 ~xs cement II Open for production II ..- TYPE: ~AS~ ~A~S: ' ..;.'~-~t~?~;~.,';%~'-:;.'-"- '-.~: '. - ?Y-'-~.~..--- ,'~-?~,':~-~--~'~-.-.',. -.~'-7~.:'-.';~'.~;~.--~- ;"~' SL:;-~'~:~'.~.~-~ ;'- - ,~-;2;~;~:-.--'~';..-'.-"'~-tf~:~;~¢~'-;..'~¢-.~ ,:~ ~- -~;~ -;' '~;~"- ,~. ~" '~ ¢ ~; ': :?::?,7? -: ':'.-.::- .-: ' .:: %, ::~:~:~. -.~ "?'- .--' :~:'-~':. -:~ -~ '- ~;.7~L~'::_~;-;' :'.:~' .:.;'::.~:~: f:':::';~ ' ;~:~::'.:7~:;.::~:..' ' -: ?:~;~:-..-~-,-".,' ~:? .... ::.¢-~,"?~; ,~-',.-" . :'~ - - '-..-'-'----. "¥~-~:..¥':::~-";~-':~%;..~. ~:..:.--~.;'--.-:..~ - ,~ -:. ':-~;- ? ..... .' .:T--'~'7" :~.: .;~. :; "-.-.7.;;: ,'-%-~7~;.' . .:?,~,,~;~ .'~;;~%.:.. ??;~;;,:,~.;~: ~-~ Form D-IO01~-C UNION O'll CO. Of CALIFORNIA 'R~PAIR RECORD SHEET C PAGE NO. LEASE ... KENAI UNIT COMPLETZON DATE: R/21/8! WELL NO. 2l'-7 FIELD KFNAT GA.g'FTFI D APPROVED DATE E.T.D. JTS 35 5 10 38 3 20 6~ DETAILS OF OPERATI~lqL4, DESCRIPTIONS & I~ESULTS TUBING DETAIL SHORT STRING - 2 7/8" DESCRIPTION LENGTH BOTTOM TOP , 2 7/8" Otis Baker Model 2 7/8".6.4# 2 7/8" Otis 2 7/8" 6.4# 2 7/8" Butt 2 7/8" 6.4# 2 7/8" butt 2 7/8" 6~4# 2 7/8" butt 2 7/8" N-80' 2 7/8" butt 2 7/8",N-80 2 7/8" butt 2 7/8" N-80 2 7/8" butt 2 7/8" N-80 2 7/8" butt 2 7/8" N-'80 27/8" butt 2.7/8" N-80 ,! · , 2 "XN"'.Nipple "A "d -5 ual pkr N-80 butt tbg "XA":sleeve N-80 butt tbg Pup;,(]) N-80 butt tbg .pu:p.' (]) N-80 butt tb9 pup (l) butt ~b9 pup (.1') butt.th9 pup(l) butt th9 pup (1) butt.th9 pup (.l) butt.'tb9 ,rPUP (,1)' butt ~.pup :(] .) 2 7/8" butt pups Tub.i~g Hanger Landed bel-ow'RT . ..~ .92' 9.78' 31.44' 2.92' 29.70' 5.15' 1080.28' 5.17' 181',.'29' 3.12" 150 .'69' 4.19' 309.68'- 3.15' 1175..54~ 5.11' 90.41 ' 3.115 ' 614..07' 3,,'06' 18-3.167.'. 5:,0,5' 7:.77' 1'~25" 13~85' 3:920.41' 3919.49' 3909.71' 3878.27' 3875.35' 3845.65' 3840.50' 2760.22' 2755.05' 2573.76' 2570.64' 2419.95' 241 5.76 2106.08 2102.93 927.39 922.28 831.87 828.72 214.65 211'.59 27.92 22.87 15~10' 13.85" 3919.49' 3909.7.1 ' 3878.27' 3875.35' 3845 ..65 3840.50 2760.22 2755.05 2573.76 2570.64 2419.95 2415.76 2106,08 2102.93 927.39 922.28 831.87 82'8 .'72 21'4 ,"65 .. . _ . . -. . .RECEIVE !OCT.'O 2 ]98! . ... .. -., :' ~:~:.:'~-:..~.'.:',:~:.:.,'-:~Z~:~' -.., ." z:. - Form D-IO01~-C UNION OIL COo OF CALIFORNIA R~PAIR RECORD SHEET C PAGE NO LEASE KENAI UNIT COMPLETION DATE: 8/21/81 WELL NO.2l-7 FIELD KENAI GAS FIELD APPROVED_____ ' DETAILS OF OPERATIQ.NS, DESCRIPTIOHS & RESULTS ........................................ TUBING DETAIL LONG STRING - 2 7/8" JTS DESCRIPTION LENGTH BOTTOM 1 ]3 1 13 13 16 13 15 TOP ,, 2 7/8" mule shoe Baker seal assembly (80,32) Baker. model "D" Packer @ 4279' Baker locator (turned -down) 2 7/8" N-80 butt pups (2) 2 7/8" N-80 butt'~ tbg 2 7/8" N-80 butt pups (2) XO 2 7/8". 10RD-X 2 '7/8" bUtt pin Baker seal assembly (,80,32). Baker locator sub 2 7/8" Otis "XA" Sleeve 2 7/8" buttress blast joints 2 7/8'! N-80 butt tbg 2 7/8" 'N-80 butt pup (1) Baker odel .A-5. dual packer 2 7/8" N-80 butt -pup '(l) 2 7/8" N-'80 but't tbg "~ 2 -7/8" Otis "XA" sleeve 2-7/8" N-80 butt tbg . . 2 7/8" butt pUp (l) · 2 7/ -N-80 butt tbg 2 8" ' , I''7/..-butt.pUp (l) 2 7/8',",N-80. butt tbg " .64.' 4292.49' 15.85' 4291.85' .9l 8.25 30.28 10.'30 .70 10.53 1.00 3.56 25.8.33 31.39 2.28 10.20 4.'10 32.01 2.92 39.3.78 4.08 - '361,. l 4 .~.-. ..... t 5.1.0 150.14 4291.85' 4276.00' 4276.00 4275.09 4266.84 4236.56 4226.26 4225.56 4215.03 4214.03 4210.47 3952.14 3920.75 3918.47 3908..27 3904.17' 3872.16' 3869.24' 3475.46' 34'71.38' ~311'0.24' 310-5.14' 2955.00' 4275.09" 4266.84 4236.56 4226.26 4225.56 4215.'03 4214:03 4210.47 3952.14 3920.75'" 3918.47' 3908,27' 3904..17.,~ 3872~.16,' _3869.24' '3475.46' 3471'i~.38.~ 31.10',24' 3'105.~'4'-': 2955~00" '2949~90' 2 .7/8",i-..N:80 -butt :tbg-:':.- .',- ,,v ,. ,492'.78''r '.' '2886.23' ;" ,.. . : (l - ':'; "'~ , :];" "' ' I " " i 2 .7/8...:b. utt,, . pup (1) .--;:-,', r :" :4 ' . '~''-.~..' :.5.20-.' 239'3-, 45 , : .' ' '"" : ":" I :' 2.7/8. N-80. butt .tbg :... , -. .... .179.39 .... 2388.25 ., ~pUp (,1.):'].....'": :'~:.::~ 4,14'., ~.,.',.',' 2208, 2 7/8.:-[,N,80 "b.u~'t] :'bg · ':,-:':_~']:-,:' 1.5~'..31 ' ;'""'l":], ' 2204.72 ""' '1 '~ :'' . ~ ' ' - :: ' ". · ":.' .";.'~' ·" ' ' I "'"' '"" " I 7/8 .:,.butt pup (]) ~ ..- :.-.~,.,...- ~,5~08' ,......, .2052~41 2'-7/8?N-~O.:.:bUtt ~bg ,~:(:].,;.-' T,?~'-' .883', 5]':t'..'-':' ~"."' 2047.33"~ 2'--7/8:~,:.:;bUtt.. pUP:.(-I )":- '.,.. ~':/:~'-.~ .' ,';-' :~, ~":' ..-'4~'09'~.:.~.--." .' .', ~-'l 2 7/8,,,::.-:. N.80 ~'utt~.: .~bg '..'~ .'."..::-..:._._]~. ~.':,39:S .0]-. '.-:....' ."-' 1'][~[9.: 2':,7/,8-~L::~butt. PUP-~.(:i) · t. ~'..!'- ':, '. '~.:': :" .; .:" ~,'10' . .. ~- .-."'- 764, 7 . ..: .~i.. ..-. . .... , .: [, .'. ....'? .., .]..,:~,, . ~.:...:.:'. :-., ,:... .... 2/.7~.8. NrS'obutt'tbg . -.. ,-',,...2~0.77 '".'L~ :.', 76.1 .'62.~.,:: 8"' ' ' "-' ':' ':'~ :'' .... '" ":~' ~ 2:7/ ..butt-pup (1:,)' - : .... :.-,.' '3.10 490,.85 2 ,;':'.,' "462.93'-. ' .4' ~"': .-8.7 ,.!: 4' 8" 2-.7/8~.": pups`.. :: :.'.'::.. '--:~ ~: :.:L~:.], ?t~':,.:,. 72..._::~.. ,-: .9.. 72-~ .'..:., .. :. .; 2 :.' Tubing.:thanger.~::-: -~'....:"-,.: ~.']:::: :']' '-?:'~.'.'.: ..' 1:.25:'.,...,-.':::: ,l.'5:','lO':,':' Lande'8-":belSW-'R':T];:''-''':': ' .-'":' ~;" '- :'.'~':~:" .q3'85~-'.:'''': "' '; "'13,'8'B':" _ . ' _ . t .']'[:(..., .... ] .-'... . , .. . - -. '. :.. [. - ,: , .' . . . .. , . EC'E VED OCT TUBING DETAIL LONG STRING · e 4. 5. 6. 2 7/8" Otis "XA" sleeve @ 3869' Baker Model "A-5" dual 'pkr @ 3908' 2 7/8" blast joints 3952-4210' 2 7/8" Otis "XA" sleeve @ 4210' Locator sub at 4214' Baker model "D" pkr @ 421 5' 7. Model 80-32 seal assy 4215-4226' . 8. Locator sub (turned down) @ 4275' 9. Baker model "D" pkr @ 4279,' 10. Model 80-32 sea] assy 4276-4292' 11. 2 7/8" mule shoe @ 4292' Tubing hanger - 13.85' bel ow RKB 10 3/4'"C. 1195' SHORT STRING A. 2 7/8" Otis "XA" sleeve @ 3875' B. 2 7/8" Otis "XN" nipple @ 3920' ll 5.1 Pool - B~3 & B-4 Sands 3978-3989' 3991-4022' 4036-4048' 4O56-4070' 4072-4102' 4128-41 60' 4162-4172' 4180-42.02' Open to production' 5.2 Pool - B-5 Sands 9 4219-4241' 4248-4260' Sqz'd & isolated 43O7-4329' 7 5/8" C. 4417' Open to production DATE KENAI UNIT #21-7 WO DItAWN ~ SGALE CKD. Com, UNION OIL. COMPANY OF CALIFO)',NIA SHEETS, I IJi'IIOI! OIL Ca ?A IY OF CALIFOP . IA £LL RECORD S ;EET D PAGE ih, ...1 LEASE A~028142 ELL NO, KU //21-7 FIELD KENAI GAS FIELD DATE A 8/5/81 DAILY COST: ACC COST' AFE AMT' 8/6/81 DAILY COST' ACC COST' AFE AMT' "1 8/7/81 DAILY COST' ACC COST- AFE AMT- 2 8/8/81 DAILY COST. ACC COST- AFE AMT- 3 '8/9/81 DAILY COST: ACC COST: AFE AMT' ETD 4453' TD 4369' ETD l0 3/4" C. 1195' '7 5/8" C. 4417' $ 17,458 $ . 17,458 $ 700,000 4453' TD 4369' ETD '10 3/4" C. 1195' 7 5/8" C. 4417' $ 20,996 $ 38,.4,54 '$' 7oo,ooo 4453' TD 4369' ETD' '!0 3/4" C. 1195' 7 5/8" C. 4417' $ 25'728 $ 64,182 $ 700,O00, 4453' TD 4369' ETD l0 3/4" C. 1195' 7 5/8" C. 4417' $ 27,697 $ 91,879 $ 700,000 4453'. TD 4369' ETD lO 3/4" C. 1195' 7 5/8" C. 4417' $ 27,218 $ 119,097 $ 700,000 RECEI OCT 0 2 oil & Gas i DETAIkS .OF. OPERATIOI.tS, DESCRIPTIOI!S ~ RESULTS MoVed in rig'#31 over KU //21-7. Commenced rig up(~) 06:00 hrs 8/5/81. · NOW' Rigging up. C°nti'nued r~gging up over well KU //21-7. Raised derrick, laid water lines, and hooked up support houses. Filled mud pits w/ water & began mixing mud. -NOW' Mixing mud. Mixed gel-KCL kill fluid. RU Dresser Atlas & tested lubricator to 3000 psi. Perfed 4 circ hol~ in LS @ 4195'. Pumped down LS ~ up SS w/ kill mud. Both stri-Dgs are dead. RU DA on SS & perfed 4 cie holes @ 3907'. Pumped down LS & up annulus until had mud to surf. Well is dead. Installed CIW BPV & removed tree. Installed 10" 5M BOPE w/ dual 2 7/8" rams & tested to 2500 psi - ok. Latched o~ SS & pulled out of dual pkr @ 3913' w/ 45M#. POOH & laid down SS.. NOW' Laying down SS. Completed pulling & laying down SS of 2 7/8" tbg. Latched onto LS & worked torque down to pkr - coulJ not unseat. RIH w/ 2 .7/8" jet cutter & cut LS @ 4179'. Worked RH torque down to dual pkr & release same. Circ btms up & POOH laying down LS. Chang~ out pipe rams. RIH w/ 5 3/4" OS w/ 2 7/8" hollow mill control on 3-4 3/4" DC's & 3 1/2" DP. Tagged TOF @ 4185' DPM. Rotate & mill on TOF. NOW' Milling on fish. ! Continue milling on TOF. Could not get over fish. POOH w/ fishing tools. Hollow mill control showed evidence of rotated on fish. RIH w/ 5 3/4" OS w/ hollow mill control & 2 7/8" grapple & milled on T~ @ 4185' DPM - had no torque. POOH. Mill control had a few marks on it but no'milling being done. RIH w/ 5 7/8" guide shoe on 2 7/8" outside cutter- could not get over fish. POOH w/ cutter. RIH w/ 6 1/2" X 4 ~/4" WO shoe & 27' of washpipe extensicn on DP. Burned over TOF @ ran down to tag pkr @ 4209' DPM. POOH. RIH w/ WO shoe w/ 2 7/8" hollow mill control & grapple. Latched onto fish. Puller IOM# over string weight & grapple pulled off'fish. Could not'get back on fish. POOH. RIH w/ WO shoe w/ 2 7/8" hollow mill control, 2 3/4" grapple & 3' extension behind grapple. NOW: RIH w/ fishing tools. U[IIOI! OIL CCi;PAUlY OF CALIFOR .iIA WELL RECORD S ;EET D PAGE ih, :..2 LEASE A-028142 NELL l~O, KU #21-7 DATE 4 8/10/81 DAILY COST- ACC COST' AFE AMT- 5 8/11/81 DAILY COST: ACC COST- AFE AMT- 6 8/12/81 DAILY COST- ACC COST- AFE AMT- 7 8/13/81 DAILY COST- ACC COST: AFE AMT' ETD 4453' TD 4369' ETD l0 3/4" C. 1195' 7 5/8" C. 4417' $ 29 ,lO0 $ 148,197 $ '700,000 4453' TD 4369' ETD 10 3/4" C. 1195' 7 5/8" C. 4417' $ 54,17~ $ 202,374 $ 700,0o0 4453' TD 4369' ETD 10 3/4"'C. 1195' 7 5/8" C. 4417' 65 PCF 36 SEC $ 22,737 $ 225,111 $ 700,000 4453' TD 4369' ETD 1'0 3/4" C. 1'195' 7 5/8" C. 4417' 65 PCF 35 SEC $ 29,748 $ 254,859 $ 700,000 FIELD KENAI GAS FIELD , RIH w/ WO shoe w/ 2 7/8" hollow mill control, 2 3/4" grapple, & 5' extension above grapple. Worked over & latched onto fish. Worked RH ~orque to fish & released Brown M-1 pkr. POOH - rec pkr & tbg tail. RIH w/ 6 1/2" WO shoe on 30' wash pipe - stopped @ DCB spool. Drained stack & found split piece of tbg laying across DCB spool. RIH w/ 7" magnet & rec 1/2 of split tbg - remainder fell in hole. RI~ w/ 6' 1/2" WO shoe & 30' of washpipe & tagged fill ~ 4230'. Run on junk for 1/2 hr & washed soft sand fill down to 4369' ETD. Cir$ btms up & POOH. LD WO assy & RIH w/ 5 3/4" OD ~vershot w/ 1 7/8" grap~ to catch WL tools. Latched onto WL tools @ 4355' ~ POOH. Rec entire 14' length of sinker bars & jars. NOW' RU Dresser Atlas to run FDC-CNL log. Ran FDC-CNL-6R-MSN & GR-CCL logs f/ 4369' to 2500' RD Dresser Atlas. RIH w/ 6 1/8" bit on 7 5/8" csg scraper to 4369'_ Circ & POOH.. RU Dresser. Atlas perfed 4-1/2"HPF w/ 4" jumbo jet cs9 guns f/ 4310 to 4330' GR-CCL. RD Dresser Atlas. RIH w/ Baker retrievamatic pkr - discovered it was dressed for 33-39# csg. POOH. Redressed retrievamatic to run in 26# csg. RIH w/ retrievamatic. NOW: RIH w/ retrievamatic. RIH w/ Baker retrievamatic & set @ 4288' Opened stimulation valve & tested perfs f/ 4310; to 4330' DIL. Rate stabilized @ 10.58 MMCFD @ 850 psi.' Opened bypass & killed well. POOH w/ DP. RU Dresser Atlas & perfed f/ 4252' to 4262' & 4223' to 4243' D~. (Had 1-10' gun missfire). POOH w/ WL. RIH w/ RBP on retriev- amatic pkr w/ stimulation valve. Set RBP @ 4280' DPM. Set retrievamatic pkr @ 4215' DPM. NOW: RU tes.t manifold. RU test manifold & loaded w/ llO0 psi gas cushion.. Opened stimulation valve & removed gas cushion. Had limited blow from well. RIH-w/ 20' of 2 1/16" perf guns - stopped @ 4224' POOH. Released test pkr & filled DP. RIH & tagged fill @ 4224'. Washe~ & circ out sand f/ 4224' to 4280'. Retrieved RBP & POOH. RIH w/ Baker 7 5/8" cmt ret on WL & set @ @ 4280'. RIH & set 7 5/8" cmt ret @ 4208'. RD Dresser Atlas. RIH w/ stab-in tool on 3 1/2" DP & tagged ret @ 4208'. RU & tested sqz manifold. · NOW' Prep to sqz off upper '.lobe of 5.2 pool sand. RECEIVED OCT 0 AI3ska Oil & ~las Oon~, 8ornmls~lon Anchor~9~ Ui'llOI.! OIL CO PAI Y LF CALIFORHIA ELL CORD SI-:EET D PAGE ih, ...3 LEASE A-028142 DATE 8 8/14/8l DAILY COST' ACC COST' AMT' 9 8/15/8l DAIL-¥ COST' ACC COST' AFE AMT: lO 8/16/8 DAILY COST: ACC COST' AFE AMT' ll 8/17/81 DAILY COST: ACC COST' AMT: ETD 4453' TD '4208' ETD (RET) 10 3/4" C. 1195' 7 5/8" C. 4417' 65 PCF 34 SEC $ 35,360 $ 290,219 $ 700,000 4453' TD 4369' ETD l0 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 35 SEC $ 23,163 $ 313,382 $ 700,000 4453' TD 4369' ETD l0 3/4" C. 1195' 7 5/8" C. 4417' 64 PCF 33 SEC $ 49,768 $ 363,150 $ 700,000 4453' TD 4215' ETD (PROD PKR) 10 3/4" C. 1195' 7 5/8" C. 4417' KCL FLUID $ 28,695 $ 391,845 $ 700,000 NELL NO, KU #21-7 FIELD KENAI GAS FIELD DETAILS_OF OPERATIOI.IS~ DESCRIP..TIOI-!S ~.RESULTS RU & tested sqz manifold & surf lines to 5000 psi. Broke circ & stabbed into ret..P.ressured up .to 5000 psi - bled to 3000 psi in 7 min. Pulled outa~ ret & broke circ. Stabbed into ret & broke down 'upper 5.2 sd f/ 4223' to 4243' & 4252' to 4262' DIT, W/ 800 psi. Pumped in w/ 6 BPM @ 2400' psi. Formation held 400 psi w/ pumps off 10 min. Mixed & sqz'd w/ 200 sxs cl "G" w/ .75% CFR-2 & .75% Hal~4 22A. Displaced 200 sxs below ret w/ a final rate~ 3 BPM @ 2700 psi. Sqz heldol400 psi-w7 pumps off~5 ~ . min, CIP @ 02:55 hrs 8/14/81. Rev out 0 sxs cmt. POOH w/ DP. RIH w/ 7 5/8" retrievamatic pkr & stim i valve & set pkr @ 3941' DPM. RU & tested test mani- fold & surf lines to 5000 psi. Loaded DP w/ 1000 psi gas cushion. Opened stim valve & tested 5.1 sds. Had an initial rate of 5.6 MMCFD & a stabil- ized rate of 6.87 MMCFD @ 820 psi after 10 hrs. Shut in well.. Opened bypass & killed well. Circ clean. Released pkr & RIH to 4197' & circ clean. POOH - laid down test tools. RIH w/ 6 1/8" bit on 7 5/8" csg scrpr. · NOW' RIH w/ bit & csg scrpr. Continued to RIH w/ 6 1/8" bit & 7 5/8" csg scrpr. Tagged ret @ 4208'. Drld ret & 5' of soft cmt. Drld firm cmt f/ 4213' to 4259'. Trip for bit chg Drld firm cmt f/ 4259' to 4280'. Drld ret @ 4280' & CO to 4369'. Circ clean. Dumped surf mud system & mixed KCL water. Circ KCL fluid around system. POOH w/ DP. RU Dresser Atlas to reperf 5.1 sds. NOW: Prep to reperf 5.1 sds. RU Dresser Atlas to reperf 5.1 sds. RIH w/ 4" csg guns (6 runs) & reperfed f/ 4205' to 4183' 4175' to 4165' 4163' , to 4131' 4105' to 4075' 4073' to 4059' 4051' , to 4039' 4025' , to 3994', & 3991' to 3981 ' DIL'. RD Dresser Atlas. RIH w/ bit #1, RR#1 on 7 5/8" csg scrpr to 4369'. POOH. RIH-.w/ Baker model "D" pkr on WL & set pkr @ 4279' DIL. POOH w/ WL. NOW- Prep to RIH & test Model "D" pkr. RIH w/ DP w/ 2' of seals. Tagged pkr @ 4279' DPM. Tested pkr - ok. Pulled out ofl~kr & spotted, l0 gal of oxygen scavenger. POOH w/ DP. RIH w/ Baker 7 5/8" model "D" pkr on WL & set @ 4215' DIL. POOK w/ WL. RIH W/ 2' of Seals on DP & tagged pkr @ 4215' DPM. Stabbed into & tested pkr - ok. POOH & LD DP. RU & ran dual 2 7/8" tbg string.. NOW' Running completion tbg. RECEIVEI Ui'IIOlt OIL C(]'?AIh OF CALIFOP .iIA WELL RECORD S :EET D PAGE ih, LEASE A-028142 DATE 12 8/18/81 DAILY COST' ACC COST' AFE AMT'- ETD 4453' TD 3913' ETD (A-5 PKR) lO 3/4" C. 1195' 7 5/8" C. 4417' $ 106,893 $ 498,738 $ 700,000 ELL HO, KU #21-7 FIELD KENAI GAS FIELD DglAILS_.OF OPERATIOItS, DESCRIPTIQ[!S & .RESUL.TS , Completed ru'nning dual 2 7/8" tbg assy. Stabbed into & tested Model "D" pkrs - ok. Spaced out & landed tbg. Retested prod pk'rs -. ok. Set' "XN" plug. in SS & set Baker Model A-5 dual pkr. Tested pkr - ok. Pulled "XN" plug & rigged 'down test equip. Set BPV's & removed BOPE. Installed prod tree & tested to 3000 psi - ok. RU Otis & opened "XA" sleeve above dual pkr in SS. Displaced annulus w/ field gas. Released pressure & flowed annulus thru choke & poor boy degasser. Gas ignited in ~it room by degasser (probably shorted el,ectrica'l wires). Closed choke. Sent driller to doctor w/ minor facial burns. Closed "XA" sleeve in SS. Opened LS to clean up to atmosphere. Flowed LS into pro- duction system at a 9.'2 MMCFD rate. Closed in LS - static pressure of 1380 psi' Opened SS to clean up. Flowed SS into prod system at a 6.2 MMCFD rate. Released rig to move rate @ 24'00 hrs 8/18/81. · NOW' Tearing out rig. 13 8/19/81 4453' TD .3913' ETD (A-5 PKR) l0 3/4" C. 1195' 7 5/8" C. 4417' DAILY COST: $ 73,496 ACC COST: $ 572,234 AFE AMT' 14 8/20/81 DAILY COST- ACC COST- AFE AMT- 15 8/21/81 $ 700,000 4453' Tb 4369' ETD 'lO 3/4" C. 1195' 7 5/8" C. 4417' $ 10,903 $ 583,137 $' 700,000 4453' TD 4369' ETD l0 3/4" C. 1195' 7 5/8" C. 4417' DAILY COST' $ 8,500 ACC COST- $ 591,637 AFE AMT- $ 700,000 Flowed well ~vhile rigging' down'Rig ~31. Flowed SS for 4 hrs. Had a final rate of 7.8 flMCFD @ 830 psi. Had final shut-in pressure of ll20.psi. Flowed LS. 1 hr w/ a final rate of 9.2 MMCFD @ 900 psi. Had a final shut-in pressure of 1378 psi. Installed BPV's. Removed subbase & set equipment away from wel 1. NOW' Rigging down. Rigging down-- moving equipment away from well. Stacking rig on Pad #14-6. Completed stacking out rig on pad #14-6. Released rig @ 18-00 hrs 8/21/81. ~, STATE OF ALASKA ~-~,~ ALASKA (~- AND GAS CONSERVATION CO,..,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation~] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA §8-5 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 s0-133-1009200 4. Location of Well at surfac~62' N & 1024' E of SW corner, Section 6,'T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 85' A-028142 9. Unit or Lease Name KENA! UNIT i O, Well No, KU #21-7 11. Field and Pool KENAI GAS FIELD POOLS 5.1 & 5.2 For the Month of. AUGUST ,19 81 12. [Zepth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations 8/5/81, workover 8/7/81. Released rig 8/18/81. 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs [un and depth where run FDC-CNL-GR and GR-CCL 4369-2500' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed: 4310-4330' 4205-4183' 4073-4059' 4252-4262' 4175-4165' 4051-4039' .- 4223-4243' 4163-4131 ' 4025-3994' 6175-6177' 4105-4075' 3991-3981 ' -'-, z 8 198l A/aska Oil & Gas Cons. Anc.5omge 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-- e~t on this form is required for eaCh calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE Of ALASKA ALASKA (.,;, AND GAS CONSERVATION CO.,: VIISSION SUNDRY NOTICES AND REPORTSON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHERY~Z] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 68-5 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 133-1009200 4. Location of Well 362'N & 1024'E' of SW corner, Section 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) RKB 85' 6. Lease Designation and Serial No. A-028142 9, Unit or Lease Name KF_NAI UNIT 10. Well Number KU #21-7 11. Field and Pool KENAI GA5 FIELD POOLS 5,1 & 5.2 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations ~]] Stimulate [] Abandon [] Stimulation [] Repair Well [] Change Plans [] Repairs Made [] Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Altering Casing Abandonment Other 13. Describe Pr6posed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting.an;/ proposed work, for Abandonment see 20 AAC 25.105-170). · 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Moved Brinkerhdff_RIG #31 to location and rigged up 8/5/81. Killed well, installed BPV's, removed tree, installed & tested BOPE. Pulled and layed down existing 2 7/8" dual completion assembly. Ran FDC-CNL-GR w/ CCL-GR l°g f/ 4369' to 2500'. Cleaned out to 4369' w/ bit and scraper. Reperfed 5.2 sands from 4310 to 4330', 4252-4262' & 4223-4243'. Squeezed w/ 200 sxs cmt. Tested 5.2 sands & killed well. Reperfed 5.1 sands from 4205 to 4183, 4175 to 4165, 4163 to 4131, 4105 to 4075', 4073 to 4059', 4051 to 4039', 4025 to 3994' & 3991 to 3981'. Set packer at 4279' & completed dual 2 7/8" tubing assembly. Installed BPV's, removed BOPE, installed & tested dual 2 7/8" tree. Placed well on production. 14. I hereby ~er~ify that the foregoing is true and correct to the best of my knowledge. Signed Title DIST DRLG SUPT The sp~,~elow for Commission use Conditions of Approval, if any: ' I £C£1v£D S£p ... 4 1981 Alaska 011 & Gas Cons. ~.'?cha~ge C°rn~!;~iol~ Date 9/3/81 By Order of Approved by COMMISSIONER the Commission Date __ Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA "'-~, ALASKA C,.. AND GAS CONSERVATION CO,.,,dlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator UNION 0IL COHPANY OF cALIFORN[A 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 362'N & 1024'E from SW corner, Section 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) RKB 85' I 6 . Lease Designation and Serial No. A-028142 7. Permit No. 68-5 8. APl Number 50-- 9. Unit or Lease Name KENAI UNIT 10. Well Number KU 21-7 11. Field and Pool KENAI GAS FIELD POOLS 5.1 & 5.2 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate I~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [~ Other [~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF.' (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other E3 13. Describe Proposed or Completed Operations. (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abarldonment see 20 AAC 25.105-170). In order to pull tubing, clean out fill, isolate Pools 5.1 and 5.2 perfs, treat with OH-AL and recomplete well KU 21-7 it will be necessary to perform the following work: (See attached) Subsequent 'Wm'k ;-~.e2o:Lcd JUL 0 ? ]98] Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below f/6r Commission use Date 7/R/R1 Conditions or-Approval, if any: Approved by COMMISSIONER Approved :."op¥ Returned __ By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICE 2 KU 21-7 PROCEDURE' 1. Move Brinkerhoff Rig #31 to location and rig up. 2. Kill well, install BPV's, remove tree, install and test BOPE. 3. Pull and lay down existing 2 7/8" dual completion assembly. 4. Clean out to +4369' ETD wi th bit and scraper. 5. Run FDC-CNL-GR w/ CCL log. 6. Isolate above Pool 5.1, below 5.2 and for water as required. 7. Reperf and treat Pools 5.1 and 5.2 with OH-AL. 8. Recomplete as dual 2 7/8" producer with dual packer @ +_3900' and single packer @ +4200'. 9. Install BPV's, remove BOPE, install and test dual 2 7/8" tree. 10. Place well on production. REEEIVE ) JUL 0 ? Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA' AND GAS CONSERVATION COA/V~AII'TEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Muit/-POZNT ~'w.S ? Test. Inlllal D Annual D Special Field Kenai Gas Field Reservoir Pool 5.1 Ol)er;~tor Union Oil Company of Californ|a Lease A-028142 (*uunty K~na i tLo~ti,,n 53' S & 1601' E from NW Corner, Sec. 7, T4N, Rl lW, S.M. Completion D&~e Test Date 7-29-75 IA'ell No. KO 21-7S I I W~llhead Producing. }BO' I ThrUcso. [Temptr~uteRe~en°lr9s 'F Temp~r~u~F TBG. Size ~Vt/Ft. O.D. 2 7/8 2.875 cst. s,- I ~'t/Ft. ! a.D. ISet~ 7 518 26.4 6.969 4417' MD Liquid 6~Pi) · VD Pipeline Connection j Type Taps Nikiski Pipeline I Flange ~Iultlple Completion ii)ual or Triple) i Type production from each zone Dual [ Gas OBSERVED DATA Flow Data ,, Time (Prover) (Choke) Press. J Diff. Tubing [ Casing Flowin~ · ~o. of Flow (Line) (Orifice) { h Press, { Press. Temp. Hours Size Size psig w pslg { psig 'F i 1 1 { 3.826 3.826 3.826 2. 500 , 2. 500 2.500 2.500 3.02 5.76 .38 20.25 1389 1363 1343 '1310 I 1220 71° 70° 700 3.826 I 70° FLO'~V CALCL'LATIONS 1. Coeffi- cient (24 Hr.) 34. 147 I 64. 510 34. 147 I ..88.443 34. 147 I 111.483 34.. 147i I 158. 142 Pressure psla 1378 1358 1325 1235 Flow Temp. Factor F t 0..9896 o. 9o5 0.9905 0.9905 PRESSURE CALCULATIONS Gravity I Compress, Factor I Factor Rate of Flow F I F ~ Q ~ICFr D g pv ~ 1.3423 I '1.1032 ... I 3228 1.3423 I 1.1027 i 4427 1.3423 ! 1. 1006 ~ 5570 1.3423 I 1.0~42 ! 7856 Cal. w w (psla) I~ F.Q (F Q)2 (F Q): X 1-e-~ P: p~ -- p2 , p p t c c I c 'v C W w t 1' t c Potential j n ......... ] 6,700 .~,cr.,r,I · 50~50 CERTIFICATE: I. ih~ undersigned, state {company), and ~al I am auihoraed by ~aid compay io make ~is report; and ~ai ~is report was pre. pared ~der my supervision and direchon and that ~e facts stated t~re~ are true, correct ~d complete to · .. o, - a~.ture ~ary/E. Carlson (;AS~'"'~LL OPEN FLOW POTEhlTIAL TEST PRESSURE CALCULATIONS (Supplement to Alaska'O & GCC Form No. G-I) Field Reserve l.r Tesl Date Kenai Gas Field Pool 5.1 7-29-75 ~ 'Operator Lease ;';sit :~o. Union 0il Company of California A-028142 ,. KU 21],7S _ Test ( I ) (2) (3) (4) Ps pf (ps2_ pr2) 0 No. Dsia 1 1405 1378 7.~1 3228 , 2 1404 . 1358 12.71 4427 , 3 1404 1325 21.~6 ~70 4 1404 1235 44.60 7856 · _ Sub-Surface Test Data Subsurface pressuffes measured. [----] Subsurface pressures computed: Cullender-Smith ;.~ethod of IOCC. (I) (2) i'3) (4) Test Pws O ' (Pws2-pwf2)· Q No. osia psia X I0 _ 4 ',:~rt~,"~=/r~ _ · _ , ,, · , Nomenclature: Ps = Static surface pressure -i~f_~= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.65 psia 1-70 · Back Pressure Tests Well: K"'"t ! - 7S Pool: $., · Survey Date: 7-3-75 1.O · · :J_~-~:k.-Jtt'{ ,:~ t~. . : .~i'J ~: . :~t: ,.:~ ~t' t :t'. ...............i/~ t .... t'. ........J ,' ..... i ....... :~: :i': i ;::. ;; : ;i:' :' :; :';;~' '~' i' '~::':'' i : --,'; :.:~i..=';:,~;~,.~'.::r,.. i{~ : ~; "i:i~:~:~:'.','~ [ifi::~ :i: :~:: --I ~ * ~--!~ .... ~4*~t*' ~,*~ih~* ~ i ..... ~',' it I rt. 'it : '~ t'" ']i' ''~;l:'t:;~;:' '[' .- -;-' ~ i i I , ; ........ ~. .,', ,: s ,~ . · :,. 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' ~; ' ':: ':" ~: ~t-' ; ', ~, ....... :.:'.; ,L. ; '. ; . ;:4.'..: :...;., :..-I .... ~ ....... ~:-,'L ,-~5-~iZ~-.l~- ; .4~'; ....... ~ . .~ * ,:;- -:-; '~ -":'t ~.-~r,-..~ .... j~',; ~If't'' ':' ': t ' T- :-~ : : .............. :; :i;' ;-' ,l..iz..: h~-~-[-~; i ~:,. ,;::L-L-I .--:-~--~ ~ J-.*T!=?-t*; '~,; ..... : ........ :~: ~.. '!- '~ ........... ' . '-- ~'- -~ ' ~:~.t ' , ~ _~ / · , '' : , ,[ ,, , ~ ,~ . . . ' _._.; .;!-i;L :. .. ; ' ..:: ... :.. :~:.I; -; .... :: .... ;:-' ..... I':: ~ ' :' :i ; - : ;,.:::t :';,;: :: .................... - :~ :. , _ . ;:;.]' ~-:.: :~: ;: .... ' ..... :: -,:. ;;; ........ j -* '--', ...... ~ ........ : 'J:.I';::::.: ;::;::'I :;::: ::: . .. '.-: .... , ..................... ~ _IJ_:-[.4i:;:'..'nt::~:t't t;',:.:~;!:::','.:~.:' ;.-':;~?j '::1:~:' '~;: '::: ;ri: :'',~;tl ...... :;'' j;;':';;':~;":;:;'; ';;"'7,' : = .i ; J.~.i.L ..... ;..: : ,-'.*~;--: :~: '~;,' ", :i: ~J:~ ~;~. ~:;: :':1.': L::: ;.LL::::L~ .:_:2; ~ ,-:~ ;-~i::i;:;'.;~i;;.;:;:l: .:::.::::. ,~ ; ;:t.: .~;.;;,;.,:::. ;.. ~::: ;.;: :::;:'7: -: :7":: ;,,.:I ...... ................. =t::,. ::' :"-' :--:' :'::.', '.: :I.: ~:~?._:.~-~:L, :~:~-~:~:~ :i~ ~ ~ ~ -I ~ :~ ~'-': ;::~::~'. ~: I:::: ~ :~'-~' :.-~'-' '-'~ .... ~: :~:t ~::. ,.~-F~; -.:'~:~-:~ ~ ~-~ ~hl :: ~ ~i~'~l ~-~ .... ~, ".-.;::[ .... , ; " - ..... , , - ~ ........ ' ............. I' .,; .~ - ..................... ....... ~ .................. ,-- . , I ] ...... ~- z ..... ~ ,-~ ~ ,... ~ .................... t .... : ...... , -%~.t:~'':!~:[ ':~:~t~I;' ~ ~ :i't?U.;:'~ .;:;: : :;!:;::: ::!'::: i'::: ~I; ,::: :-:: -.:~.~qqq.~.~--~,-~-~,~-,...-:-:r ....... :: dT-:~ -, ...... r-' -;-=~- ;-r , , ' ~ .......... ~: _ .; ' ~.. ;_1~ ~-~4 ~ ............................ ' ~-~-.'I"~:~!T~':'= ~ T'/~;:,-l~t~:~. :~' U~, ,~,, ~ - t' :" , :~ .... ] i ..;~:.;~ ': ~ . ::.~:. ;':':: t' -: - ; j. : .:;! ]:: ..': ~:~: :;' , : f-;L'' ~:-~i ~ :; : : ~:.':-: ~!:,:,:: :~:.';~: ;;::.:::; :::J:: j~ : ":: L:' : :" ':' :.: :: :: ~::'::x: :"~:~:':~' ':'t ~' ,; , :' -" .... *'~L-;-''' '-~''' t; : :t::T~:;;i:;.~:'.'~ ~-i:' ~i;~:~:';~:; .~ '-~ .... J;:'' ' , ' ''~ ' ~' J ; 'l .... : :'; I :t':::N': :'t:l'~J~- :~F:: ...... ~ ......... ~ '~:~T-~.~:~i:k:3~7~:.: :!::[::~: , t::t';:i ;t ~ '.'.,~, :I:: ,:,:~:~:t :..' ~ .... I~ .... I : .... I ;-4 . : ' ; t~ '+'ttttt: "'t"::: i: .... ':. :.-: : ~L~ : : ~. ' .... i ........ ; ' :, : .L:: ;~ ;.; :L 1;~.: -4. :;;; ; .:.',.~ ; ; : ;.; .~;~ i;;..; · ,.. :~.:..,;~ :'i~ ~- .... ~ .... ~:~-* .*--~. ,~ ....... ,h' I tJ~ I .. ~, [ ....... . .......... ]...:l ............ I t, ,' *', ':'" ..... "'t'1' : ~'['"~ ..... :':: ['t ;;;; ~ ..: kI- ~ I ,. ~.L ~, ;:.. ..... ................................ ~ ............... *J · ti.' ', " ' ~ .... ':' --ki¢, ~ ,: ~il~' ~i~ ';'i;;:' ;':'~ : t- '; l:ll , .,.t .... I':~,~:, ~-~ ..... t- .i.r.~ ~4~4t.~ ~:-.;, t ..... ~',¢. iff ' -t, : · .:':-'r::~; ,' ',,,',,,J ,.' ...... , : , , '., , i' t , . ,. ,.,,... .~.I1. ,~ ...................... .% .10 .05 .J '-' '. 02 .O1 1..0 2 ' 5 10 20 50 GAS FLOW RATE }~IOF/D /--',. STATE OF ALASKA Olri. AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT ~JuIII-POI.~T t~. S'~ Test Initial r'l Annual O Special Field j Reservoir Kenai Gas Field Pool 5.2 Opcri~tor Union Oil Company of California jTest Date 7-29-75 JLease J ',Veil No. A-O28142 KU 21-7L ('oun,y jLo~a,i,,, 53' S & 1601' E from NW Corner, Jco=~i,Uo.D,,, Kenai Sec. 7, T4N, R11W, S.H. 6-16-65 4453 TMD 56 J' .4135'-4243' I csa. t,.,,~ 7 5/8 26.4 6.969 4417, MD (Separltof) ~engtb (L) ~alIo MfF p~r Bbl. Liquid ,Api) 7/8 2.875 2.h~1 h212 0.555 ~212 2338 0 0 . VD Pipeline Connection j Type Taps APL Pipeline J Flange :Multiple Completion (Dual or Triple) . j Type production front each zone Dual J Gas OBSERVED DATA Flow Data .~o. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w pslg J pslg * F s, I I I 14'11 ! ]. 1 t 3.826 .... 12.500 [ ... '"i "'3...24.. l.. 1370 j ......... ! '60.o... 3.826 3..826 3.826 4. _ _ cient P (24 Hr.) m 34.147 t 66. 988 34. 147 t 89.491 34..147 J 110.134 34. 147 J 138.900 2. 500 ,2.50o 2. 500 Pressure psla 1385 1362 1].]0 1252 5.88 9.12 I 15.41 FLO ~.V CALCULA. TIONS i347 i 1315 J ..j 1237 Flow Temp. ~l Gravity J Compress. FactorF. t J Factor Fg 1 Factor Fpv !.O000 I 1.3423 I 1.1147 1.0010 I 1.3423 j 1. 1141 1. 0029 i 1.~.42) I 1.1138 , , ].0039 J ].3423 j ]. 1084 59° 57° 56° Rate of Flow , Q MCF, D 3441 4599 _5665___ 7123 PRE$SL'RE CALCULATIONS w P~ F Q (F q): (F Q): X l-e'~ p: p~ _ pm , Cai, { w ? (psi.',) . :t c c c w C W P wJJ -P'c~ ' t 2. I ....... ,, ~ 3. ,,, Al)solute Potential II 17,700 .~cr,,p · 5786 CERTIFICATE: 1, the undersigned, state that % am th,, en.qJneer of the Union 0i I Company (cOmpany), and that ! am authorized by said company to make this report; and that this report was pre. pared under my supervision and direction and that the facts stated~heretu are true. correct and complete to the best of my knowledge.//~ ~ C~.' ,L/~7 · · . ~-~/~(.~,, ¢ s~aiu~ ~Gar~ E. C'ariSon GAS ~-'LL OPEN FLOW POTENTIAL TEST REF'""~T ~- :z~ - .- PRESSURE CALCULAT I G~'~S (Supplement to Alaska'O & Gcc Form No, G-I) Kenai Gas Field Pool 5.2 - - "Opera%ro'r ........ Lease ;'/el I 'Jo. Union Oil Company of California A-O2B142 KU 21-7L Test ( I ) (2) (3) (4) ps Pf (Ps2- pr2) Q No. osi. a _ hsie X 10_4 ~...!CF/D z, :, : : :: : ~:: : : -~-: ~ ~-- ..-- z : : ....... , ~ 1 1433 1385 13.53 3441 2 1426 1362 17.84 4599 3. 1425 1330 26.., !7. .... 5,665 4 14.24. _1.252 46.0_3 .... 7.!23 Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith ~dethod of IOCC. .......... (i) ' ' (2) ('3') .... (4) Test Pws 0 ' (Pws2-pw~2) Q No. osia psia X 10-4 !.~CF/~) L ~ . -~ , ..~ : - .._ ~ ........ , , . ......... I Nomenclature- Ps : Static surface pressure '-Pr__.: Flowing surface pressure Pws :'Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.65 psia 1-70 · Kenai Ga~.~Field Back Pr6 !ire Tests Well: KU 2!-7[ Pool: 5.2 Survey Date: 7-29-75 0 I 100 ' ~ '. 02 · O1 1.. 0 2 5 10 20 50 100 OAS FLOW RATE t~CF/D Union Oil Company of-~",.lifornia unlen December 17, 1968 Mr. Thomas R. Harshall, Jr. State Petroleum Supervisor Division of Hines and Minerals $001 Porcupine Drive Anchorage, Alaska Dear Hr. Marshall: Enclosed for your information is the 4-Point Test for Kenai Gas Field Well No. 21-7S and 21-7L. Should you have any further questions on either of these enclosur9s, please advise. ~R: C~ Hartmann District Production Superintendent RCH:mgl Enclosures FORM 401-BL (REV. 5/67) GAS ~'~,-LL OPEN FLOW POTENTIAL TEST RL. ORT 4-POIXT TEST Test Initial ~ Annual O Special Field Kenai Gas Field Test Date 7-5-68 IVCell Xo. 21-75 Reservoir M5.1 Operator I Lease Union Oil Co. o£ California A-028142 ('ounty [ Locati,,n Top Prod interval: 53, S ~ 1601 ,E .from [ CmploU0nDate Kenai ~r~ .... Sec, :~, T4N, Rll~, SM . 6-16-65 Pr°ducing Thru ['"~ese~°t~-[ Wellhead ] CSG' Size I ~Vt/Ft'{T~. J CSG. J Te~atu[~ ' Temperatum66oF 7-5/8 26.4 6.969I'D' Set~4417 MD ~' ~ize ~'' 'V't~Ft':I O'D' I La'- [ ~et ~ [ GasGravlty I Av"Pr°d' [ ~ Gas'Liquid Hydr°carb°n(~epa~ L~l~t~ ~, Ratio MCF ~er Bbl. ~-7/8 2.875 2.441 4212 23~8 - 44i~ T~I) 160 Producing 4118 VD Gravity of Liquid (APi) Pipeline Connection [ Type Taps 20" .Kenai.N:ikiski...p..ipe!ine . [ _ Flange ~lultiple Completion (Dual or Triple) J TyPe production front each zone Dual I Gas ,, _ OBSERVED DATA Flow Data Time (Prover) (Choke) . Press.. Diff. Tubing CasinK Flowing of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w psig ] psig °F ,, , 1622 .1 · 3.826 2,5 :- 1513 · 2.'i . . 153S 106° i 3.826 2. $ 1444 3.25 1482 100° 1?~' _ , ::3:-826 ~ .,.._-_,2,$ -_ 1384 4.00 - 1438- 75° I , [ 3.826 , 2.5 1351 4.4,5 1415' 8.1.° FLO%V CALCULATIONS Coeffi-. Flow Temp. Gravity Compress. NO. eient ~hw p Pressure Factor Factor Factor' Rate of Flow (24 Hr.) m psla F ' F F Q MCF/D t g pv - , ~. 34.146 89,93 11528' .9585 1.3423 1.0833. 4,280 2. 34,172 124.15 1459 .9636 ~1 '3423 ' ,1,'1 ° 0843 5~950 .~. 34,156 149.60 1399 .9859 1.3423 1.1017 7~450 4. 34,!$8 .. 164.42 1365 .9804 1.3423 i,,1.09~'2 8,090. PRESSURE CALCULATIONS w (psia) P" F Q (F Q)-* (F Q),_ X 1-e-s p.- pi _ p~ Cal. w p :t c c c ~v o w P w P t c ~. S~o A':tached Form ",' , , i,' ~.. , , 4. i , Absolute Potential n ,. :~ :$~..~,, · -:- :, ~CF/D 0.751 Cm~T~F~CAT~: ~. the undersigned, state that I am the Prod Engr ol the union 0il Co O~ Calif. (company), and that I am authorized by said company to make this report; and that this report was pre- theParedbestUnderof' mymYknowledge.SUpervisi°n and.. direction, and that the facts~~~stated F~~ true,/~.~.correct~, and complete to s~e J. E. Church DIVISION OP O~l AND .... Alaska Oil and Gas Conservation Commission Gas Well Open Plow Potential Test Report (4.Point Test) Form No. G-1 Authorized by Order No. I Effective October 1, 1958 G~S WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska O ~ GCC Form No. G-l) Field · Reservoir -Test Date Kenai Gas Field H S.1 7-5-68 Operator Union Oil.Co. of California Lease No. Well No. A-028142 21-75 Surface Test Data .. - ~ , , (~) · ,(2y,. '~(s-) .......... (~-) .... Test Ps Pf (Pws2-pwf2) Q No. ... . Psia ....... P, sia .... X lO-q MCF/D 1 1645 1575 ~. , 22.~4 . 4_66fl , .2,, , 1645 15'28 37.1~ 6,360 3 . 1645 14,70 54.51 J R.04o ,. 4 ]645 1408 ...... -. 72.35 9.430 . Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed- Cullender-$mith b~et~,,od of IOCC. - - - (1) (2) .... (s) ' (4) ....... (s) Test Pws Q Pt f pwf (pws 2 _ Pwf 2), No., .... Psia .... MCF/,D . ~ Psi. a . Psia .X.,.IO'4' ,,. 1 1809 4.660 1575 1759 ,..17.84 , ~ 2 1809 6. 360 1528 1734 26.57 -- 3 ..... 1809 ,.. _8~040 1470' , 17,08 ' $S.52 4 1'809 9.4_%0 ' 1 aflg 1680 45. O1 S Nomenclature' _., Ps = Static Flow String pressure Pf = Flowing Flow String Pressure Pws = St~..,b0~?~m-hole pressure (mid-point of perforations) l>wf Fl~'~h~a~tom-hole pressure (mid-point of perforations) Q = F~ow~.,rate~M~F per day at 60° F and 14.'65 psia OIL · KENAI DELIVERABILI'FY GAS FIELD AT THE SANr~F~Cg WELL NO, :,2/' ~ODUL~ · ~ / Q,', ;nscF/D = INTERPRET&TI ~EC ( Pws~ . pwf~ ) BY ~CAL. E 50 60.70 80.9o,lo,o 2oo GAS ~LL OPEN FLOW POTENTIAL TEST RI::rORT 4-POINT TEST Test ~nitial ~] Annnal ['--] Special Field Kenai Gas Field Reservoir ] Test Date M 5.2 7-12-68 Yv'ell Xo. 21-7L Operator { Lease Union 0il Co. of California , A-028142 County [Location S3'S ~ 1601'E from 1~ cor. Section 7, Kenai , T4N_ RI1W_ SM Pr~ni Thru ] Reserv°i[ I Wellhead I CSG' SizeI. CS(}.Temper~u_resF. ' Tem~pe. rature6(~ °F 7-5/8 26.'Vt/Ft'4 I' 6. 969I'D' ] C0mpleti0nDate [ T0talDepth ] T/PaY I ?r°ducing 4309 TVD ~,y§_ 6-16-65 4453 TH.D 56 ]set~ 424~ VD 4417 MD 2-7/8 2.875 .441' 4212 ~7~r~ ~e~f~L) 2538 Rail0 MCF per Bbl, Liquid (Apl) Pipeline Connection ' APL Gas SaleS.,,. Multiple Completion (Dual or Triple) Dmtl Type Taps Flange Type production from each zone Gas OBserVED DAT~ Flow Data Time (Prover) (Choke) ~ .~ ': Press. · Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w psig psig 'F s~ ' 1622 ~. 1 3,826 2:: 5~ ' 1513 2.5. 1538'~ - 106,° . ~. ' 1 3,826 2.5:' 1444 .... 3.2.~ 1482 - 100° ,. I -::' ........ , ..... 3~826' : ~-':" '2,5 ". 1384 4.00 1438 - 75° ~. . i .. I. 3.826 2.5 1351 4.45 1413 '' .- ,. 81° FLOXVCALCULATIONS ' ' ...... ~ -" Flow Temp. Gravity Compress. ~o. Coefficient- ~ / h p Pressure F~tor FactorF FactorF ~ateQ MCF/D°f Flow . (24 Hr.) V w m psla t g pv ~. "~4~146 89.93 1528 .9585 1,3425 .... 1.0833 4.280 ~. - 54,172 124.15 . 1459 .9656 1.3423 1.08~3 5.950 ~. ' .54,156 149660 ' 1599 .985~ 1.5423 1.1017 7,450 ~. 34,138 164.42 1565 .9804 1.3423 "1.0952 8,090 PRESSURE CALCUL.&TIONS w P-~ F Q (F Q)-' (F Q)~ X 1-e-s p.o p~ -- p~ Cal, w (psia) ..t c c w o . w P P c 'w p t c ~. See Attached Form ,, , 2. .~. - 4. Absolute Potential { n · - 55 ~ 000 ~ ~rCF/~] O. 987 CERTIFICATE: I, the undersigned, state that I am tho 'Prod Engr of the UniOn 0il Co_ ot~ Calif. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated/therein are true, correct and complete to the best of my knowledge. " ' signature~/j .c~ .'-~Chu~,Ch ~ ~ a~ Alaska Off and Gas Conservation Commission ~ ~,~ I ii ~q;'" Q Gas Welt Open Flow Potent/al Test Report (4.Point Test) D{V/SION OF O;i, AND GAS Form No. G-1 Authorized by Order No. 1 Effective October 1, 1958 WELL OPEN FLOW POTENTIAL TEST REPORT -.- .-:- PRESSURE CALCULATIONS (Supplement to Alaska O ~'GCC Form No. G-l) _ -Fi'eld Operator . · Kenai Gas Field Union Oil Co.'of California Reservoir Test Date M S.2 7-12-68 Lease. No. Well No. A-028142 21-7L Surface Test Data , . ....... '(2) " - - (4) · Test Ps Pf (Pws 2-pwf2) Q No. Psia Psia X 10-4 MCF/D 1' 1637 1553 __.,, ~ ".2.6.80 4,28q .2 1637 1497 43.88 5,950 'S'" ' 1637 1453 56.8~ 7,450 4 ' 1637' ,. 1428 64.06 8,090 5 · S~b-Surface Test Data [~ Subsur_~ace pressures measured. .-- [~ Subsurface pressures computed- Cullender-Smith t:tethod of IOCC. ........... ('1) ' ('fi)' (3) (4)' ' ' (S) _ Test Pws Q Pti pwf (pws2-Pwf2) No. .. Psia' MCE/D... psia p.si.a x 10.-4.., I ' .1809. 4,280 -1553 . 1739 24.84 _ 2 1809 5~'950 1497 1705 36~55 3 1809 7.450_ 1453 1689 41.98 4 1'RO9 -8~090 1428 1679 45.35 5 .. · Nomenc I ature · Ps = static Flow String Pressure Pf =.Flowing Flow String Pressure Pws = Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point Of perforations) Q = Flow rate, MCF per day at 60° F and 14.65 psia DIVISION OF O;L AND G:A3 FI~GURE No. OF CAL. i DELIVERABILITY AT THE .~',~',X./D,'~,"~C',~'' , WELL NO.· ~/- ~ .MODULE' ~ Q, =soF/D = (P~= -Pwf~) DRAI~ ~ aEC' UNION' OIL COMPANY OF CALIFORNIA -' '- .-I FORM 369 10-59 150M ' ............. · ' .... '~ ! -,~-o,....... : cument ansm al No.' . : Anchoracj. e ~ g~ka 9- 2 016 5 TO State Div, of M&M Anchoraqe FROM R.C. Hartmann AT Anchorage TRANSMITTING THE FOLLOWING: 1 Rpt .&. Plan - Subsurface Survez ... KU 21-'7 · . T RE: IV 'O SE ~ 2,1 196f I~, , [x~ulive SecretOrY Alaska Oil ~ .Gas Conse~mion ,, Form S1 -: OF ALASKA SUmfZT (Other Inlt~Uctlon~ on OIL AND GAS ~ONSERVATION COMMISSION ~er.e ~lde) ! SUNDRY NOTICES AND REPORTS ON WELLS (Do uot use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT~" for such proim~lL) ozs. ['-] OAS [~ WELL WEtL OTHER NAME OF OPERATOR Union Oil Go. of California 8. ADDRESS OF OPERATOR 2805 Denali Sto,.Anchorage, Alaska 99503 4. LOCATION Or WELl, (Report location clearly and In accordance with any State requfrementL* See also space 17 below.) At surfpce 362'N and 1024'E from the SW corner Sec. 6, T4N, RllW, SM r 14. PERMIT NO. ,§5-8 16. TEST WATER EHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL Effective: July 1, 1964 '§. LEASE DESIONATiON AND IBRIAI, NO. A-028142 ~ ?, UNIT AOREEMENT NAME Kenai Unit . . . 9. WELL NO. . ' .... KU 21-:7 15. EL~V&TIONa (Show whether Dr,-eT, 0~, et~) RKB 85'. (zero) Che~k Ap~opriate Box TO Indicate .Nature si Notice, Repmt, or Other Data . ,., NOTICB OF INTENTION TO ** PULI, OR 'ALTER CASI.q~G MULTIPI,B. COMPLETE ABANDON® c. CHANGE PI,AN! 10, FIEI,D AND.POOl,; OR WII,DCAT Kenai Gas Field - ll, fJEC., T., R., M,, On BI,E, AND ' RUBVB! Ou~ LBBA . :,, Seco 6, T4N.:,Ri. iW, SM Kenai Penn,.' . ,Alaska_ (Other) WATER 8HUT*OFF : REPAIRING'. WELL FRACTURE TREATMENT ALTERINO CASINO SHOOTINO On ACIDIZINO ABANDONMENT* (Other) NOT E: Report results of multiple completion on Well REpletion or Recompletion Report and Log'form;) DESCRIBE I, aOPOSED OR COMPLETED OPERATIONS (Clearly state nil pertinent details, and give. pertinent dates, including e~timated date of starting any proposed work. If well fa dlreetionall~ drilled, give subsurface loe~tlons and measures and true vertical depths fog all markers and sones perti- · nent to this work.) * ~'". - ' ' Two water shut-off tests were run to verify the results of the Oemen"[ Bond Log~ angled hole. The 7-.5/8" casing was cemented on 6-11-65, with 55'0[Sacksf'of struction cement. The' Cement Bond I~bg was run on 6,13 65 ~nd thai: ,W. so - . . tests.'" were?._ run on 6-14-65 The results 'of the two tests are attached. .~ [~ .;~ ,~ Drilling Engineer CONDITIOn8 OF ~PPRO?~L, 1~ ~ 1 *See Instructions on Reverse Side _ . . · Form P--~7 · ~ SUBMIT IN DU~' XTE* '<' *'STALE OF AL~KA ~See other ~ structions on reverse side) OIL AND GAS COlqSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLE~ON: , ~ WELL OVER EN BACK RESVR. ~ Other Un,on O~Z Co. o~ California 8. ~no~sss 0~ o~o~ ....... DIVISION OF ~4~h~S & M;NERAL5 2805 DenaH St. ~ ~choraqe, ~aska 99503 ANCHO~A~[ 4. LocA~zoa o~ w[~ (Report location olearl~ a~d i~ aooorda~ee with a~y grate requirements)* ~t,.~e 362'N ~nd 1024'E from the SW corner Sec. 6,T4N,RZZW~ Ia. ~YPE OF.WELL: Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL' NO. A. 028142 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME . Kenai unit FARM OR. LEASE NAME ~. WELL NO, ,? KU 21-7 ;' 10. FIELD AND ~OOL, ~ WmDCAT Kenai Gas Field ' SEC., T., R., M,, OR BLOCK:AND SURVEY OR. AREA *~T4N,Pr°d'RllWinterval reportedSM below 53'S and 1601'E from the NW cor. Sec 7f.~ Sec. 6, T4N, RllW, SM ~, total depm 10'1'S and 1672'E from the NW cor Sec.7.T4N.RllW;S ~ ] 14. PERMIT NO. I~ATE ISS0ED [l'2J BOROUGH 65-8 ~ 4-26-65 I. Kenai I.' -~aSka 5-27-65 ~ 6-11-65 I 6-16-65~ ~~ R~ 85.3 (zero) ''l .75. . 20. ~L ~, ~ ~ m ~ 21. PLUe, S~ ~.~., ~n ~ ~ [ 2~( ~F ~L¢~ COM~L., [ 23. ~N~SSV*LS RO¢~R¢ ~OOLS C*SLe COOLS : I ~ H~W MANY I I DRILLED BY 4453 4366 T~) I 4369 I ~ 2 ~ I - ( ~ D * ~ '~ '- '25 WAS DIRECTIONAL 24. PRODUCIN~ INTERVAL(S), OF THIS COMPLETION TOP, BOTTOM, N~ME (MD A~ TV ) ' SURVEY M~D~ Moa l S. 974-4 04 (ae9S-4 2 ) '. Module 5.2 4217-4376 (4133-4290, TVD) Yes. · 26. ~P~ ELECTRIC AND OTHER LOGS RUN [ 27. W~S W~LL 'COS~ I No IES, Sonic, Microlog, Gamma Ray, Cement Bond 28. CASING RECORD (Report a~lstrings set in well) CASINO SIZE WEIGHT, LB./FT. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD 2.0" 78.6 48 20" None ~ '2"' 10-3//4'' 32.75 1195 17- / ~. 820 sacks -7-5//8'' 26.40 4417 9-7f8" 550 sacks AMOUNT PULLED~ None : 29, LINER RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENTS 31. PERFORATION RECORD (I~terval, size and number) 3978-3989 4128-4160 399-1-4022 4162-4172 4~72-4]_02 424R-4260 33.* 4307-4329) t30. size /s 2-?/8 TUBING RECORD (MD) 82.' DEPTH SET (MD) PACKER .SET .:(MO) 4212 4204~ 3921 391,3 ACID, SHOT. FRACTURE, CEMENT SQDE~ZE, ETC." DEPTH -INTERVAL (MD) AMOUNT AND KIND Or MATERIAL.~SED " ' et h%l- e 2/f8oot'] · PRODUCTION DATE.-FIRST PRODUCTION , PRODUCTION METHOD (.Flowing, gas lift, pumping--size and type o! pump) WELLshut.tn)ShutSTATUSin(Productng or GAS ' -MCF. WATER--BBL. 0IL GRAVITY-API (CORR.) FLOW' TUBIN0 P--S' CASING PRESSURE ] CALCULATED I O~L--BBL'24-HOUR, ~ RATE -- [ [ 34, DISPOSITION OF GAS (~0~d~ USed ~Or fUe~ ~en~ed~.etc.) . TEST WITNESSED BY 35. LIST OF ATTACHMEN~/~ · ~ify,~/~;~e ~oin 36. I hereby cert fgr g at~ attached information is complete and correct as determined from all available records [.flhng DATE , , . sm~ ~ ~ D En gin eer 7- 2 7- 65 . *(See Instructions and Spaces [or Addiiional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lan~lS End. leases to either a Federal agency or a State agency, or bol~h, pursuant to applicable Federal and/or State laws and regulations. Any necessary special instructions concerning the use 'of this form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are 'shown below or will be.issued by, or may be obtained from, the local Federal and/or- State office. See instructions on items 22 and 24, and 33,:below regarding separate reports for separat~ completions. If not.filed prior to the time this summary record is submitted, '.c~pie~ of all currently available-logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion and pressure tests, and directio.n__al surveys, should be attached hereto, to th~ extent required by applicable Federal and/or State laws and regulations. All attachments should be listed on this form, see item 35. i- · - Item 4: If there are no applicabl~ State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific instructions. - I~em ! Il:. Indicate which elevation is. used as reference (where not otherwise shown) for depth measurements given in other spa~es on this' form and in any i~ttachmenl~. I~ems 22 and 24: If this well is completed for separate production f~om more than one interval zone (multiple.completion), so state in item's22, az/ff, in item 24-show the producing interval, or intervals, top(s), bottom(s) and name(s) (if. any) f0r~ only the interval reported in item 33. ~ubmit a separate re~ort (page) on~t~i~_ form, adequately identified, for each additional interval to be Separately produced, sh0win~ the additional data pertinent to such interval... . ' ' ' I~em 29: "E~acks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. I~em 33: Submi~ a separate completion report on this form for each interval to be separately produced. (See inst~'~ction for items 22 and 24 above.) - .. . · . ~ . 37. SUMMARY OF POROUS ZONES: . '.' . ' ~ . .. SHOW ALL IMPORTANT ZONES OF POROSITY AND CONTENTS THEREO~; CORED INTERVALS; AND ALL DRILL-STE~ TESTS, INCLUDING :38. ' ~ GEOLOGIC MARKERS ~ DEPTH INTERVAL TESTED~ CUSHION USED, TIME TOOL OPEN, FLOWING AND SHUT-IN PRESSURES~ AND RECOVERIES . 'FORMATION TOP BOTTO~------~-.-----.~..~RT~T~,~,----.,~O~, ETC. TOP · - . ' ' NAME 2enai"Gas... Zone 3600 4376 .Interbedded safid, shale and.coa1. . . , , . ....... ~ - f . ., . - . . - ', . ~ ,f,. '.' :.- . ~, ,. ~- . : . . . . . . . ~ . -.. . . . . . .. . .. . . · .. : · , : ' :' .. : . . . · ... .. [ . - . ~ . . ...... ~ . . .~ ~ .'. ~~" ~- . : . .- : ~-. .::. · . ~/ . ;~ .. · . ~- ,. .. ... ~ : : ? ~ : . .. , ~ ~ :' : ~ ~ .... . . -~ ~ · t .~ :~ . :.~ . . ... ' ' ~l · '[ ' ..... - : ' ' ' · ,, : : , . ;. ~ . ..- .. . . ~ ...... ._ · . .. , ~ . - . . ' .... , ~ .- ~ : . . ; . - . . . :.. .... . ,. . ~ . .. . - ..~ - ~ , . ... .. . . . . DM-12 :.~lease Date 7/16/67 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD Top Bo t tom Sec._.6_ , 7 T. 4N 4N R. 11W 11W S_ Met idian Permit No. 65-8 Issued 4/26/65 Operator b~ion Oil Co. of Calif. Location (Surface)_ 362' FSL & 1024' FWL, Sec. 6 Lease No, A-028142 or Owner 21-7 Well No. SPud Date~_~=5/27/65 Loc. (Bottom) 145' FNL & 1721' FWL, Sec. 7 Area Kenai 4366 ' -V Drilling ceased Total Depth 4453'-M Suspended Completed (F-GL-P) Abandoned 6/16/65 IP B/D, Gray Elevation 74.12 Grd, 85' K.B. API Cut % Gas Casing Size Depth 20" 48 ' 10 3/4" 1195 ' ,_,, ,~ , ~.j,~_ 7 5/8" 4417' Bean__ -~--/64 CP psi, Sx Cmt Perf-~4208-09 WSO 5@3970' '71' None 4/ft-3/8" - WS0 3978 '-89 ' 3991 ' -4022 ' 820 4036 ' -48 ' 550 4128'60'; 4162'-72' 4180;-~ZOZ :'; ~2I~ :-4i: ...... 4248'-60~t; 4307'-29' GEOLOGIC FORMATIONS Surface Lowest Tested. : ,_.,-. .~ TP ....... ._ psi Plugs ~ 4369 ' PRODUCT I~E HORIZONS Name Depth Contents L. 4204"L432g; ' S. 3913' -4202 ' WELL STATUS Year Jan Feb Mar..Apr May June July Aug Sept Oct Nov Dec Junk.: S.T. 10 3/4" csg. 347'-1206' St. hole fr. 200' to 1206' Remarks CONTRACTOR: ,~ Santa Fe Drilling ..Company OPERATOR FIELD WELL · SURFACE LOCATION BOTTOM HOLE' LOC. ELEVAT IONS CONTRACTOR EQUIPMENT COMMEN~ED DRILLING COMPLETED DRILLING STATUS RCH:nnb 7/27/65 UNION OIL CO. OF CALIFORNIA OPERATOR Compl etlon Report Union Oil Company of California Kenai Gas Field ANCHORAGE Kenai Unit 21- 7 362'N and 1024'Efromthe SWcorner Sec. 6, T4N, RllW,SM 101'S and 1672'E from the NW corner Sec.. 7,T4N, RllW, SM NOTE: This is a directed hole. Ground 74' RKB 85' (zero) Santa Fe Drilling Company All equipment trailer mounted Mast: 94', 210,000~ Hopper Drawworks: Hopper Model GXXTA double drum powered by: 1 GMC 6-110 diesel engine Pumps: 1 National C-250 (7-1/4" x 15") powered by twin GMC 6-71 diesel engines. 1 Halliburton AC (4-1/2" x 10") mud mixing pump powered by 1 GMC 3-71 diesel engine. Drill Pipe: 4", 11.05 with 4" full hole tool joints Drill Collars: 6 - 6" x 30' with 5-1/2" reg. tool joints 10 - 7" x 3~]' with 4-1/2" IF tool joints 5-27-65 6-11-65 S hut in ga s jwell ~ R. C. Hartmann DrLlling Engineer hame Well No. Test No. Lems~ C~,ne~/~Pmny Nome uri-on COA4PANY Your...... Formation Testing Service Report Ticket Fbw ~ - 28 Do, 6-13-65 N.,be, 382501 Ckeed I, be AUB. Zmd MtB. Kind Halliburton Pm~ The ~ ~ o~ Jo$ . WSO - HOOK WALL Dbtriet ANCHORAGE aoodhm, ~ ?e'eef~'~ ONSTOTT , W~ne,, HORTMAN ~ NO Ve~ GaBje ~42~ ~. off Con~eeh= SANTA FE DRILLING COMPANY P.P-m 14o. 985 12 a~, · Ekveflon - Packer 3952 ~ A4wd P, mmuro 2281 2244 .Dopfl, 4419 ~ Packer I' I-itbl Cloeed ~ Intervel Fornmflon ..i, P,,= ~ ~ Temd 2969 ~ ~ 3970 ~ Toad I,itial I Cedng or Ca,ing ~?op ~9'69 I FlowPre~ --~ Z 3~ HokSlze 7 5/8~ CASING Perf,. ~Bot. ~70~ iii Fbw Pr~. 2 ~ 2O Choke ADJUSTABLE Choke %/8~ ~ I.D.. -ENGVH in I~e~' ~ ~ Drill ~pe 2 7/8 ~' BUTTRESS ~ 'Fbel Hydro Mud Mud A4.dPmuuro 2236 2195 . . Welgl~ 83 V~y · F ~. A.~hor Si=o ,~ 2 1/8~_ Depth Blanked l'mmperature ' Gm. ~uge ". off 100 .F ~d~, ~ ~"gm OD 2 7/ZP~ rr~ ~ Hour Depths Depth oF P.I~D. No. a~k ~ea. FNm KELLY BUSHING. Tear Valve 3937~ ~ Auou,~ DCIP Initial Hydro Del~h Back A4,d P~ Cu,hion NONE F,. pm. Valve ~9~.~2 ~ Iniflel C:loeed iB Pres. -Recovered 806' F~ of very g~ssy mud Initial 1 Fk,, Pm. 2. Reoove~ 603~ Fmc of very gsssy drilling Flow Pres. 2 . Recovered Feet of Final-Closed in-Paros.. Recovered Feet of Final Hydro Oil Water Mud. Pre.. A.P.I. Gravity Spec. Gravity Depth off Gravit~ Pretsure B~.~u~ 3965~ ,. YES Bienked Gill Surface BT. Hour Tool AJ~ Tool P.I~D. Ho. 982 12 'Ck=k Ope.ed ~oo22 AM Pe~L CloNd ~%0 ~M Initial HydN J~udPm. ~.260 2268 Ranark, Tool opened t~ m liKht blow of ~i~o Initial C:loeed inPNL = ~ tO the surfsce in. l%.minute~. Shut ~n @ 9~50 ~M Initial ! Flow pre'. h3 a ~6 With 725 PSI surface ~res~ureo No final o!o~ed , Final I l:lowP,w. 109~ 2 1082 pressure was taken. ,, · Final Hydro ~ ~ ~ Mud PN,. ~'2~9 2204 i i ii . I i. i FORMATION TEST DATA Lease Nome Well No. Test No. Lease Owner/Company Nome Owner's District liburt-ou COMPANY Your...... Formation Testing Service Report Ticket Clomd in '1~, MM. 2M Mb. Kind Halliburton PHs.. 'rmre = ~, .of job WSO DMrict J, NGHOP~.~J Pr, mre Field Office R~ Co~ Tester ONSTOTT , Witnm .~N~R~N Blanked D~lling De~b 4160~ NO SANTA FE DRZLLING COMPANY BM , ii r BT. Hour 'Top P.P.D. No. 98~ 12 ~ .r:levaflo~ - ' Packer hl?O Inil~l HYdro Total Bottom Md Pm,,,re 2369 2381 Depth hhl9 f' Packer ........ Initial Closed Interval Formflon bPH~ ~ ~ Tested 4208: ~ 09' Temd ,.~, , Ca,lug or Co,i., ~Top ~o~' m. Pm. .., 33 2' 2~ Hob S~n 7 5/8' CASING Perf'.. PBot. 4209~ ...... Fhal i Surface Bottom Flow Pres. 4~ 2 38 Choko ~STAB~ Choke .~/~ ~ , Fi~l Closed Size G' Kind ,.,~ill Collars b Pres-~ . =' .~ Drill Pipe 2 ?/8~ BUTTi~S$ &~,e Te,te, Final Hydro ~ _ ~ Mud Mud M~ ~,mro 23h8 23q6 . Weight 8 3 Viscosity -F t,,. Anchor Si=e Depfb Blanked Temperature Con. Gauge ,. off 1(~ .F ~ef ~ Leng~ 'OD 2 7/8 ~ X , P.P~D. 14o. aock Mca. From K~LLY BUSHING Tester Valve 15L~5 U Ft. ' ' ' TYPE AMOt~NT Initial H~dro Depth Back Mod Prec. Cushion NONE Ft. Pres. Valve ., Initial Closed ,..,., 1 Flow Pres. 2 , Recovered Feet .of Flow Pres. 2 Recovered Feet of Final'Closed in'preL , Recoveml. Feet of Final Hydro [ Oil Water Mud Pm. , A.P.I. Gravity Spec. Gravity, Depth ~. Blanked Gas Snrface Bot. Gauge ~79~ Ft. off Grevil), PreSSure psi BT. Hour Tool ~L Tool A.M. P.R.D. No. ~82' l~, Clock Opened ~t~ ~ P.J~ Closed ~t~ ~/~ ~ P.M. Initial Hydro Mud Pres. ~,391 2389 Remarks TOol opened with a weak blow of Initial Closed i. Pre.. - ~ minutes - then dead for the balanc~ .... InMnl I FiowPrec. 32 ' 2 ~ test. No final closed in preamble Final I , , ,,, , , , , Fi.', cb.d in Pres. =- . Final Hydro ~ud Pm.' 2.~80 .~351 FORMATION TEST DATA i t U.I t~ U.I C~ ~., orlzon TIME p.s.i. REPORT and PLAN RECEIVED SEP 2 1 1965 DIVISION OF MINES & MINERA~ ANCHORAGE of SUB-SURFACE SURVEY UNION OIL COMPANY KENAI UNIT N°- 21-7 KENAI, ALASKA JOB NO. DATE ..... ~UNE 1965 DRILLING CONTROL CORPORATION 3327 LIMI~ AVENUE LONG BEACH 7, CALIFORNIA {DRILCON} DRILLING CONTROL CORP. SURVEY DATA SHEET COMP^aY .............. !l!rt.~ ..0tl f,,ompaal, ................. . .................................... D^T~ WELL .......... I~_ 2~7 ......: FIELD ..... ~ COUNTY__. SHEET NO ...... ] ~[1]1~O ..][~ ....... JOB NO... ,STATE ..... _.~t~S.k.~ ..................... TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATIO1X DRIFT VERTICAL REMARKS DEPTH ANGLE COURSE DIRECTION DEPTH NORTH SOUTH IEAST WEST 200 Oo 00' 200 315 0O ~' 315 ~ 13 S 16° E 18. '.:':i:~ 29 · , 345 0° t~' 345 O0 13 N 22° # 06 ~34 374 0O 15' 374 ,tX) 13 $ 52o ti 14 44 474 0O GO" 474 'GO ViiIITICAL 14 44 535 0O 15' 535 O0 27 S 04° E 41 ': 42 594 lo 3o" 593 98 654 It° L5t; 653 88 3 ,JO S 20O E 5 07 27 740 5° 30'. 737 48 6 24 S 50O E 10 36 6 ,58 O01 6° 15* 801 12 6 64 S 55° 860 6° 450 858 71 6 93 S 55° i 11314 17 168 950 7° 30' 947 94 1175 S 65° a 23 11 28 33 900 7° 45' 977 67 4 05 S 65o E 24 83 32 Ol 1039 9° 00' 1035 94 923 S 60° E 29"~3 40 O0 1098 10° 15' 1094 O0 1050 S 56° E 35 30 48 70 1159 11° 15' 1153 83 1190 S 57° ii: 41 78 58 68 1217 12o 15' 1210 51 12 31 S 54° E 49 '01 68 64 1306 12o 45' ' 1297 32 19 64 S 520 Ii: 61 10 84 11 '1424 12o 30' 1412 52 25 54 S 54° ~ 12o 15' 1527 83 25 04 S 56° a 90 11 12554 1692 12o 30' 1674 27 32 46 S 54° Ii: 10919 15180 1999 12o 15' 1964 ['DRILCON) DRILLING CONTROL CORP. SUKVEY DATA SHEET COl~d PAN¥ .................. ~on 0il ~ O^TE ..................... Jmm. 1~ SHEET N O.__~ JOB NO ............................... WELL !~_ _21.-7 ............. Fl ELD _.l~aa~ ........ cOUNTY .......................................... s T A T E_]: _..A:]~S. _..~_ ..... ' ................ MEASURED DEPTH 2146 2473 2708 273~ 2~58 2977 3096 3~14 DRIFT ANGLE ],20 .12o ~.' 12° 12o 13° 14o 14° 14° 13o 12o 12o lOo TP,.UE VERTICAL DEPTH 2117 24~ 2695 2811 3155 4~17 4164 4309 DEVIATION COURSE 788'1' DRIFT DIB. ECTION SSOOE S 5,?,o E S52oE S 46oE S 51° E S570E S 56oE S 57oE S 56oE S56oE S 56oE S57oE $54oE S57oE S56oE S 560E S 56OE S 54° 25' E NORTH RECTANGULAR COORDINATES SOUTH 167 ~ 191 27 210 61 232 57 244 97 249 265 282 299 412 EAST 21t0 · '518 546 572 596 62,1 641 WEST REMARKS COMPANY ..... DRILLING CONTROL CORP. SURVEY DATA SHEET SI~I[ HOLE Unten_Otl_Ceaqmn.V OAT~ ....... J_uae 196.5_ WELL~_-~7 .......................... F I E L D ___~.~___~_ .............................. COUNTY SHEET NO.. ]-,~ JOB NO STATE MEASURED DEPTH 200 264 ~3 412 501 651 7~ 938 I~7 1115 DRIFT ANGLE 6° 15' 7° 15' 8° 45' 9° 45' l0c' 45' 12o 00' 12o 1.5' 12o 45' 13° 00' 13° 00' 12o 45' 12o 30' TRUE VERTICAL DEPTH 2OO 586 644 731 812 924 1011 1097 1186 DEVIATION[ DRIFT COURSE[ DIRECTION S 54° Ii: S56oE S570E S55oE S 61°E S 61°E S61°E S 61°E S62oE S 58° E S62oE S60°E S 59° 38' E NORTH RECTANGULAR COORDINATES SOUTH 4 L0 8 !6 1.5 ~3 EAST 5 11 23 35 50 61 77 93 116 133 167 WEST L5 ~) 18 ,16 44 59 65 REMARKS .. SCHLUMBER6ER COMPANY- UN ~ON 0 ~L WELL_ COMPANY OF CALIFORNIA KENAI UNIT. 21-7 FIELD- KEN_~J_A I COUNTY KENAI BURROUGH STATE-AL :iON DIVISION OF MI :-: ': :: -- ANCHORAGE ' ASKA -- Sec. ? . .Twp. 4 N .~Rge.__l 1W _ 74 rL , Elev._- Datum:. ~ 11 Ft. AbovePerm. Datum )ermanent Measured From ~., . ._., ... Log Measured From K~3 - Drilling Other Services: Elev.: K.B. 85 _ D.F. G.L.-'~ ,rillel 72 4~ 0 0 0 /, Form P--3 ST! OF ALASKA SUBMIT IN TR ~ATE* (Other instructio., on re- OIL AND GAS CONSERVATION 'COMMISSION verse side) .. SUNDRY NOTICES AND REPORTS ON WELLS (:Do not use this form for proposals to drill or to deepen or plug back to · ~l~e~e~t ~eee~vo~n OIL ~ OTHER ~ w~L ~ oas NA~E OF OPERATOR ~ , ~ ~.. i,,~L~3 UDi°n Oil Co. of CalifOrnia 8. ADDRESS OF OFEaATOa l.~tVi:~)i~l ,j~ ~,/~ii',i23 a 2805 Denali St,., Anchoraqe, Alaska 9950~aca°~Aga t. 5oct~zo~ o~ w~5 (Report location clearly and in accordance with an~ ~te requirement].* S~ also space 1~ below.) ' At surfece 362' N and 1024' E from the SW corner Sec. 6, T4N, R11W, .SM 14. 'PERMIT NO. J 15. Et~VATZ0NS (Show whether DF, -BT, OB, 65-8 J RKB 85' (zero) Effective: July 1, 1964 §. LEASE DEBIGNATION AND ]ERIAL NO. A-028142 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT:AOREEMENT NAME Kenai Uni, t 8. FARM OR LEA]E NAME " 9. w~u NO. KU 2i.~7 · 10. FIEI[,D A~D FOOL, OB WILDCAT: Kenai Ga ~ Field 11. SEC., T., a.,a~., OR BLE. AND EUBYE~ OR' AB~A ' sec,- 6;T4N' RtlW; SM Kenai '~'enn.~'J ~ aaSka 16. Check Appropriate Box TO Indicate .Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE- COMPLETE ]HOOT OR ACIDIZE ABANDONS REPAIR WELL CHANOE PLA~S (Other) ]UBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPrAIRINO WELL FRACTURE TREATMENT ~T,TI~RING .CA]lNG ]HOOTING on ACIDIZINO ABANDONMENT~ (Other) N OTE: .Report results of multiple..eompletlon on Well ompletion or Recompletion Rep~.rt and,;Log form.) 17. DESCRIBE PROPOSED OR cOMpLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, tncludlnK, emtimated date of starting an), proposed work. If well is dlreetlonally drilled, give subsurface locations and measured and true vertical depths zor all markers and -.ones perti- nent to this work.) * It is proposed to cOmplete KU 21-7 in Production Modules 5.1 and 5;2 instead of~ Production Module 1 and 2 as originally planned. Production Module 1 and 2 are non-productive in this well. 18. I hereby eer TITLE DrilliDa Engineer ~)ATn ;: 7,27- 65 (This space fOr Federal/or,~t~te otti~e use), CONDITIONS OF/~PPROVA~, IF ~: *See Instructions on Reverse Side RECEIVED JUL u I965 DIVISION OF MINES & MINERAL$, ANCHORAGE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY I.AND OFFICE ....................... , ...... , ...... ; ..... L.EASE NUMBER .............................. UNIT ..... ,......., .... LESSEE'S MONTHLY REPORT OF OPERATIONS S~_~..a....s..~..a ................................. Cou~ [enai Yw/~ Kenai The following is a correct report of operations and production (including drilling and producing ~elb) for the mond~ of .................. ]..~.....e. ............................................. ,19.6....5., .............................................................................................................. ~,~,~ aaa,~,,....,2....o...,o...S_~.~L..s._tr..~..t.. ........................................ Co~,y~,...rg....o...,n.....O..~....,C...,o.,..m..m..n..y..,..O.f.,..~!~., ........ .............. .~s~.~_~s.,..._.~.....s..~..a.. ................................................... ~ ..... ~ .............................. none .......... ..~..7..Z.-...!..4..~.[ ......................................................................................... ~'s ~/~...P...~.:t~.~t..M.~,....~.LE~.~e~.. Illlltlll~lll~lll~llllllttlllllllltllllllllllllltttlt~ 411IIIIIIIItlI~IIIIIIIIIIItlIIIIIItI~IilllllUlIillIIItlIIlIIIIII ~4~~~!~H~j~!~ ! Illlllllllll IIIIlllll!ltlt w~ O~s ! :~r~ ~ Cu.~Y.o~G~ : G,u~..or : ~u~.o~ :dj ¼ or),4 , , , (In thousand.) : RECOVErEr [aGue,"° ~ote): , , , ...... }.. ~'.. , .. .... , ..... ~ ~ , ....: ............. : ........... , .......... , .......... Ken~i U~' 217-7 / ; Conlinuec~ to fish fo~ casing/ could not recover, fish. , , / , . . , Sid~trac3~ed fish @ ~00' Drilled verl. hole to 564' NE/MW-, ........,-,~ : : Dtr~ ,n~y drtHe~ to 1217! Opene~ hole to 14 3/4" I \ I ......... t ~' -i I · , ~ ...... . · : @ 1~.15" R~"~ and c~mented 3,0 J~ 10i3/4 32.75~ H40 : : ' : ~m~.', s~ic es~ @ ~gs' w/~O ~x. 20 ~x ~op Job. ! : , , , , ', , : Dir~dor~lly ~'llled, 9 7/8" hole to 4t153 TD on 6/10/65 : , : · ' ' Ran ~chl~nberger IE~ l~nlc~; Microlag. Ran and ! , : , ! ' :, ., . : cem~ntedil04 lis, 7i5/8" 1-~5, 26.4% 8md, LT&C csg : , ! ' : @ 4417' ~/550 sx. ~n CBL bond doubtful. Perf 5 3/8" i ' : ' : Jet h~oles ~208-09, ~V$O ok. :Perf. 5 3,/8" Jet holes : . : , ! 3970-71,~WSO ok. ~erf. 4 318" Jet h,bles/ft 3978-89, ! ' i ' : 399i-402t, 4036-4q, 4058-7,0,4072-~102,4128-60, : , : ' , 4162-72, 180-4202 4219-41~4248-7 , 4307-29. Ran : , : ' , , . . . . ' ~,d ~ 6/16/ , : tbg c4xnp. Rig r61eased AM 65. : , : , , , : , : , : , : : , , , ' ' 'i : ' : , : , , . : , I I : ! , , , , : , ~ : ~ , : : : , : , , , , ! I i ! ~ I I ! I I : : ' : , I I I I I I I I I t I I ~ t I I I I I I I I , , , = , = , , , ~ , , ~ , , : , : : , I ! I I I I I I I I I ! I I I , , : , : , , : : , : : : i , , I I t I [ ! t I I I I I I I II ' : , , , , I o t I . t I It lll~, II~1. i I I i J i i I I I IIII! ! ill I I i 11 IiI II IiI i !1 14111 1 1 ! I ! I I !1 iiIiI !iI iI III IIi II1~1~i iiII tliti~11 1 1 1! No'~. ~ ']'hem ~ ........................................................ nm. or sale. of oil; ............................................................................... Mcu. it. al gin.old: ..................................................................... run. or .~le. ot gasoline during the montl~ (Write "no" where applicable.) No~. -- Report on this torm is required tot each ccdendar month, reg~ o!/he ~ ot operations, and must be filed in dupli- cate with the supervisor by the 6th o! the succeeding month, unless otherwSse directed by the supervisor. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ee I..IA6E NUMBER ........ ..,.-,. ..... . .... UNIT,.,.,.....,.-- ..... LESSEE'S MONTHLY REPORT OF OPERATIONS ~ Alaska ........................................... Coaaty .K.,enai . F'm~I Kenai The following is a correct report of operations and production (including drilling and p~ we. lb) 2805 Dena~ti Street Phon~ 277-1481 ~"*~*~~m~"~#~¥~u~#~mm~ .. .. ' T.~. ' RAaQ~ ........ , BmmuaeO~ , , ,. ., ........ ; ... J..,. ........... .; ...... ; ............. : ........... ,. .......... ., ........................ I' I ~1 ! ! ' ~ Kearit Un~l:-/ [///,, ---, ~.. : Spu~ 10:3pAM 5/27/~65. 20" mnduct~ cemented @ 48'. I I ...... I t t I 7 : -~-~ : :Drt~ed 9 ~/8" hole to ~97' ] trecUon H drU.ted to NE/'~ ! : ; ; 1206,'. O~ened hole ',to lq 3/~". Ran ib 27 its 10 3/4" ! I I I I l : : : , , cas .thg. Casing partied top fl h @ 3~7!, Attempting to , ' ' ' ' splt,~ cs(~ w/ b~wl 5/3,~/65,' , , , , ' e csg · · , : : : : ' , , , t I I I ~ I I I I I 'i+'' jKear~ Un t 4 6 ! i Spuc~ l lPI~I 5/26/65:2 cor~luctor c~mented @ 52'. q 6 : , : ; : ]:)rUled 1 q 5/8" hole~ to 200' .; Dtr$cttc~nally drilled to NE/~E ; : : ; 139q'. O~,enod hole ~o 17 1/~" to 13(~'. Ran and : ' : i i cem~,nted,~2 its 10 ~/4" 32.?,54f, H4~, 8rnd, ST&C, i i : , | THD: csg ~ 1297' w/~ 450 sx.i Waitingi on cement : : : : ' il/ ' : i : : : 5/3 65: : : : , , : : : , , : , : , , : ; , : : , , : , I ! I t I I t I t , , = ' : , , I I I I I I I I I ~ I I t I I I I I I I t t t I I t t I I I I I I I I I ' ' ' = = ' ' , , I I I I t I I I I I t I t ~ I t I I e I I t I I ! I t I I I I , , , : : : , , , I I I I I I ! I I t I I I I I I I I I I : ' : ' ' : ' ' i e I I I I I I I t I t t : I I I I = , , , = , , , , , = = ' , , , , I I I I I I I ~ I !I I I I I , = = ~ , , I I t I I I t I I , = , , = ' , , , , I I I I I I I I I t I I t I I I I [ I , , | = , , , , , , I I I I I I I I I ~ , , = ' , , , , , ! I I ~ ! I t I I ' : ' i ' ' ' ' ' ' I I ! I I I I I : I I I I I I I I I I t I I I I I I I I I I I t I I I I t ! I t I t I 8 I I I I I I I I I I I I I ' ' * t t I .I t Herin. --- Them~ ............................................. runs or ealee of ell; ......................................................... ........................................................... t'ur~ ~ $ d~ ~ $ ~$. ~e ~ ~ su~r ~ ~ 6~ d ~ ~ m~ ~ o~ ~ ~ ~ su~r. Form P--1 ,, . ::.~ -. · ~ SUBMIT IN. TRI ;ATE* · ~ ~- - - --.,. - ,,~ ......... t , : ~" ~eve~e side) O1[ AND OAS CONSErVATIoN CO~ISgi'ON APPLICATION FOR-PERMIT TO DRILL, DEEPENS-OR"PLUG:.BACK' la. TYP~OF,WORK ~.~:: ,.~ WELL .~ - ,~ WELL OTHER , ' 2. NAME OF.OP~A~OR Union Oil Co ~. ADDRESS OF OPERATOR ~..~ ~. ~.:c _ '-7~, ~ . ~ f'~ ,. . -: : 2805 Denali 4. ~gx~zo~or w~- (Repo~-loeatlon-ele~rly~:lm-a~drdance wi~:any-~te,~Uirements,e). · '.' xt,,,fa~e 362' north and 1024' east from the SW corner Sec. 6 T4N,: RllW, SM ~t ~,opo,ed ~,od. ,o~e 145~ south and 1721' east frOm the NW corner Sec. 7, T4N, RllW~ SM 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 7 air miles southerly from Kenai. DISTANCE FROM PROPOSEDs LOCATION TO NEAREST Approx. 1600' from PROPERTY OR LEASE LINE, (Also tO nearest drlg. unit line~ if any) lease line. ~. DISTANCE FROM PROPOSED LOCATIONS TO NEAREST WELL, DRILLING, COMPLETED, GE ,~PU~ ,o,. o~ ,HIS ...,~,. ~. 800' (KU 14-6) 21. ELeVAtIONS (Show whether DF, RT, OR, etc.) 16. NO. OF ACRES IN LEASE 2.560.00 ~. PROPOSED DEPTH 4400' 7~' gr. 23. PROPOSED CASING AND CEMENTING PROGRAM Effective: July 1, 1954 5. LEASE DESIGNATION AND SERIAL NO. ~2028142 6. IF 'INDIAN, ALI~)TT~E OR'TRIBE NAME · 7. UNIT~ AGREEMENT NAMR . · .~cnnaL._._. - 8. FARM OR .LEASE 'NAME · '9. W~,~L"fo. ' .... . -, , " ~ '21'7 Kenai Gas Field 11. sEC., T., R., M., OR AND' SURVEY OR AREA .Sec. 6, .T4N, Ri1W, SM 12. B. OROUGH sa[ 13. STATE Kenai Penn. A/aska 17. NO. OF ACRES ASSIONED TO THIS WELL 320 20. ROTARY :OR CABLE TOOLS Rotary 22[ APPROX. DATE WORK WIlL START' May 22, 1965 SIZE OF HOLE ~ SIZE OF CASING | 1~]3//4" 'I 10-3/4" 7/s" l Due to swampy terrain it is WEIGHT PER FOOT J[ SETTIN~ DE~ffH 32.755 [ 1200' - 580 sacks 26.45 [ ~- '400 sacks unfeasible to b ild economically QUANTITY OF CEMEN% roads and locations for each individual well. This well will therfore be directionally drilled from a centrally located drilling island. 1. Move in and rig up. 2. Spud in with 9-7/8" bit and drill to 200'. 3. Directionally drill 9-7/8" hole by jet deflecting from 200' to 1200'. hole to 14-3/4" to match surface casing. 4. Cement 10-3/4", 32.75~, H-40 casing at 1200'+. 5. Install and test 10" 3000~ blowout prevention equipment. 6. Install gas analyzer unit. 7. Directionally drill 9-7/8" hole to 4400' (MD). 8. Run Schlumberger wireline services. Open 9- 7/8" DIVISION Cfi: '~zil'-.,,'I'~S & N,:dNERAL~ ANCHORAGE IN ABOVE SPACE DESCRIBE PRO~O~ED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drilt~j~r deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. * Give blowout preventer program if any~,~ . , , / / .~ .... ., . 24. I hereby ce .~~at ~ F~re~-m'~fl~is True and Correct. ' ' ~.~ ~-~~.~.~ -~.~ . SIG~E. ~~/~) TITLE Drillinq Er~jineer DATE April21, 1965 ('This' space for Federal or State office use) APPROVALOATE April 26: 1965 TITLE Executive Secretary DATE April ?6; 1965 0il and Gas Conservation Committee Subject to Conservation Order ~16. · *See Instructions On ReYerse Side Application for Permit to Drill KU 21-7 April 21, 1965 · 10. 11. 12. Cement 7-5/8", 26.4~, J-55 casing below deepest gas sand. Make WSO and production tests as required° Run collar locator and perforate four 3/8" jet holes per foot as required in production modules 1 and 2. Run and land dual strings of 2-7/8" tubing with two production packers as foll ow s: 13. 14. 15. a. One packer above module 2 perforations o b. One packer abOve module 1 perforations. Test packers and install Chrustmas tree. Change over mud to fresh water and swab in. Shut well in until production facilities are installed. DIV!$10N OF M:II'.~ES & ANCHORAGE scALE / /Z · I": S W COR'. SECTION 6 CE. SURFACE LOCATIONS KU ii 7 / ~ · Top Grovel Fill. Elev.= 74.25 J. / KU 21 - 7 .... ~ ~,~-~"'Top Grovel Fill. Elev. = 74.12 ~ ~/~ KUI4 ~~i! -6 (Existing) ': ~1 '~. BJ~t3 Top Heater Foundotion I ~ Elev.= 73.8~ ,D :1~l LEGEND and NOTES. ij~ Found U.S.G.L.O. brass cop monument. Ail bearings refer to the G.L.O. datum of North for the West boundary of Section 7. Elevations refer to Mean Low Tide as being O.Oft. determined from the U.S.C. and G.S. tide datum for the Kenoi River entrance. RECEIVED APR DIVISION OF MINES & M,IN,~.RAL~3 ANCHORAGE UN ION OIL COMPANY 0 PERATOR OF CALIF. KENAI UNIT 11-7 SURFACE LOCATION LOCATED ,377.9 FT, NQRTH A'NO 992.0 FT. EAST FROM THE SW CORNER' OF SECTION 6~ T4N~ RIIW, S.M., ALASKA. KENAI UNIT 21-7 SURFACE LOCATION LOCATED 362. I FT. NORTH AND 1024.1 FT. EAST FROM THE SW CORNER OF SECTION 6~ T4N~ R IIW~ S.M.~ ALASKA. SURVEYED BY: Stanley S. McLone, R.L.S. Date April 9~1~65
