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Home My WebLink About176-056• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil f Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑Q • Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 0 1 b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or z� t z l� Aban�:) 7/JA0518 1• 4. Permit to Drill Number/ Sundry: • 176-056 / 318-195 15. API Number: 50-133-20293-00-00 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 7/23/1976 4a. Location of Well (Governmental Section): Surface: 1465' FSL, 1657' FEL, Sec 33, T8N, R9W, SM, AK Top of Productive Interval: NA Total Depth: 1404' FSL, 1701' FEL, Sec 33, T8N, R9W, SM, AK 8. Date TD Reached: 12/9/1976 16. Well Name and Number: Soldotna Creek Unit (SCU) 33-33 9. Ref Elevations: KB: 143.5' GL: 125.5' BF:125.5 17. Field / Pool(s): Swanson River / Hemlock Oil 10. Plug Back Depth MD/TVD: 6,259' MD / 6,258' TVD 18. Property Designation: FEDA028990 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 345991 • y- 2462644 Zone- 4 TPI: x- NA y- NA Zone- Total Depth: x- 345907.7 y- 2462320.1 Zone- 4 11. Total Depth MD/TVD: . 17,689' MD / 17,660' TVD - 19. DNR Approval Number: NA 12. SSSV Depth MD/TVD: NA 20. Thickness of Permafrost MD/TVD: NA 5. Directional or Inclination Survey: Yes LJ (attached) No Q Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NA (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 6,259' MD / 6,258' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary RECEIVED IVE NA C SCAM DEG 2 6 2018 NOV 2 6 2018 AOGCC 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH TVD SETTING DEPTH MD HOLE SIZE TOP BOTTOM TOP BOTTOM AMOUNT CEMENTING RECORD PULLED 20" 0 90' 0 90' Driven 13-3/8" 68# K-55 0 3,380' 0 3,380' 17-1/2" 1500 sks "G" 9-5/8" 47# S-95 0 6,259' 0 6,258' 12-1/4" 1st Stage 1,300 sks "G" 2nd Stage 2,200 sks "G" 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): l �CiMG1 d'� _T�� DAVE 11l,s 1t$ VERIFIED AAU 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes 0 No ❑✓ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27, PRODUCTION TEST Date First Production: NA Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: NA Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. NA Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RPQM�l�I� Cy� ,� � 2Ut8 SubmitORIGINIALonly� � U � tz' t,9,'6 JCC 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: Jurassic 31. List of Attachments: Wellbore Schematic, Daily Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdln er hIICOr .COm Authorized Contact Phone: 907-777-8389 Signature: Date: I'S INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: 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. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • llilK ,LC RKB: 153'/ GL: 125' MSL Orig RKB: 17'/ New RKB: 17.45' zo" Abi �Glw 13-3/8" C l!3 P D reap (fjn c u i'1%51/3 10,505' G -Zone 06/14/18 H1 H2 / H3 Tagged Fill H4 2/12/16 10,673'SLM H4/I-I$ H5 unk @ 10,650' 10-02-11 Corrected measure 9 -5/8 - TO =17,689' PBTD = 6,278' MAX HOLE ANGLE = 2 deg. @ 6,100' Downhole Revised: 2/16/16 Soldotna Creek Unit Well SCU 33-33 SCHEMATIC Completion Ran: 2/13/16 PTD: 176-056 API: 50-133-20293-00 CASING DETAIL Size WT Grade Conn ID Top Btm 20" - - 2 - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 10,321' 47 S-95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 j 8RD EUE 1 2.441" 1 9,996'10,464' JEWELRY DETAIL No. Depth ID OD Item 1 6,278 Date G2 9-5/8" CIBP 07/08/18 2 9,948' 10,508' 34' 9-5/8" CIBP w/ 35' cement 07/08/18 3 10,317' 10,476' 10,510' 2-7/8" CIBP 07/05/18 4 10,321' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,427' 2.313" 3.679" X Landing Nipple 6 10,464' 2.441" 3.679" WL Entry Guide PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,351' 10,508' 34' 4-5/8" Millennium 5spf Isolated G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf Isolated G -zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 Isolated G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 Isolated G -zone 10,512' 10,544' 10,510' 10,542' 32' Isolated HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf Isolated 113 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf Isolated H1 10,562' 10,588' 10,560' 10,586' 26' Re -pert 2/20/86 Isolated H2 10,588' 10,602' 10,586' 10,586' 14' Isolated 142 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf Isolated H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf Isolated H2 10,610' 10,628' 10,608' 10,626' 18' Re -pert 2/20/86 Isolated H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf Isolated H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8"Millennium 5spf Isolated H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 Isolated H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf Isolated H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf Isolated H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf2/20/86 Isolated H4 10,658' 10,665' 10,656' 10,663' 7' Isolated H5 10,670' 10,680' 10,668' 10,678' 10' Isolated H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 Isolated H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77; 2/20/86 Isolated H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 Isolated Updated by DMA 07-18-18 I K Hileoru Alaska. LLC RKB: 153'/ GL: 125' MSL Orig RKB: 17'/ New RKB: 17.45' L20" 0❑ F4 13-3/8" TOW 6,259' MD 10,505' G -Zone 06/14/18 H1 H2 H3 Tagged Fill H4 2/12/16 10,673'SLM H4/H5 H5 Junk @ 10,680' 10 -0z -u Corrected measure 9 -5/8 - TD = 17,689' PBTD = 6,259' MAX HOLE ANGLE = 2 deg. @ 6,100' Downhole Revised: 2/16/16 0 P&A SCHEMATIC 0 Soldotna Creek Unit Well SCU 33-33 P&A'd: 7/12/18 PTD: 176-056 API: 50-133-20293-00 JEWELRY DETAIL No. CASING DETAIL ID OD Size WT Grade Conn ID Top Btm 20" - - Surface 90' 1.3-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 5-95 BTS 8.681" Surface 6,259' JEWELRY DETAIL No. Depth ID OD Item 1 6,278 Date G2 9-5/8" CIBP 07/08/18 2 9,948' 10,508' 34' 9-5/8" CIBP w/ 35' cement 07/08/18 3 10,317' 10,476' 10,510' 2-7/8" CIBP 07/05/18 4 10,321' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,427' 2.313" 3.679" X Landing Nipple 6 10,464' 2.441" 3.679" WL Entry Guide PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf Isolated G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf Isolated G -zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 Isolated G -zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01; 8/31/09 Isolated G -zone 10,512' 10,544' 10,510' 10,542' 32' Isolated H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf Isolated HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium Sspf Isolated H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 Isolated H2 10,588' 10,602' 10,586' 10,586' 14' Isolated H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf Isolated H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf Isolated H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 Isolated H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8"Millennium 5spf Isolated H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf Isolated H3 10,640' 10,645' 10,638' 10,643' S' Re-perf 2/20/86 Isolated H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf Isolated H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf Isolated H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 Isolated H4 10,658' 10,665' 10,656' 10,663' 7' Isolated H5 10,670' 10,680' 10,668' 10,678' 10' Isolated H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 Isolated H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77; 2/20/86 Isolated H5 10,710' 10,712' 1 10,708' 10,710' 1 2' Re-perf 2/20/86 Isolated Updated by CJD 10-30-18 0 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 1 CTU/Rig 169 50-133-20293-00 1 176-056 6/10/18 7/11/18 Daily Ile a ' 06/10/2018 - Sunday PTW. Hold safety meeting. MIRU SLB CTU 12 with 1.5" CT. Start BOPE test. 24 test witness notification sent to State on 6/10/18 @ 12:44. Witness waived by Jim Regg on 6/11/18 9:12 am. Test all rams and valves 250/4,500 psi. Pump 125 bbls of 165°F produced water down tubing for cleaning. Location secure. SDFN. 06/12/2018 -Tuesday PTW. Hold safety meeting. Pick injector head, stab 10' lubricator. Make up CC, 2x singer/weight bar, ball drop cement nozzle. BHA 1.75" OD and 8.5' in Length. Stab on well. PT stack 250/4,500 psi. Bleed down. Open well and RIH. Initial WHP 632 psi. WHP bleed down in 2 minutes. RIH at stack 6K down at 873' CTMD. Pick up and come online circulating. RIH stack at same depth. Pick up close choke. Online down CT and CT x 2-7/8" tubing 4.6 bbls/min pressure spiked and dropped a few times from 1,565 psi of 0 and back up. Previous day pumped 125bbls of 165°F water to clean tubing of parrafin. Previous tag at 873' was potential paraffin blockage from previous days hot oil job. RIH to 1,000' and pick back up to 600'. No blockage or obstructions. TIH with 1.5" CT to tag top of fill. Tagged TOF @ 10,684' CTMD. Hold safety meeting with SLB Coil and SLB cementing. Cementers volumes are off. Calculated 16.1 bbls of cement vs cementers volume of 22 bbls. If formation wouldn't take some cement we would have cement across orifice at 10,259' allowing the back side of tubing to fill with cement. Called town to discuss. Decided to pump 16.1-16.5 bbls. Cementers priming up and PT lines to 250/4,500 psi. Pulled on mix water. 85°F fresh water. Previous plan was to pump 5 bbls ahead, followed f by 16.3 bbls of cement and then 5 bbls of fresh water afterwards. Looks like coil was sucked dry by wellbore. Had 4 cementers pump 25 bbls to ensure a good fluid pack to resist cement from running away. Cement wet at 1344 hrs. Cement thickening time 6 hrs and 35 minutes. Cement mixed up. Mud scale reading 15.75 ppg. Online at 1 bbl/min down CT. Zeroed total when cement was at MM. 16.5 bbls of cement pumped. followed by 5 bbls. Coil pump take over. Reel volume 25.7 bbls. Cement at nozzle. Let .5 bbls get above us. Start POOH at 14 ft/min pumping 1 bbls/min laying in 1:1. 10,464' shut down pump after 15.4 bbls pumped. Let remaining 1. 1 bbls fall out as we pull into tubing tail. POOH to surface. Online at 1.5 bbls down CT to clean Coil @ 10,300' CTMD. POOH to surface. Continue to POOH to surface. NOTE: no returns obtained during well intervention. Not sure if cement was being laid in or going in to formation as we cannot see if we are getting 1:1 at surface while laying in cement. At surface. Swab master shut in. Cooling down N2. Blow reel down. Break off well. Stack down and remove coil from injector. Install injector on back deck. Leave iron and equipment rigged up in case another cement job is needed. Slick line scheduled to be on well at 0400 hrs to tag TOC. SDFN. Arrive in field, fill out JSA and work permit. Spot equipment and RU slickline. Stab on PT 250L/2,500H psi, test good. RIH w/ 2.25 gauge ring. Tag hard bottom @ 10,536'KB. POOH. OOH RD slickline, move to SCU 243-8. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 06/13/2018 - Wednesday PTW and JSA. Pick BOP and injector head, stab 10' lubricator. Make up CC, 2x singer/weight bar, ball drop cement nozzle. BHA 1.75" OD and 8.5' in Length. Stab on well. PT stack 250/4,500 psi. Bleed down. TP - 0 psi. RIH w coil BHA and tag cement at 10,547' (SL tag was 10,536' - hard tag). Tagged with coil twice. Once with 7K tag and second with 6K tag. Called town and discussed. Decided to pump 7.6 bbls which should put cement top around 10,167' if perfs don't take any fluid. MU and test cement lines to 4,500 psi and start mixing 7.6 bbls of 15.8 ppg cement. Pump 1/2 bbl of cement around coil (7') and start out of hole pumping cement. In 9-5/8" casing pumped 1/2 bpm at 7 fpm. When got to tubing tail starting pumping 1/2 bpm at 86 fpm. TOC should be approx. 10,172'. Picked up 100' and did a 5 bbl coil flush. Total bbls pumped today including cement was 116 bbls. Cement in place at 1833 hrs. SLB cement engineer said we could tag cement at 0730 hrs in the morning. POOH. Rig down half way and will see where tag is in the am. If tag is good, coil will come out and rig the rest of the way down and move to GO -06. TP - 0 psi. 06/15/2018 - Friday Met 8 man Doyon crew at Kenai Airport, expediter led drilling crew to Swanson River field. Loaded Peak trailer at Hilcorp warehouse. Crew checked in to field housing. Held Swanson River orientation with 8 man crew at field office. Offloaded Hilcorp loader and various equipment at Tyler Pad. Did walkthrough of rig with Drilling crew. Started gen #3, both rig pump motors and floor motor with no issue. Gen 1 near dead batteries, gen 2 had no batteries. Moved derrick hyd cylinders and doghouse hyd cylinder to rig's location. Pinned bottom of doghouse cylinder in place, scoped out cylinder while priming same. Moved rig pump liners and swabs to rig location. Cleaned on both pumps and prep for pulsation dampener install. Transported electricians truck to field. Shut down at 18:00 to rest crew. Production removed piping from 344-33 wellhead. 06/16/2018 - Saturday Fired up gen's 1 and 2 (ok), tied in pushers shack and doghouse skid for lights. Finished install of doghouse hyd cylinder. Continued to wire wheel and clean pump pods and pulsation dampeners for assembly. Installed new bladders in dampeners, cleaned and installed top caps on same. Installed last nitrogen bottle on Koomey bottle bank. Cleaned and organized tool room on doghouse skid. Mechanic checked new derrick hydraulic cylinders for oil (full) and received hardware and hoses for install. Electrician gathered up conduit and equipment, started install of wiring to starter box for shakers on pit #1. Production vac truck removed rain water from containment and rig water tank. Shut down at 18:00 to rest crew. 06/17/2018 -Sunday Continued wire brushing, wire wheeling and lubricating pump parts, hammer unions, hinges and quick connects throughout the rig. Production removed rain water from well site pad. Marked off rig footprint at well site. Met with field blade operator on level up back yard and drillers side of pad. Chased pump parts at warehouse and squirrel hut. Changed oil/filters on floor motor and gen 1 and 3. Install seats and liners in pump 2. Cleaned bottom flanges and bolts on pulsation dampeners. Rig electrician continued working on shaker starters. Mechanic ran gen set on change house skid. .'c(1 JJ 1 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 06/18/2018 - Monday Removed 10" x 4" spool of pump #2, installed 12" spool (for pulsation dampener), staged boxes, baskets and assorted equipment to edge of pad. Held PJSM with Peak crane crew, spotted crane, RU and removed derrick hydraulic cylinder from off side of carrier. Picked and set two new hyd cylinders on carrier. Re -located crane, picked and set both pulsation dampeners on mud pumps. Removed Handy Berm from off drillers side and in front of sub, pulled pit 3, change house skid and catwalk to expose more rig mats. Transported 48 rig mats to 33-33 and staged. Lowered dog house for move. Blade operator leveled up 33-33 pad. Staged and set up comm tower on 33-33. Shipped old Koomey bottles and old derrick hyd cylinder to town on empty Peak truck. 06/19/2018 -Tuesday Continued working on rig pump and inspecting derrick while waiting on Pollard to retrieve orifice from GLM on SCU 33- 33. Peak crane crew on rig location at 8:00. Held PJSM, spotted cranes, RU and removed carrier from sub, picked sub and removed pony walls. Peak moved carrier and pit 3 to Tyler Pad. Pollard RD from SCU 33-33 at 13:00. Crew measured and marked pad for rig footprint, layed out felt and liner, then set rig mats. Peak moved pony walls to SCU 33-33 and set same. Moved and spotted cranes at SCU 33-33, then brought in sub base and spotted for picking and setting on pony walls in the morning. Received 6 tubs 4-1/2" DP and HWDP. Pollard RU hotoil at 06:00 and made an attempt to bullhead 60 bbls hot water down tubing to clear paraffin. Could not bullhead. Bled off and RIH with guage ring. Pollard set down at 4511' with gauge ring. POOH, MU paraffin cutter, RIH and cleaned up tubing at 4,511'. POOH with paraffin cutter, RIH and retrieved orifice from GLM at 10,259'. POOH RD released. SCU 33-33 annulus has 700 psi on it when they left at 13:00. 06/20/2018 - Wednesday Peak on location at 06:00 and warming up cranes. Held PJSM with rig team. Spot iron roughneck HPU and test pump inside pony walls, RU and pick sub base and set same on pony walls. RU, picked and set sub on pony walls, set carrier on sub, set and pinned derrick. Mechanic installed plumbing and hoses on new hyd cylinders, set iron roughneck, raised and pinned derrick windwalls and house. Set doghouse and raised same, set gen 1-2 skid, set HPU. Trailered in pits 1 and 2 from D&D welding shop. Set all three pit skids and installed equalizer tubes, raised pit roofs. Spotted crane near crown section and RU slings to crown. Held PJSM with rig super, crane crew and rig crew on exercising hyd cylinders. Raised and lowered mast to work any air out of system and check lowering speed. Pulled crane off crown and stood mast. Set both pump skids, new poorboy degasser skid and boiler skid. Started plugging in cords. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 1 CTU/Rig 169 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Qa� ily Opera#rors 06/21/2018 - Thursday Strung out and plugged in elec cords throughout the rig, set catwalk and lay over beaver slide, installed vent line and raised poorboy degasser, installed stairs off shaker pit, wrapped drill line on deadman and clamp, RU brake handle, driveline and linkage to drawworks, lay out drill line and spooled up on drum, spot office trailers and gen set, wired in trailers, installed discharge line from poorboy to shakers, RU comm's to office trailer, re -located gen 3 and wired in same, Pason Rep ran wires and PVT sensors in pits 2 and 3, set crew change shack, replaced air fitting nipple on eaton brake, staged dumpsters, set centrifuge, installed shock hose from pump skid to carrier, wired in office trailers, filled trailer water tanks with water, cleared derrick for scope up, could not find weight indicator sensor, ordered out rental from Quadco, staged centrifuge control panel and feed pump. 06/22/2018 - Friday Installed ground rods for rig and office trailers, installed weight indicator and load cell, spooled off bad cable on off -side hyd winch, spooled on new cable, Pason rep cont running cables and installing PVT's in pit #1, Handy Berm bermed in rig footprint, held field orientation with new Doyon and Peak hands, RU bridal lines and scoped up derrick, tied back bridal lines, continued wire brushing/wire wheeling pods on pump #1, MU standpipe and manifold on rig floor, took on 3,000 gallons fuel, built mud docks on staging pad, brought in 3 trailers mud products, set mud lab, steel seal some of the new iron on pit #1, brought in production bleed tank. Continue wire wheeling fluid end cylinders on # 1 mud pump & install 5" liners. Connect 8" low pressure lines on pits, air up and check all air unions on low pressure mud lines, begin installing cables on mud pit equalizers, mount and rig up Geronimo line. Clean out debris inside water tank and pits, remove shock hoses from shipping box, clean clear perimeter of location, pick up torque tube on catwalk and mount in derrick. 06/23/2018 - Saturday Charged new Koomey bottles at 1,050 psi, PU topdrive and RU same (Kelly hose and service loop), cont cleaning up pump #1 for assembly, opened up tubing (on vac) 920 psi on annulus, RU bleed tank and bleeding off annulus as wind allows (no fluid), repair water lines in office trailer, Pason tep cont RU, total safety RU and tested gas detection equipment, remove pipe spinner roller assembly on iron roughneck, (idler gear bearing froze to pin), changed oil and filters on pump #2 engine, put water in rig water tank, plugged in topdrive HPU to doghouse. Open up well to bleed off pressure, well head at 900 psi, start testing rig water lines, continue installing cables and pulleys on mud pit equalizer lines, complete clean up and installation of liners and swabs on # 1 mud pump. inspect and clean out pits of any welding rod and metal from modifications and repair. Wellhead pressure down to 750 psi at 00:00 hrs continue to bleed off. Remove middle cylinder head flange from #2 mud pump, replace butterfly valve handles on 6" mud lines in pits. clean up possum belly on 3 shakers, install screen rubbers on #1 shaker. Shut down wellhead bleed off due to wind conditions WP 700 psi at 0100 hrs. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 50-133-20293-00 176-056 6/10/18 1 7/11/18 Daily;Operations: 06/24/2018 - Sunday Pulled end caps and cleaned out mud pump suction manifolds, replaced roller assembly on iron roughneck, Pason rep cont to RU in push shack and dog house, function tested topdrive (HPU #2 not working, but topdrive did function properly on one HPU), staged spill connex on the pad, built mud and drum docks, installed valve handles in pits, cleaned pump discharge screens, checked agitator oil levels, RU compensator rams on topdrive, aligned torque tube, installed 2" hardline on pit #1 roof for fill up line, shoveled sand out of boiler hot well tank and flushed same, bleed annulus from 700 psi down to 400 psi. Continue bleeding down annulus from 400 down to 250 psi at 0:00 hrs, align torque tube. Build docks with containment for liquid mud products and unload drums. Clean up and repair rotary handling tools. Inspect mud pump drive belts (good condition). Complete assembly and repair to both mud pumps, continue to bleed down annulus 180 psi @0600 hrs, add turnbuckles to torque to align. Complete hole fill line. Shut annulus in. R/U bleeder line. 06/25/2018 - Monday Closed in annulus valve and RD bleed tank for welding project. 180 psi on annulus at shut in, tbg still on slight vac. Covered cellar box with grating and liner. RU scaffolding on rig floor. Field operator stopped by and sniffed cellar box, cellar, carrier and rig floor and issued hot work permit. Held PJSM with rig team, rig Super, Engineer and welders. RU welders and staged iron on rig floor to be welded in derrick. Staged 3 fire watch hands. Welded 6" square stock in derrick with rig Super and Engineer witnessing and inspecting. Continue work in pits, wiring in shakers, clearing gun lines. Pason Rep cont RU network. Set Sperry, Canrig, Baroid and Swaco MPD shacks. Continued to weld out 6" square stock in derrick. Remove mud pump shear relief valves for inspection and repair. Complete welding on rig floor and mast. R/U bleeder lines and tank, bleed off annulus 180 psi on wellhead. Start rig. Acceptance check list. Continue bleeding annulus 140 psi at 0200 hrs. Inspect and test bridge cranes in sub. Working on rig acceptance check list, rig floor handling tools, BOP control unit, inspect sub, checking all pins and bracing, mud pump guards, all vibrator hoses snubbed, Annulus pressure down to 100 psi at 0600hrs. 06/26/2018 - Tuesday Hilcorp inspector conducted mag particle test on welds in derrick. Good. Set SWACO choke skid in place. Close in well. Rig down bleed tank. 80 PSI on annulus. Hold prejob with Rig Super, welders, and Doyon crew. Weld two D rings on IDS 350 brace. Cut holes in new pit grating, weld in rings for Pason pit level monitors. Install pit level sensors. All 3 shale shakers, were wired and tested. Held prejob with Peak crane crew. Fly IDS 350 brace into position. Bolt in. Good fit. Remove same. Pick centrifuge off deck. Raise deck into position for drilling, pin same. Place centrifuge back in position with crane. Mechanic dressed set of suction end caps for MP's, rebuilt 3 pop offs. Pason Tech calibrated flow alarms, gain loss alarms. Hook up cables to risers in Plts 1 to 4. Open Vac degasser, clean out, work on float. Re -assemble. HPU #2 is now operational. RU bleed off tank begin bleed off of annulus 60 psi to start, install shear relief valves on mud pumps, change gear lube in mud pumps, run gear lube pumps lube slides and gear ends. Clean out flow line. Make up saver sub and top drive safety valve mount on TD quill. Inspect and make up wash pipe cartage, continue to bleed off annulus, continue pumping and testing water lines in pits checking for leaks . Clean up ram blocks, inventory subs set safety valves on rig floor. Install bails on top drive and function test. Clean inside of shaker pit. Work on rig acceptance check off list. Installed new water heater in boiler room. 0 • H i lcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 06/27/2018 - Wednesday Torque bolts for saver sub and IBOP clamps to 400 ft/lbs. Work on risers in pits, clean and inspect test equipment. Electrician worked on cameras. Bring on water from bulk tank to pit #7. Fill pit, transfer fluid, into 1,2,3. Test all lines. Test ran both rod washers. Packed off with rust. Clean same. Continued transferring between pits, tightening connections as leaks appeared. PASON tech calibrated pit volumes. Transmitted 48 hr notice to BLM for initial BOPE test. Fixed leak in equalizer line between pits 3 and 4. Fixed leak in suction line charge pump #1, between pits #7, #8 and #3. Fixed dump valve in pit #3, fixed leak in suction line trip tank. Fixed drain valves for air system dryer. Bled gas off of well. 10-20 PSI on well at crew change. Closed in the well. Monitor well for pressure build up. Shut annulus in with 0 psi R/D bleeder tank. Set sub rack on rig floor, stage x overs & safety valves for upcoming BOP test (2-7/8"). Continue checking for leaks and repair. Continue rig acceptance check list change out discharge and suction line on test pump. Inspect derrick and sub. Function test hydraulic rams for tong lines. Replace 6" line from hopper 1 to pre -mix tank 3.Pits 1&2 all suction rubbers changed. Function test rotary table drillers side lock not engaging. Arctic dump pit #6 leaking repair gasket . Tighten up gun line suction valve pits 3, 4,5 and 6 . Seal leaking on agitator in mix pit 1. Attempt to pump through mud pump #1 bleeder and pop off lines, union leaking on shock hose and all cylinder heads stop and repair. 06/28/2018 - Thursday Conducted low pressure test to both pumps w/ charge pump, 60 psi. 4 - Model 72 Oteco gate valves leaked, two 4" valves, two 2" valves. Remove, rebuild, and re -install. New rubber seals & paddles. Tested good with charge pump. Align to rig floor 4" Oteco gate valve. Leaked. Rebuild same. Calibrate block height, replace power cord for test pump. Clean all pits after pumping, remove construction debris, and scaling. Leave pit #7 full for testing mud pumps. Retightened cylinder heads on MP#1. Good at low pressure. Continue repair and rebuild of 4" Oteco stand pipe valve. Replace liner Seals in #2 mud pump cylinder head, re- test, still leaking. Remove seal and replace. Take on produced water in pits 1,2.3. Test HP mud lines via test pump. 250 psi, 1,000, psi, 1,500 psi, 2,000 psi to 3,000 psi from top drive to mud pumps. Shock hose union from pump room to sub leaking. Replace gasket in union. Still leaking. Change out hose. Function test #1 mud pump pop off, test good . Retest all mud lines 3,000 psi from Top Drive to 4" Oteco valve in pump room. Transmit notice of initial test to AOGCC. (Saturday 1500 hrs). 06/29/2018 - Friday Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 1 6/10/18 1 7/11/18 Dally Operations: Clean up threads on 16' HP shock hose to rig floor. Still dripped. Replace with new hose. Test to 3K. Good. Replace gasket on rig floor stand pipe, test to 3K. Good. Test pop off to 3K MP #1, hold for 5 mins, good. Test pop off on MP#2 to 1,500 psi, leaked, set on 3,500, install new pop off. Test to 3K, 5 mins good. Crew change. Orientation. Familiarize new crew with Swanson River, rig, well plan. Rig up centrifuge flow line to pit #4. Pump through both pumps. Rig accepted 1700 hrs. Fluid pack the poor boy for circulation. Prejob with Hot oil / Peak / Doyon. Start job. Truck pump not operating. Troubleshoot with driver. Pressure test lines from hot oil truck to wellhead. Trouble shoot hot oil pump truck problems Repair same. Test lines to 3,500 psi test good. Open up annulus and reverse circulate to displace well with 165 degree 8.45 produced water staged up to 3.5bbls. at 60psi. Hot oil truck hydraulics overheating Shut down hot oil truck with 213 bbls pumped, unable to operate pump more than 1.5bbls per min. Decision made to R/D pump truck and switch to rig pump for displacement. Rig up kill line to annulus and tubing to choke line. Begin pumping down annulus with 8.45 produced water taking returns through manual choke and poor boy separator at 2.7 bbls /35 psi stage pump up to 4bbls min 50psi pressure incresed to 1,850 psi after 495bbls pumped saw returns at cuttings tank. Pressure continued to increase, slow pump down to idle, pressure continued to increase to 2,187, open bleeder on mud pump pressure decreased to 1,300 psi. Mud pump 1 liner seals began to leak, shut pump down and bleed off pressure. Shut down and discuss options Annulus 496 Tubing 444 bleed off pressure on annulus and tubing pressure on both 0 . R/U to ensure the well is fluid packed . Attempt to pump down tubing, mud pump stalled at 2,450psi. R/U test pump attempt to pump down tubing, pressure up to 2,800. W/O success. orifice on GLM appears to be plugged. 06/30/2018 - Saturday Rig up to pump across IA to fluid pack well. Well took 7.3 bbls. Rig down all 1,502 lines in cellar. Set BPV with wellhead hand. Clean out cellar, suck out fluids. Nipple down tree. Slight bleed off of gas from 3/8" chemical control line. Isolate line with plug. Clean out and inspect hanger threads. Good. 10 turns to seat by hand with XO. Install new R54 ring. Remove tree from cellar. Tear down MP #1 and remove excess red grease. Begin nipple up of BOPE, 11" Townsend 5K stack. Install riser flange (12"), double studded adapter spool, (16" ). Torque all bolts. Blow down the choke line, poor boy, all mud lines. Empty pit #7, clean out. Continue working on nipple up in cellar. Lay back cat walk, rig up Peak crane for picking. Build mud cross with 2-1/6" manual, and HCR on kill side, and 3-1/8" manual, and HCR on choke side. Begin adding fresh water to premix pits for building mud volume. Mechanic rebuilt the 4" Oteco gate valve on stand pipe. Continue nipple up of BOP stack. Change out api rings on HCR valve and 4 Way block Set mud cross. spool, double gate & annular preventer & nipple up, torque all studs to 2,500 fp. Mix and build mud volume. Start installing 1" HP fittings on preventers found schedule -40 pipe fittings on inlet connectors for Koomey control lines, change out to schedule 80 Nipple up armored 3-1/8 x 5000 psi hose from choke side of mud cross to choke line, nipple up.Re set annular lifting cradle and nipple up. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 07/01/2018 - Sunday Complete installation of Koomey hydraulic lines. Install new rubber boots in flow box. Assemble flowbox, riser, flowline system. Remove inoperative weight indicator. Hook up 5" steel flexible kill line. Continue to mix mud in pits 4,5,6. Directional tools arrived on location. Off load. Install flow paddle. Raise beaver slide back into working position. Secure all Koomey hoses with whip checks. Rebuild hole fill line, with check valve and ball valve, install. Test Koomey electric pumps, good, set annular closing pressure to 800 psi, set manifold pressure to 1,500 psi. Continue to mix 9.5 ppg 6% KCL PHPA mud. Directional tools arrived. DD/MWD/Mud loggers arrived and begin rigging up. Open ram doors in double gate. Place 2-7/8" solid body on top, blind rams on bottom. Function test upper pipe rams, blind rams, HCR valves, install ODS 2-7/8" solid body rams in single gate. Mark cellar grating and pull out for cutting to fit stack. Visit from BLM rep, supply certification of kill and choke lines. Pad passed inspection. Complete installation of 2-7/8" rams in bottom single gate and function test same. Install safety lines on choke and kill line hoses. Grease kill choke valves on drilling cross. Grease all valves on choke manifold. Dress out shakers with 120 mesh screens. Build test joint with x overs, floor safety valve and dart valve. Fill BOP stack. Repair bell nipple leak. Energize Koomey found leaks on fittings to annular repair. AAOGC and BLM inspectors arrived on location. Tested LEL and H2S alarms and PVT system while conducting shell test. Purge system and pressure up (shell test) found leak in door seal on blind ram, drillers side of stack. Repair replace door seal. Refill stack. Attempt to shell test found leak on door seal upper pipe rams. Repair and replace door seal. Fill stack and continue shell test. Test good. Begin BOP test. Test Annular upper TD valve dart and kill choke valves 1,3,4,5,7 & 11. 250/3,500 psi 10 min test. Low pressure test stopped( leaks in test manifold rig floor). Repair valves on test manifold in dog house. Continue with BOP test. 07/02/2018 - Monday 't" AOGCC and_BLM Inspectors, conducted Pason Tech conducted PVT, gain/loss, and flow operational alarms. All tests Good. Crew verified all valves were in alignment as described by relief. Verify IA valve was open, and built 2" riser to keep full of water on IA. Bleed off pressure. Leak was reported by previous crew. Wipe down all equipment to locate leak. Reduce shell test area to LPR's and hanger, small void. Pressure up to 3,500 psi. Find leak in seal below LPR's and above 16" spool. Bleed off, and hammer up. Retest, Still leaking. Pull test joint, pull BPV, install TWC. install test joint, pressure back up to 3,500 psi, good test. Align for full body test, pressure up, small leak on mezzanine kill line 2-1/6" gate valve. Bleed off, grease, and work valve, retest, still has a small leak. Prepare to replace. State Man timed out, left location. Continue in house BOPE test. Test all choke valves, had to re -grease, 5, 8 to gain good test. Continue valve swap in mezzanine. Conduct pressure test on super choke, and manual, both tested good. Install calibrated gauges in the choke house. Continue C/O of upstream 2-1/16" kill line valve on mezzanine. Install 2" manual choke on standpipe bleeder. Repair hydraulic leak on choke actuator for choke side HCR valve Shell test kill line valve on mezzanine 250/3,500 psi test good. Continue in house BOP test 250/3.500 psi IBOP leaking top and bottom. Remove test joint F/ BOP stack R/U and test blinds 250/3,500. Remove IBOP valve F/ top drive. Remove from actuator. R/U spare on rig floor and test 250/3,500 psi. Valve leaked Locate a 3rd valve and test 250/3,500 psi test good. Lay down good double valve and begin to install actuator. 0 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 07/03/2018 - Tuesday Tesco double valve tested good. Mate up actuator to the double valve, install in top drive. Test [BOP to verify the actuator timing was correct. Call out AOGCC Inspector. Line up #1 pump through bleeder choke on rig floor. Maintain 2,100 psi 90 spm, pump 600 bbls, observed leak on fluid end caps. Notify Rig Superintendent. Rig up to test BOPE. Shell test. Perform initial BOPE test with AOGCC Inspector. BLM Rep waived witness. Test all valves #1 to #13 250 low, 3,500 psi high charted for 10 mins each. Test with 2-7/8" test joint. UPR's, LPR's, Blinds, Annular tested to 250 psi low, 3,500 psi high. All test held for 10 mins charted. Conducted accumulator draw down, super choke and manual choke pressure test. Ran in the manual locks on the blind rams for the Inspector to witness. No failures. Lay down test joint. Tear down pump #1, replace one end cap, rebuild pump, and prepare for load test. Cont. rigging down BOPE test Equip. Cont. working on MP #1 fluid ends. Replaced valves, seats and liner gaskets. Pull test port blank sub from liner hanger. Drain stack and make up Tee bar to TWC. Fill and test hole fill pump. Pull TWC and replace with BPV. Clean and clear rig floor of valves and XO's. Install IBOP clamps on top drive. SIMOPS Cont. working on MP #1. PJSM for test mud pumps. Perform high press. Test on Mud Pump #2, 4" stand pipe valve and mezzanine kill valve at 60 SPM 3,450 psi. Stand pipe and mezzanine valve passed. Mud Pump #2 1 & 3 fluid ends liner and cap end leaked. Perform press. Test on Mud Pump #1 at 60 SPM, pump motor started stalling out at 2,450-2,500 psi. Increased rate to 70 SPM and pump motor started stalling out at 2,700-3,050 psi. Fluid ends started leaking. Fluid ends 1 &3 liner and cap ends leaked. Fluid end 2 was just the cap end. Discussed further options with town. Decision was made to replace fluid ends on Mud Pump #2. Prep and disassemble all three fluid ends on Mud Pump #2. SIMOPS Stage 2-7/8" handling Equip. to rig floor. Install 3-1/2" Tubing elevators on Top Drive for landing joint. Pump up Top Drive compensators. Install 1502 cap w/ Whitey valve on IA, IA is static. 07/04/2018 - Wednesday Continue to tear down mud pump #2 fluid end. Remove suction and discharge lines, remove all swabs and liners. Remove all caps and pump rods, Remove all seats out of pods. Remove all studs from pods. Cleaned and inspected the studs. Wire wheel all parts of MP that will go back together. Sent one hand to Kenai yard to pull suction caps and squirrel cages from spare pump. SIMOPS: Mechanic replaced electronic and throttle control valve on MP#1 engine. Test ran vacuum degasser, replace air boot, retest, good. Electrician installed PA system. Electrician installed receptacle for MPD system. Adjust top drive torque tube. Check fall arrest in crown. SIMOPS: Thread chase all holes on new/rebuilt pods, clean off paint around seals, mount pod #1 on MP #2, make up bolts prepare pod #2. Cont. working on MP 42 installing fluid ends and thread rings. Torqued all studs to proper specs all witnessed by Toolpusher. Installed seats, valves, liners, 5" swabs squirrel cages and bull plugs with light grease on seals only. Hammer on all caps. Found damaged thread on discharge pod #1.Working on chasing threads. SIMOPS Install SRL at Derrick board. Clean and organize tool room. Connect hoses for SPP in Choke House. Clean up Choke House. Work on hanging fast descent device in Derrick and Geronimo line. Fuel on Hand 1,950, Fuel Used 290. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 50-133-20293-00 1 176-056 1 6/10/18 7/11/18 Daily Operations: 07/05/2018 - Thursday Continue to put MP #2 back together. Mount pulsation dampner. Torque all bolts to specification directed by rig mechanic. Work complete. Inspect pump. Put away tools. Remove locks from lock out tag out. Pressure test both pumps. Fluid pack lines. Pump through MP#1, 90 spm, 3,000 psi, ran smooth, and the engine was stable. Still leaking at cap end and past liner seal when viewed below rod wash. Line up to MP#2. Pump 90 spm, 3,000 psi. Observed fluid coming out of pod #1, coming out of the tattle tail. This pod had a blemish that we had seen when going in. The mechanic placed some permagasket in the gap, we waited 45 mins and the pump was tested to 1,500 psi. Very slight leak. Pick up landing joint. Set aside. Pull BPV. Make up U in hangar 10 turns. Screw in top drive torque to 19K. Back out ULDS. Pick up 7 feet observed string weight pop free when 90K was reached, pull up to 140K up, 80% of string pull rating. No movement. Begin to work string. Call Pollard to alert them that we might need to cut tubing. Work pipe, pressure up to 500 psi to 2,000 psi to attempt to gain some flow. Pulled to 150K max, down weight was 90. No movement. 18 feet of stretch. Pollard arrive on location 1800 hrs. Rig up to run E -Line. Mobilize Pollard Wireline to cut tubing. Prep and test 4.5" CDS40 FOV low 250 psi, high 3,500 psi. Monitor well during testing and well started a very slight flow. R/D test Equip. Started top filling with the hole fill pump to displace oil cap. Start timing flow rate at 1 bph and reduced down to 0.25 bph after 15 Min. Make up FOV, X/O and Pump in sub for E -Line. Re land Hanger and RILDS. SIMOPS Pollard spot Equip. PJSM W/ all parties for E -Line. M/U 5' 54# WB 1.6875", CCL 2.0 OD RIH for gauge run to 10,408' ELM. POOH L/D tools. P/U M/U CIPB 2.24" OD, Stroker, CCL, 5' WB. RIH, perform correlation witnessed by Co Rep onsite. Set CIBP top at 10,362' ELM (10,317' tally). Visual indication line jump and 140# loss on weight indicator. POOH L/D Tools. BOLDS and P/U 5K in tension. M/U 6" Jet Cutter, 1' 6" Shock Sub, 2' Centralizer, 5' WB, CCL. RIH and correlate witnessed by Co Rep. Shot jet cutter at 10,292' ELM (10,247' tally). Visual surface indication 80# line jump. L/D E -Line tools and sheaves. Attempt to pull tubing. Pull 120K and attempt to Circ. Down tubing. Pressured up to 2,400 psi, shut down and bled off. Filled annular with 1.6 bbl H2O. Cont. to work Pipe. 11 V - , Ir to 1 J c WY Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 1 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 Daily Operations: 07/06/2018 - Friday Lay down Pollard E -Line. Pick up and attempt to pull free, pull up to 155K 95% of tubing rating, pressure up to 2,200 psi, pressure bled down to 800 psi, keep working pipe and trying to establish flow. No success. Prejob with Pollard crew for free point run. Hang sheave on Driller side pad eye in derrick, remove drilling bails, install long bails, rig up with FOSV,XO, to Pollard. Calculate stuck point with stretch. Stuck @ 10,300'. Rig up Pollard E -line. Pick up pump in sub with Y -block and pack off. Pick up 15' CDS 40 pup, place FOSV on top, XO to NC 50. Move sheave twice to get the correct angle and height for the Y -block., and working the pipe. Begin E -line operations. E -line down to 8,150'. P/U to GLM @ 8,018 ft. plus 2 jts. measured 100% free. P/U fr 85K to 100K to calibrate. RIH drop through depth of cut, no resistance, cut had clear signature, measure stretch @ 10,202' 30% free, 10,027' 50% free, 9,912' 70% free, 9,818' 80% free, re -confirm 100 %free @ 8,018'. POOH forjet cutting tool. POOH with E -line, lay down locator tool, pick up jet cutting tool. Pollard E -Line. RIH W/ 5' WB, CCL, Cent., Shot Sub and Jet Cutter 5'6" Center CCL to Jet Cutter. Set cutter at 9.996' ELM. Correlation witnessed by DSM. Pull to 100K string weight and shot Jet Cutter. Visual indication on E -Line 100# line jump and lost 25K in string weight on rig floor. Kick while wireline drill. PJSM w/ Pollard. Rig down E -Line, long bails, install drilling bails, screw in top drive. Pollard released. Pull on tubing to ensure pipe was free 68K on weight indicator. Pump down tubing and was able to see returns at surface. Closed Annular and lined up to closed choke to check for Press. Zero. Open choke and through Gas Buster at 92 GPM, 395 psi. Increased rate to 140 GPM 800 psi. Shut down pumps and close in super choke and monitor Press. Zero. Open choke and monitor well through Gas Buster for 10 Min. no flow. Open well up and monitor well with hole fills pump. SIMOPS stage and R/U Weatherford and Pollard tools and Equip. Have PJSM W/ all parties for pulling tubing. Drain the stack. Pull Hanger to rig floor and terminate Cap line. L/D Hanger and C/O elevators. 07/07/2018 -Saturday Lay down five 2.875" L-80 EUE 6.5# pup joints, 2',4',6',8' and one 10'. Remove 7 steelbands. Remove pups from floor. Rig up air slips, monitor well on TT. Secure 3/8" control line with sash cord over the sheave in derrick. Begin laying down joints of 2.875" L-80 EUE 6.5# tubing with Weatherford tongs, and Pollard spooler. Remove steel bans off each joint. Good fill. Lay down fr jt #1 to jt. #85. Depth fr 9996' to 7327'. Began to see minor pitting @ joint #59 out, photos on the 0 drive. Work on skate, bring over long bails and install, haul first 85 jts to Pad 23-33. Continue to lay down 2.875" L-80 6.5# EUE tubing from jt #85 to jt#150. 7327' to 5300'. Pitting stopped around joint #90. (Note: pitting observed from 1852' MD to 2826' MD). Good hole fill. Continue to lay down 2.875" L-80 6.5# EUE tubing from jt #150 to jt#313. 5,300' to 9,996'. At Joint 310 SS 3/8" Cap Line was broke. Total of 313 Joints, 2 GLM, 6 Pups, Hanger and 322 SS bands recovered from well. Estimated 90' of Cap Line and 2 SS bands were not recovered. Good hole fill. Clean and clear rig floor of Weatherford and Pollard handling Equip. SIMOPS Spot Pollard E -Line and prep Equip. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 50-133-20293-00 1 176-056 1 6/10/18 7/11/18 Daily Operations: 07/08/2018 -Sunday Lay down Weatherford 2.875" elevators, P/U 4%" elevators. PJSM W/ Pollard and crew. Rig up Pollard. Run #1 - 8.20" OD gauge ring . Tag fill @ 9,948' hard 3x's. Contact AOGCC as to our new CIBP depth. POOH and L/D gauge ring. Pick up CIBP, Run #2, 7.71" OD. Set P 9,948'. POOH for Run #3 , dump bail 33 gals of 17ppg cement dump on top of CIBP @ 9,946'. POOH for Run #4, dump bail 38 gals of 17ppg cement, POOH for Run #5, dump bail 38 gals of 17ppg cement. TOC estimated @ 9,911' MD. 2.56 bbls total cement laid in hole. Rig up to test casing Test ,casingto ,5Q0_piLcharied for 30_ mins. Good test held 2,580 psi. RIH with Baker Cl bQtt4. QLplug,..f,Z78' top, correlate 3 x's, set 5 feet above collar, good setting indication. Picked up and set down twice to verify plug was set. POOH Pollard E -Line running tools. R/D Pollard tools and Equip. Release from location. PJSM W/ all parties for HP Testing. R/U to test 9-5/8" Csg and Baker Plug. Pressure up to 3,500 psi for 30 Min on chart. Good Test. R/D test Equip. Blow down Kill Line. Drain stack and set test plug. PJSM C/O Upper and Lower pipe rams to 4.5" solid body rams. SIMOPS C/O Koomey hoses to fire rated hoses. Disconnect lines from stack and purge air from system. Hook lines back up to BOPE. R/U to test rams. Function test Annular, all rams and HCR Kill & Choke. Fill stack with H2O. Test Upper, Lower 4.5" Pipe Rams, 4.5" FOSV and 4.5" Dart Valve. Rig down test Equip and lay down test joint. 07/09/2018 - Monday Pull test joint. Drain stack. Install 8.875" ID wear bushing. Lightly set 4 lock downs. L/D test joint and test plug running tool. Remove long bails, install drilling bails. Prepare to pick up BHA#1, Baker mills. 8%" window mill / 8.38" lower mill / flex pup jt. / 8%" upper mill. / float / XO / 5 jts HWDP / XO /jars / XO / 13 HWDP. OD ID and strap all tools. rabbit with 2.2 ID drift. Single in the hole with 37# CDS 40 HWDP. from 27' to 183'. SIMOPS: Quadco tech on location calibrated all gauges. We emptied pits 1,2,3, pill pit, hauled off. Build 300 more barrels of 9.5 ppg 6% PHPA drilling mud. Hydraulic leak at end of catwalk. JIC fitting had come free. Crew responded and cleaned up the spill, which was into the handiberm herculite containment area. Company Man contacted Hilcorp Environmental. The equipment was fixed and we returned to work. Pick up Weatherford jars, single in with CDS 40 HWDP from 215' to 515'. Continue to build more drilling fluid. Service top drive, and iron rough neck. Trip in with last two HWDP. Fill pipe and calibrate connection torque limit and drilling torque limit on the top drive. MI Swaco on location rigging up MPD hardline. TIH picking up singles of CDS 40 DP off the skate. from 616' to 1,235'. Load 20 jts at a time on the rack, tally and pick up, rabbit each joint. torque to 21K ft/lbs. TIH picking up singles of CDS 40 DP off the skate. from 1,235' to 5,950'. Load 20 jts at a time on the rack, tally and pick up, rabbit each joint. torque to 21K ft/lbs. Filling every 20 joints. SIMOPS Build 6% PHPA, Prep and work on plumbing for MPD W/ MI Swaco. l iet (i? Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 CTU/Rig 169 50-133-20293-00 1 176-056 6/10/18 1 7/11/18 07/10/2018 -Tuesday Filled pipe at 6,196', cont to single in to 6,281' where we tagged top of CIBP. PU 5' and MU topdrive. CBU one time with both pumps at 5.5 bpm. Held PJSM on mud displacement, lined up and displaced well to 6% KCL mud at 9.5 ppg/80 vis. Swaco MPD Reps assembled orbit valves on MPD head. Calibrated mud pump stroke counters, mix dry job, troubleshoot crown saver. Driller accidently actuated emergency crown saver on dash panel, pumped dry job. L/D single jnt, POOH racking back in derrick from 6,255' to surface. Baker Rep on site and inspected/chased bolt hole in starter mill. Test ran shear bolt with no problem. Racked stand back. Make up test joint pull wear bushing, set test plug . Make up TIW and dart valve to test joint, fill stack and all test lines. Perform Shell test to 3,500 psi test good. Begin tear down of #1 mud pump fluid ends. Perform BOP test with AOGCC and BLM inspectors. Test LEL and H2s alarm systems all passed. Test Annular Pipe and blind rams 250/3,500 5 min hold. Test TIW, IBOP, Dart and floor safety valves. Test all choke manifold valves. Perform accumulator draw down test 200psi recovery in 15 seconds full system pressure in 91 seconds. Manual choke failed, remove and replace manual choke valve and retest 250/3500 10 min test as per BLM regulations. Pull test plug, set wear bushing, R/D test joint, cont prepping mud pump #1 for pod changes. 07/11/2018 - Wednesday Cont prep work on pump #1 for pod changes, blow down choke line to poorboy degasser, make service break on dart valve for mechanic rebuild. Remove flow line, flow riser, air boot section and drip pan. Shut down and bled off Koomey. Mechanic rebuilt dart valve. Torqued service break on rig floor. Held PJSM with rig crew, RU long slings off topdrive, RU winch and sheave for tail in, picked MPD head up over annular. Installed bolts, landed MPD head. Lined up same for flowline to shakers and bolted up. Chained off stack 4 ways. Pulled blank off top of head, eased in hole one stand DP to check pipe center throughout travel of torque tube, racked stand back, re -installed blank. RU fillup line to MPD. Start re- assembly of mud pump #1 fluid end, Swaco RU airlines to orbit valve actuators, RU hardline to poorboy degasser with HP valve and "T" to tie in rig to degasser. Welders on location fabricating 6" flowline from MPD to possum belly, making centrifugal shaft guards and larger opening in rig choke house wall for SWACO MPD system. Mechanic replaced 1/2" hoses in Koomey room with 1/2" stainless steel lines. Welders cont flowline work/install of hammer seal on possum belly, Pason rep on site to install flow paddle (modified to fit 6" flowline). Got approval to proceed with well work from AOGCC Rep Jim Regg at 21:10 (pertaining to hoses in Koomey room). Torque bolts on pods, pulsation dampener, discharge manifold and discharge line on pump #1. Install new line, off drillers side tugger, completed flow line fabrication. Finished assembly of pump #1. Make up test joint pull wear bushing set test plug. Open IA, test MPD flanges, valves, piping and head at 250/1,000 psi, Good test. Pull test plug, set wear bushing, R/D test joint, close IA valve. Latch up on mill assembly (stood back), install and orient UBHO sub to starter mill. PU 9-5/8" gen-3 whipstock. Anchor set up with 3 screws at 19K shear value. Bolt whipstock to starter mill. Bolt shear value = 45K. Hilcorp Energy Company Composite Report Well Name: SRF SCU 344-33 (SCU 33-33 ST) Field: Swanson River County/State: Kenai, Alaska i (LAT/LONG): avation (RKB): 18 API #: 50-133-20293-01-00 Spud Date: 7/13/2018 Job Name: 1812067D SCU 344-33 Drilling Contractor Rig 169 AFE #: AFE $: 7,12/2018 MU 9 5/8" Gen 2 Whipstock with 45K shear bolt to starter mill, anchor set up with 3 screws and a 19K shear value.;TIH slowly from 21' to 6219' filling pipe every 15 stands. At 6219' up wt 119K, dwn wt 119K. MU topdrive.;Fill pipe and cont to circ at 113 gpm-220 psi while RU Pollard a -line and Gyro Data tool string. Mud still cold but staying on shakers at this pump rate.;RIH with gyro tool on a -line down to UBHO sub at 6170'. Seat #1 = 218`, Seat #2 = 215°, Seat #3 = 213°. Rotated string. Seat #4 = 38°. Worked pipe. Seat #5 = 39% Final survey = 38.24°.;LD Gyro Data tool string, RD Pollard a -line and released both.;PU single in hole from 6219' to 6281', up 119K, dwn wt 119K. Tag up on top of bridgeplug. Set down 20K and engage trip anchor, PU and pulled 10K over to verify anchor set. SO and set down 40K to shear bolt and release whipstock. POOH one stand, ran stand through Swaco MPD bearing and racked;back. Pulled two more stands and racked back. PU singled in hole 6 jnts. BHA length now 551.96' after setting whipstock. MU topdrive on drill string.;Pump through choke lines to clean and \ clear piping and poorboy degasser. Continue to circulate at 47spm 2.7 bbls min. Increase to 57spm 3.2 bbls min circulation rate limited due to mud loss over shakers.;Continue to shear mud at 3.7 bbls min . Change out 3 screens from 120 to 100. Increase Pump rate to 95spm 5.48bbls min. Pump rate @ 142spm 8.1 bbls in 675psi. Change all shaker screens to 100. Pump rate @ 180spm 10.3bbls min.;Begin Milling window at 6259. Up Wt 110 Dn Wt. 110 , Rt. Wt. 110, T�700fp. 90rpm. 435 gpm-882 psi Mill window frpm 6259' to 6266' md. Have recovered 139 lbs metal thus far. Started seeing cement at 6263'. '711"t( LI) 4 7LYJ STATE OF ALASKA_ Reviewed By: -7/1q, OIL AND GAS CONSERVATION COMMISSION P.I. Suprv. ► y— BOPE Test Report for: SOLDOTNA CK UNIT 33-33 Comm Contractor/Rig No.: Hilcorp 169 PTD#: 1760560 DATE: 7/11/2018 Inspector Guy Cook Insp Source Operator: HILCORP ALASKA LLC Operator Rep: Rance Peterson Rig Rep: John Nicholoson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopGDC180711092103 Rams: Annular: Valves: MASP: 318-195 Type Test: WKLY 250/3500 250/3500 - 250/3500 1480 — Related Insp No: MISC.INSPECTIONS: BOP STACK: P/F Location Gen.: P Housekeeping: P _ PTD On Location P ' Standing Order Posted P Well Sign P Drl. Rig _ P Hazard Sec. P Misc NA TEST DATA MUD SYSTEM: Visual Alarm Trip Tank P - P Pit Level Indicators v n Flow Indicator Meth Gas Detector H2S Gas Detector MS Misc Y '_ Y --P P P P -NA NA ACCUMULATOR SYSTEM: BOP STACK: Time/Pressure P/F System Pressure 3000 P . Pressure After Closure 1550 P 200 PSI Attained 15 P Full Pressure Attained 91 P ' Blind Switch Covers: All Stations - P Nitgn. Bottles (avg): 4na,2625 -_P " ACC Misc 1 F FLOOR SAFTY VALVES: BOP STACK: Quantity P/F E Quantity Size P/F Upper Kelly — 1 P, Stripper 0 NA Lower Kelly 1 P "-' Annular Preventer 1 11" 5000 P Ball Type _ 1 P #1 Rams 1 4.5" Solids " P " Inside BOP 1 P `' #2 Rams 1 " Blinds P ' FSV Misc 0 NA #3 Rams 1 -'-4.5" Solids . P #4 Rams — 0 _ _ NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 - P, HCR Valves 2 3 1/8" 2 1/16"- P Kill Line Valves 2 ------- 2 1/16" 5000 - P ----- �' Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 13 P Manual Chokes 1 FP_ Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 2 -' Test Results Test Time 9 Remarks: 4.5" test joint used. Had the accumulator system pressure set to 3000 psi minimum as it was at 2950. BLM inspector Allie Schoessler was on site for the BOP test. The manual choke failed the initial and was swapped out for another choke and passed retest. The hoses from the nitrogen bottles an e c armbottles to the accumulator were not fire rated. To be replaced after I leave location. The rest of the hydraulic hoses that were not fire rated during the last witnessed test have been swapped out for fire rated hoses. 1 _ SCANNED AUG 0 6 2018 Regg, James B (DOA) From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Wednesday, July 11, 2018 8:53 PM To: Regg, James B (DOA); Cook, Guy D (DOA) Cc: Mike Leslie; Monty Myers Subject: Hilcorp 169 Koomey Bottle Bank Hose Changes Attachments: 1_Ajpg; 1_Bjpg; 2_Ajpg; 2_Bjpg; 3_A jpg; 3_Bjpg; 4_A jpg; 4_B jpg; 5_A jpg; 5_Bjpg; 6 -Ajpg; 6-BJPg Jim and Guy, we have changed out those %" hoses with %:" stainless steel tubing. Please see the attached photos. I will now finish up the state test form and note that we had a fail/pass on accumulator misc. Rance Pederson Drilling Foreman Soldotna Creek Unit 907-776-6776 Hilcorp Rig 169 — Accumulator System Hoses Attachment to AOGCC Inspection Report #bopGDC180711092103 Photos courtesy of Hilcorp; 7/11/2018 Hilcorp 169 — Replacement of Accumulator Hose Page 1 of 3 • s • Hilcorp 169 — Replacement of Accumulator Hose Page 2 of 3 I " 11 , " * 0 0 Hilcorp 169 — Replacement of Accumulator Hose Page 3 of 3 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: 7�11?� P.I. Supry BOPE Test Report for: SOLDOTNA CK UNIT 33-33 Comm Contractor/Rig No.: Hilcorp 169 Operator: HILCORP ALASKA LLC Type Operation: WRKOV Sundry No: Type Test: [NIT 318-195 MISC. INSPECTIONS: FLOOR SAFTY VALVES: Quantity P/F Upper Kelly 1- P Lower Kelly 1 P Ball Type 1 P___ ---__-_._._-------—- Inside BOP I P ' ------------------- FSV Misc 0 NA PTD#: 1760560 DATE: 7/3/2018 Operator Rep: Bobby Ingram Test Pressures: Rams: Annular: Valves: MASP: 250 / 3500 250 / 3500 ' 250 / 3500 - 1480 TEST DATA MUD SYSTEM: P/F Location Gen.: P Housekeeping: _ P__ PTD On Location P ' ding Order Posted P Well Sign P DO. Rig _P Hazard Sec. P ' Misc NA FLOOR SAFTY VALVES: Quantity P/F Upper Kelly 1- P Lower Kelly 1 P Ball Type 1 P___ ---__-_._._-------—- Inside BOP I P ' ------------------- FSV Misc 0 NA PTD#: 1760560 DATE: 7/3/2018 Operator Rep: Bobby Ingram Test Pressures: Rams: Annular: Valves: MASP: 250 / 3500 250 / 3500 ' 250 / 3500 - 1480 TEST DATA MUD SYSTEM: Visual Alarm Trip Tank __P P _ Pit Level Indicators P P " Flow Indicator P P ' Meth Gas Detector P P ' 112S Gas Detector P P ' MS Misc 0 NA Inspector Brian Bixby ' Rig Rep: Robert Wall Insp Source i Inspector Inspection No: bopBDB180706055347 Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 P Pressure After Closure 1600 P ' 200 PSI Attained 15 P ' Full Pressure Attained 89 P Blind Switch Covers: YES P ' Nitgn. Bottles (avg): _ 4g2875 P ACC Misc 1 F, BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 11" P #1 Rams 1 2 7/8" P #2 Rams _ 1 ---Blinds P #3 Rams 1 2 7/8 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" P ` HCR Valves 2 3 1/8, 2 1/16 - P Kill Line Valves _ 2 2 1/16_" - P Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 13 P - Manual Chokes I P " Hydraulic Chokes 1 P ' CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: I Test Results Test Time 7 Remarks: Tested all gas alarms and PVT's. Tested with 2 7/8" test joint. The fail on the Misc. Acc is the fire rated hoses which they have the OK to proceed with work but have them changed out prior to the start of Ifie--n—ex-Ewell. -714f, eo'c1 qpp\Kq-- a)-4i'vd SCANNED AUG 0 6.2o;8 0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, July 2, 2018 4:03 PM To: DOA AOGCC Prudhoe Bay Subject: Fwd: [EXTERNAL] Re: Fire rated hoses on Rig 169 Sent via the Samsung Galaxy S8 Active, an AT&T 4G LTE smartphone -------- Original message -------- From: "Rixse, Melvin G (DOA)" <melvin.rixse@alaska.gov> Date: 7/2/18 3:42 PM (GMT -09:00) To: Monty Myers <mmyers@hilcorp.com>, "Regg, James B (DOA)" <jim.regg@alaska.gov> Cc: Mike Leslie <gleslie@hilcorp.com>, Paul Mazzolini <pmazzolini@hilcorp.com>, "Bixby, Brian D (DOA)" <brian.bixby@alaska.gov>, "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov> Subject: RE: [EXTERNAL] Re: Fire rated hoses on Rig 169 Monty, AOGCC grant waiver so allow Hilcorp to proceed with well work on SCU 33-33, with the expectation that hoses will be changed prior to SCU 344-33. Please assure the fireproof hoses are ordered and install ASAP. Regarding the BOPE test on Rig 169: AOGCC will want to witness this test. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin. Rixse@alaska.gov). -----Original Message ----- From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, July 02, 2018 11:37 AM To: Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Mike Leslie <gleslie@hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp.com>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Bixby, Brian D (DOA) <brian.bixby@alaska.gov> Subject: Re: [EXTERNAL] Re: Fire rated hoses on Rig 169 Hilcorp would like to request a waiver to finish the work on this well SCU 33-33 and the sidetrack well SCU 344-33 prior to making the changes to the hoses. We feel that the firewall will sufficiently protect the accumulator and controls for this well. We also feel there is very little risk to life and environment on this well because of the BOP'S that are in place and tested. Secondarily the distance from the wellhead is approximately 60' to the accumulator room. By allowing us to proceed with work on this well, will allow us to gather the equipment needed to make the upgrades. Also, we were under the impression that the rig was in sufficient condition to appease the regulatory requirements since it has worked in this condition for 5 years and we are spending a lot of money on a daily basis. By shutting us down to change out the hoses will cause an inordinate amount of financial hardship for the economics of this well. Please advise if it is acceptable to push the hose change out to when we are rigging up on Beaver Creek 5, our next well. Monty M Myers 907.538.1168 On Jul 2, 2018, at 11:17 AM, Regg, James B (DOA) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov>> wrote: Hoses need to be changed. If AOGCC has missed this during previous inspections I apologize. Our interpretation of API Spec 16A is fire rated hoses from accumulator to BOP stack. Please also confirm that the choke and kill lines have no threaded connection Sent via the Samsung Galaxy S8 Active, an AT&T 4G LTE smartphone ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT INSPECT DATE 7/1/2018 AOGCC INSPECTOR Brian Bixby Rig Hilcorp 169 Rig Contractor Doyon Operator Hilcorp Alaska Well I SCU 33-33 Operation lWorkover BOP STACK CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line Working Pressure, W/H Flange P Working Pressure, BOP Stack P Annular Preventer P Pipe Rams P Blind Rams P Locking Devices, Rams P Stack Anchored P Choke Line P Kill Line P Targeted Turns P HCR Valve(s) P Manual Valves P Flange/Hub Connections P Drilling Spool Outlets P Flow Nipple P Control Lines P MISCELLANEOUS CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line PPE P Well Control Trained P Housekeeping P Well Control Plan P FAILURES: 2 AUG Q � P.I. Supv / /1 r i S $C '" Comm: Coil Tubing Unit? No Rig Representative Robert Wall Contractor Representative Bobby Ingram Permit to Drill # Inspection Location MUD SYSTEM Pit Fluid Measurement Flow Rate Sensor Mud Gas Separator Degasser Separator Bypass Gas Detectors Alarms Separate/Distinct Choke/Kill Line Connections Reserve Pits Trip Tank RIG FLOOR Kelly or TD Valves Floor Safety Valves Driller's Console Flow Monitor Flow Rate Indicator Pit Level Indicators Gauges Gas Detection Monitor Hydraulic Control Panel Kill Sheet Current CORRECT BY 1 176-056 1 r Sundry Approval # 318-195 Swanson River 0 0 0 0 fire -rated accumulator control lines before start next well f COMMENTS Gauges on Super Choke were replaced w/correct calibrated gauges; hoses from the accumulator to the roof of the room are not fire rated (replace before next well per Mel Rixse); Kill Sheet not yet fill out. 2018-0701 _Rig_H i (corp 169_SC U_33-33_bb rev. 10-04-17 • CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line P P P P P P P P NA P P P P P P P P P P NA 0 0 0 0 fire -rated accumulator control lines before start next well f COMMENTS Gauges on Super Choke were replaced w/correct calibrated gauges; hoses from the accumulator to the roof of the room are not fire rated (replace before next well per Mel Rixse); Kill Sheet not yet fill out. 2018-0701 _Rig_H i (corp 169_SC U_33-33_bb rev. 10-04-17 • • S Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,June 18, 2018 3:38 PM To: 'Taylor Nasse' Cc: Donna Ambruz; Chad Helgeson; Monty Myers Subject: RE: Hilcorp SCU 33-33 Sidetrack Prep Revision Sundry 318-195 (PTD 176-056) Taylor, Procedure changes are approved ...Variance also approved to have CIBP >50ft from perfs. Guy Schwartz Sr. Petroleum Engineer AOGCC JUN 2 0 LUIS 907-301-4533 cell S�r� 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it o you,contact Guy Schwartz at(907-793-1226) or(Guy_schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent: Monday,June 18, 2018 1:09 PM To:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Donna Ambruz<dambruz@hilcorp.com>; Chad Helgeson<chelgeson@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Subject: Hilcorp SCU 33-33 Sidetrack Prep Revision Sundry 318-195 (PTD 176-056) Hi Guy- Attached is the revision to the sundry procedure for SCU 33-33 for your approval per our phone conversation on Frida 6/15/18.These changes were needed due to not being able to keep cement across the open G Zone after two attemp to lay cement with coiled tubing per the original approved sundry. If these changes are acceptable, I will also note them on the RWO Sundry Revision Change form. Let me know if you have any questions or need additional information. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907) 903-0341 cell 1 i /� Well Prognosis(Rev.1) ft' ,v Well: SCU 33-33 llileorp Alaska,LL Date:6/18/2018 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Gas Lifted Oil Producer Leg: N/A Estimated Start Date: May 23rd, 2018 Rig: Saxon 169 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: —2,013 psi @ 10,352' TVD (Based on downhole gauges 2/5/16) Maximum Expected BHP: — 2,013 psi @ 10,352' TVD Max. Potential Surface Pressure: — 1,480 psi (Based on recent buildup @ surface) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic,but was plugged back to the Hemlock and completed in the H-5(tested gas),Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. In 2001 the well was worked over,perfed in the Tyonek G Zone,and a rod pump was installed. Rod pump,rods,and/or tubing change outs were completed in 2004, 2008, 2009 and 2011, 2013, &2014. In February 2016,the tubing was repaired and the casing was tested to 1,500psig.After the tubing was repaired, pressure at the surface began to build and a no-flow was not successful.In 2016 it was recompleted as a gas lifted producer. The purpose of this work/sundry is to plug back the existing open intervals and prep the well for a sidetrack. Notes Regarding Well bore Condition Well is currently shut-in and lower intervals are cemented.TOC at 10,505' MD. Coiled Tubing Procedure: 1. Submit 24 hr. witness notification to AOGCC via web base notification. 2. MIRU Coiled Tubing, PT BOPE to 250/4,500 psi. 3. Make up BHA. Stab on well and PT lubricator to 250/4,500 psi. 4. Rig up cement equipment. 5. RIH and tag top of fill at±10,673'. 6. Batch mix cement and begin pumping spacer and cement.As cement exits the nozzle, begin pulling up coiled tubing and lay cement to 10,367'. Once all cement has been placed, circulate any contaminated cement to surface. POOH. 7. Rig down Coiled Tubing. Slickline Procedure: 8. MIRU slickline, PT lubricator to 250 psi low/2,500 psi high. • • Well Prognosis(Rev.1) Well: SCU 33-33 Ilileor,Alaska,LI. Date:6/18/2018 10,367' MD. 10. RIH with kick-over tool and pull lower GLM at 10,259'. POOH and RDMO. Saxon#169 Procedure 13. MIRU Saxon#169 Rig. 14. Circulate 6%KCL/PW with hot oil truck. 15. Set BPV. ND Tree. 16. Notify AOGCC 24hrs in advance to conduct Rig Inspection. 17. NU BOPE. 18. Test BOPE to 250 psi Low/3,500 psi High,annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Notify AOGCC 24 hrs in advance of BOP test. c. Test VBR rams on 2-7/8"and 4-1/2"test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 19. L/D BOP test equipment. 20. Pump PW down tubing and casing to ensure well is dead. 21. Pull tubing hanger free,tubing and S-22 anchor out of seal assembly of Model "F-1" packer. 22. Pull tubing string(2-7/8"8RD)and lay down tubing. Number and label each joint. 23. Clean and clear floor. 24. Ensure well is full of fluid. 25. RU e-line. a. RIH with 9-5/8"CIBP and set at±10,315'(just above packer). Note: Hilcorp Alaska requests a variance from the requirement in 20 AAC 25.112(c)(1)(E)that requires the mechanical bridge plug to be set within 50'of the open perforations.Due to the location of the packer and tubing tail,the CIBP will be set just above the packer. b. Dump bail 35' of cement on top of CIBP(=2.5 bbls). c. Press test plug and casing to 2,500 psig for 30 minu' d. RIH with 9-5/8"CIBP and set at±6,279' (5'above a collar) 'or whipstock. 26. RD e-line. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** Attachments 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form • Soldotna Creek Unit Well SCU 33-33 H • • SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hilcorn Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm 20" - - - - Surface 90' del �20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 5-95 BTS i 8.681" Surface 6,295' 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,464' L13-3/8" JEWELRY DETAIL No. ' Depth iD OD Item CIBP "CIBP w/35'cement 3 10,321' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 4 10,427' 2.313" 3.679" X Landing Nipple ft 5 10,464' 2.441" 3.679" WL Entry Guide > a I i� ' I n ' 1 �� iE PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date i" X G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf Isolated ri,-"'' - G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf Isolated i I G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 Isolated TOC G lone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 Isolated 10,505' G-zone 10,512' 10,544' 10,510' 10,542' 32' Isolated HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf Isolated 1 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf Isolated H1 10,562' 10,588' 10560' 10,586' 26' Re-pert 2/20/86 Isolated H2 10,588' 10,602' 10586' 10,586' 14' :plated :U HI H2 10,592' 10,624' 14590' 10,622' 32' 4-5/8"Millennium 5spf Isolated H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf Isolated :i I H2 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 lsolatr. H3 10,638' 10,643' 14636' 14641' 5' 4-5/8"Millennium 5spf Isolated (1143 H3 14638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf Isolated H3 10,640' 10,645' 10,638' 10,643' 5' Re-pert 2/20/86 lsolote Tagged Fal ❑H4 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 2/12/16 H44HS H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10,673'SLM 144 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 Isolated '" :•' 145 H4 i 10,658' i 10,665' 10,656' 10,663' i 7' Isolated Junk @ 10,680' H5 10,670' 10,680' 10,668' 10,678' 10' violated 30-02-11 Corrected H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 Isolated measure 115 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 Isolated --- - - H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 Isolated -----_- 9-5/8„ TD=17,689' PBTD=11,138' MAX HOLE ANGLE=2 deg.@ 6,100' Downhole Revised:2/16/16 Updated by TWN 06-18-18 •tioF � 4A�� /7, s THE STA Alaska Oil and Chas �►-i-d`��, _ sKA of Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 Main: 907.279. 433 ®F ALAS' Fax: 907.276. 542 www.aogcc.alaska gov Chad Helgeson swapMAY 2 2 2018 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33-33 Permit to Drill Number: 176-056 Sundry Number: 318-195 Dear Mr. Helgeson: 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, itagc-* Hollis S. French Chair s, DATED this Z day of May, 2018. RBDMS MAY 2 21018 RECEPjED • • STATE OF ALASKA MAY 0 9 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdPwn El Suspend El Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Prog}am 0 Plug for Redrill ❑✓ • Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other:I 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory El Development Q• 176-056 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20293-00 7.If perforating: 8.Well Name and Number: ` S,f6 /k What Regulation or Conservation Order governs well spacing in this pool? N/A Soldotna Creek Unit(SCU)33-33 . Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990• Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs(MD): Junk(MD): 17,689' 17,660' - 10,680' 10,678' 1,480 psi N/A 10,680'(j'nk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor I I Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate I Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 i ' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,464' ' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker F-1 Production Packer/N/A 10,321'MD-10,319'TVD/NI/2i 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development Q • Service 0 14. Estimated Date for 15.Well Status after proposed work: 5/23/2018 Commencing Operations: OIL ❑ WINJ 0 WDSPL ❑ Suspended 0• 16.Verbal Approval: Date: GAS 0 WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse@hilcora.com I �� Contact Phone: 777-8354 Authorized Signature: rtiG:� , Date: Siei j/8 �/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,1 t 1116 Plug Integrity ❑ BOP Test li Mechanical Integrity Test 1:1 Location Clearance Other: 1F- 500 ros L 50( —7--e--;t. c3t. Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /O _,4 /0 APPROVED BY S /Ze I b Approved by: COMMISSIONER, THE COMMISSION Date: �`� 's ' RM, z 1g andSormandN Form 10-403 Revised 4/2017 Approved applicatio is aid oQIN.AL )M1 ' months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: SCU 33-33 Hilcora Alaska,LL Date:5/5/2018 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Gas Lifted Oil Producer Leg: N/A Estimated Start Date: May 23rd, 2018 Rig: Saxon 169 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,013 psi @ 10,352' TVD (Based on downhole gauges 2/5/16) Maximum Expected BHP: —2,013 psi @ 10,352' TVD Max. Potential Surface Pressure: — 1,480 psi (Based on recent buildup @ surface) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added thje H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with v a single packer completion. In 2001 the well was worked over, perfed in the Tyonek G Zone, and a rod pump was installed. Rod pump, rod , and/or tubing change outs were completed in 2004,2008,2009 and 2011,2013,&2014. In Feburary 2016,the tubin was repaired and the casing was tested to 1,500psig.After the tubing was repaired, pressure at the surface began t build and a no-flow was not successful. In 2016 it was recompleted as a gas lifted producer. The purpose of this work/sundry is to plug back the existing open intervals and prep the well for a sidetrack. v 5c .3444 4 33 Notes Regarding Wellbore Condition .2 4 " • Well is currently online flowing 26 BOPD, 55 BWPD, 330 MSCFD gas at 175 psig. J PFJ 1 Coder. . l9e co eGr 4..417 Acs rodiud < y7p0I/ �( Coiled Tubing Procedure: ch4I/01 Q Avg«jcr °f ye�f, P(�yy�1 7�,s wolf Ay a fears'', Tol I��fMrtd 1. Submit 24 hr.witness notification to AOGCC via web base notification. G lk" ("f64 'r/a i9 2. MIRU Coiled Tubing, PT BOPE to 250/4,500 psi. IrOM f Lt li ,/U� 3. Make up BHA. Stab on well and PT lubricator to 250/4,500 psi. l/7 4. Rig up cement equipment. 5. RIH and tag top of fill at±10,673'. 6. Batch mix cement and begin pumping spacer and cement.As cement exits the nozzle, begin pulling up coiled tubing and lay cement to 10,367'. Once all cement has been placed, circulate any contaminated cement to surface. POOH. 7. Rig down Coiled Tubing. Slickline Procedure: 0 8. MIRU slickline, PT lubricator to 250 psi low/2,500 psi high. 9. RIH and tag top of cement and record depth. ( ofj� 3 56IA" 1111 • • Well Prognosis Well: SCU 33-33 Hilcorp Alaska,LL Date:5/5/2018 a. If cement top is below 10,367', MU dump bailer and add cement to bring top to a min.of 10,367' MD. 10. RIH with kick-over tool and pull lower GLM at 10,259'. POOH and RDMO. 11. RU pump truck and circulate 6% KCL/PW by pumping down annulus and taking returns up tubing. 12. Close wing valve and pressure test cement plug and casing to,„1,5sig for 30 minutes./ .44_11 ,Z soli Saxon#169 Procedure , Zs" /P- cNr r 13. MIRU Saxon#169 Rig. 14. Circulate 6% KCL/PW by circulating down tubing and taking returns up annulus. 15. Set BPV. ND Tree. 16. Notify AOGCC 24hrs in advance to conduct Rig Inspection. 17. NU BOPE. 18. Test BOPE to 250 psi Low/3,500 psi High, annular to 250 psi Low/2,500 psi High (hold each PF ram/valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. 1./ ko b. Notify AOGCC 24 hrs in advance of BOP test. c. Test VBR rams on 2-7/8" and 4-1/2"test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 19. LID BOP test equipment. 20. Pump PW down tubing and casing to ensure well is dead. 21. Pull tubin anger free,tubing and S-22 anchor out of seal assembly of Model "F-1" packer. 22. Pull tubing string(2-7/8" 8RD) and lay down tubing. Number and label each joint. 23. Clean and clear floor. / 24. Ensure well is full of fluid. 25. RU e-line. a. RIH with 9-5/8" IBP an set at±6,279' (5' above a collar). 26. RD e-line. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** s ( ''P Attachments 14) `S iv 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic ��oD G'651 it 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form PA7 Soldotna Creek Unit II 0 III Well SCU 33-33 SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hacor»Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL Ong RKB:17'/New RKB:17.45' CASING DETAIL Size WT Grade Conn ID Top Btm L20" - - - - Surface 90' ° 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 5-95 BTS 8.681" Surface 6,295' 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,464' L �13-3/8" .SSC)1 ( •ll _rov e (qo ciV JEWELRY DETAIL 3 1 No. Depth ID OD Item 1 15' 2.441" 3.5" 3-1/2"Tubing Hanger 2 16' 3-1/2"x 2-7/8"Crossover 3 4,605' 2.441" 2.875" 2-7/8"SF0-1 GLM#3(Live Valve) g 4 _ 8,018' 2.441" 2.875" 2-7/8"SFO-1 GLM#2(Live Valve) @ 5 10,259' 2.441" 4.750" 2-7/8"SF0-1 GLM#1(w/Orifice) o' ri it 6 10,309' 2.441" 4.679" 2-7/8"Chemical Injection Mandrel(3/8"Control line to surface) " I 7 10,319' 2.441" 6.937" S-22 Snap Latch assembly(with seals) 8 10,321' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 9 10,427' 2.313" 3.679" X Landing Nipple 10 10,464' 2.441" 3.679" WL Entry Guide 161 SI NA 181 A 11 I,' r, PERFORATIONS �� E Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date 9 El G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/201 10 '=MD G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/201 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 • G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/200: H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/201 Zone HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/201' H1 10,562' 10,588' 10,560' 10,586' 26' Re perf2/20/86 1/29/197' H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/20W Hl H2 10,592' 10,624' 10,590' 10,621' 32' 4-5/8"Millennium 5spf 9/29/201 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/201 112 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf2/20/86 1/31/197' H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium5spf 9/29/201 II 3 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/201 H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/197' Tagged Fill •114 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/201 z/12/16 673'SL H4 H5 10,648' 10,679' 10,646' 10,677' 31' 4-5 8"Millennium 5s 10/2/201 10,673'6LM • 114/115 / / � 5spf H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/197' ' '•'•'•'•'•',H5 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/198. Junk@10,680' H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/198. 10-02-11 Corrected " H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/197' measure H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/197' _-_ _ H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/197 -- ----.- 9-5/8" TD=17,689' PBTD=11,138' MAX HOLE ANGLE=2 deg.@ 6,100' Downhole Revised:2/16/16 Updated by DMA 06-17-16 Soldotna Creek Unit Well SCU 33-33 II II-PROPOSED SCH EMATI Completion Ran:2/13/16 PTD: 176-056 Nikon)n Alaska-LTC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm Ael 20" - - - - Surface 90' �J0 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 5-95 BTS 8.681" Surface 6,295' 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,464' L 13 3/8" -2 -2 C (% -W‘-' Ko0 JEWELRY DETAIL No. Depth ID OD Item 1 6,279' 9-5/8"CIBP ❑1 2 10,321' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) I - - '-1 3 10,427' 2.313" 3.679" X Landing Nipple 0 4 10,464' 2.441" 3.679" WL Entry Guide c I 1;1',pD f L° �J �, . ;5 2 11. ® .E PERFORATIONS r Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date Status ❑ 3 ::::.:TOC• :: G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 Isolated G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 Isolated n :.:.10,367' :'• G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 Isolated G zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 Isolated G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 Isolated H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 Isc'lated G H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 Isolated Zone H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf2/20/86 1/29/1977 Isolated H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 Isolated E: : : : : : :::: H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 Isolated :ii Hl H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 Isolated : :I H2 H2 10,610' 10,628' 10,608' 10,626' 18' Re-pert 2/20/86 1/31/1977 Isolated H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Isolated ::::I H3 H3 10,638' 10,643' 10636' 10,641' S' 4-5/8"Millennium 5spf 10/2/2011 Isolated H3 10,640' 10,645' 10,638' 10,643' S' Re-pert 2/20/86 1/31/1977 Isolated Tagged Fill :::I H4 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium Sspf 9/29/2011 Isolated z673SLks, :: H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium5spf 10/2/2011 Isolated 10,673'SLM H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf2/20/86 1/31/1977 Isolated :::0HS H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 Isolated lank@10,680' H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 Isolated 10-02-11 Corrected H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf2/20/86 1/26/1977 Isolated measure H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;220 86 1/17/1977 I 1 d so ate i. -___ = H5 10,710' 10,712' 10,708' 10,710' 2' Re-pert 2/20/86 1/17/1977 Isolated 95/8" TD=17,689' PBTD=11,138' MAX HOLE ANGLE=2 deg.@ 6,100' Downhole Revised:2/16/16 Updated byTWN 05-08-18 • wanson River SCU 33-33 BOP 05/08/2018 fliknrp Alaska,IAA; Saxon 169 BOP stack I iii iii iii lit ill ilii di lit Li Model 6011i 11"-5000 (ti11 frt fain] Ill _ 1io - i -.- . -- To T-3 Energy rt H , `A 1 f Model 708214I H11"-5000 H El j �® I0 \ til ) / r ---4 : : Is? : UREIRIPLIHTX - 5 : i iI _ p Amidillier T-3 Energy H '0 Model7082 H --41--r-ft 11"-5000 I i---[- ):-- III III III Ill III III fit bill Inn • II • wanson River SCU 33-33 Ilil"r"rp Aka*.lit 01/13/2016 Swanson River Tubing hanger,Seaboard SCU 33-33 DCB tension,11 X 2 7/8 EUE 133/8 X95/8X27/8 lift and susp,w/ 2 1/2"type H BPV profile, 6''A Extended neck,3/8 control line Companion flange ,29/165MFEX 2 7/8 EUE 8rd box ni FilItl IP Valve,wing,WKM-M, - I / g Valve,wing,WKM-110 M, 0 2 1/16 5M FE,HWO, • a • i 2 1/16 5M FE,HWO, AA trim ° _ AA trim in in I. Riser spool 2 9/16 5M X 2 9/16 5M in " ill I"12n�.. H"I Valve,master,WKM-M, 2 9/16 5M FE,HWO,AA —- iiiligiii Adapter,Seaboard,11 5M FE Mir X 2 9/16 5M stdd,w/ 6%slick neck pocket and%2 _,_� , "" npt chemical injection port Tubing head,Cameron DCB-S,13 5/8 5M X .® R , m- 115M,w/2-2 1/16 Ifil 5M 111 SSO r. ii ici . = Le Valve,WKM-M,2 1/16 5M I �� • I _, I1 FE,HWO,AA trim I tO' _.�� QTY 2 Fr 1111 Cill �4 it ■ I Casing head,Cameron WF, 1 f 1 III CIW-F,2 1/16 5M FE, 13 5/8 SM X13 3/8 SOW, 1 ' ( , HWO,AA trim w/2-21/165M EFO 111111 I A v N I-.• ,L 0 0 � � p / > cc o Q — � & ■o § \ E 0 ■ .2 /< k0. 0. § / < — E ® of ) / § i k� f . \ CI < k / k0 � %T > = 2 cD It c � .§ a_ 2 —-- § .- M -0 CD ■ 3 \ �• � Z k k $CO %4 )>- E7 2 CL i � � � 0 / _ ƒ 0 Q / \ u e = E O a > co & n c0 as R 0 U O C CD CD 7 ? Jc < _ c n } / = o / eu a \ ) g U) _ »% § c § / / . 2 ¥ p 2 e = $ 0 Q > § � e ii o 0. EG 0 i < U) 0 0 0_ - Q � � E o _ Q. ■ 2 R e a a) 0 .0) a Q 2 .o a) ■ � Cl) 0 C1-1 ow / 2 — 0 2U k E cu -a E o & § co C e a 3 Cl) < < / 21 0 U) • • • Schwartz, Guy L (DOA) From: Taylor Nasse <tnasse@hilcorp.com> Sent: Tuesday, May 15, 2018 3:15 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson; Monty Myers Subject: SCU 33-33 Sundry to Plug for Redrill (PTD 176-056) Attachments: SCU 33-33 CBL.pdf Hi Guy- Attached is a snapshot of the original CBL for SCU 33-33 from above the top of cement at around 4,400' MD to below the location where we plan to sidetrack at around 6,270'. Looking at the log, it appears that we have cement at our sidetrack location as well as isolation both above and below. I'll see if I can get a hard copy of the full CBL printed out and sent over to you for your records,as well. Let me know if you have any questions or need additional information. Thanks, Taylor W.Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell 1 • • X 00 N .--I Thousand Cubic Feet of Gas ("MCF") per Month oo NI 0 or Gas-Oil Ratio 0 CO Lf1 0 0 0 0 0 0 OO O O N o 1 O o o O o o m ,4. -1.1 .-1 ,- .-I .-1m m [III °°e l l , III I i °e°�4 N' � ref t ° o a a O ° �7 0 „ 0 lD L11 O I CT 1441 a° -• u.»-�g° $°a a .._I °�4�°/' >1 $a O v r4 _. v I. O 8 G a a M a �4 cI N� 0 MI I I " I. 1111* I AIM 1...1111* _.) .. E M i , 111ls i 11 �>> 1 0 �I I— G 4 41111 0 HI • i o Z> SOON v w 0 LU t3 4�'P a 1 Y N �Q �`1. ao o ° �■' o w O _am J co aB aaa ..�'0 0 �� a 4 d 3_ 'a8 i�� r ■ • 0 I I aaaa�:i -41-1' ■N °0014 0 —• >. -g 1,,,,,,_ , , ,, , , .1011 III il _.: 'Ail o I r _11111!1 er yp :in 2 . o 111111111111111111111 3 Z a . 444 us�11111.t U 04 o. . ' O111 �� ll ! .._# 0 GG Oa. 4+ 11PC;1111 B I 0 O la�, '11101 0 0.�8 ° 0 4)O) a a ° �" i.ii X1111 ° ° 8° o ° CC e CL CC a U' I 0o J 2 08a. 6 IE R 4Pr -'o d Q -- - a a i 0, r • o ° • 2 a �� a 0. 0 .. r, o 0 O ,______ I4 li i s 0 0 0 0 0 0 !6r 4, 0 0 0 0 ai 0 0 o ri 0 0 .1 O .1 ri youo j _lad Ja4ej to siaLieg Jo q uow .iad HO}o sla.ueg • ! S Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or s-; 1...- ry "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial thenc. it / it on both copies of the Form 10-403 (AOGCC's and operator's copies). ��iv ✓ Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the"Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA ` AAA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Fracture Stimulate ❑ Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: Convert to Gas Lift 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 176-056 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20293-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)33-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: RECEIVED Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680(junk) feet JUN 1 7 2016 Effective Depth measured 10,680 feet Packer measured 10,321 feet GCC true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED ,IAN 0 9 201? True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,464'MD 10,462'ND Baker F-1 10,321'MD Packers and SSSV(type,measured and true vertical depth) Production Pkr 10,319'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2 442 43 125 140 Subsequent to operation: 17 _ 801 50 950 220 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory0 Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Li WAG Li GINJ Li SUSP Li SPLUG Li 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-238 Contact Joe Kaiser-777-8393 Email jkaiserahilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature .�Z ��/� Phone 907-777-8405 Date oli t �i L. Form 10-404 Revised 5/2015 RBDMS VV JUi1 L 1 2016 6/ j Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 Moncla 401 50-133-20293-00 176-056 5/16/16 5/23/16 Daily Operations: 05/16/2016-Monday Mobe Moncla 401 from Kenai to SCU 33-33. Laid containment and MIRU Moncla 401 and associated equipment. 05/17/2016-Tuesday Watched HAK orientation video with Moncla crew,held PJSM and discussed job to be performed. RU pump,gas buster and choke manifold,MU hose to tbg side. Filled rig pit with PW. Circulated gas buster full. Continued spotting equipment and sealing in containment. SITP 400psi and bled down to gas buster/rig pit. RU floor and prep rig to pull rods. Laid containment to LD rod string. With the tbg bled off,latched the polish rod and backed off the stuffing box.PU 5K over,unseated the rod pump and LD the polish rod. MU the stripper head and pumped 60 bbls of hot water down tbg to clean the rods string. POOH,LD the rod completion 4 pony rods,120 1"rods,282 7/8"rods,16 1-1/2"sinker rods and 1-3/4"rod pump. Loaded rod string to back haul to Tubo. Secured well and cleaned work areas. SDFN. 05/18/2016-Wednesday Held PJSM and discussed daily ops. RD rig floor and tied back block.MU hoses to tbg and csg.SITP Opsi,SICP 1,100psi. Bled off slow thru choke to the gas buster,bled down to 200psi.Filled pit with PW.Started pumping down tbg 3bpm with csg open to pit. Returns gas. Pumped 350bbls,could not break circulation.SD pump and monitored well CSG and tbg on vacuum.Set BPV and ND PT.Install blanking sub.NU 11"5M BOP stack,connected the hydr control lines from the Koomey unit to annular,HCR valves and rams.MU the kill and ck lines. RU floor,handrails and stairs.Secured well and SDFN. 05/19/2016-Thursday Held PJSM,disussed daily activities.Finished RU wind walls,RU tongs and PU/MU 2-7/8"test jt. Functioned BOP's and check pre- charge on bottles.Circulated stack full and shell tested BOPE 250-3,500psi.Had several body leaks to repair on stack.Tested BOPE as follows:gas detection,pressure tested annular 250-3,SOOpsi,rams 250-3,500psi,valves 250-3,500psi. Performed Koomey drawdown test.1 F/P recorded,pit H2S sensor failed on a high,recal and retested good. BOPE test witnessed by Brian Bixby. Prep rig floor to POOH.SITP Opsi,SICP 100psi.Bled off csg to gas buster and pumped 120bbls down csg.Monitored csg and tbg on vac.Pulled BPV,MU 2-7/8"lifting joint.PU 75,000K(20K over string wieght)and turned pipe 1/4 turn to the left.Dropped out of parent bowl to string weight at 55,000K.Made 13 turns to the right and released anchor latch assembly. PU and jayed back into hanger and backed out lock down pins.Unseated tbg hanger and pulled to rig floor and LD same.Secured well and SDFN. 05/20/2016-Friday Held PJSM and discussed daily activities SITP Opsi,SICP 10psi.Bled off csg to gas buster. Pumped 60 bbls down csg.Monitored well on vac.Prepped rig to pull completion.POOH w/165 stands of 2-7/8"EUE 8rd and 1 single.LD 2 bad jts of 2-7/8"8rd,depth indicator sub,S-22 latch assembly,seating nipple,slotted sub and 2 jts of 4-1/2"IBT.Tallied stands OOH and displaced lObbls of PW every 20 stands. Off loaded S-22 snap latch assembly with seals,3 GLM,X-nipple and 1 chemical injection mandrel.MIRU Pollard truck to run the control line.RU shives and treaded control line thru shives.Prepped rig to run in hole with GL completion. 05/21/2016-Saturday Held PJSM w/Moncla Crew and Pollard Crew.Discussed daily activities to be performed SICP Opsi.Opened well and monitored. Tallied all jewelry and TIH with gas lift completion and 3/8"control line(banded every jt).Tagged packer and spaced out completion.PU/MU landing jt and control line to hanger and tested to 3,000psi.Landed completion with up weight 53K,slack-off 51K,hanger weight 50K.Ran in lock down screws.Depths are as follows:hanger,3 pup jt,xo,143 jts of 2-7/8"8rd,pup jt,GLM @ 4,494',pup jt,108 jts of 2-7/8"8rd,pup jt, GLM @ 8,007',pup jt,70 jts of 2-7/8"8rd,pup jt,GLM @ 10,248',pup jt,chem inj mandrel @ 10,297',pup jt,snap latch assembly @ 10,308',3 jts of 2-7/8"8rd,pup jt,x-nipple @ 10,416'w/RHCP,pup jt,1 jt of 2 7/8"8rd and WLEG(EOT)@ 10,454'. Total of 343 3/4"SS,bands droped ball and MU TIW valve. Cleaned work areas.Secured well and SDFN. 05/22/2016-Sunday Held PJSM.Lined up manifold and connected Kelly hoses to pump down csg and take returns up tbg.With pit full started pumping at 3bpm.Waited on vac truck to round trip 70 bbls at a time.After 650 bbls pumped well would not jug up.Monitored well static. With well static latched back onto the completion string.Picked up 4' and seal assembly was not latched in.Pulled hanger to surface,BO the tbg hanger and added a 2'pup.Spliced control line and tested to 3,000psi,good test.MU the tbg hanger and slacked off tagged packer with seal assembly and landed with 4K in compression.MU Kelly hose and lined manifold to rev circulated.Rolled pump over at 3bpm,pumped 220bbls and broke circulation.Returns oil and gas.Continued circulating until returns cleaned up and shut down pump.Lined manifold to pump down the tbg with csg open to pit.Rolled pump over and pressured up on tbg to 3,000psi,charted for 30mins,good tbg test.Lined manifold to pump down csg and SI tbg.Rolled pump over and pressured up on csg/tbg to 3,000psi,charted for 30mins,good csg test.Bled off pressure. Secured well and SDFN. 05/23/2016-Monday Held PJSM.BO/LD the landing jt and TWI valve.Set the BPV,disconnected Koomey hose and the kill/ck lines.ND the BOP stack, NU the production tree and orientated for GL hook-up.Tested tree to 5,000psi,good test.Pulled BPV.Cleaned pit,wellhead and rota flex unit.LD the derrick and RDMO Moncla 401 and associated equipment.Pickup containment and cleaned location. Mobe carrier to SCU 41-08.MIRU Pollard SL.Pulled prong and plug.RDMO SL. II • • Soldotna Creek Unit Well SCU 33-33 SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hilcoro Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm j1 21 20" Surface 90' 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380 9-5/8" 47 5 95 BTS 8.681" Surface 6,295' 53.5 5 95 BTS 8.535" 6,295' 11,350 TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,464' 13-3/8" JEWELRY DETAIL I 3 I b No. Depth ID OD Item 1 15' 2.441" 3.5" 3-1/2"Tubing Hanger 2 16' 3-1/2"x 2-7/8"Crossover 3 4,605' 2.441" 2.875" 2-7/8"SF0-1 GLM#3(Live Valve) 4 8,018' 2.441" 2.875" 2-7/8"SF0-1 GLM#2(Live Valve) U 5 10,259' 2.441" 4.750" 2-7/8"SF0-1 GLM#1(w/Orifice) 'c E 6 10,309' 2.441" 4.679" 2-7/8"Chemical Injection Mandrel(3/8"Control line to surface) I 7 10,319' 2.441" 6.937" S-22 Snap Latch assembly(with seals) 8 10,321' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 9 10,427' 2.313" 3.679" X Landing Nipple 10 10,464' 2.441" 3.679" WL Entry Guide n E El III n q �.t PERFORATIONS 1� Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date 9 El G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 Es _ G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 G-Zone H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-pert 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 R HI H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 H2 10,610' 10,628' 10,608' 10,626' 18' Re-pert 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 ❑H3 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 Tagged Fill ❑114 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 z673'S6 H4 H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5s 10/2/2011 10,673'6LM ` 0 H4/H5 / / / 5spf \\'1 H4 10,651' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 ;: l:1115 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 Junk@10,680'i;:i: *i:i* :: H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 10-02-11 Corrected H5 10,680' 10,702' 10,678' 10,700' 22' Re-pert 2/20/86 1/26/1977 measure H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re-pert 2/20/86 1/17/1977 A -i9-„8" TD=17,689' PBTD=11,138' MAX HOLE ANGLE=2 deg.@ 6,100' Downhole Revised:2/16/16 Updated by DMA 06-17-16 OF Tke, • y 1.11/j, 4\ THE STATE Alaska Oil and Gas z...= of® ®® cc TTA Conservation Commission• 333 West Seventh Avenue11' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC SCAMS j;; 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33-33 Permit to Drill Number: 176-056 Sundry Number: 316-238 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, LCath1 /°904 — Cathy y '. Foerster Aay Chair DATED this of April, 2016. RBDMS /L A99 2 1 2016 0 • RECEIVED STATE OF ALASKA APR 1 8 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION 4—/ZG //6 APPLICATION FOR SUNDRY APPROVALS 'OULIC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Gas Lift E, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development D. 176-056 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20293-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)33-33 - Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi) -VC)is a, Plugs(MD): Junk(MD): 17,689' 17,660' _ 10,680' 10,678' si I N/A 10,680'(junk) Casing Length Size MD TVD 'a-? li• Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.54/L-80 10,590' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker F-1 Production Packer/N/A 10,321'MD-10,319'TVD/N/A 12.Attachments: Proposal Summary 0 Wellbore schematic ❑✓ X13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: May 15,2016 OIL ❑ - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Li WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad HelgesonelesTitle Operations Manager Signature �j�j��/?/`� Phone 907-777-8405 Date i,et COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. -3t - z3 <. Plug Integrity ❑ BOP Test V] Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,k' ,` a,. 7:x.' f{ C Post Initial Injection MIT Req'd? Yes ❑ No ❑ �11 Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: f (,'i " '1 '..' . RBDMS L- l'''''' �J4 ( 6 APPROVED BY Approved by: ' " � ? ( THE COMMISSION Date:�_ �i _7...0 -1OCOMMISSIONER 1 \ I ` - Submit Form and Form 10.' 3 Revised 111/2/2011 5 r �[I • a valid for 12 months from the date of approval Attachments in Duplicate • • Well Prognosis Well: SCU 33-33 Hilcoru Alaska,LL Date:4/11/2016 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Rod Pump Oil Producer Leg: N/A Estimated Start Date: May 15th, 2016 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,013 psi @ 10,352' TVD (Based on downhole gauges 2/5/16) Maximum Expected BHP: — 2,013 psi @ 10,352' TVD Max. Potential Surface Pressure: — 1,480 psi (Based on recent buildup @ surface) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump, rods, and/or tubing change outs were completed in 2004,2008, 2009 and 2011,2013,&2014. In Feburary 2016,the tubing was repaired and the casing was tested to 1,500psig.After the tubing was repaired, pressure at the surface began to build and a no-flow was not successful.Therefore,a completion needs installed with a packer per regulations. The purpose of this work/sundry is to use the Moncla#401 to recomplete this well as a gas lift completion. Notes Regarding Wellbore Condition • Surface equipment (Roto-flex unit) disconnected and rolled back. Ready for WO rig. Procedure: 1. Blow down any pressure on the well and shoot fluid level (echometer) on casing. vie 2. MIRU Moncla #401 WO Rig. Set to work on 12-hr shifts. 3. Pump casing volume of produced water down annulus, lube, and bleed pressure. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. 6. LD pump and dip tube. 7. Set BPV. ND Rod Stripper head and Tree. 8. Notify AOGCC 24hrs in advance to conduct Rig Inspection. 9. NU BOPE. 10. Test BOPE to 250 psi Low/3,500 psi High,annular to 250 psi Low/1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Notify AOGCC 24 hrs in advance of BOP test. c. Notifiction to BLM is not required per email from Amanda Eagle dated 1/11/2016. • • Well Prognosis Well: SCU 33-33 ua „ , :MM.i.k.,.i.i, Date:4/11/2016 d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. LID BOP test equipment. 12. Pump PW down tubing and casing to ensure well is dead. . 13. Pull tubing hanger free, tubing and S-22 anchor out of seal assembly of Model "F-1" packer. 14. Pull tubing string (2-7/8" 8RD) and rack back tubing. a. Inspect tubing for holes/worn joints. b. Laydown: i. Bad joints and record depths of hole ii. Depth Indicator Sub iii. S-22 tubing Anchor iv. Cup Seal v. Cross-Overs vi. Slotted Sub vii. Bull plug 15. PU Snap latch assembly for the 9-5/8" permanent packer and completion jewelry and RIH w/ completion on 3-1/2" EUE 8rdTubing and 2-7/8" 8rd EUE tubing. Use Stainless steel bands to secure 3/8"control line to completion. Minimize excess pipe dope when running completion Completion jewelry per proposed schematic: a. WL entry guide b. X-nipple (RHCP plug body loaded) c. XO 2-7/8" to tubing anchor snap latch ��•� d. Tubing Anchor Snap latch for 9-5/8" Permanent packer e. XO 2-7/8" from tubing anchor snap latch connection f. 2-7/8" Chemical Injection Mandrel (loaded with live valve) g. 2-7/8" GLMs(loaded with live valves) h. 3-1/2" x 2-7/8" cross over i. 3-1/2" Tubing Hanger 16. Space out packer at—10,321' and latch tubing anchor. a. Leave tubing tail to land "30' above top of Tyonek G-zone (near 10,475').The tubing tail will be approximately 155' long. 17. Land tubing in hanger. Close the lockdown pins. 18. Drop ball and rod. Ensure rod seats into loaded X-Nipple. 19. Test tubing to 3,000 psi for 30 min with chart. _ ,14 fie, e•� 20. Test casing to 3,000 psi for 30 min with chart..--). Lures �� w 21. Set TWC, ND BOPE, NU tree and test. Pull TWC. 22. RD Moncla#401 WO Rig. 23. RU Slickline. 24. PT Lubricator to 2,500 psig Hi and 250 psig Low for 10 min. 25. RIH and pull RHCP ball and rod and plug in 2-7/8" X-nipple. RD Slickline. 26. Return to production with same surface safety system as previously installed. (Test as per AOGCC regulations.) 27. Replace IA x OA pressure gauge if required (9-5/8" x 13-3/8"). • S Well Prognosis Well: SCU 33-33 Hilcorp Alaska,I. Date:4/11/2016 Attachments 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form II • • Soldotna Creek Unit Well SCU 33-33 SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hilcnra Alaska,LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm I!Eir111t 23" Surface 90' 20, 13-3/8" 68 K-55 BTC 12A15" Surface 3,380 A� 9 5/8" 47 5-95 BTS 8.681" Surface 6,295' B 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING C 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,518' L 13-3/8" JEWELRY DETAIL .i No. Depth Length ID 00 Item --A 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-/'8rd Lift x Butt down. 2 4,210' 4.98' 2.441" 5.000" Depth Indicator Sub nI 3 10,308' 14.69' 2.441" - 5.980" Baker 5-22 anchor latch assembly(no seals),190-60 I" 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,518' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,519' 1.77' 2.441" 4.500" X0 4 1/2 EUE x 4 1/2 LTC 7 10,521' 1.96' 3.998" 4.500" X0 4 1/2 LTC x 2 7/8 EUE 8 10,523' 3.88' 3.998" 5.188" Slotted Sub,4-1/2"w/2 jts of 4-1/2"Butt below(-60') 9 10,587' 0.80' - 5.125" Bull plug I ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod B 40' 18' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 6'EL Pony Spacer Rod, (1)1"x 4'EL Pony Spacer Rod C 24' 3,000' - 1.000" 1"EL Sucker Rod,w/Class T coupling(120 rods),4 XL Guides E D 3,024' 7,050' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(282 rods(150 new 12/17/2014))),4 XL Guides E 10,074' 400' - 1-1/2" Sinker bars(16 rods)3 new 12/17/14 3 'r" ..- F 10,477' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 2/15/16) G 10,519' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" I11 holes every 2"(90 deg phased)(with memory gauges) 4 1� All new rods 5/25/14 r ti Several Rods Replaced 12/17/2014 !I _ PERFORATIONS FriFri .', Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 5 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 00 0 G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 ill " G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 P------* H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 ).<, ` H1 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 I I 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 El 113 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 Tagged Fill ❑114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 z672/16 3'SL H3 10,638' 10,643' 10,636' 10,641' 5' 4-5 8"Millennium 5s 10/2/2011 30,673'SLM \ ❑ H4/HS / 5spf \� H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' ,i :: : : : ::: :• H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 10-0z-11 Corre,ted H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 measure H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 At - �9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:2/16/16 Updated by JEK 03-15-16 11 • • Soldotna Creek Unit Well SCU 33-33 PROPOSED SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hilcorn Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm 20" Surface 90' 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 S-95 BTS 8.681" Surface 6,295' 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 3-1/2" 9.3 L-80 8RD EUE 2.992" Surface L-80 "45' 3 2-7/8" 6.5 8RD EUE 2.441" Surface "'10,341' 13-3/8" JEWELRY DETAIL 4 I tii No. Depth ID OD Item 1 -17' 2.441" 11.00" 3-1/2"Tubing Hanger 2 "45' 3-1/2"x 2-7/8"Crossover 3 -3,800' 2.441" 4.750" 2-7/8"SF0-1 GLM#4(Live Valve) _ 4 "6,800' 2.441" 4.750" 2-7/8"SF0-1 GLM#3(Live Valve) 5 "9,000' 2.441" 4.750" 2-7/8"SFO-1 GLM#2(Live Valve) S 6 "10,270' 2.441" 4.750" 2-7/8"SFO-1 GLM#1(Live Valve) 1 511 fi 7 "10,300' 2-7/8"Chemical Injection Mandrel(3/8"Control line to surface) 8 "10,308' 2.441" 5.980" Baker Anchor latch assembly(with seals) 9 10,321' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 10 "10,440' 2.313" 3.688" X Landing Nipple 11 "10,445' 2.441" 3.688" WL Entry Guide 6 1 p Z4lj , I-7 )I I PERFORATIONS �' NM ,E Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date 10 ® G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 imi G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 11 _ G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 G-Zone H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 R H1 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 112 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 ❑H3 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 Tagged Fill 01-14 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 z673'S H4 H5 10,648' 10,679' 10,646' 10,677' 31' 4-5 8"Millennium 5s 10/2/2011 10,673'6LM \ 0 H4/HS / / � 5spf \� H4 10,651' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 H5 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 Junk @ 10,680 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 10-02-11 Corrected ::::::::::: H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 measure H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 Ai H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 9-5/8" TD=17,689' PBTD=11,138' MAX HOLE ANGLE=2 deg.@ 6,100' Downhole Revised:2/16/16 Updated by1EK04-11-16 • • 11 Swanson River BOPE SCHEMATIC BOP Stack SCU 33-33 04/11/2016 nikm-p:IlnMka.l.i.l. III III III lit III .11 10111.111 4.54' pHydril GK 13 5/8-5000 1I1 III III IIIIit S 1111111f! Ill I!l Ala 2 7/8-5 variables 4.67' _—i. - rik �y�9y '�■� Blinds tt rtfi/tilt] rt 2 1/16 5M Choke and Kill 2.00' 1534 13" 5M _ J valves 11 Ill=1l1lit II1!" Wistiiiiin s 1 Crossover spool 13 5/8 5M FE X 11 5M FE ri If IUItIft rtj II • • Swanson River SCU 33-33 Proposed Wellhead 04/05/2016 M,I.,,,j, %I,,.f,,e.I.! Swanson River Tubing hanger,CIW-DCB- SCU 33-33 FBB,11 x 3''A EUE 8rd lift and 13 3/8 X 9 5/8 X 2 7/8 susp,w/3"type H BPV profile, 1-'''A non continuous control line,alloy material, 6'A extended neck BHTA,Bowen,3 1/8 5M FE X 3"Bowen top O Valve,swab,WKM-M, 1. 1 `c%' s, �0' �4 ash 3 1/8 5M FE, HWO, DD ®®�\\ �� <,c,\A. A\ <(<0, 'z' hJ,,4\95�•,� trim \.n1 a�� e' .1` 'C\ 4z"`' F�'' 40 \ a c o.:�,,=®®® J 1) ��N ,, cb(*)Ocl .. 3ti ,e Valve,Wing,WKM-M, ., �' 2 1/16 5M FE,HWO, . .`1 - <070.--)41_ ® 1 i!I/ G;, / DD trim ®\.. • 47D ®�0/®�I �\ O �1 � 5Y c / Ate. •.'�- 0. - Valve,master,WKM-M, ®® 4 3 1/8 5M FE, HWO,DD vi '• trim o ._,- Riser spool 3 1/8 5M X3 1/8 5M-used to 'm s, bring upper master out of the cellar MIS Valve, master,WKM-M, i. 3 1/8 5Mtrim ,HWO, DD - " SP ( Adapter,CIW-EN, 11 5M FE X 3 1/8 5M stdd,w/ IS! 1111 I 6'''Aslick neck pocket and' r npt chemical injection port ,w Tubing head,Cameron DCB-S, 13 5/8 5M X =41 Ilia: 11 5M,w/2-2 1/16 5M 1161 III Valve,WKM-M,2 1/16 5M SSO - : FE, HWO,AA trim I. f ° S (4-1 10 : `I r� i 1II -)= 1 • QTY 2 �i �� gam' �-f-�'_ CJ IIIc IN ,. 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S 7 £ < it 2 _. : C k Eo / ° / ® 2 fo Cr) a a. t3 () 2 0 < < STATE OF ALASKA • RECEIVED AKA OIL AND GAS CONSERVATION COMMISSION MAR 21 2016 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑� Re-enter Susp Well❑ Other: Replace Pump&Tubing ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 176-056 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20293-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)33-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680(junk) feet Effective Depth measured 10,680 feet Packer measured 10,321 feet true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic SCAM +,kP 0 I ;.:13J:, True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586'MD 10,584'ND Baker F-1 10,321'MD Packers and SSSV(type,measured and true vertical depth) Production Pkr 10,319'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 82 296 84 165 165 Subsequent to operation: 44 635 103 180 170 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations C7 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-034 ' Contact Joe Kaiser-777-8393 Email ikaisere,hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature ` Phone 907-777-8405 Date 3/2_1/1 Form 10-404 Revised 5/2015 /f//� RBDMS L� MAR 2 2 2016 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 33-33 Moncla 401 50-133-20293-00 176-056 2/4/16 2/16/16 _Daily Operations: 02/04/2016-Thursday MIRU Moncla 401.Laid containment,spotted associated euipment. Sealed in containment and raised derrick. Prep rig to pull rods.SDFN,night guy on tower. 02/05/2016-Friday Held PJSM.Discussed daily activities. SITP 500psi,SICP 500psi.Bled tbg and cgs to Opsi,bull headed 60 bbls of hot PW down tbg. Tbg on vac,csg static. Prepped rig floor to trip rod string.Latched the polished and BO the stuffing box.PU to string weight and unseated the pump.LD the polish rod, MU stripper head and TOH.LD 23 1"rods,tbg started venting gas,SI rams and flowed 10bbls to rig tank before becoming static. Lined pump to tbg side. Bullheaded 40bbls down tbg and swapped to the csg side. e"✓ Bullheaded 8Obbls down the csg.Csg and tbg static. POOH w/21 1"tod and tbg started venting gas,closed in rod BOP's. PU/MU polish rod and stuffing box. Secured well and SDFN. 02/06/2016-Saturday Held PJSM,discussed daily operations. SITP 250psi. SICP 500-,psi. MIRU Johnson tank and containment for same,hooked up taking returns from tbg to Johnson tank.Lined up to pump down csg. Filled pit with 8.5#,bled pressure of tbg and csg. Rolled pump over at 3bpm and pumped 680bbls down the csg,never broke circulation.SD pump csg on vac and tbg static. Lined up to pump down the tbg and pumped 50 bbls of 120 deg water and SD pump,tbg static. BO/LD polish rod and stuffing box, NU stripper head and TOH racking back rod string,visually inspected rod string-good. LD sinker bars,pump and dip tube. Dropped dart valve and pumped 60 bbls down tbg. Set BPV and MU TIW,RD floor and chained back. Well secure,SDFN. 02/07/2016-Sunday Held PJSM,discussed daily operations. ND PT and inspected lift threads. Filled pit with PW,RDMO Johnson tank and containment. MU 2-7/8"blank sub in hanger,NU the 13'BOP stack, 11"x 13"adapter spool,mud cross with two 2-1/16"manual and HCR valves,13"5M double gate with blinds and VBRs(2-7/8-5"), 13"5M annular preventer. Installed winterization for the pit and pump. Installed kill and check lines. Connected BOP's to Kommey unit. RU floor and set stairs.Installed winterization for same. 02/08/2016-Monday Held PJSM,discussed daily activity. Connected Kommey unit to BOP stack,installed heater hose thru kill/ck lines and connected. Secured BOP stack winterization,installed wind walls for rig floor, installed platform and stairs for rig floor.Cleaned all work areas and finished winterizing all rig associated equipment. PU/MU 2-7/8"test jt. 02/09/2016-Tuesday Held PJSM,discussed daily activity. PU/MU test jt,circulated stack and lines and manifolds. Inspected rig and tested BOPE as B,ytii follows: gas detection,pressure tested,annular 250-3,000psi,rams 250-3,000psi,valves 250-3,000psi. Performed Kommey '� drawdown test. 2 F/P recorded,rig floor LEL sensor failed on a high,recal and retested good. Annular preventer failed twice and retested good. Rig and BOPE test witnessed by Matt Herrera,OAGCC. Prepped rig floor to pull completion. Secure location and SDFN. 02/10/2016-Wednesday Held PJSM,discussed daily operations,cleared work areas.SITP Opsi.SICP Opsi.Pulled BPV,MU 2-7/8"lifting joint.PU 95,000K (30K over string wieght)and turned pipe 1/4 turn to the left.Dropped out of parrant bowl to string weight at 65,000K. Made 8 turns to the right and released anchor latch assembly. PU and jayed back into hanger and backed out lock down pins.Unseated tbg hanger and pulled to rig floor. The 2' jt below the hanger was severely rod cut.. Set the dlips and LD the hanger w/2'pup,3 jts and 3 pups(4',6',10'). MU the TIW and pressure tested tbg to 2,000psi for 15mins-Good Test. Bled off pressure. MIRU SL,pressure test Lubricator to 2,000psi-Good Test. RIH w/2"SB and latched standing valve @ 10,515', PU 1,200LB and held to equilized,POOH with same. RDMO SL. TOH w/89 stands of 2-7/8"production string.Visually inspected pin and box ends for rod wear.Stabbed TIW.Closed pipe rams.Secured location,SDFN. 02/11/2016-Thursday Held PJSM arid discussed daily activities. Continued TOH with 74 stands of 2-7/8"8RD,LD seat nipple and S-22 Anchor Latch Assembly(sent to Baker Oil Tools for redress).Stood back 4-1/2"mud Jts.(4'of fill/sand inside jt).Inspected seat nipple and perforated sub-good to rerun with completion. PU/MU 9-5/8"S2„test pkr.RIH w/same. Tallied stands in the hole and set pkr C -/ @ 10,304'.Set slips and MU TIW. Lined up manifold to pump down csg.Rolled over pump at 3BPM and caught pressure after 480bbls away.Pressured up to 1,500psi for MIT and charted for 30mins -good test. Bled off pressure.Released pkr and let well equalize overnight. Secured well and SDFN. 02/12/2016-Friday • • Held PJSM and discussed.TOH w/163 stands of 2-7/8"8RD,BO/LD xo sub and test pkr. MIRU SL,test lubricator 3,000psi-Good test.RIH w/3"drivedown bailer and tagged @ 10,673'SLM. Made 3 attemps to bail and POOH,RDMO SL. Sample of sand and scale.Secured well and SDFN. 02/13/2016-Saturday Held PJSM and discussed daily activities.TIH w/completion string,depth as following:TBG hanger,132 Jts of 2-7/8"6.5#EUE 8RD, 5"depth indicator sub @ 4,156',192 its of 2-7/8"6.5#EUE 8RD,Baker"S"type tbg anchor.Latch assembly @ 10,309", 6 its 2- 7/8"6.5#EUE 8RD tbg,2-7/8"seat nipple(ID 2.25")@ 10,5218',2-7/8"EUE 8RD x 4-1/2"IBT XO @ 10,521',4-1/2"slotted sub @ 10,523", 4-1/2"bull plug @ 10,588'. MU landing jt and landed tbg hanger weighing 55K up/dn.Ran in lockdown screws. Turned pipe a 1/4 turn to the left and J-out of hanger. Marked landing jt and slacked off 5.6'and latched in the Baker F-1 retainer packer PU and jayed back into the hanger.Tbg landed 85K(30K in tension)._ NOTE: The profile threads in the tbg hanger is rod cut. Need to test BOP with blanking sub. BO/LD landing jt,PU/MU 10'and 8'pup jts.Dropped test plug and MU TIW and Kelly hose. Pumped 30bbls of PW down tbg and pressured up to 1,500psi and charted for 30mins-good test.Bled off pressure. Held well control drill with crew, ,simulated aeras kick.Crew responded good to the drill.Held meeting after the drill and discussed ways to improve on reponse time. RD Kelly hose,BO/LD TWI,10'and 8'pup jts,set BPV. Secured well and SDFN. 02/14/2016-Sunday Held ISA and discussed daily acivities. RD rig floor,removed stairs and BOP skirting.Disconnected Kommey,kill/choke lines. ND 13"BOP stack and spacer spools. NU the production tree and ran in lockdown screws,test void 5,000psi-Good Test. Removed winterization from pit and pump,cleaned pit with hot water. Drained the pea trap and RU the gas buster. RU rig floor,pulled BPV and MU the TIW. Prep floor to run rods. Prep equipment for demobe to KGF. 02/15/2016-Monday Held PJSM and discussed daily operations. MIRU SL,RIH 2"SB and latched test plug @ 10,579'.PU and equalized plug and POOH. Plug hung up pulling thru the tree.Hand spanned plug free. Look in tree and saw an o-ring/rubber about 10'down.PU 2-7/8" brush and TIH to bull plug at 10,640'. POOH,did not recover rubber piece(pushed thru seat nipple).RDMO SL. RU stripper head, PU/MU new 21'dip tube(1'of perf section on bottom of diptube)and new 1-3/4" RHBC pump w/stabilizer.TIH w/same and 16 1-1/2" K bars,282 exsiting 7/8", 120 exsiting 1"rod,8',6'and 4'pony rods(w/guides)and exsiting 40'polish rod.RD stripped head.Sent 3 loads to KDU-01. Tagged seat nipple,MU stuffing box and seated pump,filled tbg with PW,stoked pump and PT to 500psi-Good Test.Spaced out pump 36"off bottom. Hung off polish rod 142"from the unit's slab. 02/16/2016-Tuesday Held PJSA,RDMO Moncla 401 and cleaned location,mobe rig to Kenai Gas Field. .11 • . Soldotna Creek Unit Well SCU 33-33 SCHEMATIC Completion Ran:2/13/16 PTD: 176-056 Hilcora Alaska,HA: API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:17.45' Size WT Grade Conn ID Top Btm 20" - Surface 90' 20" 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 S-95 BTS 8.681" Surface 6,295' B 53.5 S-95 BTS 8.535" 6,295' 11,350' C TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,518' JEWELRY DETAIL L .i 13-3/8" No. Depth Length ID OD Item © 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-'h"8rd Lift x Butt down. 2 4,210' 4.98' 2.441" 5.000" Depth Indicator Sub 3 10,308' 14.69' 2.441" 5.980" Baker 5-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,518' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,519' 1.77' 2.441" 4.500" XO 4 1/2 EUE x 4 1/2 LTC 7 10,521' 1.96' 3.998" 4.500" XO 41/2 LTC x 2 7/8 EUE 8 10,523' 3.88' 3.998" 5.188" Slotted Sub,4-1/2"w/2 jts of 4-1/2"Butt below('60') cd? 9 10,587' 0.80' - 5.125" Bull plug 'c I ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod B 40' 18' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 6'EL Pony Spacer Rod, (1)1"x 4'EL Pony Spacer Rod C 24' 3,000' - 1.000" 1"EL Sucker Rod,w/Class T coupling(120 rods),4 XL Guides E D 3,024' 7,050' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(282 rods(150 new 12/17/2014))),4 XL Guides ISI E 10,074' 400' - 1-1/2" Sinker bars(16 rods)3 new 12/17/14 I'I > F 10,477' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 2/15/16) [ 1 I G 10,519' 17' 0.96" 1.315" Dip Tube 2.2511 BTS Box x Pin,Bottom 6'perforated w 3/8" j, mama D. 171-> holes every 2"(90 deg phased)(with memory gauges) 11 a All new rods 5/25/14 Several Rods Replaced 12/17/2014 PERFORATIONS rF Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date I a I G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 5 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 6 7 =_ G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 © i G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 �---------). � Hl HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 "1 �40 ,- H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑113 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 Tagged Fill ❑114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 2/12/16 10,673'SLM \ H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 73'6L �L 0 H4/HS H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,684 • H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 10-02-11 H 1 Corrected H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 measure H H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 A9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:2/16/16 Updated by JEK 03-15-16 • ,,-04,-\1/7,,v THE STATE Alaska Oil and Gas F�, 'a� o f Conservation Commission ALAsKA ItItriti __ 333 West Seventh Avenue s Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 °FALAW' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson SOW JAN 2 9 20$ Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 I �y 7 6 -' V 56? Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33-33 Permit to Drill Number: 176-056 Sundry Number: 316-050 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -111 Cathy WFoerster Chair - DATED this 7day of January, 2016. RBDMS t-L- ,IAN 2 6 2016 • • • RECEIVES' STATE OF ALASKA• JAS! 2 5 2016 ` ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Ars 20 AAC 25.280 AOL CGI ' 6 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. Flow NO packer R - 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Dnll Number: Exploratory ❑ Development ❑✓• 176-056 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service Li 6.API Number: Anchorage,Alaska 99503 50-133-20293-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)33-33 _ Will planned perforations require a spacing exception? Yes ❑ No .❑ 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028990 ' Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,689' • 17,660' . 10,680' 10,678' , 1,380 psi N/A 10,680'(junk) Casing Length Size MD ND Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,590' Packers and SSSV Type: Baker F-1 Production Packer W/O Seals Packers and SSSV MD(ft)and TVD(ft): /N/A 10,321'MD-10,319'ND/N/A 12.Attachments: Proposal Summary ❑I 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: January 26,2016 OIL ❑., . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email ikaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature t'i,, Phone 907-777-8405 Date 1/1-5b b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ut -oGo Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: yE IeS �°S :.,0 is{ �.��. ,�:rK '�-t.,. 5 -S 1` Z A0tGz ZC bCh)Cy F/0,, 6 p �- -�.e lb0 t- ct' y,'zz-1`r h. t.„....v DCS J Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes Li No ❑ Subsequent Form Required: (-:wc'ilk-S rc-c`14-4"4.- 4- -r/l APPROVED BY t( Approved by: / /CL— COMMISSIONER THE COMMISSION Date: /—ll� 7 ,l-9 6' 14 RBDMS 1--t- JAN 1 6 201�ubmitFormand Form 10-403 R-' ised 11/2015o Ii lid for 12 months from the date of approval. Attachments in Duplicate OAR1 ��fff/// 111 NA .-.( 7 e.14. 4.„ • Well Prognosis • Well: SCU 33-33 Hilcorp Alaska,Lr.. Date: 1/25/2016 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: SI Rod Pump Oil Producer Leg: N/A Estimated Start Date: January 26th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Brief Well Summary Soldotna Creek Unit 33-33 stopped producing December 27, 2015. In December 2015 field crews performed troubleshooting activities and the well acted like there was a hole in the tubing. The field crews pumped down the tubing to try and pressure up and test the integrity of the tubing(jug tubing test), but the tubing did not pressure up and developed a plan to repair the well with the workover rig. On January 215t, during daily operator rounds the tubing and casing pressures were found at 1,200 psi. On January 23`d the Swanson River Operators attempted to bleed the well down to a blowdown tank, but it was taking a long time. The operators tried to vent the well through the process flowline and it started making fluids at 180 psi onhe tubing and annulus. The operators watched it flow, waiting for it to bleed down, but flow continued. The lead operator was contacted to investigate and the well was shut-in. It is now believed that there is not a hole in the tubing, but the pump became unseated which was why the well would not jug tubing test, but will flow liquids to surface. Hilcorp is requesting a variance from 20 AA25.200 (d) "All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing-casing annulus from fluids being produced, unless the commission specifically approves production through the annulus to increase flow rate without jeopardizing ultimate recovery from the well." This well does not have a production packer to isolate the tubing-casing annulus from fluids being produced. SCU 33-33 is designed to have an open flow path with the rod pump completion (which is why the packer at 10,311' was run without seals). This is to lower the bottom hole pressure and maximize the recovery of hydrocarbons from the formation and allow the gas to flow up the annulus and not gas lock or flow through the pump. Hilcorp requests approval to flow the well up the tubing with a surface safety valve and without a production packer in a well capable of flow to surface. • 'v 5 r , 4, �' Attachments � , -�' j n _ e 1. Well Schematic `l�,t '' !�-�'`�z • t(30 5 2. Wellhead photo with SSV t - ' 3. Wellhead piping schematic ��r �('4"" J j ) • Soldotna Creek Unit • Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran:5/20/14 • 11PTD: 176-056 Hikora Alaska,LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:15.5' Size WT Grade _ Conn ID Top Btm 20" - Surface 90' =r/�> L20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' riA47 S-95 BTS 8.681" Surface 6,295' B 9-5/8" 453,5 S-95 BTS8.535" 6,295' 11,350' $0 TUBING C / 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' 014"--------- ,11/ „ 6'� ,d L , 13-3/8" JEWELRY DETAIL © No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-/ 8rd Lift x Butt down. IT 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub I I ' 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8"(New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug Bottom 20 jts replaced(6 below packer/14 above packer)5/19/14 c I ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod B 40' 14' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 6'EL Pony Spacer Rod C 54' 3,000' - 1.000" 1"EL Sucker Rod,w/Class T coupling(120 rods),4 XL Guides D 3,054' 7,050' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(282 rods(150 new 12/17/2014))),4 XL Guides 171 I E 10,104' 400' - 1-1/2" Sinker bars(16 rods)3 new 12/17/14 F 10,499' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/20/14) 3 I ' G 10,544' 17' 0.96" 1.315" Dip Tube 2.250 BTS Box x Pin,Bottom 6'perforated w 3/8" L { holes every 2"(90 deg phased) .1/ �� ,F H 10,564' 3' 1.688" 1-1/4"Memory Gauge(Welded coupling to bull plug) IT-) immimi a IE All new rods 5/25/14 Several Rods Replaced 12/17/2014 PERFORATIONS r� Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date I' I G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 CG-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 ___ G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 © 1 G-zone 10,512' 10,544' 10,510' 10,553' 10,586' 10,551' 10,542' 32' 8/31/2009 H1 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 Hl H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586 26' Re-perf 2/20/86 1/29/1977 H2 H2 10,588' 10,602' 10,586' 10,586 14' 8/31/2009 H H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium Sspf 9/29/2011 ❑113 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium Sspf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium Sspf 9/29/2011 Junk @10,680' H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium Sspf 10/2/2011 10-02-11 correctedH3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 measure : H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 ' ` H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 �/ s-s/a H5 10,680' 10,702' 10,678' 10,700' 22' Re perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:12/20/14 Updated by CAH 1-25-2016 • • y a 4 -- a O j14 co — Ln 2 til eL to . , NOc � ' r co ,a a , .,,,,eilt . / /1111 , = 3 o c : 1141611ftwoo..* ......... > .1- CD v a C, .."'"."..""'111111111.111.• L mat€��, ? H > • v�� a+ c ' L N co ribirlilla mc, > .> u ter t 0 • Y ( t 11 I ill I !-ill \ 111 r i O w. a1O . 3 -- *..,,,A,`y . r 1. t " 'n_ 2 -0 �' ,P ..e. , , acv 3 _71-,3. .: 1.1(abL.-6 .1e..) 44ys-rtm ..-st,,,"(,::mAlic. 0 or I a or t i---- ---Ii r r --, 5 •" a e$ri '>k lair .--1 CX 5G 7 w `ry £ .J 10 5d i*4e ee. trtovi' rAj RuteIii �! ►jz /16 21.1111111.111711.1111.1.1111111"...m."Irmillimill".111.1.m....11.1.1.1".1.411milillimmin".....m."..........."1 or g(91'• 77, ,v THE STATE Alaska Oil andGas Y��.►✓%�� O�//®�� / /(�///{��'��y� C r (5 Conservation spy �Ay app �ppp (ylq�-, ��ypp�p��qp.�y�0 ![y��O �pq� II(PyV�.-, �i/-�^ J- 1 b +.iii �S F -._- onseE vation ommission -i'--, GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4'' P" _ Anchorage, Alaska 99501-3572 AL[�6� In ( ID ' 7 f —o,c ee Main: 907.279.1433 Fax: 907.276.7542 September 24, 2013 Mr. Larry Greenstein Regulatory Compliance Hilcorp Alaska LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Safety Valve System Variance Request Swanson River Field Rod Pump Wells Dear Mr. Greenstein: The Alaska Oil and Gas Conservation Commission (AOGCC)has reviewed Hilcorp Alaska LLC (Hilcorp)'s request dated December 31, 2012 for a variance to well safety valve system requirements found in 20 AAC 25.265(b). Hilcorp specifically requests approval to allow Swanson River Field' rod-pump wells to operate without a surface safety valve installed as part of the well's safety valve system. Additional information in support of Hilcorp's variance request was provided by electronic mail on March 6, 2013. The AOGCC hereby APPROVES Hilcorp's request to operate Swanson River Field rod-pumped wells without a surface safety valve when the no-flow criteria stated in regulations 20 AAC 25.265(k) and (I) has been demonstrated. I-Iilcotp justifies its variance by describing several "functionally equivalent components" and "conditions" common to their rod-pumped wells that automatically terminate production from the well should there be a problem with the well's flowline. Included are high pressure and low pressure switches that shut down the electric motor for the rod pump when abnormal pressure conditions are detected; back-up devices to the high pressure switch; and passing"no-flow"tests. To date, AOGCC has witnessed passing no-flow tests on the following wells: - Soldotna Creek Unit 33-33 (PTD 1760560)on 12/12/2012; - Soldotna Creek Unit 32-08 (PTD 1600450)on 12/12/2012; - Soldotna Creek Unit 31-08 (PTD 1810990)on 3/16/2012; - Soldotna Creek Unit 41A-08 (PTD 1940850)on 3/18/2013; - Soldotna Creek Unit 13-34 (PTD 1710210)on 3/18/2013; - Soldotna Creek Unit 12A-03 (PTD 1801040) on 8/9/2013; - Soldotna Creek Unit 12A-04 (PTD 1740210) on 8/9/2013. Individual letters acknowledging successful no-flow tests for these wells have been previously sent to Hilcorp. ' Swanson River Unit; Soldotna Creek Unit Mr.Larry Greenstein September 24,2013 Page 2 of 3 The no-flow test criteria in 20 AAC 25.265 are intended to provide for the elimination of a subsurface safety valve in wells that are demonstrated incapable of unassisted flow to surface. Extension of the test for the purpose of eliminating a surface safety valve is unique to rod- pumped wells, This approved variance applies future rod-pumped wells within the Swanson River Field that are equipped similarly to the existing wells; no flow tests will be required for new rod-pumped wells. A Swanson River Field rod-pumped well that demonstrates the ability to flow unassisted to surface must be shut in until equipped with a safety valve system as required in 20 AAC 25.265(b) and tested as required in 20 AAC 25.265(h). Any cleanout, perforating or other stimulation work in a rod-pumped well may necessitate a subsequent no flow test. Copies of the letters acknowledging the passing no flow tests and this variance approval are to be maintained at the Swanson River Field office. If you have any questions on this matter please contact Jim Regg of our staff at 793-1236. Sincerely, / � Cathy V. Foerster Daniel T. Seamount, Jr. Orman Chair,(Commissioner Commissioner I•mmissioner cc: Mr. Chad Helgeson (Hilcorp) P. Brooks i y OF 7.1, • • �w��\1%j�,s� THE STATE Alaska Oil and Gas �.,'w�►.... �41,� o,f LAsKA Conservation Commission ..,-, _ =___:-_._ z'- _ == 333 West Seventh Avenue we GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 01; Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED FEB G Chad Helgeson Operations Manager 6 .-0 S Hilcorp Alaska, LLC 7 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33-33 Permit to Drill Number: 176-056 Sundry Number: 316-034 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / /J91_,( E44___ _ Cathy P Foerster Chair Sf DATED this LI day of January, 2016. RBDMS 1-L- JAN L 5 2016 • • RIEC !V ' STATE OF ALASKA JAN 15 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 0M 182-//d, APPLICATION FOR SUNDRY APPROVALS A (�`+� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace Pump 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: 4-...,t,.^-j. Exploratory ❑ Development ❑✓ • 176-056" 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20293-00 " 7. If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)33-33 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,689' 17,660' 10,680' 10,678' 465 psi WA 10,680'(junk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,590' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker F-1 Production Packer/N/A 10,321'MD-10,319'TVD/N/A 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: January 29,2016 OIL 1 WIND WDSPL ❑ � ❑ ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad HelgesongTitle Operations Manager Signature (Gry9'/!vT..-�,� Phone 907-777-8405 Date i )Vii 4., COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\Lt - 0314 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance LI f "�'-s l bix.' k, c�"cisre' E'. /'C-?,r c'c''t-�.c.+0 PJ& 1 445 " Post Initial Injection MIT Req d? Yes El No 0 Cl Spacing Exception Required? Yes ❑ No M" Subsequent Form Required: /CZ --1-109 `�`c,''� �Gy 11 n APPROVED BY Approved by:(;�, ,/' _ _ COMMISSIONER THE COMMISSION Date: / /�J/'d_� O—�/�� '�, Submit Form and Fbrfn 10-403 Revised 11/2015 Rr�v,Ip i slid fo,L1 o fr m the date 91 a iblii- Attachments iq,Duplicate ��,,,/// �� ."- JAN2 520 rV�6 ,, ` ' % 'r • • Well Prognosis Well: SCU 33-33 Ililcoru Alaska,LL Date: 1/15/2016 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: SI Rod Pump Oil Producer Leg: N/A Estimated Start Date: January 29th, 2016 Rig: Moncla 401 V Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' TVD Max. Potential Surface Pressure: —465 psi (Based on 0.1 psi/ft gradient) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump, rods, and/or tubing change outs were completed in 2004, 2008, 2009 and 2011, 2013, & 2014. The rod pump produced until December 27,2015,when a suspected hole in the tubing was determined.This well is currently shut-in. The purpose of this work/sundry is to use the Moncla#401 to pull rods, replace bad tubing joints and downhole pump, and re-run the current rod string. • e ,,n` `7 Notes Regarding Wellbore Condition I 45 fi GG " • Well is currently shut-in. l • Well failed a jug test. • Surface equipment (Roto-flex unit) disconnected and rolled back. Ready for WO rig. Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #401 WO Rig with full winterization package. Set to work on 12-hr shifts. 3. Nipple up rod stripper head." jt s `4. LD polish rod and pull EL rods. 5. LD and inspect rods, pump, dip tube, and memory gauges. a. Send memory gauges to Weatherford for download. 6_ Set BPV. ND Rod Stripper head and Tree. 7. Notify AOGCC 24hrs in advance to conduct Rig Inspection. - - ,� 8. NU 13-5/8" BOPE w/ 11" crossover. riL- 9. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1,5_9apsi High (hold each ram/valve and test for 10-min). Record accumulator pre-charge press ru es and chart tests. a. Perform Test. b. Notify AOGCC 24 hrs in advance of BOP test. . • Well Prognosis Well: SCU 33-33 1°l`'°'"11,"ka.LI, Date: 1/15/2016 c. Notifiction to BLM is not required per email from Amanda Eagle dated 1/11/2016. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams on 2-7/8" test joint. „ rte f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. W 6'{ �,^�' 10. L/D BOP test equipment. C).ecai-\' 11. Pull tubing hanger free, tubing and S-22 anchor out of seal assembly of Model "F-1" packer. 12. Drop dart and pump 50bbl of 8.4 ppg PW down tubing. 13. Once hole in tubing is found, RU slickline, RIH, pull dart, and RD slickline. 14. Pull tubing string (2-7/8" 8RD) and rack back. a. Inspect tubing for holes/worn joints. b. Laydown bad joints and record depths of hole 15. RU Slickline. 16. Make 5.0" GR run and tag bottom. POOH. 17. If necessary, RU Bailer, RIH with Bailer and bail any fill covering perforations. POOH. 18. RD Slickline. 19. RIH w/8RD L-80 tubing. ei S' a. PU new slotted sub and seating nipples. � '1°‘ `1"/ b. Replace joints as needed (at a minimum 2 joints above and 2 joints below hole into tubing). PTS° P c. Set depth indicator sub at approx. 4,000'. rr S 20. Stab rebuilt S-22 anchor into seal assembly. 21. Land existing Seaboard tubing hanger with tubing in tension (approx. 30,000#'s). 15- 22. Drop dart and test tubing to 1500 psig. ,4,Si . 23. RU slickline. RIH and pull dart. RD slickline. L iDS 24. Set TWC, ND BOPE, NU tree and test. Pull TWC. 4.-t / , 25. NU Rod strr. r 26. PU existing dip tube and new 1-3/4" rod pump, RIH with existing rod string (sinker bars, 7/8" and � 40` 1"), space out the rods, install existing polish rod. t"\' a. Replace rods as needed with new equivalent rods. b. Memory gauges will not be re-installed. 27. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 28. Stroke pump and test with Rig. 29. RD Moncla#401 WO Rig. 30. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 31. Return to production with same surface safety system as previously installed. (Test as per AOGCC regulations.) 32. Replace IA x OA pressure gauge if required (9-5/8" x 13-3/8"). Attachments 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form H . • ACTUAL SCHEMATIC Soldotna Creek Unit Well SCU 33-33 Completion Ran:5/20/14 PTD: 176-056 Hilcorn Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL Orig RKB:17'/New RKB:15.5' CASING DETAIL Size WT Grade Conn ID Top Btm 1 20" - Surface 90' �- 7111. 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' �-/' 47 S-95 BTS 8.681" Surface 6,295' Br /'' 9 5/8 53.5 S-95 BTS 8.535" 6,295' 11,350' F�/ TUBING C--'"..--- r 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' L 1.13-3/8" JEWELRY DETAIL ENo. _ Depth Length ID OD Item Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 1 17.00' 0.56' 2.441" 11.00" 2-/,,8rd Lift x Butt down. � 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub l D l ' 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8"(New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug Bottom 20 jts replaced(6 below packer/14 above packer)5/19/14 c Hole in ROD DETAIL tubing 12/27/15 No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod B 40' 14' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 6'EL Pony Spacer Rod C 54' 3,000' - 1.000" 1"EL Sucker Rod,w/Class T coupling(120 rods),4 XL Guides D 3,054' 7,050' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(282 rods(150 new E I 12/17/2014))),4 XL Guides E 10,104' 400' - 1-1/2" Sinker bars(16 rods)3 new 12/17/14 ISI F 10,499' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/20/14) G 10,544' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" 1,11.1111.1.11111 holes every 2"(90 deg phased) �� j, \ 'e32-t ' H 10,564' 3' 1.688" 1-1/4"Memory Gauge(Welded coupling to bull plug) g rE All new rods 5/25/14 Several Rods Replaced 12/17/2014 - _ PERFORATIONS 6 7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date F . . G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 I € G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 © G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 __ G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 F6- G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 '�"I�} HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 H1 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑113 _ H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 ❑114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' 10-02-11 ❑ H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 Corrected NN, H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 measure ::::11 H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 "' 9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-pert 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:12/20/14 Updated byJEK 12-27-2015 II • • Soldotna Creek Unit Well SCU 33-33 PROPOSED SCHEMATIC Completion Ran:S/20/14 PTD: 176-056 Hilearn Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:15.5' 111-j--____:_.7- Size WT _ Grade Conn ID Top Btm L 23/ - Surface 90' - 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9 5/8" 47 5-95 BTS 8.681" Surface 6,295' BFEF".....--------'' 53.5 5-95 BTS 8.535" 6,295' 11,350' C TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' L ,13-3/8" JEWELRY DETAIL © No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-Vs"8rd Lift x Butt down. � 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub I"I ' 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8"(New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug * Bottom 20 jts replaced(6 below packer/14 above packer)5/19/14 M I ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod B 40' 14' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 6'EL Pony Spacer Rod C 54' 3,000' - 1.000" 1"EL Sucker Rod,w/Class T coupling(120 rods),4 XL Guides D 3,054' 7,050' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(282 rods(150 new E I 12/17/2014))),4 XL Guides E 10,104' 400' - 1-1/2" Sinker bars(16 rods)3 new 12/17/14 F 10,499' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/20/14) 13 I > G 10,544' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" [ I 1JI holes every 2"(90 deg phased) 1-41-->' ji ►E 4 anomin A �E All new rods 5/25/14 Several Rods Replaced 12/17/2014 - PERFORATIONS n ' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 I-61 >I G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 ------.p 1 :I H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 --- + 111 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 (71R H1 10,562' 10,588' 10,560' 10,586' 26' Re-pert 2/20/86 1/29/1977 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑113 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-pert 2/20/86 1/31/1977 ❑H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk 10,680' 10--02-11 0 114/115 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 CorrectedH3 10,640' 10,645' 10,638' 10,643' 5' Re-pert 2/20/86 1/31/1977 measure : 115 H4/H5 10648' 10,679' 10646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 - -- H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 ----: - 9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re-pert 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-pert 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-pert 2/20/86 1/17/1977 Downhole Revised:12/20/14 Updated byJEK 1/13/2016 • • Swanson River ROPE SCHEMATIC BOP Stack SCU 33-33 01/15/2016 Hilrarh Atask ai.Ili Ii1 Ill lillil 1i1 MON- .� IN- f9imil Il ,--' , 4.54' P.r Hydril IT GK 13 5/8-5000 11l lil 1/1111111 atilll_lal 111 iv ' 2 7/8-5 variables 4.67' _—� �'1 C 11�� m. ■�' °=�_ Blinds III i!i-Ill,i iii a_ _ 2 1/16 5M Choke and Kill MOM Iu Iu iat _ 2.00' it. . Ii -II{4 }II -ieW valves LIUKIJA-Lii(1) Crossover spool 13 5/8 5M FE X 11 5M FE • 0 Swanson River SCU 33-33 hilly/.�. .I , I I 1 01/13/2016 Swanson River Tubing hanger,Seaboard SCU 33-33 DCB tension,11 X 2 7/8 EUE 13 3/8 X 9 5/8 X 2 7/8 lift and susp,w/ 2 1/2"type H BPV profile, 61/<Extended neck,3/8 control line Companion flange ,29/165MFEX 2 7/8 EUE 8rd box Ilii u 111 Valve,wing,WKM-M, 7' \ / ! .ri • �2 Valve,wing,WKM M, 2 1/16 5M FE,HWO, i �" • 1 �) (� ( / l 2 1/16 5M FE, WO, AA trim - _ AA trim III III Riser spool 2 9/16 5M X 29/165M III III I.R. lir/^III Valve,master,WKM-M, 2 9/16 5M FE,HWO,AA � ' .e.1(4;1111: Adapter,Seaboard,11 5M FE ass oir a1 X 2 9/16 5M stdd,w/ 11111.1' 6%slick neck pocket and/2 i,,�u1 'w' npt chemical injection port Tubing head,Cameron — 1 DCB-S,13 5/8 5M X ail ■ , • (P. 11 5M,w/2-2 1/16 5M Iii — IIII SSO �'. r _, Valve,WKM-M,2 1/16 5M 1-��' •/ �� I. - �I j", FE, HWO,AA trim 14 L � �� QTY 2 1!I 1111 . M Casing head,Cameron WF, IIIi :Valve,CIW-F,2 1/16 5M FE, 13 5/8 SM X13 3/8 S OW I iI c i HWO,AA trim 1 • III - 0 / CuC Q _ e 6 ■ 2 E 0 o § ■ c< a E o . 2 ƒ § I a. J f / O. « k / / � ..IX � > > _ = E� k \ § g7 %. � ® a) a o ® 2 ■ z co e W f 2 �..1".. c c 2 % o Z ce to f / B a \ / 4 a / § 0 17 f k o c q /� k Cl) R 011 - % / a) Cl) - CC J \ 4 .0 13) ■ E § a) .8o ° � LL. � \ a) S \ / C a) »7 e § § / /■ '51) 2 2p 2 2 > 2 $ 0 2 @ 0 2 @ « g >o 0 0. ■ / O. 0 % / E 2 R cd ca k m : ® caC.) . I § / a) k $ 2 S 7 2 - § 0 E .. f / 5 & EU & - k C9 ■ 0_ 0 2 rn k 0ci • i • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, January 20, 2016 3:00 PM To: 'Joe Kaiser' Subject: RE: SCU 33-33 RWO PTD 176-056 Joe, Ok with having SCU 12A-03 first for 401 to work on.... Pressure test casing to 15QQ psi on SCU 33-33 . I will write that in the sundry. Rig inspection needed for SCU 33-33 as stated below. Will do inspec Tot n when BOP are pressure tested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Joe Kaiser [mailto:jkaiser@hilcorp.com] Sent: Wednesday, January 20, 2016 2:29 PM To: Schwartz, Guy L(DOA) Subject: RE: SCU 33-33 RWO PTD 176-056 Guy, As stated on the phone,the last casing test for SCU 33-33 was performed on 2/23/1986 at 1,500 psig. Performing the work on SCU 33-33 first is not ideal for our rig schedule. The Saxon 169 rig is currently on the SCU 322C-04 well and will be moving to the SCU 12A-03 well to drill SCU 31B-04. If Moncla goes to SCU 33-33,then Saxon will be waiting for the rods to be pulled on 12A-03. Our preference is to have Moncla go to SCU 12A-03 to pull rods prior to Saxon, then head to SCU 33-33. Joe Kaiser KEN Operations Engineer Swanson River Field jkaiserPhilcorp.corn 907-777-8393 Office 907-952-8897 Cell From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, January 20, 2016 12:28 PM To: Joe Kaiser Subject: RE: SCU 33-33 RWO PTD 176-056 1 • • Joe, Our preference would be to combine the BOP test with the inspection. So SCU 33-33 would be first well. Also .. did you find anything on last casing test for SCU 33-33? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Joe Kaiser [mailto:jkaiser©a hilcorp.com] Sent: Wednesday, January 20, 2016 12:25 PM To: Schwartz, Guy L(DOA) Subject: RE: SCU 33-33 RWO PTD 176-056 Guy, We can move the rig inspection in when we pull the rods on 12A-03.That is no problem for us. Would you like me to modify the sundry for SCU 12A-03 and SCU 33-33 to reflect this change? Joe Kaiser KEN Operations Engineer Swanson River Field jkaiser@hilcorp.com 907-777-8393 Office 907-952-8897 Cell From: Schwartz, Guy L (DOA) [mailto:guv.schwartz@)alaska.gov] Sent: Wednesday, January 20, 2016 11:18 AM To: Joe Kaiser Subject: RE: SCU 33-33 RWO PTD 176-056 Joe, Also as you point out the rig will need an inspection for winter operation.. I see you have SCU 33-33 after the 12A-03 for Moncla 401 . Would be better to swap them so inspection is on first well. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 2 • recipient of this e-mail,please delete it, out first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Wednesday, January 20, 2016 10:27 AM To: Joe Kaiser(jkaiser©hilcorp.com) Subject: SCU 33-33 RWO PTD 176-056 Joe, Can you verify the last time the casing was tested on SCU 33-33? There is nothing mentioned on the sundry to pull the tubing. If has been more than 8-10 yrs it should be tested to 1500 psi. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well Uj v Plug Perforations Perforate H Other ✓ Rod Pump Performed: Alter Casing ❑ Pull Tubing r nh) Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Repair Change Approved Program ❑ Operat. Shutdown [l Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Stratigraphic ❑ Exploratory ❑ Service ❑ 176-056 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20293-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: l/�_ E `�' E' V EI Total Depth measured 17,689 feet Plugs measured N/A f true vertical 17,660 feet Junk measured 10,680 gunk) feet ,JAN 14 2015 Effective Depth measured 10,680 feet Packer measured 10,321 feet®�� true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586' MD 10,584' TVD Baker F-1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A SCOjW ,IAN f 2015 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 76 127 104 140 140 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-656 Contact Stan Porhola Email sporhola(a)hilcorp.com Printed Name Stan Porhola Title Operations Engineer / Signature "L fy^'4—� _. Phone 907-777-8412 Date f Form 10-404 Revised 10/2012 K13DMSQ- JAN 16 201! Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-33 50-133-20293-00 1 176-056 1 12/13/14 12/20/14 Daily Operations: 12/13/2014 -Saturday Moved M401 and associated equipment from BCU -25. Laid contaiment and spotted rig. 12/14/2014 -Sunday Held JSA and discussed job to be performed. Spotted RU Moncla 401. Prepped rig to pull rods. LD the Polish Rod and tripped out of the hole standing back the Rod String. Rod #3 of the 3/4" section in the wrench make up section. The catch on TOF is 1- 5/16". Secured well and SDFN. 12/15/2014 - Monday Held JSA. MU 2-5/16" OS loaded with a 1-5/16" grapple. TIH w/OS and rod string. Replaced 3/4" rod with 1" for work string. Engaged fish with OS and PU 5k over string weight. Fish came free with 1k extra on the weight indicator. No vacuum on tbg to indicate pump unseated. TOOH with rod string. LD 3/4" rods, Rod # 27 in the 3/4" section parted at the wrench make up section. With the same fishing BHA, ran back in the hole and tried to engage fish with no luck. Secured well and SDFN. 12/16/2014 -Tuesday Held JSA. Tripped out the hole with the fishing BHA. The wickers of the grapple were warn and some missing. MU a new 1- 5/16" grapple and TIH. Engaged fish and PU on string. Saw the pump stroke and pulled 7k over string weight. Pumped unseated with the tbg on a vacumm. Pumped 40bbls of hot water down the tbg to clean rods. TOOH with fish. L/D the OS, 3/4" rod section, sinker bars. Bucket tested the pump - test ok. Inspected the seating cups and they are in good condition. 12/17/2014- Wednesday Held JSA. MU the memory gauge, dip tube and pump. TIH w/ 16-1-1/2" K bars, PU 150 new 7/8", exsiting 132 7/8" rods, 120 1" rod, 8' and 6' 1" pony and a new 40' polish rod. Striped the stuffing box over the polish rod and tagged the the seating nipple. Seated the pump. Spaced out pump 40" of bottom and secured with rod clamp. Filled the tbg with PW and tested tbg for 15 mins to 700psi-tested good. Bled off pressure, Secure well and SDFN. 12/19/2014 - Friday Held JSA. Layed Containment and MIRU M401. Perped rig to pull rods. TOOH w/rods. Treads stipped out of the rod box between the 27th and 28th 1" rods. Waited on spiral grapple to arrive from Knight Oil Tools. MU 2-5/16" OS loaded with 2" spiral grapple. TIH and engaged fish. PU on fish and unseated the pump. TOOH and LD OS and the rod with stripped threads. 12/20/2014 -Saturday Held JSA. Replaced rod number 24 25 26 27 28 29 30 in the 1" section. TIH checking the connection with rods and tagged bottom. PU the polish and MU the stuffing box. Pumped 50 gals of Nano Desolve down the tbg. Seated the pump and pumped 35 bbls of PW down tbg. Stroked the rods with the rig and pressured up on tbg to 750psi.- Test ok. Spaced pump 40" of bottom and set rod clamp. MDMO M401 and associated equipment. c � ( PL�c P- Soldotna Creek Unit Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran: 5/20/14 PTD: 176-056 Hileoro Alaska. LLC API: 50-133-20293-00 RKB: 153'/ GL: 125' MSL CASING DETAIL Orig RKB: 17' / New RKB: 15.5' TD =17,689' PBTD = 11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' 20" -3/8" ne Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 5-95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441" 1 Surface 10,586' JEWELRY DETAI( No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-%" 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,517 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" (New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,586' 0.80' 32' 5.125" Bull plug Bottom 20 jts replaced (6 below packer/14 above packer) 5/19/14 ROD DETAIL No. Depth Length ID OD Item A 0' 40' 1.500" Polish Rod B 40' 14' 1.000" (1) 1" x 8' EL Pony Spacer Rod, (1)1" x 6' EL Pony Spacer Rod C 54' 3,000' 1.000" 1" EL Sucker Rod, w/ Class T coupling (120 rods), 4 XL Guides D 3,054' 7,050' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (282 rods(150 new 12/17/2014))), 4 XL Guides E 10,104' 400' 1-1/2" Sinker bars (16 rods) 3 new 12/17/14 F 10,499' 45' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 11/20/14) G 10,544' 17' 0.96" 1.315" Dip Tube 2.25# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) H 10,564' 3' - 1.688" 1-1/4" Memory Gauge (Welded coupling to bull plug) All new rods 5/25/14 Several Rods Replaced 12/17/2014 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/29/2011 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/29/1011 H1 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -pert 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf 9/29/2011 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/29/2011 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 12/20/14 Updated by STP 1/14/15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Perforate U Other ✓ Rod Pump Performed: Alter Casing ❑ Pull Tubing ❑✓ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Repair Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 176-056 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-20293-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: RECEIVE Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680Qunk) feet DEC 0 8 2014 Effective Depth measured 10,680 feet Packer measured 10,321 feet e OGC /'� true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586' MD 10,584' TVD Baker F-1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A+j��{'I Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 74 198 125 120 150 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-607 Contact Stan Porhola Email Worhola(a)hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature'' Phone 907-777-8412 - -� Form 10-404 Revised 10/2012 h —(C --M �� r ' I Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-33 50-133-20293-00 176-056 1 11/12/14 11/15/14 Daily Operations: 11/12/2014 - Wednesday Held JSA. Laid containment and MIRU M401 and associated equipment. Raised Derrick and secured guide lines. Prepped Rig to pull rods. Backed out polish rod and LD. PU on rod string, weight 11k. Rod weight indicates the string is parted in the 7/8" section. Secured well and SDFN. 11/13/2014 - Thursday Held JSA. TOOH w/ 129ea 1" rods, 132ea 7/8" rods and 3ea 3/4" rods. The 4th rod in the 3/4" section parted at the square wrench land / make up section. MU 2-1/8" OS, loaded with 1-1/4" basket grapple. TIH w/ OS using existing rod string. Latched up fish. Pulled 5k over and grapple slipped off fish. Tried latching back up with no luck. TOOH w/ OS. Secured well and SDFN. 11/14/2014 - Friday Held JSA. MU 2-5/16" OS loaded w/1-5/16" basket grapple. TIH with existing rod string and latched up on fish. Unseated pump with 10k over string weight. TOOH w/rods. L/D OS and parted rod. Continued TOOH, L/D pump and Diptube. Removed Pressure and Temp tool.While POOH we Inspected rod guides and boxes for wear. Minimal guide wear on the bootom of the 3/4" rod section. PU 17' Dip Tube w/ 3/4" plug in bottom and a rebuilt 2-1/2" x 1-3/4" x 1 x 7 x 9 x 19 x 21 x 37 RHBC Rod Pump. Type of Barrel: Steel w/ Chrome ID. Type of Plunger: Sparymetal. Type of Cage: Steel Hardline. Accessories: Sandseal. Max Stroke: 368". Bucket tested pump. TIH w/Diptube, pump and rod string. Tagged seating nipple and seated pump. Secured pump and SDFN. 11/15/2014 - Saturday Held JSA. Filled the TBG string with 30bbls of PW. Stroked pump with Rig and pressured up to 500psi. Held for 15mins. Test ok. Bleed off pressure. Spaced out pump 42" off bottom, Set the top of the polish rod 145' from the concrete slab. Clamped off Rod String. RDMO M401 and associated equipment. Well to Production. J. 0 Hilcoru Alaska. LLC RKB: 153'/GL: 125' MSL Orig RKB: IT/ New RKB: 15.5' TD = 17,689' PBTD =11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' 20" S-3/8" une 15 s" ACTUAL SCHEMATIC CASING DETAIL Soldotna Creek Unit Well SCU 33-33 Completion Ran: 5/20/14 PTD: 176-056 API: 50-133-20293-00 Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 5-95 BTS 8.681" Surface 6,295' 9-5/8- 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441" Surface 10,586' IFWFI RY DETAIL No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2 %" 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" (New 5/19/14) 6 10,522' 3.88' 3.998" 5.188 -Slotted Sub, 4.5" 7 10,586' 0.80' - 5.125" Bull plug Bottom 20 jts replaced (6 below packer/14 above packer) 5/19/14 MOT.1.»rim No. Depth Length ID OD Item A 0' 40' 1.500" Polish Rod B 40' 14' 1.000" (1) 1" x 8' EL Pony Spacer Rod, (1) 1" x 6' EL Pony Spacer Rod C 54' 3,225' 1.000" 1" EL Sucker Rod, w/ Class T coupling (129 rods), 4 XL Guides D 3,279' 3,300' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (132 rods), 4 XL Guides E 6,579' 3,600' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling (144 rods), 4 XL Guides Re -pert 8/6/01 10,179' 325' 1-1/2" Sinker bars (13 rods) F 10,504' 45' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 11/15/14) G 10,549' 17' 0.96" 1.315" 1 Dip Tube 2.25# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) All new rods 5/25/14; Replaced parted 3W1 on 11/15/14 DPRFf1RATIr11UC Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 Hi 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/29/2011 HI 1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/29/2011 H2 10,592' 10,624' 10,590' 10,621' 32' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -pert 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8"Millennium 5spf 9/29/2011 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium Sspf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 HS 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 1 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 11/15/14 Updated by STP 11/29/14 1'111: S7'A"I'E OIALASKA ()OVERNOR RILL WALKER Joe Kaiser Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 SCANNED DEC 11 2014 x'16-0�b� Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33-33 Sundry Number: 314-656 Dear Mr. Kaiser: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair 7q - DATED this e day of December, 2014. Encl. i f STATE OF ALASKA M ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DEC S 5� 2014.(� qL AOGCC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdovn ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other: Rod Pump Repair ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development 2 Stratigraphic ElService 116. 176-056 3. Address: 3800 Centerpoint Drive, Suite 100 API Number: Anchorage, Alaska 99503 50-133-20293-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1236 Will planned perforations require a spacing exception? Yes F1No21Soldotna Creek Unit (SCU) 33-33 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028990 Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689 17,660 10,680 10,678 1 WA 10,680' (junk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 10,590' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker F-1 Production Packer/ N/A 10,321' MD - 10,319' TVD / N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: • Detailed Operations Program n BOP Sketch n Exploratory n StratigraphiC Development n Service n 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 12/11/14 Oil ❑✓ • Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Cortact Joe Kaiser Email Printed Name Joe Kaiser Title Operations Engineer Signature Phone 907-777-8393 Date Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �\ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: LA9411 19 At'4-Vy1/1— COMMISSIONER THE COMMISSION Date: /Z – –I /L —1y I Submit Form and Form 10-403 ( vised 10/20 / Appro a p c t i vNAL.ths from the date of approval. Attachments in Duplicate R$C MS DEC 10 201 l ©y,.. Z_ 'e. - �s� 11 H Hilcory Alaska, LL, Well Prognosis Well: SCU 33-33 Date: 12/5/2014 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Rod Pump Oil Producer Leg: N/A Estimated Start Date: December 11, 2014 Rig: Moncla #401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' TVD Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,OOOft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltenes. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing change outs were completed in 2004, 2008, 2009 and 2011, & 2013. A rig workover in early July 2013 removed the chemical injection mandrel, re -ran the tubing and changed out the rod pump. A hole was found in a crossover and the tubing was pulled and replaced in late July 2013. A parted rod in the 7/8" rods at 5,500' was replaced in November 2013. May 2014 20 joints of tubing was replaced, 6 below the packer and 14 above the packer. Additionally in May 2014, all existing rods and pump were replaced with new rods and 1-3/4" pump. November 2014, a 4th rod in the 3%" rod string parted and was replaced. December 2nd, 2014 it is suspected that a rod parted in the 3%" rod string. The purpose of this work/sundry is to use the Moncla #401 to pull and replace failed rods. Notes Reeardine Wellbore Condition 0 Plan to pull and replace the failed rods. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #401 WO Rig. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD parted rod (rods separated in 3%" rod string). 6. PU overshot and fish parted rods and LD %" rods. 7. LD and inspect pump and dip tube and all pulled rods. 8. PU existing dip tube and existing 1-3/4" rod pump, RIH with new rod string (sinker bars, 7/8" and 1"), space out the rods, install new polish rod. 9. ND rod stripper, install surface equipment onto well and test to 1,000 psi. Hilcorp Alaska, LL Well Prognosis Well: SCU 33-33 Date: 12/5/2014 10. RD Moncla #401 WO Rig. 11. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 12. Return to production with same surface safety system as previously installed. (Test as per AOGCC regulations.) 13. Replace IA x OA pressure gauge if removed (7" x 13-3/8") Attachments Actual Schematic r, liilcoro Alaska. LLC RKB: 153'/ GL: 125' MSL Orig RKB: 17'/ New RKB: 15.5' 20" 13-3/8" G -Zone H4 H4/H5 TD=17,689' PBTD=11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' ACTUAL SCHEMATIC CASING DETAIL Soldotna Creek Unit Well SCU 33-33 Completion Ran: 5/20/14 PTD: 176-056 API: 50-133-20293-00 Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 S-95 BTS 8.681" Surface 6,295' 9 5/8" 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441" 1 Surface 10,586' JEWELRY DETAIL No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-%" 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 30-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" (New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,586' 0.80' H 5.125" Bull plug Bottom 20 jts replaced (6 below packer/14 above packer) 5/19/14 ROD DETAIL No. Depth Length ID CID Item A 0' 40' 1.500" Polish Rod B 40' 14' 1.000" (1) 1" x 8' EL Pony Spacer Rod, (1) 1" x 6' EL Pony Spacer Rod C 54' 3,225' 1.000" 1" EL Sucker Rod, w/ Class T coupling (129 rods), 4 XL Guides D 3,279' 3,300' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (132 rods), 4 XL Guides E 6,579' 3,600' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling (144 rods), 4 XL Guides Re -pert 8/6/01 10,179' 325' 1-1/2" Sinker bars (13 rods) F 10,504' 45' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 5/25/14) G 10,549' 17' 0.96" 1.315" Dip Tube 2.25# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) H 10,566' 3' - 1.688" 1-1/4" Memory Gauge (Welded coupling to bull plug) All new rods 5/25/14 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/1011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/19/2011 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re -pert 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 31' 4-5/8" Millennium Sspf 9/19/2011 H2 10,592' 10,614' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -pert 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium Sspf 9/19/2011 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 HS 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 5/25/14 Updated by STP 6/16/14 THE STATE t GOVERNOR SEAN PARNELL Joe Kaiser Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33-33 Sundry Number: 314-607 Dear Mr. Kaiser: Alaska- an Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of November, 2014. Encl. Sincerely, avi J. Mayberry Commissioner SUW0 NOV 182014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED N&V 10 2014 'p -r-5 it// 3 J 1 AOGC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdowt ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other. Rod Pump Repair Q ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development ❑� Stratigraphic ❑ Service ❑ 176-056 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-133-20293-00 . 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1236 ❑ 0 Soldotna Creek Unit (SCU) 33-33 Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028990 Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689 17,660 10,680 10,678 WA 10,680' (junk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8' 6.5# / L-80 10,590' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker F-1 Production Packer / N/A 10,321' MD -10,319 TVD / N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program F� BOP Sketch n Exploratory n Stratigraphies Development ❑ 'Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/12/14 Oil Q Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: r !I/z--1li Commission Representative: (-.) �-- l — -f2- GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true nd correct to the best of my knowledge. Contact Joe Kaiser Email ' se hil co Printed Name Joe Kaiser Title Operations Engineer Sig natb4e Phone 907-777-8393 Date el COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance [] Other: Spacing Exception Required? Yes ❑ No u Subsequent Form Required: l o ` '/0y y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 �'► ^^ I Y Submit Form and Form 10-403 (Revised 10?[a�z) tlJpi \e� li a i� i al� for 1 months from the date of approval. !,, Attachments innDDuplicate i1arar`AA� Nint/ 1 ri 9n1/ \�r�C l ' ` 11 el Hilcorp Alaska, LL Well Prognosis Well: SCU 33-33 Date:11/10/2014 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Rod Pump Oil Producer Leg: N/A Estimated Start Date: Nov. 12th, 2014 Rig: Moncla #401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' TVD Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltenes. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing change outs were completed in 2004, 2008, 2009 and 2011, & 2013. A rig workover in early July 2013 removed the chemical injection mandrel, re -ran the tubing and changed out the rod pump. A hole was found in a crossover and the tubing was pulled and replaced in late July 2013. A parted rod in the 7/8" rods at 5,500' was replaced in November 2013. May 2014 20 joints of tubing was replaced, 6 below the packer and 14 above the packer. Additionally in May 2014, all existing rods and pump were replaced with new rods and 1-3/4" pump. The purpose of this work/sundry is to use the Moncla #401 to pull and replace failed rods and change out the pump. Notes Regarding Wellbore Condition • Plan to pull and replace the failed rod and change out the pump. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing. 2. MIRU Moncla #401 WO Rig. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD parted rod (rods separated at 4,875'; 7/8" rod box). 6. PU overshot and fish parted rods and LD parted rod. 7. LD and inspect pump and dip tube and all pulled rods. 8. PU existing dip tube and new 1-3/4" rod pump, RIH with existing rod string (sinker bars, 3/4", 7/8" and 1), space out the rods, install existing polish rod. 9. ND rod stripper, install surface equipment onto well and test to 3,000 psi. Well Prognosis Well: SCU 33-33 Ilacorp Alaska, LL' Date: 11/10/2014 10. RD Moncla #401 WO Rig. 11. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 12. Return to production with same surface safety system as previously installed. 13. Replace IA x OA pressure gauge if removed (7" x 13-3/8"). Attachments Actual Schematic -> Soldotna Creek Unit Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran: 5/20/14 PTD: 176-056 Hileoru Alaska. LLC API: 50-133-20293-00 RKB: 153'/ GL: 125' MSL CASING DETAIL Orig RKB: 17'/ New RKB: 15.5' Parted Rods 11/9/2014 13-3/8" G -Zone R Hl 7 H2 H3 Size WT H4 �k @ 1o,ead ID H4/H5 10-02-11 20" - Comec[ed 11.00" - measure 90' H5 68 K-55 - --= 9-5/8., ----- TD =17,689' PBTD = 11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 5-95 BTS 8.681" Surface 6,295' 9 5/8" 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441" 1 Surface 10,586' JEWELRY DETAIL No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-/ 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" (New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,586' 0.80' - 5.125" Bull plug Bottom 20 jts replaced (6 below packer/14 above packer) 5/19/14 ROD DETAIL No. Depth Length ID OD Item A 0' 40' 1.500" Polish Rod B 40' 14' 1.000" (1) 1" x 8' EL Pony Spacer Rod, (1) 1" x 6' EL Pony Spacer Rod C 54' 3,225' 1.000" 1" EL Sucker Rod, w/ Class T coupling (129 rods), 4 XL Guides D 3,279' 3,300' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (132 rods), 4 XL Guides E 6,579' 3,600' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling (144 rods), 4 XL Guides Re-perf 8/6/01 10,179' 325' 1-1/2" Sinker bars (13 rods) F 10,504' 45' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 5/25/14) G 10,549' 17' 0.96" 1.315" Dip Tube 2.25# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) H 10,566' 3' 1.688" 1-1/4" Memory Gauge (Welded coupling to bull plug) All new rods 5/25/14 PFRFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/1011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/29/2011 H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re -pert 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium Sspf 9/29/1011 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf 9/19/2011 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 HS 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 1 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 HS 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 5/25/14 Updated by STP 6/16/14 d Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 12, 2014 8:45 AM To: 'Chad Helgeson' Cc: Joe Kaiser Subject: RE: Verbal approval for rod pump repair on SCU 33-33 (PTD 176-056) Chad, You have verbal approval to perform the rod pump change -out as proposed. The sundry matrix will be changed in the near future to only require a 10-404 (report with a coversheet) for rod pump workovers. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aov). From: Chad Helgeson [mailto:chelgeson0hilcorp.com] Sent: Wednesday, November 12, 2014 8:24 AM To: Schwartz, Guy L (DOA) Cc: Joe Kaiser Subject: Verbal approval for rod pump repair on SCU 33-33 (PTD 176-056) Guy, We submitted this sundry late on Monday. The Moncla #401 workover rig finished work on the Paxton well and is available to complete this work starting today. Is there any chance we can get verbal approval to conduct the work as submitted? Thanks Chad Helgeson OPERATION: Drilling Drig Contractor Operator: Location: Section STATE OF ALASKA I_� (P ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT 1(21%1111114 Workover x Aurora Hilcorp 33 T. 8N Compl. U IC DATE: 5/14/2014 Well Name SCU 33-33 PTD# 1760560 Rig# 1 Rep. Donnie Williams Rep. Dan Byrd Rig Ph.# R. 9W M. S 20 Sufficient valves x INSPECTION ITEMS IN COMPLIANCE::' .:::INSPECTION ITEMS INSPECTION ;ITEM'' IN (A.) B.O.P. STACK YES NO N/A C. MUD SYSTEM YES NO N/A 1 Wellhead flg wkg press x 29 Pit level floats installed x 2 Stack wkg press x 30 Flow rate sensor x 3 Annular preventer x 31 Mud gas separator x 4 Pipe rams x 32 Degasser x 5 Blind rams x 33 ISeparator bypass x 6 Stack anchored x 34 Gas sensors x 7 Chke/kill line size x 35 Choke line connections x 8 All turns targeted ( chke & kill Ln.) x 36 Trip tank x 9 HCR valves (chke & kill Ln.) x INSPECTION:1TEM:$'; IN COMpLtANCE 10 Manual valves (chke & kill Ln.) x (downstream choke lines) (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped x 37 Kelly cocks (upper, lower, IBOP) x 12 Drilling spool x 38 Floor valves (dart, ball, ect.) x 13 Flow Nipple x 39 Kelly & floor valve wrenches x 14 Flow monitor x Personnel protective equip. avail. Drillers console (flow monitor, x 15 Control lines fire protected x 40 flow rate indicator, pit level x INSPECTION AN COMPLIANCE: ... ..... .. . ... ... All Drillsite Supervisors Trained indicators, gauges) x (B.) CLOSING UNIT YES NO N/A 41 lKill sheet up-to-date x 16 Working pressure x For Procedures Gas detection monitors x 17 Fluid level x 42 (H2S & methane) 18 Operating pressure x 43 Hydraulic choke panell x 19 Pressure gauges x 44 Choke manifold x 20 Sufficient valves x .:::INSPECTION ITEMS IN GOMPLIANCE' 21 Regulator bypass x (E.) MISC. EQUIPMENT YES NO N/A 22 4 -way valves (actuators) x 45 Flare/vent line x 23 Blind rams handle cover x All turns targeted x 24 Driller control panel x 46 (downstream choke lines) 25 Remote control panel x 47 Reserve pit tankage x 26Firewall x 48 Personnel protective equip. avail. x 27 Nitrogen power source (backup) x All Drillsite Supervisors Trained x 28 Condition (leaks, hoses, ect.) x 49 For Procedures 50 H2S probes x 51 IRig housekeeping x REMARKS: I had then anchor the stack down. Hose from choke to stack was tight; they bumped choke manifold towards the well to give it some slack. Witnessed BOPE test - refer to Insp Rpt #bopRCN140516112705 RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non -Compliance Items: Non -Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? SaHNED Ort Kill Sheet Current? ')g14 Distribution: orig - Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector AOGCC REP: OPERATOR REP: Bob Noble Donnie Williams 2014-0514_Rig_AWS1_SCU 33-33_bn.xlsx (Rev. 12/92) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair Well Ll Plug Perforations Ll Perforate L Other ✓ Rod Pump Performed: Alter Casing ❑ Pull Tubing P] Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Replacement Change Approved Program ❑ Operat. Shutdown ❑ Stimulate -Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development E Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 176-056 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-20293-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A fee E C J true vertical 17,660 feet Junk A measured 10,680 Qunk) feet Effective Depth measured 10,680 feet Packer /` measured 10,321 feet 1 UN 1 7 201¢ true vertical 10,678 feet true vertical 10,319 feet iOGCC Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586' MD 10,584' TVD Baker F-1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 130 145 Subsequent to operation: 112 199 191 130 150 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 1Z Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-247 Contact Stan Porhola Email seorhOla2hIICOrp.COm Printed Name Stan Porhola Title Operations Engineer Signature s— z,�-- Phone 907-777-8412 Date (r 7 1 r Form 10-404 Revised 10/2012 RBC MS JUN 1 Submit Original Only z�T Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number I Start Date End Date SCU 33-33 50-133-20293-00 1 176-056 1 5/9/14 5/25/14 Daily Operations: 05/09/2014 - Friday MOB rig to SCU 33-33, Set berm move in rig components. 05/10/2014-Saturday Prep rig to raise derrick, set gas buster, set berms around rig, pull pump tower back 134" with production to make room to raise derrick, raise derrick. 05/11/2014-Sunday Finish rig up, set berm to lay down rods, hook up electrical to trailers. Rig up Jonson tank and 2" line blow down well. POOH with 15 rods, rods hung up, possibly parting rods, upwt. 22K after hanging up 17K, lay down 129-1" rods and 122-7/8" rods. SDFN. 05/12/2014 - Monday Bleed well down with 120psi overnight pressure. Finish POOH with rods. Rods parted at 7,700'. Rod total: 129-1", 132-7/811, 47-3/4". Install backpressure valve, remove tree, install BOPE. 05/13/2014-Tuesday Continue nipple up BOP, rig pump. Repair nitrogen bottles on Koomey unit. 05/14/2014- Wednesday Finish nipple up, body test BOP, leak between Hydril and double gate, tighten, test good. Tested ROPE, Annular 250-1,SOOpsi, Valves 250-3,OOOpsi and function tested Koomey Unit. (Witnessed by Bob Noble, AOGCC). As detection monitor failed, bringing in Total Safety equip to rig up. SDFN. 05/15/2014 - Thursday Rig up gas detection system. Remove back pressure valve. Rotate anchor out. Remove backpressure valve. Pull hanger. Rig up Pollard, pick up gauge ring, make it down to 800'. POOH. SDFN. 05/16/2014 - Friday Rig up hot oiler and pump 34 bbls hot water clear tubing. RIH with tubing tester on slickline set at 3,100' SLM. Load tubing and test to 500 psi - test good. POOH and reset tool. RIH with tester set at 7,696' SLM. Test tubing to 500 psi - test good. POOH, shear off rubber, rolled over re-tie. RIH, fish tester. POOH. RIH with collar stop and set at 7,598' SLM. RIH with tubing punch, punch holes at 7,596'. POOH. RIH and retrieve collar stop. SDFN. 05/17/2014 -Saturday POOH, S/B 2-7/8" EUE 8RD 6.50 L80 TUBING, 242 JTS. L/D 2 JTS, 1 WITH HOLE SHOTS. R/U to pull rods, unseat pump, pull 2Sk to unseat pump. POOH, L/D rods. POOH, L/D 8 rods, rod string stuck. Do blind backoff on rods, continue POOH. L/D rods and weightbar, pump lift sub, backoff right above pumprod. SDFN. 05/18/2014-Sunday MIRU slickline. RIH with 2.35" G/R to tag at 2,752' SLM. POOH. RIH with 1.50" LIB, tag 2,752' SLM. POOH, indentations show pump rod looking up. RIH with hole finder to 2,730' SLM, set and test to 500 psi - test good. POOH and R/D slickline. POOH, S/B tubing, L/D lasts 20 jts, find pump, beat through seat nipple. L/D pump and seat nipple, fill in mud jts, clean mud jts. MIRU slickline. RIH with bailer, tag 10,645' SLM, get sample. POOH. RIH with pressure temp gauge for 20 min. BHP test. POOH. RDMO slickline. SDFN. 05/19/2014 - Monday M/U BHA 1 bull plug, 2 4-1/2" mudjts. 1 slotted sub, 1 xover, 12-7/8" pup, 1 seat nipple, 6 jts 2-7/8" tubing eue 8rd tbg, 12- 7/8" sub, 1 xover, 1 anchor assy, 1 xover. PU 14 new jts tubing and 310 jts out of derrick and RIH. SDFN. 05/20/2014-Tuesday Tag bottom latch packer, pull 30 k over get space out, unlatch packer, put in subs,slick jt and hanger, drop standing valve test tubing to 2,500 psi. 05/21/2014- Wednesday N/D BOP, install prod tree, test to 5,000 - test good. Remove BPV, rig down. SDFN. 05/22/2014 - Thursday RDMO Aurora rig, move to SCU 44-05. SDFN. 05/23/2014 - Friday Wait on Moncla rig, get rig rigged up, bleed well down, PU dip tube with memory gauge, insert pump, stabilizer bar, 13 weight bars. Start P/U 3/4" rods. 05/24/2014 -Saturday Continue P/U rods to 5,600', Weatherford rod tech showed up said rods not tight enough. POOH, rods standing back. RIH with rods check and card each connection with rod torque, try to flush tubing with water card using rod tongs. PU rods to #31 1" rod tag at 7,700', try flush tubing with water, no luck, work rods, no luck. POOH, S/B with rods. 05/25/2014-Sunday POOH, S/B all rods, lay down weight bars and pump, find cups rolled on pump. MIRU slickline, RIH with 2.33" G/R to 10,566' SLM, no obstructions found. RIH with rods. 1 dip tube with memory gauge, 1 rhbc pump 1.75" x 42', 1 stabilizer bar, 13 weight bars 1-1/2", 144 3/4" EL rods with 4 molded guides per rod, 132 - 7/8" EL rods with 4 molded guides per rod, 129 - 1" EL rods with 4 molded guides per rod, 1 8'x 1" in pony, 16' x 1" pony and 140' polish rod, seat pump, test to 700 psi, stroke pump, good pump action. RDMO. Ililcoro Alaska. LLC. 0 K RKB: 1537 GL: 125' MSL Orig RKB: IT/ New RKB: 15.5' TD=17,689' PBTD=11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' 201, -3/8" Inc ACTUAL SCHEMATIC CASING DETAIL Soldotna Creek Unit Well SCU 33-33 Completion Ran: 5/20/14 PTD: 176-056 API: 50-133-20293-00 Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 S-95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE I 2.441" Surface 10,586' IFWFI RY DFTAII_ No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-31." 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" (New 5/19/14) 6 10,522' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 1 10,586' 1 0.80' - 5.125" Bull plug Bottom 20 jts replaced (6 below packer/14 above packer) 5/19/14 1106191.»r_m No. Depth Length ID OD Item A 0' 40' 1.500" Polish Rod B 40' 14' 1.000" (1) 1" x 8' EL Pony Spacer Rod, (1) 1" x 6' EL Pony Spacer Rod C 54' 3,225' 1.000" 1" EL Sucker Rod, w/ Class T coupling (129 rods), 4 XL Guides D 3,279' 3,300' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (132 rods), 4 XL Guides E 6,579' 3,600' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling (144 rods), 4 XL Guides Re -pert 8/6/01 10,179' 325' 1-1/2" Sinker bars (13 rods) F 10,504' 45' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 5/25/14) G 10,549' 17' 0.96" 1.315" Dip Tube 2.25tt BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) H 10,566 3' - 1.688" 1-1/4" Memory Gauge (Welded coupling to bull plug) All new rods 5/25/14 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/19/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HS 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/29/2011 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium Sspf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/19/2011 H2 10,592' 10,624' 10,590' 10,621' 31' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf 9/29/2011 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 5/25/14 Updated by STP 6/16/14 z.: ,s, HE STATE .� �Auk.z 01.'1 aL A rye r / /\ 333 Wesr Sever In Avenue GOVERNOR SEAN PARNI;I,I, Anchorage, Alaska 99501 3572 ��. 01,� Main 907 279 1.433 AL 5'" 111.27;,.7 Stan Porhola O�� Operations Engineer , �! Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33-33 Sundry Number: 314-247 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. p ,p Commissioner DATED this/0 day of April, 2014. Encl. • STATE OF ALASKA [;. r , ' ALASKA OIL AND GAS CONSERVATION COMMISSION ` APPLICATION FOR SUNDRY APPROVALStt 20 AAC 25.280 '` s 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing[ • Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Rod Pump Replacement [ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development [ • 176-056 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: \ 50-133-20293-00 • Anchorage,Alaska 99503 7.if perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B \ Soldotna Creek Unit(SCU)33-33 • Will planned perforations require a spacing exception? Yes El No No 9.Property Designation(Lease Number 10.Field/Pool(s): FEDA028990 \ Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 17,689 . 17,660 . 10,680 10,678 N/A 10,680'(junk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,590' Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): Baker F-1 Production Packer/N/A 10,321'MD-10,319'TVD/N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphies Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 04/29/14 Oil ❑✓ ' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Email soorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature " — PoPhone 907-777-8412 Date l s /'/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '2.0\LA. , (_1—ri Plug Integrity ElBOP Test lEr Mechanical Integrity Test ❑ Location Clearance Ill Other: -V 3� P S /3 b I 'eS� � AieDMSr: MAY ° 7 2014 Spacing Exception Required? Yes El No [i Subsequent Form Required: /6 — it 0 l �''� APPROVED BY Approved by: ' COMMISSIONER THE COMMISSION Date:47�1/ 7 / 9— Form 10-403(Revised 1 12) ApprovOftiileiNfoA2 to.nths from the date of approval. Attach nts in Duplicate Well Prognosis Well: SCU 33-33 Hilcora Alaska,LLC Date:4/15/2014 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Rod Pump Oil Producer Leg: N/A Estimated Start Date: April 29th, 2014 Rig: Aurora AWS#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' ND (Fluid level calculations, 50%oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' ND Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) with added Safety Factor of 1,000' ND of oil cap) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltenes. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing change outs were completed in 2004, 2008, 2009 and 2011, &2013.A rig workover in early July 2013 removed the chemical injection mandrel,re-ran the tubing and changed out the rod pump.A hole was found in a crossover and the tubing was pulled and replaced in late July 2013.A parted rod in the 7/8" rods at 5,500' was replaced in November 2013. The purpose of this work/sundry is to pull the rods and tubing with the Aurora AWS#1 rig. Notes Regarding Wellbore Condition • Well not pumping 5 months from previous well work. Possible leak in the tubing(plan to replace some v of the tubing string and rod string and pump). Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level(echometer)on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Aurora AWS#1 WO Rig. 4. Nipple up rod stripper head. 5. LD polish rod and LD EL rods. 6. LD pump, investigate pump damage. 7. Set BPV. ND rod stripper head and tree. �� 8. NU BOPE and test to 250psi low/3,000psi high (ho dl each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when/if inspector arrives. b. Using 11" BOPE. Well Prognosis • Well: SCU 33-33 Hilcorp Alaska,LLC Date:4/15/2014 9. Pull tubing hanger free,tubing and S-22 anchor out of seal assembly of Model"F-1" packer. 10. Lay down tubing string(2-7/8" 8RD). a. Inspect tubing for holes/worn joints. 11. RIH w/2-7/8" 8RD L-80 tubing. a. Replace joints as needed. b. Set depth indicator sub at approx. 4,000'. 12. Land existing Seaboard tubing hanger with tubing in tension (approx. 30,000Ws). 13. Set TWC, ND BOPE, NU tree and test. Pull TWC. 14. NU Rod stripper. 15. PU existing dip tube and new 1-3/4" rod pump, RIH with tapered rod string(sinker bars, 3/4", 7/8" and 1" as previously run),space out the rods, install polish rod. a. Replace rods as needed. b. Install memory gauges on bottom of pump. 16. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 17. RD Aurora AWS#1 WO Rig. 18. Roll up Rotoflex pumping unit, recouple,and remove LOTO on motor. 19. Return to production with same surface safety system as previously installed. Attachments Actual Schematic Proposed Schematic BOPE Diagram Soldotna Creek Unit Well SCU 33-33 II ACTUAL SCHEMATIC Completion Ran: 11/12/13 PTD: 176-056 Ilileoru Alaska.1,11: API: 50-133-20293-00 RKB:153'/GL:125'MSL Orig RKB:17'/New RKB:15.5' CASING DETAIL Size WT Grade Conn ID Top Btm 0 20" - - _ - - Surface 90' 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' t 47 S-95 BTS 8.681" Surface 6,295' I I/ 9-5/8" 53.5 S-95 BTS 8.535" 6,295' 11,350' I�1 TUBING (' 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' L ,13-3/8" JEWELRY DETAIL 2 No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-'/"8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub D ' 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug 06 <. New Tubing Ran 7/25/13 c ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod O 9 B 40' 12' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 4'EL Pony Spacer Rod C 52' 3,225' - 1.000" 1"EL Sucker Rod,w/Slimhole Class T coupling(129 rods), D 3,277' 3,300' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(132 rods) E 6,577' 3,600' - 0.750" 3/4"EL Sucker Rod,w/Class T coupling(144 rods) 10,177' 325' - 1-1/2" Sinker bars(13 rods) © ` ii F 10,502' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/12/13) G 10,547' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" ii-J holes every 2"(90 deg phased) I 4 I New Rods Ran 11/12/13 ' PERFORATIONS t - r 1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date Pi I G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 CG-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 !. G-"Lone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 ® H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 ❑ 111 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 7 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑H3 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626 18' Re-perf 2/20/86 1/31/1977 ❑114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 10-02-11 Corrected H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 measure H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 �9 s/a^ H5 10,680' 10,702' 10,678' 10,700' 22' Re perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:11/12/2013 Updated by STP 11/20/13 Soldotna Creek Unit • II Well SCU 33-33 PROPOSED SCHEMATIC Completion Ran: 11/12/13 • PTD: 176-056 ink., klaskth III. API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:15.5' Size WT Grade Conn ID Top Btm 20" - Surface 90' 20 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 9-5/8" 47 5-95 BTS 8.681" Surface 6,295' 15}..............„.....--...........g53,5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' L. . 13-3/8" JEWELRY DETAIL H No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-h"8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub [ii] 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug 0 `= Replace joints as needed a' I ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod El i. B 40' 12' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 4'EL Pony Spacer Rod C 52' 3,225' - 1.000" 1"EL Sucker Rod,w/Slimhole Class T coupling(129 rods), D 3,277' 3,300' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(132 rods) E 6,577' 3,600' - 0.750" 3/4"EL Sucker Rod,w/Class T coupling(144 rods) 10,177' 325' - 1-1/2" Sinker bars(13 rods) ® I F 10,502' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/12/13) J G 10,547' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" 'C holes every 2"(90 deg phased) I" 4 Replace rods as needed " _ PERFORATIONS n Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 ) G2 10,476' 10,510' 10,351' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 I" G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G-`Lone G zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 a = I I G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 G Hl H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 ❑7 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 011 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 011 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' 114/115H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 10-02-11 Corrected � H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 measure H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,6.51' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 • _ '" `=< 9-s/s" H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Proposed Updated by STP 4/15/13 • r Aurora Well Service 3000#BOP Stack 1_11_1 Rig Floor • F, ;,r y1a F h d.i -. I 6's" I. 11" Shaffer 3K mil 1 l [TETT _7-71.1 8,5„ ► 11" Shaffer 3K PIPE RAMS 9'6" ► 11" Shaffer 3K 1 BLIND RAMS i ri ,r , l 11 , Choke Line ___________ -) Kill Line 11'1" /'! .0 t Iin„ 11" 3KINN 40'lb_ i. �� _s 'r-L KILL SPOOL �L�I�; :1411-1( . C 1 [Ai 1 B i 11.,3 . C ,_Q_ S 14' 1" pStartin9 I Head A silt �� II",°.3000u I "'f "U'" " `i" A-31!16"5K HCR valve B-3 1/16"5K Gate valve C-31!16"5K Gate valve Varies it. D-3 1116"5K HCR valve E E-3"200#Ball Valve STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations L Perforate Other U Rod Replacement• Performed: Alter Casing ❑ Pull Tubing El Stimulate-Frac ❑ Waiver El Time Extension El Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 176-056 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20293-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 • Soldotna Creek Unit(SCU)33-33 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: RECEIVED Total Depth measured 17,689 feet Plugs measured N/A feet 2.a y true vertical 17,660 feet Junk measured 10,680(junk) feet Effective Depth measured 10,680 feet Packer measured 10,321 feet AOGCC true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic sumo APR n h U 4 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586'MD 10,584'ND Baker F-1 10,321'MD Packers and SSSV(type,measured and true vertical depth) Production Pkr 10,319'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 99 169 103 150 200 Subsequent to operation: 142 133 121 150 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory El Development❑✓ • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0• Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-582 Contact Stan Porhola Email soorholaahllcorp.com Printed Name ,0-14(Stan Porhola Title Operations Engineer d -_ Signature . _ Phone 907-777-8412 Date [( Z7 13 x(•22• /1 Form 10-404 Revised 10/2012 Submit Original Only .430:4—‘70,,,r Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-33 50-133-20293-00 176-056 11/9/13 11/12/13 Daily Operations: 11/09/2013-Saturday Laid contaiment and MIRU Moncla 405 WOR and associated equipment. Prep WOR to pull rods,LD Polish rod,Pony's rods and the Stuffing box. PU on rod string 10k. SOOH with 134 1'rods,86 7/8"rods. The 87 7/8"rod parted 3"below the coupling. PU a 2-1/8"OS loaded w/7/8"basket grapple and TIH with 86 7/8"rods. Secured well and SDFN. 11/10/2013-Sunday TIH w/135 1"rods. Latched fish at 5,500'. PU to 35k and unseated the pump. TOOH LLD the rod string and.jump. MIRU SL. RIH w/tandem gauges to 10,530'and made a 15 min stop. POOH. RIH w/SV and set in set nipple at 10,565'. Tested tbg to b 700psi,tested good. Pin sheared on pulling tool. POOH. RIH w/2"JDC and latched SV. Waited on well to equalize. Jar out SV 'r and POOH. Secured well and SDFN. 11/11/2013-Monday Prepped to PU new rod string and rod pump. PU and TIH w/the used diptube,new 1.75"ring pump,used 30"stabilizer bar, 13 used sinker bars, 144 new 3/4"EL rods, 132 new 7/8"EL rods,131 new 1"EL rods,8'and 4'pony's and new polish rod. Seated pump and spaced out 30"off bottom. Filled well w/40 bbls of PW. Stroked pump and pressured up to 500psi. Well lost 100psi in 3mins. Repeated tbg test several times with no luck. With no leaks at surface we unseated the pump and reseated. Tried to test again with no luck. Left 500psi on tbg and secured well. SDFN.TLTR:80bbls 11/12/2013-Tuesday Tagged bottom several times with pump. Unseated rod pump and pumped 30 bbls of FSW down tbg to wash seating nipple. Reseated pump and filled tbg. Stroked rod pump and pressured up to 700psi and held for 15 mins,repeated test 3 times. All tested good. RDMO WOR and associated equip. Hooked up Rotaflex and put well to sales. �' Soldotna Creek Unit Well SCU 33-33 ACTUAL SCHEMATIC CoPpleti176-0on Ran:56 11/12/13 TD:m Hilcuru Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:15.5' Size WT Grade Conn ID Top Btm 0 20" - - - - Surface 90' 2a 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' � ��• 9-5/8" 47 S-95 BTS 8.681" Surface 6,295' B� 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 6.5 L-80 8RD EUE 2.441" Surface 10,586' 4. ,13-3/8" JEWELRY DETAIL El No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-'/a"8rd Lift x Butt down. � 2 4,083' _ 1.00' 2.441" 5.000" Depth Indicator Sub I L I 3 10,311' 8.58' 2.441" 5.980" Baker 5-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 _ 10,517' _ 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 0 7 10,586' 0.80' - 5.125" Bull plug ; New Tubing Ran 7/25/13 c i ROD DETAIL No. Depth Length ID OD Item A 0' 40' - 1.500" Polish Rod ❑E > B 40' 12' - 1.000" (1)1"x 8'EL Pony Spacer Rod,(1)1"x 4'EL Pony Spacer Rod C 52' 3,225' - 1.000" 1"EL Sucker Rod,w/Slimhole Class T coupling(129 rods), 0 3,277' 3,300' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(132 rods) E 6,577' 3,600' - 0.750" 3/4"EL Sucker Rod,w/Class T coupling(144 rods) 10,177' 325' - 1-1/2" Sinker bars(13 rods) F 10,502' 45' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 11/12/13) El G 10,547' 17' 0.96" 1.315" Dip Tube 2.25#BTS Box x Pin,Bottom 6'perforated w 3/8" is i holes every 2"(90 deg phased) 131 New Rods Ran 11/12/13 imins 1 rt PERFORATIONS 0 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium Sspf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium Sspf 10/2/2011 © A G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 _ G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 © - G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 _ HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 �1-------'' H1 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 ❑7 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑H3 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 10-02-11 Corrected H3 10,640' 10,645' 10,638' 10,643' 5' Re-perf 2/20/86 1/31/1977 measure HS H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 A� -�9-s/s" H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:11/12/2013 Updated by STP 11/20/13 i. • • or T� Alaska Oil and Gas ��\��(�j,�� THE STATE :_= fALAS� Conservation Commission �� GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF" ;; ' Anchorage. Alaska 99501-3572 AL . ( 1` Main: 907.279.1433 >0' ��Hc G L L, V ,4 •-• Fax: 907.276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 6� 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Soldotna River Field,Hemlock Oil Pool, SCU 33-33 Sundry Number: 313-582 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. erster Chair,Commissioner DATED this(2 day of November,2013. Encl. • 4& t STATE OF ALASKA # NOV 0 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair WeN❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ p,., Time Extension El Operations Shutdovn❑ Re-enter Susp.Wel ❑ Stimulate❑ After Casing❑ Other. Rod Replacement In ' 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development E- 176-056 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service 111 6.API Number: Anchorage,Alaska 99503 50-133-20293-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)33-33 • Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 ' Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 17,689 • 17,660 10,680 10,678 N/A 10,680'(junk) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,34.8' 8,150 psi 7,100 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,590' Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): Baker F-1 Production Packer/N/A 10,321'MD-10,319'TVD/N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n -Service n 14.Estimated Date for t/ 15.Well Status after proFosed work: Commencing Operations: 11/09/13 Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: ir,g,r3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: L7 ,S.-:` •■■i, GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is due and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hi(corp.com Printed Name Stan Porhola Title Operations Engineer Signature S::: i.■416- Phone 907-777-8412 Date ((/ 4 7/13 COMMISSION USE ONLY (( Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ''Sk3 - 5%2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 17 Subsequent Form Required: /O _ Yet i APPROVED BY Approved by: / )(LC*,"L", COMMISSIONER THE COMMISSION Date: Il ' 3 /1 Submit Form and '�i Form 10-403( vised 10/2012) Appr re Rite s NdAtonths from the date 41 ao o ,n;. NOV 2 �A;,;-4,,,.-nts in Duplicate �L , I •; • • • Well Prognosis Well: SCU 33-33 Hitcorp Alaska,LL' Date:11/07/2013 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Rod Pump Oil Producer Leg: N/A Estimated Start Date: November 9th, 2013 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50%oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' ND Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) with added Safety Factor of 1,000' ND of oil cap) Brief Well Summary Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltenes. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing change outs were completed in 2004, 2008, 2009 and 2011, & 2013. A rig workover in early July 2013 removed the chemical injection mandrel, re-ran the tubing and changed out the rod pump. A hole was found in a crossover and the tubing was pulled and replaced in late July 2013. Notes Regarding Wellbore Condition • The rod string is showing minimal weight, indicating parted rods shallow in the 1" rods. ' Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. A. MIRU Moncla#405 WO Rig. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. Rack back the rods in basket. 6. LD parted rod (suspected part depth at+/- 100'; 1" rods). 7. PU overshot and fish parted rods and LD parted rod. 8. LD and inspect pump and dip tube and all pulled rods. 9. PU new dip tube and new 1-3/4" rod pump, RIH with new tapered rod string(sinker bars, 3/4", 7/8"and 1,space out the rods, install polish rod. 10. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 11. RD Moncla#405 WO Rig. 12. Roll up Rotoflex pumping unit, recouple, install new belt,and remove LOTO on motor. 13. Return to production with same surface safety system as previously installed. Attachments: 1. Actual Schematic " . • • Soldotna Creek Unit Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran:7/25/13 PTD: 176-056 Hiicoro Alaska.LLC API: 50-133-20293-00 RKB:1531 GL:125'MSL CASING DETAIL Orig RKB:17'/New RKB:15.5' Size WT Grade Conn ID Top Btm U 20" - - - - Surface 90' 20" 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' El 47 5 95 BTS 8.681" Surface 6,295' p 9-5/8" 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING B 1 h rG I 2-7/8" I 6.5 I L-80 18RD EUE I 2.441" I Surface I 10,586' L , 13-3/8" JEWELRY DETAIL © No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-7/s 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub Q > 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly(no seals),190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,522' 3.88' 3.998" 5.188" Slotted Sub,4.5" 7 10,586' 0.80' - 5.125" Bull plug(New Tubing Ran 7-25-13) 0 a ROD DETAIL No. Depth Length ID OD Item A 26' 40' - 1.500" Polish Rod D B 66' 3,533' - 1.000" 1"EL Sucker Rod,w/Slimhole Class T coupling(141 rods),(1) 1"x 6'EL Pony Spacer Rod,(1)1"x 2'EL Pony Spacer Rod C 3,599' 3,300' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling(132 rods) D 6,899' 3,250' - 0.750" 3/4"EL Sucker Rod,w/Class T coupling(130 rods) 10,149' 325' - 1-1/2" Sinker bars E 10,474' 46' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 7/06/13) El > F 10,520' 63' 1.26" 1.660" Dip Tube 3.02#BTS Box x Pin,Bottom 6'perforated w 3/8" IL, 1I holes every 2"(90 deg phased) CI 1 rE PERFORATIONS © Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 , G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 © M G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 G-Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01;8/31/09 1/3/2001 6 _ G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H1 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 © H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 Hl H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 El H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 0 H3 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk @ 10,680' 10-02-11 H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 Corrected H3 10,640' 10,645' 10,638' 10,643' 5' Re-pert 2/20/86 1/31/1977 measure H5 H4/H5 10,648' 10,679' 10,646' 10,677'1 677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 _ H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 - --- - = s-s/s^ H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-perf 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Downhole Revised:7/26/2013 Updated by STP 07/29/13 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 08, 2013 12:38 PM To: 'Stan Porhola' Subject: RE:Verbal Approval for SCU 33-33 (PTD 176-056) Rod Replacement Stan, You have verbal approval to pull pump rods on SCU 33-33 as proposed in your sundry application. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Stan Porhola (manta_sporholata_hilcorp,com] Sent: Friday, November 08, 2013 9:59 AM To: Schwartz, Guy L(DOA) Subject: Verbal Approval for SCU 33-33 (PTD 176-056) Rod Replacement Guy, We are requesting verbal approval to replace the parted rod string in SCU 33-33(176-056).A sundry was submitted to your office yesterday. Plan start date would be tomorrow,Saturday November 9th utilizing the Moncla#405. Regards, Stan Porhola Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC spbrhola@hilcom.com Office: (907) 777-8412 Mobile: (907) 331-828 1 STATE OF ALASKA AA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS AUG 0 7 2033 1. Operations Abandon Lj Repair Well Lj Plug Perforations Perforate Other � Rod Pump Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Replacement Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development ❑� Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 176-056 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-20293-00 , 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33-33 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680 (junk) feet Effective Depth measured 10,680 feet Packer measured 10,321 feet true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner SCANNED AUG 12 2013 Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5#/L-80 10,586' MD 10,584' TVD Baker F-1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 111 163 189 150 150 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Q . Gas WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-384 Contact Stan Porhola Email S orholaiWhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature y Phone 907-777-8412 Datp—# Form 10-404 Revised 10/2012 '14 PI.t3 le Submit Original Only a Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-33 50-133-20293-00 176-056 1 7/22/13 7/26/13 F.. Daily Operations: 07/22/2013 - Monday Laid containment and MIRU WOR and equipment. RD Stuffing box and rod BOPS. RU rod stripper and L/D polish rod and pony rods. Racked back 100 1" EL rods. Secured well and SDFN. Job status is on going. 07/23/2013 -Tuesday RU rod BOPS and RU rod stripper, Racked back 1", 7/8", 3/4" and inspected rods. L/D sinker bars and rod pump. Set BPV, ND PT and NU 11" 5m BOP stack. Tested BOPS, Annular 250-1,500psi, Valves 250-3,000psi (witness waived by Jim Regg, AOGCC) and function tested Komey Unit. MU 2-7/8" lifting joint. PU 90k (30k over string weight) and turned pipe 1/4 turn to the right. Dropped out of parent bowl to string weight at 60k. Make 8 turns to the right and released anchor latch assembly. PU back into hanger and backed out lock down pins. PU on the pipe and L/D tbg hanger. Set slips and TIW valve. Secured well and SDFN. Job status is ongoing. 07/24/2013 - Wednesday SICP 100psi. Bled pressure off to gas buster. Prep rig to pull pipe. TOOH L/D 342 jts of 2-7/8" 6.5# EUE 8RD, anchor latch assembly, 2-7/8" XO butt to 8RD and 2-7/8" seating nipple. We inspected tbg for holes and did not find any. The 8RD pin side of the XO was flow cut from the middle to the top part of the threads. Sent tbg latch assembly to Baker for redress and inspection. Secured well and SDFN. 07/25/2013 -Thursday SICP 50psi, bled off togas buster. PU and TIH w/ new seating nipple, 6 jts of 2-7/8" 6.5# 8RD tbg, XO 2-7/8" 8RD to 2-7/8" butt, anchor latch assembly and 325 jts of 2-7/8" 6.5# 8RD tbg. PU tbg suspension hanger (4.2"). Landed hanger and turn 1/4 turn to the right. Dropped thru parent bowl and latched packer. Beat down on packer several times. PU 6.35' and work back thru bowl and landed tbg 32k over string weight at 59k. Dropped test plug, pumped 61 bbls of PW and pressured up to 1,000psi. Held for 15 mins. Bled of pressure and MIRU SL. RIH w/2" JDC and latched plug at 10,518'wlm. PU and prong to equalize well. Made two jar licks and POOH w/test plug. Set BPV. Secure well and SDFN. 07/26/2013 - Friday Set BPV, RD rig floor. ND BOPS and NU PT. Prepped rig to run rods. TIH w/rod pump, stablizer bar, 111-1/2" sinker bars, 128 3/4" EL rods, 132 7/8" EL rods, 1411" EL rods, 6' pony, 2' pony and the polish rod. Seated pump and filled tbg with 40bbls of PW. Tested tbg to 500psi - OK. Bled off pressure. Spaced pump 24" off bottom and set rod clamp. L/D WOR and secured well. SDFN. Soldotna Creek Unit Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran: 7/25/13 PTD: 176-056 Hileorn Alaska, LLC API: 50-133-20293-00 RKB: 153'/ GL: 125' MSL CASING DETAIL Orig RKB: IT/ New RKB: 15.5' Size WT Grade Conn ID Top Btm 1 20" - - Surface 90' A 20" 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' IT 9-5/r 47 5-95 BTS 8.681" Surface 6,295' 53.5 S-95 BTS 1 8.535" 1 6,295' 11,350' TD=17,689' PBTD=11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' S-3/8" one 15 i8" TUBING 6.5 r L-80 I 8RD EUE 1 2.441" 1 Surface 10,586' IEWELRY DETAII No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-/ 8rd Lift x Butt down. 2 4,083' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,311' 8.58' 2.441" 5.980" Baker S-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,517' 1.05' 2.255" 3.063" Cup Type Seating Nipple, 2-7/8" 6 10,522' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,586' 1 0.80' 32' 5.125" Bull plug (New Tubing Ran 7-25-13) ROD DETAIL No. Depth Length ID OD Item A 26' 40' 1.500" Polish Rod B 66' 3,533' 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling (141 rods), (1) 1" x 6' EL Pony Spacer Rod, (1) 1" x 2' EL Pony Spacer Rod C 3,599' 3,300' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling (132 rods) D 6,899' 3,250' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling (130 rods) 10,478' 10,149' 325' 1-1/2" Sinker bars E 10,474' 46' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 7/06/13) F 10,520' 63' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/1011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re-perf 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium Sspf 9/29/2011 HS 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/2/1011 H1 10,562' 10,588' 10,560' 10,586' 26' Re -pert 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/29/1011 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf 9/19/2011 H3 10,638' 10,643' 10,636' 7i0,64V 5' 4-5/8"Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/19/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 1 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 7/26/2013 Updated by STP 07/29/13 THE STATE klaska 01i and Gas ®f l SConservation Commissiolft GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola uONED NOV 012013 Operations Engineer Hilcorp Alaska, LLC / —OS -1 3800 Centerpoint Drive, Suite 100 El Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33-33 Sundry Number: 313-384 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED thisA day of July, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DI3 18 2013 ,4oUW�C3 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing0 - Time Extension ❑ Operations Shutdovn ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Atter Casing❑ Other. Rod Pump Replacement ❑� - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill! Number. Hilcorp Alaska, LLC Exploratory ❑ Development Q- Stratigraphic ❑ Service ❑ 176-056 - 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number- umberAnchorage, Anchorage,Alaska 99503 50.133-20293-00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A ❑ ❑✓ Sddotna Creek Unit (SCU) 33-33 ' Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028990 - I Swanson River Field / Hemlock ON 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 17,689 17,660 ' 10,680 10,678 WA 10,680' (junk) Casing Length Size MD ND Burst CoNapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 Psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 10,590' Packers and SSSV Type: Packers and SSSV MD (t) and ND (ft): Baker F-1 Production Packer / N/A 10,321' MD - 10,319 ND / N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: • Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/21/13 Oil Q Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: ' FCr Date: � ,Z� l3 yt5a1-) Commission Representative: ✓6 f GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Emad si2orhol lc_orD.com Printed Name Stan PorholaTitle Operations Engineer Signature L. e- !r Phone 907-777-8412 Date % /-6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (1' JVD Plug Integrity El BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: S C RBDMS JUL 2 6 201 Spacing Exception Required? Yes ❑ No - s uent Form Required: 40 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: A�r /,/4* rLi F/�Ajeij)n +Af 2 months from the date of approval. 10403 (Revised 122) L1 Submit Form and Attachments in DUplicate t �ti flilcorp Alaska, LLI Well Prognosis Well: SCU 33-33 Date:7/18/2013 Well Name: SCU 33-33 API Number: 50-133-20293-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: July 21St, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 176-056 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: 1352033 Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary 1,500 psi @ 10,352' TVD 1,500 psi @ 10,352' TVD 0 psi (Fluid level calculations, 50% oil cut.) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Soldotna Creek Unit 33-33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H-5 (tested gas), Added the H2&3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to . produce a lot of asphaltines. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing changeouts were completed in 2004, 2008, 2009 and 2011, & 2013. A rig workover in early July 2013 removed the chemical injection mandrel, re -ran the tubing and changed out the rod pump. Notes Regarding Wellbore Condition • Well not pumping less than 10 days from previous well work. Possible leak in the tubing (plan to replace entire tubing string and rod string and pump). Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Williams 405 WO Rig 4. Nipple up rod stripper head. 5. LD polish rod and LD EL rods. 6. LD pump, investigate pump damage. 7. Set BPV. ND rod stripper head and tree. 8. NU BOPE and test to 250psi low/3,000psi high (hold each valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24hrs in advance to witness, be ready to test when/if inspector arrives. b. Using 11" BOPE. 9. Pull tubing hanger free, tubing and S-22 anchor out of seal assembly of Model "F-1" packer. 10. Lay down tubing string (2-7/8" 8RD). a. Inspect tubing for holes/worn joints. 11. RIH w/ new 2-7/8" 8RD L-80 tubing. a. Set depth indicator sub at approx. 4,000'. • • Well Prognosis Well: SCU 33-33 Hilcoru Alaska, LLQ Date• 7/18/2013 12. Land existing Seaboard tubing hanger with tubing in tension (approx. 30,000#'s). 13. Set TWC, ND BOPE, NU tree and test. Pull TWC. 14. NU Rod stripper. 15. PU existing dip tube and new 1-3/4" rod pump, RIH with new tapered rod string (sinker bars, 3/4", 7/8" and 1" as previously run), space out the rods, install polish rod. 16. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 17. RD Williams #405. 18. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 19. Return to production with same surface safety system as previously installed. Attachments Actual Schematic Proposed Schematic BOPE Diagram Hilcoro Alaska. LLC RKB: 153'/ GL: 125' MSL New KB -THF: 17' TD=17,689' PBTD=11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' • ACTUAL • Soldotna Creek Unit Well SCU 33-33 SCHEMATIC Completion Ran: 7/06/2013 PTD: 176-056 API: 50-133-20293-00 CASING DETAIL Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 S-95 BTS 8.681" Surface 6,295' 9 5/8' 53.5 S-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441" 1 Surface 10,590 JEWELRY DETAIL No. Depth Length ID OD I Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-/ 8rd Lift x Butt down. 2 3,890' 2.00' 2.441" 5.000" Depth Indicator Sub 3 10,317' 1.88' 2.441" 7.000" Baker S-22 anchor latch assembly (no seals), 190-60 4 10,321 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2-7/8" 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,590' 0.65' - 5.125" Bull plug ROD DETAIL No. Depth Length ID OD Item A 0' 34' 10,476' . 1.500" Polish Rod B 42' 3,290 9/29/2011 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500 34' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' 10,476' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod, (129 rods) Re -pert 8/6/01 10,042' 350' 10,510' . 1-1/2" Sinker bars E 10,522' 43.50' 1.75" 2.250' 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 7/06/13) F 10,534' 12' 1.26" 1.660' Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' . 10,510' 10,352' 10,508' 34' 4-5/8" Millennium Sspf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-S/8" Millennium Sspf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' . 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 H3 10,553' 10,586' 10,553' 10,584' 33' 4-S/8" Millennium Sspf 9/29/1011 HS 10,553' 10,S86' 10,551' 10,584' 33' 4-S/8" Millennium Sspf 10/2/1011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf2/20/86 1/29/1977 H2 10,588' • 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,614' 10,590' 10,622' 32' 4-5/8" Millennium Sspf 9/29/2011 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium Sspf 10/1/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -pert 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8"Millennium 5spf 9/29/2011 H3 10,638' 10,643' 10,636' 10,641' S' 4-S/8"Millennium Sspf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-S/8" Millennium Sspf 9/29/2011 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium Sspf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' ' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Downhole Revised: 7/06/13 Updated by STP 07/15/13 • Soldotna Creek Unit Well SCU 33-33 PROPOSED SCHEMATIC Proposed Completion PTD: 176-056 Hilcom Alaska. LLC API: 50-133-20293-00 RKB: 153'/ GL: 125' MSL CASING DETAIL New KB - THF: 17' TD = 17,689' PBTD = 11,138' MAX HOLE ANGLE = 2 deg. @ 6,100' Size WT Grade Conn ID Top Btm 20" - 2.441" 11.00" - Surface 90' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' 2.441" 47 5-95 BTS 8.681" Surface 6,295' 9-5/8- 53.5 5-95 BTS 8.535" 6,295' 11,350' TUBING 2-7/8" 1 6.5 1 L-80 I 8RD EUE 1 2.441"1 Surface 10,590 JEWELRY DETAIL No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-/ 8rd Lift x Butt down. 2 3,890' 2.00' 2.441" 5.000" Depth Indicator Sub 3 10,317' 1.88' 2.441" 7.000" Baker 5-22 anchor latch assembly (no seals), 190-60 4 10,321' 2.00' 6.000" 8.218" Baker"F-1" 190-60 Retainer Production Packer (Set 10-03-11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2-7/8" 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 1 10,590 1 0.65' 1.26" 5.125" Bull plug ROD DETAIL No. Depth Length ID OD Item A 0' 34' 10,476' 1.500" Polish Rod B 42' 3,290' 9/29/2011 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' 34' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' 10,476' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod, (129 rods) Re -pert 8/6/01 10,042' 350' 10,510' 1-1/2" Sinker bars E 10,522' 43.50' 1.75" 2.250" 1-3/4" RHBC Pump w/ Stabilizer Bar (New Pump 7/06/13) F 10,534' 12' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90 deg phased) PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium Sspf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8/6/01; 8/31/09 1/3/2001 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HS 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 9/29/2011 H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8" Millennium 5spf 10/1/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/19/2011 H2 10,591' 10,614' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-perf 2/20/86 1/31/1977 H3 10,638' 10,643' 10,636' 10,641' S' 4-S/8"Millennium 5spf 9/19/2011 H3 10,638' 10,643' 10,636' 10,641' S' 4-5/8" Millennium 5spf 10/2/2011 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/19/2011 H4/HS 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 H5 10,710' 10,712' 10,708' 10,710' 2' Re-perf 2/20/86 1/17/1977 Proposed Downhole Updated by STP 07/18/13 Swanson River SCU 33-33 07/18/2013 Nilnp 11:•Aa.l.l./. 3 1/8 5M i Kill \ Swanson River Williams BOP 2013 • Ferguson, Victoria L (DOA) • From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, July 22, 2013 4:27 PM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Cc: Chad Helgeson; John Barnes; Luke Saugier Subject: SCU 33-33 (PTD 176-056) Sundry Submittal Victoria, Per our conversation regarding the short lead time in sundry submittal and the proposed start date for the proposed tubing/rod pull for SCU 33-33 (PTD 176-056): The reason we submitted the sundry so close to the proposed start date is the well stopped pumping the evening of July 16th. Diagnostics were run on July 17th and confirmed that there was a leak that prevented the tubing from lifting fluid to surface. A sundry was submitted on July 18th with a proposed start date as early as July 21St, based on our current rig availability. Due to delays at the current well, SCU 12A-03 (PTD 180-104) we will not be ready for SCU 33-33 until July 23rd to start NU BOPE. Our objective is to return wells like SCU 33-33 that require a pump or tubing change out as soon as possible. Let me know if you need any additional information. Stan Porhola I Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 • cut 33-33 Pit 1760 5 Regg, James B (DOA) From: Chad Helgeson [chelgeson @hilcorp.com] Sent: Tuesday, July 23, 2013 8:58 AM (� (24(l3 To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Stan Porhola Subject: RE: Williams 405 Bop test Jim, On the job in question (Sundry#313-346),the original work scope included just pulling the rods, but when the tubing was tested and didn't pass, a new procedure was written to pull the tubing. This triggered a scope change to the well work and required approval from AOGCC, BLM, and Hilcorp. The following steps were taken, which follows the Hilcorp MOSsrocess. 1. Developed a plan with the well site consultant to perform the work. ' 2. Identified the equipment necessary to complete the work. 3. Wrote a plan to complete the work, which was reviewed and approved by the North Kenai Team Ops Engineer and Ops Manager. 4. Submitted the plan to AOGCC and BLM and requested a verbal approval to proceed, identifying the variance from normal operations in the request, verbally and written. 5. Once approved verbally over the phone by the AOGCC, the procedure was delivered to the field (Well Site Supervisor) and reviewed with them between the Operations Engineer and the Well Site Supervisor. 6. Work was started on the well. The reason that the annular preventer was removed from this stack because we only had a 13-5/8" stack available and the height of the stack only allowed joints to be removed one joint at a time (not enough room above the stack and top of the derrick to pull doubles and rack back). The 11" stack that we had been with this rig was rented out to another company and not available. We have taken the following steps to prevent the need of a 13-5/8" stack on the Williams 405 rig:we currently do not have any wells on the schedule or foreseeable future for the Williams 405 rig that will need a 13-5/8" stack and we have contracted with one of the BOP rental vendors in Kenai to have a 7" and 11" stack dedicated for the Williams 405 rig. It is not our intentions to operate without an annular preventer on our BOP stack in the future. We were comfortable with the removal of a safety device because we know that this well is a no-flow well, and we were not doing anything to the formation to change on this well. If you need any additional information, please let me know and don't hesitate to ask. Regards, Chad From Regg, James B (DOA) [mailtoaim.regg(aalaska.gov] , ° 4" Sent: Wednesday, July 17, 2013 3:05 PM 1 '" To: Chad Helgeson Cc: Schwartz, Guy L(DOA) Subject: FW: Williams 405 Bop test We received corrected BOPE Test Report but as of yet have not seen a response to our question about use of Management-of-Change for performing the rig workover without an annular preventer installed in the BOP stack. With the potential for this to happen again, we would appreciate understanding how Hilcorp will addressed it. 1 • „Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-7934236 From: Regg, James B (DOA) Sent: Thursday, July 11, 2013 11:41 AM To: 'Donnie Huffman - (C)'; Donna Ambruz Cc: Brooks, Phoebe L (DOA); Chad Helgeson; Stan Porhola; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: Williams 405 Bop test Corrections needed: - Annular Test Pressure should be shown as NA instead of 0 - You show 2 BOP Misc components and no test result—what are these? - Test Results for Accumulator System? - Since no component failures, repairs within "10" days should be NA Regarding no annular installed in BOPE stack, did you use Management-of-Change procedure to assess and document the impact of this significant deviation? I don't know what your normal standing orders are for use of stack components to control flow from the well but that would definitely need to be adjusted and communicated to rig personnel and posted if those existing orders call for using annular preventer to control flow from well. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Donnie Huffman - (C) [mailto:DHuffman @hilcorp.com] Sent: Friday, July 05, 2013 6:10 PM To: Donna Ambruz; DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Chad Helgeson; Stan Porhola Subject: Williams 405 Bop test 2 • RECEIVED STATE OF ALASKA ` ALO OIL AND GAS CONSERVATION COMIVIDION JUL 18 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC I.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Rod Pump Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver p Time Extension❑ Replacement Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 176-056 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20293-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)33-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680(junk) feet Effective Depth measured 10,680 feet Packer measured 10,321 feet true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13-3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic c NOV ue Vertical depth See Attached Schematic S# t4N� N O 1! 0 6 2013 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,547'MD 10,545'ND Baker F-1 10,321'MD Packers and SSSV(type,measured and true vertical depth) Production Pkr 10,319'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 76 164 14 160 130 Subsequent to operation: 103 301 148 145 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil SI Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. 'Sundry Number or N/A if C.O.Exempt: 313-346 Contact Stan Porhola Email sporhola(C�hilcorp.com Printed Name Stan Porhola Title Operations Engineer J Signature ,/f C.v Phone 907-777-8412 Date 7/,'/i3 ,7-17-13 RBDMS JUL 2 4 20 Form 10-404 Revised 10/2012 7/7/) Submit Original Only • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-33 50-133-20293-00 176-056 7/1/13 7/7/13 Daily Operations: 07/01/2013-Monday MIRU Williams 405 WOR,RU Rig Pump/Pitts. Put berm up around rig and equipment. 07/02/2013-Tuesday Blew casing down to gas buster,RD production equipment on surface. LD polish rod and 3'pony rod. PU on rods and pump, unseated pump from seat nipple. POOH W/rods and pump,hung rods in rod basket,laid down weight bars(K),and pump. Seat cups on pump show no signs of damage or wear. MIRU Pollard Slickline,RIH WI End test tool(standing valve)on slickline, set in seat nipple,RU Williams 405 Pump,pumped 48 Bbls of produced SW down tbg,showed running pressure of 1,000 psi but would not hold,pressure would bleed down to 0 within 45 seconds. Attempted several times,same outcome. RBIH w/ retrieving tool,latched and pulled End test tool,RDMO Pollard slickline Unit. Attempted to circulate well clean,pumped 300 Bbls of produced SW with no returns. Started RU associated equipment to pull tbg. Secured Well,SDFN. 07/03/2013-Wednesday Zero pressure on well. Set back pressure valve in hanger. ND welhead,NU Spool and BOP. Connected all equipment and manifolds. Landed test joint and tested BOPs and equipment,tested BOPs to 250 psi on low and 3,000 psi on high,had __variance from State(witness waived by Jim Regg,AOGC0 to not use annular preventer due to height problems. 07/04/2013-Thursday PU on tbg to 120,000#,released tbg hanger,sat down on tbg anchor,put 12 turns to the right and PU to release anchor. SOOH with 2-7/8"8RD production string.(Spooled up chemical injection line and LD chemical injection mandrel. Found no visible holes or damage in tbg,inspected slotted sub below seat nipple,no build up or fill,inspected Seat nipple,no damage or wear visible. Inspected anchor latch and connections,no visible damage,dropped end test tool down to Seat nipple,loaded and tested to 1,000 psi,tested good. Continued TIH W/2-7/8"Tbg,tested every 20 stands while running in hole to 1,000 psi, TIH W/80 stands total. Secured well,SDFN. 07/05/2013-Friday Continued TIH W/2-7/8" Production Tbg,tested every 20 stands,MU Tbg Hanger and landing joint,landed j-latch hanger, released hanger body from parent bowl,dropped down and latched tbg anchor,PU from 67,000#string weight to approx 100,000#and hung tbg off with hanger,left approx 30K pulled over on tbg. Tested tbg string to 1,200 psi,tested good. MIRU Pollard Slickline Unit,RIH W/1"JDC.Tagged and latched End test tool,PU to pull prong,tbg went on vac. Set for 20 mins to let equalize,then attempted to beat tool free,jarred up 4 times and sheared brass pin in tool. POOH,MU new pulling tool with steel pin,attempted to pull again,jarred up 11 times before shearing pin again. MU new pulling tool and latched ETT again,jarred up 3 times and broke free,POOH,Recovered Fishing neck,dart,and 1/2 of body of tool. RDMO Pollard Slickline. PU and released Tbg hanger again,stacked out on tbg anchor,Put 12 turns to right and PU slowly,released tbg anchor and started SOH,SOOH W/100 stands of 2-7/8"and 1 single. Secured Well,SDFN. 07/06/2013-Saturday Continued SOOH W/2-7/8"Tbg, SO to Seat nipple,remove SN,Pressed test tool out at shop,Installed SN back on Tbg,TBIH With 168 Stands of 2-7/8"Production tbg,Landed Tbg Hanger,String weight of 67,000#. Jarred out of hanger,went down and latched tbg anchor,PU and hung well off with 30,000#over pull,total of 98,000#of PU weight. Dropped Standing valve, pumped 38 Bbls of fluid and tested tbg to 1,200 psi,Tbg tested good for 30 mins,,MIRU Pollard Slickline Unit,RIH W/2 JDC to 10,541'wlm,PU to equalize fluid,Jarred up 1 time and POOH W/standing valve. RDMO Pollard Unit. ND BOPs and NU Welhead,PU 1-3/4"Rod Pump on rod design and started in hole with Pump. Secured Well,SDFN. 07/07/2013-Sunday Continue TIH W/rod design,PU 40'Polish rod and rod BOPS,Seated pump in seat nipple,Spaced rods out to Rotaflex spec and hung well off. Loaded tbg with 31 Bbls of produced water,pressured up to 700 psi on pump seat and tbg. Bled down to 300 psi and stroked pump multiple times and pressured up to 700 psi with pump. RDMO Williams 405 WOR and associated equipment,Hooked flow lines back up to production,turned over to production. • Soldotna Creek Unit • Well SCU 33-33 ACTUAL SCHEMATIC Completion Ran:7/06/2013 PTD: 176-056 Hilcorn Alaska.LLC API: 50-133-20293-00 RKB:153'/GL:125'MSL CASING DETAIL New KB-THF:17' , Size WT Grade Conn ID Top Btm 0 ' 20" - - - - Surface 90' 20' 13-3/8" 68 K-55 BTC 12.415" Surface 3,380' A 47 S-95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 S-95 BTS 8.535" 6,295' _ 11,350' TUBING B 2-7/8" 6.5 I L-80 I 8RD EUE I 2.441" I Surface 10,590' L .113-3/8" JEWELRY DETAIL © No. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl,11"DCB x 2-7/5 8rd Lift x Butt down. �-I 2 3,890' 2.00' 2.441" 5.000" Depth Indicator Sub I I ' 3 10,317' 1.88' 2.441" 7.000" Baker 5-22 anchor latch assembly(no seals),190-60 4 10,321 2.00' 6.000" 8.218" Baker"F-1"190-60 Retainer Production Packer(Set 10-03-11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple,2-7/8" 6 10,530' 3.88' 3.998" 5.188" Slotted Sub,4.5" 0 7 10,590' 0.65' - 5.125" Bull plug (iii) 0 I ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod D > B 42' 3,290' - 1.000" 1"EL Sucker Rod,w/Slimhole Class T coupling w/(3)2.25" R&M Stealth XL AF Rod Guides per rod(131 rods)&(2)1"x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8"EL Sucker Rod,w/Class T coupling-136 w/(3)2.25"R&M Stealth XL AF Rod Guides per rod(140 rods) D 6,817' 3,225' - 0.750" 3/4"EL Sucker Rod,w/Class T coupling-130 w/(3) 2.25"R&M © >'' Stealth XL AF Rod Guides per rod,(129 rods) j �I 10,042' 350' 1-1/2" Sinker bars 3I J,F E 10,522' 43.50' 1.75" 2.250" 1-3/4"RHBC Pump w/Stabilizer Bar(New Pump 7/06/13) F 10,534' 12' 1.26" 1.660" Dip Tube 3.02#BTS Box x Pin,Bottom 6'perforated w 3/8" holes every 2"(90 deg phased) El 0 11 rE PERFORATIONS r7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date I` I G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8"Millennium 5spf 10/2/2011 © G-zone 10,478' 10,510' 10,476' 10,508' 32' Re-pert 8/6/01 1/3/2001 ___ G-Zone G zone 10,510' 10,512' 10,508' 10,510' 2' Re-pert 8/6/01;8/31/09 1/3/2001 6 - _ G-zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 � - H3 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 9/29/2011 8 H1 HI 10,553' 10,586' 10,551' 10,584' 33' 4-5/8"Millennium 5spf 10/2/2011 H1 10,562' 10,588' 10,560' 10,586' 26' Re-pert 2/20/86 1/29/1977 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 9/29/2011 ❑113 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8"Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re-pert 2/20/86 1/31/1977 114 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 9/29/2011 Junk@ 10,680' 10-02-11 H4/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8"Millennium 5spf 10/2/2011 corrected H3 10,640' 10,645' 10,638' 10,643' 5' Re-pert 2/20/86 1/31/1977 measure : H5 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8"Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re-pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 --- - 9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re-pert 2/20/86 1/26/1977 TD=17,689' PBTD=11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re-pert 1/26/77;2/20/86 1/17/1977 MAX HOLE ANGLE=2 deg.@ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re-pert 2/20/86 1/17/1977 Downhole Revised:7/06/13 Updated by STP 07/15/13 • • Schwartz, Guy L (DOA) From: Donnie Huffman - (C) <DHuffman @hilcorp.com> Sent: Thursday, July 04, 2013 10:03 AM To: Schwartz, Guy L (DOA) Subject: RE: SCU 33 -33 (PTD 176 -056) Verbal Approval Request to Pull Tubing (Sundry 313 -346) Guy, per our conversation we have moved forward with verbal agreement not to use annular. We have tested bop's and associated equipment to state approval. We had begun pulling the well this morning. We spoke about future wells with the 13 5/8 stack, this well has special circumstances, it is a rod well with a rotoflex unit, the unit sits on 18" of concrete and 18" of steel structure, it is also on 18" from center of well, this cause us to use a 4' riser to start with and then our flow cross on top of riser. We will not see this on our next 6 wells here in swanson and will be looking for a fix in rnean time if we have to go to another rotoflex well. Let me know if you need anything else. Original Message From: Schwartz, Guy L (DOA) [mailto uy.schw rtz @al ska.gov] Sent: Thursday, July 04, 2013 8:23 AM To: Stara Porhola Cc: Chad Helgeson; Donnie Huffman - (C) Subject: Re: SCU 33 -33 (PTD 176 -056) Verbal Approval Request to Pull Tubing (Sundry 313 -346) an you drop hook - __ re _ ---= -o - gaze you - -_ you a == -�,= -- - --_ --- _=- °_-- ° ----`- - -- use= = -ja -- - '-' - ° --- z-- -c---= -- -- -- �.� =, ��u z... .r �.: a..� € € <�� y- za _ :. -� - _ .a�.=e., auk i.:'e,.= -� -, -. � 3 i € =sz- ; tea, �.+��- -= a,h � �.. - Yom... _: :.� Via`-- ,- :�z . -.z clear ante? Call t d: Call me ii5 discuss. ��j - _ SCANNED JUL 1 (I 2013 444-3433 Sen.. from my !Phone On Jul 3, 2013, at 3:52 PM, "Stan Porhola" <sporholararh Iccrp corn> wrote: > Guy, > Please see the attached documents for the SCU 33 -33 Tubing Pull, to be included as an additional scope of work to the original sundry (313 -346) for pulling the rod pump. > We are requesting a variance to 20 AAC 25.285(c)(2)(A)(iii) to not run an annular preventer due to clearance issues on pulling tubing with a larger 13 -5/8" BOPE on the Williams #405 Pulling Unit. The 11" BOPE stack previously used on this rig is unavailable and the wellhead requires an 11" BOPE or larger. This well has a MASP of 0 psi and no fluid is expected to reach surface on this well. Use of a double gate ram preventer with VBR and Blind Rams should provide adequate well control for pulling the tubing and re- running tubing. > Stan Porhola l Operations Engineer > North Kenai Asset Team > Hilcorp Alaska, LLC > s or_E cl . r` iscorl,_cornt r ailtf?:spc rholaitth lcprp.corr > > Office: (907) 777 -8412 > Mobile: (907) 331 -8228 • • > From: Schwartz, Guy L (DOA) [; p<3iito :Rt ysch °artL.r alaska . roe, > Sent: Tuesday, July 02, 2013 2:38 PM > To: Stan Porhola > Subject: RE: SCU 33 -33 (PTD 176 -056) Verbal Approval Request to Pull > Tubing (Sundry 313 -346) > You have verbal approval to pulling tubing... submit sundry tomorrow as stated below. > Guy Schwartz 7_Z ,13 > Senior Petroleum Engineer > AOGCC > 907 - 444 -3433 cell > 907 - 793 -1226 office > From: Stan Porhola [Riailto orhoia @hiicorp.i:os_ ] > Sent: Tuesday, July 02, 2013 1:59 PM > To: Schwartz, Guy L (DOA) > Cc: Chad Helgeson > Subject: SCU 33 -33 (PTD 176 -056) Verbal Approval Request to Pull > Tubing (Sundry 313 -346) > Guy, > After pulling the Rod Pump from well SCU 33 -33 (PTD 176 -056, Sundry 313 -346), we ran a standing valve on slickline and found that the tubing is leaking. The rod pump pulled appears to be in good shape. > We are requesting verbal approval to NU BOPE and pull the tubing. A hard copy sundry will be submitted tomorrow. > Regards, > Stan Porhola 1 Operations Engineer > North Kenai Asset Team > Hilcorp Alaska, LLC a ..,. } > 5 ��)( Fa,? i�t• i ;;:'sst{'t,Eat.�,.)ii`I�;il1r3E lo.Tistllola et;p Ct`?!`p,cG'n> > Office: (907) 777 -8412 > Mobile: (907) 331 -8228 > > <SCU 33 -33 Actual Schematic 06- 28- 13.docx> <SCU 33 -33 Proposed > Schematic 07- 03- 13.docx> <SCU 33 -33 WO Regulatory 7 -03 -13 Tubing > Pull.docx> <SCU 33 -33 BOP 07 -03 -13 In Progress.docx> • OF ., \ \I % % %s THE STATE Alaska Oil Gas h � ALASKA. Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF P Anchorage, Alaska 99501 -3572 ALAS NEO 3 2013 Main: 907.279.1433 JUL U 3 L, Fax: 907.276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 100 / 6 _ Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33 -33 Sundry Number: 313 -346 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sinc= rely,,i .►Irman Commissioner DATED this //day of July, 2013. Encl. STATE OF ALASKA 3 ) -\ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS . , 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wein Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubin4 Time Extension ❑ Operations Shutdowi ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter CasinC Other. Rod Pump Replacement 5 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drip Number Hilcorp Alaska, LLC Exploratory ❑ Development 0 176-056 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50-133-20293-00 7. If perforating: 8. Wep Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Soldotna Creek Unit (SCU) 33-33 Will planned perforations require a spacing exception? Yes ❑ No 5 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028990 • Swanson River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689 ° 17,660 • 10,680 10,678 N/A 10,680' (junk) Casing Length Size MD 1VD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13 -3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MO (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.5# / L-80 10,590' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker F -1 Production Packer / N/A 10,321' MD - 10,319' TVD / N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch [I Exploratory ❑ Stratigraphic❑ Development n Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/01/13 Oil 5 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 6/28/2013 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Email sporholat hiICOrD.COm Printed Name Stan Porhola Title Operations Engineer Signature J Phone 907 - 777 -8412 Date 6,/2 -3 A COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 5 ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS JUL - 3 201 Spacing Exception Required? Yes ❑ No r4 = r.- equent Form Required: / 0 — -(o (( // APPROVED BY Approved by: 1 COMMISSIONER THE COMMISSION Date: �/ /5 �I 1 7'Z" 13 Submit Form and N7 \ ✓ Form 10-403 (Revised 10/2012) Ara • . i n rf42 months from the date of approval. ttachments in Duplicate �" ffff vvv tr ■ .1 1' . . • Well Prognosis Well: SCU 33 -33 Hilcorp Alaska, LL' Date: 6/28/2013 Well Name: SCU 33 -33 API Number: 50- 133 - 20293 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: July 1 2013 Rig: Williams 405 Reg. Approval Req'd? 403 _ Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 176 -056 First Call Engineer: Stan Porhola (907) 777 -8412 (0) (907) 331 -8228 (M) Second CaII Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' TVD Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 33 -33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H -5 (tested gas), Added the H2 &3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltines. In 2001 the well was worked over, perfed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing changeouts were completed in 2004, 2008, 2009 and 2011, & 2013. Notes Regarding Wellbore Condition • Possible pump damage to pump installed in May 2013. • Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Williams 405 WO Rig 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. LD pump, investigate pump damage. 7. RU slickline. Drop standing valve down tubing. Pressure up and test tubing to 1,500 psi. • 8. RIH and pull standing valve. 9. PU dip tube (install screen on dip tube if debris caused damage) and new 1 -3/4" rod pump, RIH with tapered rod string (sinker bars, 3/4 ", 7/8" and 1" as previously run), Inspect rods and guides and replace as necessary and the pump, space out the rods, install polish rod. 10. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 11. RD Williams #405. 12. Roll up Rotoflex pumping unit, recouple, install new belt, and remove LOTO on motor. 13. Return to production with same surface safety system as previously installed. Attachments Actual Schematic • • • Soldotna Creek Unit Well SCU 33 -33 w SCHEMATIC Completion Date: 02/13/13 PTD: 176 -056 liilcorn Alaska. LLC API: 50- 133 - 20293 -00 RKB: 153'/ GL: 125' MSL CASING DETAIL New KB - THF: 17' Size WT Grade Conn ID Top Btm 0 20" - - - - Surface 90' 20' 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 47 S -95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 S -95 BTS 8.535" 6,295' 11,350' TUBING 1 2 -7/8" 1 6.5 L -80 1 8RD EUE 1 2.441" 1 Surface 10,590' L 1113 -3/8" JEWELRY DETAIL I 1-(V7 B • Chemical No. Depth Length ID OD Item Inj Line 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2 -/ 8rd Lift x Butt down. 2 3,951' 3.38' 2.441" 3.5" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line 0 3 10,317' 1.88' 2.441" 7.000" Baker S -22 anchor latch assembly (no seals), 190 -60 4 10,321 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" © > 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 0 7 10,590' 0.65' - 5.125" Bull plug a I ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod D > B 42' 3,290' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' - 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M © > Stealth XL AF Rod Guides per rod, (129 rods) j 4 10,042' 350' 1 -1/2" Sinker bars 2 LL ; l - _ , E 10,522' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar F 10,534' 12' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" i holes every 2" (90 deg phased) 1 re - PERFORATIONS E Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 9/29/2011 "' G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 10/2/2011 ® 2 G-zone 10,478' 10,510' 10,476' 10,508' 32' Re -perf 8/6/01 1/3/2001 G -Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re -perf 8/6/01; 8/31/09 1/3/2001 6 q G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HI 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 9/29/2011 E 3J ■ Hl HI 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 10/2/2011 El 411101111161P H1 10,562' 10,588' 10,560' 10,586' 26' Re -perf 2/20/86 1/29/1977 ' H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 9/29/2011 • 143 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 9/29/2011 Junk @ 10,680' 1 • 114/115 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 10/2/2011 o �mrrect �ea 4 N , H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 measure ::: I H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium 5spf 9/29/2011 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 - _+r� 145 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 �. + 9 -5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re -perf 2/20/86 1/26/1977 TD = 17,689' PBTD = 11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re -perf 1/26/77; 2/20/86 1/17/1977 MAX HOLE ANGLE = 2 deg. @ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re -perf 2/20/86 1/17/1977 Updated by DMA 05 -03 -13 • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, June 28, 2013 2:18 PM To: 'Stan Porhola' Subject RE: SCU 33 -33 Rod Pump Replacement (PTD 176 -056) Stan, You have verbal approval to repair pump on well SCU 33 -33 as per your attached program. Please submit a 10 -403 as soon as you can. PS... make sure you put in PTD # in subject line for all email correspondence. Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Stan Porhola [r ailto srorrhola,x,hiicorp_com] Sent: Friday, June 28, 2013 11:43 AM To: Schwartz, Guy L (DOA) Subject: RE: SCU 33 -33 Rod Pump Replacement Guy, Please disregard my previous attachment. I have an updated attachment that includes steps to test the tubing after the pump is out of the hole. We want to confirm that we do not have a tubing leak, but we are still confident that the issue with the well is the rod pump. Sta n From: Schwartz, Guy L (DOA) [P i alaska,go ] Sent: Friday, June 28, 2013 10:21 AM To: Stan Porhola Subject: RE: SCU 33 -33 Rod Pump Replacement Stan, Please send me a outline of the well work (outline with steps) and I can get you a verbal .. looks like you will need one. You will need to submit a sundry as soon as possible also. Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907- 793 -1226 office From: Stan Porhola [ ma ilt©:spo.hol<, Sent: Friday, June 28, 2013 9:41 AM 1 • To: Schwartz, Guy L (DOA) Subject: SCU 33-33 Rod Pump Replacement Importance: Hkth Guy, SCU 33-33 rod pump appears to be damaged. Plan to mobilize the Williams #405 on Monday, July 1 to pull and replace. This pump was ran back in May 2013. The pump pulled in May showed some wear and damage to the seals. If we pull the existing pump and find similar damage, we will evaluate a plan forward. Regards, Stan Porhola 0 per:itions Engineer North Kenai Asset Team Hilcorp Alaska, LLC vorholaQ2 (,)fir I] 2 motnie: 0ft/ ) 331 -822i-3 STATE OF ALASKA .. ALA OIL AND GAS CONSERVATION COMMISSION L 2 13 d it; REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Lf Repair Well U Plug Perforations [] Perforate U Other LJ Rod Pump Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Replacement Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: • Hilcorp Alaska, LLC Development 0 . Exploratory ❑ 176 -056 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 20293 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33 -33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil • 11. Present Well Condition Summary: Total Depth measured 17,689 feet , Plugs measured N/A feet true vertical 17,660 feet Junk measured 10,680 (junk) feet Effective Depth measured 10,680 feet , Packer measured 10,321 feet true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13 -3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic SHED MAY 3 0 2013 True Vertical depth See Attached Schematic G t 3 GU Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5#/L -80 10,547' MD 10,545' TVD Baker F -1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 180 0 Subsequent to operation: 113 125 160 170 140 14. Attachments: 15. Well Class after work: • Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil PI , Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -218 • Contact Chad Helgeson Email chelgeson©hilcoro.com Printed Name Chad Helgeson Title Operations Manager r� // Signature edel, ` ," 7 / Phone 907-777-8405 Date 211J3 � ° S j RBDMS MAY 2120f3 Form 10-404 Revised 10/2012 A Submit Original Only • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33 -33 50- 133 - 20293 -00 176 -056 5/5/13 5/5/13 Daily Operations: 05/05/2013 - Sunday MIRU Williams WOR and associated equipment, Bled pressure off casing and Tubing, PU on Polish Rod and unseated pump, TOH W/ Rods and hung in rod basket, layed down 14 weight bars and 2" Pump. MU gas anchor on new 1 -3/4" Sprayed V metal Pump, MU 14 weight bars & TBIH With rods, seated pump in seat nipple, loaded & tested tbg and SN to 700 psi, stroked pump to ensure pump action, hung well off. Turned over to prod. RDMO Williams WOR. III Soldotna Creek Unit • Well SCU 33 -33 SCHEMATIC Completion Date: 02/13/13 PTD: 176 -056 Hilcoro Alaska. LLC API: 50- 133 - 20293 -00 RKB: 153'/ GL: 125' MSL CASING DETAIL New KB -THF: 17' Size WT Grade Conn ID Top Btm Q > 20" - - - - Surface 90' A 20 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 9-5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' TUBING 2 -7/8" 1 6.5 L -80 8RD EUE 2.441" Surface I 10,590' L F , is -a /a JEWELRY DETAIL 13 Chemical No. Depth Length ID OD Item Inj Line 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed OW Bowl, 11" DCB x 2 -%1' 8rd Lift x Butt down. ICI 2 3,951' 3.38' 2.441" 3.5" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line I �- I > 3 10,317' 1.88' 2.441" 7.000" Baker S -22 anchor latch assembly (no seals), 190 -60 4 10,321 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 - 7/8" IT > 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" I 7 10,590' 0.65' - 5.125" Bull plug aO c I ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod D I , B 42' 3,290' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) -3-1 D 6,817' 3,225' - 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M > r----__ Stealth XL AF Rod Guides per rod, (129 rods) I t 10,042' 350' 1 -1/2" Sinker bars I I E 10,522' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar 41-* �� F 10,534' 12' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" 1� re holes every 2" (90 deg phased) I PERFORATIONS I L I . Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 10/2/2011 1 5 G zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 C-Zone G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -pert 8 /6/01; 8/31/09 1/3/2001 6 :I Ir G-zone 10,512' 10,544' 10,510' 10,553' 10,586' 10,551' 10,542' 32' 8/31/2009 HI 10,584' 33' 4 -5/8" Millennium Sspf 9/29/2011 F lil H1 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 10/2/2011 0 H1 10,562' 10,588' 10,560' 10,586' 26' Re -perf 2/20/86 1/29/1977 ' 112 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 9/29/2011 113 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 9/29/2011 Junk @ 1Q68a 10-02-11 ■ 114/H5 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium Sspf 10/2/2011 corrected H3 10,640' 10,645' 10,638' 10,643' 5' Re -perf 2/20/86 1/31/1977 re measu .::: I H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium 5spf 9/29/2011 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 _7+r111 H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 - :-. 9 -5/a- H5 10,680' 10,702' 10,678' 10,700' 22' Re -perf 2/20/86 1/26/1977 TD = 17,689' PBTD = 11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re -perf 1/26/77; 2/20/86 1/17/1977 MAX HOLE ANGLE = 2 deg. @ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re -perf 2/20/86 1/17/1977 Updated by DMA 05 -03 -13 OF T o I % % Alaska y sA THE STATE 011 and Gas ° AL SKA Conservation Commission t GOVERNOR SEAN PARNEIArr - 333 West Seventh Avenue \ Tip, ora Anch e, Alaska 99501 -3572 O�ALAS*P 9 Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson SCANNED M,4Y 9 2013 Operations Manager S(„AN Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 6 ©�� Anchorage, AK 99503 / 7 Re: Swanson River Field, Hemlock Oil lsoo'`l", "SCU -33 Sundry Number: 313 -218 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of May, 2013. Encl. ICI • '6 A 4 RECEIVED STATE OF ALASKA mAY 0 3 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 , - -1 " A.—C 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair We(] Change Approved Programs ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ PuN Tubing Time Extension ❑ Operations Shutdowt ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casin([] Other. Rod Pump Replacement 0 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number. mbe Exploratory ❑ Development 10 • 176 -056 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50-133-20293-00 7. if perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Soldotna Creek Unit (SCU) 33-33 Will planned perforations require a spacing exception? Yes ❑ No el 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028990 • Swanson River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 17,689 17,660 10,680 10,678 WA ) 10,680' (junk) Casing Length Size MD 1VD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13 -3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic - See Attached Schematic 2 -7/8" 6.5# / L-80 10,590' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker F -1 Production Packer / N/A - 10,321' MD - 10,319' TVD / N/A 12. Attachments: Description Summary of Proposal El - 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Strat:graphicH Development n • Service n 14. Estimated Date for 15. Well Status after proposed work: 05/05/13 Commencing Operations: Oil j0 . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: S- 3.13 WINJ ❑ GINJ ❑ WAG ❑ Abandoned [] Commission Representative: 6',4-1 Sj.,,,•,• GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct' to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 Emad chelueson ©hilcorp.cam Printed Name &:"1"117/,—. Chad Helgeson Title Operations Manager Signature Phone 907 - 777 -8405 Date S /V/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number _ 1 Plug Integrity ❑ BOP Test L Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY - 8 201 Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: /c - �D y aei,7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S — 7 !3 � 13 Submit Form and 10 0 Form 10-403 (Revised 10/2012) Appro t n ' v f 1 months from the dat�of approval. Attachments in licate \lr\ • • Well Prognosis • Well: SCU 33 -33 Hilcorp Alaska, LLC Date: 5/3/2013 Well Name: SCU 33 -33 API Number: 50- 133 - 20293 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: May 5 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 176 -056 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Jason Ewing (907) 777 -8441 (0) AFE Number: Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: — 1,500 psi @ 10,352' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 33 -33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was 99 lu ed back to the Hemlock and completed in the H -5 (tested gas), Added the p H2 &3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltines. In 2001 the well was worked over, prefed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing changeouts, were completed in 2004, 2008, 2009 and 2011, & 2013. Notes Regarding Wellbore Condition • Travelling valve appears to be stuck or possible pump damage. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Williams 405 WO Rig 4. Nipple up rod stripper head.✓ 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. LD pump, investigate pump damage. 7. PU dip tube (install screen on dip tube if debris caused damage) and new 1 -3/4" rod pump, RIH with tapered rod string (sinker bars, 3/4 ", 7/8" and 1" as previously run), Inspect rods and guides and replace as necessary (min 3 guides per rod), land the pump, space out the rods, install polish rod. 8. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 9. RD Williams #405. 10. Roll up Rotoflex pumping unit, recouple, install new belt, and remove LOTO on motor. 11. Return to production with same surface safety system as previously installed. Attachments Existing Schematic • • Soldotna Creek Unit Well SCU 33 -33 SCHEMATIC Completion Date: 02/13/13 • Ili PTD: 176 -056 liilcoru Alaska. LL(• API: 50- 133 - 20293 -00 RKB: 153' /GL: 125' MSL CASING DETAIL New KB -THF: 17' Size WT Grade Conn ID Top Btm 0 20" - - - - Surface 90' 20' 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 0 47 S -95 BTS 8.681" Surface 6,295' 9-5/8" 53.5 5 -95 BTS 8.535" 6,295' 11,350' TUBING 2 -7/8" I 6.5 L -80 18RD EUE I 2.441" I Surface 1 10,590' 1-7." ,13 -3/8" JEWELRY DETAIL B . C hemical No. Depth Length ID OD Item Inj Line 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2 - 8rd Lift x Butt down. 2 3,951' 3.38' 2.441" 3.5" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line Q 3 10,317' 1.88' 2.441" 7.000" Baker S -22 anchor latch assembly (no seals), 190 -60 4 10,321 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" © > ` 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 7 10,590' 0.65' - 5.125" Bull plug 0 0 1 ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod D > B 42' 3,290' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' - 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M © > _ _ Stealth XL AF Rod Guides per rod, (129 rods) t I 10,042' 350' - 1 -1/2" Sinker bars � ` � '� E + E 10,522' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar F 10,534' 12' 1.26" 1.660" Dip Tube 3.024 BTS Box x Pin, Bottom 6' perforated w 3/8" e holes every 2" (90 deg phased) - PERFORATIONS n Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium Sspf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium Sspf 10/2/2011 ® G -zone 10,478' 10,510' 10,476' 10,508' 32' Re-perf 8/6/01 1/3/2001 _ -- G -Zone G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -perf 8/6/01; 8/31/09 1/3/2001 n _ G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 I ° I � H3 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium Sspf 9/29/2011 ■ Hl H1 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium Sspf 10/2/2011 El H1 10,562' 10,588' 10,560' 10,586' 26' Re-perf 2/20/86 1/29/1977 ' H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium Sspf 9/29/2011 1 H3 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium Sspf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium Sspf 9/29/2011 Junk 010,680 I • 114/15 H3 10,638' 10,643' 10,636' 10,641' 5' 4- 5 /8 " Millennium Sspf 10/2/2011 coCrrectosa ed H3 10,640' 10,645' 10,638' 10,643' 5' Re -perf 2/20/86 1/31/1977 measure : H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium Sspf 9/29/2011 : H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium Sspf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 _ _++1'� H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 - 9-5/8' H5 10,680' 10,702' 10,678' 10,700' 22' Re-perf 2/20/86 1/26/1977 TD = 17,689' PBTD = 11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re -perf 1/26/77; 2/20/86 1/17/1977 MAX HOLE ANGLE = 2 deg. @ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re -perf 2/20/86 1/17/1977 Updated by DMA 05 -03 -13 • Schwa Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, May 03, 2013 2:47 PM To: 'Chad Helgeson' Cc: Ferguson, Victoria L (DOA) Subject: RE: SCU 33 -33 Rod Pump PTD #176 -056 Chad, You have verbal approval to pull rods and repair pump on SCU 33 -33 as proposed in your sundry application. Guy Schwartz Senior Petroleum Engineer AOGCC 907- 444 -3433 cell 907 -793 -1226 office From: Chad Helgeson [ma;ito:c eig€ son «: i;ik :orp.ccn_m] Sent: Friday, May 03, 2013 2:29 PM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA) Subject: SCU 33 -33 Rod Pump PTD #176 -056 Guy, Attached is a 10 -403 to pull a rod pump and rerun a new pump. The pump quit working yesterday afternoon and our troubleshooting indicates that we have an issue with the travelling valve and the pump needs to be replaced. We would like to squeeze this in before we start on the other project you gave me verbal approval on. We have spare pumps in Swanson River and everything to get this repaired as soon as we are allowed. Let me know if you think you can provide a verbal approval on this or if I need to wait until next week and do the work after the perforating work on SRU 13 -27. Hard copy will be delivered today. Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 1 THE STATE °'ALASKA GOVERNOR SEAN PARNELL Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Soldotna Creek Unit 33-33 PTD 1760560 Dear Mr. Myers: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 March 13, 2013 SCONEp OCT 0 9 2014 On December 12, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Soldotna Creek Unit 33-33. The well is operated by Hilcorp Alaska, LLC (Hilcorp), completed as an artificially -lifted producer that relies on a rod pump system to bring production to surface. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to the well and monitored three hours for flow to surface. During the flow monitoring period, liquid production did not exceed 6.3 gallons per hour and gas production was measured at rates less than 900 standard cubic feet per hour. Soldotna Creek Unit 33-33 meets the AOGCC requirements for a no -flow status determination. Hilcorp requested a safety valve system variance for its rod pump wells located in the Swanson River Field (Swanson River Unit and Soldotna Creek Unit) by letter dated December 31, 2012. In lieu of a surface safety valve (as required by 20 AAC 25.265), Hilcorp requests AOGCC consider an alternate configuration for well control equipment supported by the approved no flow status. The AOGCC decision regarding a required surface safety valve for Soldotna Creek Unit 33-33 will be addressed in response to Hilcorp's variance request. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM ON MAR 0 6 202 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations Lf Perforate U Other U Rod Pump Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Replacement Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ 176 -056 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: (('�� Anchorage, Alaska 99504 50-133-20293-00 – V 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 33 -33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A feet r 10,680 (junk) true vertical 17,660 feet Junk measured 0, 680 � ) feet Effective Depth measured 10,680 feet Packer measured 10,321 feet true vertical 10,678 feet true vertical 10,319 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13 -3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation depth Measured depth See Attached Schematic scANNED MAR 2 0 2013 True Vertical depth See Attached Schematic 4CItt �l Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5 # /L -80 10,547' MD 10,545' TVD Baker F -1 10,321' MD Packers and SSSV (type, measured and true vertical depth) Production Pkr 10,319' TVD + .......N/A......— ... >.: N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 80 40 100 120 130 Subsequent to operation: 120 120 160 150 160 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil v El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -053 Contact Chad Helgeson Email chelgesonfahilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907 - 777 -8405 Date 3 d e l i w DMS MAR 0 7 1013 ? .,5' /7'45 Form 10 404 Revised 10 2 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33 -33 50- 133 - 20293 -00 176 -056 2/6/13 2/13/13 Daily Operations: 02/06/2013- Wednesday Finished RU Winterization Kit. Attempted to pull rods, rods not parted. Attempted to unseat pump. Could not jar free. Stacked rods out and performed back off. Rods backed off on the 8th connection. TOH W/ 7/ "8 Rods. Cameron wellhead rep installed BPV. Started ND Tbg head and started NU Bop's. 02/07/2013 - Thursday Finished NU Bop's. Tested BOP to 250 psi low and 3000 psi on high (witness waived by Jim Regg, AOGCC 2/6/13), tested Tested gas detection system, all test psi high, tested all manifold valves to 250 low/ 3000 high, este annular to 250 psi low and 1500 ps g / g g Y good. MU 2 -7/8" landing joint in top of tbg hanger, pulled lock pins and unseated tbg hanger. PU to 92K lbs on weight indicator, attempted to rotate to right and release latch assembly in top of packer. PU to 100K lbs, anchor not free. Slacked off to string weight and realized a break failure on Rig. Shut Rig Down and started replacing brake equipment. 02/08/2013 - Friday Finished installation of breaks. Noticed ground movement under base beam due to heaters. Rigged down work -over rig and winterization equipment. Moved in Rig mats and braced base beam up. MIRU Williams WO Rig and installed all winterization equipment. PU on landing joint and attempted to release latch assembly on packer again. No sucess. Started PU Power swivel. 02/09/2013 - Saturday RU power swizel. Stacked out tgb string to 20K. PU while rotating pipe to string weight at 95,000K. Released latch seal assembly and LD power swizel and continued OOH with 5 stands and 1 single. RU on rods. PU 5K over and backed off pony rod above oil jars. TOOH w /rods. MIRU EL, RIH and tag top of fish at 10,056'. PU 1' and perf tbg from 10,053' to 55'. Tbg went on vacuum. POOH and RD eline. 02/10/2013 - Sunday SOOH w/157 stands and 1 single, LD latch assemby, LD 2 jts of IBT 2 -7/8" tbg, seat nipple, chem injection sub, 40' of 4 -1/2" screens and 60' of 4 -1/2" blank pipe with the bullplug. The screens were covered up with scale. Striped out the jars, OS and pump. Between the plunger barrel of the plug was full of scale and solids. 02/11/2013 - Monday PU BHA, Bullplug, 60' of 4 -1/2" blank pipe, Slotted 6', seating nipple, 6 jts of 2 -7/8" EUE and the Anchor Latch assembly. RIH 100 stands of 2 -7/8 ". Made a decision to TOOH and replace the last 2,000' of 2 -7/8" tbg above latch assembly. TOOH and LD 64 jts and PU 64 jts of new 2 -7/8" tbg. TIH with 90 stands. PU chem injection sub at report time. 02/12/2013 - Tuesday TIH w/ 156 jts 2 -7/8" and chem injection sub (3,985'). Latched anchor assembly and PU 15k tenion. Marked and released anchor. PU hanger and spaced out with 10', 6', 6' and 5' sub. Landed hanger with 22k in tenion. Washed BOP stack and ND, NU PT. Prep rig to run rods. PU diptube and 2" pump. TIH w/ rods, the rod tongs were over torquing. SD waiting on replacement tongs at report time. 02/13/2013 - Wednesday PU new set of rod tongs, TIH w /rod and seated pump. Spaced pump out and hung off. Pumped 34 bbls and pressure tested pump to 500 psi, bled pressure back to 0 psi. Stroked pump with rig and pressured up to 500 psi. Tested good. Washed Roto Flex unit and WOR. RDMO WOR. • Ill Soldotna Creek Unit Well SCU 33 -33 SCHEMATIC Completion Date: 10 /7/11 PTD: 176 -056 Hilcoru Alaska. LLC API: 50- 133 - 20293 -00 RKB: 1537 GL: 125' MSL CASING DETAIL New KB -THF: 17' Size WT Grade Conn ID Top Btm 0 . 20" - - - - Surface 90' 20" 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 9-5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' TUBING 2 -7/8" 1 6.5 L -80 1 8RD EUE 1 2.441" 1 Surface 1 10,539' A SI13 -3/8" JEWELRY DETAIL B , Chemical No. Depth Length ID OD Item Inj Line Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 1 17.00' 0.56' 2.441" 11.00" 2 -W' 8rd Lift x Butt down. 2 3,951' 3.38' 2.441" 3.5" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line 0 3 10,317' 1.88' 2.441" 7.000" Baker 5 -22 anchor latch assembly (no seals), 190 -60 4 10,321 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) 5 10,522' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" © ' "'" 6 10,530' 3.88' 3.998" 5.188" Slotted Sub, 4.5" 0 7 10,590' 0.65' - 5.125" Bull plug cap 0 I ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod I E I > B 42' 3,290' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' - 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M ITI-i Stealth XL AF Rod Guides per rod, (129 rods) ti { r i 10,042' 350' 1 -1/2" Sinker bars E 10,522' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar q mum= v El I F 10,534' 12' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" re �� holes every 2" (90 deg phased) PERFORATIONS © Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 9/29/2011 G2 ,' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 10/2/2011 © S G-zone 10 10,510' 10,476' 10,508' 32' Re pert 8/6/01 1/3/2001 _ G -Zone G-zone 10,510' 10,512' 10,508' 10,510' 2' Re -perf 8/6/01; 8/31/09 1/3/2001 6 G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 HS 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 9/29/2011 © . H1 HI 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 10/2/2011 O H1 10,562' 10,588' 10,560' 10,586' 26' Re -perf 2/20/86 1/29/1977 H2 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 9/29/2011 • H3 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H4 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 9/29/2011 Junk @10,680' 10 -02 -11 • 114/115 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 10/2/2011 Corrected N H3 10,640' 10,645' 10,638' 10,643' 5' Re -perf 2/20/86 1/31/1977 measure : ::;, H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/29/2011 H4/H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 = `!'� H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 .-rG . 9-5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 TD = 17,689' PBTD = 11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re -perf 1/26/77; 2/20/86 1/17/1977 MAX HOLE ANGLE = 2 deg. @ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re -perf 2/20/86 1/17/1977 Updated by DMA 03 -05-13 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 12, 2012 SUBJECT: No -Flow Test Hilcorp / Swanson River Field SCU 33-33 PTD 1760560 Soldotna Creek Unit December 12, 2013: 1 traveled to Hilcorp's Swanson River Field to witness a No -Flow Test on well SCU 33-33. On my arrival on the wellsite I met with Hilcorp's Lead Operator Chris Walgenbach and we discussed the operational details of the test. Mr. Walgenbach indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Well SCU 33-33 was lined up from the tree top swab valve through an Nu-flo flow meter (0 to 2200 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours and unassisted gas and liquid flow from the well during this test did not exceed 900 SCF or 6.3 gal hourly flow rate. SCU 33-33 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Hilcorp's Swanson River Field well SCU 33-33. Attachments: none SWArmOCT a 9 2014, RJF 09/19/02 Page I of 1 2012-1212_No-Flow_SCU_33-33Jj.xlsx SC (�l. 33-33 17(�,Q sem, Regg, James B (DOA) From: Donnie Huffman [donnierhuffman@yahoo.com] Sent: Friday, February 08, 2013 4:00 PM To: Regg, James B (DOA) 6 Cc: Chad Helgeson; awhudgens75@yahoo.in Subject: Update Williams 405 WOR, Hi Jim, As per our conversation this afternoon, we are in process of rigging the rig down due to ground movement under our base beam. We have tested all bop and safety equipment yesterday. We then removed out 2 way check and installed a landing joint, we pulled our tbg hanger and noticed the rigs movement. I am not comfortable with the way it was moving so I hung the production string off, closed our 2 7/8 pipe rams and annular preventer on tbg, Installed a TIW and indside gray on top of tbg. We are not going to break any connections on well control or unhook and well control equipment. We will them Rig the rig down and install rig mats un er ase eam and rig to evenly distribute the weight load. We will then rig back up and continue operations. I will update you before starting back up. Thanks for your help this morning. Donnie Huffman 903-920-2953 dhuffinan(&hilcorp. com SCANNED OCT 0 9 2 . M4 v ,oF ,v THE STATE Alaska Oil and Gas 1 ..3 1.7..--.71,1 ®f l L lS -,- Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op, Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 SCANNED MAR 1 203 Fax: 907.276.7542 Chad Helgeson Operations Engineer Hilcorp Alaska, LLC J l'f - 0 5-6 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33 -33 Sundry Number: 313 -053 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 .e, Cathy P. • erster Chair DATED this Ocray of February, 2013. Encl. • • :,3 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 4 2013 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wet❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tub ind Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter CasinLJ Other. Rod Pump Replacement 0 , 2. Operator Name: 4. Current Well Class: 5. Permit to DriN Number. Hilcorp Alaska, LLC Exploratory ❑ Development - 176 -056 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number • Anchorage, Alaska 99503 50-133-20293-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Solddna Creek Unit (SCU) 33-33 • Will planned perforations require a spacing exception? Yes ❑ No 13 - 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028990 • Swanson River Field / Hemlock Od 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689 • 17,660 10,680 10,678 WA 10,680' (junk) Casing Length Size MD ND Burst Collapse Structural 90' 20" 90' 90' Conductor Surface 3,380' 13 -3/8" 3,380' 3,380' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.5# / L-80 10,547' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker F -1 Production Packer / N/A 10,354' MD - 10,352' TVD / N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ Development 9 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Operations: 02/07/13 Commencing il g p Q Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: .2 - 5 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Sc..L., ., GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true knd correct to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 Email chelgesonchilcorp.com Printed Name Chad Helgeson Title Operations Engineer Signature �� Phone 907 - 777 -8405 Date L 1 �i3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number ■3 Plug Integrity ❑ BOP Test 2 Mechanical Integrity Test ❑ Location Clearance ❑ Other: g-- . 3 pelt) x,_' 130P e -51 RBDMS FEB 11 201$ Spacing Exception Required? Yes ❑ No Subsequent Form Required: `6 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2 O _ 7 3 Z•�•/ 0,RiFeivNicAt. Submit Form and / ! c t, Approved application is valid for 12 months from the date of approval. ments in Duplicate • • • Well Prognosis Well: SCU 33 -33 Hilcorp Alaska, LL Date: 1/29/2013 Well Name: SCU 33 -33 API Number: 50- 133 - 20293 -00 , Current Status: Oil Producer Leg: N/A Estimated Start Date: February 7 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 176 -056 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1320332 Current Bottom Hole Pressure: — 1,500 psi @ 10,352' TVD (Fluid level calculations, 50% oil cut.) Maximum Expected BHP: -y 1,500 psi © 10,352' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 33 -33 was originally drilled and completed in February 1976 as an oil well. It was originally drilled to 17,000ft in the Jurassic, but was plugged back to the Hemlock and completed in the H -5 (tested gas), Added the H2 &3 later. SI well in 1977 due to high GOR. A workover was completed in 1986 where the tubing was replaced with a single packer completion. After the workover in 1986 it was the best producer in the field. In 2000 the well started to produce a lot of asphaltines. In 2001 the well was worked over, prefed in the Tyonek G Zone and a rod pump was installed. Rod pump and tubing changeouts, were completed in 2004, 2008, 2009 and 2011. Notes Regarding Wellbore Condition • Broken rods or pump assembly deep, based on Dyno testing. Tubing tested to 500 psi and no leaks • identified. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Williams 405 WO Rig 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods. (rack back the rods in basket) 6. RU fishing tools and RIH with rods and attempt to fish rods and pump from seat. a. If fish removal is successful and pump is pulled b. Drop standing valve to test tubing, Test tubing to 2,000 psi c. RU slickline, pull standing valve. d. RIH w/ bailer to tag bottom and clean out well sump. e. Once all debris has been cleaned out, RIH w/ magnet and clean well f. PU dip tube, NEW rod pump, RIH with tapered rod string (sinker bars, 3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install polish rod. • • Well Prognosis Well: SCU 33 -33 Hilcorp Alaska, LL Date: 1/29/2013 g. ND rod stripper head, install surface equipment onto well and test. h. RD Williams #405. i. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. j. Return to production I 7. If unable to fish pump, RU a -line, RIH top top of fish and tubing punch tubing between collars as 1 V deep as possible. �� +;,5� 1 8. Circulate PW, kill the well, circulate out all oil. 9. Set TWC, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi �v high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures.• a. Notify AOGCC 24hrs in advance to witness, be ready to test when /if inspector arrives b V b. Ensure winterization package is completely installed 10. Remove TWC, pull J -latch tubing hanger. 11. Pull tubing from seal assembly (do not exceed 75% of tubing strength, 108,750 #) 12. Pull 2 -7/8" 8rd EUE tubing, rack back tubing string. 13. Remove rods and pump from tubing string. 14. RU slickline 15. RIH w/ 3" bailer, tag bottom and get sample. 16. If fill covers perfs, bail sand from well. 17. PU 2 -7/8" 8rd EUE L -80 tubing with a redressed seal assembly and run new BHA (No chemical injection mandrel below seal assembly, it will be located at 4,000ft.) 18. Land tubing in seal assembly and tubing hanger. 19. Install TWC. 20. ND BOPE, NU tree and test. 21. NU Rod stripper. 22. PU new dip tube, new rod pump, RIH with tapered rod string (sinker bars, 3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install polish rod. 23. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 24. RD Williams #405. 25. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. • 26. Return to production with same surface safety system as previously installed. Attachments Existing Schematic Proposed Schematic — w/ tubing changeout if necessary BOP Schematic . • Soldotna Creek Unit Well SCU 33 -33 Complet Date: 10 -07 -11 SCHEMATIC PTD: 176 -056 ion Hilcoru Alaska. LLC API: 50- 133 - 20293 -00 RKB: 1537 GL: 125' MSL New KB 17 CASING DETAIL > Size WT Grade Conn ID Top Btm i i r L20" 20" - - - - Surface 90' Q 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 9-5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' TUBING 2 -7/8" 6.5 L -80 1 8RD EUE 1 2.441" Surface I 10,547' © L > JEWELRY DETAIL 13 -3 /8" No. Depth Length ID OD Item B , Chemical 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, Inj Line 11" DCB x 2 -h" 8rd Lift x Butt down. 2 3,063' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,353' 1.88' 2.441" 7.000" Baker S -22 anchor latch assembly (no seals), 190 -60 4 10,354' 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) ra 5 10,435' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" > 6 10,436' 4.10' 2.441" 4.335" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line 7 10,444' 102' 3.958" 5.125" 40' of 4 -1/2" Wire Wrap Screen. (two 20' jts) 0 60' of 4 -1/2" Blank Pipe w/ bull plug ; 8 10,547' .65' - 5.188" Bull plug I ROD DETAIL No. Depth Length ID OD Item A 0' 34' 1.500" Polish Rod B 42' 3,275' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" D > R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" , I, J :4 4)L .,),,, l‘ - R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod, (129 rods) © > 10,042' 350' 1 -1/2" Sinker bars (14 bars) E 10,436' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar L{ l� F 10,499' 63.02' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" i III , © holes every 2" (90 deg phased) 111111111111111111 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 9/29/2011 I I G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 10/2/2011 G -zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8/6/01 1/3/2001 © G -zone 10,510' 10,512' 10,508' 10,510' 2' Re perf 8/6/01; 8/31/09 1/3/2001 = G -zone 10,512' 10,544' 10,510 10,542' 32' 8/31/2009 El HI10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 9/29/2011 HI 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 10/2/2011 ` l I G -Zone H1 10,562' 10,588' 10,560' 10,586' 26' Re -perf 2/20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 10,547.2' ---$31101M H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium 5spf 9/29/2011 111 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H2 H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 9/29/2011 Junk @ 10,680' H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 10/2/2011 10 -02 -11 • H3 H3 10,640' 10,645' 10,638' 10,643' 5' Re -perf 2/20/86 1/31/1977 Corrected measur:U H4 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4 -5/8" Millennium 5spf 9/29/2011 ::I H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -perf 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 ':'':- .�•�ti.-.- H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 H5 10,680' 10,702' 10,678' 10,700' 22' Re -perf 2/20/86 1/26/1977 - 9 -5/8" H5 10,702' 10,710' 10,700' 10,708' 8' Re -perf 1/26/77; 2/20/86 1/17/1977 TD = 17,689' PBTD= 11,138' H5 10,710' 10,712' 10,708' 10,710' 2' Re -perf 2/20/86 1/17/1977 MAX HOLE ANGLE =2 deg. @ 6,100' Updated by DMA 01 -29 -13 • • Soldotna Creek Unit Well SCU 33 -33 PROPOSED Completion Date: 10 -07 -11 PTD: 176 -056 Hilcoru Alaska, LLC API: 50- 133 - 20293 -00 RKB: 1537 GL: 125' MSL New KB -THF: 17' CASING DETAIL Size WT Grade Conn ID Top Btm 0 ,"11111;1 20" - - - - Surface 90' 20' 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 0 9-5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' TUBING 2 -7/8" 1 6.5 1 L -80 1 8RD EUE 1 2.441" I Surface 1 10,547' 2 A . ■ 13 -3/8" JEWELRY DETAIL B „ Chemical No. Depth Length ID OD Item Inj Line 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2 -N" 8rd Lift x Butt down. 2 3,063' 1.00' 2.441" 5.000" Depth Indicator Sub 0 3 4,200' 2.2' 2.441" 3.5" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line 4 10,353' 1.88' 2.441" 7.000" Baker 5 -22 anchor latch assembly (no seals), 190 -60 5 10,354' 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) © ' '" 6 10,535' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" 40' of 4 -1/2" Wire Wrap Screen. (two 20' jts) 7 10,554' 102' 3.958" 5.125' ; 60' of 4 -1/2" Blank Pipe w/ bull plug 0 8 10,650' 0.65' - 5.188" Bull plug I ROD DETAIL No. Depth Length ID OD Item A 0' 34' - 1.500" Polish Rod D ) B 42' 3,275' - 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods C 3,317' 3,500' - 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' - 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M III > ' Stealth XL AF Rod Guides per rod, (129 rods) Lj t 11 10,042' 350' - 1 -1/2" Sinker bars (14 bars) �. E 10,535' 43.50' 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar inomninm © ( F 10,555' 16' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" a r holes every 2" (90 deg phased) - PERFORATIONS © Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comments Date I . G2 10,476' 10,510' 10,352' 10,508' 34' 4-5/8" Millennium Sspf 9/29/2011 G2 10,476' 10,510' 10,352' 10,508' 34' 4 -5/8" Millennium 5spf 10/2/2011 6 G zone 10,478' 10,510' 10,476' 10,508' 32' Re -pert 8 /6/01 1/3/2001 G -zone 10,510' 10,512' 10,508' 10,510' 2' Re -perf 8/6/01; 8/31/09 1/3/2001 El G -zone 10,512' 10,544' 10,510' 10,542' 32' 8/31/2009 _ .t. HI 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 9/29/2011 0 G -Zone H1 10,553' 10,586' 10,551' 10,584' 33' 4 -5/8" Millennium 5spf 10/2/2011 10,547.2' -.- ' H1 10,562' 10,588' 10,560' 10,586' 26' Re -pert 2 /20/86 1/29/1977 H2 10,588' 10,602' 10,586' 10,586' 14' 8/31/2009 1111 H2 10,592' 10,624' 10,590' 10,622' 32' 4-5/8" Millennium 5spf 9/29/2011 • H2 H2 10,592' 10,624' 10,590' 10,622' 32' 4 -5/8" Millennium Sspf 10/2/2011 H2 10,610' 10,628' 10,608' 10,626' 18' Re -perf 2/20/86 1/31/1977 • H2 Junk @ 10,680' H3 10,638' 10,643' 10,636' 10,641' 5' 4 -5/8" Millennium 5spf 9/29/2011 10 -02 -11 • H3 H3 10,638' 10,643' 10,636' 10,641' 5' 4-5/8" Millennium 5spf 10/2/2011 Corrected measur.0 H4 H3 10,640' 10,645' 10,638' 10,643' 5' Re -pert 2/20/86 1/31/1977 H5 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 9/29/2011 H4 /H5 10,648' 10,679' 10,646' 10,677' 31' 4-5/8" Millennium 5spf 10/2/2011 H4 10,651' 10,658' 10,649' 10,656' 7' Re -pert 2/20/86 1/31/1977 H4 10,658' 10,665' 10,656' 10,663' 7' 2/20/1986 : � H5 10,670' 10,680' 10,668' 10,678' 10' 2/20/1986 9 -5/8" H5 10,680' 10,702' 10,678' 10,700' 22' Re -pert 2/20/86 1/26/1977 TD = 17,689' PBTD = 11,138' H5 10,702' 10,710' 10,700' 10,708' 8' Re -pert 1/26/77; 2/20/86 1/17/1977 MAX HOLE ANGLE = 2 deg. @ 6,100' H5 10,710' 10,712' 10,708' 10,710' 2' Re -pert 2/20/86 1/17/1977 Updated by DMA 01 -29 -13 • • . Swanson River SCU 33 -33 11ile..n %kakis. 1.1.11. 01/29/2013 Swanson River Williams BOP 2013 • v iii 1 1 1 • 3.46' 111 Ill Ill Ill 111 Shaffer LWS � ■'_3 �' .4 * 2.75' 11" SM 1` 11 2 1/16 10M Choke and Kill Valves 111 1!1 1!I IP1 111 i i � • ? C . �J l� • •• i 2.00' i Ale" i . 1• -1l1 1a1 1� vt i • � 111 1!1 i!1 1!1 101 X 2.00 - 9" 5M ail, , \ q'in lei i � 1!1 1 ,..01, E I , ip,,!: „. 1 E ptioil __I .-... 1 .. : En Itc, I IL; .,.. „., :. . i ® 1 1i1 III 11 it III - 0 ! III � ICI i t , "� -1- TIO i ' • Page 1 of 1 a • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 05, 2013 4:29 PM To: 'Chad Helgeson'; Ferguson, Victoria L (DOA) Subject: RE: Sundry for Rod pump well (SCU 33 -33 PTD 176 -056) Chad, You haue.verhaI approval to work over well SCU 33 -33 as proposed in your emailed copy of the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Monday, February 04, 2013 12:56 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: Sundry for Rod pump well Guy /Victoria, We submitted a sundry this morning for Soldotna Creek 33 -33 Rod pump Well. We are moving onto this well this week (sorry for the late notice). The summary of the work is to try and pull the pump and change it out. The rods broke on us about 10 days ago. I have a suspicion that we will have to pull the tubing to retrieve the pump, (we think the rods broke at the pump and may not be able to fish it.) If we pull the tubing we do not plan to add perfs or anything, just remove the pump and change out anything on the bottom of the completion that gets damaged during the removal. Let me know if you have any questions. I'II be more than happy to get back with you right away. Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907 -777 -8405 Mobile: 907 - 229 -4824 2/8/2013 • scc� 33_:3 P 17�os�&, Regg, James B (DOA) From: Sent: To: Subject: Attachments: attachments Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Regg, James B (DOA) Monday, December 03, 2012 2:41 PM Grimaldi, Louis R (DOA) RE: SRU rod pump wells SSV SCU 13-34 No Flow.pdf; SCU 33-33 no flow.pdf From: Regg, James B (DOA) Sent: Monday, December 03, 2012 2:40 PM To: Grimaldi, Louis R (DOA) Subject: RE: SRU rod pump wells SSV --7 irk ---7 't -f- Cil r S�ANNEp ?wt 5 Ctt 3 3- A)d fZuw 7r_sa- VIZ71 76) rtiv�s Appears I mis-spoke in my email yesterday (at least somewhat). According to 20 AAC 25.265(c)(8), both wells were required to obtain approval from AOGCC to continue operating without SSV by December 3, 2011. No request was received from then -operator Union Oil of California (Hilcorp did not take over field ops until Jan 1, 2012). SCU 13-34 (PTD 1710210) 1 researched this some more this morning; well has been approved (apparently) to operate without SSV based on passing no flow tests — see attached. I don't find the specific approval allowing the well to operate w/o SSV, but not sure why we would witness no flow tests unless it was our intention to allow. They would still be required to seek AOGCC approval to keep in operation. SCU 33-33 (PTD 1760560) Indicates that there was no flow test done but I don't find a record of Inspector witness, nor do I find specific approval allowing the well to operate w/o SSV. Same situation as SCU 13-34. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Sunday, December 02, 2012 10:19 PM To: Grimaldi, Louis R (DOA) Subject: Re: SRU rod pump wells SSV no variance exists on rod pump wells so SSV is required by regulation. "Grimaldi, Louis R (DOA)" <Iou.grimaldiC&alaska.gov> wrote: Jim, During my tests on Thursday I came ass two wells that were on rod pumps. These wells had Low Pressure pilots that \would strut the rod pump mechanism down nearly immediately but the system lacked a Surface Safety Valve. One well 33-33 had a pressure regulator outside of the wing valve that kept a small amount of back pressure on the well (280 flowing/130 downstream regulator). The other well 13-34 was flowing at about 130 psi without any regulator present. I believe the regulators purpose was to keep gas from breaking out in the tubing at the pump. The IA and tubing were tied together with a 'T section". I had them trip the LP sensor and watched the pump jack stop within 30 seconds. There was additional tubing/casing gas feeding the flowline and without a SSV there was nothing to bleed down to test. It would have been helpful if the well pressure fell off but it seemed to remain at the pressure that was present when the LPP was tripped. I have included a picture of 13-34 I had not heard of a variance for these wells so I would like to know if they are supposed to have a SSV - 13 -34 171-0210 33-33 176-0560 Lou Grimaldi Alaska Oil and Gas Conservation Commission Petroleum Inspector Home 776-5402 Cell 252-3409 Lou. Grimaldi(a-)Alaska.gov TE OF ALASKA r ALASKA OIL AN S CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Clean Out Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate EI Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 176 -056 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 133 - 20293 -00 r QQ 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 [Soldotna Creek Unit] Soldotna Creek Unit (SCU 33 -33) 9. Field /Pool(s): Swanson River Field / Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 17,689 feet Plugs measured N/A feet true vertical 17,659 feet Junk measured 10,680 (Junk) feet Effective Depth measured 10,680 feet Packer measured 10,354 feet true vertical 10,678 feet true vertical 10,352 feet I Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 89' Conductor . Surface 3,380' 13 -3/8" 3,380' 3,379' 3,450psi 1,950psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150psi 7,100psi Liner Perforation depth Measured depth See Schematic feet I / 7 a j True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5 #/ L -80 10,547' 10,545' Packers and SSSV (type, measured and true vertical depth) Baker F -1 10,354'(MD) Production Packer 10,352' (TVD) N/A N/A . I ` - I, 11. Stimulation or cement squeeze summary: NOV 01 Intervals treated (measured): Top of the G2 zone to the Bottom of the F5 zone. Please reference the attached Schematic. Treatment descriptions including volumes used and final pressure: Atoka Oil & Gas Cons. Commission Solvent 25bbls & Acid 23bbls. Spotted across perfs (above.) rtC' ". ;:t 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 105 60 90 150 170 Subsequent to operation: 86 49 212 130 140 13. Attachments: 14. Well Class after work: o Copies of Logs and Surveys Run N/A Exploratory❑ Development b Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil 0 • Gas fl WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 311 -261 Contact Marcus Barbee Phone: 263 -7605 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature "C -. Ath ....." Phone 276 -7600 Date 11/3/2011 paDMJ c� :.111 20 ‘ 10 -404 Revised 10/20 10 Submit Original Only • Sw�n River Field r o SC 3-33 Chevron Actual Completion 10 -07 -11 API# 50 -133- 20293 -00 RKB: 153'/ GL: 125' MSL CASING AND TUBING DETAIL New KB - THF: 17' SIZE WT GRADE CONN ID TOP BTM. 0 - L 20" - - - - Surface 90' 1 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' el 9 -5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' Tubing 2 -7/8" 6.5 1 L -80 1 8RD EUE 1 2.441" 1 Surface 1 10,547' II , DETAIL N Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB B Chemical x 2 -' /g" 8rd Lift x Butt down. Inj line 2 3,063' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,353' 1.88' 2.441" 7.000" Baker S -22 anchor latch assembly (no seals), 190 -60 4 10,354' 2.55' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 10- 03 -11) 5 10,435' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" 6 10,436' 4.10' 2.441" 4.335" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line 7 10,444' 102' 3.958" 5.125" 40' of4 -1/2" Wire Wrap Screen. (two 20' jts) 60' of 4-1/2" Blank Pipe w/ bull plug - 8 10,547' .65 - 5.188" Bull plug N O 1 , ROD DETAIL a NO. Depth Length ID OD Item A 0' 34' 1.500" Polish Rod B 42' 3,275' 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & (2) 1" x 8' EL Pony Spacer Rods D ■ C 3,317' 3,500' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod (140 rods) D 6,817' 3,225' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) 2.25" R &M Stealth XL AF Rod Guides per rod, (129 rods) 10,042' 350' - 1 -1/2" Sinker bars (14 bars) E 10,436' 43.50 1.75" 2.250" 1 -3/4" RHBC Pump w/ Stabilizer Bar © F 10,499' 63.02' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" holes I I a l every 2" (90deg phased) J Perforation Intervals 0 11111111111111111111111 I Date Zone Top(MD) Btm(MD) Amt Comments Top(TVD) Btm(TVD) it FA 9/29/2011 G2 10,476' 10,510' 34' 4 - 5/8" Millennium 5spf 10,352' 10,508' 10/2/2011 G2 10,476' 10,510' 34' 4 - 5/8" Millennium 5spf 10,352' 10,508' 1/3/2001 G -zone 10,478' 10,510' 32' Re -perf 8/6/01 10,476' 10,508' © 1/3/2001 G -zone 10,510' 10,512' 2' Re -perf 8 /6/01; 8/31/09 10,508' 10,510' 8/31/2009 G-zone 10,512' 10,544' 32' 10,510' 10,542' • Fl 4 9/29/2011 Hl 10,553' 10,586' 33' 4 -5/8" Millennium 5spf 10,551' 10,584' 10/2/2011 Hl 10,553' 10,586' 33' 4 -5/8" Millennium Sspf 10,551' 10,584' 6 0 = 1/29/1977 HI 10,562' 10,588' 26' Re -perf 2/20/86 10,560' 10,586' 8/31/2009 H2 10,588' 10,602' 14' 10,586' 10,586' © I G-Zone 9/29/2011 H2 10,592' 10,624' 32' 4 -5/8" Millennium Sspf 10,590' 10,622' 10,547.2'x' 10/2/2011 H2 10,592' 10,624' 32' 4 -5/8" Millennium 5spf 10,590' 10,622' 1/31/1977 H2 10,610' 10,628' 18' Re -perf 2 /20/86 10,608' 10,626' I in 9/29/2011 H3 10,638' 10,643' 5' 4 -5/8" Millennium Sspf 10,636' 10,641' 10/2/2011 H3 10,638' 10,643' 5' 4 -5/8" Millennium Sspf 10,636' 10,641' Junk @10,680' 1/31/1977 H3 10,640' 10,645' 5' Re -perf2 /20/86 10,638' 10,643' 10 -02 -11 • H3 Corn ctedmeasurII H4 9/29/2011 H4/H5 10,648' 10,679' 31' 4-5/8" Millennium Sspf 10,646' 10,677' 10/2/2011 H4/H5 10,648' 10,679' 31' 4 -5/8 "Millennium Sspf 10,646' 10,677' I 1/31/1977 H4 10,651' 10,658' 7' Re -perf 2 /20/86 10,649' 10,656' 2/20/1986 H4 10,658' 10,665' 7' 10,656' 10,663' 2/20/1986 H5 10,670' 10,680' 10' 10,668' 10,678' >_ > >- 1/26/1977 H5 10,680' 10,702' 22' Re -perf 2 /20/86 10,678' 10,700' TD =17,689' PBTD= 11,138' 1/17/1977 H5 10,702' 10,710' 8' Re -perf 1/26/77; 2/20/86 10,700' 10,708' MAX HOLE ANGLE =2 deg. @ 6100' 1/17/1977 H5 10,710' 10,712' 2' Re -perf 2/20/86 10,708' 10,710' SCU 33 -33 Current WBD 10 -26 -11 REV 1.docx Updated by TDF 10 -27 -11 Chevron • • 1 %0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 33 -33 SOLDOTNA CK UNIT 33 -33 FEDA028990 5013320293 QB0763 153.00 JOB ' ° ` `, . Primary Job Type Job Category Objective Actual Start Date Actual End Date Clean -Out Major Rig Clean out & re- complete 9/8/2011 10/7/2011 Work Over (MRWO) Primary Wellbore Affected Welibore U M Well Permit Number SCU 33 -33 501332029300 1760560 9/8/2011 00:00 - 9/9/2011 00:00 Operations Summary Bled csg & tbg, MU & test Ratigan to 500psi, unseat pump, pump solvent to clean rods, POOH racking back rod string, laying down pump assembly. Notified AOGCC and BLM of upcoming BOP test, Jim Regg and Tom Zelenka both waived witness. 9/9/2011 00:00 - 9/10/2011 00:00 Operations Summary ND tree / NU BOPE & test 250psi low/ 3,000psi high. Unseat hanger and POOH with 2 -7/8" tubing from 10324'. 9/10/2011 00:00 - 9/11/2011 00:00 Operations Summary POOH with production tubing. 9/11/2011 00:00 - 9112/2011 00:00 Operations Summary LD lower completion BHA (note: latch was left in the hole off of the A -22 Anchor & (14] 3/4" SS bands were not accounted for). PU MU Cyclone bailer BHA. 9/12/2011 00:00 - 9/13/2011 00:00 Operations Summary RIH W /Cyclone bailer, work tools w/o making hole, tagged bottom @ 10,630' RKB, POOH 9/13/2011 00:00 - 9/14/2011 00:00 Operations Summary Run Cyclone bailer # 2, tagged bottom @ 10,630' RKB. RU Slickline, RIH slick line magnet and recover small metal debris, run pump bailer and recover small metal debris, sand and scale. 9/14/2011 00:00 - 9/15/2011 00:00 Operations Summary RIH 2 magnet runs, 2 bailer runs, 1 wire brush and 1 (8.35 ") gauge ring, tag bottom at 10,642' with slickline. Minimal recovery of metal debris with magnets and bailers, no recovery with wire brush. RD Slickline. 9/15/2011 00:00 - 9/16/2011 00:00 Operations Summary Pump Calcium Carbonate in three (3) seperate stages. Stood well up and circulated 8.7ppg 6% KCI to surface. Notified AOGCC and BLM of upcoming BOPE test. 9/16/2011 00:00 - 9/17/2011 00:00 Operations Summary Continue to circulate 8.7ppg 6% KCI, POOH, test annular to 250psi low/ 2,500psi high, test BOPE to 250psi low/ 3,000psi high, witness waived by John Crisp and Jim Regg of AOGCC and Tom Zelenka of BLM. 9/17/2011 00:00 - 9/18/2011 00:00 Operations Summary PUMU 8.4" packer milling BHA, RIH to 10,335' WLM, pump LCM pill. Begin packer milling operations at 10,323'. 9118/2011 00:00 - 9/19/2011 00:00 Operations Summary Continue to mill packer to 10,325', POOH and recovered milled packer, RIH with 8 -1/4" shoe, 7 -5/8" wash pipe clean out BHA to 10,534'. 9/19/2011 00:00 - 9/20/2011 00:00 Operations Summary Begin to clean out with 8 -1/4" shoe and 7 -5/8" wash pipe from 10,534' - 10,643'. 9/20/2011 00:00 - 9/21/2011 00:00 Operations Summary POOH with 8 -1/4" shoe assy, recovered scale cuttings. PUMU 8.25" packer milling assy w/ boot baskets & 6 collars. Begin to RIH w/ same. 9/21/2011 00:00 - 9/22/2011 00:00 Operations Summary Continue to RIH w/8.25" packer milling assy, work tools © 10,656'. POOH, recover parts of strip guns, metal bands and scale. 9/22/2011 00:00 - 9/23/2011 00:00 Operations Summary MIRU a -line & RIH w /1- 11/16" tool string w/ gamma ray, CCL and begin log from 10,656' to 9,500' POOH w/ logging tools. Notified the AOGCC and BLM of upcoming BOPE test. Complete Log from 10,656' - 9,500' found bottom @ 10,656' ELM, RD E- line.Test BOPE 250psi low/ 3,000psi high, annular 250psi low/ 1,500psi high (witness waived by Matt Herrea - AOGCC and Tom Zelenka - BLM). PUMU 8 -1/4" burn shoe w/ 7 -5/8" wash pipe and begin RIH. 9123/2011,00;00.9124 /20'11100;00 - . Operations Summary Continue to RIH w/8 -1/4" clean out assy to 10,642' work tools to 10,643', unable to make hole. POOH & PUMU 8 -1/4" drag tooth shoe w/ 5 -3/4" wash pipe and begin RIH. Chevron • IMO Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface U M ChevNo Original RKB (ft) Water Depth (ft) SCU 33 -33 SOLDOTNA CK UNIT 33 -33 FEDA028990 5013320293 QB0763 153.00 Daily C164'• • • 9124/2011 00:00 - 9/25/2011 00:00 Operations Summary Continue to RIH w/ 8 -1/4" clean out assy to 10,654', work tools to 10,668', unable to work deeper. pump calcium carbonate pill & begin to POOH. 9/25/2011 00:00 - 9/26/2011 00:00 Operations Summary Continue POOH with C/O BHA, recovered wadded up ball of slick line and some perf debris. MU same assembly and RIH to 10,668', establish C/O parameters and begin C/O operations 9/26/2011 00:00 - 9/27/2011 00:00 Operations Summary Work C/O BHA to 10,684' work string measure, unable to work deeper. PUH to 10,437', open circ sub and pump calcium carbonate pill. POOH w/ C/O BHA. Recovered wadded up ball of slick line and perf debris. LD C/O BHA and MIRU E -line to correlate bottom, begin RIH w/ logging gamma ray & ccl BHA. 9/27/2011 00:00 - 9/28/2011 00:00 Operations Summary Continue to RIH with logging tools to 10,685' WLM and log bottom 1,000' of hole. POOH & RD E -line. PUMU 4 -5/8" TCP gun assy w/ CHAMP pkr and begin RIH. 9/28/2011 00:00 - 9/29/2011 00:00 Operations Summary Continue to RIH with TCP assy to 10,680', correlate depth with Gamma ray CCL, TCP assembly 5' off of desired depth, unable to put guns on depth. POOH with TCP assy. Stand back champ pkr & add 2 full joints above guns, begin to MU pkr and RIH on 3 -1/2" work string. 9/29/2011 00:00 - 9/30/2011 00:00 Operations Summary Continue to RIH w/3 -1/2" work string, Champ pkr & TCP 5 shot per foot 60 degree assy to 10,680', set packer with top shot at 10,476' and bottom shot at 10,679', spot stimulation pill at packer, adjust work string pressure, drop bar and fire guns (w /positive indication of detonation). Pump 25bbls of solvent with sized salt pill and stand well up. Reverse circulate to clean up remaining pill and begin POOH. Notify AOGCC and BLM of upcoming BOPE test. 9/30/2011 00:00 - 10/1/2011 00:00 Operations Summary Continue POOH to surface. Lay down guns (all shots fired). Perform BOPE test to 250psi low/ 3,000psi high, annular 250psi low/ 1,500psi high, witness waived by Jim Regg and Tom Zelenka. 10/1/2011 00:00 - 10/2/2011 00:00 Operations Summary PU 2 -7/8" production tubing and RIH to 10,677'. Circulate 23 Bbls Oil safe AR and spot across perforations. POOH racking back 2 -7/8" production tubing from 10,677'. 10/2/2011 00:00 - 10/3/2011 00:00 Operations Summary Continue to POOH. PUMU 4 -5/8" TCP 5 shot per foot 60 degree guns with identical configuration and RIH on 2 -7/8" production tubing to 10,691.5' production tubing measure (correlated to 10,680' ELM) Set pkr @ 10,374' w/ top shot 10.476' and bottom shot 10 679', spot oil safe AR at ported sub and drop bar to fire guns (w/ positive indication of detonation) bull head oil safe AR into perforations with of 6% KCL. Release packer and begin POOH from 10,679'. 10/3/2011 00:00 - 10/4/2011 00:00 Operations Summary Continue to POOH with 4 -5/8" TCP assy, all shots fired. PUMU 192 -60 Baker Model 'F' packer & RIH on 2 -7/8" production tubing to 10,364' (10,354' corrected measure) Set packer and confirm set with 50K down weight, release from packer and POOH w/ Model 'B' setting tool. OOH, LD setting tool, prepare rig floor to run completion tubing. 10/4/2011 00:00 - 10/5/2011 00:00 Operations Summary PUMU 4 -1/2" tail pipe and screen assembly, chemical injection mandrel, seating cup nipple and S -22 Anchor latch and begin RIH on 2 -7/8" 6.4# L -80 production tubing. 10/5/2011 00:00 - 10/6/2011 00:00 Operations Summary Continue to run in the hole with 2 -7/8" production tubing from 6,900' to 10,476'. Pick up , Make up 11" seaboard tension set surface hanger assembly, run in and land same. Jay out of surface hanger and run in 4.2' and land production tubing into packer at 10,354' and pull back into surface hanger with over pull. Nipple down BOPE and nipple up tree, test same 250 psi low and 5,000 psi high. Pick up rod handling equipment, pick up and run in the hole with rod pump on tapered rod string from 456' to 3,681'. 10/6/2011 00:00 - 10/7/2011 00:00 Operations Summary Continue to run rods from 3,681' to 10,435', space out and land pump in seating nipple. Rig down and move to SCU 32 -08 • • Aubert, Winton G (DOA) From: Barbee, Marcus [APRS] [Marcus.Barbeecchevron.com] 1 74. - CJ $ (p Sent: Friday, September 16, 2011 10:08 AM To: Tzelenkacblm.gov; jtmiller©' blm.gov; Aubert, Winton G (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: FW: 10 -403 Sundry # 311 -261 / 3160 -5 BLM for well SCU 33 -33 Gentlemen, Chevron has successfully pulled rods and production tubing in well SCU 33 -33. We are currently unable to clean out the well using Jet 'A' and not maintaining a fluid level. Chevron is planning to make the following changes to our approved procedure • Pump Calcium carbonate pill across zone and circulate the well to 6% KCI • Mill and recover production packer located @ 10,323' • Clean out fill with conventional clean out BHA to original planned depth • TCP (same as previous), pump solvent treatment followed by sized salt pill • Run new completion packer • Run completion assembly as previously indicated in sundry application If you have any questions please do not hesitate to call 41 9 d Wellbore Maintenance Team Chevron, Alaska 1- 907 - 263 -7605 Office *NNW s ! 1- 907 - 250 -1163 Cell 1- 907 - 745 -2386 Home This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format Thank You. i 1 3 Tr 9 6 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California „® 0 J 4 P.O. Box 196247 I 1 b Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 33 -33 Sundry Number: 311 -261 Dear Mr. Brandenburg: Ada) SEA t 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this f day of September, 2011. Encl. , an, • tot #e- • RECEIVE!? (,,ek. STATE OF ALASKA $1; Ito « ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 5 201 APPLICATION FOR SUNDRY APPROVAA a is & Gas Cams. Commission 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Afigiterefewed Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El - Pull Tubing El - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0 - Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 - Exploratory ❑ 176 -056 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O> Box 196247, Anchorage, Alaska 99519 50- 133 - 20293 -00■• 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Soldotna Creek Unit (SCU 33 -33) 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028990 [Soldotna Creek Unit] - Swanson River Field / Hemlock Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689' - 17,659' - 10,613' 10,611' - N/A 10,613' fill Casing Length Size MD / TVD Burst Collapse Structural 90' 20" 90' 89' Conductor Surface 3,380' 13 -3/8" 3,380' 3,379' 3,450 psi 1,950 psi Intermediate Production 11,350' 9 -5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Actual Schematic See Actual Schematic 2 -7/8" 6.5#/ L -80 • 10,443' i Packers and SSSV Type: Baker F -1 production packer and N/A Packers and SSSV MD (ft) and TVD (ft): 10,323' MD / 10,321' TVD and N/A / 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: ((7� 9/1/ 11 Oil El - Gas ❑ WDSPL ❑ Suspended ❑ pp 16. Verbal Approval: \ „/ Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee Phone 263 -7605 Printed Name pe Timothy C. Brandenb r Title Drilling Manager Signature I \ Phone 276 -7600 Date 8/24/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 - a Plug Integrity ❑ BOP Test Et Mechanical Integrity Test ❑ Location Clearance ❑ Other: TA.*- B 0 P E -(-0 3 0 0 0 ' 0 , Subsequent Form Required: 1 0 — 40 tt APPROVED BY Approved by: A COMMISSIONER THE COMMISSION Date: /) R I INAL Form 10 -403 Revised 1 /DNIS SEP 0 1. Zp • � Submit in Duplicate Chevron • • Swanson River SCU 33 -33 %. 8/24/2011 OBJECTIVE: Pull existing completion, clean out fill to +1- 10,762, spot solvent treatment across perforated interval, re- perforate all existing open perforations, re- complete with new rod pump, screens, and chemical injection below the pump. Current BHP: 2,823 psi @ 10,476' TVD _ Max Do hole Pressure: 2,823 psi @ 10,476' TVD 117 C f MAS 0 si ((Based on actual reservoir conditions and water cut of 65% (0.402psi /ft) with added Safety F r of 1000' TVD of oil cap) PROCEDURE SUMMARY: 1 Prep location and pad, de- couple and roll back Rotaflex pumping unit. 2 MIRU Key Energy Rig # 3. 3 Strip rod surface equipment off well & NU rod BOP, and test same to 500 psi. 4 Lay down polish rod and Unseat rod pump. 5 Pull & rack back EL rods, LD pump Assembly. i 6 Install BPV, ND tree, NU BOPE & test same 250 psi low/ 3,000 psi high, test annular to 250 psi low/ 1,500 psi high. 7 PUMU landing joint, unseat mandrel from tension hanger, lower string to neutral & release anchor. 8 Pull 2 -7/8" production tubing and lay down same. 9 Run in hole with Cyclone tubing bailer and clean out fill to +1-10,762' or refusal. 10 PUMU TCP guns RIH and re- perforate existing open perforations, spot solvent and allow to soak prior to perforating. 11 PUMU screen, chemical injection sub, seating nipple, spacer pipe & parallel flow head anchor seal assembly. 12 RIH on 2 -7/8" production tubing, space out, latch into packer @ 10,323', and land tubing in tension. 13 Install BPV, ND BOPE, NU tree, test same, NU rod BOPE & test same. 14 PU dip -tube, rod pump & sinker bars, RIH on tapered rod string, land the pump, space out the rods, install the polish rod. 15 ND rod BOPE and strip surface equipment onto well. ,- 16 RDMOL Key Energy Rig # 3. 17 Roll back Rotaflex pumping unit and Re- couple same. 18 Return the well to production. l SCU 33 -33 REVISED BY: TDF 8/24/2011 • • Swanson River Field 4 . . SCU 33 -33 Chevron Actual Completion 10 -16 -09 API# 50- 133 - 20293 -00 RKB: 153'/ GL: 125' AMSL New KB - THF: 18.44' CASING AND TUBING DETAIL © L SIZE WT GRADE CONN ID TOP BTM. 20" Surface 90' 0 13 -3/8" 68 K -55 BTC 12.415" Surface 3,380' 9 -5/8" 47 S -95 BTS 8.681" Surface 6,295' 53.5 S -95 BTS 8.535" 6,295' 11,350' Tubing 2 -7/8" 6.5 L -80 8RD EUE 2.441" Surface 10,443' Ill L > B heroical Inj Line JEWELRY DETAIL NO. Depth Length ID OD Item 1 17.00' 0.56' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2 -'/," 8rd Lift x Butt down. IN > 2 3,050' 1.00' 2.441" 5.000" Depth Indicator Sub 3 10,322' 1.88' 2.441" 7.000" Type S Tubing Hanger Latch, 190-60 4 10,323' 2.00' 6.000" 8.218" Baker "F -1" 190 -60 Retainer Production Packer (Set 7/28/01) 5 10,436' 1.05' 2.313" 3.063" Cup Type Seating Nipple, 2 -7/8" 6 10,437' 4.10' 2.441" 4.335" Chemical Injection Sub w/ 3/8" SS Chemical Inj Line a t 7 10,443' 102.81' 3.958" 5.125" 40' of4 -1/2" Wire Wrap Screen. (two 20' jts) 60' of 4 -1/2" Blank Pipe w/ bull plug D ■ ROD DETAIL NO. Depth Length ID OD Item A 0' 34' 1.500" Polish Rod B 34' 3,281' 1.000" 1" EL Sucker Rod, w/ Slimhole Class T coupling w,(3) 2.25" R &M Stealth XL AF Rod Guides per rod (131 rods) & 1" x 2' & 1' 4' EL Pony Rod Spacer Pup © C 3,315' 3,650' 0.875" 7/8" EL Sucker Rod, w/ Class T coupling -136 w /(3) & 10 w/ (12) 2.25 "2.25" R &M Stealth XL AF Rod Guides per rod (146 rods) D 6,965' 3,425' 0.750" 3/4" EL Sucker Rod, w/ Class T coupling -130 w /(3) & 7 w/ (12) ►5 2.25" R &M Stealth XL AF Rod Guides per roc( (137 rods) 0 � g E 10,393' 43.35 1.75" 2.250" , 1 -3/4" RHBC Pump w/ Stabilizer Bar F 10,437' 61.87' 1.26" 1.660" Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8" holes every 2" (90deg phased) CI © AI f PERFORATION HISTORY 6 Interval E Date Zone Top (MD) Btm(MD) Amt Comments Top(1'VD) Btm(rVD) © 1/3/2001 G -a ne 10,478' 10,510' 32 Re-peif 8/6/01 10,476' 10,508' I G Zone 1/32001 G -a ne 10,510 10,512' 2' Re-ped 8/6/01, 8/31 /09 10,508' 10,510' 10,545'--- """'"" 8/312009 G -ane 10,512' 10,544' 32' 10,510' 10,542' 1/29/1977 Hl 10,562' 10,588' 26' Re.peif2/20 /86 10,560' 10,586' i yng Fil l @ 1 Hl 8/312009 H2 10,588' 10,602' 14' 10,586' 10,600' (0,613' SLM • 112 1/31/1977 H2 10,610' 10,628 18' Raped 2/20/86 10,608' 10,626' 8/29/09 • H2 1/31/1977 H3 10,640' 10,645' 5' Re-pelf 2/20/86 10,638' 10,643' 1/31/1977 H4 10,651' 10,658' 7 Reped220 /86 10,649' 10,656 • 113 220/1986 H4 10,658' 10,665' 7' 10,656' 10,663' • 114 220/1986 H5 10,670' 10,680' 10' 10,668' 10,678' ' HS 1/26/1977 H5 10,680' 10,702' 22 Re.perf220 /86 10,678' 10,700' 1/17/1977 H5 10,702 10,710' 8' Raped 126/77; 2/20/86 10,700' 10,70F 1/17/1977 H5 10,710' 10,712 2 Re-pelf 2/20/86 10,708' 10,710' TD = 17,689' PBTD = 11,138' MAX HOLE ANGLE =2 deg. @ 6100' SCU 33 -33 Actual Well Schematic Updated 8- 10- 11.doc Updated by TDF 8/10/2011 IM • • RKB 153' / GL 125' AMSL New KB-THF: 18.44' Swanson River Field Chevron Soldotna Creek Unit 4 1 ?; Well Name: SCU 33 -33 I Original Completion 1977 Last Work -over 10 -16 -09 API 50- 133 - 20293 -00 / PTD 176 -056 'WI Proposed Completion I Casing Size Wt Grade Conn ID Top Btm } 22" Weld Surface 90' 3 13 -3/8" 68# K -55 BTC 12.415" Surface 3,380' 3,380' • ■ 9 - 5/8 " 47# 5 -95 BTS 8.681" Surface 6295' C 53.5# S-95 BTS 8.535" 6,295' 11,350' Tubing 2 -7/8" 1 6.4# 1 L -80 1 8rd EUE I 2.441" I Surface I 10,546' Jewelry Detail # Top / ft Btm / ft Length / ft ID/ in OD/ in Description 1 18.44 19.00 0.56 2.441 11 Seaboard Tension hanger 2 3,000.00 3,004.00 4.00 2.441 5 Depth indicator sub i 1 3 10,322.00 10,323.88 1.88 2.441 7 Type 'S' anchor latch 190 - 60 9 4 10,323.00 10,325.00 2.00 6 8.218 Baker 'F production packer III) 5 10,436.34 10,437.39 1.05 2.313 3.063 Cup Type seating nipple 6 10,437.39 10,441.49 4.10 2.441 4.335 Cherrical injection sub 7 10,441.49 10,481.49 40.00 3.958 4.9 0.080 Dura Grip Screens 8 10,481.49 10,541.49 60.00 3.958 4.5 4 -1/2" blank pipe jiisk. 9 10,541.49 10,542.49 1.00 0.000 5.5 Bull plug Rod Detail =_- # Depth Length ID OD Item Bake] - : packer 4 A 43.76 40.35' - 1.5" Polish Rod IiiM• Et 1.00" I B 3318.76 3275 - 2 025" 131 - 1" EL rods w/ 3 XL guide s per rod I C 6818.76 3500 0 875" 140 -7/8" EL rods w/ 3 XL guides per rod 1.812" i If S D 10043.76 3225 _ 0.750" 129 -3/4" EL Rods w/ 3 XL guides per rod 1.625" 6 E 10393.76 350 1-1/2" sinker bars 2.150„ 25 -175 RHBC 36'x36 -1 /2'x37'rod pump F 10436.26 42.5 - w/ CPID Bbl., 80 Ring P.A. Plgr, Dbl Valves, 2.340' BDV, 1 "x 30 "stabilizerbarw /coupleing 1 -1/4" (1.660" OD 1/1/4" NPT X 1.66 BTS -8 G 10499 Perforations 62.74 1.28" 1.660" boxcross over to bull nose tubing w/ _ bottom6' perforated (72 [3/8 "] holes) G 10, 478' G 8 Interval H1 Date Zone Top Btm Amt Comments H2 1/3/2001 G -zone 10,478' 10,510' 32' Re -perf 09 -201 l 9 1/3/2001 G -zone 10,510' 10,512' 2' Re -perf 09-2011 H3 8/31/2009 G -zone 10,512' 10,544' 32' Re- perf09 -2011 H4 1/29/1977 H1 10,562' 10,588' 26' Re- perf09 -2011 H4 8/31/2009 H2 10,588' 10,602' 14' Re -perf 09-2011 H5 = 1/31/1977 H2 10,610' 10,628' 18' Re -perf 09-2011 1/31/1977 H3 10,640' 10,645' 5' Re -perf 09-2011 H5 1/31/1977 H4 10,651' 10,658' 7' Re- perf09 -2011 H5 2/20/1986 114 10,658' 10,665' 7' Re -perf 09-2011 10,712' 2/20/1986 H5 10,670' 10,680' 10' Re -perf 09-2011 9 ;' ,. ., 1/26/1977 H5 10,680' 10,702' 22' Re -perf 09-2011 ''''''',..17.177t; '; r , 1/17/1977 H5 10,702' 10,710' 8' Re -perf 09-2011 xx,}.: 1/17/1977 H5 10,710' 10,712' 2' Re -perf 09 -2011 TD= 17,689' PBTD= 11,138' Max hole angle = 2° @ 6,100' • • Chevron Swanson River IWO SCU /2011 08/23/2011 1 Key Stripper head assy 1.77'_ i 1 IM 1 o P C _ _ 111 111411 111 111 111 111 111 1 1 3.45' ■ Shaffer 1 " 5000 111111 1i1 IM1 t 1 1 _ - -_� Shaffer LWS 11" 5000 Blind rams _ _ 2.75' _ ® = 13.49' 2 7/8 X 5 Variable rams - !� ' 1, — y��rTS�i _ -- 111 111 trivrlil 2.00' 1 lel 1" 5000 ' /o iw: I : � . I I b I ., : . I " I 111 111 111 111 111 t Choke and Kill lines 2 1/16 5M I ilWill w/ unbolt connections 111 1!1'1!1 111 111 0 • i' 1.95' Top of Rotaflex skid beam lil = iii l 0il III 1 Mil al 1 1111111 Ili 111 3.95' WFT owned A Ground level 2.38' 11 111 111 111 111 I H — 111 il o W III MI' 0 IN IlifAill • -i. 1 11 I 1 11 1111 0 ii 1 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS WG~ r~ ( q~zoag 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ Rod pump Recomplete Performed: Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^~ Re- ter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: . Permit to Drill Number: Name: Development ~^ Exploratory 176-056 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ . API Number: 50-133-20293-00' ,Property Designation (Lease Number): . Well Name and Number: FEDA028990 [Swanson River Facility] Soldotna CK Unit (SCU) 3333 Field/Pool(s): Swanson River Field/ Hemlock Oil Pool & G-Zone Pool ~la ~Ca ~il & Gas L'ons. ~i 17. Present Well Condition Summary: iAfIGh0~8Q@ Total Depth measure'~ 17,689 feet Plugs (measured) N/A feet , true vertic~,17,659 feet Junk (measured) 10,613 (fill) feet Effective Depth measured 10,602 feet Packer (measured) 10,323 feet true vertical 10,600 feet (true vertical) 10.321 feet Casing Length Size MD j ND Burst Collapse Structural Conductor 90' 20" 90' 89' Surface 3,880' 13-3/8" 3,880' 3,879' 3,450 psi 1,950 psi Intermediate Production 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Liner PerForation depth: Measured depth: 10,478'-10,544', 10,562'-10,602', 10,610'-10,628', 10,640'-10,649', 10,651'-10,658', 10,670'-10,712' True Vertical depth: 10,476'-10,542', 10,560'-10,600', 10,608'-10,626', 10,638'-10,647', 10,649'-10,656', 10,668'-10,710' Tubing (size, grade, measured and true vertical depth): 2-7/8" 6.4# L-80 10,545' MD 10,543' ND / N/A 10,323'MD (10,321'ND) N/A Packers and SSSV (type, measured and true vertical depth): Baker F-1 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,„, ~t~~ , , , ~; ~ ~ ~ ~~~~ a~i~~:~~"+~~~ ~~~ ` d N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 12 psi 50 psi Subsequent to operation: 82 0 157 150 psi 145 psi 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ~^ Service ^ Daily Report of Well Operations X . Well Status after work: Oil ~ Gas WDSPL G OR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 77. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numt~er or N/A if C.O. Exempt: 309-285 l Contact Mike Quick 263-7900 Printed Name Timothy C. Brandenburg Title Drilling Manager f'-~ Signature '°~~ Phone 276-7600 Date 11/5/09 ~'" '---- ~ 1~~ ~t t b~~ ~ 0~ Form 10-404 Revised 7/2009 Submit Original Only ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name , Lease SuRace UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 33-33 SOLDOTNA CK UNIT 33-33 FEDA028990 5013320293 QB0763 153.00 x * °~;t ~ ~ ~ ~ ~ ``~% ~ ~~ ~• ~' ~~. ~`. w.;. ~^ ~ r.~~. > ~ ,~,_~ , . n ~ ~, » ~~ Primary Job Type Job Category Objective AMual Start Date Actual End Date Pump Repair Major Rig 8/27/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 33-33 501332029300 1760560 Dai O ratiorrs ; `~~.; , ~; ~ ~, ~ 8/27/2008 00:00 - 8/28/2009 00:00 Operations Summary MIRU Key Energy Rig # 3/ fill production tubing w/ 3% KCI and pressure test rod BOPE 250 low 1200 high / POOH with rod string. 8/28l200~ 00:00 - 8/29/2p08 OQ:00 ` , £y Operations Summary Continued to POOH with rods, recover 401 rods. MIRU APRS wireline, RIH and tubing punch 10,059' - 10065'. POOH & RDMOL APRS wireline. Mix and pump 25 Bbls Xylene cocktail, 20 Bbls Jet A& 3 Bbls KCL. Set BPV, ND tree and NU 11" BOPE stack, test same 250psi low/3,OOOpsi high. Witness waived by BLM & AOGCC Lou Grimaldi. ,,: . , . ~.~ r o ~ ~~. $I29/2009 0~,00 ~-~8f30/2009~ 00:00 ~ ~ ~ ~ ~ ~``'~~ ~~~` ~ ~ ` ~ Operations Summary Complete BOPE test, pull hanger to the floor & POOH with production tubing, racking back. MIRU Pollard slickline, RIH and tag bottom w/ 2.5" sample bailer @ 10,613', POOH, RIH with pressure, temperature, gamma ray, CCL & log from 10,605' to 8,000', POOH and down load data. RD slickline. ~S~`Otl~`,af~.00 - 81~'If~9~ 00.00 ~;, ; Operations Summary Continued downloading data from memory log, stand by on analysis and TCP guns, PUMU TCP perForation assembiy and RIH with same. ~ . r. ~, ~ . . . ~, ~ , $/31/~009 OO:t~= 9Mi2008 00:~ ~ ~ ~ ~ ~~ ' ~ ~ ~ - ~, ~~ . ~ ~ _ ~ 'ti `~ ~ Operations Summary Continue RIH w/ TCP guns, latch into packer at 10,323'. Pertorated 10,510'-10,544' & 10,588'-10,602' w/ 4-5/8" Millennium guns 60deg phased, 5spf. Unlatched from packer & POOH. Begin RIH w/ 2-7/8" completion, banding 3/8" SS chemical injection line. 9/?/2009 OQ:00 =.~12f~ ~~tlf1:00:;`: ". Operations Summary Continue RIH w/ 2-7/8" 6.4# L-80 completion to 10,544', banding 3/8" SS chemical injection line, latch into packer at 10,323', put tubing in tension, landed tubing hanger. ND BOP, NU tree w/ rod BOP. Tested to tree to 250psi low/5,OOOpsi high. Began RIH w/ 3/4" rods. 912T2609 UO:dO~~ 9/S/70b8 OO:E10 ~~~ ~ ~~ ~ ' ~ ~; _~, <, , .y '- .° ,~ ~. . ~ ~ Operetions Summary Finish R!H w/ RHBC rod pump on 137-3/4" rods, 146-7/8" rods, 131-1" rods, Space out, seat pump. Test pump and tubing to 1000 psi for 30 minutes - good. Rig down, move off location. tQt41~ t~~l:00 _ t0/bl~ , ~ OOs00 Operations Summary MIRU Key Energy Rig #3 10l5l2009 00:00 -10/612009 00:~~ ~ ~ . ~ ~ - `~ ~ ~ ~ „~' y' ~ Operations Summary Prep to pull rods, pressure test rod BOP to 500 psi - good. POOH with rods and pump assembly, lay out pump for inspection, lay out circulating valve. RIH with rods and pump assembly, space out, stroke pump to 1000 psi to pressure test, pressure bleeding off slowly - no test. Secure well for night. 10/6/2009 OOs00 -10t71~ $ OOiQO Operations Summary Stroke pump to build pressure, bleeding off trapped air. Would not hold pressure to test, POOH with rods and pump assembly. Drop standing valve to seating nipple, pressure test tubing to 1000 psi, pressure bleeding off. Secure well for night. Notified BLM & AOGCC at 12:30 pm of possilbe upcoming BOP test. ,.~ . ~. ~ 10/7/2009 00:00 -1 b/8/2009 OE~:00 ~ ~ Operetions Summary ~ Rig up slickline, run W-Circ plug, set at 10372'. Fill tubing with water, pressure test tubing to 1000 psi - failed p-test. Pull W-Circ plug, pull standing valve, N/D rod BOPE, start to N/U 11" BOPE. Secure well for night. Note: BLM & AOGCC Jeff Jones notified of BOP test at 0900 - test witness waived. 'lt~/8~24~4~~ ~t1;~0~ -10/912009 OOt00 ~ ~ ~ , . ~ '~ . ~ ~ ~ ~€°~~ Operations Summary Continue to N/U BOP's. Test BOPE to 250 psi low / 3000 psi high charting all tests - BLM & AOGCC Jeff Jones waived witness10/7/09. Release hanger and POOH laying down 2-7/8" tubing. Secure well for night. ,~ ,,x 10/9/2009 OO:~t1-10/10d20Q9 00;00 ~~~ _ _ ~~_ ~ , ~ ~~ Operations Summary Continue POOH laying down 2-7/8" tubing. Inspect tubing anchor and seating nipple, prep to run completion. Secure well for night. 10/10/2009 OO:OQ ~ 101'~'~~qQ9.bQ,~Q Operations Summary Make up completion string and RIH with new 2-7/8" 6.5# L-80 EUE tubing and 1/4" SS chemical injection line. Ran 214 jts, secure well for night with DSM monitoring welL 10M 1/2009 OQt00 -10/12I2009 00:00 y Operations Summary Continue to RIH with 2-7/8" completion. At 280 jts, chemical injection line would not hold pressure test. POOH with completion, spooling chemical injection line. Found chemical injection line rupture disk ruptured at injection mandrel. Secure well for night. ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 33-33 SOLDOTNA CK UNIT 33-33 FEDA028990 5013320293 QB0763 153.00 ~~II ~ Q .~ u. ~' G~~. ,-:~ , fii,r,u,~~„ ~k "'~u, ,~ b''fi ` ~:"°~*`~~ %'fr yP' _, ~:,,.. ,.,. ~. .r .~ ~.:;~~r, , . . .,~~zn.. 10112I2009 00:00 -1 ON 3/2009 A0:00 Operations Summary Prep and RIH with 338 jts. of 2-7/8" 6.5# L-80 EUE tubing completion with 1/4" SS chemical injection line banded to tubing. Pressure test chemical 'rnjection line, burst rupture disk - good. Space out to land hanger. Tubing tail at 10,546'. Secure well for night. 10/13/20b9 00:00 -10/14/2009 00:00 ` ~ ' Operations Summary Space out hanger, set down and latch anchor, pull tubing in 35k tension (stretch tubing 4.7') and land hanger. N/D BOP, N/U tree and test hanger void to 250 low / 5000 psi high for 30 min - good test. Test tree to 250 low / 5000 psi high for 30 min - good test. Test Rod BOP (ratigan) to 500 psi. P/U & RIH with rod pump assembly and run 367 rods (tapered string). Secure well for night. ~ ~~.,•~., ~ ~ ~~~ 70/14l20Q9 00:00 -10h'5f20 SO4:QQ :: , Operations Summary RIH with remaining rod string (Rod totals = 137 total 3/4", 146 total 7/8", 131 total 1" rods plus two 1" pony rods). Pump 10 bbls KCI to flush seating nipple. P/U polish rod, Space out pump, strip on stuffing box, seat pump. Stroke pump until good returns at surface, pressure test tubing/pump assembly to 1000 psi for 30 minutes - good test. Rig Down, move off location. 10M 5/2009 00:00 -10/16/2009 A0:00 Operations Summary Rig Down, Demobe. 10t1'612005 00:00 -10/17/2009 00:00 Operations Summary Rig Down, Demobe. Rig released at 1000 hours. , F , ... . 1t~t'F~`t~;00~ bt~:~G;~ 1Qt4#tt1~09 00:00 f ..~,. . ~~ ~ <, _ Operations Summary Demobe. , ~.t ~lQ/'[812009 d0;~t6 -'~W19/2009~ 00:00 ~ ~ ~ ~ ~ ~ ~ *~ ~ ~ ~ ~ ~ ~ Operations Summary Demobe. 10119/2009 00:00 -10/20120Q9 U0:00 Opera' nsSummary D o e. 1 J2 2Q08 00:00 -10/21/2009 00:00 ~~°'s" r.. 0 tions Summary emobe. i ~ ~ ~ ~ Swanson River Field Soldotna Creek Unit U N O CAL ~6 Well No. 33-33 API# 50-133-20293-00 Actual Com letion Orig. RKB = 17' WO RKB = I2.25' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.415 Surface 3880' " 47 S-95 8.681 Surface 6295' 9-5/8 53.5 S-95 8.535 6295' 11,350' Tubin 2-7/8" 6.4 L-80 EUE 2.441 15' 10,546' 1/4" CIL SS Surf 10,437' JEWELRY DETAIL NO. De th Len th ID OD [tem 17.00' 1' 2.441" 11.00" Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-'/a" 8rd Lift x Butt down. 40' 1.5" Polish Rod A 3,250' - 1" 1" EL Sucker Rod, w/ Slimhole Class T coupling w,~3) 2.25" R&M Stealth XL AF Rod Guides per rod(131 rods) & 1" x 2' & 1' 4' EL Pon Rod S acer Pu 3,650' - '/e" 7/8" EL Sucker Rod, w/Class T coupling-136 w/(3) & 10 w/ (12) 2.25"2.25" R&M Stealth XL AF Rod Guides er rod l46 rods 3,425' '/<" 3/4" EL Sucker Rod, w/Class T coupling-130 w/(3) & 7 w/ (12) 2.25" R&M Stealth XL AF Rod Guides er rod 137 rods 1. 3,049' 1' 2.441" 5" De th [ndicator Sub 2. 10,322' 66' 2.375" Model "A"-Anchor Pazallel Tb Seal Ass w/ 3 s in b- ass area. 3. 1Q323' 1' 2.441" 4.25" Baker"F-I" 190-60 Retainer Production Packer. B 1Q393' 4335 1.75" 2.25" 1-3/4" RHBC Pum w/ Stabilizer Bar 4. 10,43T 4.10' 2.441" 4335" Chemical In ection Sub 5. 1Q436' Cu T e Seatin Ni le, 2-7/8" 6. 10,442' 60' 3.958" 40' of4-V2° Wire Wrap Screea (two 20' jts) 60' of4-I/2" Blank Pi e w/ bull lu C 61.87' 1.260" 1.66° Dip Tube 3.02# BTS Box x Pin, Bottom 6' perforated w 3/8°holes eve 2" 90de hased PERFORATION HISTORY i o, I merva~ Zone To Btrn AM CommeiRs G zone 1 Q478' 1 Q512' 34' G zone 10,510' 10,544' 34' 4-5/8" Millau»umgims 6(kleg Sspf HI 10,562' 10,588' 26' H2 10,588' 10,602' 14' 4-5/8"IVSlleutiumgims60deg5spf [ i~ 10,610' 10,628' 18' Hi 10 640' 10 649' 9' I-~1 1 Q651' 1 Q658' T I15 10,67d 10,712' 42' WBD SCU 33-33 Actual 11-3-09.doc DRAWN BY: slt: 11/30/2005 Revised cvk 9/15/2008 PBTD=11,138' TD=17,689' M A X HO LE AN G L E= 2 deg. @ 6100' • • f ~;.~ ~, ~: '~ E .~ , ~ ~~: ~ ~p' ~ ~,r_ ~ r ~ ~, a "'~ ` ~ f ~ ~'' ` ,~~ ~~;, ~ ~~, ` ~ ~ € _ E ~~ & ~ i b"~~ ~ ~ n~G ~ "~"t ~ 40 ~$",~ ~ vF C~ t~ ~~L ~ r a ~ ~~a ~~ ~ r y ~- e ~, ~ ~ ~ ~-~ ~f~ ~ ~ u ~~ ~ `~~`~ ~ p ~ ~ ~ { SEAN PARNELL, GOVERNOR ~=~'~ 4 ~ ` ~ ~~ ~~~ ~_~. ~ ~ ~ ~~ ~~ ~,~ ~ ~.s': a ~ ~,~ ~ ~:% ~~~ ~,~ ~,~ ,~~ tust~-7~ OIL t~lsi~ Vrv~,7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T CO1~II~II551O1~T fi~ ANCHORAGE, ALASKA 99501-3539 q PHONE (907) 279-1433 s~ FAX (907) 276-7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 ~ `~ V~ a ~~ Re: Swanson River Field, Hemlock Oil Poo18s G-Zone Pool, Soldotna CK (SCU) 33-33 Sundry Number: 309-285 F ~ ~~~,~ ~.~~ ~t~~a ~~ ~ t.~ w Dear Mr. Brandenberg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days aiter written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Se~mount, Jr. % /A Chair ~/~~ DATED this~ day of August, 2009 Encl. , ~ 0~ ,v`~ ~ ~, ~. ~ ~ # Y IL..~ v~~~~ ~ STATE OF ALASKA ~ '~ ~~ C ~. ~ 2~09 ~ ~ ~9 $~ ALAS~IL AND GAS CONSERVATION COMMI~N ~~y~Zppg APPLICATION FOR SUNDRY APPROVALS ~~~~~~ ~?~° ~~ ~~~ ~" ~~ ~~~"!~'~~'~~ 20 AAC 25.280 ~,~ ~.~-~.s t..::, 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ Waiver ^ Other ^~ Aiter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ - Rod pump Change approved program^ Pull Tubing^Q - Perforate New Pool ^ Re-enter Suspended Well [] recomplete 2. Operator Name: 4. Current Well Class: 5. Permit to Drili Number: Union Oil Company of California Development ~, Exploratory ~ 176-056 - 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20293-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^' Soldotna CK Unit (SCU) 33-33 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028990 [Swanson River Facility] 17' Swanson River Field/Hemlock Oii Pool & G-Zone Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689 17,659 10,602 10,600 N/A 10,602' (fill) Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 89' Conductor 3,880' 13-3/8" 3,880' 3,879' 3,450 psi 1,950 psi Surface 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# L-80 10,323' Packers and SSSV Type: Packers and SSSV MD (ft): Baker F-1 190-60 Retainer Production Packer / N/A 10,323' / N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP et h^~ Exploratory ^ Development Q- Service ^ 15. Estimated Date for 2 009 16. Well Status after proposed work: Commencing Operations: Oil ^~ _ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name tD Timothy C. Brandenburg Title Drilling Manager ID Signature Phone 276-7600 Date 8/14/2009 COMMISSION USE ONLY diti n f r l C N tif i th N b ~(J !'-~(~5 C i t ti it S d t on ova : o s o app y omm on so a represen um er: o ss a ve may w ness un ry a Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ e S-C ~~ Q c ~O 3 0D 0 ~ L(,~ , ~p r Zo ~4/~ ~ 25• 2~ 5 C G~.~ , a.~~'ev K,~'e /3D ~~ iS a~'~oW i1e d, Subsequent Form Required: ~ 0 - L~.Q 4. , APPROVED BY ~ ~ ~ A roved b : COMMISSIONER THE COMMISSION Date: pp y ~.- , Form 10-403 Revised 06/2005 ~._._- .. ~~~~- +", s; ~ 6(~~1~ I l Submit in Duplicate ~ • Chevron Timothy C Brandenburg Union Oil Company of California ~ Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 ~ Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com August 14, 2009 ~`~~~~~~~ f~~)~ ~ 4 ~[1~19 Commissioner at~s~~ ~~~~ ~ ~~~ ~ ,rt~ ,. y ~ ~,P,~,~.r~xs~,, Alaska Oil & Gas Conservation Commission ~ ~ ~ ~~~~,~; ,,~~ 333 W. 7'h Avenue Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request for SCU 33-33 Dear Commissioner, UOCC is requesting a variance of 20 AAC 25.285 (c) (9) and (10) for well service work in ; the Swanson River Field, for SCU 33-33. UOCC is currently performing well intervention work with a"well servicing unit" provided by Key Energy. Key Energy mobilized the workover unit here from the Rocky Mountain area. After reviewing the BOPE rig up and equipment as used in UOCC's last Swanson River workover campaign in 2004, we feel that the proposed system is fit for purpose in well control capabilities and mobility to other BOPE configurations for this well service work. This variance request was granted for the KGSF #1 workover on Sundry Number r 309-221, and was successfully utilized on this well intervention. As in this same configuration successfully used in 2004, UOCC is asking for a variance of the kill line and choke line configuration and the choke manifold equipment requirements. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. / UOCC appreciates your consideration of this proposal and looks forward to discussing any questions with the proposed configuration as needed. Attached is a brief description of the well to be worked on, and the proposed BOP configuration and s~hematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, ~• Timothy C. Brandenbu g ~~D Drilling Manager Attachments: Summary of Swanson River Workover Program, BOP diagram, Choke diagram Union Oil Company of California / A Chevron Company Chevron ~ • ~ ~ Summarv of Kev Enerqv Riq #3 Specifics SCU 33-33 Workover The SCU 33-33 workover is to pull the existing completion, fish and cleanout to the base of the Hemlock (or as deep as possible) and run a new completion. The rig specifics are for the planned rig up on this l well and are likely to change from well to welL Proaosed Confiquration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft- 9/16" sand line. Derrick ,-- The derrick is a telescoping double, with~0,00A'Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. ,./ %`~ Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Shaffer ~~~.....- , , ~ ~ ~ c~~~~~ ~ Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram and blind ram ~~~~ ""~ ---- Mud Cross, 5M, 7-1/16" ~ „~'~ BOP Diagram See attached. Accumulator 140 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SCU 33-33).doc 7/27/09 Chevron + • ~ ~ Kill Line Valves ~---- ~ The ki~~-iir~e,valves consist of 2 ea. ~nual operated, 2-1/16", 5M valves attached to the mud cross witk~ co-~ ~hose with a Unibolt/Hub= ged connectors. Choke Line / The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke '- )valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated CFZ~valve that is attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged ~ connecto : Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a~ single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SCU 33-33).doc 7/27/09 Chevron ~ ~ Soldotna Creek Unit ~ Well # SCU 33-33 ~ 8/10/09 OBJECTIVE: • Pull rod pump completion & tubing, reperforate G Zone & Hemlock, recomplete rod pump well. PROCEDURE SUMMARY: 1. De-couple and roll back Rotaflex pumping unit, MIRU Key Energy Rig #3. 2. Strip rod surface equipment off well, NU rod BOPE, test same to 1,500 psi & lay down polish rod ~ 3. Unseat rod pump, pump chemical treatment to clean rods, Pull EL rods and pump Assembly / lay down same 4. Install BPV, ND tree, NU BOPE & test same 250 low 3,000 psi high ~ 5. PUMU landing joint, unseat mandrel from tension hanger, lower string to neutral & release anchor by working right hand torque to anchor 6. Pull 2-7/8" production tubing and lay down same 7. MIRU Slick line, RIH w/gauge ring and tag packer, RIH w/ dummy gun to tag fill. RIH w/pressure temperature survey. RDMOL 8. PU TCP guns and latch sub, RIH, latch into packer, pump chemical treatment and allow to soak. Drop bar and re- perforate "G" Zone and Hemlock from 10,478'(+/-) -10,512'(+/-) & 10,562'(+/-) - 10,588'(+/-). POOH ~ 9. PUMU screen, chemical injection sub, rod seat, lower production tubing & parallel anchor 10. RIH on 2-7/8" production tubing banding chemical injection line to each joint, latch into packer @ 10,323', space out and land tubing in tension 11. Install BPV, ND BOPE, NU tree, test same, NU rod BOPE & test same / 12. PU rod pump, RIH on tapered rod string, land the pump, space out the rods, install the polish rod 13. ND rod BOPE and strip surface equipment onto well 14. RDMOL, roll up Rotaflex pumping unit and Re-couple 15. Return the well to production / SCU 33-33 AOGCC-Operation Summary.doc REVISED BY: CVK 8/10/09 '"~' • • Swanson River Field Soldotna Creek Unit U N O CAL 76 Well No. 33-33 API# 50-133-20293-00 Actual Com letion SIZE WT CASING AND TUBING DETAIL GEtADE CONN ID TOP BTM. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.415 Surface 3880' 9-5/8" 47 S-95 8.681 Surface 6295' 53.5 5-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323' .iFWF.I.RV i1RTAIi. NO. De th Len th ID OD Item 17.00' 1' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, I 1" DCB x 2-'/e" 8rd Lift x Butt down. 36' 1.5 Polish Rod (spaced out 6' above stuffing box w/ pump 1.5' off btm). A 2' ------ 1" 1" x 2' EL Pony Rod Spacer Pup 3,300' 1" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 132 rods 3,650' - '/8" 7/8" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 146 rods 3075' '/4" 3/4" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 123 rods B 10,103' 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump w/ Dual Seating Cups w/ Stabilizer Bar w/ collar. C 10,104' 115' 1.28 1.66 1-1/4" Di Tube 1. 10,103' .66' 2.280 3.125 Cu T e Seatin Ni le, 2-7/8" 10,104' 6' 2.441 3.5 2-7/8" 6.4 lb/ft, L80 Buttress Pu Joint w/collar ]0,110' 1' 2.441 3.5 XO 3`h" IBT Pin Ported sub x 2-7/8 IBT Box 10,115' S' 2.992 3.5 3'/z" IBT Pu Jt. & orted sub BXP 10,116' 192' 2.992 3.5 3- U2" 9.2 Ib/ft, L80 Buttress 2. 10,307' 1' 2.441 4.25 XO 2 7/8" IBT Pin X 3-1/2" IBT box. 3. 10,308' 8' 2.441 3.2 2 7/8" IBT Pu Joint, 6.4 #, L-80 w/ collar d. 10,316' 2' 2.188 3.500 Otis "R" Profilc ni le, 2.180" w/ lu in lace 5. 10,319' 2' 2.312 7.437 Baker L-10 on/off tool w/ box 6. 10,320' 2' 2.441 3.688 X-over, and Mod orted collar. 7. 10,322' 3' 4.875 7.000 "E"-22 Anchor Tb . Seal ass. w/out seals 5.5 LTC box 8. 10,323' 6.000 8.438 Baker"F-1" 190-60 Retainer Production Packer. ~ T~ge on PBTD= 11,138' TD=17,689' MA~HOLE ANGLE=2 deg. (a~ 6100' WBD SCU 33-33 R1 2008.doc PERFORAT ION HISTORY Interval Zonc Top Bhn Ar-rt Corm~ents Gaorie 10,478' 1Q512' 34' Hl 10,562' 1Q588' 26' I-~2 10,610' 10,628' 18' H3 10,640' 10,649' 9' H4 10,651' 10,658' T HS 10,670' 10,712' 42' DRAWN BY: slt REVISED: 3/16/O1 REVISED BY:jrn REVISED: 10/21/04 Orig. RKB= 17' • • Swanson River Field Soldotna Creek Unit VNOCA~ 76 Well No. 33-33 API# 50-133-20293-00 Pro osed Com letion Orig.RKB=17' WORKB=1215' CASING AND TUBING DETAIL SI'LE WT GRADF, CONN ID "COP BTbi. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.4I5 Surface 3880' " 47 5-95 8.681 Surface 6295' 9-5/8 53.5 5-95 8.535 6295' 11,350' Tubin 2-7/8" 6.4 L-80 BTC SC 2.441 IS' 10,575' 3/8" CIL 316 SS Surf 10,590' JEWELRY DETAIL NO. De th l,en th ID OD Item 17.00' 1' 2.441 1 I.00 Seaboazd Intemational Tension Hanger installed CIW Bowl, I I" DCB x 2-'/s" 8rd Lift x Butt down. 36' - 1.5 Polish Rod (spaced out 6' above stuffing box w/ pump 1.5' off btm). A 2' ------ l" 1" x 2' EL Pony Rod Spacer Pup 3,50 0' 1" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 132 rods 3,90 0' - '/e" 7/8" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 146 rods 3300 ' '/<" 3/4" EL Sucker Rod, w/Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 123 rods 1. 3000' 1' 2.441 S' De th [ndicator Sub 2. 10,322 .66' 2375 Model "A"-Anchor Pazallel Tb Seal Ass w/ 3 s in b- ass area. 3. 10,323' 1' 2.441 4.25 Baker"F-l° 190-60 Retainer Production Packer. B 10,524'(+/-) 41.4 5' 1.75 2.25 l-3/4" RXBC Dbl valve Pump w/ Stabilizer Baz& collaz Petro-Tech circulatin Valve between um & Dual Seatin Cu s 4. 10,566' +/-) Cu T e Seatin Ni le, 2-7/8" 5. 10,575'(+/-) 60' 3.958 40' of4-U2" Wire Wrap Screen. (two 20' jts) 20' of4-U2" Blank Pi e w/ bull lu C 60' Di Tube PERFORATION HISTORY [ rrerval 7vne To Btrn Artt Comrrents Gzone 10,478' 10,512' 34' Proposallaeperf HI 1 Q562' i Q588' 26' Proposed I~~ rf H1 10,610' 1 Q628' 18' Hi 10,640' 10,649' 9' I# 1 Q651' 1 Q658' T I~ 10,670' 10712' 42' WBD_SCU_33-33_Proposed_8-5-09.doc DRAWN BY: slt: 11/30/2005 Revised cvk 8/5/2008 PBTD=11,138' TD=17,689' MAXHOLE ANGLE=2 deg. ~ 6100' Chevron ~ Swanson River ~ SCU 33-33 ~ 08/14/2009 Annular preventer, Shaffer, 11 5M Flanged Double gate, Shaffer 11 5M stdd X 11 5M stdd ~ Kill line 2 1/16 Unibolt connection ~ Mud Cross, 11 5M FE X 11 5M FE w/ 2 1/16 5M X 3 1/8 5M EFO Choke line 2 1/16 5M ~- ~~ Unibolt connection ~ ~ DSA 31/85MX21/165M S ~~-~~~ ~ s O K Che1-ron ~ Swanson River ~ 2009 Workover Program ~ Rod BOPE 8/11 /2009 Rod Plate for Landing Elevators Rod BOP, VBR 0"to 1" Rattigan From Pump S ~ ~ ~ 0 ~ ~ ~ ~ ~ ~ 0 ~ ~ ~ ~ To Choke x ~ ~/~ ~ STATE OF ALASKA ~~~~~~ ~~ X09 ~, ~ rte ~ G ALA OIL AND GAS CONSERVATION COMMI~N ` ~ ~; ~` REPORT OF SUNDRY WELL OPERATIONS,~AN 2 ~ ~~09 :~ 1. Operations Abandon Repair Well Plug Perforations Stimulat ~~ ~~~ ~ ~~ ~~ of rod ~ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver Time tension pump reconfig Change Approved Program^ Operat. Shutdown^ Perforate ^ Re-enter Suspen e e I 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ Exploratory^ 176-056 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-133-20293-00 7. KB Elevation (ft): 9. Well Name and Number: 17' Soldotna CK Unit (SCU) 33-33 - 8. Property Designation: 10. Field/Pool(s): FEDA028990 [Soldotna Creek Unit] - Swanson River Field /Hemlock Oli Pool & G-Zone Pool 11. Present Well Condition Summary: Total Depth measured 17,689. feet Plugs (measured) N/A true vertical 17,659 feet Junk (measured) N/A Effective Depth measured 10,693 feet true vertical 10,691 feet Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 89' Conductor 3,880' 13-3/8" 3,880' 3,879' 3,450 psi 1,950 psi Surface 11,350' 9-5/8" 11,350' 11,348' 8,150 psi 7,100 psi Intermediate Production Liner Perforation depth: Measured depth: See Attached Schematic ~~ L.~ True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 2-7/8" 6.4# L-80 10,323' Packers and SSSV (type and measured depth) Baker F-1 190-60 Retainer 10.,323' / N/A Production Packer / N/A 12. Stimulation or cement squeeze summary: N/A Intervals 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil Q Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-372 Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager ~ Signature Phone 276-7600 Date 1/27/2009 ~.~ C./ Form 10-404 Revised 04/2006 ~ I ~~ Submit Original Only UNOCAL Swanson River Field Soldotna Creek Unit Well No. 33-33 API# 50-133-20293-00 ctual Com letion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.415 Surface 3880' 9-5/8" 47 5-95 8.681 Surface 6295' 53.5 5-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323' IF WFI.RV IIRTAII. NO. De th Len th ID OD Item 17.00' 1' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-'/8" 8rd Lift x Butt down. 36' 1.5 Polish Rod (spaced out 6' above stuffing box w/ pump 1.5' off btm). A 2' ------ 1" 1" x 2' EL Pony Rod Spacer Pup 3,300' 1" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides er rod 132 rods 3,650' '/8" 7/8" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 146 rods 3075' '/4" 3/4" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 123 rods B 10,103' 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump w/ Dual Seating Cups w/ Stabilizer Bar w/ collar. C 10,104' 115' 1.28 1.66 1-1/4" Di Tube 1. 10,103' .66' 2.280 3.125 Cu T e Seatin Ni le, 2-7/8" 10,104' 6' 2.441 3.5 2-7/8" 6.4 Ib/ft, L80 Buttress Pu Joint w/collar 10,110' 1' 2.441 3.5 XO 3 ''/z" IBT Pin Ported sub x 2-7/8 IBT Box 10,1 15' S' 2.992 3.5 3 %" IBT Pu Jt. & orted sub BXP 10,116' 192' 2.992 3.5 3-1/2" 9.2 Ib/ft, L80 Buttress 2. 10,307' 1' 2.441 4.25 XO 2 7/8" IBT Pin X 3-1/2" IBT box. 3. 10,308' 8' 2.441 3.2 2 7/8" IBT Pu Joint, 6.4 #, L-80 w/ collar 4. 10,316' 2' 2.188 3.500 Otis "R" Profile ni le, 2.180" w/ lu in lace 5. 10,319' 2' 2.312 7.437 Baker L-10 on/off tool w/ box 6. 10,320' 2' 2.441 3.688 X-over, and Mod orted collar. 7. 10,322' 3' 4.875 7.000 "E"-22 Anchor Tb .Seal ass. w/out seals 5.5 LTC box 8. 10,323' 6.000 8.438 Baker"F-1" 190-60 Retainer Production Packer. nc Tagg, o n 10, P BTD = 11,138' TD = 17,689' MAX HOLE ANGLE = 2 deg. ~ 6100' WBD SCU 33-33 R1 2008.doc PERFORAT ION HISTORY Interval Zone Top Btm Amt Comments G•zone 10,478' 10,512' 34' Hl 10,562' 10,588' 26 ~ 1o,61a 10,628' is H3 10,640' 1Q649' 9' H4 10,651' 10,658' T IIS 10.670' 10.712' 42' DRAWN BY: slt REVISED: 3/16/01 REVISED BY:jrn REVISED: 10/21/04 Orig RKB =1T Nor: 9-Sib"~sg is Kery Whipel, bad • ALASSA OIL A11TD GAS COI~TSERQATIOlY CODIIri15SIO1Q Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage, AK 99519 4~C.MJ'V.'L~~~"~~6/ ~~j.' _. ii ~.~.V~L7 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Swanson River Field, Hemlock G Oil Pool, SCU 33-3 Sundry Number: 308-372 Dear Mr. Brandenburg: b .0~ ~~b Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~ Daniel T. Seamount, Jr. Chair '~ DATED this~~ day of October, 2008 Encl. • Chevron October 15, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, AK 99501 Dear Commissioner, ~~ ~`16~ After reviewing our well files for Soldofia Creek Unit (SCU) 33-33, we have come across a form 10-403 that was submitted and approved on 4/7/06 for this well (Sundry Number 306-130). The well work was never performed due to initial material delays and subsequent falling in job priority. We apologize for this delay and we are filing a new form 10.403 to request the change in scope of the past approved program for the upcoming work on this well. Thank you for your understanding. Sincerely, ~~~ Timothy C. Brandenburg Drilling Manager ~~~~~.. tf~ r ~ (`~ ~~~ For any questions or concerns, please contact Jack Newell at 263-7832. :-`86R~4't Rl9 X+'lF sh ~~Jq~~4': vf~l~ ., ~, 53 i~~*, li?1~tF.f C't kS..S.'~F ~Yyi Attachments: 10-403 for Soldotna Creek Unit 33-33 ~0,2~' ~~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION CbM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 ~~~ is o?0-08 ~-~i 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate Q ~ Waiver^ OtherO Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Rod pump Change approved program0 Pull Tubins0 Perforate New Pool ^ Re-enter Suspended Well ^ recomplete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ ~ Exploratory ^ 176-056 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20293-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Soldotna CK Unit SCU 33-33' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028990 17' Swanson River Field/Hemlock Oil Pool & G-Zone Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17,689' ~ 17,659' 10,693' 10,691' N/A N/A Casing Length Size MD TVD Burst Collapse Structural 90' 20" 90' 89' Conductor 3,880' 13-3/8" 3,880' 3,879' 5 psi 1,950 psi Surface 11,350' 9-5/8" 11,350' 11,348' _ 7,100 psi Intermediate , .S Production ' Liner _ 8S ,~ ~#$ ~ c: , _ _' ~~ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: ohs... ; . . ~ Tubing MD ): See Attached Schematic See Attached Schematic 2-7/8" 6.4# L-80 10,323' Packers and SSSV Type: Packers and SSSV MD (ft): Baker F-1 190-60 Retainer Production Packer / N/A 10,323' ! N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 11/24/2008 16. Well Status after proposed work: Commencing Operations: Oil Q ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263-7832 Printed Name ~ Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 10/14/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r Plug Integrity ^ BOP Test `~ Mechanical Integrity Test ^ Location Clearance ^ ~~~ ~'~ ~'~ ~~~--~ other: ~,~ ~C~ A E'aC,,. ~S , ~~~`h~ ,G.~~c~rc~.~€ ~~iP ~ C.i ~Q~`~C'c~ ~~ (<y, d ~~ Subsequent Form Required: L.I ~I~` APPROVED BY / ~ ~ 2 Approved by: _ COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~' ~~~~ Submit in Duplicate Chevron ~ • Swanson River Unit Well #SCU 33-33 10/14/08 OBJECTIVE: • Rig de completion perforation, with recompletion of rod pump assembly in well SCU 33-33 PROCEDURE SUMMARY: - Prep location and pad. Disconnect and roll Rotaflex out of the way. - MIRU Nabors Rig 106E Swanson River Field. - Strip Rod Surface equip off well. NU Rod BOPE. LD Polish Rod. - Unseat Rod pump. POOH LD EL Rods & pump Assy. - Install BPV. ND tree. NU BOPE. Test Same. Test t/ 250 PSI Low - 3000 PSI High - PUMU Land joint. Unseat Mandrel from Tension hanger. Lower string to neutral. Release anchor by working right-hand torque to anchor. - POOH Stand back tubing. - RU slickline. RIH w/ GR & 3-1/2" Dummy Gun. Tag for fill. RIH w/ Temp/Pressure Survey. POOH. RD Slickline. - RU Eline. RIH Re-Perf G zone & Hemlock. RD. - PUMU Screen, Rod Seat, Parallel Anchor Seal Assy. - RIH on tbg. Latch into pkr @ 10,323'. Hang tbg in tension. - Install BPV. ND BOPE. NU Tree. Test same. NU Rod BOPE. Test same. - PU Rod Pump. RIH w/ same on tapered rod string. Land/space-out polish rod. - Release & Demobe rig. SCU 33-33 WO 2008 Operation Summery.doc REVISED BY: CVK 9-22-08 Revised 10-06-2008 JRN • UNOCAL ~6 API# 50-133-20293-00 ctual Com letion • Swanson River Field Soldotna Creek Unit Well No. 33-33 SILE W'1' CASING AND TUBING DETAIL GRADE CONN ID TOP B'I'M. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.415 Surface 3880' 9-5/8" 47 5-95 8.681 Surface 6295' 53.5 S-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323' IFWFI.RV IIF.TAII. NO. De th Len th ID OD Item 17.00' 1' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-'/e" 8rd Lift x Butt down. 36' 1.5 Polish Rod (spaced out 6' above stuffing box w/ pump 1.5' off btm). A 2' ------ 1" 1" x 2' EL Pony Rod Spacer Pup 3,300' 1" I" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 132 rods 3,650' '/K" 7/8" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 146 rods 3075' '/e" 3/4" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 123 rods B 10,103' 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump w/Dual Seating Cups w/ Stabilizer Bar w/ collar. C 10,104' 115' 1.28 1.66 1-1/4" Di Tube 1. 10,103' .66' 2.280 3.125 Cu T e Seatin Ni le, 2-7/8" 10,104' 6' 2.441 3.5 2-7/8" 6.4 Ib/ft, L80 Buttress Pu Joint w/collar 10,110' 1' 2.441 3.5 XO 3 '/~" IBT Pin Ported sub x 2-7/8 IBT Box 10,115' S' 2.992 3.5 3 %" IBT Pu Jt. & orted sub BXP 10,116' 192' 2.992 3.5 3-1/2" 9.21b/ft, L80 Buttress 2. 10,307' 1' 2.441 4.25 XO 2 7/8" IBT Pin X 3-1/2" IBT box. 3. 10,308' 8' 2.441 3.2 2 7/8" IBT Pu Joint, 6.4 #, L-80 w/ collar 4. 10,316' 2' 2.188 3.500 Otis "R" Profile ni > >le, 2.180" w/ lu in lace 5. 10,319' 2' 2.312 7.437 Baker L-10 on/off tool w/ box 6. 10,320' 2' 2.441 3.688 X-over, and Mod orted collar. 7. 10,322' 3' 4.875 7.000 "E"-22 Anchor Tb .Seal ass. w/out seals 5.5 LTC box 8. 10,323' 6.000 8.438 Baker"F-1" 190-60 Retainer Production Packer. nc egged l i Il/14. PBTD = 11,138' TD = 17,689' MAX HOLE ANGLE = 2 deg. (a7 6100' WBD SCU 33-33 R1 2008.doc PERFORAT ION HISTORY Interval Zone Top Btm Amt Commnts G-zone 10,478' 10,512' 34' Hl 10,562' 10,588' 26 H2 10,610' 10,628' 18' H3 10,640' 1Q649' 9' H4 10,651' 10,658' T HS 10,670' 10,712' 42' DRAWN BY: slt REVISED: 3/16/01 REVISED BY:jrn REVISED: 10/14/04 o~~~ [tlc6 = 17' ;~ ~ ~ Swanson River Field I~ Soldotna Creek Unit VN~CA~ 76 Well No. 33-33 API# 50-133-20293-00 Pro osed Com letion Orig. RKB = l7' WO RKB =1225' CASING AND TUBING DETAIL SIZE WT GRADE CONK ID TOP BTM. 20" - - - Surface 90' 13-3/8" 68 K-55 - 12.415 Surface 3880' 9 /8" 47 S-95 8.681 Surface 6295' -5 53.5 5-95 8.535 6295' 11,350' Tubin 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,753' 3/8" CIL 316 SS Surf 10,750' JEWELRY DETAIL NO. De th Len th ID OD Item 17.00' 1' 2.441 1 1.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-'/8" 8rd Lift x Butt down. 36' 1.5 Polish Rod (spaced out 6' above stuffing box w/ pump 1.5' off btm). A 2' ------ 1" 1" x 2' EL Pony Rod Spacer Pup 3,500' 1" 1" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 132 rods 3,900' '/e" 7/8" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 146 rods 3300' '/<" 3/4" EL Sucker Rod, w/ Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides er rod 123 rods 1. 3000' 1' 2.441 5" De th Indicator Sub 2. 10,322 .66' 2.375 Model "A"-Anchor Parallel Tbg Seal Assy w/ 3 sgin by- ass area. 3. 10,323' 1' 2.441 4.25 Baker"F-1" 190-60 Retainer Production Packer. B 10,684' 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump w/ Stabilizer Bar & collar Petro-Tech circulating Valve between pump & Dual Seatin Cu s. 4. 10,726' Cu T e Seatin Ni le, 2-7/8" 5. 10,730' 80' 3.958 40' of 4-1/2" Wire Wrap Screen. (two 20' jts) 20' of 4-1/2" Blank Pi e w/ bull lu C 30' 1.28 1.66 1-1/4" Di Tube PERFORATION HISTORY Interval Zone Top Btm Amt Corments G-zone 10,478' 10,512' 34' Hl 10,562' 10,588' 26' H2 10,610' 10,628' 18' H3 10,640' 10,649' 9' H4 10,651' 1Q658' T HS 10,670' 1Q,712' 42' WBD_SCU_33-33_Proposed_10-008.doc DRAWN BY: slt: 11/30/2005 Revised jrn 10/14/2008 P BTD = 11,138' TD = 17,689' MAY HOLE ANGLE = 2 deg. ~ 6100' ,BORS 106E BOP DATA Chevron Job - Plug 8 Abandonment Location - SRU 33-33 Rig - Nabors #106E Stack: Size 13-5/8 in Pressure Rating 5000 psi Nace Trim Yes Annular: Make/Model Shaffer Spherical Pressure Rating 3000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL VBR Pressure Rating 5000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL Blind Pressure Rating 5000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL Pipe Pressure Rating 5000 psi Closing Volume Opening Volume Kill line: Line size 2 inch Valve (1st) Manual Valve (2nd) HCR Chock line: Line size 3 inch Valve (1st) Manual Valve (2nd) HCR e e rID FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, SCD 33-33 Sundry Number: 306-130 t1 ~ - o5(¡; -. <"'I\..~)~I~'" 0" :JI\N"¡¡ .~, ~...._, .':~ ~!, ~; n rt~J""'.,: .1, "';.. '..........':,..1 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been reque~ted. Sincerely, . DATED this-t- day of April, 2006 Encl. STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMeoN APP~ATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 17' Suspend D Repair well D Pull Tubing [] Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate ~ Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Other ~ Workover Development [] Stratigraphic D Exploratory D 176-056 Service D 6. API Number: 50-133-20293-00 9. Well Name and Number: 8. Property Designation: Soldotna Creek Unit SCU 33-33 10. Field/Pools(s): Swanson River Field/Hemlock 11. Total Depth MD (ft): 17,689' PRESENT WELL CONDITION SUMMARY Casing Structural Conductor Surface Intermediate Production Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17 ,659' 10,693' 10,691' Length Size MD TVD Burst Collapse 90' 20" 90' 89' 3,880' 13-3/8" 3,880' 3,879' 3,450 psi 1,950 psi 11 ,350' 9-5/8" 11,350' 11,348' 8,150 psi 1,580 psi Liner Perforation Depth MD (ft): 10,478 to 10,712' Packers and SSSV Type: Perforation Depth TVD (ft): 10,476 to 10,710' Tubing Size: 2-7/8",6.4# Tubing Grade: L-80 Packers and SSSV MD (ft): Tubing MD (ft): 10,323' Baker F-1 190-60 retainer production packer 10,323' 12. Attachments: Description Summary of Proposal U Detailed Operations Program [] BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg ____ Title Drilling Manager Signature ~ <z A ...- ..d>hone 907-276-7600 Date If _:; 0(:. ¿:;;> f COMMISSION USE ONLY '" Date: 13. Well Class after proposed work: ~ck'" Exploratory D Development [] oz,ooG 15. Well Status after proposed work: 6/1/~ Oil G Gas D Plugged D WAG D GINJ D WINJ D Service D WDSPL D D Abandoned Conditions of approval: Notify Commission so that a representative may witness Sundry Number: &t..o -- !~} Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D r-e-v VJMLlS. o~~lcl.)L¿J~(~\ Q:Jtev-tulL j~ ck-~~ '7t..Upw.c..wJ /$ t:tff~()\(eJ. Subsequent Form Required: I 0 - ~. (/ j, APPROVEOBY II Approved by: .,--1,J./ f COMMISSIONER THE COMMISSION \"pate: T-7".~ ~1U~~ '\ C ~TL R8DMS BFL APR 1 0 Z006~' Form 10-403 Revised 07/2005 U1 t"'L I ,A I ßFE 164958 , Submit in Duplicate e e UNOCAL€Ð Swanson River Field Soldotna Creek Unit Well No. 33-33 API# 50-133-20293-00 ¡Actual Completio~ Orig. RKB ~ 17' WO RKB ~ 12.25' Note: 9.518" c.çg i.f Kelly Whiped, bad. Csg ¡"tegrity ¡.f que:"i""uble @ 500 p.ç;. CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" Surface 90' 13-3/8" 68 K-55 12.415 Surface 3880' 9-5/8" 47 S-95 8.681 Surface 6295' 53.5 S-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323' JEWELRY DETAIL A NO. Depth Len!!th ID OD Item 17.00' I' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-? " 8rd Lift x Butt down. 36' - 1.5 Polish Rod (spaced out 6' above stuffing box wI pump 1.5' off btm). A 2' ----- I" I" x 2' EL Pony Rod Spacer Pup 3,300' - I" 1" EL Sucker Rod, wI Slimhole Class T coupling wi (3) 2.25" R&M Stealth XL AF Rod Guides per rod (132 rods) 3,650' - ?" 7/8" EL Sucker Rod, wI Class T coupling wI (3) 2.25" R&M Stealth XL AF Rod Guides per rod (146 rods) 3075' - 3;4" 3/4" EL Sucker Rod, wi Class T coupling wI (3) 2.25" R&M Stealth XL AF Rod Guides per rod (123 rods) B 10,103' 41.45' 1.75 2.25 1-3/4" RXBC DbI valve Pump wI Dual Seating Cups wI Stabilizer Bar wI collar. C 10,104' 115' 1.28 1.66 I -1/4" Dip Tube 1. 10,103' .66' 2.280 3.125 Cup Type Seating Nipple, 2-7/8" 10,104' 6' 2.441 3.5 2-7/8" 6.4lb/ft, L80 Buttress Pup Joint wlcollar 10,110' l' 2.441 3.5 XO 3 W' IBT Pin Ported sub x 2-7/8 IBT Box 10,115' 5' 2.992 3.5 3 W' IBT Pup Jt. & ported sub BXP 10,116' 192' 2.992 3.5 3-1/2" 9.2Ib/ft, L80 Buttress 2. 10,307' I' 2.441 4.25 XO 2 7/8" IBT Pin X 3-1/2" IBT box. 3. 10,308' 8' 2.441 3.2 27/8" IBT Pup Joint, 6.4 #, L-80 wi collar 4. 10.316' 2' 2.188 3.500 Otis "R" Profile nipple, 2.180" wI plu!: in place 5. 10,319' 2' 2.312 7.437 Baker L-IO on/off tool wI box 6. 10,320' 2' 2.441 3.688 X-over, and Mod ported collar. 7. 10,322' 3' 4.875 7.000 "E"-22 Anchor Thg. Seal ass. wlout seals 5.5 LTC box 8. 10,323 ' 6.000 8.438 Baker"F-I" 190-60 Retainer Production Packer. PERFORATION HISTORY Interval Zooe Top Btm AIIÌ Comments G-zone 10,478' 10,512' 34' HI 10,562' 10,588' 26 H2 10,610' 10,628' 18' H3 10,640' 10,649' 9' H4 10,651' 10,658' 7' H5 10,670' 10,712' 42' PBTD = 11,138' TD = 17,689' MAX HOLE ANGLE = 2 deg. @6100' SeD 33-33 Schematic 10-04 DRAWN BY: sIt REVISED BY:crw REVISED: 3/16/01 REVISED: 11109/04 UNOCAL~ e e Swanson River Field Soldotna Creek Unit Well No. 33-33 API# 50-133-20293-00 ¡Proposed Completionl Orig. RKB = 17' WO RKB = 12.25' seD 33-33 Proposed Schematic CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" Surface 90' 13-3/8" 68 K-55 12.415 Surface 3880' 9-5/8" 47 S-95 8.681 Surface 6295' 53.5 S-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323 ' JEWELRY DETAIL w NO. Depth Len!th ID 00 Item 17.00' I' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, II" DCB x 2-? " 8rd Lift x Butt down. 36' - 1.5 Polish Rod (spaced out 6' above stuffing box wI pump IS off btm). A 2' ----- I" I" x 2' EL Pony Rod Spacer Pup 3,300' - I" I" EL Sucker Rod, wI Slimhole Class T coupling wI (3) 2.25" R&M Stealth XL AF Rod Guides per rod (132 rods) 3,650' - ? " 7/8" EL Sucker Rod, wI Class T coupling wI (3) 2.25" R&M Stealth XL AF Rod Guides per rod (146 rods) 3075' - %" 3/4" EL Sucker Rod, wI Class T coupling wI (3) 2.25" R&M Stealth XL AF Rod Guides perrod (123 rods) 1. 10,322 .66' 2.375 Model "A"-Anchor Parallel Tbg Seal Assy w/3 sqin by-pass area. 2. 10,323 ' I' 2.441 4.25 Baker"F-I" 190-60 Retainer Production Packer. B 10,700' 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump wI Stabilizer Bar & collar Petro-Tech circulating Valve between pump & Dual Seating Cups. 3. 10,750' Cup Type Seating Nipple, 2-7/8" 4. 10,753' 80' 3.958 20' of 4-1/2" Wire Wrap Screen. 60' of 4-1/2" Blank Pipe C 30' 1.28 1.66 1-1/4" Dip Tube G-Zone HI H2 H3 H4 H5 PERFORATION HISTORY Interval Zone Top Btm AnI: Comments G-zone 10,478' 10,512' 34' HI 10,562' 10,588' 26' H2 10,610' 10,628' 18' ID 10,640' 10,649' 9' H4 10,651' 10,658' ., H5 10,670' 10,712' 42' DRAWN BY: sIt: 11130/2005 e e Swanson River Field seD 33-33 WO Summary of Operations þ.> Prep location and pad. Disconnect and roll Rotaflex out of the way. þ.> Mobe Nabors 126 to Swanson River Field. þ.> Spot pulling Unit. RU production Hoist. þ.> Strip Rod Surface equip off well. NU Rod BOPE. LD Polish Rod. þ.> Unseat Rod pump. POOH LD EL Rods & pump Assy. þ.> Install BPV. ND tree. NU BOPE. Test Same. þ.> PUMU Land joint. Unseat Mandrel from Tension hngr. Lwr string to neutral. Release anchor by working right-hand torque to anchor. þ.> POOH Stand back tbg. þ.> PUMU 100' of Weatherford 5-3/4" Vacuum Bailer & BHA. þ.> RI H with tbg. þ.> Attempt to work bailer down to 10,750'. POOH stand-back tbg. Dump bailer @ surface. LD Bailer. þ.> RU slickline. RIH w/ GR & 3-1/2" Dummy Gun. Tag for fill. RIH w/ Temp/Pressure Survey. POOH. RD Slickline. þ.> RU Eline. RIH Re-Perf G zone & Hemlock w/ 3-1/2" PowerJet Omega Guns. RD. þ.> PUMU Screen, Rod Seat, Parallel Anchor Seal Assy. þ.> RIH on tbg. Latch into pkr @ 10,323'. Hang tbg in tension. þ.> Install BPV. ND BOPE. NU Tree. Test same. NU Rod BOPE. Test same. þ.> PU Rod Pump. RIH w/ same on tapered rod string. Land/space-out polish rod. þ.> Release & Demobe rig. UNOCALSWANSON 11" 5M Annular BOP 5M Studded Top and Flanged Bottom 11" 5M Annular BOP 11" 5M Double Ram 11" 5M Drillin S 001 wi 2 ea 4" 5M OTL 2 1/16 5M Manual Gate Valve 2 1/16 5M Manual Gate Valve 21/16 5M Manual Gate Valve 2 1/16 5M Manual Gate Valve ~~ : ::J:il11" 5M Double Ram e ~ dJ1 Optional 11" 5M Drilling Spool wI 2 ea 4" 5M OTL 12" 5m Hose wI flange connections. e 2" 5m High Pressure hose. To Flow Back Tank SCU 33-33 Gas Monitoring During WO e e Subject: SCU 33-33 Gas Monitoring During WO From: "Tyler, Steve L" <tylersl@chevron.com> Date: Fri, 07 Apr 2006 13: 13:53 -0800 To: "Aubert, Winton wI AOGCC" <winton_aubert@admin.state.ak.us> Winton We will have WSI Total Safety on SCU 33-33 location, providing H2SILEL sensors at the rig site. Steve Tyler Union Oil Company of California *Office: (907) 263-7649 *Cell: (907) 350-6295 *Home: (907) 696-1837 *Fax: (907) 263-7389 *Email: tvlersl@chevron.com II. , ,~I Content-Type: apPlicatiO,nlms-tn;;t]1 i wmmall.dat, . J L_ __------II C~te~t-Enco~mg: base~___ 1 of 1 417/20061:25 PM e e Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com April 3, 2006 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Request for Variance-SCU 33-33 Mr. Aubert, We are requesting a variance of 20 AAC 25.285 (c) (9) and (10). We are preparing to perform well intervention work on SCU 33-33 with a "well servicing unit" provided by Nabors Alaska Drilling. We augmented the BOP equipment on the unit to satisfy our internal standards. We believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the well to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. Sincerely, ~c_ Timothy C. Brandenburg Drilling Manager Attachments Union Oil Company of California I A Chevron Company http://www.chevron.com e e Winton Aubert AOGCC 4/3/2006 Page 2 Well Descriptions Well: SCU 33-33 Reservoir The BHP at this time is 2350 psi @ 10,476' TVD (G Zone) which is equivalent to a .224 psi/ft gradient or a 4.31 ppg EMW. Fully evacuated, the MASP would be as follows: 2350 psi BHP - (10,476' TVD x .1psi/ft Gas Gradient) = 1,302psi MASP. Proposed Configuration BOP's Annular, 5K, 11" Double gate, 5K, 11" Mud Cross, 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2",3000 psi Iron or 2",5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16", 5K valves attached to either the mud cross or the tubing spool annulus valve. Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2",5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The c~oke manifold is 2-1/16", 5K with two manual chokes and four valves. Union Oil Company of California I A Chevron Company http://www.chevron.com e e Winton Aubert AOGCC 4/3/2006 Page 3 Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. Union Oil Company of California / A Chevron Company http://www.chevron.com ) STATE OF ALASKA, AlA5. ,Oil AND GAS CONSERVATION COMM. )ION REPORT OF SUNDRY WELL OPERATIONS 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate Other Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 76-56 Service D 6. API Number: 50-133-20293-00 9. Well Name and Number: SCU 33-33 10. Field/Pool(s): Swanson River Field/G Zone 1. Operations Abandon Repair Well ../ Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: Total Depth measured 17,689' true vertical 17,659' feet feet Plugs (measured) Junk (measured) 7. KB Elevation (ft): 17' 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: Effective Depth measured 10,607' true vertical 10605' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 90' 20" 3,880' 13-3/8" 11,350' 9-5/8" MD 90' 3,880' 11,350' TVD Burst Collapse 89' 3,879' 3,450 psi 1,950 psi 11,348' 8,150 psi 1,580 psi Perforation depth: Measured depth: 10,478 to 10,712' SCAN~"En DEC True Vertical depth: 10,476 to 10,710 Tubing: (size, grade, and measured depth) 2-7/8",6.4#, L-80 @ 10,323' Packers and SSSV (type and measured depth) Baker F-1 190-60 Retainer Production Packer @ 10,323' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 121 24 150 356 0 150 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil 0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 14 121 Tubing Pressure 150 150 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: Contact Steve Tyler 263-7649 RBDMS BFL DEC 1 3 1004 Printed Name Tim C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 12/6/2004 Form 10-404 Revised 04/2004 Submit Original Only UNOCAL8 API# 50-133-20293-00 [š] Orig. RKB = 17' WO RKB = 12.25' .J l ¿ ~ II] NO. ) Depth 17.00' A m IT] [£] B 10,103 ' 1. G-Zone HI m¡¡¡¡r¡¡¡¡¡i¡'~jr¡r~[¡rr1S H2 ~ Tagged Fill @ ;~, H3 ~ 10,607' on 10/10/04 ¡ H4 ~¡I¡r~,r~mmmi: H5 III11 ~~~ PBTD = 11,138' TD = 17,689' MAX HOLE ANGLE = 2 deg. @ 6100' seD 33-33 Schematic 10-04 2. 3. 4. 5. 6. 7. 8. 10,322' 10,323 ' ) Swanson River Field Soldotna Creek Unit Well No. 33-33 ~ctual Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" Surface 90' 13-3/8" 68 K-55 12.415 Surface 3880' 9-5/8" 47 S-95 8.681 Surface 6295' 53.5 S-95 8.535 6295' 11,350' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 15' 10,323' JEWELRY DETAIL Leneth ID OD Item 1 ' 2.441 11.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-1"8" 8rd Lift x Butt down. 36' 1.5 Polish Rod (spaced out 6' above stuffing box wi pump 1.5' off btm). 2' I" 1" x 2' EL Pony Rod Spacer Pup 3,300' I" I" EL Sucker Rod, wi Slimhole Class T coupling wi (3) 2.25" R&M Stealth XL AF Rod Guides per rod (132 rods) 3,650' 18" 7/8" EL Sucker Rod, wi Class T coupling wi (3) 2.25" R&M Stealth XL AF Rod Guides per rod (146 rods) 3075' %" 3/4" EL Sucker Rod, wi Class T coupling wi (3) 2.25" R&M Stealth XL AF Rod Guides per rod ( 123 rods) 41.45' 1.75 2.25 1-3/4" RXBC Dbl valve Pump wi Dual Seating Cups wi Stabilizer Bar wi collar. .66' 2.280 3.125 Cup Type Seating Nipple, 2-7/8" l' 2.441 3.668 XO 2-7/8" IBT Pin x 2-7/8" EUE 8RD Box 6' 2.441 3.5 2-7/8" 6.4 lblft, L80 Buttress Pup Joint wlcollar 1 ' 2.441 3.5 XO 3 W' IBT Pin Ported sub x 2-7/8 IBT Box 5' 2.992 3.5 3 W' IBT Pup J1. & ported sub BXP 192' 2.992 3.5 3-112" 9.2 lblft, L80 Buttress l' 2.441 4.25 XO 27/8" IBT Pin X 3-112" IBT box. 8' 2.441 3.2 2 7/8" IBT Pup Joint, 6.4 #, L-80 wi collar 2' 2.188 3.500 Otis "R" Profile nipple, 2.180" wI plug in place 2' 2.312 7.437 Baker L-lO on/off tool wi box 2' 2.441 3.688 X-over, and Mod ported collar. 3' 4.875 7.000 "E"-22 Anchor Tbg. Seal ass. wlout seals 5.5 LTC box 6.000 8.438 Baker"F -1" 190-60 Retainer Production Packer. Zone G-zone HI H2 ill H4 H5 PERFORATION HISTORY Interval Top Btm 10,478' 10,512' 10,562' 10,588' 10,610' 10,628' 10,640' 10,649' 10,651' 10,658' 10,670' 10,712' Ant Comœnts 34' 26' 18' 9' '7 42' DRAWN BY: sIt REVISED BY:crw REVISED: 3/16/01 REVISED: 11/09/04 10/7/04 Remarks MI/RU Bled off casing gas pressure to blow down tank 50 PSI, Picked up polish rod, Up weight 24 picked up and worked. LD polish rod and 2 pups Work rods, tight approximately 6' feet up hole Fill pits with 30 bbl diesel and added 1 drum of Pao-33, PT lines to 1000 PSI. Continue to work rod string. RU and pump lease oil at 80 degrees ) ) 10/8/04 Remarks Ready equipment for blind back off and SOP NU Attempt blind SO using hydraulic rod tongs. RU Foster tongs. Install bushing for blind BO on 111 rods. Rotate ods using Foster tongs in break out direction. POOH with rods hanging in derrick 130 111 rods, 20 7/811 rods RID rod table, hang rig floor prep for NO of tree Set 2.5" CIW H BPV ND and remove tree inspect hanger neck and lift threads 2 7/8" EUE, Prep BOP, set choke manifold, set koomey unit Install 6' riser, double gate, and annular. Install choke and kill valves, wear plate 10/09/04 Remarks Continue to tighten BOP connections hook up choke and kill lines. Install rams in BOP Test BOPE to 250 PSI low and 3000 PSI high. LD test joint and pull TWC, RU pulling joint, ready floor to rotate out of anchor and pull tubing PU 80 K and un J from tension hanger, start to slack off weight dropped to 77K, slacked off 18'. PU same 77K up weight, BO LOS and pulled hanger to surface with 77K up weight. LD pulling joint, hanger, and hanger joint. POOH with 2 7/811 1ST tubing, racking back in derrick POOH and LD 38 7/8 rods, RU and pull 2 7/8" 1ST tubing POOH with rods laying down in singles recovered 1267/8" rods and 4 3/4" rods POOH with 2 7/8" 1ST tubing, racking back in derrick, at 97 stands and 2 singles out 1 0/1 0/04 Remarks RU Pollard RIH to make tubing punch, tagged rods at 825' down from surface picked up and located collar at 757' set collar stop and punched hole in tubing. RD Pollard. POOH with tubing to hole, lay down 2 joints, continue to POOH to rods RU on rods. POOH with 120 joints of 3/4" rods and lay down same. RU Pollard and RIH with A slip stop. Set stop at 2987' just above rods and POOH. POOH and rack back 109 stands. Laid down 14 joints. (155 stands in derrick LID 14 joints = 324 total joints pulled). LID 3 joints of 3/4" rods. LID anchor and jewelry. Pump was free and would stroke. (Recovered 130 each 111 rods, 146 each 7/8" rods and 127 each 3/4" rods) RU Pollard and RIH with 2.9" swedge and tag fill at 10607'. POOH Pick up gauges and RIH for pressure gradient survey. 10/11/04 Remarks Finish pressure gradient survey with Pollard Make junk basket run on Pollard wireline. Found fluid level @ 3850' Shot fluid level @ 3800' PU MU BOT Model "E" anchor latch, OnlOfftool, (190') 3-1/2" Gas anchor assembly. RIH on 2-7/8" Buttress tubing. Rabbit and strap each stand while RIH. 48 stands in hole. RU Pollard wireline. Pump 5 bbl of diesel wI PAO-33 down tubing. Chased same w/10 bbl of lease water. RIH wI "W" circulating plug wI 2.30" centralizer. No-Go plug on dual cup seating nipple @ 3037'. RI set IIG" stop on plug. Pressure test surface lines to 1500 psi. Pressure tested tubing to 1500 psi for 5 min. Continue RIH wI 2-7/8" tubing. Hydro-test tubing to 1500 psi every 5 stands. 1 0/12/04 Remarks Continue RIH wI 2-7/8" tubing. Hydrotest tubing to 1500 psi every 10 stands to anchor depth of 10274'. SCU 33-33 morning report summary, AFE 162874, CONFIDENTAL: last revised 11/15/2004 Page 1 'II ,) RÙ Pollard wireline. RIH latchlpull ~) Stop anchor. RIH latch "W" circulating Plu~! Shear equalizing ports. Allow tubing to equalize (10 min). Retrieve plug. PU 3 joints of 2-7/8". RIH latch into "F" packer @ 10,323'. Pull 55" of stretch. Mark pipe for space-out. Slack off release from OnlOff tool. PU LD 2 joints. PU/MU 5' & 4' pups for space out. PU slick joint, Seaboard tubing hanger & landing joint. Rlland tubing hanger. RI LOS. Un "J" mandrel from parent bowl. Rllatch on/off tool. PU 62" (27,500#) stretch. "J" mandrel into parent bowl. BO land joint. Install BPV. NO BOPE. NU tree. 10/13/04 Continue NU tree. Install TWC valve. Pressure test tree to 5000 psi. Lower driller platform. Remove TWC. PU RXBC pump & dip tube. RIH on tapered rod string. (118) 3/4" Rods, (151) 7/8" Rods & (132) 1" Rods. Tag seating nipple. PU space out. Added (1) 2' pony rod. PUMU polish rod. Strip offWO BOPE & table. Strip on surface equip. MU polish rod. Added 16 bbl of lease water down tubing. PT to 1000 psi for 5 min. Stroke pump. Verify working. Move floor. Blow down lines and secure Uskids. Remove weight indicator & Koomey panel. RIG RELEASED @ 2400 HRS. SCU 33-33 morning report summary, AFE 162874, CONFIDENT AL: last revised 11/15/2004 Page 2 ~~-,,:---t r.:1 1? ~ ~ ¡P-"- r- {~(;:::'\ (~lrJß\!iIÞ In) 1~\lll~\~ r¡1 iU! /,=;\ II' ¡L ¡uJ In' ¡L¡r~\ruJ ",,::;j uuu~ ~ b-iUi_~LL-.....::.../ / I ¡ / I ¡ I I I 176~-t)~~ FRANK H. MURKOWSKI, GOVERNOR AItASIiA OIL AlWD GAS CONSERVATION COMMISSION i / 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 22,2004 Mr. Philip J. Krueger Drilling Manager D nocal Alaska PO Box 196247 Anchorage AK 99509-3330 RE: Swanson River Field Workover HOPE Configuration Dear Mr. Krueger: Per 20 AAC 25.285 (h), the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Dnocal Alaska ("Dnocal")'s request for variance from the workover blowout prevention equipment ("BOPE") requirements of 20 AAC 25.285 (c) and ( e), during operations on wells in the subject field. This variance is applicable to Swanson River Field wells SCD 32-08, SCD 33-33, SCD 312-09, SCU 24A-05, SCD 21-03, SRD 23-27, and SRU 32A-15. AOGCC finds that Unocal's requested variance provides at least an equally effective means of ensuring well control as that required by regulation. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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 h~day or weekend. A person may not appeal a Commission decision to Superior Court y6ie~ehearing has been requested. ( / .... 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: Variance: Perforate: Other: X Rod Pump Change 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 18' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519/ Service: Soldotna Creek Unit 4. Location of well at surface ~' ~r ,,/' 8. Well number 1,400' FSL, 1,700' FEL, Sec. 33, T8N, R9W, SM SCU 33-33 At top of productive interval 9. Permit nu,~ber Same 76-56 At effective depth 10. APl number Same 50- 133-20293-00 At total depth 11. Field/Pool Same Swanson River Field / Hemlock and Tyonek G 12. Present well condition summary Total depth: measured 17,689' ~/// feet Plugs (measured) 11,138' MD/TVD true vertical 17,689'~/' feet Effective depth: measured 11,138' feet Junk (measured) None true vertical 11,138' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 72' 20" 90' 90' Surface 3,862' 13-3/8" 3,880' 3,880' Intermediate Production 11,332' 9-5/8" 3,500 sx in 2 Stages 11,350' 11,350' Liner Perforation depth: measured 10,478'-10,512'; 10,562'-10,588'; 10,610'-10,628'; 10,640'-10,649'; 10,651'-10,658'; 10,670'-1~171~!' ;i'" i true vertical 10,478'-10,512'; 10,562'-10,588'; 10,610'-10,628'; 10,640'-10,649'; 10,651'-10,658'; 10,670'-10,712' Tubing (size, grade, and measured depth) !' ,~..".~. 2-7/8", 6.4#, N-80 to 10,324' Packers and SSSV (type and measured depth) ~,i;~.Si~3 L~i?. ~,~ ~:i;~'~ ~..~ii ;. Baker Model "D" (Used as Tubing Anchor for rod pump) @10,324' 13. Attachements Description summary of proposal: Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 8/25/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~.,~ ~ Title: ~-~'¢k.J..~~ .,/.// FOR COMMISSION USE ONLY Conditions OfPlugapproval:integrityNotify CommissiOnBopSO Testrepresentative~ may witneSSLocation"~j~clearance ~ ~,x ~'~"~::~ '%~ V'~eC'C&~'~ [ A P P r°v.~.~,~, ,.J,--.,._~ ~ ~) 4;} Mechanical Integrity Test Subsequent form required 10- t..[~.~ 0ng~nai $~gnecl By_,_, _ / Approved by order of the Commissioner Cammy Oechsli Taylor Commissioner Date Form 10-403 Rev 06/15/88 ORiGINA L--- , SUBMIT IN TRIPLICATE BOPE Variances Unocal Swanson River Unit August- September 2002 In order to operate Nabor's Well Service Rig 26 in Alaska, Unocal requires several variances to the requirements at 20 AAC 25.285. This approval is specific to the wells listed below. Due to the specific well type or work performed in advance, the chance to encounter hydrocarbons that can flow to surface is remote. Work on other well types using these specific waivers is not approved. SRU 32-33 WD WO SCU 13-34 WO SCU 33-33 WO SCU 24A-5 WO SCU 43B-8 WO SCU 21B-16 WO SRU 32A-15 WO - Replace Tubing/Packer - Replace Rod Pump - Repair Rod Pump -Install additional gas lift -Abandon Hemlock (?) Recomplete in Tyonek - Abandon Hemlock and recomplete in Tyonek - Replace corkscrewed tubing Unocal requested an exception to 20 AAC 25.066 to allow using a single LEL gas meter. Gas detection must comply with 25.066 for methane and H2S detectors (if necessary). This request is denied. Unocal proposed using high-pressure line(s) and hose with 1502 threaded connections which requires an exception to 20 AAC 25.285 (c) (9) and (e) (6). The waiver request is approved as provided by 20 AAC 25.285 (e) (6). With regard to the actual lines, hose (flexible, continuous) may be used. Steel pipe and traditional chicksan may not be employed. All of the valves Unocal plans to employ are manual. 20 AAC 25.285 (9) (C) requires that the outer choke valve must be a hydraulic valve. For the planned application with calculated pressures likely well below 2000 psi, this is acceptable and the waiver is approved as provided by 20 AAC 25.285 (h). The choke manifold does not have a bypass line per 20 ,AAC 25.285 (9) (D). The request for waiver should be approved as provided by 20 AAC 25.285 (h). Your approval of these recommendations is requested. I propose that a copy of this document with the appropriate well identified be attached to the workover Sundries as they are processed. A copy of this document is included as an attachment to the sundry approval for the respective well work. Unocal Alaska Business Unit Swanson River Well #SCU 33-33 UNOCAL No. Preliminary Procedure Slide RotaFlex Pump unit back from well. Remove flowlines to below ground level. 1 Install felt and double liner for Base Oil fluid containment. 2 MIRU Production Hoist. RU surface lines. Utilize landing rod, strip secondary BOPE, Riser, and Rod table over rods and NU to 3 tree. 4 Rotate and reciprocate rod string to attempt to free it up. If rod ~trin~:.b~o~ freb; re¢iPro~te rod ~tring up to be~t/jar rod pump: off seat. PO©H:. W/ rod ~tring; h~g in derric~i ~O ~Od Pump : : PU/MU repla¢~en~ rod ~rnp ~ ~dd::~h~r~t bbOve seal cups: Run rods land IF ROD PUMP WILL NOT PULL FREE Proceed as Follows 7 Perform blind back-off rod string. POOH hang rods in derrick 8 ND Rod BOPE. Set BPV. ND tree. NU 11" BOPE. 9 Test BOPE 250 psi to 3,000 psi. 10 Punch tubing above rods for drain hole. 11 Release Anchor from packer. 12 POOH standing tbg back in derrick to rods. Re-engage rods with rod elevators. Pull up strain on rods and perform blind back-off 13 of rod string. POOH hang rods. Continue POOH standing tubing back in derrick, Recover pump and Tubing Anchor, 14 15 PU new Anchor and completion BHA, RIH w/tbg. 16 Space out and land tubing. 17 Install BPV. ND 11" BOPE. NU tree, rod surface and BOPE equipment. PU replacement rod pump. Run rods and land pump. Space out rod string. ND strip 18 off rod running equipment off tree. MU polished rod. Release Rig. SCU 33-33 State Attachment.xls Page 1 of 1 8/22/02 UNOCAL Orig. RKB = 17' WO RKB = 20.75' i~i on 11/14/00 PBTD = 11,138' G-Zone H1 -] H2 -] H3 -! H4 SIZE WT Swans{,._ River Field Well # SCU 33-33 CASING AND TUBING DETAIL GRADE CONN ID 13-3/8" 68 K-55 9-5/8" 47 S-95 53.5 S-95 TD = 17,689' MAX HOLE ANGLE = 2 deg. ~ 6100' Tubing 2-7/8" 6.4 L-80 TOP BTM. Surface 90' 12.415 Surface 3880' 8.681 Surface 6295' 8.535 6295' 11,350' BTC SC 2.441 18' 10,400' JEWELRY DETAIL NO. Depth Length I~D OD Item 20.75' 5.96 36.43 1.5 42' 3,282' 1" 3,324' 3,657' 7/8" 6,981' 3176' ¼" B 10,157' 42' 2.15" C 10,199' 60' 1.28 1. 10,192' 2.280 2. 10,193' 2.441 3. 10,202' 2.441 4. 10,208' 2.441 5. 10,304' 2.188 6. 10,306' 2.441 7. 10,314' 2.441 8. 10,323' 4.875 10,324.' 1.665 6.00 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-%" 8rd Lift x Butt down. Polish Rod (spaced out 7' above stuffing box w/ pump 2.91' offbtm). 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 7/8" EL Sucker Rod, w/Slirnhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 1-3/4" RXBC Dbl valve Pump w/Dual Seating Cups w/Stabilizer Bar. 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose Cup Type Seating Nipple, 2-7/8" 6' Pup Joint Ported Sub 3 Joints of 2-7/8" tbg Otis "R" Profile nipple, 2.188" w/ Plug set 8/9/01 10' Pup Joint Ported Sub Baker "S-22" Anchor Latch Assy w/o seals, 190- 60 6.5 8.2! PERFORATION HISTORY Interval Zone Top Btm Amt Con~nents G-zone 10,478' 10,512' 34' H1 10,562' 10,588' 26' H2 10,610' 10,628' 18' H3 10,640' 10,649' 9' H4 10,651' 10,658' 7' H5 10,670' 10,712' 42' 8/08/02 UNOC&L Swans~__ River Field Well # SCU 33-33 SCU 33-33 BOP Arrangement for Pulling/Running Rods From Pump 47.00" 66.5" or 5.54' Rod Plate for Landing Elevators Rod BOP, with 1" x Blind Rams Rod BOP, with 1" x Blind Rams I To Choke 8/O8/02 , 1502 THO ' .o · o ,o · T1502 .. . · 1502 TI-ID · o ., 1502 THD · Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 9/14/O 1 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Subsequent Well Work Report; SCU 33-33 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits its subsequent report of wellwork operations for the subject well. Please find enclosed a Report of Sundry Well Operations (Form 404), a Workover Summary Report and an updated wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446. Drilling Manager ORIGINAL Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL ) Thursday, August 22, 2002 Commissioner Cammy Taylor AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Swanson River Form 10-403 SCU 33-33 Rod Pump Change Out Dear Commissioner Taylor: Please find the enclosed 10-403 for the rod pump replacement in SCU 33-33. The well was completed as "packer less" rod pump completion during the 2001 Workover Program. The well was de-completed and new completion tubing ran with a drilling rig. The rod pump and rods were later installed with a 50 Ton Crane after the rig was moved off the well. As required in the original Sundry Approval, a no flow was obtained on the well with an AOGCC witness prior to installation of the pump. Currently the pump is stuck in the seating nipple. The plan is to rig the pulling unit up on the well with the Rod BOP configuration proposed and attempt to unseat the pump. If unsuccessful at this attempt, it will be necessary to nipple down the Rod BOPE and install conventional BOPE (11" Double Gate and 11" Annular). The tubing would then be pulled from the well to recover the pump. The tubing would then be re-run and landed, the 11" BOPE removed and the Rod BOPE installed to allow for running of the rods. The proposed Rod BOPE configuration was utilized last year during the initial rod installations. Additional detail on the Rod BOPE is provided in a letter to Mr. Tom Maunder dated August 20, 2002. If you have any questions, please contact me at 263-7657. Sincerely, ~.~ Tim Brandenburg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: Convert to rod pump 2. Name of Operator UNOCAL 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1400' FSL, 1700' FEL, Sec. 33, T8N, R9W, SM At top of productive interval Same At effective depth Same At total depth Sterne 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) 18' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU #33-33 feet 9. Permit numbedapproval number :' 76-56 ~'~'' ~' ~ 10. APl number 50- 133-2029~3 11. Field/Pool Swanson River / Hemlock 12. Present well condition summary Total depth: measured true vertical 17,689 feet Plugs (measured) 17,689 feet None Effective depth: measured true vertical 11,138 feet Junk (measured) 11,138 feet None Casing Length Structural Conductor 72' Surface 3862' Intermediate Production 11332' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 20" 90' 90' 13-3/8" 1500 sx 3880' 3880' 9-5/8" 3500 sx in 2 stages 11350' 11350' 1~478~-1~512~~1~562~-1~588~~1~61~~-1~628~~1~64~~-1~649~~1~651~-1~658~~1~67~~-1~712~ true veHical 1~478~-1~512~~1~562~-1~588~~1~61~~~1~628~~1~64~~-1~649~~1~651~~1~658~~1~67~~~1~712~ Tubing (size, grade, and measured depth) 2-7/8", 6.4# L-80 Tubing to 10,324' Packers and SSSV (type and measured depth) Baker Model 'D' Packer @ 10,324' 13. Stimulation or cement squeeze summary NA Intervals treated (measured) NA Treatment description including volumes used and final pressure NA Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Prior to well operation 11/00 70 Subsequent to operation 9/01 236 59 64 875 59 104 45 Tubing Pressure 26O 2OO 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: 16. Status of well classification as: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dan Williamsolr~~_ Form 10-404 Rev 06/15/88 Title: Drilling Manager SUBMIT IN DUPLICATE-~ Unocal Alaska Drilling Workover Summary Report SCU 33-33 7/21/01 to 8/11/01 7/21/01 7/22/01 Accept H&R Rig #9 at 12:00 hrs. Check and test mud lines. Shoot fluid level - 8,810'. Vent annulus to tank - flowing only gas. Pump 50 bbls base oil down annulus while venting annulus gas to tank. Continue to pump base oil into annulus while venting annulus gas to tank. Install lubricator and pull BPV. Vent gas from tbg. Pump base oil down tbg. Tbg and annulus dead. N/D tree. N/U BOPE and test. M/U landing joint to tbg and pump base oil. Well dead. Pull BPV. 7/23/01 Pull hanger free and monitor well - well stable. POH slowly w/tbg until wireline fish encountered at 4,860'. Rig up T-bars and pull wireline free. Spool up on Schlumberger unit. Continue POH slowly w/tbg. 7/24/01 Finish POH. L/D corkscrewed tbg and jewelry. L/D bent pipe from derrick. Make dummy run w/tbg hanger. Not seating properly - send to shop for mods. Did this twice. M/U and RIH w/completion assy. 7/25/01 Finish RIH w/ completion assy. Attempt w/o success to set packer. POH w/ completion. 7/26/01 Finish POH w/completion. M/U scraper and mill and RIH to 10,418' - no tight spots. POH. P/U pkr, function test and RIH w/completion. 7/27/01 7/28/01 RIH w/completion assy. Attempt w/o success to set pkr. POH. Pkr set at 1,968' while POH. Release pkr and finish POH. Wait on replacement pkr. Wait on pkr. M/U pkr and RIH w/same on tubing. Set pkr and POH w/tbg. RIH w/ completion assy and tbg. 7/29/01 Finish RIH w/ completion assy. Tag pkr and space out. Land tbg hgr w/ 18K lbs tension on tbg. L/D excess tbg and drill pipe from derrick. N/D BOPE. N/U tree and test to 5,000 psi. Clean oil base mud from pits. Release rig at 22:00 hrs, 7/29/01. 7/31/01 MIRU slickline. RIH, tag fill at 10,197' w/2.35" gauge ring, P©H. RIH, tag fill at 10,651' w/2" dummy gun. RDMO. 8/2/01 MIRU wireline. M/U 1-11/16" pivot Gun #1 and RIH. Attempt to perforate - no go. POH, shot deployment mechanism damaged. RDMO. Shoot fluid level - 5540'. 8/5/01 8/7/01 MIRU wireline. M/U 1-11/16" pivot gun and RIH. Attempt to perforate - no go. POH, gun clogged with debris preventing charge deployment. Shoot fluid levels of 4,228' and 4,853' for AC)GCC inspector Lou Grimaldi. MIRU slickline. Tag fill at 10,625' with 2.00" gauge ring. Set plug in R-nipple at 10,297'. RDMO slickline. 8/8/01 MIRU rods and rod running equipment. N/D tree and rotate 90 deg. N/U master valve and rod BOPE. 8/9/01 Finish R/U rod running equip. Test BOPE. Repair and re-test BOPE. 8/10/01 8/11/01 Fill pits w/base oil. M/U pumping BHA and RIH on rods. Finish running rod pumping assembly. Space out, close BOPs on rods and secure well for installation of surface pumping unit. RDMO rod running equipment. UNOCAL APl# 50-133-20293-00 Orig. RKB = 17' WO RKB = 20.75' SIZE 20" 13-3/8" 9-5/8" Tubing 2-7/8" Actual Completior 68 47 53.5 6.4 NO. Depth Length 20.75' 5.96 A 42' 3,324' 6,981' B 10,157' C 10,199' G-Zone H1 -1 ~i2 -! H3 -! H4 PBTD = 11,138' TD = 17,689' MAX HOLE ANGLE = 2 deg. @ 6100' 1. 10,192' 2. 10,193' 3. 10,202' 4. 10,208' 5, 10,304' Swanson River Field Soldotna Creek Unit 'Well No. 33-33 As Run 7/29/01 Rods Ran 8/11/01 WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 6. 10,306' 7. 10,314' 8. 10,323' 9. 10,324' K-55 S-95 S-95 L-80 BTC SC 12.415 8.681 8.535 2.441 Surface Surface Surface 6295' 18' 90' 3880' 6295' 11,350' 10,400' JEWELRY DETAIL ID OD Item 36.43 3,282' 3,657' 3176' 42' 60' 2.15" 1.28 2.280 2.441 2.441 2.441 2,188 2.441 2.441 4.875 6.5 1.5 1.665 6.00 8.218 Seaboard International Tension Hanger installed CIW Bowl, 11" DCB x 2-%" 8rd Lift x Butt down. Polish Rod (spaced out 7' above stuffing box w/ pump 2.91' offbtm). 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25" R&M Stealth XL AF Rod Guides per rod 1-3/4" RXBC Dbl valve Pump w/Dual Seating Cups w/Stabilizer Bar. 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose Cup Type Seating Nipple, 2-7/8" 6' Pup Joint Ported Sub 3 Joints of 2-7/8" tbg Otis "R" Profile nipple, 2.188" w/Plug set 8/9/01 10' Pup Joint Ported Sub Baker "S-22" Anchor Latch Assy w/o seals, 190- 60 Baker Model "FB-I" Retainer pkr, 192-60, 9-Y8", 40-58.4# w/WLEG PERFORATION HISTORY Interval G-zone 10,478' 10,512' 34' H1 10,562' 10,588' 26' H2 10,610' 10,628' 18' H3 10,640' 10,649' 9' H4 10,651' 10,658' 7' H5 10,670' 10,712' 42' SCU 33-33 Current 7-29-01 DRAWN BY: sit REVISED: 3/16/01 FW: Swanson Workover Program Subject: FW: Swanson Workover Program Date: Thu, 3 May 2001 08:47:11 -0800 From: "Bill Penrose" <bill@fairweather.com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, For your information and records: This is the same e-mail I sent you .on 5/1/01 except that I've changed the discussion of BOPE to be used when running rods in the rod pump conversions. Please dispose of that previous message as the BOP discussion was grieviously in error. Thanks! Bill ---Original Message .... From: Bill Penrose [mailto:bill@fairweather. com] Sent: Tuesday, May 01, 2001 8:57 AM To: Tom Maunder (E-mail) Subject: RE: Swanson Workover Program Tom, Following each question that you posed is the answer, preceded with an A: One big question. What rig is proposed? A: H&R Rig #9, being imported from Canada. SRU 14-15... -What are the BHPs of the. old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. A: BHP of the old interval is 4,900 psi and will only flow water. The BHP of the new interval is 3,000 psi and is expected to flow gas. The request for testing the BOPs to only 3,000 psi as well as not installing an SSV is an artifact from one of the other programs. Please disregard it. It is our intention to test the BOPs to 5,000 psi. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? A: Yes, as stated above, the SSV request is an artifact. Please disregard it. -Do you plan to do a casing test in the pre rig work or prior to perfing? A: We will perform a casing test after plugging the presently perforated interval. -How the well will look after workover is not too difficult to imagine, but a drawing will help as ! move it up the line. A: i will generate proposal drawings ASAP and get them to you. -What gas rate is expected? Will 2-3/8" tubing limit the production? A: The gas rate is expected to be ~2MMSCFD which will not be limited by the 2-3/8" tubing. 1 of 4 513/01 10:05 AM FW: Swanson Workover Program -What zone/sand is the new completion in? A: The Tyonek 62-5 Sand SRU 234-15... -This plan is pretty straight forward. You have the BHP of the intended zone. Are there any others of concern? A: No, we'll just reperf the existing perforated intervals. -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? A: No tag run has been made since this interval was perforated. However, the well makes sand so there is probably some amount of fill. -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? A: No. The perforations are open and the producing pressure will be very iow. -Although you have larger tubing planned for this well, will it limit production? A: No. There will not be enough rate from this well to see the tubing as a limitation. SRU 14A-33... -As I indicate in my comments..,is there any intent or need to clean out the deeper intervals? A: No. We'll just acidize the existing perfs. -You are requesting not to have a SSV on a gas lifted completion. As noted above, will adding the G perfs make the well capable of flowing? A: No. The BHP in the G-Zone is 1600 psi and will not allow the well to flow, -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? A: There are 2 manual valves at the surface for shutting in the gas lift. While discussing this question, the field supervisor and I decided that we are uncomfortable with the possibility of a line leak occuring some time before somebody notices and turns off the gas lift gas supply. We therefore withdraw the request to eliminate the SSV. -What are the BHPs. A: Hemlock BHP = 1500 psi, G Zone BHP = 1600 psi ! would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. A: Photos and diagrams attached to this message. I can provide more technical data if you'd like. SCU 33A-8... How high will the tie back be? A: The casing leak is suspected to be at the port collar at 7,332'. The tie-back liner will extend up to cover it, making the tie-back ~2500' long. If the leak is found elsewhere, it will effect the length of the liner as the intent is to tie back from the existing TOL to just above the leak. 2 of 4 5/3/01 10:05 AM FW: Swanson Workover Program Will it be fully cemented? A: Yes. BOP and contingencies when using crane? A: We plan to use a 2-ram stack consisting of: Top: 2-7/8", t500 psi WP, 0 - 1-1/2", variable red rams Btm: 2-1/2", Model LP-15, 0 - 1-1/2", variable red rams Each well will use both rams while running the rods, with the bottom set being left on the well as a permanent part of the wellhead equipment (i.e., when it's ali done, each well will have an LP-15 BOP left on it and the top ram will be left over for future use in running and pulling .rods.). Is there any liklihood that the Hemlock could flow after reperfing? A: No, the BHP is only 1500 psi, not enough to lift the oil column. Need BHPs A: BHP = 1500 psi. Will tubing be anchored? A: Yes, see the attached gas anchor schematic. Will gas be produced out of a casing valve? A: Yes. SCU 33-33 Why base oil on this one? A: Base oil is being used because the G-Zone is very water-sensitive. Any plan to test the casing? A: No, the perforations are open and the producing pressure will be very Iow. SCU 13-34 BHP = 1500 psi. Please call or write with any additional questions or comments. Regards, Bill J 'i Name: 1100SIDE&FRTVIEWBELTOUT.jpg i ~_~, 1100SIDE&FRTVIEWBELTOUT. il3gi Type: JPEG Image (image/jpeg) i 1 Encoding: base64 Name: 1100SIDE&FRTVIEWBELTOUT.jpg Encoding:Type: JPEGbaseo41mage (image/jpeg) { Name: 1100SIDEVIEW.jpg i ~-~ 1100SI DEVi EW'jP'q t' Encoding:Type: JPEGbase64 Image (image/jpeg)i - 3 of 4 5/3/01 10:05 AM 33-33 80 6O 4O 20 0 1057 104- 103- 102 _ 104 _ 100- 10-! 1O00O 1000 · 100 - 10 0.1 0.01 Cum Gas Prod ( Cum Water Prod ;.;~:;:;.;:.~; :.:; ::::::::::::::::::::: :.~; :.;;~;:,;:;.:~;: ;~ ;;. ;:~:~;;~;.;:: ! Oil Rate (PD) ( bbl/d ) Gas Rate (PD) ( MMcf/d ) Water Rate (PD) ( bbl/d ) Gas / Oil Ratio ( Mcf/bbl ) Swanson Workover Program Subject: Swanson Workover Program Date: Wed, 25 Apr 2001 03:02:30 EDT From: STMaunder@aol.com To: bill@fairweather~com CC: tom_maunder@admin.state.ak.us Bill, Doing a little homework. Funny, the phone doesn't ring near as much here. But the new office doesn't have plumbing problems either. But I digress... I have some questions with regard to the programs. I'll start off with my cryptic diary notes and expand on them. One big question. What rig is proposed? C~;:x~~.~'~-~ ~ ~'-~. ~ SRU 14-15...(191-237),,.(301-106)...proposal is to clean out the well, abandon the existing perforations and recomplete...request to test BOP to 3000 psi and also not to have a SSV...say that the well won't flow...plan to recomplete as a gas well...might need proposed drawing -What are the BHPs of the old interval and the neW? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. ts the SSV request an artifact from another program? -Do you plan to do a casing test in the pre rig Work or prior to perfing? -How the well will look after workoVer is not too difficult to imagine, but a drawing will help as I move it up the line. -What gas rate is expected? Will 2-3/8" tubing limit the production? -What zone/sand is the new completion in? ~ ~o~- .~ SRU 234-15...(160-041)...(301,102).. proposaI is to clean out the well, reperf and gravel Pack the interval and run tubing...BHP stated at 2785 psi...request 3000 psi BOP test...need a new drawing...no mention of deleting SSV -This plan is pretty straight forward. You have the BHP of the intended zone. · Are there any others of concern? -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? -Although you have larger tubing planned for this well, will it limit production? SRU 14A-33...(162-017)...(301-103)...proposal is to cut tubing above top packer and clean out the well, not necessary or possible to clean out deeper...run tubing shallower, acidize the existing perfs and add G zone perfs...this is.an oil.well and presently will not flow unassisted...request is to not have a SSV...how do they propose to SI...will adding the G perfs make the well flow? 1 of 2 -As I indicate in my comments...is there any intent or need to clean out the deeper intervals? -YOu are requesting not to have a SSV on a gas lifted completion. As noted ~Wi;:III~SUII VVUI'I~UV~I I'~IU{~I~IlII above, will adding the G perfs make the well capable of flowing? -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? -What are the BHPs. The proposed rod pump wells have similar comments. I did talk with Steve Tyler regarding this proposal some time ago. I would appreciate some detailed information regarding the doWnhole equipment and the surface pumping unit. I have just copied my notes regarding these wells. I don't think they are too cryptic. If you need further clarification, please call SCU 33A-8...(172-017)...(301-103)...proposal is to clean out the well, repairing a 7-5/8" casing leak by runing a 5" tie back and equipping with a red pump...makes same request to omit SSV...probably more appropriate on this well type...how high will the tie back be?...will'it be fully cemented?...BOP and contingencies when using crane?...is there any liklihood that the. Hemlock could flow after reperfing?...need BHPs...will tubing be anchored?...will gas be produced out of a casing valve? SCU 33-33...(176-056)...(301-105)...somewhat similar to 33A-8, plan to clean the well out and complete with red pump...request relief on SSV as before...plan to use base oil for workover fluid...no reperf...why base oil on this one?...Hemlock and G zones already open in this well...any plan to test the casing? SCU 13-34...(unsure of permit number)...(301-104)...cleanout and equip with pump...plan to add G zone perfs...similar requests as before...plan to use 6% KCI for fluid Bill, thanks in advance for looking at these comments/questions. Please call to discuss. Tom 2 of 2 4/25/01 9:49 AM FW: Swanson Workover Program i [~ 900FOLDEDSHIPMENT.ip.q Name: 900FOLDEDSHIPMENT.jpgi Type: JPEG Image (image/jpeg) Encoding: base64 j ~ ~ Name: 900WEIGHTBOX.jpg ~ :i ~_~,~ 900VVEIGHTBOX. ii:).Cl i Type: JPEG Image (image/jpeg)! ~ i~ Encoding: base64 j Name: Swanson Gas Anchor.doc ! ~Swanson~ Gas Anchor. doci Type: WINWORD File (application/msword)I ~ ~ Encoding: base64 4 of 4 5/3/01 10:05 AM Swanson River "Poor Boy" Gas Anchor Gas breaking out of production I' Production Production IProduction ICasing I 2-7/8" Tubing IRods I IRXBC .Rod Pump I Seating Nipple, 2-7/8" Cup Type w/2.280" ID I2-7/8" Ported Sub [ I1.660" Dip Tube w/10 rd Box x ~ MS btm 3 jts of 2-7/8" Tail Pipe 2-7/8" Otis "R" type Profile Nipple w/plug, 2.188" ID I2-7/8" Ported Sub I LocSet Packer w/o Element JP~EG image 768x1024 pixels 1 of 2 5/3/01 10:09 AM Date: Wireline Company: Work Being Done: Present Operations: / Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: UN( " AL ALASKA RESOUr t, ES WELL SERVICE REPORT 8/7/2001 Tag fill, set plug Pollard Wireline Inc. Tag fill & set Plug Complete R. Grainger Swanson Unit Tubing Hanger 2.188" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: SCU 33-33 Swanson River AFE # 149641 D. Pollard/Smith 8 10641' 16.8' 2.18" Time Operation Details 12:00 Arrived at Swanson 12:10 Held safety meeting w/Supervisor 12:30 On stand-by awaiting Fluid Shot 13:00 Two Fluid Shots were made, 4826' & 4853' 13:20 '~. Tubing pressure at 250 PSI, bled Tubing down to Zero, to do No Flow Test for State 16:45 No Flow Test - satisfactory 17:00 Started R/U, pulled 50' of wire 18:30 Hydro to 1500 PSI - test satisfactory 19:00 RIH w/2.0" GR to 10625', POOH 20:20 RIH w/2.18 RR Plug on X-line R/T to 10297' WL, set Plug, POOH 21:30 OOH, R/D 22:30 i Depart Field Tool Cost: 12 hr min $1,830.00 2 7/8" X-line Running Tool $150.00 2.0" Gauge Ring $50.00 Work String Detail: (1/5" TS) RS, K J, 15' Stem, KJ, O J, SJ ,, Description of anyNone tools or debris left in the hole: Brief Summary of Made Tag Fill run & set RR Plug Total Work Comleted: ,,, Total Hours Worked 12 Total Tool Cost $ 200.00 Total Hour Cost $ 1,830.00 Ticket #:1 P-9730 Daily Cost:I $ 2,030.00 Day # :1 3 Cumulative Cost:I $ 3,110.00 Well Downtime Hr. H2S PPM Wire Test Approved by: Russell Grainger Code: AFE # 149641 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 Dan R. Williamson Drilling Manager UNOCAL ) Tuesday, April 17, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SCU 33-33 Workover, Swanson River Field, Alaska Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to repair Well SCU 33-33 and convert it to a rod pump completion. SCU 33-33 is a shut-in, Iow rate Hemlock and G-zone oil producer that has a wireline fish in the tubing. The proposed workover will consist of pulling the old completion and fish and re- competing with a rod pump completion. The Hemlock will be re-perforated before running rods. Because this well will not flow unassisted, Unocal requests approval to re-complete this well without a surface safety valve. For this same reason, we also request approval to test BOPE to a maximum of 3,000 psi. The anticipated commencement of this workover is approximately June 22. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258- 3446. Enclosures cc: Bill Penrose Sincerely, Dan Williamson Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL t. Type of Request: . [ ] Abandon [ ] Alter Casing [ ] Change Approved Program Name of Operator UNOCAL ALASKA RESOURCES Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 Location of well at surface ,/ 4' J 1400' FSL, 1700' FEL, Sec. 33, T8N, R9W, SM At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical [ ] Suspend [ ] Plugging [ ] Repair Well [X] Pull Tubing [ ] Operation Shutdown [ ] Re- Enter Suspended Well 5. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service 17,689 feet .,/ Plugs'(measured) 17,689 feet 11,138 feet Junk (measured) 11,138 feet ] Time Extension [ ] Perforate ] Variance [X] Other* ] Stimulate *Convert well to rod pump 6. Datum Elevation (DF or KB) 18' RKB 7. Unit or Property Name Soldotna Creek Unit 8. Well Number 33-33 9. Permit Number ~' 76-56 10. APl Number ~ 50-133-2029300 11. Field and Pool Swanson River: Hemlock 11,138' (top of cmt plug) Perfgun and wireline stuck at unknown depth in tubing Casing Length Size Cemented M D TVD Structural N/A Conductor 72' 20" Driven 90' 90' Surface 6,277' 13-3~8" 1,500 sx 6,295' 6,295' Intermediate N/A Production 11,332' 9-5/8" 3,500 sx in 2 stages 11,350' 1 t ,350' Liner N/A Perforation depth' measured: (10,562'-10,588'), (10,610'-10,628'), (10,640'-10,649'), (10,651'-10,658') and (10,670'-10,712') true vertical: (10,562'-10,588'), (10,610'-10,628'), (10,640'-10,649'), (10,651'-10,658') and (10,670'-10,712') Tubing (size, grade and measured depth) 2-7/8", L-80 at 10,420' Packers and SSSV (type and measured depth) 9-5/8" Hydraulic-set retrievable packer at 10,334' 13. Attachments [X] Description of Sumary Proposal ] Detailed Operations Program [ ] BOP Sketch 14. 15. 16. Estimated date for commencing operation 6/22/01 If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Bill Penrose, 258-3446 I here~'¥ify that,~e f~e~ng is true and correct to the best of my knowledge Cor~missi°n U~/~ Only Status of well classification as: [X] Oil [ ] Gas [ ] Suspended Service Prepared By Name/Number: Bill Penrose, 258-3446 17. Conditions of Approval: Notify Commission so representative may.w~tness ~~,~ Plug integrity ~ BOP Test ~ .~,._ Locat~n Clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 Commissioner iii Date /-~"'/¢ ~' O IApproval No. Date/~~~/ S~b~t ~h/rrip~cate Unocal Ataska l~us~ess Unit Swanson Ig~ver Field Well #SCU 33-33 AFE # Prepared by: WJP Date: Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) No. Preliminary Procedure ' Time CUM cum Estimate Time Time (rIours) (~ours) (Days) Prep Well For Workover Test Wellhead Use Slickline to Pull Valve From Deepest Possible GLM Circulate Clean Base Oil Down Tbg, Out Annulus · Workover MIRU Workover Rig ~.~. 72 72 3.0' Set BPV, N/D Tree, N/U BOPE and Test 15 87 3.6 M/U Landing Joint, Pull pkr Loose, Pull Hgr to Floor, Circulate Well 4 91 3.8 POH and L/D Tbg and Jewelry (10,420') 15 106 4.4 P/U and RIH w/New 2-7/8" Completion to 10,400 24 130 5.4 Set BPV, N/D BOPI~, N/U Tree, Test Tree 12 142 5.9 RDMO Workover Rig 0 142 5.9 'Post-Rig Work . . Run Rod Pump and ROds Using 50-Ton ~rane Subtotal (Days) Loss/Trble Time (11%) Total Project Days 5.92 0.65 6.57 Note: Loss, Trouble, Unplanned is based on 11%. Also, the risked troubled costs were included in the AFE costs. SCU 33-33 AFE Est Page 1 of 1 4/5/01 UHOCAL ) I I I Original KB is 18' to P.D. PBTD = 11,138' TD =17,689' Hole Angle = Max. of 2 degrees at 6,100' Sr~E WT 20" 13 3/8" 68 9 5/8" 47 9 5/8" 53.5 $.rZEWT 2 718" 6,4 .NO, D,~,~th 1. 20.75' · . 2. 1750' 3. 3193' 4. 435~ 6. 5258' 6. .S7~ 7. 630~ 8. 6794' 9. 728T 10. 7810' 11. 8312' 12. 88O8' 13. 9303' 14. 9798' 15. 10~02' 16. 10,334' 17. 10,386' 18. 10,420' TOP 10,562 10,610 10.640 10,651 , -... 10,670 Swm ~ .... -'iver Field Well e S~.., 33-33 Completion, As Run 6/12/97 CASING AND LINER DETAIL GRADE CQNN TOP BOTTOM Surf 90' K-65 Surf 3880' S-95 Surf 6295' S-95 6295' 11,350' TUBING DETAIL GRADE COHN TOP. BOTTOM L-80 BTC SCC Surf 10,420' JEWELRY DETAIL cIW 2 7/8" DCB tbg hgr, · P_5" CIW BPV profile Macro 2 7/8' (;IMM Macro 2 7/8"'GLM Macro 2 7/8" GLM Macro 2 718" GLM Macro 2 7/8" GLM Macro 2 7/8" GLM Macro 2 7/8" GLM Macro 2 7/8" QLM Macro 2 7/8" GLM Macro 2 7/8" GMM Macro 2 7/8" GLM Macro 2 7/8" GILM Macro 2 7/8" GLM Macro 2 7/8" GLM Hydraulic retrievable packer X nipple Mule shoe re-enW guide · ,PERFORATION DATA r~TM 7;ONE SPF 10.588 Hem 3 10,628 Hem 3 10,649 Hem 3 10,658 Hem 3 10,712 ' Hem 3 REVISED: 6/12/97 DRAWN BY: KDW '~ ...... STATE OF ALASKA ~- ALASKA O,._ AND GAS CONSERVATION COI,.._41SSION ¥' ~. WiLL COMI}LI=TIO# OR RI=COMIILI=TION RI= OItT _liND LOG "- 1. Status of Well Classification of Service Well OIL [X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 76-0056 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5o-133-20293 4. Location of well at surface 9. Unit or Lease Name 1404' N & 1701' W of SE Corner Section 33, TSN, R9W, SB&M Soldotna Creek Unit At Top Producing Interval 10. Well Number same SCL 33-33 At Total Depth 11. Field and Pool same [5. Elevation in feet (indicate KB, DF, etc.) i 0. Lease Designation and Serial No. Swanson River - Hemlock G.L. = 125' K.B. = 153'] A-028990 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 1t3. No. of Completions 7-23-76 12-9-76 2-23-86 NA feet MSL 1 .... 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 17,689' 11,138' YESI~ NO []I NA feet MD NA 22. Type Electric or Other Logs Run OR/Neutron/CCL, Carbon/Oxygen 23. CASING, LINER AND CEMENTING RECORD S!ETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED , · 20" 90' DRIVEN I~-~/R" 6g K-55 30' 3,380 17-1/2 1500 SKS"G" 9-5/8" 53~5- 47 S-95 29' 11,350' 12-1/4 1st Stage 1300 SKS"G" ' ' 2nd State 2200 SKS "O'I DV ~ 8,027' 24. Perforations open to Production (MD+TVD of Top and Bottom and ' 25. TUBING RECORD · . · interval, size and number) ~ SIZE DEPTH SET (MD) PACKER SET (MD) 10,712' - 10,670' 42' 168 1/2" 2-7/8" 10~520' 10,444' 10,645 - 10,640' 5' 20 lt~ '20. Nz~ AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10.,628'. - 10,610'~ -· 18, 72 1/-2" -- , . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10,588' - 10,562' 26' 104 1/2" 27. ' PRoDuCTION TEST Date First,Product on· - ;' I Method of Operation (Flowing, gas lifL etc ) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE sIZE I GAS-oIL RATIO 2-20-86 8 . TEST PERIOD ,1~ NA. NA NA 8/64" I Flow T.i~iIP4~g' ,. ~Casing Pr. essure CALCULATED OIL~BBL GAS-MCF .. WATER-BBL OIL GRAVITY-APl (cor'r) Press,5~SI. ,,- ;,.O 24,HOUR.RATE I~ : NA .NA NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips ~nd presence of oil, gas or water. Submit core chips. . NA · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., ' ' GEOLOGIC MARKERS FoRMATIoN TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR~ and time of each phase. NA NA I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge // Area Operations Superintendent Signed__ ~/'~//~-- Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL]~ OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 76-0056 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 1404' N ~ 1701' W of SE Corner Section 33, T8N, R9W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) O.D. = 125' K.B. = 153' Lease Designation and Serial No. A-028990 12. 8. APl Number 5o- 133-20293 Unit or Lease Name Soldotna Creek Unit 10. Well Number scu 33-33 1 1. Fi;~d'ana ~'0~ ..... Swanson River - Hemlock 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 [] 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). See Attached RECEIVED APRO? 19 6 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that t~e foregoing is true and correct to the best of my knowledge. Signed ............. Title Superintendent The sBace below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WORKOVER COMPLETION REPORT SWANSON RIVER FIELD, ALASKA Soldotna Creek Unit Surface Location: Drilling Rig: Rig Acceptance: Rig Released: Elevation: Total Depth = 17,689 Well: Scu 33-33 Lease No.: A-028990 1404' N & 1701' W of SE Corner S33, T8N, R9W, SB&M Brinkerhoff Signal Inc. #16 February 12, 1986 February 23, 1986 G.L. = 125' K.B. = 153' Plug Back Total Depth = 11,138' Casing: Perforations: Logs Run: 20" Conductor Driven at 90' 13-3/8" Surface Cemented at 3380' 9-5/8" Cemented at 11,350' (Reperforate 4-1/2" JSPF) (Perforate 4-1/2" JSPF) Dresser Atlas GR/NEUTRON/CCL Carbon/Oxygen 10,562' 10,610' 10,640 10,651 10,670' 10,800' 10,750' - 10,588' - 10,628 - 10,645 - 10,658 - 10,712 - 10,350' - 10,380' Mi I<. Rauser Senior &rea Engineer 2-12-86 2-13-86 2-14-86 2-15-86 2-16-86 2-17-86 2-18-86 33-33 First Report TD -- 17,689' PBTD -- 10,655' 9-5/8" csg ~ 11,350', 9.5 PPG BW, Located 1,404' N & 1,701' W of SE Corner of Section 33, TSN, R9W, SB&M, G.L. - 125' K.B. - 153': MI & RU BSI//16 from SCU 43A- 8, Accepted rig ~ 9:00 p.m. 2-12-86, Mix 9.5 PPG BW. TD = 17,689' PBTD = 10,655' 9-5/8" csg ~ 11,350', 9.5 PPG BW, Retrieve BPV, Test lines to 3,500 PSI, Circ 9.5 PPG in and out-well flowing, Killed well with 9.8 PPG BW and circ through choke, Installed Cameron BPV, N/D tree & N/U 5000 PSI BOPE. TD = 17,689' PBTD = 10,655' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Fin N/U BOPE, Test BOPE to 5,000 PSI, Test annular to 3,500 PSI, Removed Cameron BPV, Backed out lock-down screws in tbg head, Unseated hanger & 9-5/8" Baker "FH" pkrs w/max overpull of 20,000~, Circ bottoms up w/no flow, POH & lay dn 3,600' of 3-1/2" tbg w/gas bubbles migrating up hole- no flow, Circ ~ 7,050'-bubbles cont w/no flow, Cont lay dn 3-1/2" tbg. TD = 17,689' PBTD = 10,655' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Fin lay dn 334 its 3-1/2" tbg & equip w/TOF ~ 10,602', PU & TIH w/7-5/8" guide & overshot w/4-1/2" grapples bumper sub jars accelerator sub pump out sub 4-3/4" DC's & 3-1/2" DP to 10,578', Circ bottom up. TD = 17,689' PBTD = 10,655' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Circ, Workover TOF ~ 10,605', Work fish free w/80,000# overpull, POH w/fishing tools slowly due to swabbing, Lay dn fish-rcvd remaining production equip & left a 5" OD ring from "FH" pkr in hole, PU & TIH w/8-1/2" FB mill to 10,658' - slip & cut drlg line, Cleaned out F/10,658' to 10,666' mill on junk ~ 10,666'. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Cont milling junk F/10,666' to 10,667', Washed F/10,667' to 10,708', Rotated F/10,708' to 10,748', Washed down F/10,748' to 10,900', Circ & sweep hole clean w/Hi-Vis pill, TIH w/DP to 11,138' PBTD, POH, PU & TIH w/Baker 9-5/8" retrievable pkr & set pkr ~ 10,500', Tested 9-5/8" csg to 2,500 PSI, TIH to 10,700' &circ, POH. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Fin POH w/Baker retrievable pkr, R/U Dresser Atlas & tested lubricator to 1,000 PSI- OK, Ran GR/Neutron/CCL logs F/10,800' to 10,350' & Carbon-Oxygen log F/10,750' to 10,380', P/U & TIH w/8-1/2" bit & csg soaper to ll,138'-eut & slip drlg line, Pumped Hi-Vis sweeps, Circ, POH. 33-33 2-19-86 2-20-86 2-21-8'6 2-22-86 2-23-86 2-28-86 TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Fin POH w/8-1/2" bit, PU & TIH w/tbg conveyed guns, Ran GR/CCL and space out, Arm guns, POH w/logging tools, Load DP w/diesel, set Baker pkr ~ 10,450', Test pkr to 1,000 PSI, R/U test head & manifold, Attempted to test - head & swab valve was leaking, Changed swab valve. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Drop bar & perforate 4-1/2" JHPF w/4" guns 10,5'62' - 10,588', 10,610' - 10,628', 10,640'- 10,645', 10,651'- 10,665' & 10,670' - 10,712', Left well open to tank setting and well died - max surface press 50 PSI on 8/64" choke, Pick up on tbg & open pkr bypass, Reverse circ 1-1/2 DP vol & flush out flow line - DP gasing, Pump dn DP & circ well dead, POH al! shots fired, TIH w/8-1/2" bit. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Fin TIH w/8-1/2" bit to PBTD ~ 11,138', Pumped Hi-Vis sweeps, POH & ].ay dn DP & DC, Installed 2-7/8" tbg rams & test Class III BOPE to 5,000 PSI & annular to 3,500 PSI, RU hydrotest & prep to run production tbg. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', 9.8 PPG BW, Ran 328 JTS 2-7/8" 6.4# N-80 BTC SCC production tbg & landed ~ 10,520' w/Baker "FH" hydraulic pkr ~ 10,444', Install back pressure valve and land tubing, Tested tubing in hole to 5,000 PSI, ND BOPE & NU tree & tested to 5,000 PSI. TD = 17,689' PBTD = 11,138' 9-5/8" csg ~ 11,350', Lease Crude, Removed back pressure valve, Displace w/lease crude, Set Baker "FH" pkr ~ 10,444', Shear ball from shear, sub, Test pkr & annulus to 1,500 PSI for 30 min, Install back press valve, Clean pits, RELEASED RIG..~.. 6:00 PM 2-23-86 FINAL REPORT. -- . ~ Returned well to production on 48/64" choke. Initial production 331/4/2888 (O/W/G). STATE OF ALASKA ALASKA O~LL AND GAS CONSERVATION CO~_MISSION SUNDRY ?TICES AND REPORT , .tN WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 1701'W & 1404'N of SE Corner Section 33, T8N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 125' K.B. = 15Y 6. Lease Designation and Serial No. A-028990 7. Permit No. 76-0056 8. APl Number 5o-133-20293 9. Unit or Lease Name Soldotna Creek llnit 10. Well Number SCU 33-33 11. Field and Pool Swanson River- Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) 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.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). . 10. II. 12. 13. 14. 1. Move in and rig up workover rig. 2. Nipple up and test rams, manifold, and valves to 250 PSI and 5000 PSI. Test annular to 250 PSI and 3500 PSI. 3. Kill the well with 9.5 PPG fluid. 4. Pull the tubing and production equipment. 5. Trip in the hole with an 8½" bit, and clean out to 10,900' +/-. 6. Trip in the hole with a retrievable packer and test the casing to 2500 PSI above 10,500'. Locate leaks. A squeeze procedure will follow to repair leaks if there are any. 7. After all squeezes and clean out runs are made, run GR-Neutron and Carbon/Oxygen logs. 8. Run tubing conveyed guns on drill pipe and reperforate as directed with 4 - ½" JSPF. Flow the well until it has cleaned up. Kill the well. Pull out of the hole with guns. Lay down the drill pipe. Run the production equipment on 2-7/8" tubing. Space out and land the tubing. Nipple down the BOPE. Nipple up and test the tree to 5000 PSI. Hydraulically set the packer. Test the packer/annulus to 1500 PSI for 30 minutes. Release the rig and move off. 14. I hereby Jtify that the foregoing is true and correct to the best of my knowledge. Signed_ ~ Title Area Operations Superint&~:~Date The spare b~10w for Commission use Condit~of Approval, if any: Approved by A~proved Cchoy Returrted ~ COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Chevron Chevron U.SA Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area Operations Superintendent Production Department November 26, 1985 Well SCO 32-33 WD Swanson River Field~ Alaska U.S. Environmental Protection Agency Region 10 Attn: Mail Stop 409 1200 Sixth Avenue Seattle, Washington 98101 Dear Sirs: Please find attached a copy of the pressure chart used during the pressure test of the tubing-casing annulus on the subject well. This well was worked over on October 25-27, 1985, to repair a leak in the packer. The well was pressure tested at that time, however, no chart was run. Recently the surface work for this well was completed, so the well is now ready to resume injection. To satisfy the permit conditions, a pressure test on the tubing-casing annulus was performed on November 22, 1985. The casing successfully held 1000 psi for 30 minutes. Please advise us of your approval of this test as soon as possible so we can return the well to injection. If there are any questions, please contact Ms. C.D. Creed or Mr. J.B. Logan at (907)786-6600. JBL:mw Attachment Very _truly yours, Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. .Anchorage, AK 99501 RECEIVED o ]985 Alaska DEPARTMENT OF NATI~RAL RESOI~RCES MINERALS AND ENERGY MANAGEMENT June 3, 1982 C.V. Chatterton Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage,-Alaska. 99501 JAY S. HAMMOND, GO VERN~ 555 CORDOVA STREET ,ouc, 7-005 ANCHORAGE, ALASKA 995 (907) 276-2653 ' Refernce: Release of Confidential Well Records Dear Chat: The following wells were granted extended confidentiality by the Commissioner of Natural Resources pending the offering of adjacent unleased acreage for competitive leasing'. Operator Well Union Oil Co. Chevron U.S.A. Chevron U.S.A. Chevron U.S.A. Clam Gulch Unit No. 1 Well Pretty Creek Unit No. 2 Well Stump Lake Unit No. 41-23 Well Soldotna C-reek Unit No. 33-33 Well The data from these wells no longer qualifies for extended confidentiality. Therefore, these data should be released to the public at your earliest convenience. Please call if you have any questions. Sincerely, D~Yr~~or, DMEM cc: Bill Van Dyke .. MINERALS AND £A/ERG Y MA/VAGEMEtVT April 26, 1982 Mr. J. J. Anders Chevron U.S.A., Inc. P.O. Box 7643 San Francisco, CA 94120 JAY S. HAMMOND, GO 555 CORDOVA STREET POUCH 7-005 ANCHORAGE, ALASKA 9951~" (907) 276-2653 Reference' Pretty Creek Unit No. 2 Well Stump Lake.~uaiL,,Wa .......... ...... S51'8'ot,'~' creek Unit No. 33-33 Dear Mr. Anders: The Division of Minerals and Energy Management recently completed a review of all wells which have baen granted extended confidentiality in accordance with 'the provisions of AS 31.05.035(c). Our records indicate that the Pretty Creek and Stump Lake wells were granted extended confidentiality penOing the offering of adjacent unleased acreage For competitive leasing in Sales No. 33 and No. ~2. Those sales ~ere conducteo on May 13, 1981 and August 25, 1981, respectively; as a result, we believe the wells no longer qualify for extended confidentiality. The Soldotna Creek well was granted extended confidentiality pending the offering of unleaded acreage in the Federal OCS Sale 60 in Cook Inlet. A reasonable amount of time has lapsed since that sale was held; as a result, we believe this well no longer qualifies for extended confidentiality. Accordingly, it is my inten'~ion to request that the Alaska Oil .and Gas Conservation Commission make public Oata ~rom these wells on May 31, 1982. Should You have any questions regarding this decision, or if you feel that there are extenuating circumstances which should be considered prior to the release of these data, please contact me prior to May 31. Sincerely, 4 ~. ~<ay Brown Director . E[EiVED cc' John Katz, Commissioner, DNR C. V. Chatterton, Chairman, AOGCC AL:sI:a (oil & Gas Cuns. Coiml]issi~ll-'~ /vl£ho~'ag~ Chevron Chevron U.S.A Inc. 5'75 Market Street, ',gan F~ancisco, CA 94105 Mail Address: P..O. Box 3852, San Francisco, CA 94119 Exploration Departmen! Western Region To: Date: Attention: ? rol?i: Standard Oil Company of California Western Operations, Inc. Exploration Department P. O. Box 3862 San Francisco, California 94119 Attention: the 'following: Please sign and return duplicate copy of this meTnorandum. Date STATE of ALASKA Staff FROM: Alaska Oil & Gas Conservation Commission Febr~uary 2, 1979 DATE: · FILE NO: John A. Levorsen Petroleum. Geologist TELEPHONE NO: SUBJECT: Extended Confidentiality Commissioner LeResch of DNR has extended the confidential period of another well, Soldotna Creek Unit #33-33, at least for 30 days after regulations implementing AS 31.05.035C as amended by HB 815 at the las! session, become final. The following wells now have indefinitely extended confidential status. FORMER WELL NAME RELEASE DATE OPERATOR & NUMBER API NUMBER 08/25/78 ARCO 03/16/79 Chevron U.S.A. 05/06/79 Union 0il Co. JAL:emi West 'Beach St. #3 50-029-20208 East Harrison Bay St ltl 50-250-20001 January 24, 1979 Mr. J. J. Anders Manager, Alaska Division Land - Western Region Chevron U.S.A., Inc. P. O. Box 7643 San Francisco, California 94120 Dear Mr. Anders: I am writing in reply to your letter of January 4, 1979, to me concerning~Soldotna .C..reek .Unit Well $ 33-33 and Stump Lake Unit Well $41-33. I have considered ~he points raised by you in that letter with respect to Soldotna Creek Unit Well $33-33 and believe it was not the intent of the Legislature to require the data from wells such as this one to be-held confidential beyond the 25-month period. However, to afford you any benefit of the doubt on this matter, I have decided to direct that the data from this well be held confidential until such time as ~%e Department issues final regulations for AS 31.05.035c as amended by HB 815. As soon as such regulations become final I will expect that you file an application for confidentiality under those regulations and at that time I will again consider the matter of whether the data from Soldotna Creek Unit Well #33-33 should be held confidential. In the event you do not file an application within 30 days after the regulations become final I will direct that the information be released. Sincere ly, Robert E. LeResche Commi s s loner cc: Tom Cook Jeff Lowenfels REL: FHB: cb December 5, 1978 Mr. J. J. Anders Manager Alaska Division Land - Western Region Chevron U.S.A. Inc. 575 Market Street San Francisco, California 94105 Dear Mr. Anders: I ga writing in reply to your letter of October 16, 1978, in which you request that I authorize holding data confidential under AS 31.05.035(c) as amended by HB 815. I hereby deny your request for S_oldotna Creek Unit Well 33-33J This wei1 is located in th~middle~0f a fu'ily explored unit and is quite some distance from the nearest unleased state lands.. I believe to authorize indefinite confidentiality for tA~at well would certainly be an abuse of the confidentiality provision contained in ~B 815. Stump Lake Unit well ~41-33 poses a more difficult problem. However, I have determined to deny your request at this time. I have directed the Division of Minerals and Energy Management to begin preparation of regulations to clarify and J/uplement this provision of }~ 815. After those regu- lations are completed, you may wish to again file a request for confidentiality of the Stump Lake Unit well. I would then consider your request in the light of those regulations. I do not believe this should pose any problems for you as the existing confidentiality on the Stump Lake well does not e4cpire until June 13, 1980. . . · Sincerely,' ,--'*' / / ;//' . / t : Robert E. L-~Resche Commissioner bcc: Tom Cook I{oyle }[amilton REL: FHB: bll L'hevron ..... ' ~ el- .VRON U.S.A. IN . TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) 'r'0: FL,ACS:. ATT. TtIE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. RECEIVED BY / REMARKS ON OTHER SIDE, TNlq .c-,I~F~T STATE OF CHEVRON U.S.A. lNG, TRANSMITTAL AN ~CKNOWLEDGEMENT OF RECEIPT OF b ~RIAL - (ALASKA) OIL t: ,"'... AItCtJOR ACE, ALASKA 99504 ATT'II:'_ "'"- · . THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. · -/ RECEIVED · /R£~ARKS OLOTHER SIDE, THIS SH~T ,i ,l~ / .~) · Chevron CHEVRON U.S.A. INC. TRANSMITTAL Ak ACKNOWLEDGEMENT OF RECEIPT OF ~ .... 'ERIAL - (ALASKA) .. THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMlv[EDIATELY. OiR. PRO lO- 10- . LOG CO~ANY WELL ," '-, IHISTORY SUR, 3i2. 401' 403' P-i' P-'4 'P'7 INDEX · , , ,, , , ,, ....... _ ...... , ,. ~,, , , t, ~ ~ , , , ' · - ., .'.." , ... ........ ..... .... ................ ~.~ .- . , II I I I[ '1 r, - . , ~. ,-,-to .. - st,,~lf m [,,,~,lc*~' "J0'40~ OIL AND GAS CONSERVA1 ION . OIL AND GAS CONS[RVPItON COT&lifTER STALE OF ALASKA js.,.on,.,}..,...,~ .., ,, , , OI[ AN~ 6AS CONSERVATION ~OMMIfll[ " ...... ~" &~OI,ITHI. Y REPORT OF DRILI. ING P'7...... SUNDRY NOTICES AND REPORTS ON WELLS " ~'~ ~.:~D ~YORKOVER OPfRATION5 WELl_ CONi['i.KI'I(bN OR RECOMPI.[TION R~PORf AF4D t.O,3' Wo ,o, ,,, ,.,, :~,.- ,o, ,,,*e ..... ,,,o ........ ~J OIL ANT; GAS CONSI.'RVATION COMMtlIEE OIL AND OlZ¢ CONSEIIVAI'ION COMMR%EE j ./P[.ICATION FOk Pi3'MIT T('3 DRH.L. DLFP[{N OR ?LUG PACK PI~llMIF 'JCl DRILL O}{ I)t:EI'EN / / REMARKS ON OTHER SIDE, THIS' SHE'ET BY C}m~VRON U.S.A. /NC. BOX 7~39 ~6E, At~'~CA 99,510 -":'la. TYP~L~OF WELL: b. TYPE OF COMPLETION: NEW ~ WORK %%' b: [, L~ OVER [ _ SUBMIT IN DU A' ' ~' ~ ~ nor Ill- . STATE OF ALASKA ,,,,..~,..,..., reverse side! OIL AND GAS CONSERVATION COMMITTEE · · i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* '-'"" [] """" © W ELL W ELL DR ¥ Other CHEVRON U. S. A. 3. ADDRES~ OF OPERATOR P. O. BOX 7-839 BACK g ES%'R. Other ANCHORAGE, ALASKA 99510 4. I'.OCA~ION 0;F WELL (Report location clearly and in accordance with a~y State requirements)* Atsurfaee I,~[F00' N Al700' W from S.E. car. of Sec. 33; T-8N, R-9W~ S.B. & M At top prod. interval reported below 84' North and 27' West of surface At tota! depth location. Not determined. 5. APl NU~2{/CAL CODE I15. DATE COM~P SUSP O1% ABAND. 2/14/77 g~U qq-q3 10. FLED AND POOL, OR WILDCAT SWAM-qON I~_T ~/l~ R 11, SEC., T., It., 5I. (}3OTTONI HOl_Jg O}3JECTIVE; SEC. 33; T-8N, R-9W S,B, & M 12. PEI~IIT NO. 76-56 v.J_,EVAT/ONS tDF, ]{KD, R.T, GR, ~TC)* ]17. ELEV. CASINGiiE/kD 153 ' K.B · , ~ ' CAa,,Z TOO,..s 1~. DATE SPUDDED [14. DA~E T.D. REACHED 'i 7/23/76 12/9/76 li~. TOTAL D£P'fH, irED & TVD~9- PLUG, B&C'K MD & WD~. ~ ~vtb-L'rwLS CO~L.. I 21. / / ~ow ~NY* 1 ROTARY TOOLS ] No 17689'~ 17684'TVD 10665'~D 10664'TVD[ 0 - 176~9 ~. PRODUCING !N~RVAL(S, OF THIS COMP~TION--TOP, BOSOM, N~IE (~ AND Top 10562' ~ 10561' T~ ~OCK ] Yes ~ttom 10658'~ 10657'TVD 24- TxI'PE ELECTi:tC AND oTHER LOGS RUN DIL, SONIC FDC/CNL, dipmeter CBL, GRL, V.elocity Survey. CASING REC(~I~D (Report all strings set m LINEX E~COt~ 27. TUBING SCi~E~ t55D; SIZE DEPTH SET (51D~ { PACI~Ei( SET (MD) , 29, ACID. Si:CT. i;-;{~%C% URE, C~,i~-~T SQUL~Z~, ETC. D~IIi IN~iV>_L {5ID) I AMOUNt >~D }i!ND OF AI.%IE~AL US~ [ o c¢iV'FD I '" - - 2/13/77 } ~owipq . ' :' ....... / ,,~i o~ ~sr. Inuu~s ~ zs'r~ 'lcnoxz i~zz lm:ov'N ?)_ o~zz. ~.~x~c~. w,-,,rmt-nuz. [ ~;.s-om ~:~.~o I 2Z!~7 7 (COXR.) F =,-=, ' I I , ~40 . Ir - - 31. DISPOSITION OF GA8 ( ~old, ~$ed ]or f~e[, t'~n/t'd, 6lC.) Izzs.r W l Inflected_back into field ~. I.I$T OF i,i [ TOP (AID} HOWl'OM (MD) SACK CEMENT* SlZE 9s. PEIif~)RATtONS OPWN TO PRODU~ON (interval, size and number) 10562 - 10588' 10610 - 10628' Three 1/2" holes per foot. 10640 - 10645' 10651 - 10658' r[~llh '~ 11('1 33.1 hereby certify that t~e foregoing and attached/h,(-rmatic, n is complete and correct aa determined f. rum all ava in, me ri.tufas .... i ~: ~ul i1~1 ~11 i .... *(~e Instructions Side) iNSTRU(~Y|ON$ . · General: This form is designed for submitting a complete and correct well completion report and log on ali types of landis and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in other spaces on this form and in any attachrnents. Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 27 show the ptc. Juci~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each'additional inteJval to be seperat.ely produced, show- ing the ac~ditional.data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. - Item 28: Submit a separate complelion'report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SIJ'MMAH.¥ OF I~OI~MATI'C)N T~S~;'S INt'LUDIN(; l~gkL 'T~'rE~"'. I;~SU~E ~A~ ~ ~COVER~ OF ~I~'.' GAS.- .......... WAT~ AND MUD . ......... NA~ .' - SEE ATTACHED - , , s~s~s. 6~t ~u~ ~m,,. 6~, . ,. . , , AN~' [)E'I~C~I) SIlOWS OF OIL. G~.OH %VA~ll ' .. i i i i i I I i _ I i ....... ,.. ........ ............ CORE NO. INTERVAL II789-II819 I2593-I263I I389I-I3936 I3936-I397I I5037-I5075 I5750-I5,806 I7 , 629-I7 , 689 CORE DESCRIPTIONS' SOCAL SCU 33-33 CUT 30' 38' 45¸l 35' 38' 56' 60' REC. 29' 38 ~' 45' 34.5' 38' 56' 52.75' DESCRIP. gry to grn gry v fn slty ss grading to sltst near bott.. slickensided section at II808 w/tr oil stain mudst dk gr¥ frm-hd slty w/IO% ss-lamfn &pods fn-med v hd weld'd in pt recry- stalized 44I/2'clyst-dk gry -hd slty lam w/it bl gry sltst bott. 6" ss-med gry fn scat'd med sa sft fri arg biot sltst grdnB locally to clyst dk-med gry w/scatterd pods ss vfn hd ttte w/biot books dk gry v hd brittle no cut clyst/Sh slty w/thin lamins vfr ss,calcite frac fill &prob fish remains pyroclas sed rocks: it gry grn red, v p srt'd, hd, carb, cgl -ss, sil sltst; clyst. predom pyroclastic at top becoming predom volc trap rock (basalt-andesite) at base Compiled from mud log by F.L.Jones, I0/29/82 SUMMARY OF FORMATION TESTS'~ Test No. 1 F. T. of Perfs. 10702 - 10712'. Open 9 hrs. 10 min. Rec 12 bbl. rise of 71 pcf mud in 3-1/2" tubing. Took 12 hrs. 20 min. Final shut-in. Pressure Data Initial Hydrostatic Final Flow Final Shut-in Final Hydrostatic- 5467psi 809psi 4556psi 5452psi Test No. 2 F. T. of Perf. 10680 - 10712'. Open 15 hrs. 25 min. Fluid to sfc. in 13 min. 'Oil to sfc. in 2 hrs. 10 min. Flowed at 43 B/D oil, 0 B/D water, 12597 mcf/D gas rate for balance of test. Pressure Data Initial Hydrostatic Initial Flow Final Shut-in Final Hydrostatic 5034psi 2823psi 4451psi 5067psi Test No. 3 F. T. of Perf. 10562 - 10588'. Open 8 hrs. 18 min. Flowed at 1418 B/D oil, 0 B/D water, 4307 mcf/D gas. Pressure Data Initial Hydrostatic Final Flow Final Shut-in Final Hydrostatic 5159psi 3795psi 4673psi 5098psi RECEIVED ELEV. 187' K.B. 62'95' I IU__ -- l[ I, Il K.B. TO TU/BI HANI;ER' PUP JTS.;51~' EUE BUTT. N-8OTBG. 64 JTS. 3.v~'' EUE BUTTRESS N-80 TBG. · 1'977'001- ' CAMCO MMG 'MANDREL 3,7 JTS. SYz' EUE 3,.090.46 CAMcO MMG MANDREL 2:9 JTS. $½' EUE 3'986'25L-~" ' CAMCO MM.G MANDREL 1 :)3' -JTS. SY~'EUE 4,759,86---~ CA?CO MMG MANDREL . I / · 19 'JTS. 5,'z' EUE 5,:541.1l..'? CAMC° MMG MANDREL 16 JTS. 3Y~'EUE . I 5,822.99-'-~ CAMCO MMt; MANDREL 13 JTS. 3.Yz" EUE 6,ZZ I .29L ~ CAMCO MUG MANDREL I! JTS. 3½"EUE 6,571.21 '-- ~ CAMCO MMG MANDREL I$0 JTS. SYz"EUE' BOTTRESS N-80'TBG. BUTTRESS 'N-80 TBG. BUTTRESS N-80 TBG. BUTTRESS . N- 80 TBG. BUTTRESS N.80 TBG. BUTTRESS N-80 TBG. BUTTRESS N-80 TBG. BUTTRESS N,.80 TBG. I0,543.23'-'- - ' !0,547.23'.'~ OTIS "XA" SLEEVE t'~ssz' 10,555,37:--~ 3~'~ 9~" BAKER FH PACK'ER OTIS T NIPPLE, Position ' / 2 BAKER 3Yz~ BLAST JTS. (20.20'-9.88 I0, 588.19' ,osae'! ..... .~ BROWN CC SAFETY JT. --10,593.95.:-"~ OTIS 'XA"SLEEVE ' -- !0,602.10'--<~ 5Yz~,< 9~"BAKER FH PACKER ~o61o.- - 4" OTIS T NIPPLE, Position*2 m 10,624.Z4'--.-~/ ' BAKER BLAST JT. ''. ,~Tz~.!0,626.03~__~ BROWN CC SAFETY JT." ' -- i0,630,00'---~ O~IS "XA" SLEEVE .. ~_~_6, o, 10,6:38.15,._._./.~. ~'*x 9~s"BAKER FH PACKER OTIS "Q."NIPPLE i 1064S .,oGsr BAKER BLAST JT. -- 10,649.30' SHEAR SUB 1065e' TOP PLUG 10,655' 10680' REPERF'O. lO/It' ') T. D. 17.689' 2 L. 44 i7,o8: 1959.9Z'~ 8.73' I I 0z~.73'~ 8.73" 887.56'~. 8.68: 764.43' 8°63 $72.62'i 8.67 473.2.1' 8.64, 8.68' :541.24' 8.55' 3965.47' S. C. U. 33-33 4.0~' 8.14' I 30.08' 1.76' 4.00' 8.15' 1.94' 20.20' 1.79' 3.97 8.15; 1.65 9.00' .?o' _ ; CASING 1~ TUBING DETAIL SECTION 33 T. 8N.,R.9W. SM CHEVRON U.S.A. INC. WELL NO., SCU 33-33 SECTION NO. 33 TRACT #0.,,, , r"l PROPOSED E3 PRELIMINARY ~ FINAL V/ELL SURVEY Pro-312 COUNTY OF Kenai CiTY OF · _TOYMSH I P_ 8N RAM GEl.I 9W [~[] S. B.B. & g. I-3 14. D.B. & g. LOT MO. FI ELD Swanson River 1701 ft. Westerly at right angles from east boundary Sec. 33, and 1404 ft. Northerly at right angles from Southerly boundary Sec.33, T.8N.,R.9W.,S.M. LOCAT I ON ELEVATION: GROUND CONCRETE NAT DERRICK FLOOR ,, , , ~ ALTERNATE OR mU RYE YED LOCAT I ON LocAT j Off ' , DES I GN AT I ON LOCAT I ON COORD I NATES NOV E l E]4ARKS , , , , Final N .22.097.264.97 E 2,023,111.70 ,, Position to existi.ng ~ well "Christmas Tree" , , , .... , , , , , ,, .... ,, ..... , NO"TH SKETCH OR RENARKS. . : : I S 3 im .... ~ ~+ BEmClt ~RK IS: Top South rim C.M.P, cellar elevation 125.05 ft. sTATION SEARING DISTAIICE SINE COSINE NORTH 8c)u~H:~.:?: EAST VEST , , C.C. DIV. ENGR. FILE ~URVEYOR ~. 0~-~$~*~ HAINT. FRHN. HAINT. SUPT. DATE ,~/o,.: } / / 7,2' DATE DATE PIINTED IN U,I,A. PRO.312 (2 500.CD. 1- 5~: .-TRANSMITTAL ANL :KNOWLEDGEM~NT OF RECEIPT OF MA ~IAL- (ALASKA) DEPT.: ~. ~ ~__~ TtlE FOLLOWING IS A LIST OF llATERIAL ENCLOSED HEREIN. ~LEA~CO '~~(FJ~i~'~C~,"~ ~'~' ~~IiE. IMMEDIATELY. RECEIVED. BY FOR TYPE OF SURVEY'__ t 'z' ~: ..... ;' "' ~'' -~ t¢f'. ! / ~/[" ] ~:':?', ~) ? FR 0 ¢-/L._._.ic:.Z~=~ C,~ .............. FT. SU~VE..Y DEPTH: ' q ~ ¢ ~ ~, TO ........ 3~ L~.'~:~ ,_.,~: .......... t,~,~' , ..... _ ........ WELL NO. COUN~/PAi~,SH ~', ".. _ .- .' ............. '. _STATE .... DATE OF c,~¢v ,,~,:,.,",..~. ,:-:.,, ], f(. JOB ~n F~:~.z]A~??' STANDARD OIL CO OF CALIFORNIA 33-35 SWANSO~ RIVER ALASKA MEASUREO DEPTH TRUE SUB-SEA COURSE COU VERTICAL- VERTICAL I. NCLINATION DIRE DEPTH ....... DEPTH ............... DEG ....MIN ......... DEG SPERRY-SUN WELL SL ~EYI~.IG COMPANY AGE ANCHORAGE, ALASKA DATE OF SURVEY OCTOBER 25 1976 . COMPUTATION DATE ................................ ~URWEL'GYROSCOPIC ~ULTISHOT SURVeY'- oCTOBER 28 1976 -'dOB NUPiBER SU3-16~27 ........................ KELLY BUSHING ELEV, = 155,00 FT. -.. RSE DOG-LEG TOTAL CTION 'SEVERITY RECTANGULAR COOPDINATES VERTICAL REES ...... DEG/iO0" NORTH/SOUTH ...... EAST/WEST- ' -SECTION' 0 0,00 -155,00 0 0 S 0 -100 99,99 ............ ~53,00 . 0 o . S 57 290 199.99 q6.99 0 28 S 50 300 299,98 lq6.98 0 2% S ~5 qO0 ...... $9~,98 ........ ]---]-2%6,98 ................ O' .... 2~ ......... S 500 .%99.98 3~6,98 0 22 S 600 599,98 .~q6,98 0 26 · S 700 ...... 699,98 ........... 5~6,98 ................. 0'- 25 ............ S lo00 I100 1200 1330 1~$0 1500 17o0 18o0 2CO0 2!00 2200 2JO0 2~00 2500 2':3G 2.00 ~.'00 39 35 q3 1899,S9 199~.88' 209~,87 2!99,8& ..... 2299,85 239~,85 795,97 6q6.97 0 36 S 899,97 7q'6,97 O' .37 -. '- S 29 99~,96 ............. 8~6,96 .... :"~: .......... 0 ~ ~9 ......... S.27 1099,95 9q6.95 O. q2 : .S 33 1199.94 10~6,9q 0 q2 ' S 20 1295.9~ ....... 11%6o9q ................ 0 .... q2 S"- % 139~.~$ 12~6'~95 0 ql $ 7 1%99.92 13%6.92' 0 q2 S 11 1599,92 ........ 1%%6,92 ............ 0" q2 S .... 6 169~.91 15%S,91 0 q3 S 1799.90 - 16%6.90 . 0 q~ S 8 17%6,89 ~ 0 %6 $ 18%&.,88 0 %7 S.32 19q6,87 0 %9 S 33 20q6,86 ......... 0 ..... q6 ........S' 33 2i~6.85. 0 *~ S q2 22q6,85 0 q8 S 38 2599,83 2446,83 0 56 S 29 269~.82 2.5~6o82 0 39 S SS 2799.62 --' 26q6.~2 ..... 0 ' '~0 ......... S' 24 2699,,~! 27~6,8~ 0 59 S 29 2999,~,0 28~6.80 0 55 S 55 , O. ,50 ,17 .99 ,70 . 5 ,56 .73 ,26 ,55 . 9 . 6 ,'69 E . '0,00 '" '-0,00 0,00 E 0,59 0,28 'S : ....... E E 0o1~. 0.82 S 1,19 E · E 0,07 . 1,32 S 1,75 E E 0,0~ ~,8~ S 2 ,'2 3-"E E O,Oq 2,36 S 2,6q E 0,08 0.02 0,18 0,16 0.04 0,08 0,15 0,19 'O.O% 0,0~ 0,05 0o18 0,01 0,07 0,26 0,03 0,0% W 0,i2 W 0,08 W 0,09 W O~l~ W 0,09 W' 0°05 W 0,07 2,90 S .........._ _5,08:E 3o~3 S 3.60 E q.05 S ~.2q E ~.88 S ~,87 E 5.85 s-. 5.40 .... E - 6,87 S 6.00 E 7~95 S 6.5'5 E 9.13 S ' 6,8t'--E 10.33 S 6,9~ E 11.52 S. 7,!4 E 12,73 S 7-~33 E 13,95 S 7,31 E 15,20 S 7,12 E 16~9 S 6,88 E 17,71 S 6,35 E 18,88 S 5,59 E 20,0% S q,8~ E 21.07 S %.0~ E 22,09 S 5o17 E '23,16 S 2,57 E ~4,15 S 1~76 E 25,.08 S 1.19 E s .......... E -7 -6 -6 -.6 -2 . -1 o0 -0 . 2. 2, q. q, 5. 6, 6. 6, 7. 7, '27,11 S 0,11 E . 28,02 S 0,~4 W' O0 18 61 ~7 2O 85 55 75 22 18 q2 85 97 17 55 97 12 SPERRY-SUN WELL , tVEYiNG . o ANCHORAGE, ALASKA STANDARD OIL CO OF CALIFORNIA 33-33 COMPUTATION DATE SWANSON RIVER OCTOBER 28 !976 ALASKA COMPANY..- ................................................................... _P_AGE.._ 2 DATE OF SURVEY OCTOBER 25 1976 SUF, WEL GYROSCCPIC NULTISHOT SURVE"- WO8 NUMBER SU$- KELLY BUSHING ELEV. = 155o00 FT. MEASURED DEPTH. TRUE SUB-SEA COURSE COURSE DOG-LEG VERTICAL. VERTICAL INCLINATION DIRECTION SEVERITY ...... DEPTH ............ DEPTH ....... DEG'--MIN: .......... DEGREES ...... BEG/lO0 TOTAL RECTANGIJLAR COORDINATES VERTICAL --. NORTH/SOUTH EAST/NEST SECTION 3100 3099,80 3200 ..... 5199.80 ..... 3400 5500 ~700 5800 3930 qO00 4200 6300 'q~O0 ~500 29~6.80 0 529~.79 5599,79 52~6,79 0 35 5~99,78 ......... 55~6,78 ............ 0 .... ~1 5599.77 ~q~6.77 0 ~1 ~699.77 ~5~6.77 0 ~2 579~.76 55~6.76 ............... 0 ....... 46 3899.75 ~7~6.75 ~999.7~ ~099.72 ...........~9~6.72 q19~o70 ~0~6.70 q299.69 ~1~6.69 0 55 0 55 0 '"56 i 6 I 7 1 ! 7 51 S ~3 26 .......... S ...... ~8 39 S 50 'S 52 S 5~ S 69 S 8~ N 85 N 78 N 68 N 69 N 65 N 55 -" q399.67 ......... ~246.67 ............ 1- ~99,65 ~3%&.65 i q, 600 q. 700 "' 4800 8900 5000 5100 5290 5500 ' -' 5qO0 5600 5700 5 ~-0.0 6030 61 C: 0 4599,62 8~6.62 1 19 N ~7 q699,60 .......... ~566.'60 ............. 1 ....... !4 ............ ~799,58 ~646o58 1 8 N NO k899.56 ~7~6.56 1 6 N 53 4999,5q ........ 48q6,54 ............ i .... 1~ ........ 5099.52 q946.52 1 6 N 30 5199.50 50q6.50 i 10 N '--lq 17 N 12 19 N i8 -25 31 N 9 41 N 0 47' N 5 5999,22 56q6,22 2 0 N 6099.16 5946.16 2 9 N .- .16 ,20 .57 .32 .67 ,50 .19 .58 .24 .16 °55 o175 .29 ,59 ,7q . 7 5. 6 W 0.il '28,77 S 2.05 W 2,29 W 0,09 29,35 S 2,63 W 1,69 W 0,21 29 9'7 S 2,3q W 2 61 · W 0,07 ~0.64 S 3,18 W 3. W ................... 0,17 ........... 31,41 S $~'96'--W W 0o13 32,24 S q,81 W 5.09 W 0,21 ~2,83 S 5,85 W 6,1% ........................................ W 0,22 ~5,09 S 7,09 W 7,58 W 0,19 $~,08 S 8,55 W 8.8~ W 0,11 $2,86 S 10,15 W 10.~2 .............................................. _ W 0,16 52.~0 S. 11,67 W 11.96 W 0.16 ~1,7& S 15.~ W 1~.61 W 0,08 51o01 S 15,11 W 15.30 W '0,34 29,92 S 16,77 W 17.0~ W 0,15 26,68 S 18o5k W 18,60 W 0,26 27,55 S 20,00 W 20,2~ W ............ 0,08 .........25,8~ S .............. 21,62 W 21.85 W 0.I~ 2~.Sq S 25,0~ W 25.25 W 0,!~ 22.78 S 2q,21 W 28.~1 W 0,20 2i,17 S 25,~N W 25.~ W 0,25 19,53 S 26,66 W 26,6~ W 0.2~ 17o7~ S 27,q~ N 27,60 W ............ 0,1~ - '-i5,78 S ....... 28,20 -$'- .............. 26.5~ W 0,2q. 13,71S 28,86 W 29,00 W 0,16 -¢ 11,55 S 29oq9 W 29.60 ........................... W 0,20 9,25 S 30,11 W 30,19 W 0oll 6,71S 30,59 E 0.33 5,9k S 30.80 W 30.8= .................. E 0~!6 - 0.~92 S $0,6%' W $0,6b E 0,21 2,55 N 30~35 W 30.33 E 0o15 5,95 ~,; 30.0" · o ,, 50,00 ................. · .................................................................. S~..ER.B'~_-_SUN WELL SURVEYING__ COFiP.Ai'4.Y. A.N~HORAGE, ALASKA STANDI, RD OIL CO OF CALIFORNIA DATE OF SURVEY OCTOBER 25 33-35 CONPUTATiON DATE SURWEL' GYROSCOPIC MULTISHOT SURVE.'( . :: ~.;SON RIVER OCTOBER 2o 1976 ............................ ?~JOB ALASKA .- KELLY BUSHING ELEVo '= 155,00 FT, TRUE SUB-SEA COURSE .COURSE URED VERTICAL' VERTICAL $NCLINATION DIRECTION H ..... DEPTH ............ DEPTH ................ DEG ....HZN ........DEGREES .... ' M~AS VERTICAL DEPT ..... SECTION 619~.09 6046,09 1 56 N '7 .......... 629~,0~ .......... 61~6.'0~ ............ 1 ..... 5~ ........... N 7 50 .N t~ ~1 ~ 6 ~ ......... N ..... 6 ~7 N 5 2~ N ~ N 9 6200 6300 6~00 6596,99 62~5,99 6500 6~98.9~ 6600 ...... 6596,90 ............ 6~5;~0 670u 6698,86 65~5,86 6800 6798,85 6645,85 6900 ........ 6898,80 7000 6998,77 68q5.77 .71 7098°75 6915,7b 1 6 ' N 2.86 7178.75 ...........70q5,75 ................. 1 ....... 5 .... 7 ...... N ..... 0~28 1,90 5o7~ 0~60 ~. 0 7898.58 77q5,58 1 27 N 8,6~ 799&.55 .78~5,55 1 27 N 15.55 8096,52 ........ 79~5,52 ............... ~ - 21 ....... N 18,q5 8198.~ 80q5.~9 1 !5 N 21,98 8238,~7 81~5o~7 1 11 M. 21.6~ °57 7100 7200 7300 7~00 7500 7600 7700 7900 8O00 &lO0 8200 8500 7298,72 71q5,72 1 7 N 7598,70 72q5,70 1 7 N ..... 7998,6¢ ....... 75~5,68 1 9 ...... " N-- 7598,65 7q~5'.o65 1 17 N 7698,65 75~5,65 1 !5 N ...... 7796.61 ...... 76q5,61 ......... -'-' 1 ....... 15 .......N ! 8500 8000 8700 E.' ~ ~0 o-'00 DOG-LEG SEVERITY DEG/~O0 TOTAL RECTANGULAR cOORDINATES NORTH/SOUTH ...... EAST/WEST-~ · q-E 0,25 "~.51 N '29.71 ,3~ E 0.0~ 12.8;5 N 29,29 .50 E 0,11 16,07 N 28.95 ,55 E 0,16 19.12 N 28.66 ,65 'E ............ 0,15 21.92 N 28,5~ ,25 E 0~07 26,67 N R8,05 E 0,22 27,29 N ~7,85 EE ............... 0,!10'10 ............ 5129'6~,85NN ............ ~7,~2~'7";'~9--" · ~ ~':' E 0 20 ~5 89 N <7,19 E ............... 0,02 .......... 55,79 N .............. ¢~, 09 W 0,07 ~7,71 N ~}7,0'5 W 0,05 $9,65 N . 27.07 --W ................ 0,08 ........... ~1,6~ N 27,-20 E 0.18 ~5,7~ N 27,29 E 0.17 ~5,92 N 27,15 [ ............ 0,15 ........... q8~05 N ........... 26~'72 E 0,2~ 50,~5 f.J 26,2? E 0,~2 52,82 N 25,78 E 0,15 55,~6 N 25,11 E 0,.15 57.26 N 2~,5~ ~ 0,03 59,21 N 23,~&- E 0,08 61,06 N 22,82 0,12 0,21 0,21 0.10 0,01 E E E E E E E 82"" '~5 ! ........ 6 ......N-22 8~98,q2 8q~5.q2. 0 55 ~ 2~oq~ 8698.g! ....... 6Sql, q! ............... 0 q5 ....... 6796.k0 86~5,~0 0 qq N 15o6q 8~9£,39 87~5,39 0 ~0 N 8995,3A ...........88~5.38 .......... 0 '- ~0 ..... N 10,89 9098.~8 -89q5,~8 0 ~,~5 N 5.65 919~o57 90~5o37 0 ~ N 5,96 29.62 29.17 28.~' 28. 27.85. 27..61 27.q3 27,1~ 26.89 26,77 26.70 26.72 26.65 26,90 26.73 26~0 25,82 25.~I 24, 25,83 ~5,Oq 22.28 62,8~ N 22,19 W 21,6~ 6qo~5 N 21,59 W 21.02 65,81 N 21,07 W 20,49 '67o06 Di 20.7~ W 20.15 68,2~ Fi .20,4q W 69~38 N ......... 20,18'-W 19.57 70 60 r'J 20,01 W' 19, 71 89 r',~ 19 $8 ~; 19 2~ STANDARD $3-35 SWANSO't ALASKA ................................................... S~ERR~%SUN WELL Sgr~VEYZNG COMPAN.¥ ............................. pAGE ~ ° AN~tORAGE~ ALASKA OIL CO OF CALIFORNIA DATE OF' SURVEY OCTOBER 25 1976 COMPUTATION DATE $URNEL'GYROSCOPIC MULTISHOT SURVEY RIVER ............................................................................ OCTOBER 28 1976 ......................... "~dOB NU~BER 8U5-16~27 .................... KELLY BUSHING ELEV. = ~55o00 FT, ~EASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA COURSE COURSE DOG-LEG VERTICAL I~CLINATION DIRECTION SEVERITy RECTAN DEPTH DEG MIN DEGREES DEG/IO0 NORTH/ 9500 9298,~ 91~5,56 0 50 N !1,96 9gO0 ........ 9598.55 ...........92N5.55 0 ........ q5 .......... N-'i0-.57 9500 9~96.3~ 95~5.3~ 0 ql N 1,69 9600' 9598,55 9~5.55 0 ~8 N 5,59 9700 9698,$2 ...... 95~5,52 ......... 0--'~7 ......... N 22,60 9600 9798.32 96q5o52 0 37 N ~5,22 9900 9~96,31 97~5.5! O ~3 N q6,67 10000 10100 10230 10500 lOkO0 10500 10600 10700 10800 '10900 11000 11100 11200 115OO llqO0 11600 1i7~0 11800 11900 121~0 122~0 9998.~0 ........ 96q5.50 ............. 0--59 .......... N ~7,82 10096,30 99~5o50 0 36 N 52.82 10198,29 100~+5.29 0 qO ' N 51,26 ''10296°28 ......... 101L~5,28 ................. 0 ........ 57 ............. N'57.,$7 10598.28 102N5.28 0 I0~98.27 103q5.27 0 q0598.27 ....... 104q5o27 ................ 0-' 10698.26 105q5o26 107qS.2g 106q5.26 0 10898.26 ...... 10745.26 ...... ~ .... O' 10998,26 108q5.26 0 11098.26 109q5.26 0 · . _ ii195,26 .... 110q5.26 ....... 0 11298.25' 111q5,25 0 11598.25 112q5.25 0 !iq98,25 ....... 115~5,25 ................ 0 .... q6 ......... S-58,$8 Ii598.2~ 11~5,2~ 0 5~ S 25,18 11696.24 1t5~5.2~ 0 21 S 3~,!7 11798 2q llbq.~ ~2~ 0 3N N 5~,28 38 N 71, 0 . 27 N 7.,19 29 N 79.28 2! N 88.92 26 ......... N 70.9~ 16 N 6~.88 1~ S 83.76 8 .... S 8g.~ 18 S 69.2~ lq S 71.99 1i898,24 117~5.2q 0 6 S 11998.24 118~5,2q 0 29 S 12095,23 '-ii9q5.23 ...... 0' 18 .... 'S !2!~6.2~. 120"5.23~ 0 57 1~203 22 12i~5.22 0 51 S . .... .... TOTAL GULAR cOORDINATES VERTICAL SOUTH .... EAST/WEST SECTION -E 0,12 75,2q N 19,66 W W 0.~1 7~,59 N 19.63 W E 0,16 75.85 N 19,75 W. W 0.1~ 77.12 N 19,78 W ~ 0~25 78o~5 N 20o1~ W W 0.51 79.~6 N 20°76 W W 0,10 80.26 N 21.60 W W 0.06 81.07 N 22.~7 W W 0.07 81.77 N 2~,51 W W O.O$ 82oq5 N 2qo18 W W 0.08 85.11N 2~o09 W W 0.05 85,69 N 25o9~ W W 0,18 8qo15 N '26,87 W W ........ 0°18 ..... 8q.q'~'"k 27.-77 W W 0.05 8~,65 N 28,56 W W 0o15 8~°7~ N 29,28 W ........................... W 0~I7 65°05 N 50.51 W W 0o!~ 85.1q N 50.92 W W 0.10 85.11 N ~!.2~ W W 0,1.7 85,01 N 51,60 W W 0,06 8~,85 [,j 32,0q W W 0,58 8~,27 H 52,65 W W 0,25 63,30 N 55.28 W ~'w 0~22 '- 82,60 N 53,67 W .............................. W 0,51 82,$~ N 53,90 W 55,15 W 0,05 ~2o29 N 5qo02 W ~8,20., W O,Sg 8!,95 i',; 54,ql ~ 55~54 ~i ....... 0,19. 81.47 N - 5~,58 W 3~° 7 W 0~31 80°80 f,! 55°33 W 8'Oo77 W 0,69 80,31 i'J ~6°36 W ....... 19.01 18.97" 19.F 19.1U 20,06 20;89 21.75 22,59 25.q5 2~.35 25.20 26.12 27.02 27,81 28.53 29.19 29.76 50.1- 50.~ 50~85 5t.29 31.9! .52,55 52,~5 $5.17 3z 6° SPERP, Y-SUN WELL ANCHORAGE, ALASKA STAD~DARD OIL CO OF CALIFORNIA DATE OF SURVEY OCTOBER 25 1976. . ~5-3~ CO~-~PUTATiON DATE SURWEL GYROSCOPIC MULTISHOT SURV.EY S>~Ar~SO~J RIVER .............................................................................. OCTOBER 28 ~76 ..... ALASKA KELLY BUSHING ELEV. = 153.00 FT, FEASUEED DBPTH 12400 12500 12&00 12700 12800 12900 13000 1~100 13200 15500 13~00 13500 15600 15700 1~600 13900 lqO00'- 1~100 14200 lq400 lq530 lq6SO 1~7)0 14630 15030 15!'10 152~0 153'0 TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH '- ....... DEPTH ............. DEG HIN .... DESR£ES DEG/IO'O NORTH/SOUTH'-' EAST/WEST ............ SECTION 12398.21 122q5.21 0 12498.20 ...... 12545.20 ................ O ].2598,18 12~%5.18 1 12698,16 125~5,16 1 12798.1~ ............. 126q5,1~ ................... 1 12898.15 127%5.15 0 12998.12 !23%5,12 55 N 69.~2 W 0.3~ ' '80,55 N 37.85 W 57.1~ ......................................... q. 1 W 58.70 59 S 70.51 W 0.65 80.5~ 2 S 80.62 W 0,18 80,11 i'.; ql,ll W qO.qO 5 .N Y8,15 W 0,~9 80.15 ....... 10 ........... S-'87,71 W ............. 0,28 ........ 80,51 N ............ q4,86' W %q.15 ~7 S 88,51 W 0,58 80,22 N ~6.56 ~ ~5,85 q5 S 75.96 W 0~16 80,00 E ~7~87 W qY,'i7 ....... S 76.q. 5 W ....... 0.13 79.69 N ~-9.03 W q8.32 S 81,69 W 0,26 79,52 N ~9,8~ ~,j q9.13 S 50,90 W 0~21 79.25 N · 50,ql W %9,71 S 3%,I1 W .......... 0,~1 78,~4 N ............ 5!,08"W'- ......... 50.39 S 29, 7 W 0,32 77,02 N 51,95 W 51.26 S 2~.76 W 0,52 75,05 id 52,9'2 W 52,25 . - -22,q~ W ............... 0,0~ 72,69 N ........ '55,~2 ..'.' 55.27 21.87 W 0~16 70,kO N 5~,85 W 5~.22 2q.5J W O,lq 68.57 N 55.72 ¢ 55,~1 25,~& W ............. 0.20 ....... 66.63 N -- ~6.~3' W 55.°~' 26,58 W 0,05 65,07 ~; 57,32 ",.~ 56.7~ q7 S 26,85 W 0.21 63,70 N 58,0q W 57.q8 52 ...... S- 2~ 80 N ........ 0 09 62 39 N S 28,92 R 0.26 60,85 S 23,53 W 0.15 '59.20 f,,; 60,25 ~,~ 59,72 --S-20,!5 W ........ 0,27 .... 57,35 h ....... ' .... 60.98-W ................. 60.~7 S 6,68 N 0.55 5%,85 N 6i,55 ~ 61,05 S 0.44 W 0.92 -- 51.11 [~ 61.72 W 61.27 .... S' 5,56 E .............0,67 ~6,06 N ..... 61.q7 W ............. 61.06 S 1.66 E 1.57 59,14 M ~!.O.S W 60.'7~ S O. 5,W 1.32 29,72 M 60.9S W 60.70 S 12,5~'E~. .... 1,90 1.8~25 S %~53; ~J 2,5~ 5~09 [~ 58,7~. ~ 58,69 S 3.79 t,] 0,55 0.52 S 59,15 i,t 59,15 ..... 1~098.1! ..... 129%5,1.1 .................. 0 ..... 37 13198.11 150'+5,11 0 20 15298,11 13!q5.!1 0 25 13~98.10 .... 13245.10 ............. 0 q8 13498,09 13545,09 1 7 15598.06 15kq5.06 1 25 13g98,05 ............ 13545.0~ .......... i .... 30 ....... -"S 15798.00 136q5000 1 20 S 13897,97 137~4.97 I 12 S 15997.95 ......... 15644.95 ............... 1 ......... 0 .......... S 18097,9~ 139~.9~ 1 0 S 14197,95 lq644.95 14297,92 ....... lq144.92 14397,90 . 19244,90 14497.88 145q4-.88 14597.86 .... 14qqq.86 1~697.85 Iq797,76 14897.53 15096.93 !5196,2a 15295,55 Iq5%4,85 1~6%%.76 · 1454%,38 J. 50~5,24 !5!~2.35 15131.95 0 i 16 i 42 2 56 _.. 5 12 q. q5 6 ~ 7 &8 ~ 0 6 12 FEET AT SOLITH, 89 DEG, 29 P;iN: ~,'ESi' AT i~"iB = 15340 THE USE OF THREE DiF,';EF,!SiOf,!~L RADIUS OF CURVATUEE'METHCD~ · ............................................................ SFERR_y.-_SUN WELL SUR\ 'ING._.CO[ApANY ..................................... F ' ANCHORAGE, ALASKA ,,-,~,O~,RO OiL CO OF CALIFORNIA DATE OF SURVEY OCTOBER 25 .. 3~-~ COF, PUTATION DATE SURWEL GYROSCOPIC F~UL'TiSitOT SURVEY.. S,,;;;:',:SOr~~IVER ................................................................................. OCT'ODER 28 1976 ........................ U~'B NU~;BER SU3-16127 ................... ALASAA KELLY BUSHING ELEV, = ~53,00 ALASKA INTERPOLATED VALUES FoR--EVEN"IO00 FEET-OF-NE~SURED DEPTH TRUE SUB-SE ~,EASUREG VERTICAL VERTICA _~ TH DEPTH DEPTH A TOTAL L ........ RECTANGULAR CooRDIt~!ATE NORTH/SOUTH EAST/WES S ........ FID-TVD ............. VERY T DIFFERENCE CORRECTIOf,! 0 ............. 0'00 ..........153'.00 ..................... 0'~-00 1000 999.9~ 6q6,96 5.85 S 5,qO E 0.05 2000 1999.88 18q6.88 17.71 S 6,55 E 0,11 5000 "2999.80 ........ 28q6.80 .......................... 28.02 S .................. O.q~ W ............. 0,19 4000 3999,73 ~846,73 32.86 S 10,13 W 0,26 5000 ~999.5~ ~$q6o5~ 21.17 S 25.~ W O.q5 6000 5999,22 ...........58~6.22 .................... 2,36 'N .............. 50,35 'W ...... 0,77 7000 6996.77 '68~5..77. ~1,85 N 27.~2 W 1,22 8000 799~.55 7845.55 52.62 N 25.78 W 9000 8995,38 ...........88~5,38 ............................ 69,38 N 10000 9998.30 98~5'.30 81o07 N 22,~7 W !,6 11000 10998,26 10545.26 85,06 N 30,51 W 1.7 ~2C00 119~E,2~ ...... 11~5,2~ .......................... £1.96 N ......... 5goal W ............. 1,7 ~3000 12998.12 128q5,12 80.00 N '~7,87 W 1o8 1NO00 13997,95 13844,95 66,63 N 56,53 W 2,0 i5C50 iq997.36 ..... i'4f4'4,36 ....... ' ........ 39.1'+ N ........... 61,06 i53~0 ~533~.~5 - 15161.95 0,52 S 59,13 W 5,0 0,05 0.07 0.07 0.07 0.19 0.31 0.45 0,22 0,08 0,0~ 0,02 0,11 0,16 0°57 2,q2 THE CALCULATION PROCEDURES .... ARE BASED .... ON THE-'USE OF"THRHE GINENSIONAL RADIUS OF' CUR~AYURE-'METHOD'; .............. ALASKA OIL RIVER SPERRY-SUN WELL SU,,vEYiNG COMPANY ANCHORAGE, ALASKA CO OF CALIFORNI'A . .......................................................................... COHPUTATION DATE OCTOBER 28 1976 .A.GE .... 7 .... MEASURED DEPTH DATE OF SURV'EY OCTOBER 25 1976 sURWEL G Y R 0 SC 0 P I C_MUL_T IS._H 0]~ _SU R Vm__y... ,JOB NU~iD, ER S53-16127 KELLY BUSHING ELEV, = 153,00 FT. INTERPOLATED VALUES FOR EV EN 100 FEET OF SUB-SEA DEPTH TAL COORDINATES MD-TVO VERTICAL ...... EAST/WEST ..... DIFFERENCE .......... CORRECTI_ON TRUE ......... sUB-sEA ............................. TO RTICAL VER. TICAL RECTANGULAR EPTH DEPTH NORTH/SOUTH 1000 955 1153 1553 1933 2053 2253 3 2~53 2553 2653 9 10 11 12 15 16 17 18 2O 21 22 2~ 25 26 99.96 6~6.96 5.85 S 5.qO E O,Oq 55.00 600,00 5°37 S 5.15 E 0,03 55,00 .......... 900,00 ............. 6.38 S ............... 5,68 E ........... O,Oq 55.00 1000,00 7.~1 S 6.3~ E 0,05 53,00 ~100.00 8,55 S 6,75 E 0.05 53,00 1200.00 9,76 S 6,86 E 0.06 53,00 1300,00 10,95 S 7,02 E 0.07 55.00 lgO0.,O0 12,!5 s 7.25 E 0:08 5~.00 .... i500,'00' ' ....... 13,36 S .................. 7,37 E O.OS 53.00 1600,00 14,60 S 7,20 E 0.09 55,00 1700,00 15,87 S 7,01E 0o10 53°00 .........!,300,00 .......................... 17o16'--S ........... 6,67 E ....... O,li 53.00 1900.00 16°32 S 5.95 E 0.12 53.00 2000,00 19.50 S 5.i7 E 0,13 53.00 ....... 2100.00 ......... 20.62 S .............. ~,~5 E ........ 0,1~ qS,O0_ 2200o00 21.58 S ~,x 57 E 0,1~ 55.00___ 2300.00 22,66 S . 2,71 E 0,!5 ~$.~0 2~00.00 23,71 S 2,00 5 0,1~ 55.00 2500.'00 2~o63 S 1.q7 E 0,17 0,00 0,00 0,00' 0,00 0.00 0,00 0,00 0,00 0,00 0,00 O,O0 ....................................... 0o00 O.O1 0,00 ..... 0.00 0,00 O,OO ~ 0~0 ~IA;,DARD OIL ~t~A~,$SOF.: RIVER ~.LASKA TR 'tEASURED VERT )EPTH DEP 2753 2953 $253 3753 3853 3933 %053 ~153 q253 q~55 q555 SPERR~.xSUN WELL SU~.EYING._COHPANY ~AGE_ ANCHORAGE~ ALASKA CO OF C~LIFORNIA DATE OF SuRvEY OCTOBER 25 1976 COFqPUTATION DATE ................ SURWEL GYROSCOPIC MULTISHOT SURVEY'" OCTOBER 28 1976 dOB NUFi~ER SU3-16127 KELLY BUSHING ELEV, = ~53,00 PT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH uE .................. SUB"SE'A- ................................... ToTaL:' ..... ICAL VERTICAL RECTANGULAR COORDINATES TH DEPTH NORTH/SOUTH EAST/WEST 2755,00 2600.00 25,59 S 0,86 E 2853.00 2700.00 26.63 S 0,37 E 2953,00 ..... 2800,00 .................... 27,6i'S ................. 0,18 W- 5053,00 2900,00 28,q5 S 0,75 W 5153.00 3000.00 29,10 S 1,37 W 3253.00 ...........3100,00 .................... 29,62 S ............. 1,95 W 3353.00 3200,00 30,3~'S 2,81 W 3~53.00 3300,00 30~98 S . 3,62 W 5553,00 3qO0.OO 31,88 S 4,39 W 3653,00 3500,00 32.61S 5,33 W 5755.00 ...... 3600.00 55.05 S 6.~7 W 3853.00 3700°00 ...................... 33,12 ~ ................... 7,82 W 5955,00 3800,00 32,99 S 9,~1 W q053,00 3900.00 32.66 $ 10,97 W ~155.00 .............. qO00.O0 ...................... i. 52,06 S ......... 12,51 W 4253.00 ~100,00 31,~8 S 1~,29 W q355.00 q200.O0 . 50.53 S 16 05 W ~q53.00 4300.00 29~19 S ............ 17,60 W ~553.00 ' qqO0,O0 28,05 S 3.9,21 W MD-TVD DIFFERENCE' VERTICAL CORRECTION 0,17 0,18 0,19 0,19 0,20 0.20 0,2! 0,21 0,22 0,23 0.25 0,25 0.27 0,28 0,30 0,32 O,3q 0,00 0.00 0,00 0.00 O.O0 0,00 0,00 0,00 0,00 O.OO. 0o00 0,0i 0,0i 0,01 0.01 0,02 STA~C~D $.L$SKA MEASURED DEPTH _ _ %853 5053 5153 5253 5353 Sq. 53 5553 56~3 57~3 5853 5~ 6153 6253 6~53 .............. SPERRY~.SUN WELL SU,.VEYING._COMPANY .......................................... ~AGE__9, ANCHORAGE, ALASKA OIL CO OF CALIFORNIA DATE OF SUR~EY OCTOBER 25 1976 ................................................................................... COEPUTATiON DATE SURWEL GYROSCOPIC MULT!SHOT SURVEY- RIVER OCTOBER 28 1976 UOB NUF~BER SU3-16127 KELLY BUSHING ELEV, = ~53,00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ......... TRUE ......... VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEP?H ................... DEPT.H ........ NORTH/.SOUT_H ............ EAST/WEST DIFFERENCE ' CORRECTION · q653,00 g500,O0 26.52 S 20,90 W 0,39 0~02 ~753,00 ...........%600.00 25.03 S 22.%q- W 0,~1 0~02 ~853.00 %700,00 23.51 S 25.71 W 0.~3 .......... 0.01 49.55,00 4800,00 21,91 S 2~,80 W O.q5 0,01 5053.00 ~900.00 20,29 S 26.18 W O.q7 0,02 5155,00 5000.00 16,6'2 S 27,1~ W 0,~9 0,01 5253.00 5100,00 16,69 S 27,81 W 0,51 0,02 5553.00 5200.00 1~,71.S 28,64 W 0,53 0,02 5455,00 5~00,00 12,53 S 29,16 W 0,56 0,02 5553,00 5400;00 lO,3q E 29.88 W 0.58 0.02 5653,00 ......... 5500,00 ......................... 7,91 ~ ................ 30,39 ~ .... 0,61 0,03 5753,00 5600,00 5,28 S 30,80 W 0,65 ................ 0,03 5653.00 5700,00 2,3~ S 30.77 W 0,69 0,0~ 5955.00 5600,00 . 0,77' N 30,50 N 0o7~ O,Oq 6053,00 5900,00 ~.25 N 30,20 W 0,60 0,06 6153.00 6000.00 7.96 ~.i 29,90 W 0,87 0,06 6253,00 .....6100.00 . 11,32 N 29.q9 W 0,93 - 0,05 6353.00 6200,00 1~.60 N .................. 29.08 W ........... 0,99 0,05 6~55.00 - 6300..00 ~7.78 N 28,82 W ~.0~ 0,05 3TA?:D~,'-~ J3-33 ),LASKA OIL CO OF CALIFORNIA SPERRY-SUN NELL' Sb..~£YING CoMpANy ANCHORAGE, ALASKA COMPUTATION DATE RIVER OCTOBER 28 1976 _,_AG E .... 10 .... . DATE OF SUF, VE¥ OCTOBER 25 1976 , SURWEL GYROSCOPIC MULZI~O_I'__SWRVE~..:. dOB NUMBER SU3-1617.7 KELLY BUSHING ELEVo = 153,00 FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DF. PIH .............. -TRUE su'~3-gSE"A- L;EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD }EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST .DIFFERENCE 655~ 6555,00 6~00,00 20,69 N 28o69 W 1,08 665~ 6655.00 6500.00 25,~9 N 28,18 W 1,12 675~ 6753,00 ........ 6600,00 ..................... 26"!'? N ................. 27,93 W .......... 1,15 655~ 6853,00 6700,00 28,61N 27,78 W 695~ 6953,00 6800,'00 ~0,87 N 27,59 W 705~ 7053,00 6900,00 ~3,01 N 27,25 W 1,23 71~q 7I~'~. . o O0 7000.00 ~.9~ N 27.1~ W 1.25 72~ 725~o00 7100.~0 $6.8B N 27,0~ W 1o27 735~4 755~,00 7200,00 38,77 N 27,05 W 1,29 ?q=% 7~55,00 7500,00 ~0,72 N 27,12 W 75~q 7553.00 7~00,00 ~2,7~ N 27,30 W 765q 7655°00 ........ 7500,00 ..................~,96 ~.I ............... 27.27 W ......... -,~.00 7800.00 ~7o07 N 765~ 7853.00 7700.00 ~9,21 N 26,~5 W 795% 7953°00 7800.00 51.70 N 25,05 W i,q3 &O~ 8053.00 7900.00 5~,15 N 25,~5 W 1.q6 8!5~ 6155o00 _ 8000.00 56.37 N 24,71 W l,q9 ~25~ ~255,00 8!00,00 58°3g N 25~92 W 1,51 83~ 8353.00 6200o00' 60,25 N 23o16 W VERTICAL CORRECTION 0.0~; 0.03 0.03 0~02 0,02 0,02 0,01 O,Ot 0o0! 0°01 0.02 0,02 '0°02 0,02 0,03 0.02 STAF;D,CRD ~L~SKA OIL CO RIVER ................. SPERRY, SUN WELL SUtqVEYING_._CODiPANY...: .................. '~AGE..__I~._ AD.JCHORAGE, ALASKA OF CALIFORNIA DATE OF SUR.VEY OCTOBER 25 1976 '- COFCPUTATION DATE SURWEL GYRoSCOP!C_.HUL!iSUO!.~_SURVEY- ...................... OCTOEER 28 1976 ....................... dOB NUMBER $U~-l&127 KELLY BUSHING ELEV, = 1~5.00 FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~EASURED DEPTH 8~5~ 855~' 865~ 875~ 8854 905(~ 925~ 9~5~ 9~ 975~ 985~ 995g 1005~ !OID~ 102b~ .......... TROE ........... ~'uB~SE~ .............................................................................................................................. TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES ~D-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTIO~ 6~55.00 8~00.00 62,05 N 22,qff W 1,55 0,0! 8555,00 8400.00 65,80 N 21,91 W 1,57 0,01 8655.00 ......... 850~.00 ................ 65,2~ N ................. 21~25 W ................. 1,58 ...................... 0,0! 8755.00 8600.00 66,50 N 20~-89 W 1.59 0,00 8855.00 8700.00 67.7~ N 20,58 W 1.60 O,O0 8955,00 8800.00 68,87 N 20,29 W 1.61 0,00 9055.00 8900.00 70,02 ,~ 20,08 W 1,61 0,00 9155,00 900.0,00 71o$2 N 19,95 W 1~62 0,00 9255,00 .......... 9100',0'0 ....... 72~60 N ....... 19,80 W !,85 0,00 9553,00 9200,00 7q. Ol N 19.5q W 1,Gq 0o01 9q55,00 9~00.00 75,~0 ;~ !9,75 W 1,65 0,00 ..... 955~,00 ........... 9400,00 ..................... 76,50 ~ ............ !9.?$ W ................ !,66 ......................... 0,00 9655.00 9500.00 77,88 M 19,69 W 1,67 0,00 9755,00 9600.00 79.11 N 20.q5 W 1.68 0.00 9855.00 ..... 9700.00 ................. 79,89 N ............... 21.20 W .............. 1,68 ...... 0,00 9955,00 9800,00 80,7~ M 22,i0 W 1,69 0,00 10055,00 9900,00 81.49 N 22,9~ W 1.70 10155.00 .... 10000.00 ............... 82,13 ;~ 23,78 W !,70 0~00 10255,00 10100,00 82,85 Cd 24~68 W loYl 0,00 .... , . .$PERRYT..SUN NELL S~.,VEYING COMP'ANY ............................................................................. pAGE_12.~ ANCHORAGE~ ALASKA STADJDARD OIL CO OF CALIFORNIA DATE OF SURVEY OCTOBER 25 1976 33-33 COMPUTATIOF! DATE SURWEL GYROSCCFIC MULTISHOT SURVEY $~Ar,,iSO¢~ RIVER ....................................................................... OCTOBER 28 i976 ................................ dOB NUMBER SU3-16127 ALASKA KELLY BUSHING ELEV, - 155o00'FT. INTERPOLATED U OR EVEN VAL ES F !00 FEET OF SUB-SEA DEPTH i F:EASU DEPTH REO TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL/' DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1035~ 1055~ 1065~ 10754 1085~ 1095~ 11054 1115~ 1125~ 1135~ 11~3~ 115~ 1165~ 117~ 1185~ 12054 1215~ 10553.00 10200,00 83.q5 N 25,58 W 1,71 0o00 · lOa5b. .00 10500.00 85o99 N 26o~i W 1,72 O,O0 !0553,00 I0400.00 8q,55 N 27,42 W 1.75 0,00 10655,00 10500,00 8q,55 N 28,19 10755.00 10600.00 84,71 N 29.00 i0655,00 10700.00 8~,7~ N 2~65 ~! 1°7~ O,OO 10955,00 lOSO0,O0 8A~.98 N 50,52 W 1.7~ 0.00 11055.00 10900.00 85.16 D.; 50,75 W 1.7~ O.OO 1115~.00 11000",00. 85.1~ N 5l,lq W 1.7~ 0.00 112~5.00~ 11!00,00 85~10 N 5!~o59 W 1,TN 0,00 11355.0o 11200.00 8q.92 N 51.87 W 1.7~ 0.00 ll~SS,O0_ .... 11500,00 ...................... 64.75"*",,, ........... 52,29 W 11555.00 llqO0.O0 83.72 DJ 35.09 W 1.75 GoO0 11655.00 11500.00 82.85 N 55,52 W 1.75 0~00 I1755.00 ..... 11600.00 ...................... 82.57 N ........... 55.8~ W .... 1.76 ............ 0.00 11855,00 11700,00 82o~4 N ~°97 W 1o76 0,00 1i935.00 11800.00 .. 82,21 ~,! J~o15 W 1,76 0.00 12055.0n .... ii~00.00 81.67 N 34.7¥ W 1,76 O°CC. 12155.00 12000,00 81,21 N 55,08 W i,76 0.00 $5-55 SWAb:SO;,; ALASKA MF_ASURED DEPTH 1255~ 1245% 1255~ 12754 1295% 1505% I~154 1355~ 15654 1375~ 1~855 13955 1~0~= SPERRY-SUN ~JELL SUt ANCHORAGE, OIL CO OF CALIFORMIA COMPUTATION RIVER .............................................................................. OCTOBER 28 "YING COMPANY ALASKA DATE 1976 15 DATE OF SURVEY OCTOBER 25 1975 , SURWEL GYROSCOPIC_..MULTIG_HO..T__SURVE.¥,_;.. dOS NUFi~ER 8U3-16127 KELLY BUSHING ELEV. = 153,,00 FT, INTERPOLATED VALUES FOR EVEN I00 FEET OF SUB-SEA DEPTH '-- TRUE ............. SUB-SEA ...................................... T'OTA"L"- ............................ : ................................................... VERTICAL VERTICAL RECTANGULAR COORDINATES F;D-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTZON 12255,00 12100,00 80,$8 N 55,72 12355.00 12200.00 80°52 N 37.18 1245~.00 ....... 12500.00 ..................80.78 N .............. 58.69 12555.00 12400.00 80.26 N q0,32 12655.00 12500.00 80,01N 42,10 12755.00 12600.00 80.54 N 45,96 12855,00 12700.00 80,27 N 45,94 12955.00 12890.00 80,16. N ~7.51 15055.00 12900.00 79.82 N 48.56 15155.00 15000,00 79,57 N ~9,57 15255,00 15100,00 79,q6 N 50,16 !5B53.00 ...... 13200~00 ................. 78.95 ;,i ................... 50,7q 15455.00 15500.00 77~78 ?J 51.55 15553.00 15400,00 76.05 N 52,q8 13655.00 ........ 15500.00 73,79 N 53.47 13753.00 13600,00 71.39 N 54.~6 15855.00 13700,00 69.2~ N 55.33 15955.00 !5600.00 67,35 ~,t 56,19 14055,00 - 15900,00 65.77 N 56.95 W W W W W . W W 1.77 0,0 1o78 0.0 1,79 0,0 1,81 0,0 1.82 0,0 1,8~ 0,0 1.$6 0,0 1.87 0.0 1,88 0.0 i.88 0,0 1,89 0,0 1,89 0.0 1~90 0o0 1,92 0.0 1,95 OoO 1.98 0,0 2.01 0,0 2.03 0.0 2.05 0,0 0 1 1 1 1 1 ! 0 o 0 ........................................................................... SFERRy...,_SUN WELL ..$ .VEYING coMPANY ANCHORAGE, ALASKA STA;iC;,~D OIL CO OF CALiFOR" ~.3-33 .............................................................. ~ ........... COM?UTATION DATE .... , SWA~;SOFj ~IVER OCTOBER 28-1976 AL A~'' '~ ................................. . _...CA G E .... 14:~ DATE OF SURVEY OCTOSER 25 Z976 SURWEL GYROSCOPIC MULTISHOT SURVE~ dOB NUMBER SU5-16127 KELLY BUSHIN6 ELEV, = 153,00 FY, INTERPOLATED VALUES FOg EVEN !00 FEET OF SUB-SEA DEPTH ' TRUE suB-SEA TOTAL MEASUR£D VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH' DEPTH NORTH/SOUTH -EAST/NEST DIFFERENCE' CORRECTION · 14155 I~!55,00 lqO00.O0 6~o26 N 57.77 W 2,06 0,01 Iq255' 1~253,00 lqlO0.O0 63.02 N 58,39 W 2,07 0,00 lq355 1q353.00 ...... lq200.O0 ........................ 61-,62 N .............59.02 W ..... 2.08 ..................... 0o01 1~N55 1~g55,00 14500.00 59,93 N 59,94 W 2,'10 0.01 !~555 i4'555,00 14~00.00 58.29 N 60.65 W 2,!2 0.01 !~655 iq655o~0 !~500.00 56.'16 N 61.5~ W 2.1~ 0.02 1~755 I~753.00 lq600,O0 55.11 r,~ 61.71 W 2.19 OoOq 1~855 1485~.00 1~?00.00 ~8o5~ N 61.71 W 2.30 0.10 2g$55 1~53.00 ..... 1~800.00 ............ ~2.78 ~ ............. 61o20 W .... 2o~7 ........ 0.!6 15055 15055,00 1~900,00 54,35. N 60,97 W 2,83 0,35 !5~=,& ~5155,00 15000,00 2~,62 ?.j 60,75 W 5~0 0,57 15257 15255,00 15100,00 11,02 N 58,3¥ W 153r;0 !535q,95 !5!81,95 0o51 S 59~1~+ W 5,04 HE CALCUt, ATIOM PROCEDURES'USE A.- L'INEAR"INTEEPOL'ATIO~rJ 5~ETWEEN T~£ NEARES~ 20 FOOT MD (FROi~ RADIUS OF CURVATURE) POINTS 0°82 0°81 . . LOCATED IN THE APPENDIX [21 WFL 'Cl IPR LOG CALIPER SURVEY VOLAN CURVE DATA STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER' TIL&NSt.II. TTAL AND ACI(.NOWLJ'U~GJ'lt,~NT i.)F Rt,]C],.'I]~T OF I.I/~'E],~IAL - (ALASKA) :/ Tt[1E FOLLOWING IS A LIST OF MATERIAl, ENCLOSED tlEREIN. PLEASE CHECK /tiN]) ADVISE IMMEDIATELY. K I:: L I:::.1 V..I:: U ............................... ......... . , RECEIVED BY _ . - .. ~L' ...... ? REM/~I,II($ ON OTItER SIDE, TIllS $1tE'ET STATE O} .LASKA REV. $- i-?0 OIL AND GAS CONSERVATION COMMITTEE PAONTHLY REPainT OF DRI'L[JNG AND WOEKOVE~ OPERATJO'NS W~LL WELL OTHZR SUBMIT I.N DUPLICATE 2, N~ME OF OP~q%ATOR a ^DD~ZSS OF ,, P..Q.. Bgx .7,829: kr'jnhcrrnge_...Alnn'k'n qqq'10 4. LOCATION OF WF. LL 1400' North and 1700' West from Southeast corner of Sec. 33; T-8N, R-9W, S.B. & M. LEASE DES:GI4A~ION AND SEE1AL NO ~A028990 7. IF INDIAA[ ALO'TTEE OR TRIBE NAME 33=3':: ,, FlED AND POOL, OR %VILDCAT Swanson River n. SEC., T., R, M., (BOTTOM HOnE Sec. 33; T-8N, R-gW S.B. &M. 12. PF_,R,MIT NO. 76-56 13. t{W-PORT TOTAL DEPTH AT END OF MON/~H. CHAfrGF~q IN HOLE SIZE, CASING A~N~D C~NTING JOBS INCLUDING DEP~ SET AN~ VALISES USED. P~ORATIONS. ~TS ~%~ ~SUL~. FISHING JO~. J~K LN HO~ ~ND SIDE-~CKED HOLE ~N'D ~Y O~R SIGNIFIC~T C~G~ ~ HO~ ~ITIONS. January 1977 Commenced operations at 12:00 Noon 1-10-77 Drilledout bridge plug at 11250' and cleaned out to 16000'. Bridged hole with 311 sacks of cement from 16,007'; with 167 sacks of cement from 13,502'; with 206 sacks of cement from 12,042'; and with 194 sacks of cement from 11,350'. Drilled out cement from 11,121' to 11,140'. Press tested casing OK under 800 psi with 96 pct mud R~_n CBL & collar locator. Per~'d. 9-5/8" casing with four 1/2" holes per foot from 10702-10712'. F. T. of perle, i0702-10712'. Open 9 hrs 18 · minomedium blow of gas decreasing to light blow at end of test. Recovered. 42bbls. gas cut mud in 3 1/2" tubing. Per~'d.9 5/8" casing with four 1/2" holes per foot 10680- 10710 and three 1/2" holes per foot 10702-10712. F. T. of perle, 10680-10712. Gas mud and oil to surface in 13 rainutes. '. Flowed at 40 B.D. oil 3 B.D. water and 12,597 MCFD gas on 15 hr. 35. min test. Recovered 6.7 bbls oil in 3 1/2" tubing. Set bridge p I Il ° ' II plug at 10665'. err d 9-5/8 caszng wzth three 1/2 holes per foot from 10562- 10588'. F.T. of per~s. 10562-10588. Fluid to surface in 32 min. Flowed 1418 B.,D,. oil .2 B.D. Water, and 4307 mct per day gas on 4 hour 11 min. test. Pezf'd. 9-5/8 casing with three 1/2" holes per foot from 10610-10628', 10640-10645' and 10651-10658'. RECEIVED FEB I 0 t977 D!vislon of Oil and Gas Conservation Anchorage ii l[ : - . ill , , Il LU - . ~ NOTE--Reporl on this~form i~ required for e0ch calendQr ~nth~regardless 0f lhe status of operations, and must ~ filed in duplicate with the end gas conser.af~°~ commIHee by the 15~ of the ~u~c~ding month, unle~ otherwise directed. Form ~o. REV, 5-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'ri'EE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE 1. Exploratory ~. N~E OF OP~TOR Standard 0il Company Qf California WOI S. ADDRESS OF OP~R P. O. Box 7-839 ~ Anchorage~ Alaska 995] 0 4, LOCA~ON OF W~ 1400' NotCh and 1700' ~es~ from southeast corner of Sec. 33~ T-8N, R-9~, S.B.~ ~. 12. PEB. MIT NO. 76 - 56 13. REPORT TOTAL DE~TH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEA~ENTING JOBS INCLUDING DEPTH SET A2~D VOLLrMES USED. PE/{FORATIONS. TESTS A_N-D RESULTS. FISHING JOBS, JUWK IN HOL~ A-ND SIDE-TP~ACKED HOLE AND AJqY OTHER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS. ..... $oldotna Creek " 9. WELL NO .. SEC..oB.~.~T., R., ~,, (B~O~ ~OU ...... Sea, 33~ T-SN~ December 1976 Ran DIL, BHC Sonic, FDC-CNL, dipmeter logs at 17689'. Ran velocity survey and took S.W.S. Set bridge plug at 11250'. Displaced mud in hole with diesel oil from 150' to surface. Closed BOPE. Suspended operation at 12:00 midnight 12-14-76 until labor contract negotiations are completed. RECEIVED JAN. 6 1927 Division °~_an.~1 Gas Conservation "=horage 14. I hereby certify that the Iorego~ S,~NED ~. lqatiu~.--- - _~/-;- ,L.~-~ Area Enqineer i NOTE--Report on this form is req~d for each calendor ~nth~ regardless of fha status of operations, and must ~ filed ~n duplicate with th e oil and gas conIervation ~ommiflee bj the IS~ of the suoc~ding month, unle~ otherwise directed. Form STATE OF OIL AND GAS CONSERVATION COMMITt'EE o.,~:~, [~ o^,~,.~ [~ o'm~ Exploratpr_2i 2. 1NAA~E OF OPF~.~TOR Standard q~J. Core--of Calif°rnia 3, ADI)iIESS OF OPZiilATOI~ P. O. Box 7-839 4. LOCATION OF W]~LL 1400' North and 1700' West from Southeast corner of Section 33; TSN, Rgw, SB & M 50-133-20293 AND SEF1AI.. I~O. A028990 '7 If' INDiA)~, AiM)T-WEE OR T}IlBE NAME 8. UNIT,I;'Ai'~,'i OR LEASE NAME __~5.0 ]_~.dot n__.__a Creek 9 WELL NO 10. FIELD A.ND F'OOL, OR WILDCAT 11. SEC., T., H.., M.. ()BJ 'EC..~FIV 12 P}%I{MIT I";0. t3. i'{EIz>O}{'F 7'OTAL '~>}D~771{ AT' E.ND O1,' MON'F~I. CH/~iCGILS iN H()LI< SIZE. CASING AlOft C~A,iENTI}{G. ,lOBS INCLUDING DE}'T].i SET A.N~D VOLITMES LISED, PE~FOIiAT~ONS, ~$TS A:~ ~SUL'?S. FiSHiNG dOI~;. JUNK IN 110/~ A2qD SIDE-'~RACt{ED I'tOLE AND ~'Y O7~t{ SIGNIFIC~T C~.~GF~ ~ ttOL¢ CO~[DITIONS. SEPTi, OCT., & NOV. 1976 Drld. 8 1/2" ho[~_=.[~100-1~350'. Ran DIL, compensated sonic logs, dipmeter, & took SWS. Cmtd. 9 5/8", 47 & 53~ S-95 csg at 11,350' with 1300 sks of "G" cmt. CP'd at 8027' with 2200sks of "G" cmt. Install class 1!/ B~O~P~.E. and tested OK under 10000 psig. Drld 8 1/2" hole 11350 - 14226'~ Ran DiL~ FDC, CNL & GFJ~ logs. Drld 8 1/2" hole 14226 - 16300'. 'Ran Dil & sonic logs~ Drld 8 1/2" hole 16300 - 17689'. Lost & rec. D.P. fish at 17629~. Ran D~fl log' to 16947'. WELL I~0._ BR 2.21-23 . r ' ' COUNTY OF', SECTI ON I'10. TRACT -ltO. [] PROPOSED r'-I PREL INI}tARY ID] FI tiLL WELL SURVEY Pro-312 · CITY OF 73 .... TOWNS~ilP 13N RANGE 10W CZ] S.B.B. & M. F'l M.D.B. & 14. LOT NO..,,. FIELD BELUGA RIVER 252 FEET SOUTHERLY AT RIGHT A~.IGLE FRO~'~ NORTH BOUrtDARY OF LOCATION SECTION 23, AND 1818 FEET EASTERLY AT RIGHT ANGLE F.ROrl _ WESTEBLY BOUNDARY.OF SECTION 23, T13~, RIOW, SEWARD t.iERIDIAN.. ELEVATION: GROUND __ CONCRETE MAT D. ERRICK FLOOR F ' A L T E 'R N A T E O R 3 U R ~''E'y E D L 0 C A'T i O'll "LOCAT'I Oil ...... DES1 G~iATI ON LOCATION COORDINATES MOVE REHARK$ ,, FINAL , y: 2,635,432.67 · x = 319 ,,902.21 _ COORDINATES ARE ALASKA STATE PLANE .. . · . ZONE 4 · ,, ,, . , , , ...... , , , , , ., , , , . ,, , t c~ J ' j ',Sec. 23 .... + .....~ ! J SOUTH ...... ~ (~r -A~ .;~_ · ~-~ . ~ 4.. ~'a . ............ g' ',~'"'"~"*' .... 7 "~'.. ~*., .... ·.... ~..-,.;.,~ ~ .......... .-- . ~y ~, ~u~ ;.~- ~ .............. ¢~ .~_ 22~4-S /2? ~ , , ~ .... ~ ~ ~ ~, ...... , , C.C, DIV. ENGR. FILE SURVEYOR_ G, DRASKY .. HAINT. FRNN. HAINT. SUPT. DATE, NOV. ]_, 1976 DATE DATE · 'JI#TID IN TlbiNSMITTAL AND ACKNOWLEBGEblENT OF RECEIPT OF MATI£RIAL - (ALASKA) DEPT.: PLACE: TIlE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD - Fo] deal R - Roi.]ecl S - Sepia F - Fi].m X - Xerox PLEASE CttECK AND ADVISE IMMEDIATELY. COMPANY RECEIVED BY BY Form 9-331 Dec. 1973 UNITED S'I'ATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form. for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1. oil gas well ,~ well [] other Exploratory 2. NAME OF OPERA/OR Standard Oil Company of California, WOi 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) 1400'N & 1700' W from S.E. corner AT SURFACE: Sec. 33; T8N, R9W, SB&M AT TOP PROD. INTERVAL: AT TOTAL DEPTH: 16. TEST WATER SHUT-OFF '[] fRACTU RE TREAT ~[--~ SHOOT OR ACIDIZE '[] REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE CHANGE ZONES [] ABAN DON * [] (other) Sundry Notice CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA · REQUEST FOR APPROVAL TO: sUBSEQUENT REPORT OF: ir-] 11-6 to 11-12-76. 5. LEASE A208990 Form Approved. Budget Bureau No. 42-R1424 IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME Soldotna Creek 8. FARM OR LEASE NAME Soldotna Creek 9. WELL NO. sco 33-33 10. FIEkD OR WIkDC~T Swanson R~°r ~eld - ~ildcat 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA Sec. 33; T8N, R9W, SB&M 12. COUNTY OR pARISHI 13. STATE Kenai I Alaska 14. APl NO. 50-133-20293 15. ELEVATIONS (sHow DF, KDB, AND WD) Approx. 135' qr (NOTE: Report results of multiple completion or zone change on Form 9-330.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* 11-13 through 11-26-76 Drilled 8 1/2" hole 16,657 to 17,629'. Left 878' of drilling assembly fish in hole 16,751 - 17,629'. Cleaning out fill on top of fish 14,150 -~ 14,758'. Pressure tested B.O.P.E. ok under i0,000 psig on 11-13 & 11-18-76. Mud properties: Wt. 99 pcf Vis. 43-70 Sec. W.L. 5.0-5.6 cc. Filter cake 2 Solids 23-26% Sand 0.75 - 1% Subsurface Safety Valve: Manu. and Type Salinity 1155-1330 PPM Set @ Ft. 18. I hereby certify that the fore,~6~g is true and correct I /~/ SIGNED-- G. Matiuk ~//vl~ TITLE Area Engineer (This space for Federal or State office use) DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Instructions on Reverse Side Form 10-.t 03 REV. 1-30~73 Submit "Intentions" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS' (Do t~ot use this forrn for proposals to drill or to deepen Use "APPLICATION FOR PERMI-F~-" for such proposals,) WELL ~ OTHER NAME OF OPERATOR Stand. ard Oil Com~ of California~ W0i ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1400 ~ N & 1700'W from S.E. corner of Sec. 33; TSN, RgW, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 153 "KB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 15. APl NUMERICAL CODE 50-133-20293 6, g~-~.~- L~I~"'~I~.~'r'I~N AND SERIAL NO. A028990 7. IF INDIAN, ALl_OTTER OR TRIBE NAME UNIT, FARM OR LEASE NAME Soldotna Creek 9. WELL NO. SCu 33-33 10. FIELD AND POOl_, OR WILDCAT Swanson RJ..ver Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33; T8N¢ R9W, SB&M 12. PERMIT NO. 76-56 )oft, or Other Data NOTICE OF INTENTION TO: TEST WATECR SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPt_E COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) __ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSE[3 OR COMPLETER) OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Com_plete in He~r, lock Sands as per. attached program. lB. I hereby certify that tile foregoing Is true anti,correct SIGNEDG· _.-]~__~.~.j_~ "/"' 7 ~ TITLE (Tht~ ~pace for State',*o1¢lCe use) CONDITIONS OF APPROVAL. IF ANY: ~..- TITLE See Instructions On Reverse Side DA'TE - ' ' ~ Approved Copy Returned PROPOSAL FOR ?~ELL OPERATIONS, PRO 316-1 COMPLETION PROG Plum Fi. eld: Swanson River Property and Well: Soldotna Creek Unit 33-33. Surface Location: Approximately 1400' North and 1700' West of the Southeast Corner of Section 33, T. 8 N., R. 9 W., SB&M. Elevation: 135' est. G.L. Estimated 153' K.B. (Brinkerhoff Rig t~59). BlOwout Prevention Consideration:~ A. MaXim~a smticipated formation pressure: 4700 psi. Maximum anticipated surface pressure: 3850 psi assuming a gas column to the surface. C. Lost circulation: No problems anticipated. Casing: 20" conductor @ 90' 13 3/8", 68~, K-55 cmt'd @ 3380' 9 5/8", 47~ & 53~, S-95 cmt'd @ 11350' Program: , 1. Abandon bottom hole. Bring cement plug to 11200'+. (Addihional field program will be prepared after reaching total depth to-cover abandonmenZ as necessary). 2. R~n Variable Density Cement B~nd Log from'effective depth to 3400'+. Use ga.?mia ray for correlation with signature presentation on CBL. Engineering to witness. 3 InStall grease lubri6ator and pressure ~eou to 4000 psi. Condition tigno~-sulfonate mud to 65-66 pcf (50-2'00 -psi overbalance @ · 10700 ' ) . 5. Perforate the 9 5/8" casing with three 1/2" jet holes per foot. Use 4" jun~o jet with magnetic de-centralizer (22 gm charge). Using casing Collars for depth control, shoot the following intervals: 10706'-i0673', 10660'-10652', 10645'-10640', 10628'-10605', 10588'-10584' and 10580~-10564' . PROPOSAL FOR ~',FELL OPERf~TIONS, PRO 316-1 COMPLETION PROGRAM -2- 6. Run tandem casing scrapers arid scrape the 9 5/8" casing to 10710'. Run pipe slowly' to minimize pressure surges against %he foz~nation. 7. Run and hydrotest to 5000 ].}si approximately 10,710' of tubing and jewelry as per attached diagram. Run with ali: XA sleeves open. Run t~3bing slowly to minimize pressure surges against the formation. 8. Run ga~una correlation log' ~_.~d collar locator to space for packe~" depths Engineering to witness. 9. Land tubing and set blanking plug in hanger. Remove BOPE and install x-mas tree. Test tree to 5000 psig. 10. Close all XA sleeves and set Brown plug in "D" nipple. Pressure tubing and set packers. 11. Open kill sleeve at 10540'+ ~nd reverse mud out with lease crude.' Close .kill sleeve. Retrieve Broaden plug from "D" nipple. 12. ' Open XA sleeves at 10661', 10629' and 10592'. Check XA sleeve at 10540' closed_ ~ · · 13. Move off rig. Place well on production wi-[:h all zones open. I. J. EPPERSON WELL/LOCATION NO. SCU 33-3~ FI E L D Swanson River TOTAL DEPTH ~_~.i,._Q~Q0_.METHOD OF PRODUCTION _~]_=_o,,,!iDg. __ ESTIMATED O/W/G'L0_0_0/_],=0 /I_QL00DQUIP. FOR STEAM CASING Gross Footag_e APl Size Weight Grade Conductor Threads Surface Use. F~iS himg \ __ DATE 10/28/76 ESI'IMATED SPUD DATE i~l__-/[J~'?6 · MAX. ESTIMATED SURF. PRESSUF]E INJ. Coupling 38O0 PRODUCER x Computer Design For' This Well Standard Design For Field Well No. Mak. Drift Angle PSI Water String: Desi§n b~sed on mud density Ibs./~u. ft. and above max. surf. pressure Cementing Accessories Hanger Pe rfo rate d __.., ...... ', to ' M es h, . Rows, SI ots, Ce n te rs CASING UNITIZED H'EAD-___~000 PS! CWP. Bottom Conn. 10 3//4TM SOW, .r~pe Top Conn. 10:' 5000 RJ fl.~.qe 2x2 ,,, Scr~,¢ed __ Fitti,~gs ~ i o~.~_~=:,.ed 3000 psi. KOG va}ye bull plug o~ ~S~5~ ~id.e. CASING SPOOl_ ' MC MU.C outlets F! TUBING ttEAD . TUB! NG Bottom Next Total ___5_0_Q0____ PSI CWP. Bottom Conn. 10" ,5000 psi P~7 F].".o~..qe__L;Li~_? 59L Top Conn. 10" 5000 PJ Flange " Type Suspension _~affer 5DL_27_!/2" Buttress up a do:~ full bore~ ]~red for 3 1/2: Cosasco. Feet AP___LSize Weigh.t Grade. Threads Type Remarks 10,500 3 1/2" 9.3 N-80 Butfm:ess (Cross-overs, otc.) 7- 3 1/2" Cemco~ P~4G ~3~¢ke]_s w/PD valves 4 - 9 5/8" x 3 1/2" Br~,¢n Packers 4- 3 ]./2" Otis ")<A" slaves 3- 3.1/2" Otis "T" Nipples (pso ¢2, ~,~4) 3 - 3 1/2" Br~,a~ CC Safety Joints 1-.3 1/2" Ca.~o "D" Nipple 4 - Baker 3" ! D Blast Joints (~pprox. '40', 30', 25', 20') Tubing Catcher... Packer with XMAS TREE 3 Tubing Beans Header Stuffing Box__ PUMP: RODS: Grade~ PUMPING UNIT. APl Size Engine ZO.]_~,ltPrepared ....... " type.. Csg. Size "x " Type witl] __ -¢ wt. Other Fittings 2 Arm __ PSI CWP. · r~ ~s x ' of Arm Wt. Install a-t "stroke at rs. r Dwg, No. AP_-_C-114-Q_all~n-CrA7~-__) Type 1-3 " 500.0_psi WilAis._~y~._e_l Bean PSI CWP. Dwg. No. __Type. Polished Rod "x l'ype at ' of "; __' of Max. Stroke .... "Set at "Stroke and Remarks .Type Motor HP ' / :: ,-'7'" ,/ /'/~/ ' Area Supervisor _~:_;:/':5/./~ ,-.?;b. r ,¥ ~;.',./-", Sr. Drlg. Engineer% Approved I.W %1,/' Drtg. SuPt, Type ' Lpnfi SPM I'RO-;t 16-A (CD-1-75) o . i~DV~ 3~ h~oo3, 4~75o . ~:~3~o 6,250'~ ~, 6,690~' ~ . JTS. 3~" gU~ 6rd N-80 TUBING · ,7 " JTS 3"fi" SUE 5rd N-80 TUBI:;G · ' i :;At4 0 KM MANDREL ' · , JTSo 3%'" EUE 8rd N-80 TUBING ' .~CO 'fUZING ~;-. '~%~{C0 M24 MANDREL "' [:..:[ "' ::... , .. · J,S 3'" EUE ~* l,-80 TUBING. C~35CO ~q MAND~L ,'"':-: J:'-". a'rso 3%" · .. 5,'35o~..:.-- . . . . . ' J'rS~ - ~.. -.. . --'~ cAMCo ,~-4 . . - - ~ OTiS "XA" "SLEEVE ~..~ ~ o~, BRC~ ,v' ~'r~--~ · .. 2~IS "T" NIPPLZ, PosiSion ~ ~> 3~": x 9~" BqOWN PACKER , ~ OTIS "T" NIPPY, Position 39' Bi~,.BT d rS' (2.5') I · ~ 3~" ~I.S'"~~' NIP:'~;) Position ~t2. . - BR~N' '~S"..S~ETy J'l% ', ' --~ 3~'' ' x - N{U, VN PACKER , 3%" .~L3ST a'r. (30') -': ,o~o~ 1Q,70o, ',--. :'OP OF ['Iii:] il, 2o0' EUE 8rd :i-80 TUBI:;O 8rd !:o80 TUBING .EUE 8rd N~80 TU3ING - .. f &' SC U 53 -515 <' C~SING 8~ TUBING DETAIl._ SECTIOH 5:5 T SN.,R.gw. SM sr,~.NDAP. D OIL CCdP.A,xY O? CALII:OI.:2'~itt ~'m'm Z0.401 e STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TRIF (Othcr Instructs rcvcrso PERMIT TO DRILL OR DEEPEN Ia~ 'l~lCl~ OF WORK DRILL [~ DEEPEN [~ I~ ~ OF WELL 6. LEASE DESIGNATION AND SERIAL NO. ?. II.: INDIAN, AI. LOTI'EE OR '1'~ BE NAME ~T.~'I'ANCE IN MILES AND~ D1RI.~'TTION FROM NEAREST 'l'O¥,qN OR ~ST OFFICE* ~mgO~HAT~O~: , /~, R~// < ~ *; .-~ .~r~,~ J ~ATION TO NEAREST to nearest dtig, u n~t. ff any) ~:m~Nct~ F~o~ ~,xo~ac~ LOC,XTION ltOOt~%U~A }i9. PRESSED DE.ii NEAREST WELL DRILLINC;, COM~LETE~, ~ .3 4,? ...~-..>" .-;~ /~ o ~0 / ~VATIONS (Show whether DF, RT, CR. etc.) -/ ~ ....... / ~ - PRO~SED CASING AND CEMENTING PROGRAM 8. UNIT FARM OR I.EASE NAME ~.~--o z.~o/~ ~ c,,~-e ~_r~,,/-- 9. ~LL'NO. .. 3~-zz , 10. FIELD AND I~O~. OR WILDCAT ~~2,~ . ~ ~.~ ' ~ Io/c~ ~. I1.SEC., T,, R., M., (BOTTOM HOLE OBJECFIVE) 12. . ., .. '~ lO% ooo '' Amount' I~Z~'c3, {30~ 1,7.NO.ACP. ES ASSIGNED ., TO THIS WELL 20.ROTARY OR CABLE TOOLS .. _~,,/z?- 22.. APPROX. DAlE WORK WILL START · . .7-/',57-:'76 ............ , ~ $1Z~OF L;OLE SIZE OF CASING WEiGItT PER FOOl' GRADE SETTING DEFTH . Quantity of cement · " ~-o''/ ~av,~,/~q// _~0 ' ~ ~/,/~ . . , ...: , ..... . ...:,z, .n_~_e~ ~ x '" ." ,. . .720 " .... ', '- ..... ..... ~ ~ ~., ~: '~.- ..., : lN ABO~ SPACE D~CRIBE PRESSED FROGRAM: If propo~ ~ to deepen give data on present p~ducdve zone and pressed new productive zone. If pmpo<fi is to drill o~ dt-e~n d~fion~y, [~ve pertinent data on $~bg~face locations ~6?~d ~0~' d ~;~ fi :,¥} ';7~'.?~ :':. )e[ti~ depots. Give ~lowout preventer pmg~am. ?.>','~7.~,}' :..; .7 .- thai t!'-e Foregoing is True and Correct ~,~~~_, ,, C ~/e ~ f for State office use) CORE CHIPS REQUIP. ED ! [] xo },IUD LOG [] YES D!~R'IONAL SURVEY Rt".QUIKED PERi:-%~I' NO ................. CONDITIONS OF API'ROVAL. 1F ANY: [~ NO t OTHER REQUIREMENTS: NUMERICAL CODE APPROVAL DATE ....... TITLE __ Instruction On Reverse Si(to DATE WELL SECTION i~0. TRACT !~0. Lr~ PROPOSED E] PRELI~iNARY E:~ FIliAL .: WELL SURVEY Pro-312 SCU 33-33 COUNTY OF. KENAI CITY OF 33 ~_TONNSItlP 8N RAttGE 9 W I]~]S.B,B/. & H. [Z] H.D.B. & H. LOT HO. FI ELD Swafison River ]700 Ft. westerly at.right angles from East boundary. LOCATION Sec. 33, and 1400 Norther].v at riflht angles from South boundary Sec. 33, T.8 N., R.9 W., S.M. ELE~fATION: GROUND CO~tCRETE MAT DERRICI( FLOOR A L T E R ~1A T E 0 I~ S U R V E Y E D L O C A T I O N LOCAT I O~ DE~ i G~,~ATI O~ LOCATIOi~ COORDI ~AT[8 MOVE . ~ro, posed N 22,097,260.72 E 2,023,113.30 IS: 8¥ATi ON BEA~ ! NG D i STA.~ C E $ i~E C081 C.C. DIV. ENGI). FILE SURVEYOR HAINT. DATE DATE ~:."'.. ': :'",'.'? ' -' . :~'~': ':Z:-T ':---- .... >':.:::iF-": ':,..,,t.,.:.._ /:..?" '.:,,,,-.::,,]::::.: ~ ': DATE PRd. 312 (2500-CD. 1- 58) Wednesday, October 20, 1976 Re' Socal #33-33 SCU Socal is drilling the SCU #33-33 about 940' east of the Swanson River Unit Boundary, where there is a change of ownership. The hole is drifting westward. Jack Thoene called and was told that the well could not be drilled less than 500' from a Unit boundary. He said that Socal was going to run a deviation survey. I requested a copy for D.O.G. HWK I .LIN/? VN.L 0 ~ I I _.1 ! 0668~0-V £-£ (o'3av-qvoos) 3~zs3 eao~xv .bg£egO- ¥ C Cl~lOaX~ 3 .' · r¢-z~'e o · ££-I~, ££-IZ~ ~'z'~ 66£8g0- V > ~ OO~V-qVOOS ~:'C,~ ZZOSZO- V 96£8g0-~ I£ OOMV-qVOO,~ ZZ.-0~:- 9 ~o~ ~o. P--~ STATE OF ALASKA suB~rr 1~ DUPLICAT~ OIL AND GAS CONSERVATION CO~I~EE 50-133-20293 MONTHLY REPORT OF DRILLING A028990 AND WORKOVER OPERATIONS O~L ~ ~*, ~ o~a~ Explorato~ ~LL ~LL ,, , '~. N~E'~F OP~TOR ' ~. ~iT'F~ Standard Oil Company of California, WOI Soldotna Cree~ P. O. Box 7-839, Anchorage, Alaska 99510 33-33 '4. LOCA~ON O,F ~' ~0. FIE~ AND P~L, OR WILE 1400' North and 1700' West from Southeast corner of ... Swanson River Wil~ Section 33, T-8N, R-9W, SB&M n. sEC..o~~ ?'' R'' M.. (~O~O~ .~ Sec. 33 T-8N, lZ. P~IT 76-56 REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/Nq~ VOL~ USED, PERFORATIONS, TESTS A/N/) RESULTS. FISHING JOB~. JUNK IN HOLE A~ND SIDE-TRACKED HOLE A]~'D A2WY OTHER SIGNIFICANT C~IA_NGF~ IN HOI.~ CONT)ITIONS. August 1976 Drilled 12 1/4" hole from 3400' to 11,100'. density logs. Ran D1L and compensated Neutron 14. I hereby certify tl~at the and correct G Matiuk Area Engineer ~:.. NOTE -- Rel)orI on this form is recluired for each calendar month~ regardless of the status of operations, and must be filed in duplicate with th e oil and gas conservation committee by the 15th of the succeeding month, unle~ Otherwise directed. 1;'Grin approved. Budget Bureau No. 42-R356.5. UNITED STATES ,ND Grace ..... _Au_characje .......... DEPARTMENT OF THE INTERIOR LEASE NUMB£R .... ~_0~9_9_0 ........... GEOLOGICAL SURVEY UNIT .... Sol-do~-Cre~ ....... LESSEE'S MONTHLY REPORT OF OPERATIONS S~ate ...... ~.~-¢-~_~-¢- ............... Co~tU Kenai F~e~a Swanson ~ver ...................................................................................................... T~e follow~ng ~s a oorreot repor~ o/operations a~d prod~otion (~nctud~n~ dr~ll~ and prod~o~n~ wells) [or t~e mo~th o[ ..... BJ3___~_~__~_~g_O .......... , 1~___7~, ............................................................................ ~$e~t's address P,~. BOx 7-839 ......... Compan~ Standard-~~O~°mpanY of ............................................................................................................. .... ..... ......................................... ................. P~one ......... ~J~z_~_~_~_~_ ......................................................... ~ent' s title ~_~_~_~_.~_~_~_~_~_~_~_~ ......... .................... REMARKS I~EC. AND BARRELS OF OIL GRAVITY CJASOLINE I~rATER (If (If drilling, depth; if shut down, cause; 1~ OF ~ TWP. RANGE WELL DAYS CU. FT. OF GAS (~AI, LONS OF BARRELS OF NO. PRonuc~n (In thousands) date and result of test for gasoline i~ECOVERED none, so state)content of gas) ,, 1/4 of 1/4 of :. 33 T8N R9W SCU 33-33 d]illed 12 1/4" hDle 62;30' to 8829'. SE Sec NoTE.~There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this fomn is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) u.s. GOVERNMENT PRINTING OFFICE:1964--O-729-784 R]~V. 3-1-70 STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS o,L [] Gs. [] 0?.z, Exploratory ~'I~LL W[:LL 2. NAME OF OP]~:~kTOR Standard 0il Company of California, W0I ~. ADDRESS OF P.O. Box 7-839, Anchorage, Alaska 99510 4. LOCA~ON O'F WELL 1400' North and 1700' West from the Southeast corner of SEction 33, T-8N, R-9W, SB&M DESIGNATION L~SE AN'D A INDIA~, A~T~E OR TRIBE Soldotna Creek Unit ~ ~ WE~ ~'O 33-33 Swanson River Wildc; ii. SEC.. T., R., 5~ ,I (BO%~'OM HOL3g OB,rSCTrVE) Sec. 33,T-8N,R-9W,SB&M PIgP,.M IT NO. 76-56 13. REPORT TOTAL DKPTH AT END OF MONTH, CPLA~NGF_,S IN HOLE SIZE, CASING AND C~H2VlENTING JOBS INCLUDING DEPTH SET ~xKD VOL~ USED, PEP~FORATIONS. T~STS ~ F~ESULTS. FISHING JO]3~S. JUNK IN HOLE A_ND SIDE-/q14%CKED HOLE AND ANY OTHER SIGNIFICANT C[4ANGES IN HOL~ CONDITIONS. JULY 1976 Commenced operations 4:00 P.M. July 24, led 17 1/.2." hole from 90' to 3400'. Ran DiL and sonic logs. ~em'~ted 13 3/8", 68~, K-55 cas£ng at 3380' with 1500 sacks of class "G" cement treated with 2.4% gel. Ce- ment returns to surface. Installed class IV B.O.PoE' and tested ok under 5000 psig. Drilled out Cement from 3291 - 3380' and cleaned out to 3400'. Please treat this information as confidential. __ NOTE--Report on this form il required for each calendor month1 regardless of /he status of operations, and must be filed in duplicate with th · oil and gas conservation committee by the 15th of the sueceeding month, unle~ otherwise directed. PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Swanson River Property and Well: Soldotna Creek Unit 33-33 Surface Location: Approximately 1400' north and 1700' west of the southeast corner of Section 33, TSN,R9W, SB&M. Elevation: 135' est. G.L. Estimated 153' K.B. (Brinkerhoff Rig #59) Blowout Prevention Considerations: A. Potential Problems 1. Gas and Water Entries: Gas sands may be encountered at any depth below the shoe of the surface casing. In the early Sixties the surrounding wells were drilled using anywhere from 83 pcf to 98 pcf mud weights and encountered no prob- lems while drilling to and through the Hemlock sands. There is a high head water entry known to exist in the field, but was not indicated to cause trol~le while drilling l]~e surrounding wells. Since the time these wells were drilled the productive Hemlock sands have been depleted and a pres- sure maintenance program initiated. Nearby well, SCU 343-33 is currently injecting gas at less than 5500 psi into the Hemlock sands. This represents a gradient of .55 psi/ft or a mud weight of 79 pcf.to equalize. After the 9 5/8" casing is cemented through the Hemlock inter- vals little is known about the deeper measures. An early well SCU 22-32, 6 miles to the south and separated by a major fault encountered pressures of 9121 psi at 14,100+. While these pressures are not anticipated, caution should be used at all times. Anticipated pressure at this location should not exceed a .5 psi/ft gradient or 8000 psi. Planned mud weights will exceed even the pressures encountered in SCU 22-32 by 400 psi. Caution should be exercised not to swab the hold on trips. Gas and water entries, while not anticipated, can cause severe hole Problems and the mud system should be carefully monitored at all times. Proposal for Well Operations pRO 316-1 Drilling Program 2. Lost Circulation: No circulation was lost in the surrounding wells while drilling to and through the Hemlock interval. Be- low the Hemlock little information is available. Lost circu- lation materials will be kept on hand at all times. 3. Precautions: Any kicks should be handled by our normal pro- cedures. Drilling crews should be made aware of these methods prior to spudding. Kick and BOP dril!s should be practiced at regular intervals and noted on the tour sheets. Care must be exercised at all times, and especially when going in or pulling the drill pipe.. Scheduled mud weight will adequately control pressures known to exist in the area. B. Maximum Anticipated Formation Pressure: 8000 psi based on a .5 psi/ft gradient. C. Maximum Anticipated Surface Pressure: 7200 psi assuming a gas column to the surface. Blowout Prevention Equipment A. Class III, 5000 psi on the 13 3/8" casing. B. Class IV, 10,000 psi on the 9 5/8" casing. C. Install and test BOPE per "Operating Instructions D-17". Estimated Depths and Correlations: Marker Subsea Vertical Drilled pepth ,~epth pepth H1 Top Hemlock - 10,380' 10,533' 10,533' Base H 10 Sand - 10,750' 10,903' 10,903' I Point * Faulted ...... Top Jurassic - 10,850' 11,003' 11,003' T.D. - 15,847' 16,000' 16,000' Missing due to Fault "E" Proposal fOr Well Operations PRO 316-1 Drilling Program Pr__~_~ram 1. Drive 20" conductor pipe to 80'+ or as deep as possible during rig up. 2. Drill for 13 3/8" casing to 3400'+. Maintain drilling fluid per attached drilling fluid program. 3. Condition hole for logs, Take a one-half gallon mud sample prior to pulling drill pipe for logs. Run the following logs: a. Dual Induction - Laterolog from effective depth to shoe of 13 3/8" casing. Use linear scale for the 2" = 100' track and logarithmic scale for the 5" = 100' track. Use 10+ MV, SP scale and 0.-50 o~n-meters for the linear resistivity scale. b. SP-BHC Sonic with integrator from effective depth to shoe of surface casing. c. Compensated Neutron-Density log over the s~ne interval to shoe of cond. if gas-is indicated. 4. Cement 13 3/8',, 68#/ft, K-55 buttress casing at 3400'. a. Centralize casing at and above the bottom 3 joints. b. Use float shoe and duplex (stab-in) collar two joints off bottom, c. Cement through shoe with sufficient Class "G" cement premixed with 2.4% gel, by weight of water, to obtain cement returns at the surface. If returns are not received at the surface, do a top job. Note: Class "G" cement premixed with 2.4% gel, by weight of water: Yields - 1.86 ft3/Sx cmt Water requirements - 1.36 ~ft3/Sx cmt Gel requirements - 1.5 lbs/ft3 of water Slurry weight - 98 pcf 5. Cut off 13 3/8" casing below top of cellar (ground level) to allow · the top flange of the 'tubing head to be above ground level after completion. 6. Install 13 5/8" - 5000 Psi, SOW casing head. Test lap weld to 2500 psi. Proposal for Well Operations PRO 316-1 Drilling I'rogram 7. Install Class III, 13 5/8" - 5000 psi BOPE per attached design sheet.. Test BOPE, lines and manifold to'5000 psi per "Operating Instructions D-17". DOG and/or USGS to witness BOPE tests. 8. Drill out cement in 13 3/8" casing to within 10' of the shoe. Pres- sure test 13 3/8" casing to not over 2500 psi. If test is okay, drill out the 13 3/8" shoe. 9. Drill ahead in 12 1/4" hole to dull bit near t1,100' , appxoximately 200' below the base of the Hemlock 10 Sand. ao Follow mud program per attached sheet. b. Take single shot surveys at each dull bit. 10. Condition hole for logs. Take a-l/2 gallon mud sample prior to pulling dzill pipe for logs. Run the following logs: a. Dual Induction - Laterolog from effective depth to shoe of 13 3/8" casing. Use linear scale for the 2" = 100' track and logarithmic scale for the 5" = 100' track. Use 10+ MV, SP scale and 0-50 o~n-meters for the linear resistivity scale. b. SP-BHC Sonic with integrator from effective depth to shoe of 13 3/8" casing. c. Compensated Neutron-Density log over the same interval to 8000'. d ~ SWS Note: Have High-resolution Dipmeter on location. 11. Cement 9 5/8" 53.5 ~/ft and 47#/ft, P-110 Buttress casing at effective depth as follows: a. Use differential fill-up shoe and collar. b. Use a stage collar at approximately 8000'. c. Use centralizers across the Hemlock Zone and above and below the stage collar near 8000'. d. Cement in two stages as follows: 1) Shoe job - Use sufficient Class "G" cement treated with 3/4% CFR-2 to reach near 8800'. Mix to a slurry weight of 118-122 pcf. 2) Stage collar - Use sufficient Class "G" cement pre- mixed witD 2.1% gel, by weight of water, to lap into the 13 3/8" casing at 3400'. Proposal for Well Operations PRO 316-1 Drilling Program Note: Class "G" cement premixed with 2.1% gel, by weight of water: Yields: 1.68 ft3/Sx cmt. Water requirements - 1.18 ft3/Sx cmt. Gel requirements - 1.3 lbs/ft3 of water. Slurry weight - 102 pcf. 12. Remove BOPE and land 9 5/8" casing. Install 13 5/8" 5000 psi bottom flange X 11" - 10,000 psi top flange tubing head. Test secondary packoff to 10,000 psi. Install 13 5/8" - 10,000 psi ]3OPE. Test BOPE to 10,000 psi per "Operating Instructions D-17". 13. Drill out cement and stage collar and clean.out to within 10' of the 9 5/8" casing shoe. 14. Run Neutron-Variable Density-Cement Bond log from effective depth to above top of cement from the stage collar job. 15. Pressure test 9 5/8" casing to 3000 psi. 16. Drill ahead in 8 1/2" open hole to 16,000'. Note: a. Continue to follow mud program attached, and take single shot surveys at each dull bit. b. Install Mud Loggers when drilling out 9 5/8" shoe and maintain to T.D. Mud logging specifications to be provided in the Formation Evaluation section. c. Be prepared to core as directed by the onsite Geologist. 17. Condition hole for logs. Take 1/2 gallon mud sample prior to pulling drill pipe for logs. Run logs as directed in the Formation Evaluation section. 18. A program to either complete or plug and abandon will be pro- vided at this time. ODtim~ Properties To 13 3/8" CSG PT SCU 33-33 DRILLING FLUID PROGR3d~ SP[ANSON RIVER FIELD From 13 3/8" CSG PT. To 6000' From 6000' To 9 5/8" CSG PT. From 9 5/8" CSG PT. To T.D. .'nd ~ype Reclaimed Mud or Extended gel Lignosulfonate(2) Lignosulfonate Extended gel Weight, pcf 68 - 78 70 - 75 75 - 98(.5) 96 - 105 Funnel Viscosity, Sec/qt 45 - 200(1) 35 - 38 40 - 55 40 - 60 · Fluid Loss, cc, API ...... Less than 10 Less than 10 Plastic Viscosity, cps --- 15 - 25 30 - 40 30 - 40 Yield Point tb/100 ft2 --- 8 - 15 8 - 15 12 - 18 Gel, lb/100 ft2 10 min(4) 4 - 6 6 - 8 6 - 8 pH 8.5 - 10.5 8,5 - 10.5 9.0 - 9.5 9.0 - 9.5 Solids Content, % 4 - 15% 6 - 10% 10 - 22%(.3) 23 - 28(3) REd,ARKS: (!) High viscosity needed for surface drilling. Reduce when. below 1000'. ') Chemically inhibit mud with lignosulfonate concentration up to 12 Ib/bbl below 6000'. (3) Maintain Mud Wt. and solids according to formula: Optimum. Solids % = .46 (M.W. pcf - 45). (4) Gels must not be progressive. (5) Do not make rapid mud weight increases to this mud system without pilot testing. Maintain 5% Diesel content in mud below 9000'. Note: Have high pressure-high temperature fluid loss detez-mination equipment on hand after drilling out the shoe of the 9 5/8" casing. SCU 33-33 DATE June 11, 1976 WELL/LOCATION NO. Swanson River ESTIMATED SPUD DATE . J_u_~f_15~_ 1976 FIELD TOTAL DEPTH _1~6_,_0/)&3 .... METHOD OF PRODUCTION -------F--lowd~9- MAX. ESTIMATED SURF. PRESSURE 7200 ESTIMATED O/W/G___ / .... / EQUIP. FOR STEAM No __ INJ. No__ PF1ODUCER --- PSI CASING Gross Footage APl Size Weight Grade Threads Couplinfl Conductor 80 ' 20" Heavy Wall Welded Surface 3400' 13 3/8" 68~/ft. K-55 Buttress Requires: Float shoe; Duplex Collar (stab'in); 10 - 13 3/8"x17 1/2" Centralizers; 2 - 13 3/.8" st p r' s Water String: Design based on rnud density 98 lbs./cu. ~. an~JZar~gve max. surf. pressure 5,000': 9 5/8" 53.5 S-95 Buttress 6,700r 9 5/8" 47.0 S-95 Buttress 11,700 ' Requires: Stage Collar Cementing Accessories Stop rings; Cornputer Design For' This Well Standard Design For Field Well No. 5+ Max. Drift Angle -- [3 D rq o 9 5/8" Buttress differential fill-up shoe and collar; (Buttress); 25 - 9 5/8" x 12 1/4" centralizers; 4 - 9 5/8" Liner Hanger Perforated ~ ', CASING ~ /t/.~T/~ ~ HEAD: CASING SPOOL to ', Mesh, R ews, SI ots, Ce nters, .~ 5:000 PSI CWP. Bottom Conn .... .13 3/8" _FzO_W_ Top Conn.__l~_~_/8" - 5,_O0__0_psi R J F].an~t¢ ", 2 - 2" threaded Fittings __.__:L:~::t. kr_~e-~]~~O_0__~_si: :~/O_G va].ve3, h~aad_ed__bl.zll_.i~ . MC MUC outlets TUBING HEAD TUBING Feet Bottom Next 10~000 PSI CWP. Bottom Conn. : _l_3 5./8" - 5,0Q0__p~.~la~._cj_e Top Conn.~ 11" - 10 ,000 _P~i RJ Flat, ge ", 2 - 2" FJ~ln~e~ s_id~__QlLt_~e_ts Type Suspension APl Si ze We__ight Grade Th rea ds Ty Pa Re ma rks (Cross-overs, etc.) Total Tubing Catcher Packer with XMAS TREE __" Tubing Beans Header Stuffing Box PUMP: RODS: Grade__ PUMPING UNIT. APl Size Engine " type. X ..... Arm ,, # wt. Arm Csg..Size " Wt. Install at Type with __ "stroke at Other Fittings PSI CWP. Dwg. No. Type ." PSI CWP. Dwg. No. Type Type Motor HP Type. Polished Rod ' of "; Max, Stroke "Set at Remarks Type at ' of "Stroke and ' Long SPM Prepared By Area Supervisor Approved by W. D. SAUER ~/~!!/~_6 _ Drlg. Supt Sr. Drlg. Engineer. PRO-316-A (CD~1-75) Prlntod In U.S,A, 5000~ j 113 I;'-IOO00~ I I ~,~-'~oooo~' i ~x-~5~ .... ~)' f I~'(-~oooo,,~ I .......... ~ l~-~ooooil , - ~ xt~2_.~_.~ ..... ~, ..................... ~J ;.Z ~ .... ~135/a".lOO. OO~ BX-159 ' DOUBLE STUDDED ADAPTER ~~-.~ ~-'-T"-fq .. ~./ ........... ~_ . ~.~ , ~,,.,,.,ooo~~~t~ ~'. ~-A~T0~ 2"-I~000~VALVES B3'/.' 5oo°:~ ~x-~se 2_3,,_10000~ ~ ..... DOUBL~ STUDDED ~ , I~"- SO00 m~ DOUBLE STUDDED ~'-', ooo,o~ i'/ ~ ~,,~-~oo~,- ..... ~':,oooo~ ~1 ' _,, ..~1~ VALVE W BULL PLUG I~ 5000.,; SOW- ~ - . }'-~Y'Dr-~, IL G K 5000~ oooop. -BX - 15~1 KILL LINE 2- 2"-IO000~VALVES EITHER SPOOL OR DOUBLE' STUDDED ' ADAPTEIq / KERO TEST 'lION VALVE .BX-160 BULL PLUG w/.~' MUD .CROSS TBG HEAD OUTLET CASING HEAD I/V£L L' HEAD/-/00H- UP ,~. 15~' CASING.- .. .._ / 20!'. i% , '"" '~' '"~", 'I' i '~" ~-" ' '~' . . , o ,~'['...r. ~ ~,.~ CHOKE LINE BX 159 'DoUEILE STUDDEOADAPTER EI× ,58 2" ~ ~'"'~ 2"- 5000 ~ VALVE BULL PLUG · 1~-5000 psi SOW CL,45,S' .Z~~, .0..'~~-. Divtsion of 0tl and Gas 3001 Porcupine Drive, Anchorage, Alaska 99501 June 22, 1976 Re: Soldotna Creek Unit 33-33 Standard Oil Company of California State Permi t rio. 76-56 R. M. McKinley Area Engineer Standard Oil Company of California P. O. Box 7-839 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 33, Township 8N, Range 9W, SB&~I. Well samples, core chips and a mud log are required. A directional survey is not required. t4any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- ment of FiSh and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prol mul ga ted thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to conmmncing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. ,lune 22, 1976 ~n the event of suspension o~ abandonment please gtve this office adequate advance notification ~ t~hat we may have a witness present. ~ O. K. Gilbreth, Chat~n Alaska Oil and Gas Conservation Ceaeittee Enclosure cc: Oepartment of Fish and ~ame, Habitat Sectton w/o encl. Oepa~t of Envt~tal Conservation w/o encl. Oepar~nt of Labor, Supervisor, Labor Law Compliance Division w/o encl. Standard Oil Company of California, Western Operations, Inc. P. O. Box 7-839 Anchorage, Alaska 99510 June 16, 1976 Permit to Drill Exploratory Well - SCU 33-33 Swanson River Field, Alaska Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Gilbreth: Standard Oil Cc~pany of California proposes to drill the subject well at a location as shown on the attached plat. For your consideration and approval we suhnit, in triplicate, State of Alaska Oil and Gas Conservation Committee form, "Permit to Drill or Deepen" and our check in the amount of $100 which covers the necessary filing fee. We are also filing the necessary application with the U. S. Geological Survey for their permit. If further data is required, please advise. ~ Very truly yo~s, JET :nh Enclosures Form 10-401 * SUBMIT iN (Other ir.:t, P,~V. 1-1-71 re¥orse la: TYPE OF WORK SI'ATE OF ALASKA OIL AND GAS CONSERVAIION COMMITTEE 't E ·.ri PERIV~'I TO DRILL OR DEEPEN DRILL ~ DEEPEN [~ b. TYPE OF Wf,;LL eli, (;AS SIN(;I.E MULTIPLE WZLL [~] W,i:LL [~ O'mUR Exploratory zoNz D ZONE [~] 2. NAME O!: OPERATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPI';RA'fOR P.' O. Box 7-839, Anchorage, Alaska 99510 6. J.,I,;ASE D},.SI(;NATION AND SI';I(IAL I,40. A028990 7. Il" INDIAN, ALLO'I'TEI~ OR 'fRIBE NAME 8. UNIT FARM OR LI,iASI'; NAME Soldotna Creek Unit 9. WELL NO. 33-'33 10. I"II:;LD AND POOL, OR WILDCAT Swanson River Wildcat 1l. SEC., T., R., M., (IIOTTOM IIOI,E OBJECFIVE) 4. LOCAT!O.U OF WEt. L 1400' North and 1700' West frora $oor}xeast corner At surface of Section 33, T8N, R9W, SB&M At proposed prod. zone 13. DISTANCE IN .~qLE,,, ;S ANDi? DIRI~]TION FROM NEAREST TOW OR POS]' OFFICE* Approximately 17 miles from Kenai. Sec. 33, T-8N, R-9W~ SB&M t4. BONDINFOP, MATION: Statewide $SL 6223435 TY?~Nat ionwide Surety and/or No. SLG205862 15. DISTANCE F'ROM PROPOSED * ~ ~ ~ ! 16. No. OF ACRES IN LEASE LOCATION TO NEA REST c3/.b D [ PROFERTY OR LEASE LINE, FT. . [ (Also to nearest dr/g, unit, if any) ~ 2400 18. ~~~~OCA'r,ON ..... ' ck,,eh / DEPTIt ..... , ,. ....... c 1100 ........ 19. PROPOSED TO NEARFS ,' YELL DRILLING, JOMPLETED, ] westerly fro~ OR A_PPLIn) t:O~, l:~' 16,000 ' SCU 343-33 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Ap_p_roxim:a&_e.2iL 135 ' ground level 23. PRONDSED CASING AND CEMENTING PROGRAM $100,000 amount 150z000 17. Ne. ACRES ASSIGNED · TO ~ItlIS WEI_I. 80 ' 20. ROTA'R¥~I~6-A-~'LE TO(~LS · Rotary.. . 22. ~kPPR~x'~;('I'E {VORK WILL START L_ 7~_k5~_~__ MZE OF HOLE 17 1/2" 12 1/4" 8 1/2" SIZE OF CASING } WI.lIGHT PER FOe I 20" .'-Ia avy wall 9 5/8" 3 5 s 47~- 7" GI~ADF K-55 P-Il0 P-!10 SET[lNG DEPTH 80=+ 3400' 11,100' 16,000' - Driven Quanlity of Sufficient to fill to surface Shoe--8800'. C.P' 8000[ to lap of 13 3/8" shoe at 3400'. Liner. Sufficient cement to fill 10900' above lap. We propose to drill SCU 33-33 as per attached program. Please consider this exploratory well as confidential. IN ABOVE SPACE DESCRIBE PROPOSED PI~OGRAM: If propo~! is to deepen give data on present productive zone and proposed new productive zone. If propo~l is to drill or deepen dixection;xlly, give periinent data on sub~urlhce locations and measured and true vertical depths. Give blowout preventer program. 24. I kereby centre- that the Foregoing is True and Co~rcct SIGNED R.M. McKinley DNI'E, ~TLE_Area Enqineer ICl'his space for State vfficc use) £XONDITIONS Ot: APPP, OVAI.. IF A NY: SAMPLF2.'.'.q AND CORE CIIiPS REQUIRED MUD t. OG l~ vrs [] No kt] vl:s [] DIRIiC'f!ONAL SURVEY REQUIRED OTHER REQLilREMF. NTS: sa.mples & mud 1o9 below shoe of 9 5/8"_ cs~. A.P.I. NUMERICAL CODE 50-] 33-20293 PERMIT NO,__16-56 , APPROVAL DATE__ APIYOVED BY. ._ 'ri'tEE_ Chairman ee Instruction On Reverse Side June 22, 1976 _ ____D^TV,. Juno_ 22, !976 ---- CHECK LIST FOR NEW WELL PERI-tiTS bO j d o !. I-s the permit fee attached . . 2. Is well to be located in a defined pool .... 3. Is a registered survey plat attached ~. Is well located proper distance from property line . 5. Is well located proper distance from other wells . Company JO (Z~ / Yes No Remarks ~. ts sufficient undedicated acreage available in this pool ~' ,s well to be deviated .... B. ts operator the only affected party . . ..... Can permit be approved before ten-day wait · ,3. Does operator have a bond in force ]. Is a conservation order needed . . 2. Is administrative approval needed ........... 3. Is conductor string provided ............. Is enoumh cement used to circulate on conductor and surface 5.i .lill cement tie in surface and intermediate or production strings 6. i~..~ll cement cover all known productive horizons ...... 7. Will surface casing protect fresh water zones .... B. FIill all casing give adequate safety in collapse, tension & burst . 9. Does BO?E have sufficient pressure rating ....... '-dd~ tional Requirements' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpler finding information, information, of this nature is accumulated at the end of the file under APPENDIX... No special'effort has been made to chronologically organize this category of information. Ol F 1 E i~ D .... ::~:::'i::',i~:.:::~ . ':..,~ ......i:&'. ,~', ... '-, .....~- :!..:::": ~::~:' :~' ~ t2.,.~ 0,50 !2.30 i~!~ .200 0.0(~o .10 0.30 ~:::::~':::::~ ~?:;'~:~:.. ~:~:~:~:~ ~:~:":::~:~'~;::~::a:: ':~2:~:i':~:I: i:~:~'l'~'~?":::';:~,: .. o.oo o.,~o 0.25 ....... :::::::::::::::::::::::::::::::::::: :~?;.: ?~:5~5:~ ~:~:?::~:":::~:~'~?:~ "::::: :"'~::'~:~ ~::' '"":":' ~:"::::~' "~;:::::: "~::::~: '"~:::~"~ ]~::t~'~;. ~'"l~.. ~,~::A ~:~ !~!~~ .... :::::::::::::::::::::::::::::::::::::::: :::~i~::::: ".':":::: :¢.'!: '::::: ~¢~: :'~: ::: ~( '3~::.;~.:~ '"": i~5~5 :i :~:~ ::~::' 1:.,. I001~.0 10015.0 1007~ .0 10081,0 100~5,0 10087.0 t00~9,0 .. 10091,0 10093,0 i. 0095,0 0.0 :::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::: :5~::;.'.'~ ::?:;":::::t;;:: ::::: ::::::::::::::::::::::::::::::::::::: :: ~:::: :::::::; ::::::: :::~::::: :: !: :~:!:i:: !:f'::~,+i'! ::! 10097.0 0,0 :::::::::::::::: :::::::::::: ::::..'..:: ::..~:;+i!?. :....:: g~ ::::::5:::: ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 10099,0 0,1 ,:.:.:. :.: .:..:.........:... ::.... :...~....:.....:..: .., ................. :~ .....~. 1010i,0 t !3.2 101 37,0 O, 7 i'i, !!:?'. ?.i:.!::! 10139,0 0,2 lOiii,O 0,0 · ':' !~:i:: :::: :: ::!: ':': ':: ':'::: 5'"'q::::' ;~:' :::° i~::::: iSi~!i:i I: ~:~::~.i::':' ':::::~/::' ::::: :::i4~.::~.: ii:':': .:i::5':::':::i .,...........: o...:....., c....;....:..... · ...... ............ · 10143.O 12.4 10.2 100 33 100 48 7~.14 l Oo 4e, 7o. O~ !oo. 42 7 ~:~. 02 1 O0 ~0 75.9'1 'i 0(0 3t;,,~. 75- 92 I O0 25 75. i O0 26 75.. 79 1 O0 20 75.73 ~':0 28 75. oo lO0 21 100 5 75.42 'i0.0 3 75. ~0 lOtJ 4 75.3d lO0 t O 75. ~J iO0 1~ 75.28 ~s. '2o I00 2I 75.13 1 O0 !9 75.. 07 1 O0 18 75. O0 i.8::0 I. 3 74.89 100 I I 14. le I O0 I I 74 . 34 ~,:::l..(.~. 0 2 7 '<~., '28 t':i .. C & 4.:20 4"20 4. ;;:0 4.2(} 4.20 4- 2'0 4.20 4.20 ~. 2(t 4.20 4.2O 4.20 4.2(1 4.20 4.20 4.20 4.20 4.~0 4.20 '4.20 4.20 ~' 20 4.20 4 . 20 4.2'0 4.20 4.20 4.20 4.20 4.20 4.20 '4° 20 10i49.0 0.5 I t.7 100 10151,0 0,5 11.6 100 t0153,0 0.5 ·I1,5 I0155.0 0.5 ! I .5 100 10157.0 0,6 f2.0 100 I0161.0 0.4 I!.I i00 loth3,0 0,0 8,3 1 O0 ::::::::::::::::::::::::::::::::::::z~:::::.:::: ::: ~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~.~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::: ::: :::: ::: :: ::::: :::::::::::~:::: : 10167.0 0.7 12.2 ~00 10169,0 0.2 t0,3 I00 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: :::::: :::~ ::::::::::::::::::::: ::: ::::::::::::::::::::::::::::::. :::: :::::::::::: ::: ::::::::::::::::::::::::::::::::::::::::::::::::::::: :::: g::::: :: :::: :::?: lOi?l,O 2 14.0 10I'~5.0 t 12,7 lot o 1 t 2.9 1 o 0 iOlai.O 0.4 11.2 lO0 ...................:.:.:..::........:.:..:. :<. :.:. :..: .:.... :;:... .... 10183.0 0,2 10,6 100 :::::::::~:::: ::? :?:: :: ::::::::: ::: ::~:: 57:~:~/;:!:: :":::~::i:~::~a ~:::~ :i:: 5::?:: :::: ~:~:~::5:::i:::::5:5:::::::::::: :::i::::::::::~:::?:~:: ::::~:::::::~ :: ?'::::: :' .:~:::: :: ::~::~:::~ ":::?:::',:'~; :~:::~ ::::: :::i::i ::J:: ::/::: i: ::i :::::::::~ 5.::: i ::? :::::::':; · ....:. :..:. :.........>:..z:.:..;......?.. ,:...;. ?.... ,%........:...,........... ~...... · ..... ... ?............. -... [0187,0 0.3 i0,9 I00 :: ::::: :~:~::!::~:: :::::::T: ?~:~7%:: ~ :'~::: ~¥:!~:~: :? ~ ::: :?::!O~:~::::::::::::: ::::::~::::::::: ::'~::::::: ::::¥ '~':::::::::::::::::::;:::::::::::::::::::::::: ::' '~:::::::: ':: ::: ::5:::::" j0i89,0 0.3 ti,0 100 ~0~9i,0 0.5 II .5 1.7' l? 7t I9 71. ·5_7 lb tl .4o I2 7t.34 :?4: 7I, Ii 30 71.0~ 23 70,9'4 1~ '/O.84 17 1-9 1! 15 15 4 ..20 4.20 4:. 20 4.20 4.20 4.2O 4.:/'0 4.20 4'_.20 4.20 4.20 4.20 4.20 4.20 4.20 ~. 20 4.20 4.20 4.2{'} 4;. 20 4.20 4.20 4.20 4,20 4.20 4.20 4,20 4.20 4.20 .4.20 4.2o 4.2O 4.20 4.20 4.20 4.20 i019~,0 0.9 12,6 ~00 10195,0 0.~ i2,,? ..: :::. '::::::::.%~:::: <:.:::~:::: :::::::::::::::::5::::::::: ::: :::::::::: :::::::::: :::::' ...:::~::: :::::::::::::::::: :::::::::: ::::: ===================== 10t99.0 0,2 I0,5 10201.0 O. t 9,2 I O0 I0203,0 0,0 7,3 I O0 t0213,0 6.3 lO,b I00 :: :::::::5 ::: :::5:: :::: ::. :::: ::: :;:::::::: :: :.: ::.:-~< 5:: '::¥ ~::: :; ... z,.:~:::: :,.:. :~: :::: :: ~.::: ::::: :: :.:: ::~:'::::: 5:: 5:: ::: :: :: :: :5 ::::::: 5:: ::: :::: :5 :::: :~: ::::. ::: :::: ::: ::::i:;: 5: :::: ::j ::: :?:y. :5:: :::: :5 :;:: ::: :::: :~: :: ::: ::5 ::::: :: ::::.:::: :5 ::: :: ::::::::::::::::::::::::::: ""'" '"' ' "" ?' ""' "" ii'"""' ' '"" ~-" '' lo iv.o o.o 10219.0 0.7 i2,1 10221,0 O,Y t2,2 t0223.0 O, i 9.3 l 00 i0225.0 0,2 10.4 i00 102~t.0 0.0 ~,2 i O0 ?: ::: :Y~: ~}:~:~::~ ::::: ?" 5¥i'~:~5: :<' ':'~< ~{':' :: ~i{'": .' 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