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161-019
1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Swanson River Field GL: 140.2' BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 22" - 28' 11-3/4" J-55 988' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. 988' (TOW) Surface N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 15-1/2" Cemented (No Record) Surface 1200 sx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 2/26/2023 161-019 / 323-039 SETTING DEPTH TVD 2462919 TOP HOLE SIZE N/A N/A 988' MD / 988' TVD N/A 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 344086 2462919 50-133-10163-00-00May 8, 1961 N/A SRU 23-33June 2, 19611717' FSL, 1715' FWL, Sec 33, T8N, R9W, SM, AK 158.2' Sterling / Upper Beluga Gas A028399 10,895' / 10,895' 988' MD / 988' TVD N/A CASING, LINER AND CEMENTING RECORD Gas-Oil Ratio: AMOUNT PULLED 344086 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. PACKER SET (MD/TVD) Conductor BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 1717' FSL, 1715' FWL, Sec 33, T8N, R9W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information - 47# 28' Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 1:46 pm, May 18, 2023 8 JSB Abandoned 2/26/2023 JSB RBDMS JSB 053123 xGDSR-6/12/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS 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. 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. INSTRUCTIONS Hemlock 4 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). 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. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. P&A Schematic, PreDrill Reports, P&A Reports Authorized Title: Drilling Manager Formation Name at TD: No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 5.18.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.05.18 12:56:05 -08'00' Monty M Myers ___________________________________________________________________________________ Updated by DMA 03-01--23 P&A SCHEMATIC Swanson River Unit Well: SRU 23-33 P&A’d Date: 3/27/2023 PTD: 161-019 API: 50-133-10163-00-00 2 TD =10,895’ PBTD = 1,015’ 9 11-3/4” @ 1,756’ 5 7” @ 10,895’ 18 RKB: 158.2’ KB / GL: 140.2’AMSL 7 1b 2 12 10 14 16 17 11 6 13 15 19 20 3 4 7”punches @ 1,698’ 1,806’ 8 2 1a 10.2 PPG KW Aquagel MUD DV Collar 6,990’ CBL Top: 2,550’ H-1 H-2 H-3 H-4 Tight Casing 10,684’RKB 10/08/87 Tag Fill 10,572’ SLM 2/10/05 CBL Top: 9,210’ G Top of Pack 10,531’ WLM 10/17/87 Sterling B-2 Sterling B-3 TOW @ 988’ Directional Data: max = 2.25° at 7,083’ CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22”Conductor -Surface 28’-Cemented 11-3/4”Surface 47#, J-55 Surface 988’8RD / 11.000”1200 sx / Cmt to Surface 7” Production 23#, N-80 1,135’4,712’BTC / 6.366” 26#, N-80 4,712’6,541’BTC / 6.276” 29#, N-80 6,541’6,990’BTC / 6.184” 6,990’6,992’DV Collar 29#, N-80 6,992’8,411’BTC / 6.184”700 sx / Cmt to x,265’ 29#, P-110 8,411’10,895’8RD / 6.184” *7” Marker Jt at 10,519.49’ (12.63’) PRODUCTION STRING JEWELRY DETAIL No.Depth (RKB)Length ID OD Item 1a 988’ 11-3/4” Whipstock (TOW @ 988’ MD) 1b 1,015’11-3/4” CIBP for whipstock base (2/17/23) 2 1,756’ 7” Cement retainer with ToC at 1629’ MD 3 2,610’7” CIBP with ToC at 2566’ (tagged 2/10/23) 4 2,618’Top cut 2-3/8” tubing (2/2/23) 5 2,630’3.07’3.25”5.68”Baker Oil Tool E Latch Assembly (TC-II Box Up) 2,631 6.1”Packer, Model D (E-Line Set) 6 2,640’ 2-3/8” CIBP with ToC at 2629’ MD (2/2/23) 7 2,644’ 1.01’1.875”Baker 2-3/8” X-Profile Nipple (NOTE: Cut for IBT-MOD x 2- 3/8” IBT P Down (x-over:2-3/8” IBT - 8 RND Pin DN) 2,647’1.57’WLEG w/ tubing release ( Slickline Shift to drop) 8 >3,000’2ea 5ft 1-11/16” strip gun assemblies >3,000’92.43’1.995”Tubing, 2-3/8” 4.6# 8 RND EUE 0.7’1.995”Fill Disk Assembly, 8 RND EUE 8.06’1.995”2-3/4” Model II-D FH (Acme x 8 RND EUE) 0.9’1.995”2-3/8” WLEG from Auto Release Upper Section 9 6,645’404’Cement Plug 10 7,049’BOT N1 Bridge Plug w/ 404’ CMT On Top 11 10,380’BOT K1 Cement Retainer w/ 548’ CM On Top 12 10,476’4.18’4.000”5.968”Baker SC-1L packer (Set 10/15/87) 13 10,499’0.81’3.000”5.560”XO Sub 14 10,500’1.01’3.00”5.160”Gravel Pack Safety Joint, 3-1/2” 10RD 53k shear 15 10,501’118.14’2.992”3.500”Blank Pipe w/ welded centralizers 3-1/2” 10RD 16 10,619’118.13’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 17 10,737’0.53’2.500”4.250”O-Ring Seal Sub 18 10,738’10.12’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 19 10,748’1.40’2.439”4.250”S-22 Indicating Seal Assembly w/ 2’ of seals 20 10,749’?3.250”5.687”Baker Model D Sump packer (Set 10/12/87) PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)SPF Condition B2 2,708’2,714’2,708’2,714’6 SPF 1-11/16” strip guns 2 runs(12/7/12) B3 2,802'2,810'2,802'2,810'12 SPF 4-5/8” Millennium TCP 9-27-2010 G 10,552’10,570’10,552’10,570’4 Perf 5/19/02 (1-11/16”, 0 deg) (ABANDONED 9-25-2010) H1 10,630’ 10,657’ 10,630’ 10,657’4,4,12,2 Perf 6/9/61, ½” EH, 2/63, 10/87, 3/95(ABANDONED 9-25- 2010) H2 10,669’ 10,688’ 10,669’ 10,688’ 4,4,12 Perf 6/9/61, ½” EH, 2/1/63, 10/10/87(ABANDONED 9-25- 2010) H3 10,697’10,701’10,697’10,701’4,12 Perf 6/9/61, ½” EH, 10/10/87(ABANDONED 9-25-2010) H4 10,720’10,725’10,720’10,725’4 Perf 6/8/61, ½” EH(ABANDON 9-25-2010) Note: The fluid control valve (FCV) for this well was set at 1,000 psi on 8/2012. The serial number on this valve is 040800161. Activity Date Ops Summary 1/31/2023 PJSM, Mobe unit to well pad location,Rig up Lubricator M/U tool string w/1.78" blind box, PT lubricator 250/2500 good,RIH w/ blind box tag @ 2638' WLM, POOH,RIh w/ 2.3/8" KOT w/1 14 JDS t/2404, bleed IA f/250 t/0 latch GLV POOH recovering valve,Bleed tubing f/ 1000 psi t/350 psi, monitor f/20 min pressure build t/450,RIH w/.65" x5' prong t/2640'WLM no pressure change, POOH,RIH w/2" GS t/2638 unable to latch, POOH sheared,RIH w/2" GS t/2638 WT POOH recovered "A" stop,RIH w/2" GS t/2640' latch Packoff, POOH hanging in collars, recovered D&D pack off plug,RIH w/2" GS t/2642' latch "G" slip stop, POOH recovered stop,R/D, secure well, 650psi tubing, 200 psi IA 2/2/2023 PJSM, discuss hazards & mitigation,R/U E-line tools w/ 2 3/8" CIBP, m/u lubricator, r/u circulating lines,PT lubricator, had leak on companion sub, change out sub re-test 250/2500 good,RIH correlate w/ CCL to tally, set plug @ 2640' in 5'pup below packer, set down on plug verify set, POOH (CCL @ 2632.5', ccl to top of plug 7.5'),Bleed down well (800 on tubing , 200 on annulus ) monitor static. pull lubricator install night cap,Reverse circulate 114 bbls PW @ 2.5 BPM 720 psi, took 30 bbls get returns, circulated hole volume plus getting clean returns. shut down monitored well good.,PT tubing & IA against plug & packer t/1500 psi good. freeze protect well w/50/50 methanol.,R/U e-line w/cmt bailer 20', fill w/ 1.7gal RIH t/top of plug @ 2640', p/u 10' dump cmt on top of plug, (etoc 2629',) POOH,,M/U tools w/1.68 jet cutter, RIH correlate placing cutter @ 2618', (CCL @ 2615.5', CCL to cutter 2.5' )fire cutter good indication fired, POH w/cutter fired, secure well,,RDMO 2/6/2023 PTSM, Orientation to Swanson River field,Prep pad, level grade around well.,Layout Felt & liner, spot Base beam, spot & level rig carrier to well center,Spot Eq on liner, Accumulator, Pits, Mud pump, Choke house, Bang Box, Generator, heater & fuel tank. Spot change room/office.,PJSM, Raise & scope up derrick, secure same.,Install Berming around Rig & Eq. r/u curtain walls on pits, install Driller Dog house to carrier, start running circulating lines f/pits to pump.,SDFN, rest crew's 2/7/2023 PTSM, PTW,Continue R/U, spot light plant, heater, & return tank, R/U circulating lines to well & return tank. start heating eq.,R/U gas alarm system, calibrate & function test, run electrical lines, r/u gas-buster & plumb same, install skirting around carrier. blow through circ lines good.,Check well static, circulate hole volume w/produced water, clean, monitor well 15 min static.,Install BPV, N/D tree, prep wellhead, cap injection line, install blanking sub.,N/U BOPE, install xo spool, stack up mud cross, double gate w/blinds & 2 3/8" rams, single gate w/4 1/2" x 7" VBR, annular, install choke & kill line.,R/U rig floor install Winterization around cellar.,Night watch, heat rig, tq flanges, fuel Eq. 2/8/2023 PTSM, PTW, Install stairs to rig floor, run accumulator lines, secure stack, Function test BOPE good,,Fill pits 60 bbls water, Service choke manifold, M/U & install 2 3/8" TJ, fill surface Eq w/test water,Shell test BOPE, repair leaks as needed, tighten 7 1/16" flange, kill line connection. test 250/2500 good,Test BOPE as per Hilcorp & AOGCC expectations, test Witnessed BY AOGCC inspector Kam StJohn, Witness waived By BLM inspector Allie Schoessler, Tested w/2 3/8" TJ, 250 low 2500 High, Had 2 FP one on missing Well Sign, one on manual choke valve, cycled retested good.,Blow down lines & Eq.,Pull blanking sub, pull BPV, Secure well for night. Replace H@S sensor @ pits (failure bad circuit board) calibrate & test good.,Night watch rig, fuel & prep handling Eq. 2/9/2023 PTSM, PTW, Check well static, Blow through surface lines & eq. good.,R/U handling Eq. (Bails, elevators, slips tubing tongs) r/u spooler for chemical injection line,M/U landing joint, back out L/D pins, pull hanger free 17k, cont. pull hanger to floor, l/d same. break down landing joint. change dies in tongs.,POOH w/2 3/8" 4.6# L-80 TCII completion, strapping on the way out, standing back in derrick. Recovered 107 bands, 2612' completion w/2 GLM's & chem mandrel.,M/U shooting flange, R/U e-line, PT lub 250/ 1500 good,RIh w/junk basket, GR 5.72" t/ 2615', tagging top of cut jt. referenced to to CBL log dated 6-7-1961, POOH,M/U 7" CIBP, RIH tag cut pickup set plug w/top @ 2610', POOH,P/U bailer fill w/ 35 gals 17ppg cmt, RIH tag plug @ 2610', P/U dump bailer on plug, P/U wk tool, POOH,Redress bailer, fill w/30 gal 17ppg cmt, RIH t/ 2593' dump bailer, wk tool, POOH,Secure well, R/D Bailer, night watch Rig & fuel. 2/10/2023 PTSM, OTW, Blew through surface lines, spot & r/u mix tank.,R/U e-line w/ 3.5" junk basket, RIh for tag, AOGCC inspector Kam StJohn witnessed tag. @ 2566', POOH, BLM waived witness via phone conversation @15:56 on 2-7,R/U & test casing /plug t/1500 psi f/30 min Good, AOGCC inspector Kam StJohn witnessed pressure test. Initial pressure 1700 psi, 15 min 1650psi, 30 min 1630psi, bleed down, blow down.,R/U e-line with 3 1/8" 18shots per foot, 60 deg phasing casing punch, P/T lubricator 250/1500 good, RIH, correlate on depth placing top shot @ 1806', bottom shot 1809', pressure up 7" t/500 psi, monitor 7" x 11 3/4" annulus 0, fire shot 7" pressure dropped t/300psi, no change on 7 x 11 3/4", POOH all shots fired. R/D e-line,Pump down 7" line up to take returns out 7 x 11 3/4 annulus, pump 1 BPM pressure 820 psi no returns, increase t/2 bpm 890 psi, no returns, shut down pressure bleed off in 4 min, check well static, re-try w/ same results, attempt to pump down 7 x 11 3/4 annulus, pressured up t/ 1375 psi with one bbl, pumped, hold pressure 5 min, check flow path, good, check for obstruction at wellhead, clear.,continue attempt to get communication with no joy, consult with Engineering, decision to move forward with Contingency #1 in sundry.,Clear floor, r/u handling tools, r/u start mixing 9.5 brine.,Continue building 9.5 brine 100 bbls. Night watch rig & fuel. 2/11/2023 PTSM, PTW, check well pressure good, blow through surface lines Good, R/U 2 3/8 handling Eq.,TIh w/ 2 3/8 tubing, t/2542', up/dn wt 16k,Displace well t/9.5 brine, pump 3 BPM 420 psi, pumped 109 bbls getting back 9.5 brine,Blow down surface lines, prep handling tools to POOH,POOH stand back tubing,,M/U shooting flange, R/U e/line w/ 7" retainer, RIH correlate retainer, set @ 1756', P/U 10' clean rih & tag f/verification good. POOH,P/T retainer t/1050psi 10 min good, while e-line P/U hole punch.,P/U e-line PT lub t/250/1500 good, RIH correlate top shot @ 1698, bottom shot @ 1701', pressure up 7" t/500 psi fire punch, lost 200 psi on 7", no pressure change on 7 x 11 3/4" annulus. POOH,L/D e-line, pump down 7" monitor 7 x 11 3/4, pressure up t/ 1330 psi with .75 bbl shut down monitor 5 min pressure drop to 495, no pressure show on 7 x 11 3/4,,Bleed off blow down, secure well.,Night watch,fuel Eq. clear snow on pad. 2/12/2023 PTSM, PTW, R/D shooting flange, R/U handling tools, M/U CMT stinger,,TIH w/ stinger on 2 3/8" tubing t/1756' tag retainer, L/D single, P/U space out pups,RIh tag retainer, attempt to sting in, R/U circulating lines, pump down verifying not in retainer,,Continue working to get into retainer with no luck, consult with tool hands & engineer. decide to POOH inspect tools.,R/D circ lines, blow down, l/d space out pups,POOH, inspect tools, no markings on tools, clean up & paint stinger.,TIh with stinger, P/U pups tag retainer,,Attempt to sting in w/no luck, POOH to inspect tools.,OOH inspect paint was warn 3 1/2" up on stinger, consult with tool hands to try & diagnose issue. Rest crews, night watch rig & fuel.,Rest crews, night watch rig & fuel. n (LAT/LONG): evation (RKB): 50-133-10163-01-00API #: Well Name: Field: County/State: SRF SRU 231-33 Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:231-00028 SRU 231-33 PreDrill Spud Date: 2/13/2023 PTSM, PTW, check well static, check handling eq. M/U clean-out assy w/1.66"nozzle,RIH w/2 3/8" tubing, t/ 1742', up/dn wt 12k P/U space out pups, m/u circulating lines,RIH t/ top of Retainer @ 1756', wash down into retainer@ 2bpm, 300psi, wash down t/ tag, line up REV circ. 2 tubing volumes. open valve & inject @ 1.2 BPM 690 psi, r/d circulating lines, blow down.,POOH, l/d c/o assy, P/U CMT stinger,,TIH on 2 3/8" tubing t/ 1756', p/u space out pups, stab into retainer, p/u verify latch, good,,R/U circulating lines, pump through retainer @ 1.5 BPM 800 psi, attempt work up t/2BPM, pump started running erratic. Trouble shoot & blow lines down, secure well f/night,Night watch, fuel rig 2/14/2023 PTSM, PTW, check well static, blow through surface lines good, Prep for Cement job, line up handling tools. R/U cementers.,PJSM f/cmt job, Pump fluid w/ cmt pump est. injection rate 1BPM 760psi, 1.5BPM 890psi, 2BPM 890psi, PT lines 400/3570 good,Pump 15.3PPG Cement, @ 2 BPM 740psi, inject 9bbls below retainer @1756', un-sting & place 7 bbls on top of retainer chase w/5bbls w/9.5 brine,L/D space out pups, pull 4 stands t/1498' pumped down tubing @ 1BPM 10 psi to clear & clean 2-tubing volumes,Finish washing up cementers, r/d & move out, r/u t/ L/d tubing,POOH l/d 2 3/8" TCII tubing f/1498' t/surface, l/d cmt stinger,TIH w/remaining16 stands tubing t/951', POOH L/D 2 3/8" tubing,Blow down surface lines & eq. M/U 5" & 7" test joints, Secure well.,Night watch rig, wk on project list. fuel rig eq. 2/15/2023 PTSM, PTW, check well static, swap accumulator lines from from double gate 2 3/8" rams t/ single gate w/4 1/2" x 7" rams function test same good. install 5" TJ shell test had leak on 2 connections, re-torque connections re-test good.,Test BOPE as per Hilcorp & AOGCC expectations, AOGCC witness waived by Jim Regg, Tested w/ 5" & 7" TJ's,250/2500 good,M/U shooting flange on top of annular, R/U e-line w/5.90JB/GR,RIH t/ 1084' tagged , attempt t/work down, not much luck, POOH, drop GR RIH w/ 3.5 Junk basket t/ same depth 1084', wk down make POOH,,Change tools t/ 1 11/16 OD, RIH tag 1084', wk tools break through cont. in hole tag @ 1505' worked not making headway, POOH p/u 3 1/8" CCL w/2.75 Paraffin cutter, RIH tag and work down t/1507', POOH, tag witnessed By AOGCC inspector Sean Sullivan,Pressure Test 7" casing against cmt plug, t/ 1500 psi good, initial 1700psi, 15 min -1650 psi, 30 min- 1630psi Test witnessed by AOGCC inspector Sean Sullivan,RIH w/3 1/8" CCL t/tag @ 1503' POOH, Tag Witnessed by AOGCC inspector Sean Sullivan,C/O tools t/ 5.9" JB/GR, RIH wk through tight spot @ 1804' cont in tag TOC @ 1503' POOH Test 11 3/4 x 7" annulus t/1500psi, initial 1650, final 1550psi bleed down secure well for night,Night watch, Blow down surface lines, fuel rig eq. 2/16/2023 PTSM, PTW Check well static, monitor 30 min good, shut in 30 min verify no pressure build. R/U e-line w/5.80 jet cutter, PT lubricator good,,Correlate on depth @1135' above collar, pressure up t/ 500psi & monitor annulus at 0, fire cutter good indication fired, pressure on annulus came up t/ 200psi, 7" dropped to 80psi, POOH R/D e-line,P/T 11 3/4 x 7 annulus t/1500psi 10 min good,R/U t/circulate hole, fill mix pit w/9.5 brine, line up t/ take returns t/ R4R tank, prep floor for r/d. Remove tarps & handrails.,Circulate hole clean, pump 173 bbls , spot 9.5 brine in hole. monitor hole static,,Prep t/N/D BOPE, remove stairs & fold up rig floor, Prep 3 5/8 3k x 5k DSA, pull stack & tie back, remove 13 5/8 x 7" xo flange n/d tubing head,Remove pack-off (tight) weld slips t/casing for pull.,N/U 13 5/83k x 13 5/8 5k DSA, 2' 13 5/8 spacer spool, N/Y BOPE stack, Tq flanges, install kill line.,Test Breaks 250/1500 f/ 5 min each good,Secure well, Night watch rig, Blow down surface lines, Fuel rig 2/17/2023 PTSM, PTW, Check well static, install floor, hand rails & stairs. Change out bails & R/U 7" handling eq. M/U spear assy. PJSM with third party contractors.,Spear casing & pull casing w/ slips t/floor, 32k, L/D spear & 15' stump, cont. POOH l/d casing f/1135', full recovery to cut.,R/D handling tools, Clear floor break down tools, load casing Eq. on trailer.,R/U e-line, w/CBL tools, calibrate tool, rih tag cut @ 1135', Run logging pass & repeat, pull to surface.,C/O tools string, p/u 11 3/4" 42-60# CIBP, RIH tag @ 1135', correlate & set plug @ 1015' (placing top of plug 5' below collar), good indication plug set, P/U logging 2 collars rih tag plug @ 1015' good, POOH r/d e-line., 2/18/2023 PTSM, PTW, R/d 401 rig equipment, N/D BOPE, install steel cover plate & secure, Demobe eq. from pad, Activity Date Ops Summary 2/20/2023 Traveled to Swanson River pad 23-33 and met with CCI grader operator and loader operator. 3 sand trucks enroute. Checked grade in various spots on pad for backyard. Offloaded 3 trucks of sand and began grading for level, ordered 3 more truck loads. Notified Production Rep of need to remove above;ground abandoned 2" gas lift line. Wait on sand trucks and CCI welder.;CCI welder arrived with Production Rep, cut off 2" line and capped same. Released welder, offloaded 3 sand trucks and graded level. Staged rig mat trailers on pad. Rig's day crew marked pad for felt/liner lay out. Rolled out felt and liner, marked liner for rig mats and started setting those,;Staged remaining available rig mats, light plants, and fuel cube on location;Set up light plants and heater, covered and thawed rig mats w/ Tioga heater, chipped and cleared ice off rig mats w/ shovels and set same.;Broke tours w/ rig crews. Crew change at midnight. Cont. working on removing ice and snow from rig mats in prep for setting rig modules at 07:00 hrs. 2/21/2023 Cont thawing rig mats of ice with tarps and heaters, CCI crew on location at 07:00 and warming up equipment, rig hands on 215 TS pad shoveling off snow berm from rig modules, CCI moved small crane to 215 TS pad and LD derrick board windwalls, loaded pony walls and sub base, moved same to location.;Tried to transport derrick but trailer wheels (5 axle) froze up, CCI worked on freeing trailer wheels, set pony walls on 231-33. Moved derrick, pit module, catwalk and boiler skid off rig mats on 215 TS, cleaned rig mats and loaded same for transport to our location. Transported derrick to location.;Transported 2nd crane and rig mats to 231-33, staged cranes, set iron roughneck HPU, set sub base on pony walls, set iron roughneck on rig floor, folded out walkways and installed stairs, set carrier on sub, set derrick on carrier, stood V door windwall, stood derrick board windwalls, set doghouse;skid, set pit #1, set jig, set pump #1. Raised doghouse.;Set rig HPU, set MP module #2. set pit module # 3 and raised roof. Set pit module #3. R/U suction line between pump modules. Raised roof on pit module #3. Plugged in most of electrical throughout rig. R/U and secured lights on top of;rig modules. Warmed up gen skid w/ Tioga heater, fired gen #2, turned on lights to rig. CCI rig support went to Pad-215 and cleaned up felt, liner, and misc. dunnage. Raised degasser in pit #4. Got heat to doghouse and removed snow from stairways.;Crew change, held PTSM. R/U steam, air, and water jumper lines between pit module #2 and MP module #2. R/U same in pits along w/ roughneck heaters. Attempted to get HYD to mast too raise mast w/ no luck. Currently trouble shooting HYD issue.;CCI rig support hauled to location, choke house, gen #3, wind wall rack, CCI shack, Mud lab, hot box, centrifuge, centrifuge pump, and control panel. Currently cont. to R/U. 2/22/2023 Raise mast from headache rack, CCI clean up on pad 215 TS pad, set service shacks and connect to rig. Crane on location @ 07:00 and set choke house, hung cellar tarps and staged heater in cellar box for welder, sanded pad and access road, set boiler skid, set centrifuge pump.;Quadco rep on location at 09:00, assemble gas alarm system and function test same. Good. Set centrifuge control panel, set safety/ change shacks, set auxiliary fuel tank (empty), set centrifuge, set MGS, Electric and Mechanics shack. Send 72 hour notice for Diverter function test to BLM @ 11:06.;Crew change, held PTSM. Welder and wellhead rep continue to install new wellhead and complete, Install MGS vent stack, Install windwalls for pits and rig floor, spot camp trailers and set up, Connect trailers to generator, CCI continue bringing equipment from Tyler pad, received confirmation from;BLM that they waive witness of Diverter function test @ 13:00.;Functioned tested DWKS prior to spooling up drill line (ok). Spooled on drill line, slipped on an extra 7 wraps for a total of 90 wraps. Cleaned snow and ice off mast. Prepped mast to scope, scoped mast. Unbridled and stored bridle lines, R/U camera system and coms. R/U IR HPU. Cont. w/ R/U in pits.;Set up mud dock for DP.;Crew change, held PTSM. M/U wash pipe on top drive. R/U rigging and tailed TDS to rig floor in cradle. Hung TDS to blocks w/ dog bones. R/U HYD lines on TDS. Connected service loop and Kelley hose to TDS. Cont. R/U in pits. Built wet dock for mud products. M/U steam jumper hoses for steam loop.;Installed roof over centrifuge. Prepping MP's and working on rig acceptance check list. 2/23/2023 Continue working on Steam, Water and air lines. Handy Berm install berm around entire rig footprint, Load diesel and continue rigging up TDS, Install new stocking on service loop lines and adjust as needed, Install T-Bar on torque tube and straighten torque tube, Third party personnel continue;rigging up equipment and their shacks.Continue bringing in equipment from staging pad and placing on pad including mud products.;Pason arrives and meets with Toolpusher on plan of checking entire system and getting it working as designed. Take on hot water to the boilers. Shovel snow from bottom of water tank and mud pits. Clean up all snow in work areas. Disconnect service loop and re-configure orientation of lines.;Run TDS up & down mast to make sure Kelly hose & service loop were clocked right. Cont. hauling water to rig tank and 400 bbl upright. Installed bails and adjusted link tilt clamps. Cont. staging up temp on boiler. Installed cutting shoots on end of shakers. Cont. working on rig acceptance check;list. R/U elevators & tongs. Installed HYD mast raising cylinder covers. Warmed up MP #2. Replaced frozen valves on water system.;Crew change, held PTSM. Opened up boiler @ 03:00 hrs., completed steam loop through out the rig, purged air out of heater, installed steam trap disks. Finished water loop and got water circulating. Fired and warmed up MP #1, checked liner wash/ lube pump. Function tested mixing equip on pit;module #3. Finished filling 400 bbl up right and rig tank. Started bring on water to pits to Hydro test pit system. Cont. R/U and working through rig acceptance check list. 2/24/2023 Cleaned/ Organized connex boxes, Function test Pit #1 & #2, ALL ESD's, Catwalk, TOP Drive (Fix comms error for float function), Stage mud products for current mud system to be built, Remove shipping beams, Dress out derrick board and rig floor for drilling, Install wear ring, Prep Diverter for N/U.;Submitted AOGCC Diverter test notice @ 09:38 and AOGCC Brian Bixby responded and wants an update tomorrow afternoon. Updated BLM with a 72 hour notice of spud.;Worked on N/U Diverter System, Install screens on shakers (API 120's), Started building first batch of 9.0ppg 6% KCL PHPA mud, Complete a pump parts inventory. Pason rep continues completing installation. Checked pressures on accumulator bottles.;Cont. working on N/U diverter system. Installed flow line, chained down stack. Installed knife valve. Hook up accumulator lines. Pressured up accumulator, Installed diverter vent line (98' from closest ignition source). Set diverter sign at end of vent line and entrance of pad.;Cont. building first batch of new mud. Installed level sensor on water tank. Cont. w/ rig and working through rig acceptance check list.;Crew change, held PTSM. Loaded MWD tool on drillers side on catwalk. Changed filters on camp gen. Finished building first 300 bbl batch of 6% KCL PHPA mud. Loaded ODS catwalk racks w/ CDS-40 4.5" DP. Started build second batch of KCL mud. Strapped & tallied DP. Pulled test plug.;Currently function testing diverter annular. 18 n (LAT/LONG): evation (RKB): 50-133-10163-01-00API #: Well Name: Field: County/State: SRF SRU 231-33 Swanson River Hilcorp Energy Company Composite Report , Alaska 2/27/2023 Contractor AFE #: AFE $: 231-00028 $3,964,000 Job Name:231-00028 SRU 231-33 Drilling Spud Date: 2/25/2023 Diverter bag closing time of 25 seconds and knife valve 2 seconds. Pump fluid through MP #1/ MP#2 (Trouble shoot throttle valves and repair) Leak tight test of surface lines, Good. Assure Iron Roughneck, Pull tongs & TDS are torquing properly. Confirmed Good. P/U and stand back Drill Pipe 35;stands. Breaking in re- cut connections and continue building 9 ppg 6% KCL PHPA mud.;P/U and stand back 8 stands of CDS40 DP, Continue breaking in re-cut connections (Total of 29 pins and 19 boxes were re-cut), Continue building 9ppg 6% KCL PHPA mud, Work with welder repairing flowline, mud pump liner wash plates and link tilt cylinders, Adjust the service loop on the top drive,;Function test fill pump. Good. Talley 18 jts of CDS40 HWDP, P/U and stand back 9 stands of HWDP. Verify Rig Acceptance checklist complete. Accept rig at 18:00 hours.;Performed rig service- Greased blocks, TD, IR, DWKS, and crown. Inspected all handling equip. for P/U BHA.;Removing ice & snow from rig mats and modules. Gathered and staged tools for BHA #1. MWD worked on testing there tools. Finished building new 6% KCL PHPA mud. Cleaned & organized pad. Installed new inspection cover gasket on small boiler.;Noticed gear oil increase in sight glass on TD gear box. Performing multiple tests to decipher were the increase in oil is coming from.;Crew change, held PTSM. Cont. to trouble shoot top drive, remove snow & ice from rig containment, and organize rig modules. Replaced suction rubbers in pill pit. Cleaned threads on spiral drill collars. Strapped and tallied BHA #1 tools.;At 02:50 hrs. had 1 cup of power steering fluid discharge onto the gravel of the pad due to a power steering hose bursting on the vac truck. Spill was immediately cleaned up, and the proper personal have been notified. 2/26/2023 30 minute hazard hunt, Install kill line, Continue conditioning 9ppg 6% KCL PHPA mud, Drain stack and pull mouse hole from rotary, P/U 4-1/2" test joint and function test 21-1/4" Annular Preventer, 35 seconds for closing and 2 seconds for knife valve opening.;AOGCC representative Brian Bixby arrive for witness, Test all gas alarms, Good, Drawdown test with 21-1/4" Annular Preventer, Annular Preventer closed in 36 seconds and Knife valve opened in 2 seconds, Function test Trip Tank, PVT alarms and flow paddle. All good.;Gather equipment for BHA #1 and get to rig floor. Prep tongs, Slips, Dog collar clamp and change elevators.;P/U, M/U and RIH with BHA #1 Cleanout/ Gauge run for whipstock assembly. 10-5/8" window mill, Float sub, Two crossover subs, 8 6-3/8" spiral drill collars, Two crossover subs and 9 stands of 4-1/2" CDS40 HWDP T/ 811'.;RIH with 4-1/2" CDS40 DP F/ 811' and tag CIBP @ 1022' with 20K down weight to ensure Anchor sets on whipstock. P/U and circulate STS for a total of 1600 strokes, B/D TD and monitor well.;P/U and circulate STS for a total of 1600 strokes, B/D TD and monitor well.;POOH F/ 1022' with BHA #1 and L/D mill assembly.;Bring tools to rig floor for Tri-Mill assembly from catwalk. M/U Tri-milling assy. w/ UBHO and racked back in derrick. P/U WIS mechanical set whip stock and set in false table. M/U tri-milling assy. to whip stock w/ 35K shear bolt as per WIS rep.;RIH w/ whip stock, Tri-milling assy. DC, HWDP, and 2 stds. of 4.5" DP T/1013' at 20' per/min.;Crew change, held PTSM. P/U & M/U E-Kelley to string. R/U AK E-line and Gyro data tools. RIH w/ Gyro data tool on E-line. Tagged UBHO at 925' WLM. Took 3 TF shots= 246. Re-orientated TF, worked pipe, took reshot=26.5, re-orientated TF, worked pipe, took reshot=31.5. RIH F/1013'-T/1023';Set anchor w/ 14K down weight. Pulled whip stock up hole and set on depth at 1017' (Bottom of whip stock). Set anchor on whip stock w/ 14K down weight. P/U- 62K. Reshot TF w/ gyro tool= 33.92.;POOH w/ E-line/ Gyro data tools. L/D tool and R/D E-line unit.;Sheared off whip stock bolt w/ 35K. TOW-988 BOW-1006.;Held PJSM on displacement. Displaced well over to 8.95 ppg 6% KCL PHPA mud. (Total Disp. = 111 bbls).;Started Milling window at 988'. GPM-342 SPP-269 psi RPM-90 TQ-5K P/U-57K S/O-56K ROT-57K. From:Davies, Stephen F (OGC) To:Brooks, James S (OGC) Subject:RE: 161-019 State plane issue Date:Wednesday, May 31, 2023 11:20:38 AM This well is fine too. The difference here is 67’, which is acceptable for a Cook Inlet Basin well. Thanks again, Steve From: Brooks, James S (OGC) Sent: Wednesday, May 31, 2023 11:12 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: 161-019 State plane issue Hi, I have another one for you. thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230317 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU L-57 50029236090000 218072 3/7/2023 READ CaliperSurvey SRU 23-33 50133101630000 161019 2/16/2023 AK E-LINE Jet Cut CLU-9 50133205440000 204161 2/24/2023 HALLIBURTON PPROF CLU-15 50133206870000 220003 2/26/2023 HALLIBURTON PPROF END 1-11 50029221070000 190157 2/19/2023 HALLIBURTON MFC END 1-11 50029221070000 190157 2/25/2023 HALLIBURTON PLUG-PERF KU 14X-06 50133203420000 181092 3/1/2023 HALLIBURTON LDL Please include current contact information if different from above. SRU 23-33 50133101630000 161019 2/16/2023 AK E-LINE Jet Cut Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230310 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-14RD 50733204080100 201171 3/5/2023 AK E-LINE Perf MPU L-02A 50029219980100 209147 3/5/2023 READ Caliper Survey SRU 23-33 50133101630000 161019 2/17/2023 AK E-LINE CBL CIBP Jet Cut SRU 23-33 50133101630000 161019 2/11/2023 AK E-LINE Plug Cement Punch Please include current contact information if different from above. SRU 23-33 50133101630000 161019 2/17/2023 AK E-LINE CBL CIBP Jet Cut SRU 23-33 50133101630000 161019 2/11/2023 AK E-LINE Plug Cement Punch Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/27/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230227 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 233-23 50283201360100 222050 1/20/2023 AK E-LINE Perf END 2-06 50029216990000 187018 1/23/2023 AK E-LINE Perf PBU 04-22A 50029214540100 194097 1/10/2023 AK E-LINE PPROF PBU 11-39 50029235180000 214099 2/8/2023 READ MultipleArrayProductionProfile SRU 23-33 50133101630000 161019 1/3/2023 AK E-LINE Plug_Cement_Jet Cut TBF A-01RD 50733100550100 190147 1/24/2023 AK E-LINE Tubing Punch Please include current contact information if different from above. SRU 23-33 50133101630000 161019 1/3/2023 AK E-LINE Plug_Cement_Jet Cut MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 33 Township: 8N Range: 9W Meridian: Seward Drilling Rig: Hilcorp 401 Rig Elevation: 13.95 ft Total Depth: 10895 ft MD Lease No.: FEDA 028399 Operator Rep: Suspend: P&A: X Conductor: 22" O.D. Shoe@ 28 Feet Csg Cut@ Feet Surface: 11 3/4" O.D. Shoe@ 1756 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 10895 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 2 3/8" O.D. Tail@ 2631 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 1750 ft 1507 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 1700 1650 1630 OA 20 20 20 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Travel to Swanson River Field for plug tag verification on SRU 23-33. Encountered a small obstruction at 1070 ft during tag attempt; changed to 2-inch spang and added weight bar to get through. Final tag depth 1507 ft MD. Good pressure test. February 16, 2023 Sully Sullivan Well Bore Plug & Abandonment SRU 23-33 Hilcorp Alaska LLC PTD 1610190; Sundry 323-038 None Test Data: P Casing Removal: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-0216_Plug_Verification_SRU_23-33_ss 9 9 9 9 9 9 9 99 9999 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.08 15:56:36 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:401 DATE:2/15/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1610190 Sundry #323-038 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:964 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13 5/8" 5M P Pit Level Indicators P P #1 Rams 1 4 1/2" x 7" VBR P Flow Indicator NA NA #2 Rams 1 2 3/8" Ram NT Meth Gas Detector NT NT #3 Rams 0 Blind Ram P H2S Gas Detector NT NT #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 4 1/16" 5M P Time/Pressure Test Result HCR Valves 1 4 1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 4 1/16"&2 1/16"5M P Pressure After Closure (psi)1900 P Check Valve 0 NA 200 psi Attained (sec)23 P BOP Misc 0 NA Full Pressure Attained (sec)115 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 x 2265 P No. Valves 8 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 24 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:4.0 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-13-23 19:59 Waived By Test Start Date/Time:2/15/2023 9:00 (date)(time)Witness Test Finish Date/Time:2/15/2023 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested w/7" & 5" TJ, Gas detection alarms tested on 2-8-23 Kevin Reed Hilcorp Harold Soule SRU 23-33 Test Pressure (psi): hsoule@hilcorp.com hsoule@hilcorp.com Form 10-424 (Revised 08/2022)2023-0215_BOP_Hilcorp401_SRU_23-33 Alaska LLC jbr J. Regg; 6/12/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:33 Township:8N Range:9W Meridian:Seward Drilling Rig:Hilcorp 401 Rig Elevation:13.95 ft Total Depth:10895 ft MD Lease No.:FEDA028399 Operator Rep:Suspend:P&A:X Conductor:22"O.D. Shoe@ 28 Feet Csg Cut@ Feet Surface:11-3/4"O.D. Shoe@ 1756 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 10895 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:2-3/8"O.D. Tail@ 2631 Feet Tbg Cut@ 2618 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 2610 ft 2566 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 1700 1650 1630 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Tag top of cement with E/L at 2566 ft MD with tool string correction off CCL. Cement sample looked good. Tubing was cut and pulled at 2618 ft. 30 min test was good. February 10, 2023 Kam StJohn Well Bore Plug & Abandonment SRU 23-33 Hilcorp Alaska LLC PTD 1610190; Sundry 323-038 Test Data: p Casing Removal: rev. 11-28-18 2023-0210_Plug_Verification_SRU_23-33_ksj STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________SWANSON RIV UNIT 23-33 JBR 03/31/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 2-3/8" TJ. F/P on well sign missing they got one made up with all correct info and posted. F/P on manual choke C5 Cycled and cleaned to work properly passed retest. 4-1/2 X 7 VBR are on the stack but not hooked up and operational so not tested. 24 Bottles & 1000 psi Avg. Test Results TEST DATA Rig Rep:Chris HannevoldOperator:Hilcorp Alaska, LLC Operator Rep:Harold Soule Rig Owner/Rig No.:Hilcorp 401 PTD#:1610190 DATE:2/8/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS230209135745 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 964 Sundry No: 323-038 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign FP Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 FPManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 4-1/2x7 VBR NT #2 Rams 1 2-3/8" fixed P #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4-1/6" 5K P HCR Valves 1 4-1/16 5K P Kill Line Valves 3 4-1/16 & 2-1/1 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1900 200 PSI Attained P14 Full Pressure Attained P116 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6 @ 2250 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams NT0 #2 Rams P8 #3 Rams P8 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 999999 9 9 9 9 9 2QO\UHTXLUHGWRKDYHDSUHYHQWHU VWDFNEDVHGRQ0$63MEU FP NT NT FP F/P on well sign missing F/P on manual choke C5 4-1/2 X 7 VBR are on the stack but not hooked up Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: DATE: 02/01/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #20230201 SRU 23-33 (PTD 161-019) Cement Bond Log 6/7/1961 Please include current contact information if different from above. By Meredith Guhl at 10:53 am, Feb 01, 2023 161-019 T37482 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.01 10:54:40 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,895'N/A Casing Collapse Structural Conductor Surface 1,510psi Intermediate Production 3,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,340psi10,895'10,895' 28' 1,756' Perforation Depth MD (ft): 10,895'7" 22 11-3/4" 28' 1,756'3,070psi 28' 1,756' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 10,895'6,645'6,645'~964psi 6,645' (cement) MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028399 161-019 50-133-10163-00-00 Swanson River Sterling/Up Beluga Gas Same CO 716A Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit (SRU) 23-33 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 4.6# / L-80 2,631' February 3, 2023 Baker Model D Pkr; N/A 2,631' MD/TVD; N/A See Schematic See Schematic 2-3/8" 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 and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 8:21 am, Jan 24, 2023 323-038 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.01.23 19:36:34 -09'00' Noel Nocas (4361) BOP test to 2500 psi 10-407 BJM 2/1/23 Yes, for pre-rig only 2/1/23 Bryan McLellan DSR-1/26/23 X DLB 01/25/2023 X Variance to 20 AAC 25.112(c)(1)(E) for placing cement plug >50' above perfs, approved on the following conditions: Reservoir cement plug inside 7" casing must be set on top of bridge plug and placed across annular cement 2592-2604' MD. Secondary cement job at surface casing shoe must have at least 50' of cross-sectional coverage with cement outside surface casing, inside 11" x 7" annulus and inside 7" casing. X GCW 02/01/23 JLC 2/1/2023 2/1/23Brett W. Huber. Sr. Digitally signed by Brett W. Huber. Sr. Date: 2023.02.01 13:56:32 -09'00' RBDMS JSB 020223 Well: SRU 23-33 Pre-sidetrack Decomplete Well Name: SRU 23-33 API Number: 50-133-10163-00-00 Current Status: Offline Gas Producer Permit to Drill Number: 161-019 First Call Engineer: Chad Helgeson (907) 777-8504 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 229-4824 (C) Max. Expected BHP: ~1,244 psi @ 2,810’ TVD Used 0.443psi/ft to deepest perf Max. Potential Surface Pressure ~964 psi Based on 0.1 psi/ft to surface Well Summary SRU 23-33 is an offline gas producer that was originally drilled in 1961 as an oil well and flowed until 2009. In 2011 it was recompleted to a gas well, but never sustained production and last recorded production in May of 2011. The intent of this project is to P&A and decomplete the existing well with rig 401 to be prepared for sidetrack in February. The plan for the new drill well will be to kickout of the 11-3/4” casing at approximately 1,000’. The initial string of the sidetrack will be brought back to surface, and fully cemented, thus fully abandoning the 11-3/4” casing. A new wellhead will be built upon the new 7-5/8” casing. This sundry does not include the whipstock setting and milling window, which will be included in the PTD. The goal of this project is to P&A the well and plug back in the 11-3/4” casing for a future sidetrack. Notes Regarding Wellbore Condition x Current: T/IA/OA = 1,000/250/0 x Inclination: Straight hole. MD = TVD x Backside fluid is diesel, PW, and glycol from MIT work in 2017 x Pertinent History o 7/11/17: SL Set Packoff plug at 2,635’ o 7/18/17: MIT-IA to 1500 psi, passed o 1/15/23: MIT-IA to 1500psi, passed o 1/15/23: MIT-OA to 1110psi with losses of 185psi in 1 hr (no communication to IA) x Cement: (See schematic for additional details) o ToC behind 7”: 2,660’ MD based on CBL o ToC behind 10-3/4”: 1200 sacks pumped (Couldn’t find drilling or cement reports for well in 1961 indicating cement returns to surface) CBL will be conducted in step 30. Pre-RWO Procedure 1. MIRU Slickline and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. Fill tubing with ~8.6 ppg lease water 4. Pull Dummy from GL valve at 2,604’ 5. Reverse Cir fluid until clean fluid (minimum of - 99bbls) a. Tubing Volume 10bbls b. IA volume 89 bbls 6. RU Eline with pressure control equipment 7. PT Lubricator to 250L/2500H T/IA/OA = 1,000/ Well: SRU 23-33 Pre-sidetrack Decomplete 8. RIH with 1-11/16” cement bailer. Dump 2.5gal of cement on top of packoff plug (TOC approximately 2,610’) This is to ensure packoff plug holds. Additional zonal isolation performed after removing the tubing in step 7 below. 9. Pressure test plug and casing (combi T&IA Test) to 1,500 psi (this is not the perf isolation plug, just plug for killing well and pulling tubing) 10. PU tubing jet cutter. RIH and cut tubing at top of cement ~2610’. 11. POOH and Rig down Eline and SL RWO Decomplete/Abandonment Procedure: 1. MIRU Hilcorp rig #401 2. Circ/flush tubing and annuli with produced water (~8.6ppg) to establish same fluid throughout and ensure well is dead 3. Set BPV or TWC 4. NU BOP’s and test (Notify AOGCC & BLM of test) a. PT to 250psi low / 2500psi high / 2500psi annular b. Test to handle 2-3/8” tubing in lower set of rams c. Test to handle 7” casing in single set of rams (if necessary, 7” can also be tested before step 26.) 5. Pull TWC 6. POOH with 2-3/8” tubing from cut a. Count bands on chemical injection mandrel b. Flush and plug chemical line as necessary for safety when removing line 7. RU Eline, PT Lubricator to 250L/1500H 8. RIH and dump 60 gal (37.5’) of cement on top of packer, tubing stub with plug and cement 9. Pressure test plug and chart for 30 min (notify agencies of test 24 (AOGCC)-48hrs (BLM) in advance of pressure test) 10. PU casing punch, RIH and punch at 1806’ (50ft below 11-3/4” shoe) a. Ensure tubing/casing is fluid packed with 8.6ppg KWF b. Aim to connect to the OA 50’ below the 11-3/4” shoe c. Hold at least 500psi on the 7” casing to ensure overbalance to OA (unknown mud weight on the backside) d. Monitor OA for pressure responses after perf’ing 11. Attempt to circulate from casing to OA, or visa-versa a. Given pre-rig screening, we know OA pressure bleeds off, we are optimistic we can establish circulation b. When pressuring up on the OA, keep pump pressure <1,500psi c. This will keep the uncemented portion of the J-55 11-3/4” casing below 50% of burst pressure d. As mud is removed from OA, Circ pressure limit on OA can be increased 12. Confirm circulation up OA and try to get close to 2 bpm If unable to establish circulation close to 2 bpm see contingency option 1 below. 13. PU and RIH with 7” cement retainer on workstring 14. Set 7” cement retainer approximately 1,756’ (within 50’ of the casing punch, not in a collar) 15. Perform 10min PT on 7” casing and retainer to 1000psi to ensure retainer is set 16. Confirm injectivity below retainer and up OA of at least 2 bpm 17. Circulate 9ppg brine (NaCl) 18. RU cementers 19. Provide agencies 24hr notification to witness abandonment activities below Ensure cut allows enough room to place top of CIBP inside 7" casing deeper than 2605' MD, referenced to 7" CBL dated 6/7/1961. -bjm Set cement retainer at 1706' (50' above csg shoe). -bjm Pressure test plug to 1500 psi. Tag cement to determine TOC. -bjm Cement plug must overlap cemented 7" casing from 2592-2604' MD referenced to CBL 6/7/1961. -bjm Set bridge plug just above tubing stub as base for cement. -bjm Well: SRU 23-33 Pre-sidetrack Decomplete 20. Circulate cement up the 11-3/4” x 7” annulus through the open perf sets as follows: a. Ensure OA is open, taking returns to surface, maintain backpressure as necessary to prevent cement from running away with 9ppg brine chasing 15.3 ppg cement. b. Cement volumes i. Wellbore volume below retainer to perfs in 7” (±2bbls) ii. OA volume from perfs at 1806’ to 1250’ (±39bbls) iii. Total volume = 41 bbls c. Chase the cement with 9ppg brine 21. Wait on cement (based on samples and cementers test) 22. Pressure test the 11-3/4” x 7” annulus to 1500 psi, chart for 30 min. 23. Bleed all pressures to 0psi, and ensure well is dead a. Hold open bleed on IA and OA for 30 min, confirm no flow b. SI well for 30 min and confirm no pressure build on IA or OA 24. RIH with 7” casing cutter and cut casing at 1150’, pressure test OA for 10 min to ensure 7” cutter did not cut through 11-3/4”. 25. Remove BOP’s from wellhead (This same procedure was completed in October in Swanson River Well 12-15 (PTD# 160-022)) 26. Remove casing hanger snap rings and primary seal plates (over sized 1960 technology, and will not fit through 13-5/8” BOP’s) 27. Reinstall BOP’s 28. Test broken connection between BOP’s and casing head a. Will be testing against tested cement plug below b. It is not possible to use a test joint / plug / etc… c. Test to 250psi low / 1500psi high d. If fails on BOP criteria, consult inspectors about using rolling BOP test criteria / procedure to verify leak is downhole and not at surface. 29. Spear 7” casing, and pull from prior cut 30. RU Eline and run CBL in 11-3/4” to find cement and casing collars. 31. Set 11-3/4” bridge plug at approx. 1010’ MD avoiding collars for whipstock. Tag plug after it is set. 32. NU RDMO rig 401 Contingency #1: If no communication from perfs @ 1,806’ to surface via the OA, move up and repeat steps 9 and 10 from 1,706’ MD and try to establish communication 1.1 PU and RIH with 7” cement retainer on workstring 1.2 Set 7” cement retainer at ~1756 1.3 Confirm injectivity below retainer and up OA for a suicide squeeze 1.3a. If unable to get circulation from below retainer and above to upper perfs at 1706. squeeze in a plug below the retainer and above the retainer. 1.4 RU cementers 1.5 Provide agencies 24hr notification to witness abandonment activities below 1.6 Circulate cement up the 13-3/8” x 7” annulus through the open perf sets as follows: 1.6a. Ensure OA is open, taking returns to surface 1.6b. Cement volumes x Wellbore volume below retainer in 7” (±2bbls) x OA volume between perfs’ 1806- 1706’ (±4bbls) x Wellbore volume above retainer in 7” (±2bbls) x Contingency volume to pump 100% Excess x Total volume = 16 bbls 1.7 Wait on cement per rep to set Adjust casing punch and retainer depth as needed to achieve conditions of approval. -bjm 43 bbls. -bjm 4 bbls -bjm Well: SRU 23-33 Pre-sidetrack Decomplete 1.8 RU Eline, RIH and tag top of cement 1.9 Pressure test 7” to 1500 psi, chart for 30 min 1.10 Return to step 23 above Attachments: 1. Current schematic 2. Proposed Schematics 3. Current wellhead schematic 4. Proposed Wellhead schematic 5. Yellowjacket BOP’s (13-5/8” with additional ram for 7”) 6. BOP test procedure 7. AOGCC RWO Change Form ___________________________________________________________________________________ Updated by DMA 07-18-17 SCHEMATIC Swanson River Unit Well: SRU 23-33 Completion Date: 9/29/2010 PTD: 161-019 API: 50-133-10163-00 2 TD =10,895’ PBTD = 10,797’ 6 11-3/4” @ 1,756’ 2,631’ KB-THF: 15.0’ KB 7” @ 10,895’ 2-3/8” Chemical Injection Sub MOC 1 15 222” @ 28’ 1 RKB: 154’ KB / GL: 139’AMSL 5 32 9 7 11 13 14 8 4 10 12 16 17 5A 10.2 PPG KW Aquagel MUD DV Collar 6,990’ CBL Top: 2,550’ H-1 H-2 H-3 H-4 Tight Casing 10,684’RKB 10/08/87 Tag Fill 10,572’ SLM 2/10/03 CBL Top: 9,210’ G Top of Pack 10,531’ WLM 10/17/87 Sterling B-2 Sterling B-3 Directional Data: max = 2.25° at 7,083’ CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22”Conductor -Surface 28’-Cemented 11-3/4”Surface 47#, J-55 Surface 1,756’8RD / 11.000”1200 sx / Cmt to Surface 7” Production 29#, N-80 Surface 81’BTC / 6.184”1800 sx / Cmt to x,275’ 26#, N-80 81’1,019’BTC / 6.276” 23#, N-80 1,019’4,712’BTC / 6.366” 26#, N-80 4,712’6,541’BTC / 6.276” 29#, N-80 6,541’6,990’BTC / 6.184” 6,990’6,992’DV Collar 29#, N-80 6,992’8,411’BTC / 6.184”700 sx / Cmt to x,265’ 29#, P-110 8,411’10,895’8RD / 6.184” *7” Marker Jt at 10,519.49’ (12.63’) TUBING 2-3/8”Production 4.6#, L80 Surface 2,631’TC-II-/ 2.055”Rethreaded Tubing PRODUCTION STRING JEWELRY DETAIL No.Depth (RKB)Length ID OD Item 1 15.0’0.52’2.992”6.000”Tubing Hanger 3-1/2” TC-II 15.7’1.24’1.995”2.375”X-Over 3-1/2” TC-II Pin x 2-3/8” TC-II Pin 1,514’ 2.76’ 1.995”3.783”2-3/8” Chemical Injection Sub Assembly – TC-II Thread using ¼” SS Tubing (MOC 1) 1.995”2.675”Tubing, 2-3/8” 4.6# TC-II 2 2,546’ 7.21’2.910”4.250” 2-3/8” GL Mandrel, SFO-1 BK-2 Latch w/ DV NOTE: Mandrels cut for 2-3/8” IBT Mod Pups will cross these to TC-II Box Up, Pin Down 28.7’1.995”2.375"Tubing, 2-3/8” 4.6# TC-II 32,604’ 7.2’2.910”4.250” 2-3/8” GL Mandrel, SFO-1 BK-2 Latch w/ Orifice NOTE: Mandrels cut for 2-3/8” IBT Mod Pups will cross these to TC-II Box Up, Pin Down 2,630’3.07’3.25”5.68”Baker Oil Tool E Latch Assembly (TC-II Box Up) 4 2,631 6.1”Packer, Model D (E-Line Set) 52,644’ 1.01’1.875”Baker 2-3/8” X-Profile Nipple (NOTE: Cut for IBT-MOD x 2- 3/8” IBT P Down (x-over:2-3/8” IBT - 8 RND Pin DN) 5A 2,635’2-3/8” Tubing Plug 2,647’1.57’WLEG w/ tubing release ( Slickline Shift to drop) >3,000’2ea 5ft 1-11/16” strip gun assemblies >3,000’92.43’1.995”Tubing, 2-3/8” 4.6# 8 RND EUE 0.7’1.995”Fill Disk Assembly, 8 RND EUE 8.06’1.995”2-3/4” Model II-D FH (Acme x 8 RND EUE) 0.9’1.995”2-3/8” WLEG from Auto Release Upper Section 6 6,645’404’Cement Plug 7 7,049’BOT N1 Bridge Plug w/ 404’ CMT On Top 8 10,380’BOT K1 Cement Retainer w/ 548’ CM On Top 9 10,476’4.18’4.000”5.968”Baker SC-1L packer (Set 10/15/87) 10 10,499’0.81’3.000”5.560”XO Sub 11 10,500’1.01’3.00”5.160”Gravel Pack Safety Joint, 3-1/2” 10RD 53k shear 12 10,501’118.14’2.992”3.500”Blank Pipe w/ welded centralizers 3-1/2” 10RD 13 10,619’118.13’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 14 10,737’0.53’2.500”4.250”O-Ring Seal Sub 15 10,738’10.12’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 16 10,748’1.40’2.439”4.250”S-22 Indicating Seal Assembly w/ 2’ of seals 17 10,749’?3.250”5.687”Baker Model D Sump packer (Set 10/12/87) PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)SPF Condition B2 2,708’2,714’2,708’2,714’6 SPF 1-11/16” strip guns 2 runs(12/7/12) B3 2,802'2,810'2,802'2,810'12 SPF 4-5/8” Millennium TCP 9-27-2010 G 10,552’10,570’10,552’10,570’4 Perf 5/19/02 (1-11/16”, 0 deg) (ABANDONED 9-25-2010) H1 10,630’ 10,657’ 10,630’ 10,657’4,4,12,2 Perf 6/9/61, ½” EH, 2/63, 10/87, 3/95(ABANDONED 9-25- 2010) H2 10,669’ 10,688’ 10,669’ 10,688’ 4,4,12 Perf 6/9/61, ½” EH, 2/1/63, 10/10/87(ABANDONED 9-25- 2010) H3 10,697’10,701’10,697’10,701’4,12 Perf 6/9/61, ½” EH, 10/10/87(ABANDONED 9-25-2010) H4 10,720’10,725’10,720’10,725’4 Perf 6/8/61, ½” EH(ABANDON 9-25-2010) Note: The fluid control valve (FCV) for this well was set at 1,000 psi on 8/2012. The serial number on this valve is 040800161. ___________________________________________________________________________________ Updated by CAH 01-19-23 PROPOSED Swanson River Unit Well: SRU 23-33 Completion Date: 9/29/2010 PTD: 161-019 API: 50-133-10163-00-00 2 TD =10,895’ PBTD = 10,797’ 6 11-3/4” @ 1,756’ 2,631’ KB-THF: 15.0’ KB 7” @ 10,895’ Cement Min 50’ above & Below casing shoe 15 222” @ 28’ RKB: 154’ KB / GL: 139’AMSL 5 3 9 7 11 13 14 8 4 10 12 16 17 5A 2 10.2 PPG KW Aquagel MUD DV Collar 6,990’ CBL Top: 2,550’ H-1 H-2 H-3 H-4 Tight Casing 10,684’RKB 10/08/87 Tag Fill 10,572’ SLM 2/10/03 CBL Top: 9,210’ G Top of Pack 10,531’ WLM 10/17/87 Sterling B-2 Sterling B-3 9.0 PPG Brine Directional Data: max = 2.25° at 7,083’ CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22”Conductor -Surface 28’-Cemented 11-3/4”Surface 47#, J-55 Surface 1,756’8RD / 11.000”1200 sx / Cmt to Surface 7” Production 29#, N-80 Surface 81’BTC / 6.184”1800 sx / Cmt to x,275’ 26#, N-80 81’1,019’BTC / 6.276” 23#, N-80 1,019’4,712’BTC / 6.366” 26#, N-80 4,712’6,541’BTC / 6.276” 29#, N-80 6,541’6,990’BTC / 6.184” 6,990’6,992’DV Collar 29#, N-80 6,992’8,411’BTC / 6.184”700 sx / Cmt to x,265’ 29#, P-110 8,411’10,895’8RD / 6.184” *7” Marker Jt at 10,519.49’ (12.63’) TUBING PRODUCTION STRING JEWELRY DETAIL No.Depth (RKB)Length ID OD Item 2 ±1,010’2’0”10.84”11-3/4” CIBP 3 ±1,750’ 2’ 6.24 7” CIBP 2,630’3.07’3.25”5.68”Baker Oil Tool E Latch Assembly (TC-II Box Up) 4 2,631 6.1”Packer, Model D (E-Line Set) 52,644’ 1.01’1.875”Baker 2-3/8” X-Profile Nipple (NOTE: Cut for IBT-MOD x 2- 3/8” IBT P Down (x-over:2-3/8” IBT - 8 RND Pin DN) 5A 2,635’2-3/8” Tubing Plug 2,647’1.57’WLEG w/ tubing release ( Slickline Shift to drop) >3,000’2ea 5ft 1-11/16” strip gun assemblies >3,000’92.43’1.995”Tubing, 2-3/8” 4.6# 8 RND EUE 0.7’1.995”Fill Disk Assembly, 8 RND EUE 8.06’1.995”2-3/4” Model II-D FH (Acme x 8 RND EUE) 0.9’1.995”2-3/8” WLEG from Auto Release Upper Section 6 6,645’404’Cement Plug 7 7,049’BOT N1 Bridge Plug w/ 404’ CMT On Top 8 10,380’BOT K1 Cement Retainer w/ 548’ CM On Top 9 10,476’4.18’4.000”5.968”Baker SC-1L packer (Set 10/15/87) 10 10,499’0.81’3.000”5.560”XO Sub 11 10,500’1.01’3.00”5.160”Gravel Pack Safety Joint, 3-1/2” 10RD 53k shear 12 10,501’118.14’2.992”3.500”Blank Pipe w/ welded centralizers 3-1/2” 10RD 13 10,619’118.13’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 14 10,737’0.53’2.500”4.250”O-Ring Seal Sub 15 10,738’10.12’2.992”4.000”Johnson Screens, 0.20” 3-1/2” 10RD centralized 16 10,748’1.40’2.439”4.250”S-22 Indicating Seal Assembly w/ 2’ of seals 17 10,749’?3.250”5.687”Baker Model D Sump packer (Set 10/12/87) PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)SPF Condition B2 2,708’2,714’2,708’2,714’6 SPF 1-11/16” strip guns 2 runs(12/7/12) B3 2,802'2,810'2,802'2,810'12 SPF 4-5/8” Millennium TCP 9-27-2010 G 10,552’10,570’10,552’10,570’4 Perf 5/19/02 (1-11/16”, 0 deg) (ABANDONED 9-25-2010) H1 10,630’ 10,657’ 10,630’ 10,657’4,4,12,2 Perf 6/9/61, ½” EH, 2/63, 10/87, 3/95(ABANDONED 9-25- 2010) H2 10,669’ 10,688’ 10,669’ 10,688’ 4,4,12 Perf 6/9/61, ½” EH, 2/1/63, 10/10/87(ABANDONED 9-25- 2010) H3 10,697’10,701’10,697’10,701’4,12 Perf 6/9/61, ½” EH, 10/10/87(ABANDONED 9-25-2010) H4 10,720’10,725’10,720’10,725’4 Perf 6/8/61, ½” EH(ABANDON 9-25-2010) Note: The fluid control valve (FCV) for this well was set at 1,000 psi on 8/2012. The serial number on this valve is 040800161. Swanson River SRU 23-33 Current 01/12/2023 Casing head, Shaffer KD, 13 5/8 3M X 11 3/4 SOW, w/ 2- 2'’ LPO, 7'’ KD slips and packoff assy in head Tubing head, Vetco FTC-IT, 11'’ 3M X 7 1/16 5M w/ 2- 2 1/16 5M SSO, BG bottom Swanson River SRU 23-33 11 3/4 X 7 X 2 3/8 Double studded packoff, 13 5/8 3M X 11 3M, prepped for 7'’ casing stub top and bottom Tbg hanger, Vetco FTC-1A-EN, 7 X 3 ½ TC-2 susp X 3 ½ EUE lift, w/ 3'’ Type H BPV profile, ¼ CCL, 5.5'’ neck Adapter, Vetco, FTC-EN, 7 1/16 5M FE x 3 1/8 5M, prepped for 5 ½ hanger neck Valve, master, VG-M, 3 1/8 5M FE, HWO, DD Valve, upper master, VG-M, 3 1/8 5M FE, HWO, DD Valve, swab, VG-M, 3 1/8 5M FE, HWO, DD 11 ¾’’ 7'’ 2 3/8'’ Swanson River SRU 23-33 Proposed 01/18/2023 Casing head, Shaffer KD, 13 5/8 3M X 11 3/4 SOW, w/ 2- 2'’ LPO Swanson River SRU 23-33 Proposed-post Rig 401 11 ¾’’ OPEN AND CLOSE DATA OPEN CLOSE 13-5/8" 5M ANNULAR 17.41 23.58 13-5/8" 5M RAMS (PER CAVITY) 5.5 5.8 4-1/16" 5M HCR 0.61 0.52 ϭϯͲϱͬϴΗ/^&KZ' EEh>Z ϭϯͲϱͬϴϱDD ZKEKh> dzW hKW ^dZ/',dKZ ZD^ϮͲϯͬϴΗ >/EZD^KddKD ϭϯͲϱͬϴΗϱDKW^d< tͬ^/E'> ϭϯͲϱͬϴϱDD ZKE^/E'> dzW hKW sZZD^ϰͲϭͬϮΗdKϳΗ ,K< ^/ ϰͲϭͬϭϲΗϱDDEh>/E^/ ϰͲϭͬϭϲΗϱD,ZKhd^/ ϰͲϭͬϭϲΗyϮͲϭͬϭϲΗϱD^Khd^/ </>> ^/ ϰͲϭͬϭϲΗϱDDEh>/E^/ ϰͲϭͬϭϲΗϱDDEh>Khd^/ ϰͲϭͬϭϲΗyϮͲϭͬϭϲΗϱD^Khd^/ ϭϯͲϱͬϴΗϱDZ/>>/E'^WKK> tͬϰͲϭͬϭϲΗϱD^/ Khd> d^ Rig 401 BOP Test Procedure Hilcorp Alaska, LLC - BOP Test Procedure: Rig 401, WO Program Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. x Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 401 BOP Test Procedure f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ~ 1200 psi and bleed off 200 – 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 401 BOP Test Procedure g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SRU 23-33 (PTD 161-019) Sundry #: 323-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date From:McLellan, Bryan J (OGC) To:Chad Helgeson Subject:RE: [EXTERNAL] SRU 23-33 (PTD 161-019) CBL Date:Wednesday, February 1, 2023 10:31:00 AM Chad, Hilcorp has conditional verbal approval to perform the proposed pre-rig slickline work outlined in the Sundry application submitted on 1/24/23 for “Plug for Redrill” on this well. Ensure tubing cut allows enough room to place top of CIBP inside 7" casing deeper than 2605' MD, referenced to 7" CBL dated 6/7/1961. A variance will be required. Variance to 20 AAC 25.112(c)(1)(E) for placing cement plug >50' above perfs, approved on the following conditions: Reservoir cement plug inside 7" casing must be set on top of bridge plug and placed across annular cement 2592-2604' MD. Secondary cement job at surface casing shoe must have at least 50' of cross-sectional coverage with cement outside surface casing, Ð inside 11" x 7" annulus and inside 7" casing. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Wednesday, February 1, 2023 9:44 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: [EXTERNAL] SRU 23-33 (PTD 161-019) CBL Chad, A couple issues with the plan: The proposed abandonment plug in the 7” casing is >50’ above the top perf. Does Hilcorp want to ask for a variance to 20 AAC 25.112(c)(1)(E)? I don’t agree with the diagram that calls TOC outside 7” casing at 2550’ MD. The shallowest good cement based on the log is probably 2592-2604’ MD, so you’ll need to set a bridge plug in the 7” casing below 2605’ MD (corrected to this CBL) and place the planned 37.5’ long cement inside the 7” on top of the bridge plug and across this depth from 2592-2604’ MD. I’m still reviewing the annular cement and contingency plan. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, February 1, 2023 7:06 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] SRU 23-33 (PTD 161-019) CBL Attached is a scan of the CBL from 2000-3000’. The depths don’t match exactly page to page (there is a little overlap), but the top 1000’ of the log is there. I will have one of our Geotech’s submit a tiff file (large file) of the entire CBL to the state through the access portal that we upload new logs to as well. If you have any questions on this let me know. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, January 31, 2023 2:19 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] SRU 23-33 (PTD 161-019) CBL Chad, Can you send me the CBL for the 7” casing in this well? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 RECEIVED STATE OF ALASKA � FEB 2 2013 . ALI. OIL AND GAS CONSERVATION COMMIa5ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Lj Repair Well 11 Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ 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 ❑ 161 -019 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic Service ❑ 6. API Number: --• ®® Anchorage, Alaska 99504 f• 50- 133 - 10163 -00 7. Property Designation (Lease Number): 8. Well Name and Number: i FEDA028399 ' Swanson River Unit (SRU) 23 -33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Sterling Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,895 feet Plugs measured 6,645 (cement) feet true vertical 10,895 feet Junk measured N/A feet Effective Depth measured 6,645 feet Packer measured 2,631 feet true vertical 6,645 feet true vertical 2,631 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,756' 11 -3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED MAR 20 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6# / L -80 2,631' MD 2,631' TVD 2,631' MD Packers and SSSV (type, measured and true vertical depth) Baker Model D 2,631' 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 0 200 1,020 Subsequent to operation: 0 0 0 440 1,000 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ , Gas IS 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: Contact Chad Helgeson Email chelgesonAhilcoro.com Printed Name �Chad Helgeson Title Operations Manager Signature .Z j G _ z./ , Phone 907 - 777 -8405 Date / / / 3 666 `�i�� ► � R9DMS FEB 2 6 z �� Z• 2 7. (.3 Form 10-404 Revised 10/2012 41 4 ��� Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23 -33 50- 133 - 10163 -00 161 -019 11/28/12 12/7/12 Daily Operations: 11/28/2012- Wednesday MIRU slickline -PT Lub & WLV -good, RIH w /2" 42 BO Shift Tool w /Positive Key to 2,640' WL (2,655' KB) latch jar up came free pooh, RIH w /TT Locater w/1.7" Swedge to 2,782' KB pull up to 2,642' WL (2,657' KB) locate tubing tail -pooh, OOH R/D Slickline -park at PS pad 12/07/2012- Friday MIRU Pollard E -Line Unit, RU lubricator and Tested to 3,000 psi, MU 6 ft 1- 11/16 ". Snake exposed perforating 6 SPF gun, RIH to 2,830'. Correlated to SLB Packer setting record. Placed gun on depth @ 2,708'- 2,714' and fired guns. Attempted to POOH, gun hung up at Re -Entry guide on EOT @ 2,651'. Worked free and POOH, only had 6 inches of gun left on E -Line. MU 2.75" GR, RIH down through end of tubing to ensure clear. POOH, MU 2nd Gun and RIH, Correlated on depth of 2,708'- 2,714'. Fired second gun and perforated. Attempted to POOH, again gun got stuck @ 2,651'. Worked gun free and POOH, RDMO Pollard E -Line Unit. III Swanson River Unit • Well: SRU 23 -33 SCHEMATIC Completion Date: 9/29/2010 PTD: 161 -019 Hilcorp Alaska, LLC API: 50- 133 - 10163 -00 RKB: 154' KB / GL: 139' AMSL KB -THF: 15.0' KB CASING DETAIL Ct - Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" Conductor - Surface 28' - Cemented 22"81 28' =' 11 -3/4" Surface 47 #, J -55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29 #, N -80 Surface 81' BTC / 6.184" 1800 sx / Cmt to x,275' 26 #, N -80 81' 1,019' BTC / 6.276" s 23 #, N -80 1,019' 4,712' BTC / 6.366" f 1 26 #, N -80 4,712' 6,541' BTC / 6.276" ,. 2-3/8' Chemical 7" Production Injection Sub 29 #, N -80 6,541' 6,990' BTC / 6.184" MOC 6,990 6,992' DV Collar 11J/a" 1,758' ✓ 29 #, N -80 6,992' 8,411' BTC / 6.184" 700 sx / Cmt to x,265' CBL Top: 2,550' 4 29 #, P -110 8,411' 10,895' 8RD / 6.184" • / *7 "Marker ltat10,519.49'(12.63) 2s TUBING r T .. , i 1 2 -3/8" 1 Production 1 4.6#, L80 1 Surface 1 2,631' 1 TC -II -/ 2.055" 1 Rethreaded Tubing Sterling B -2 st' Sterling B-3 PRODUCTION STRING JEWELRY DETAIL a b 0 No. Depth (RKB) Length ID OD Item p 1 15.0' 0.52' 2.992" 6.000" Tubing Hanger 3 -1/2" TC -II s `r AC : . 6 15.7' 1.24' 1.995" 2.375" X -Over 3 -1/2" TC -II Pin x 2 -3/8" TC -II Pin DV Collar „1. 1,514' 2.76' 1.995” 3.783" 2 -3/8" Chemical Injection Sub Assembly — TC -II Thread 6,990' ;' ' using'' /." SS Tubing (MOC 1) 7 1.995" 2.675" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV NOTE: 2 2,546' 7.21' 2.910" 4.250" Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 28.7' 1.995" 2.375" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice NOTE: 3 2,604' 7.2' 2.910" 4.250" Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 2,630' 3.07' 3.25" 5.68" Baker Oil Tool E Latch Assembly (TC -II Box Up) 10.2 PPG KW 4 2,631 6.1" Packer, Model D (E -Line Set) Aquagel MUD Baker 2 -3/8" X- Profile Nipple (NOTE: Cut for IBT -MOD x 2- CBL Top: 9,210' 5 2,644' 1.01' 1.875" 3/8" IBT P Down (x- over:2 -3/8" IBT 8 RND Pin DN) , 2,647' 1.57' WLEG w/ tubing release ( Slickline Shift to drop) >3,000' 2ea 5ft 1- 11/16" strip gun assemblies >3,000' 92.43' 1.995" Tubing, 2 -3/8" 4.6# 8 RND EUE e 0.7' 1.995" Fill Disk Assembly, 8 RND EUE 8.06' 1.995" 2 -3/4" Model II -0 FH (Acme x 8 RND EUE) * '• ' a 0.9' 1.995" 2 -3/8" WLEG from Auto Release Upper Section , j � 1 6 6,645' 404' Cement Plug < 41 4. ° " +'±' 8 7 7,049' BOT Ni Bridge Plug w/ 404' CMT On Top 1 Top of Pack : ' s 8 10,380' BOT K1 Cement Retainer w/ 548' CM On Top 10,531' WLM _. 9 9 10,476' 4.18' 4.000" 5.968" Baker SC -1L packer (Set 10/15/87) 10/17/87 r 10 10,499' 0.81' 3.000" 5.560" XO Sub 7a Fill 1 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3 -1/2" 1ORD 53k shear 9 10,572' SLM ` k ,, G 12 10,501' 118.14' 2.992" 3.500" Blank Pipe w/ welded centralizers 3 -1/2" 1ORD 2/10/03 13 •? {? ti ? ; ? ?t_ 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3 -1/2" 10RD centralized VS tite . •? H - 1 Tight Casing ?* "f {f tir;? _ H.2 14 10,737' 0.53' 2.500" 4.250" 0 -Ring Seal Sub 10,684' RKB •f tir , 1 '1 ? • I 10/08/87 . 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3 - 1/2" 1ORD centralized r .. ' }r :'• : 44.0.1.1.7 7 H - 3 - .0 .0 = 16 10,748' 1.40' 2.439" 4.250" S -22 Indicating Seal Assembly w/ 2' of seals 14 17 10,749' ? 3.250" 5.687" Baker Model D Sump packer (Set 10/12/87) 15r 16 :; 17`, ` 7" @ 1O,895' 41 4 PERFORATIONS TD = 10,895' PBTD = 10,797' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Condition 82 2,708' 2,714' 2,708' 2,714' 6 SPF 1- 11/16" strip guns 2 runs(12 /7/12) Directional Data: B3 2,802' 2,810' 2,802' 2,810' 12 SPF 4 -5/8" Millennium TCP 9 -27 -2010 max = 2.25° at 7,083' G 10,552' 10,570' 10,552' 10,570' 4 Perf 5/19/02 (1- 11/16 ", 0 deg) (ABANDONED 9 -25 -2010) Hl 10,630' 10,657' 10,630' 10,657' 4,4,12,2 Perf 6/9/61,34" EH, 2/63, 10/87, 3 /95(ABANDONED 9 -25- 2010) H2 10,669' 10,688' 10,669' 10,688' 4,4,12 Perf 6/9/61, %" EH, 2/1/63, 10 /10 /87(ABANDONED 9 -25- 2030) H3 10,697' 10,701' 10,697' 10,701' 4,12 Perf 6/9/61, 'A" EH, 10 /10 /87(ABANDONED 9 -25 -2010) H4 10,720' 10,725' 10,720' 10,725' 4 Perf 6/8/61,Y." EH(ABANDON 9 -25 -2010) Note: The fluid control valve (FCV) for this well was set at 1,000 psi on 8/2012. The serial number on this valve is 040800161. Updated by DMA 02 -25 -13 STATE OF ALASKA RECEIVED AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS SEP 1 4 2012 1. Operations Abandon U Repair Well U Plug Perforations U Perforate [J Ott iQ 3: On Install Performed: Alter Casing ❑ Pull Tubing 0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development IS Exploratory ❑ — 161 -019 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: Alaska 99503 50- 133 - 10163 -00 -00 7. Property Designation (Lease Number): ti . 8. Well Name and Number: Gs FEDA028399 Swanson River Unit (SRU) 23 -33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Swanson River Field / Sterling Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,895 feet Plugs measured 6,645 (cement) feet true vertical 10,895 feet Junk measured N/A feet Effective Depth measured 6,645 feet Packer measured 2,631 feet true vertical 6,645 feet true vertical 2,631 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,756' 11 -3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6# / L -80 2,631' 2,631' 2,631' MD Packers and SSSV (type, measured and true vertical depth) Baker Model D 2,631' 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: 0 0 0 300 120 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development El '• Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas p r 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: N/A Contact Chad Helgeson Phone: 907 - 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature ‘Z.//,� u / Phone 907 - 777 -8405 Date / / �T �/ // 4Z DMS SEP 17 ?812 p -'/ l 74 Z -1 J' G1NAL V W17.--- Form 10-404 Revised 11/2011 q f .1 / i v Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23 -33 50- 133 - 10163 -00 161 -019 8/10/12 8/10/12 Daily Operations: 8/10/2012 - Friday Line injector over WH, lower and thread WPA into WHA. Pressure the WPA hydraulic seal to 3,000 psi. Pressure test. Rig - down chemical pump, close WPA ball valve, bleed off all pressure and remove the manifold from the WPA. Install plug in ball valve. RIH to setting depth. 5 feet per minute through the tree. 10 -30 feet per minute to 200 feet, gradually increase RIH speed as the tubing RIH. RIH to 2,802'. POOH to 2,792'. Set Slips. Set Rattigan's. Release pressure on skates to 0. Reduce spool back - pressure to 0. Lift injector off of well and lift to approx 10 feet, watch weight indicator < 500 lbs force to lift. Apply 50 -100 psi to skates and run out tubing tail. Install slip retainer pins. Place 3,000 psi on WPA hydraulic seals, close needle valve on WPA, bleed off hose and remove. Insert hydraulic plug. Rig -down. RD /MO. Secure area. A • • 1 SCH E M ^ � Swanson River Unit J fl C I V'!1 Well SRU 23 -33 • m L Completed 9/29/2010 liilcoru Alaska, LLC p Casing and Tubing Detail RKB: 154' KB / GL: 139' AMSL KB -THF: 15.0' KB Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 1 22" Conductor - Surface 28' - Cemented 4, 11 -3/4" Surface 478,1 -55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 22" 28' `,+ 29 #, N -80 Surface 81' BTC / 6.184" 1800 sx / Cmt to x,275' ? 268, N -80 81' 1,019' BTC / 6.276" 238, N -80 1,019' 4,712' BTC / 6.366" 268, N -80 4,712' 6,541' BTC / 6.276" 2 - 3/8 " Chemical 7 Production Injection sub 298, N -80 6,541' 6,990' BTC / 6.184" r! MCC 1 6,990 6,992' DV Collar 11 - 3 4 298, N -80 6,992' 8,411' BTC / 6.184" 700 sx / Cmt to x,265' CBL Top: 2,550' * I 298, P -110 8,411' 10,895' 8RD / 6.184" 2631' Tubing *7" Marker ft at 10,519.49' (12.63') 2 -3/8" Production 4.6#,L80 Surface 2,631' TC -II- /2.055" RethreadedTubing Sterling B - 2 S.S..049" Cap String e. 3/8" Cap String Surface 2,792' Surface to Wall 2,792' f =Sterling B — Production String Jewelry Detail . + r "411.1 6 No. Depth (RKB) Length ID OD Item ` #' 1 4 1 15.0' 0.52 2.992" 6.000" Tubing Hanger 3 -1/2" TC -11 DV Collar p ' a" '� 6,990 ".. '" "* ''. 15.7' 1.24 1.995" 2.375" X -Over 3 -1/2" TC -II Pin x 2 -3/8" TC -II Pin N.— " " 1514 2.76 1.995 3.783 2 -3/8" Chemical Injection Sub Assembly — TC-II Thread 7 using 34" SS Tubing (MOC 1) 1.995" 2.675" Tubing, 2 -3/8" 4.6# TC -11 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV NOTE: 2 2546' 7.21' 2.910" 4.250" Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 28.7' 1.995" 2.375" Tubing, 2 -3/8" 4.68 TC-Il 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice NOTE: 3 2604' 7.2' 2.910" 4.250" Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to 10.2 PPG KW TC -ll Box Up, Pin Down Aquagel MUD 2630' 3.07 3.25 5.68 Baker Oil Tool E Latch Assembly (TC -11 Box Up) CBL Top: 9,210' - > 4 2631 6.1" Packer, Model D (E -Line Set) „ 5 2644' 1.01 1.875" Baker 2 -3/8" X- Profile Nipple (NOTE: Cut for IBT -MOD x 2- 3/8" IBT P Down (x- over:2 -3/8" IBT - 8 RND Pin DN) 2647' 1.57 WLEG w/ tubing release ( Slickline Shift to drop) '. 92.43 1.995" Tubing, 2 -3/8" 4.68 8 RND EUE 1' 2741' 0.7 1.995" Fill Disk Assembly, 8 RND EUE 2772' 8.06' 1.995" 2 -3/4" Model II -D FH (Acme x 8 RND EUE) + s 4 2782' 0.9 1.995" 2 -3/8" WLEG from Auto Release Upper Section Top of Pack ' c - t a.. 6 6,645' 404' Cement Plug 10,531' WL■ ,,,411 ''''',°.° 8 i 10/17/87 a7 + 7 7049 BOT Ni Bridge Plug w/ 404' CMT On Top , 8 10,380' BOT Kl Cement Retainer w/ 548' CM On Top Tag Fill .� g 9 10,476' 4.18' 4.000" 5.968" Baker SC -1L packer (Set 10/15/87) 10,572' SLM ' 10,499' 0.81' 3.000" 5.560" XO Sub 2/10/03 1 ' 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3 -1/2" 1ORD 53k shear ' 41 G ;_ • ? {,ti S {{ 12 10,501' 118.14' 2.992" 3.500" Blank Pipe w/ welded centralizers 3 -1/2" lORD r;. •r•r Ng,: • r•+`. 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3 -1/2" 1ORD centralized Tight Casing ,w _H - 1 ti. ti.ti 14 10,737' 0.53' 2.500" 4.250" 0 Seal Sub 10,684' RKB •rti ' A , ti; {EH - 2 10108/87 • ..17.„ .1::,,r 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3 -1/2" lORD centralized 13'. ft. ' 47 H -3 16 10,748' 1.40' 2.439" 4.250" S -22 Indicating Seal Assembly w/ 2' of seals 14 •'' ti•ti H-4 17 10,749' ? 3.250" 5.687" Baker Model D Sump packer (Set 10/12/87) 15; Perforation Data 7" (a 10,895' ZONE TOP(MD) BTM(MD) TOP(TVD) BTM(TVD) SPF Condition TD = 10,895' PBTD = 10,797' 63 2,802' 2,810' 2,802' 2,810' 12 SPF 4 -5 /8" Millennium TCP 9 -27 -2010 G 10,552' 10,570' 10,552' 10 4 Perf 5/19/02 (1- 11/16 ", 0 deg) (ABANDONED 9 -25 -2010) Directional Data: max = 2.25° at 7,083' H1 10,630' 10,657' 10,630' 10,657' 4,4,12,2 Perf 6/9/61, Y :" EH, 2/63, 10/87, 3 /95(ABANDONED 9 -25- 2010) H2 10,669' 10,688' 10,669' 10,688' 4,4,12 Perf 6/9/61,16" EH, 2/1/63, 10 /10 /87(ABANDONED 9 -25- 2030) H3 10,697' 10,701' 10,697' 10,701' 4,12 Perf 6/9/61, h" EH, 10 /10 /87(ABANDONED 9 -25 -2010) H4 10,720' 10,725' 10,720' 10,725' 4 Perf 6/8/61, 34" EH(ABANDON 9 -25 -2010) Note: The fluid control valve (FCV) for this well was set at 1,000psi on 8/2012. The serial number on this valve is 040800161. Updated by TDF 8/17/2012 • • slitz[E oF tiaAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager r Union Oil Company of Californian AP 0 (Q C `� P.O. Box 196247 \Ito Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, SRU 23 -33 Sundry Number: 311 -114 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. 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, /% 0 Daniel T. Seamount, Jr. /% Chair DATED this U day of April, 2011. Encl. • RECEJV STATE OF ALASKA rb \pp 9 5 2,0lL ` // ALASKA OIL AND GAS CONSERVATION COMMISSION WAN APPLICATION FOR SUNDRY APPROVALS Masks OA & Gas Cons. o` 2ou 20 AAC 25.280 'rr - r , �il p 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Appfo`ve P'roijram ❑ Suspend ❑ Plug Perforations el Perforate 0 - Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 - Exploratory ❑ 161 -019 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 133 - 10163 -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 Swanson River Unit (SRU) 23 -33 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028399'[Swanson River Unit) Swanson River Field / Hemlock Oil & Sterling Undef Gas 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): 10,895 10,895 6,645 6,645 6,645 (cement) N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,756' 11 -3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft):/ Perforation Depth TVD (ft): Tubing Size: / Tubing Grade: Tubing MD (ft)y 2,802 -2,810 2,802 -2,810 2 -3/8" 4.6#, L80 4031, Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): --- Model D / N/A 2,631 MD and 2,631 TVD / N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: /15/ X 11 Commencing Operations: Oil ❑ Gas 0 - WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ GINJ WAG ❑ Abandoned ❑ PP ❑ ❑ Commission Representative: P GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 4/4/2011 COMMISSION USE ONLY t l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 i r /! Plug Integrity V BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: • Subsequent Form Required: i 0 — q. O 4 0 , APPROVED BY Approved by: 1 - COMMISSIONER THE COMMISSION Date: 416 1 l Form 10-403 Revised 1/2010 — c� R 1 G 1 N A L Submit in Duplicate Chevron • • Swanson River ft . SRU 23 -33 %. 4/04/11 OBJECTIVES: • Abandon the B -3 sand and perforate the Sterling B -2 sand. • Current BHP: 1215 psi @ 2802' TVD Max Dow ole Pressure: 1251 psi @ 2707' TVD (Based on Sterling B3 sand) MASP: 80 psi (Based on a pressure gradient of 0.1 psi/ foot of TVD) PROCEDURE SUMMARY: 1. RU slickline. Pressure test lubricator 250psi low /2500psi high. 2. RIH with gauge ring to ( + / -) 3,000'. 3. RIH with releasing tool and release tubing tail at ( + / -) 2,647'. 4. RIH with dummy gun to ( + / -) 2,850'. -" 5. Rig down slickline. 6. RU E -line. Pressure test lubricator 250psi low /2500psi high. 7. Set 7" plug at ( + / -) 2,790'. • 2$V / 8. Dump bail ( + / -) 35' of cement on top of plug. WOC 24 hrs 9. Perform 12 hr negative /12 hr positive pressure tests. Chart test. 10. RIH and tag top of cement at ( + / -) 2,755'. 11. Perforate the Sterling B -2 sand ( + / -) 2,707' to ( + / -) 2,712'. / 12. Rig down E -line and turn well over to production. evro • Swanson River Unit SRU 23 -33 Well SRU 23 -33 414■../..° P ropose d W e ll bore Schematic Last C 9/29/2010 RKB: 154' KB / GL: 139' AMSL KB -THF: 15.0' KB Casing and Tubing Detail \ 1 „L Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” @ 28' 22" Conductor - Surface 28' - Cemented 11 -3/4" Surface 47 #, J -55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29 #, N -80 Surface 81' BTC / 6.184" 26 #, N -80 81' 1,019' BTC / 6.276" ° Chemical 23 #, N -80 1,019' 4,712' BTC / 6.366" L 2310 Injection S" 1800 sx / Cmt to x,275' MOC 26 #, N -80 4,712' 6,541' BTC / 6.276" 11 -3/4" @ 1756' ID z 7" Production 29 #, N -80 6,541' 6,990' BTC / 6.184" 1 3 a 6,990' 6,992' o CBL Top: 2,s50' 29 #, N -80 6,992' 8,411' BTC DV / C 6.184 " 2631' 700 sx / Cmt to x,265' "7" Marker Jt at 10,519.49' (12.63 29 #, P -110 8,411' 10,895' 8RD / 6.184" t 5 ) 5a Tubing _ Proposed 2 -3/8" 1 Production 1 4.6# , L80 1 Surface 1 2631' 1 TC -II -/ 2.055" 1 Rethreaded Tubing = Sterling B -2 Production String Jewelry Detail ' 6 Proposed Sterling B -3 # Depth (RKB) Length ID OD Item ■ r7 6a 1 15.0' .52 2.992" 6.000" Tubing Hanger 3 -1/2" TC -II DV Collar 15.7' 1.24 1.995" 2.375" X -Over 3-1/2" TC -I I Pin x 2 -3/8" TC -I I Pin 6,990' 1514' 2.76 1.995 3.783 2 -3/8" Chemical Injection Sub Assembly — TC-II 7 Thread using 1 /4" SS Tubing (MOC 1) 1.995" 2.675" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV 2 2546' 7.21' 2.910" 4.250" NOTE: Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 28.7' 1.995" 2.375" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice 3 2604' 7.2' 2.910" 4.250" NOTE: Mandrels cut for 2 -3/8" IBT Mod Pups will PPG KW Aqu agel MUD cross these to TC -II Box Up, Pin Down Aquagel CBL Top: 9,210' 2630' 3.07 3.250 5.680 Baker Oil Tool E Latch Assembly (TC -II Box Up) 4 2631 6.1" Packer, Model D (E -Line Set) Baker 2 -3/8" X- Profile Nipple (NOTE: Cut for IBT - 5 2644' 1.01 1.875" MOD x 2 -3/8" IBT P Down (x- over:2 -3/8" IBT - 8 RND Pin DN) 5a 2647' 1.57 WLEG w/ tubing release ( Slickline Shift to drop) 6 +/- 2790' Plug w/35' cement on top Top of Pack . ' • _ 6a +/ -6407' 92.43 1.995" Tubing, 2 -3/8" 4.6# 8 RND EUE 10,531' WLM 10/17/87 _ 8 .7 1.995" Fill Disk Assembly, 8 RND EUE 30.91' 1.995" Tubing, 2 -3/8" 4.6# 8 RND EUE Tag Fill 9 8.06' 1.995" 2 -3/4" Model II -D FH (Acme x 8 RND EUE) 10,572' SLM 2/10/03 11 +/ -6543' .9 1.995" 2 -3/8" WLEG from Auto Release Upper Section 5tir •ti•ti r• •.• ti• " f f ti G 7 7049' BOT Ni Bridge Plug w/ 404' CMT On Top • Yf•f i••r•• • f "r•ti ti f r.r ,.._ 8 10,380' BOT K1 Cement Retainer w/ 548' CM On Top Tight Casing ti5fftif tir:} of ;EH -1 10,684' RKB r•� f•r tir ti Z•�• ti•t lH -2 9 10,476' 4.18' 4.000" ;x.968" Baker SC-1L packer (Set 10/15/87) .ti .ti �,.ti. 1o/oa /s7 {;; • : S ?: ;tif {; ; ti•� H-4 10 10,499' 0.81' 3.000" 5.560" XO Sub 13 tir,: ti:::: }f }H -3 14 � ti• 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3 -1/2" 1ORD 53k shear { 15 12 10,501' 118.14' 2.992" 3.500" Blank Pipe w/ welded centralizers 3-1/2" 1ORD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3 -1/2" 1ORD centralized P$ * 7` ° 14 10,737' 0.53' 2.500" 4.250" 0-Ring Seal Sub 7" @ 10,695' = - 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 1ORD centralized TD = 10,895' PBTD = 10,797' 16 10,748' 1.40' 2.439" 4.250" S -22 Indicating Seal Assembly w/ 2' of seals 17 10,749' ? 3.250" 5.687" Baker Model D Sump packer (Set 10/12/87) Perforation Data ZONE TOP BTM SPF Condition B2 +/ -2707' +/ -2712' 6 Proposed B3 2802' 2810' 12 4 -5/8" Millennium TCP 9 -27 -2010 (Isolated) G 10,552' 10,570' 4 Perf 5/19/02 (1- 11/16 ", 0 deg) (ABANDONED 9 -25 -2010) Directional Data: H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61,'/2" EH, 2/63, 10/87, 3 /95(ABANDONED 9 -25 -2010) max = 2.25° at 7,083' H2 10,669' 10,688' 4,4,12 Perf 6/9/61, IA" EH, 2/1/63, 10 /10 /87(ABANDONED 9 -25 -2010) H3 10,697' 10,701' 4,12 Perf 6/9/61, 1 /2" EH, 10 /10 /87(ABANDONED 9 -25 -2010) H4 10,720' 10,725' 4 _ Perf 6 /8/61,'/2' EH(ABANDON 9 -25 -2010) SRU 23 -33 Proposed Schematic 3- 29- 11.doc Updated by BCA 03 -29 -2011 N • • ' evro • Swanson River Unit SRU 23-33 Well SRU 23 -33 \woo"... W S Last Co m p leted 9/29/2010 /01/2010 RKB: 154' KB / GL: 139' AMSL KB -THF: 15.0' KB Casing and Tubing Detail 1 L Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22 "@28' 22 Conductor - Surface 28' - Cemented 11 -3/4" Surface 47 #, J -55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29 #, N -80 Surface 81' BTC / 6.184" 26 #, N -80 81' 1,019' BTC / 6.276" 2 -3/8" Chemica 23 #, N -80 1,019' 4,712' BTC / 6.366" Injection Sub 1800 sx / Cmt to x,275' L MOC 1 26 #, N -80 4,712' 6,541' BTC / 6.276" ■ 11-3/4" @ 1756' 02 7" Production 29 #, N -80 6,541' 6,990' BTC / 6.184" 1 3 4 6,990' 6,992' DV Collar CBL Top: 2,550' r� -� 2 9 #, N -80 6,992' 8,411' BTC / 6.184" 2631' 700 sx / Cmt to x,265' 29 #, P -110 8,411' 10,895' 8RD / 6.184" s I Tubing *7" Marker Jt at 10,519.49' (12.63') Sterling B -2 2-3/8" 1 Production 1 4.6# , L80 1 Surface 1 2631' 1 TC -II -/ 2.055" 1 Rethreaded Tubing Sterling B -3 Production String Jewelry Detail D ® # Depth (RKB) Length ID OD Item 1 15.0' .52 2.992" 6.000" Tubing Hanger 3 -1/2" TC -II DV Collar 15.7' 1.24 1.995" 2.375" X -Over 3 -1/2" TC -II Pin x 2 -3/8" TC -II Pin 6,990' 1514' 2.76 1.995 3.783 2 -3/8" Chemical Injection Sub Assembly — TC -II . . 7 Thread using /d' SS Tubing (MOC 1) 1.995" 2.675" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV 2 2546' 7.21' 2.910" 4.250" NOTE: Mandrels cut for 2 -3/8" IBT Mod Pups will cross these to TC-Il Box Up, Pin Down 28.7' 1.995" 2.375" Tubing, 2 -3/8" 4.6# TC -II 2 -3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice 3 2604' 7.2' 2.910" 4.250" NOTE: Mandrels cut for 2 -3/8" IBT Mod Pups will 10.2 PPG KW Aquagel MUD cross these to TC -II Box Up, Pin Down CBL Top: 9,210' 2630' 3.07 3.250 5.680 Baker Oil Tool E Latch Assembly (TC -II Box Up) 4 2631 6.1" Packer, Model D (E -Line Set) Baker 2 -3/8" X- Profile Nipple (NOTE: Cut for IBT - 5 2644' 1.01 1.875" MOD x 2 -3/8" IBT P Down (x- over:2 -3/8" IBT - 8 RND Pin DN) 2647' 1.57 WLEG w/ tubing release ( Slickline Shift to drop) 92.43 1.995" Tubing, 2 -3/8" 4.6# 8 RND EUE . 2741' .7 1.995" Fill Disk Assembly, 8 RND EUE op of Pack 30.91' Tubing, 2 -3/8" 4.6# 8 RND EUE ),531' WLM 8 2772' 8.06' 1.995" 2 -3/4" Model II -D FH (Acme x 8 RND EUE) 10/17/87 2782' .9 1.995" 2 -3/8" WLEG from Auto Release Upper Section Tag Fill , 'nil ir 9 10,572' SLM 2110/03 1 1 r.r.r . 1;.., 1 yti r1rtir t•?• C ' 7 7049' BOT Ni Bridge Plug w/ 404' CMT On Top • }•y :AC r 'r•ti S• S•S• • r•r. r•r 8 10,380' BOT K1 Cement Retainer w/ 548' CM On Top ti• : vs - } 1CH Tight Casing •r +• :vs ......-- 1 • �f 9 10,476' 4.18' 4.000" 5.968" Baker SC-1L packer (Set 10/15/87) �• • ti 10,684' RKB • ' r 10/08/87 •rti ti .r ti ,.,. }•} r } } }r H -2 V.. . 10 10,499' 0.81' 3.000" 5.560" X0 Sub .r.r r•r r•r = 13 ' },f ti ••• 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3 -1/2" 1ORD 53k shear 14 • • . 141'. 'el' — H - 15 - 12 10,501' 118.14' 2.992" 3.500" Blank Pipe w/ welded centralizers 3-1/2" 1ORD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3 -1/2" 1ORD centralized 14 10,737' 0.53' 2.500" 4.250" 0-Ring Seal Sub r @ 10,895' A ' ' • - • 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 1ORD centralized TD = 10,895' PBTD = 10,797' 16 10,748' 1.40' 2.439" 4.250" S -22 Indicating Seal Assembly w/ 2' of seals 17 10,749' ? 3.250" 5.687" Baker Model D Sump packer (Set 10/12/87) Perforation Data ZONE TOP BTM SPF Condition B3 2802 2810 12 SPF 4 -5/8" Millennium TCP 9 -27 -2010 G 10,552' 10,570' 4 Perf 5/19/02 (1- 11/16 ", 0 deg) (ABANDONED 9 -25 -2010) H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61, 1 /2" EH, 2/63, 10/87, 3 /95(ABANDONED 9 -25 -2010) Directional Data: H2 10,669' 10,688' 4,4,12 Perf 6/9/61, EH, 2/1/63, 10 /10 /87(ABANDONED 9 -25 -2010) max = 2.25° at 7,083' H3 10,697' 10,701' 4,12 Perf 6/9/61, EH, 10 /10 /87(ABANDONED 9 -25 -2010) H4 10,720' 10,725' 4 Perf 6/8/61, 1 /2" EH(ABANDON 9 -25 -2010) SRU 23 -33 Schematic.doc Updated by JRN 10 -01 -2010 Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 907 263 78 Fax: Fax: 907 263 7828 28 E -mail: fcastro @chevron.com DATE November 3, 2010 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 , WELD ta6��� � iNFERVAL' B SRU 23 -33 PACKER SETTING RECORD 9/27/2010 2630 -2630 X X 019 NOV 1 5 2010 Please acknowledge receipt b signing and returning one copy of this'tra itta[ Qr�FAX �a. °OY7 263 7828. 9 P Y 9 9 9 P _..._ Received By: Date: STATE OF ALASKA ALASKRIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: oil ❑ Gas ❑Q SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: ` 10/2/2010 12. Permit to Drill Number: 161-019 3. Address: PO Box 196247, Anchorage, Alaska, 99519 6. Date Spudded: 5/8/1961 13. API Number: 50-133-10163-00 4a. Location of Well (Governmental Section): Surface: 1660'FSL, 1670'FWL, Sec33, T8N, R9W, S.M. Top of Productive Horizon: 1660'FSL, 1670'FWL, Sec33, T8N, R9W, S.M. Total Depth: 4W 1660'FSL, 1670'FWL, Sec33, T8N, R9W, S.M. 7. Date TD Reached: 6/2/1961 14. Well Name and Number: Swanson Riv Unit (SRU) 23-33 8. KB (ft above MSL): 154' GL Ground (ft MSL): 139' 15. Field/Pool(s): Swanson River Field Swanson River Sterling Gas Pool 9. Plug Back Depth(MD+TVD): 6,568'MD (6,568 -TVD) 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 344082 y- 2462929 Zone- 4 TPI: x- 344082 y- 2462929 Zone- 4 Total Depth: x- 344082 y- 2462929 Zone- 4 10. Total Depth (MD + TVD): 10,895'MD (10,895 -TVD 16. Property Designation: FEDA028399 [Swanson River Unit] 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes 0 No F (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 1 N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A 22.Re-drill/Lateral Top Window MD/TVD: I N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD FT TOP BOTTOM TOP BOTTOM HOLE SIZE AMOUNT CEMENTING RECORD PULLED 22" Surface 28' Surface 28' Cemented to surface 11-3/4" 47# J-55 Surface 1,756' Surface 1,756' 16" 1200 sxs, cement to surface 7" 23/26/29# N-80 / Surface 10,895' Surface 10,895' 9-7/8^ P-110 700sxs @ shoe & 1800sxs thru DV @ 6,990' 24. Open to production or injection? Yes[Z No ❑ If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): 4-5/8" TCP guns, 12spf 30/150deg 2,802'-2,810'MD (2,802'-2,810'TVD) OCT 2 2 WD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-3/8" 2,782' 2,631'MD(2,631'TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9,840' 20bbl (90sxs) 15.6ppg balanced cement plug on retainer 6,576' 15bb1 (67sxs) 15.6ppg balanced cement plug on retainer 27. PRODUCTION TEST Date First Production: 10/2/2010 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 10/10/2010 Hours Tested: 5 Production for Test Period Oil -Bbl: 0 Gas -MCF: 271 Water -Bbl: 0 Choke Size: N/A Gas -Oil Ratio: N/A Flow Tubing Press. 925 psi Casing Press: 740 psi Calculated 24 -Hour Rate —► Oil -Bbl: 10 Gas -MCF: 1300 Water -Bbl: 0 Oil Gravity - API (corr): N/A 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑� If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil gas or water (submit separate sheets with this form, -if needed). Submit detailed descriptions, core chips, photographs and la qw C 25.071. led OCT 2 0 2010 winks UA�t�S ti=NWe�I� a RB©AAS OCT 2 1 �t�it�taQ� Form 10-407 Revised 12/2009 '--�ONTINUED ON REVERSE Submit original only 0 • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Ll Yes � No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Top of Sterling Gas Pool 605' 605' Sterling B-2 Sand Top 2,700' 2,700' Sterling B-2 Sand Bottom 2,790' 2,790' Sterling B-3 Sand Top 2,800' 2,800' Sterling B-3 Sand Bottom 2,910' 2,910' Bottom of Sterling Gas Pool 3,315' 3,315' Formation at total depth: 31. List of Attachments: Current Well Schematic, Daily Operations Summary 32. 1 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: 10/18/2010 V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 12/2009 Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 23-33 SWANSON RIV UNIT 23-33 FEDA028399 5013310163 QA5335 154.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion - Reconfigure Major Rig 9/13/2010 Work Over (MRWO) Primary Wellbore AffectedUWI Wellbore Well Permit Number SRU 23-33 501331016300 1610190 t 9/17/2010 00:00 - 9/1811010 00:00MIL Operations Summary Prepare location fo well operations - LD containment areas - Move in tanks and non -rig equipment. 911812010,00:00 - W0464.6 .6 00:00 - Operations Summary M1 RU pumping equipment - Lubricate and bleed to 7" x tubing annulus w/ lease water. Circulate well down tubing and up annulus w/ lease water. 9/191201000:00-91201201000 .., ` Operations Summary RU Wireline, Test wireline valves, pump -in sub 250 PSI Low/ 2500 PSI High, OK - RIH w/ 1-3/4" swedge and tag fill @ 10575 RKB, POH - RIH w/ 2.74" Gauge ring, sit down weight at 9925', work down to 9992' RKB, POH using jars to 9952'RKB, cont POH w/out jars to surface - RU E -line, PU 1-7/16 x 12' tubing punch, RIH to depth 10,505'- 10,517' RKB, All shots fired, RD E -line. 24 hour notice to AOGCC & BLM of upcoming BOP test - Winessed test waived by AOGCC Mr. Bob Noble - 9/19/2010 13:48 Hours 9 01000:00" . Operations Summary MI RU Key Rig #3. Pressure test HP fluid lines to 5000 PSI - Circulate well with lease water, SD Pumps, monitor well - Well Static - Install back pressure valve, ND Tree, NU BOP and associated equipment. 44W*00 r. Operations Summary Function test BOP, verify operations from all stations - MU Test joint, test BOP 250 PSI Low/ 3000 PSI high. RU, pull hanger set slip on landing joint. MIRU E -line, PU 2-7/8" jet cutter, RIH to 10, 002' RKB, unable to pass, locate coupling, place shot at 9990' RKB, Good cut, POH E -line - POH 3-1/2" tubing. 9/22/2010 00:00 - 91231906 00:00 Operations Summary Contiue to POH 3-1/2" tubing, recovered 315 jnts, 13.5' cut joint. RIH w/ fishing assembly to recover tubing and seal assembly in packer. 9/23/2010. :00 - 91241 r 00.00 Operations Summary Continue to RIH w/ workstring to recover fish - Set down on top of tubing stub (top of fish), pull fish free, POOH, recovered all 3-1/2" tubing, jewelry and seal assembly down to 10,476' (Original RKB). RIH w/ 7" casing scraper assembly. Operations Summary Continue to RH w/ scraper assembly to 10,476' (Original RKB). tagging top of packer. Establish circulation and pump 20 BBL Hi-visc sweep. Displaced with 8.4 PPG lease water, RD circulating equipment, PU 7" cement retainer, RIH 1:110,380' RKB and set on workstring. RU cementing equipment, establish circulation, sting into retainer, pressure annulus to 1500 psi, holding, could not establish injection rate into formation at 4000 psi. Pull out of retainer and prepare to set balanced plug on top of retainer. 91192010+`9128/2010 00:00 .`ar„ Operations Summary Pump 10 BBIs Chem wash, followed w/ 20 bbls 15.6 PPG Easyblock cement (90 sacks) holding 800 PSI back pressure on choke, displace with 84 barrels lease water. POH to 9,832'RKB, reverse out, recovered 1/4 barrel cement - Estimate TOC plug at 9,840' RKB. RIH to TOC and displace well to 10.8 PPG KW mud, POH with workstring. PU 7" BP, RIH on workstring, set at 7,049' RKB, set 30K on BP, release from BP, PU 2' above BP, establish circulation, pump 10 bbls 13.2 PPG mudpush, 15 barrels 15.6 PPG Easyblock cement at 3 BPM holding 500 PSI on choke, followed w/ 3.5 bbls 13.2 PPG mudpush. Displaced cement w/ 53 barrels 13.8 PPG mud. PU reverse circulate, no cement in returns, POH with workstring. 9128/2010'00:00=n91 % 0 x{ ,r Operations Summary PU cleanout assembly, RIH and tag TOC @ 6,576' RKB with 2000 lbs down. Pick up 34' off tag, RU circulating lines - Circulate annular volume at 4 BPM - MU swivel, establish circulation, wash at 2.5 BPM 550 PSI, from 6568' to TOC at 6,576'RKB, tag with 5K Lbs. Performed AOGCC witnessed MIT test of 7" casing at 1,690 PSI hold for 30 minutes, pressure bled 50 PSI in 15 minutes, bled 20 PSI next 15 minutes, held for additional 15 minutes to monitor pressure, stabilized at 1,620 PSI, holding. Displaced well to lease water and pump 74 bbls clean up pill train/flush at 2.5 BPM. 00.9128/2010 00.00:'*} Operations Summary Displace lease water from well with 238 bls 6% KCL. Pressure test 7" casing to 2,500 PSI, no bleed off. Begin RIH with 4-5/8" Perforating Guns, x -profile and packer w/ seal bore extension on E -Line. 9/28/2010 00:00 - 9/29/2010 00;00 xv "' Operations Summary Continue to RIH with E -line set packer w/ 8' guns. tie in with gamma ray and set shots at 2,802' to 2,810' RKB WLM, packer set at 2,631'RKB WLM. RIH w/ 2-3/8" tubing w/ seal assembly, Gas lift valves, & injection mandrel and land hanger with .8' of seal assembly above guide at 2,636' RKB. Pressure test to 500 PSI to verify good seal, OK. ND BOP and NU tree. I' Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 23-33 SWANSON RIV UNIT 23-33 FEDA028399 5013310163 QA5335 154.00 -77777777 MY 0 =*M2010 00:00 Operations Summary Pad closeout. Production equipment hookup. fi0 00:00 -10/11201q 00:00 Operations Summary Pad closeout. Production equipment hookup. .,, , i :00 -10/2/2010 00:00 Operations Summary Pad closeout. Production equipment hookup. 0110,90:00 -10/3/2010`00.00 � s= Operations Summary RU and drop bar, TCP perforated w/ 4-5/8" 12spf Millennium guns from 2,802'-2,810'RKB WLM. Turned well over to production. 22" @ 28' RKB: 154' KB / GL: 139' AMSL KB -THF: 15.0' KB 11 1 FT 2-318" Chemic Injection Sub MCc1 11-3/4" @ 1756' 2 3 4 CBL Top: 2,550' 2631' 5 Sterling B-2 Sterling 8-3 � $7 6 DVCollar 6, 990' 7 10.2 PPG KW Aquagel MUD CBL Top: 9,210' op of Pack ],531' WLM 8 10/17/87 Tag Fill 9 10,572' SLIM 2/10103 11 Tight Casing 10,684' RKB 1 10/08/87 13 14 15 7"@10,895' U'. - JA TD =10,895' PBTD = 10,797' Directional Data: max = 2.25° at 7,083' SRU 23-33 Wellbore Schematic Swanson River Unit Well SRU 23-33 Last Completed 9/29/2010 Updated 10/01/2010 Casing and Tubing Detail # Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" Conductor 6.000" Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 11756' 8RD / 11.000" 1200 sx / Cmt to Surface 7" 2-3/8" Chemical Injection Sub Assembly — TC -II Thread using /4 SS Tubing MOC 1) 29#, N-80 Surface 1 81' BTC / 6.184" 1800 sx / Cmt to x,275' 26#, N-80 81' 1,019' BTC / 6.276" 23#, N-80 1,019' 4,712' BTC / 6.366" 26#, N-80 4,712' 6,541' BTC / 6.276" Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6,990' 6,992' DV Collar 29#, N-80 6,992' 8,411' BTC / 6.184" 700 sx / Cmt to x,265' 29#, P-110 8,411' 10,895' 8RD / 6.184" Tubing 28.7' 1.995" 2.375" Tubing, 2-3/8" 4.6# TC -II '7" Marker Jt at 10, 519.49'(12.63) 2-3/8" 1 Production 4.6#, L80 Surface 2631' TC -114 2.055" 1 Rethreaded Tubing Production String Je elry Detail # Depth (RKBL Length ID OD Item 1 15.0' .52 2.992" 6.000" Tubin Hanger 3-1/2" TC -II 10,570' 15.7' 1.24 1.995" 2.375" X -Over 3-1/2" TC -II Pin x 2-3/8" TC -II Pin 4,4,12,2 1514' 2.76 1.995 3.783 2-3/8" Chemical Injection Sub Assembly — TC -II Thread using /4 SS Tubing MOC 1) Pelf 6/9/61,'/2' EH, 2/1/63, 10/10/87 ABANDONED 9-25-2010 H3 10,697' 1.995" 2.675" Tubing, 2-3/8" 4.6# TC -ll 2 2546' 7.21' 2.910" 4.250" 2-3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV NOTE: Mandrels cut for 2-3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 28.7' 1.995" 2.375" Tubing, 2-3/8" 4.6# TC -II 3 2604' 7.2' 2.910" 4.250" 2-3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice NOTE: Mandrels cut for 2-3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down 2630' 3.07 1 3.250 5.680 Baker Oil Tool E Latch Assembly (TC -II Box U 4 2631 6.1" Packer, Model D(E-Line Set) 5 2644' 1.01 1.875" Baker 2-3/8" X -Profile Nipple (NOTE: Cut for IBT- MOD x 2-3/8" IBT P Down (x-over:2-3/8" IBT - 8 RND Pin DN 2647' 1.57 WLEG w/ tubing release ( Slickline Shift to drop) 92.43 1.995" Tubing, 2-3/8" 4.6# 8 RND EUE 2741' .7 1 1.995" Fill Disk Assembly, 8 RND EUE 2772' 8.06' 1.995" 2-3/4" Model II -D FH (Acme x 8 RND EUE 2782' .9 1.995" 2-3/8" WLEG from Auto Release Upper Section 7 7049' BOT N1 Bridge Plug w/ 404' CMT On To 8 10,380' BOT K1 Cement Retainer w/ 548' CM On To 9 10,476' 4.18' 4.000" 5.968" Baker SC -1 L packer Set 10/15/87 10 10,499' 0.81' 1 3.000" 5.560" XO Sub 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3-1/2" 10RD 53k shear 12 10,501' 118.14' 2.992" 3.500" Blank Pipe w/ welded centralizers 3-1/2" 1 ORD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 10RD centralized 14 10,737' 0.53' 2.500" 4.250" O -Ring Seal Sub 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 10RD centralized 16 10,748' 1.40' 2.439" 4.250" S-22 Indicating Seal Assembly w/ 2' of seals 17 10,749' ? 3.250" 1 5.687" Baker Model D Sump packer Set 10/12/87 Perforation Data ZONE TOP BTM SPF Condition B3 2,802' 2,810' 12 SPF 4-5/8" Millennium TCP 9-27-2010 G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de ABANDONED 9-25-2010 H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61,'/2" EH, 2/63, 10/87, 3/95 ABANDONED 9-25-2010 H2 10,669' 10,688' 4,4,12 Pelf 6/9/61,'/2' EH, 2/1/63, 10/10/87 ABANDONED 9-25-2010 H3 10,697' 10,701' 4,12 Perf 6/9/61,'/2' EH, 10/1 0/87ABANDONED 9-25-2010 H4 10,720' 10,725' 4 Perf 6/8/61, 1/2" EH ABANDON 9-25-2010 SRU 23-33 Completion 9-29-2010 docx Updated by JRN 10-01-2010 Page 1 of 2 Aubert, Winton G (DOA) From: Aubert, Winton G (DOA) Sent: Monday, September 20, 201011:11 AM j . 0 ( l To: 'Newell, Jack R [Swift]' 1 Subject: RE: Chevron: SRU 23-33, Sundry 310-258: Operation Change Request Mr. Newell, AOGCC hereby approves proposed changes to Sundry No. 310-258 (well SRU 23-33, PTD 161-019), as described below. All previous sundry approval stipulations apply. Winton Aubert AOGCC 793-1231 From: Newell, Jack R [Swift] [mailto:]Newell@chevron.com] Sent: Monday, September 20, 201010:42 AM To: Aubert, Winton G (DOA) Subject: RE: Chevron: SRU 23-33, Sundry 310-258: Operation Change Request Mr. Winton Aubert, Please find the proposed schematic attached. Jack R. Newell • Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel (907) 263-7832 Fax (866) 401 0624 Mobile {907} 529-5450 From: Aubert, Winton G (DOA) [mailto:winton.aubert@alaska.gov] Sent: Monday, September 20, 201010:34 AM To: Newell, Jack R [Swift] Subject: RE: Chevron: SRU 23-33, Sundry 310-258: Operation Change Request Mr. Newell, Your proposed change to Sundry No. 310-258 is not yet approved. Please submit an updated proposed well schematic. Thank you, Winton Aubert AOGCC 793-1231 From: Newell, Jack R [Swift] [mailto:]Newell@chevron.com] Sent: Monday, September 20, 2010 9:47 AM 9/20/2010 0 • Page 2 of 2 To: Aubert, Winton G (DOA) Cc: PORHOLA, STAN T; Kanyer, Christopher V Subject: Chevron: SRU 23-33, Sundry 310-258: Operation Change Request Please accept these proposed changes to Chevron well Swanson River Unit PTD: 161-019, Sundry Number 310- 258. HISTORY for proposed change: During pre -well work before the rig arrived on location the well had an injectivity test performed on the productive interval to be cemented. At that time the well showed communication between the annulus and the tubing string that was being pumped through. We suspect that the tubing may be not in full structural condition. Rigged up Slickline and was able to RIH w/ 1.75" gauge ring and tagged at 10,575' RKB:MD. There were no indications of problems to this depth. This depth correlates to the earlier cleanout depth done this summer under Sundry 310-173. WE were only able to get a 2.74' gauge ring to a depth of 9925' with struggling attempts and jarring to pull back out at from 9992' RKB. WE propose to; 1: Cut 3-1/2" tubing at 9925' with 2.70" Jet Cutter. 2. Attempt one time to fish out remaining 3-1/2" tubing and seal assembly to provided an effective depth in the 7" casing to 10476' MD, and set the cement retainer at the Sundry 310-258 approved depth of 10,375' MD. If unable to recover below 10,375' MD we will: A) Set 7" cement retainer at 9910' RKB. B) RU and pump a total of 36 Bbls Cement (Additional volume of 16 Bbls) to isolate productive interval. NOTE: This additional volume is to do a 465' measured length casing fill from previous retainer depth of 10,375' RKB. C) Continue with Sundry 310-258 approved operations. REQUEST: We ask for approval of the proposed retainer depth to 9925' RKB and with the noted increase (16 Bbl's) in cement volume. We are expecting to be setting the cement reatiner Wednesday, September 22, 2010. Jack R Newell e • jnewell@Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel 1907 263-7832 Fax 1 866 4010624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible far delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message atter notifying me immediately by replying to the message or contacting me at (907) 263-7832. 9/20/2010 RKB: 154' KB I GL: 139' AMSL KB -THF: 15.0' KB 22' @ 28- 11-314" @ 1756' CBL Top: 2,550' DVCol lar 6.990 CBL Top: 9,210' Top of Pack 10,531' WLM 10117187 Tag Fill 10,572' SLM 2110103 Tight Casing 10,684' RKB 10108187 Chemic. on Sub 1 Sterling B-2 Sterling B-3 7" @ 10,895' 4M.M TD =10,895' PBTD = 10,797' Directional Data: max = 2.25° at 7,083' 11 SRU 23-33 Proposed Wellbore Schematic Inson River Unit I SRU 23-33 Completed 10/19/87 Casing and Tubing Detail # Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" Conductor 6.000' Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 3.783 2-3/8" Chemical Injection Sub Assembly — TC -11 Thread using ''/d' SS Tubing MOC 1 29#, N-80 Surface 81' BTC / 6.184" 2.675' Tubin , 2-3/8" 4.6# TC -II 2 26#, N-80 81' 1,019' BTC / 6.276" 2-3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV NOTE: Mandrels cut for 2-3/8" IBT Mod Pups will cross these to TC -11 Box Up, Pin Down 10,720' 1 10,725' 23#, N-80 1,019' 4,712' BTC / 6.366" 1800 sx / Cmt to x,275' ±2610 26#, N-80 4,712' 6,541' BTC / 6.276" ±2624 7" Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6.1xx" Packer, Model D (E -Line Set) 6,990' 6,992' DV Collar 1.875" 700 sx / Cmt to x,265' 29#, N-80 6,992' 8,411' BTC / 6.184" ±2670' 29#, P-110 8,411' 10,895' 8RD / 6.184" Tubing ±106' 1 1.995" Tubing, 2-3/8" 4.6# 8 RND EUE '7"Marker Jt at 10,519.49'(12.63) 2-3/8" Production 4.6# , x80 Surface ±2675' TC -II-/ 2.055" Rethreaded Tubing Production String Je elry Detail # Depth (RKqL Length ID OD Item 1 15.0' .7 2.992" 6.000' Tubing Hanger 3-1/2" TC -II ±2805 15.7' 1 1.995' 2.375" X -Over 3-1/2" TC -II Pin x 2-3/8" TC -II Pin 4 ±1550' H1 1.995 3.783 2-3/8" Chemical Injection Sub Assembly — TC -11 Thread using ''/d' SS Tubing MOC 1 Perf6/9/61,'/z" EH, 2/63,10/87, 3/95(ABANDON 8-2010 H2 ±2564 1.995" 2.675' Tubin , 2-3/8" 4.6# TC -II 2 ±2580 1 10,701' 4,12 4.250" 2-3/8" GL Mandrel, SFO -1 BK -2 Latch w/ DV NOTE: Mandrels cut for 2-3/8" IBT Mod Pups will cross these to TC -11 Box Up, Pin Down 10,720' 1 10,725' ±30' 1.995" 2.375" Tubing, 2-3/8" 4.6# TC -II ±2610 4.250" 2-3/8" GL Mandrel, SFO -1 BK -2 Latch w/ Orifice NOTE: Mandrels cut for 2-3/8" IBT Mod Pups will cross these to TC -II Box Up, Pin Down ±2624 Baker Oil Tool E Latch Assembly (TC -11 Box Up) 4 ±2625 6.1xx" Packer, Model D (E -Line Set) ±2630 1.875" Baker 2-3/8" X -Profile Nipple (NOTE: Cut for IBT- MOD x 2-3/8" IBT P Down (x-over.2-3/8" IBT - 8 RND Pin DN ±2670' ±2' WLEG w/ tubing release Slickline Shift to drop) ±106' 1 1.995" Tubing, 2-3/8" 4.6# 8 RND EUE 2776'M+2' 1.992" Fill Disk Assembly, 8 RND EUE ±2779'2.125" 2-3/8" Auto release with WLEG 8 ND EUE ±2781'NFO 2-3/4" Model II -D FH (Acme x 8 RND EUE) ±2783 NFO Safet Spacer Based on Stack RU±2800'NFO HES TCP Packa e before release 6 - (70 TCP FISH 7 ±7050 BOT K1 Bridge Plug w/ 400' T On To 8 9910' 4.18' 4.000" 5.968" BOT K1 Cement Retainer w/ 100' CM On To 9 10,476' 4.18' 4.000" 5.968" /87) Baker SC -11- packer (Set 1011'S/87) 10 10,499' 0.81' 3.000" 5.560" XO Sub 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3 1/2" 1ORD 53k shear 12 10,501' 118.14' 2.992" 1 3.500" Blank Pipe w/ welded centralizers 3-1/2" 1 ORD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 1ORD centralized 14 10,737' 0.53' 2.500" 4.250" O-Rinq Seal Sub 15 10,738' 10.12 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 1ORD centralized 16 10,748' 1.40' 2.439" 4.250" S-22 Indicating Seal Assembly w/ 2' of seals 17 10,749' ? 3.250' 5.687" Baker Model D Sump packer Sct 10/12/87 Perforation Data ZONE TOP BTM SPF Condition B2 ±2705 ±2710 6 SPF 1-11/16" EL Run Perforating Gun To be perforated at a later date B3 ±2800 ±2805 12 SPF 4-5/8" TCP 8-2010 G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de ABANDON 8-2010 H1 10,630' 10,657' 4,4,12,2 Perf6/9/61,'/z" EH, 2/63,10/87, 3/95(ABANDON 8-2010 H2 10,669' 10,688' 4,4,12 Perf6/9/61, %" EH, 2/1/63, 10/10/87 ABANDON 8-2010 H3 10,697' 1 10,701' 4,12 Perf6/9/61,%" EH, 10/10/87(ABANDON 8-2010) H4 10,720' 1 10,725' 4 Perf6/8/61,'/�" EH(ABANDON 8-2010 SRU 23-33 Proposed Well Schematic 09-20-2010 docx Updated by JRN 09-20-2010 • • ~~p~[~ 0~ p~p~~{p /,E,.Poa~..~e....,~ Timothy C. Brandenburg Drilling Manager Union Oil Company of California n ~ _ T, fir, P.O. Box 196247 " . ~ ~ ~:~ .. - ~ ~ ~~ Anchorage, AK 99519 ~ ~ I' Re: Swanson River Field, Hemlock Oil 8s G-Zone Pool, SRU 23-33 Sundry Number: 310-258 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. 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 ~Sday of August, 2010. Encl. ~~ ~'f~ ~~ • ~~~ -.l'~ •'li ~4~ ~~~ ~ ~ ~u~ ~ ~ zo~~ ~1z~lz~to ~`' STATE OF ALASKA ~/ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ~ ~ ~~ ~ ~0t+1~SSion APPLICATION FOR SUNDRY APPROVALS ~~~,~~,~~ 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^Q Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^~ Pertorate ^ Pull Tubing ^~ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Recomplete as gas well ^~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^~ Exploratory ^ 161-019 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10163-00, 7. If pertorating, 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 ^~ Swanson Riv Unit (SRU) 23-33 9. Property Designation (Lease Number): 10. Field/Pool(s): , FEDA028399![Swanson River Unit] Swanson River Field /Hemlock Oil & G-zone 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): 10,89 10,895 10,797 / 10,797 N/A 10,572' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surtace 1,756' 11-3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,522'-10,570', 10,630'- 10,522'-10,570', 10,630'- 10,657', 10,669'-10,688', ' ' ' 10,657', 10,669'-10,688', ' ' ' ~ 3-1/2 9.2# N-80 Surtace-1,040' ' ' 10,697 -10,701 , 10,720 - 10,697 -10,701 , 10,720 - 9.3# J-55 1,040 -10,479 10,725' 10,725' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SC-1 L & Baker Model D Sump Packers / N/A 10,476' 8 10,749' / N/A 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ~- Service ^ 14. Estimated Date for 9/8/2010 15. Well Status after proposed work: r Commencing Operations: ~~ Oil ^ Gas ^~ - WDSPL ^ Plugged ^ 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 Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~~ ~ Phone 276-7600 Date 8/18/2010 COMMISSION USE ONLY ~JO ~ ~$ Z , Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: T'~ 5 t ~j ~ P t {'D 3 0 0 0 ~ ta. P+ar s it awl ~`n Z o /`~d4C. ZS . t l L (i) ~ e~,~, ~'e v rt.a-t't L~ w~tti,'E' ~/J ~w~ ~~~ we ~,~. ~' s ~p~~red. 1 Subsequent Form Required: ~ m •- c f O "l APPROVED BY ~~ ~ ~~ ~ Approved by: ~,~~~~ COMMISSIONER THE COMMISSION Date: , 'F`NBDMS AUG ~ 6 2~~ Form 10-403 Revised 12/2009 ~ ~ ~ ~{ q ~ Submit in Duplicate Chevron • OBJECTIVE: • Abandon open oil sands & recomplete as gas well. ~ PROCEDURE SUMMARY: 1 MIRU Key Energy Rig #3. 2 Kill w/ 8.5ppg lease water 3 NU BOP, test same to 250psi low/3,OOOpsi high. ~ 4 RU Eline 5 Cut 3-1/2" tubing at (+/-) 10,475'. 6 RD Eline. 7 Pull and LD 3-1/2" completion. • Swanson River Unit Well #SRU 23-33 8/18/10 8 Set EZSVB retainer at (+/-) 10,375' on DP nd tag with 10K. ~ 9 Establish injection, ~'x, and pump (+/-) 16 I (+/-) 15.6ppg cement to abandon open oil zones, PU out of ,~- retainer ,Lay (+/-),4bb1 cement on top retainer. Contingency (If unable to injec-t-cement below retainer): Lay (+/-) bbl (+/-) 15.6ppg cement on top of retainer. ~ 10 Circulate in 10.8 PPG KW mud. 11 PU 7" BP and set at (+/-) 7,010' Qn DP and tag with 10K. ~ 12 Mix and pump (+/-) 400' - (+/-~5 ~ I balanced (+/-) 15.6ppg cement plug on top of BP across DV collar. 13 RIH TCP perforating guns, 2-3/8" x-profile, 7" x 2-3/8" packer assembly, gas lift valves, set packer on E-line at (+/-) 2,625'. RIH with 2-3/8" tubing and stab into packer. 14 TCP perforate (+/-) 2,705' - (+/-) 2,710' and (+/-) 2,800' - (+/-) 2,805'. ~ 15 RD. Release Key Energy Rig #3. 16 Return well to production operations. Current BHP: 2,675 psi @ 10,550' TVD Max Downhole Pressure: 2,675 psi @ 10,550' TVD (Based on fluid level at 6,595' and a 7.8 ppg fluid gradient) MASP: 1620 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) ~ 39i s Z~o~i - ~(iosso- ~s~s~)C,oS~~~7.~~ - ~~~t~5~is~~ ~ ~{~I SRU 23-33 REVISED BY: CVK 8-18-10 uCVrv~ - - Swanson River Unit SRU 23-33 Well SRU 23-33 '`'" Last Completed 10/19/87 _ Actual Wellbore Schematic Updated 7/2/10 RKQ 156' KB / GL 139 /Y1119 IB-THF:15.0 F03 2z' @zs 11.3~~' @1755 CBLTgx 2,55U D'V Cdlar 5,99Q c~r~: s,z1a Top of Pack 18531' WLM 10M7B7 Tag FII 1g57z' 12F03 6/27/10 Ti~tt Coming lgssa' RtB 10/08187 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Conductor - Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29#, N-80 Surface 81' BTC / 6.184" 26#, N-80 81' 1,019' BTC / 6.276" 23#, N-80 1,019' 4,712' BTC / 6.366" / C 275' 1800 t t " 26#, N-80 4,712' 6,541' BTC / 6.276" m o x, sx 7 Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6,990' 6,992' DV Collar 29#, N-80 6,992' 8,411' BTC / 6.184" 700 / C t t 265' 29#, P-110 8,411' 10,895' 8RD / 6.184" sx m o x, Tubing '7" Marker Jt at 1q 519.49' (12.63 3-1/2" Production 9.2#, N-80 Surface 1040' IBT / 2.992" 3-1/2" Production 9.3#, J-55 1040' 10,479' 8RD-Mod / 2.992" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 15.0' 8.38' 2.992" 6.000" Tubin Han er w/ u , 3-1 /2" lift threads? 2 4,703' 14.95' ? ? Flo etrol-Johnson 3x1 GLM 3 7,205' 14.85' ? ? Flo etrol-Johnson 3x1 GLM 4 8,996' 14.77' ? ? Flo etrol-Johnson 3x1 GLM 5 10,401' 9.20' ? ? Otis LBX 3-1/2"x1-1/2" GLM 6 10,442' 1.31' 2.750" 4.500" X Ni le Min ID = 2.750" 7 10,475' 0.87' 3.000" 4.500" S-22 Locator Seal Assembl w/ 15.76' of seals 8 10,476' 4.18' 4.000" 5.968" Baker SC-1 L acker Set 10/15/87 9 10,480' 5.74' 4.770" 5.500" 80-40 Perforated Extension 10 10,499' 0.81' 3.000" 5.560" XO Sub 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safet Joint, 3-1/2" 10RD 53k shear 12 10,501' 118.14' 2.992" 3.500" Blank Pi a w/ welded centralizers 3-1/2" 10RD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3-1 /2" 10RD centralized 14 10,737' 0.53' 2.500" 4.250" O-Rin Seal Sub 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1 /2" 10RD centralized 16 10,748' 1.40' 2.439" 4.250" S-22 Indicatin Seal Assembl w/ 2' of seals 17 10,749' ? 3.250" 5.687" Baker Model D Sum acker Set 10/12/87 Perforation Data ZONE TOP BTM SPF Condition G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61,'/2' EH, 2/1/63, 10/10/87, 3/20/95 H2 10,669' 10,688' 4,4,12 Perf 6/9/61,'/2' EH, 2/1/63, 10/10/87 H3 10,697' 10,701' 4,12 Perf 6/9/61,'/2' EH, 10/10/87 H4 10,720' 10,725' 4 Perf6/8/61,'/2" EH r'@1gs96 ~"~4~`~`~'"'~{~ Directional Data: TD=10,896' PB7D=18797' max hole angle = 2.25° at 7,083' MD SRU 23-33 Actual Well Schematic 7-2-10 doc Updated by CVK 7-2-10 zr' @ zs' 11.314" @ 175s' CBL Top: 2,550' DV Collar 6,990' CBL Top: Top of Pack 10,531' WLM 10117187 Tag Fill 10,572' SLM 2110103 Tight Casing 1o,saa' wc6 laosls7 Sl~- 96 Perforation Data ZONE TOP BTM SPF Condition 62 12705 12710 15 SPF Pro osed 4-5/8" TCP 63 ±2800 ±2805 15 SPF Pro osed 4-5/8" TCP G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de ABANDON 9-2010 H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61,'/z" EH, 2/63, 10/87, 3/95 ABANDON 9-2010 H2 10,669' 10,688' 4,4,12 Perf 6/9/61, '/2' EH, 2/1/63, 10/10/87 ABANDON 9-2010 H3 10,697' 10,701' 4,12 Perf 6/9/61,'/2' EH, 10/10/87 ABANDON 9-2010 H4 10,720' 10,725' 4 Perf6/8/61,'/x" EH ABANDON 9-2010 7" ~ 10,895' ~.. .: ~'~ `+~"~ TD =10,895' PBTD =10,797' Directional Data: max hole angle = 2.25° at 7,083' MD SRU 23-33 Proposed Well Schematic 08-18-10.docx Updated by STP 08-18-10 Sterling B•3 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Conductor - Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29#, N-80 Surface 81' BTC / 6.184" 26#, N-80 81' 1,019' BTC / 6.276" 23#, N-80 1,019' 4,712' BTC / 6.366" 1800 / C t t 275' " 26#, N-80 4,712' 6,541' BTC / 6.276" m o x, sx 7 Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6,990' 6,992' DV Collar 29#, N-80 6,992' 8,411' BTC / 6.184" 700 / Cmt to x 265' 29#, P-110 8,411' 10,895' 8RD / 6.184" sx , Tubing '7" Marker Jt at 10, 519.49' (12.63 2-3/8" Production 4.6# , L-80 Surface ±2670' IBT SCC C I OD = 2.700" Production Strin J ewel Detail # De th RKB) Len th ID OD Item 1 15.0' 0.7 2.992" 6.000" Tubin Han er 3-1 /2" BTC 2 15.7' 1.0 1.995" 2.375" X-Over 3-1/2" BTC x 2-3/8" IBT 3 12110 t6' 1.995" 3.875" GL Mandrel 4 12610 t6' 1.995" 3.875" GL Mandrel 5 12624 t6' 1.990" 3.250" Seal Assembl w/ 4' Seals 6 12625 t6' 3.250" 5.875" Packer, Model D w/ 5' Bore E-Line Set 7 12630 t1' 1.875" 2.375" X-Profile Ni le 8 12670' t1' 1.995" 2.375" WLEG w/Auto release 9 ±6475' 1135' - - TCP Guns Dro ed 10 ±7010 t4' - 5.968" EZDrill Brid a Plu w/ 400' CMT On To 11 10,375' ±4' - 5.968" EZSBV Cement Retainer w/ 100' CM On To 12 10,476' 4.13' 4.000" 5.968" Baker SC-1 L acker Set 10/15/87 13 10,499' 0.81' 3.OC0" 5.560" XO Sub 14 10,500' 1.01' 3.00" 5.160" Gravel Pack Safety Joint, 3-1/2" 10RD 53k shear 15 10,501' 118.14' 2.99?" 3.500" Blank Pi a w/ welded centralizers 3-1/2" 10RD 16 10,619' 118.13' 2.992" 4.000" Johnson Screens. 0.20" 3-1/2" 10RD centralized 17 10,737 0.53' 2.500" 4.250" O-Rin Seal Sub 18 10,738' 10.12' 2.992" 4.000" Johnson Screens, L) 20" 3-1 /2" 10f2D centralized 19 10,748' 1.40' 2.439" 4.250" S-22 Indicatin Seal Assembl w/ 2' of seals 20 10,749' ? 3.250" 5.687" Baker Model D Sum acker Set 10/12/87 ,/ ,,n;: 11 f^.ti -~ ; 12 I owl 7!0 KB-THF: 15.0' KB Chevron • • Summary of Key Energy Rig #3 Specifics SRU 23-33 Workover The SRU 23-33 workover is to abandon the existing oil completion, isolate the 7" casing below the DV collar, perforate new shallow gas zones w/ TCP guns hung from a new 2-3/8" completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration 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 260,000 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" Hydril /. Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Eight 15 gallon accumulator bottles. 200 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 (SRU 23-33) rev0.doc 8/18/10 Chevron ~ . Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. 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 (SRU 23-33) rev0.doc 8/18/10 Chevron ~ BOPE Diagram SRU 23-33 Workover 8/18/2010 Annular preventer, 7 1/16 5M Flans 3.08' haffer Chasovoy 7 1/16 5 ~ 0 94~ stdd X 7 115M stdd Pipe Ram 9.00 1.04' Chevron ~ Swanso~River 2010 Choke Manifold 07/01/2010 Blooey Line To Gas Buster 0 ~ Unibolt Connection 0 • 0 ~. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Perform CT cleanout Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permjt to Drill Number: Name: Development Q Exploratory^ 161-019 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-133-10163-00` 7. Property.~esignation (Lease Number): 8. Well Name and Number:` FEDA028399 [Swanson River Unit] Swanson Riv Unit (SRU) 23-33 9. Field/Pool(s): ,~ Swanson River Field /Hemlock Oil & G-zone Pool 10. Present Well Condition Summary: Total Depth measured 10,895 feet Plugs (measured) N/A feet true vertical 10,895 feet Junk (measured) 10,572 (fill) feet Effective Depth measured 10,797 feet Packer (measured) 10,476 & 10,749 feet true vertical 10,797 feet (true vertical) .10,476 & 10,749 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,756' 11-3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Perforation depth: Measured depth: 10,522'-10,570', 10,630'-10,657', 10,669'-10,688', 10,697'-10,701', 10,720'-10,725' True Vertical depth: 10,522'-10,570', 10,630'-10,657', 10,669'-10,688', 10,697'-10,701', 10,720'-10,725' Surface-1,040' Surface-1,040' Tubing (size, grade, measured and true vertical depth): 3-1/2" 9.2# N-80 / 9:9#J-55" 1,040'-10,479' 1,040'-10,479' Baker SC-1 L & Baker 10,476'MD/11/D & Packers and SSSV (type, measured and true vertical depth): Model D Sump Packers 10,749'MD/TVD N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~~,, ~ U ~ ~{ ~ 2 O Treatment descriptions including volumes used and final pressure: ,~~BSka ~ ~ ~~ G~~ ~~I11gS10(1 N/A 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 300 psi 0 psi Subsequent to operation: 0 0 0 260 psi 260 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Service ^ Daily Report of Well Operations X 15. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-173 Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 7/26/10 Form 10-404 Revised 7/2009 Submit Original Only • • Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 23-33 SWANSON RIV UNIT 23-33 FEDA028399 5013310163 QA5335 154.00 Jobs - - - - -- -- -- - - - -- Primary Job Type Job Category Objective Actual Start Date Actual End Date Clean-Out Well Services 6/23/2010 Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 23-33 501331016300 1610190 --.- -a~ -l) rations ------ - - .8123/2010 00:00 - 6124/2010 00:00 - - ----- Operations Summary Site visit to location. 6/24/2010 00:00 - 6/25!2010 00:00 _ - Operations Summary Mobe CT and pumping equipment. 6/25!201 q 00:00 - 612612 010 00:00 _ _ __ ' Operations Summary - RU slickline, pressure test lubricator to 250psi low/2500psi high. Tag fill at 10,462' RKB SLM w/ 1.7" GR. RD slickline. Contacted AOGCC of upcoming CT BOP test. Test witness waived by AOGCC Jim Regg. ___ - ---- 6/26/2010 00:00 - 6(27!2010 00:00 _ _____ _ _ Operations Summary Mix 450bb1 2% KCI for cleanout operations. Tested CT BOP to 250pis low/4000psi high. 6/27/2010 00:00 - 6/28/2010 00:00 _ __ _ _ ___ _ __ _ Operations Summary RIH w/ 1-3/4" CT pumping 2%KCL at 0.6bpm, cleanout from 10,462' RKB CTM to depth of 10,550' RKB CTM and sat down and broke through bridge. Continue cleanout to 10,572', POOH with CT. SDFN. ---- --- 6/2812010 00:00.6129/2010 00:00 _ _ _ __ _ Operetions Summary RU 2.31' bit and motor assembly on 1-3/4" CT, RIH w/ CT, stopped solid at 10,424' RKB CTM, POOH. Shut down and secure well. _ 6/29/2010.00:00 -6/3012010 Q000 _ -- Operations Summary Rig down all equipment, demobe/clear location. _ 6/3012010 00:00 - 7/1/2010 00:00 _ _ __ - ___ Operations Summary - Finished demobe/clear location. a• evro Swanson River Unit Sit V G3'33 Well SRU 23-33 Last Completed 10/19/87 Actual ~Vellbore Schematic Updated 7/2!10 RKQ 751' FB/ 0:139 MVISL ~-- sz' 11-3 CBL CBL 7D=10,896' PSTD=10,757' I max hole angle =v2.25° at 7,083' MD SRU 23-33 Actual Well Schematic 7-2-10 doc Updated by CVK 7-2-10 • Page 1 of 1 • l(v(-Ot~ Autxrt, Winton G (DOA) From: Kanyer, Christopher V [Chris.Kanyert~chevron.com] Sent: Tuesday, June 15, 2010 3:28 PM To: Aubert, Wnton G (DOA) Cc: Newell, Jack R [FEP] Sub~ct: RE: SRU 23-33 AOGCC 10-403 Approved 6-11-10 Attachments: SRU 23-33 AOGCC 10-403 Approved 6-11-10.pdf BOP Schematic 5K Choke -Kenai equipment 6-7-10.pdf .~t., ...T, <.< v. _. ._ ... ..1 s :_... .;-.;; _ . ~.... €...~ !_ _ "4.... e._.-, _ i2.t.; Lk i..S.~ .~ .ids ~ ~i.._ ..^a } 3 j S~ 'i€3ii u_.Vfs~ ~e,'~,~.~'~ ~'A'~_1~'~~z°?s7 s;d~~~ ~.t.'~4~~C,~€i i€ _r'~, r ~y~,r1-. 4st~ ~~~ ,' ~~~'IF+ ~:R; From: Kanyer, Christopher V Sent: Tuesday, June 15, 20101:04 PM To: 'Hubert, Winton G (DOA)' Cc: Newell, Jack R [FEP] Subject: SRU 23-33 AOGCC 10-403 Approved 6-11-10 Winton, Upon receiving our approved AOGCC form 10-403 for SRU 23-33 today (PTD 161-019, Sundry 310-173), we noted an error in the proposed procedure summary. Instep 3 we indicated the use of 1-'/z° coil. We will be utilizing 1 '/+n coil tubing for this tubinglgravel pack cleanout. I apologize for this mistake. Please let me know if you have any questions. Chris Kanyer ~ Technical Assistant Wellbore Maintenance Team Office: (907) 263-7831 Cell: (907} 250-0374 Chevron North America Exploration and Production MidcontinentlAlaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 6/16/2010 Kenai Well Control Equipment Crossover 4 1 /16" 10K BX- 155 to 7" 5K Bowen Lubricator _._~____.___~ Thread 4 1/16" 10K Quad BOP Dressed for 1.75" 1 4 1/16" 10K Flowcross with flanged 2 1 /16" 10K ports Returns Outlet ta'5 K rated - j'~ Variable choke 1 Crossover from wellhead _ ---°°~'~ flange to 4 1 /16" 10K BX-155 M~ ~,~ ~ 5K Conventional stripper dressed for 1.75" Coil .~' Blind Ram Shear Ram Slip Ram ~~~ J~a~~~.y tested min 1.5 X MPS or 1000 psi over max treating pressure. Pipe Seal Ram Kill Line rigged to ~'~ pump Dual 2 1/16" 10K fully open valves per side • • ~~Q~~ 0~ Q~Q~~Q /,~....E,~~o Timothy C. Brandenburg t ,~r:,, Drilling Manager ~~:~=~ x ~!~' ~ ~'~ ~~~~ `~"~ Union Oil Company of California `~`' ~"~' ~"~~ // ~~ ~ ,.. ~ ~ q P.O. Box 196247 '~ t(/ Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil 8a G-zone Pool, SRU 23-33 Sundry Number: 310-173 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. 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 June, 2010. Encl. c~t~-,<<~ ,!~ ~ ~a ~ ,~i • 6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE~EIVEL)~ ~Q-io wy~- JUN 0 ~ 2010 ~~~~ f LDID APPLICATION FOR SUNDRY APPROVAL~iska Dil ~ Gss Cea~~. Commissiol~ 20 AAC 25.280 ~1nrF-dr~ma 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Pertorate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Pertorm coil tubing cleanout ^~ i 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~ Exploratory ^ 161-019 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10163-00 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 ^~ Swanson Riv Unit (SRU) 23-33 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028399 [Swanson River Unit] Swanson River Field /Hemlock Oil & G-zone 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): 10,895 10,895 10,797 10,797 N/A 10,476' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surtace 1,756' 11-3/4" 1,756' 1,756' 3,070 psi 1,510 psi Intermediate Production 10,895' 7" 10,895' 10,895' 6,340 psi 3,830 psi Liner Pertoration Depth MD (ft): ' ' ' ~ Pertoration Depth TVD (ft): ' ' ' Tubing Size: Tubing Grade: Tubing MD (ft): 10,522 -10,570 , 10,630 - 10,522 -10,570 , 10,630 - 10,657', 10,669'-10,688', 10,657', 10,669'-10,688', 3-1/2 9.2# N-80 Surface-1,040' 10,697'-10,701', 10,720'- 10,697'-10,701', 10,720'- 9.3# J-55 1,040'-10,479' 10,725' 10,725' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SC-1 L & Baker Model D Sump Packers / N/A 10,476' & 10,749' / N/A i' 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development ^~ - Service ^ 14. Estimated Date for 7/15/2010 15. Well Status after proposed work: Commencing Operations: Oil ^~ Gas ^ WDSPL ^ Plugged ^ 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 Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 6/7/2010 ,' COMMISSION USE ONLY N b i S d ~ I ~~' +~ un um er: Conditions of approval: Notify Commission so that a representative may w ry tness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: -~„LS-t- ~0 ~t -~-p ~-DO O ~ S~ - Subsequent Form Required: ~p ~. 40 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ ~ , 0 ~~`GtIV JUN 15 2010 Form 10-403 Revised 12/2009 ~ Submit in Duplicate Chevron • OBJECTIVE: • Perform coil tubing cleanout of 3-1/2" tubing & gravel pack completion. PROCEDURE SUMMARY: 2 3 4 R/U coil tubing. Pressure test CT BOP to 250 psi low and 4000 psi high. ~ Perform CT cleanout w/ 1 1/2" CT from (+/-) 10,476' to (+/-) 10,797'. R/D coil tubing. • Swanson River Unit Well #SRU 23-33 6/4/10 SRU 23-33 REVISED BY: CVK 6-4-10 SitV 23-33 Weall SRU23-33 nit _ . _ , « ~ _ ,»_ _ _ _ c~ _ ~_ _ __ _ _ ~ ~ _ Last Completed 10/19/87 RKf3 154' KB / GL• 139 NN9 iB-THF:15.0 I~ .r,...~. 1 • ' =. 2T@26 ~;.' 11-3!R' @ 1756' CBL Tap: 2,59D' DV Collor s,ssa cBL ro}r. s,21a Tag Fill 18476' RIB 4118/10 8 Top of F2ck 1 8531' VIA.M 10M7B7 G 13 F41 TghtCasing ~I I~ I+z 18684' RKB z~ ~ '~ 10A8ffi7 ;~ °~ i ~,~ k ~ •t„ - Fi3 F44 14 15 16 17 Casing and Tubing Detail Size Type Wtl Grade Top Btm CONN / ID Cement /Other 22" Conductor - Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29#, N-80 Surface 81' BTC ! 6.184" 26#, N-80 81' 1,019' BTC / 6.276" 23#, N-80 1,019' 4,712' BTC / 6.366" 1800 / C t t 275' " 26#, N-80 4,712' 6,541' BTC / 6.276" sx m o x, 7 Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6,990' 6,992' DV Collar 29#, N-80 6,992' 8,411' BTC / 6.184" 700 265' / C t t 29#, P-110 8,411' 10,895' 8RD / 6.184" o x, sx m Tubing "7"MarkerJt at 10,519.49' (12.63) 3-1/2" Production 9.2#, N-80 Surface 1040' IBT / 2.992" 3-1/2" Production 9.3#, J-55 1040' 10,479' 8RD-Mod / 2.992" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 15.0' 8.38' 2.992" 6.000" Tubin Han er w/ u , 3-1/2" lift threads? 2 4,703' 14.95' ? ? Flo etrol-Johnson 3x1 GLM 3 7,205' 14.85' ? ? Flo etrol-Johnson 3x1 GLM 4 8,996' 14.77' ? ? Flo etrol-Johnson 3x1 GLM 5 10,401' 9.20' ? ? Otis LBX 3-1/2"x1-1/2" GLM 6 10,442' 1.31' 2.750" 4.500" X Ni le Min ID = 2.750" 7 10,475' 0.87' 3.000" 4.500" S-22 Locator Seal Assembl w/ 15.76' of seals 8 10,476' 4.18' 4.000" 5.968" Baker SC-1 L acker Set 10/15/87 9 10,480' 5.74' 4.770" 5.500" 80-40 Perforated Extension 10 10,499' 0.81' 3.000" 5.560" XO Sub 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safet Joint, 3-1 /2" 10RD 53k shear 12 10,501' 118.14' 2.992" 3.500" Blank Pi a w/ welded centralizers 3-1/2" 10RD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3-1 /2" 10RD centralized 14 10,737' 0.53' 2.500" 4.250" O-Rin Seal Sub 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 10RD centralized 16 10,748' 1.40' 2.439" 4.250" S-22 Indicatin Seal Assembl w/ 2' of seals 17 10,749' ? 3.250" 5.687" Baker Model D Sum acker Set 10/12/87 Perforation Data ZONE TOP BTM SPF Condition G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de H1 10,630' 10,657' 4,4,12,2 Perf6/9/61,'h° EH, 2/1/63, 10/10/87, 3/20/95 H2 10,669' 10,688' 4,4,12 Perf 6/9/61,'/2' EH, 2/1/63, 10/10/87 H3 10,697' 10,701' 4,12 Perf 6/9/61,'/:" EH, 10/10/87 H4 10,720' 10,725' 4 Perf6/8/61,'/2'EH Directional Data: TD=10896' PBTD=18791' max hole angle = 2.25° at 7,083' MD SRU 23-33 Actual Well Schematic 4-18-10.doc Updated by STP 5-21-10 evro RK@ 154' KB I GL.: 139 MA9 fB-7HF:15.0 I~ 1 zzn@zs ';~ 11-3IR' ae1759 CBL Tcp: 2,590' evcdiar 5,990 CBL Top: 9,210 8 Top of Pack 1 8531' VIA_IVI 10M 7/87 G 13 F41 Tight Casing Ft•2 1 q 684' RKB 10A8B7 ,~~,_.,. ?...?'... - FF3 FF4 14 15 16 17 7 Swanson River Unit Well SRU 23-33 Last Completed 10/19/87 1C Updated 4/18/10 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement I Other 22" Conductor - Surface 28' - Cemented 11-3/4" Surface 47#, J-55 Surface 1,756' 8RD / 11.000" 1200 sx / Cmt to Surface 29#, N-80 Surface 81' BTC / 6.184" 26#, N-80 81' 1,019' BTC / 6.276" 23#, N-80 1,019' 4,712' BTC / 6.366" 275' 1800 / C t t " 26#, N-80 4,712' 6,541' BTC / 6.276" sx m o x, 7 Production 29#, N-80 6,541' 6,990' BTC / 6.184" 6,990' 6,992' DV Collar 29#, N-80 6,992' 8,411' BTC / 6.184" 700 265' / C t t 29#, P-110 8,411' 10,895' 8RD / 6.184" sx m o x, TUbi ng '7" Marker Jt at 10, 519.49' (12.63 3-1/2" Production 9.2#, N-80 Surface 1040' IBT / 2.992" 3-1/2" Production 9.3#, J-55 1040' 10,479' 8RD-Mod / 2.992" Produc tion Strin Jewel Detail # De th RKB Len th ID OD Item 1 15.0' 8.38' 2.992" 6.000" Tubin Han er w/ u , 3-1/2" lift threads? 2 4,703' 14.95' ? ? Flo etrol-Johnson 3x1 GLM 3 7,205' 14.85' ? ? Flo etrol-Johnson 3x1 GLM 4 8,996' 14.77' ? ? Flo etrol-Johnson 3x1 GLM 5 10,401' 9.20' ? ? Otis LBX 3-1/2"x1-1/2" GLM 6 10,442' 1.31' 2.750" 4.500" X Ni le Min ID = 2.750" 7 10,475' 0.87' 3.000" 4.500" S-22 Locator Seal Assembl w/ 15.76' of seals 8 10,476' 4.18' 4.000" 5.968" Baker SC-1 L acker Set 10/15/87 9 10,480' 5.74' 4.770" 5.500" 80-40 Perforated Extension 10 10,499' 0.81' 3.000" 5.560" XO Sub 11 10,500' 1.01' 3.00" 5.160" Gravel Pack Safet Joint, 3-1/2" 10RD 53k shear 12 10,501' 118.14' 2.992" 3.500" Blank Pi a w/ welded centralizers 3-1/2" 10RD 13 10,619' 118.13' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 10RD centralized 14 10,737' 0.53' 2.500" 4.250" O-Rin Seal Sub 15 10,738' 10.12' 2.992" 4.000" Johnson Screens, 0.20" 3-1/2" 10RD centralized 16 10,748' 1.40' 2.439" 4.250" S-22 Indicatin Seal Assembl w/ 2' of seals 17 10,749' ? 3.250" 5.687" Baker Model D Sum acker Set 10/12/87 Perforation Data ZONE TOP BTM SPF Condition G 10,552' 10,570' 4 Perf 5/19/02 1-11/16", 0 de H1 10,630' 10,657' 4,4,12,2 Perf 6/9/61,'/2" EH, 2/1/63, 10/10/87, 3/20/95 H2 10,669' 10,688' 4,4,12 Perf6/9/61,'/2' EH, 2/1/63, 10/10/87 H3 10,697' 10,701' 4,12 Perf6/9/61,'/i'EH, 10/10/87 H4 10,720' 10,725' 4 Perf 6/8/61, %' EH ,.~ F--.~.at:»~ Directional Data: TD=10896' PB7D=10;791' max hole angle = 2.25° at 7,083' MD SRU 23-33 Proposed Well Schematic 6-4-10 doc Undated by CVK 6-4-10 Kenai Well Control Equipment 5K Conventional stripper Crossover 4 1 /16" 10K BX- dressed for 1.75" Coil 155 to 7" 5K Bowen Lubricator ~ Thread All sealing rams ~ Blind Ram tested min of 4 1/16" 10K Quad 1.5 X MPWHP BOP _ _ , ~ Shear Ram or 1000 psi over Dressed for 1.75" Slip Ram max treating ~ pressure. Pipe Seal Ram 4 1/16" 10K ~~ ~ Flowcross with flanged 2 1 /16" 10K Kill Line ports rigged to ~. _ ,~ pump Returns Outlet ~" ~ ' to 10K rated ~ ~ ~ Variable choke " Crossover from wellhead 10K fully open Dual 2 1 /16 flange to 4 1 /16" 10K BX-155 valves per side Schlumberger ) ') UNOCALe '-Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com May 16, 2005 ~,yO\'\;' RECEIVED MAY 1 () 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Re: 10-404 Sundry for Well SRU 23-33 Dear Mr. Aubert, Enclosed please find the 10-404 Sundry for SRU 23-33 to perforate the G-zone sand. This work was completed in May 2002. Please excuse our tardiness in submitting this report. If you have any questions or comments, please do not hesitate to contact me. Si;r~I~'-? C-. D ~ Timothy C. Brandenburg Drilling Manager SCANhlED MAY 2 6 2005 Attachment Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com STATE OF ALASKA ) ALA~ )OIL AND GAS CONSERVATION COMM......dON REPORT OF SUNDRY WELL OPERATIONS ~O ! 6 200, 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development 0 Stratigraphic D -.. ~ 6as Cons. Commis!\ion Stimulate U Other U Anchorage Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 161-019 ServiceD 6. API Number: 50-133-16163 9. Well Name and Number: SRU23-33 10. Field/Pool(s): Sewanson River Field/Hemlock, G-zone 7. KB Elevation (ft): 154' 8. Property Designation: Swanson River Production Facility 11. Present Well Condition Summary: Total Depth measured 10895 true vertical 10895 feet feet Plugs (measured) 10,795 Junk (measured) Effective Depth measured 10,740 true vertical 10,740' feet feet Casing Length Size Structural Conductor 36' 22" Surface 2,035' 11-3/4" Intermediate Production 10,895' r Liner MD TVD Burst Collapse 36' 3,070 psi 1,510 psi 2,035' 10,895' 6,340 psi 3,830 psi 36' 2,035' 10,895' Perforation depth: Measured depth: 10,552 to 10,723' True Vertical depth: 10,552 to 10,723' ." Packers and SSSV (type and measured depth) 3-1/2" 9.3#, J-55 @ 9.001'; 3-1/2", 4.6# N-80 @10,728' RECEIVED MAY 1 6 LOUJ Baker DB sump packer @ 10,740' Tubing: (size, grade, ~nd measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Alaska Oil & GltS Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 34 1,050 43 74 1,000 15. Well Class after proposed work: Exploratory n Development IJl 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 32 39 Tubing Pressure 210 250 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service n x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 302-158 Contact Diane Dunham 263-7604 Printed Name Timothy C. Brandenburg . 0/ ~/-" ;:;< é'· X Signature é:-.:Ç-X ;/ ~ V -¿:J Title Drilling Manager Phone 907-276-7600 Date ~- Ib~-ë:::S"' ReDMS 8Fl MAY 1 9 7DD5 Üt\\G\¡~AL Form 10-404 Revised 04/2004 Submit Original Only 5/19/02 ') ) MI Schlumberger. PJSM. RU. Pressure test to 3,000#. RU gun. RIH wI 18' gun, jars, CCL. TP @ 950#. Tied in with jewelry. Tagged fill @ 10,626. Fired gun. Perforated 10,552 to 10,570' (18 feet), 4 SPF, O-degree phasing. Logged up. POOH. TP @ 1,000#. RD/MO. SRU 23-33 (AFE 154639) morning report summary, CONFIDENTIAL: last revised 4/21/2005, Page 1. ,~ ~ ~ ,.1 ~ ! 1 .. "", ~,!I i '- : } : ~ ~ î :, ¡ I 1 ! I .f' I !fj i, .' ',¡ I:. .:'" ,:r . ,...... i ai'~1 , ~., 'i~ I '.'jl', ',',....."..',.:.,..ì n !! .' ¡: I . k···· ~\" ¡ .¡,~, - . U :; I q , :¡M¡ i ·Ii ...... !U ~ ':. I. "I .. ii.. ,~ y'~,U.ll~·1 . ." .' l.....,....... '='\..~.. i'...................... :,......1.,. . ..... tR1. .'., .... ..."..... 11 ¡--., 1Lu:1 I '¡,rø ~ ~.~ [, J~"1 ~ . ..... ~ .. ""u.t ....' .. ".'. .....: ....'â . i ..... ...... ~~."" ,~. A;. - .:~ ¡ ~ . - .....' ,.. 1__ ::: . '.æu.¡ .; --.,. ---.., . -'- ...... . "»>, - ~. '- r· ~-'.'~ ,"~, -:~~ == , .. ......... " --... '. .........., . --' 11- rnli~fJiilìiu~1f~~ ~ ~ ll-" :Cø1!1'1!~ COnduc.tGf ..p¡p. .., ~~UlCam,O' ~ "Odudallì CUing 111 ~) ) ~ arow 1 "1-114-. ·.11JS5: 0 ·20IS· "·.IHIIIIIIII.N'Ia&Pt1·(f cþt:·o"r IMIl'ßSJllllU t:Olptb'l WLM·¡RKB) 1, 1'-1rl'..'I'U, JIB TubI,ng .. a FlopeHhlGMlðn 111 ¡ew: I, .1.rr,.I,.II'. ,'11 Tubing ·,&----'tAoPl:'fI'oI~Mß III G1Jd! I, s:~·t2·.I"II, .III Tubing I Flø"tJal~n.n lit BlU· t 1·111'. t'..~: TublnQ I ct. \IIX' 1..I!I2~.1 'OtM . a 1"'~I2·fJt11 T Nlppl,: "11 ""'.1' 8Ð1¡¡~'GfIMIt'"P" :.' 11 ""' a~,UZ;~B,dt'""UF!.a_ JOfm" 11 1"'~.·.4;íllf Nij'" 1t..,1p.I 11 :.'Ir 4~&I. .... ~.'l!WItd 0.. GfIveI, PMklcnlnt '&:11 at' 14 ~<, U 3~'11" 0.. Hint:...·... 11 3-14· 4_N. ....··llkMwIkI ^,' ·OJ12t Tellta1la.18A1 1.1 BakI,1)8 Sump Packet P.rttJ,.tJ'l_ ¡""Jill ~IPlht WLM·'Rf<BJ G-ZönstQ',552 to 1 Or 570'. 4 SPF H1 · 10.130·. to.lsr 11 SPF HZ · '0:651' .10.GW·18 SPF H3 · 1 O.69T · 10.701' 16 SPF H4 · 1 O.72tr "" 10.723' 4 SPF PBTD · 1 D.795 n':ll'"; 4,8,;. 4111 4701 11,11 7221 8~g96r -, 11111 '.0'48. '.au7, 't04" 1041,1 'GIGI t0717 . ,,< tOf11 107~O ,I,ft....·.,.·,...·.·.·.·.·.. '- 2fHr I~'ltl~ ~, 2SIa- a19r 1~1$r .4~œ· 'Ii 2.500" ".1.: D~sòfSJ1QtQ2 sTATE OF AI_~SKA ..' ." " - ALASKa,. OIL AND GAS~ CONSERVATION COMMISSION,.. " APPLICATION FOR SUNDRy. APPROVALS ,. · Alt~r eau~tng: X_,, ' RePak well: Plugging: . ;. 11me extenlion: ... 6~~ '._j ' '. Oh~g~ approved e~r~: . p~l ~ln~ ~ ~-~-~r~ ' - .... . :~ ' Ut~lon ell ~r,~ et Call,mia .-- ............... : ............. ... Dev~pm~b a,~, ~lo~a~ ~ 7,"~orPmp,~e ' .' ~ '" . ......... 1eeo' FSL & ls7~ ~ S.o, ~, TaN,'~W, 'At top of pro~a~ve lM~, ... e.p~t~T~ ",,, . , , ...... :,,. At caesura ~F~ .. 10. ~l'n~ber 1~ FSLA 187~ F~, 8oo, ~, ~, ~W.'~M ~1~101~ . . ...... " At ~ dap~ .. " "~ 1. ~P~' : .v 18~' FSL & 1~0' F~, Soo. ~, ~ Rg~ ~ue v,r~ t~ ~ ' '. , . . , . . . ,' E~oUvo d~p~: . m~asumd t~ ,. ~ ' ' ~ (~~ ,.. ', ... ~ua va~ I~ bM · · . . , . . . . . , *. . , Ca~lng . ~n~ Size ' ~men~d ' Measur~ ~p~ ~e Vo~ dap~. '" . 6urfa~ 1756' 1 I~/4' I 1~ aX'. ' ,176e' ', t76¢ .... · · . . , . . If~r'fi~a~a~ ' .. "' ', .. ~ '. .. , .. . , ,.. Pesior'aUon depth: me~Ured . ~;~11~1~7, ~0~10701~ 10~&107~) ,~'.. . . . .... ., , , ,. . .. . .. . . P~t, and ~SV (~p, m~d m~sumd aleph) .. ~r &O1-L ~ivM ~ar lO,~r; ~ DB ,ump ~,r.O lO7~O' . ' . '. " , ......... ... ....... :... ,.,. , ~ . , ......... ...... , . ' , ,...,,. ' .......... t4. EsUmat~"~'d~'~ ~r ~mmenchg o~raU~ ..... 1~. a~t of w~ ~Mse~o'~'~o: '. . . tS, If propo~ Well verba~ ~pmv~: . .. , ,, Nmne ~l ~prov~ ~ ' De~ ~prov~ 8~1 ' ., ' ' . ..... __ _. . · --- : ,.- _ ~ ;~ ~ .... · ..... - ............ , ........ ,.,,..- ................ FOR ~MMI~ION USE ONLY- ' ~ ............... ...... M,O:~}Io~ Inta~ Te8~ S~soqu~t ~rm re~lmd 1~ ' ~ 0 ~ · :.~ ' . .,. =,.. . ... .: ... . ....:.....' :. ',.. . . · . . ..... ':' .. . . . ... , . . .. . . . . ' 'OnDna, Signed B~ " ..." .." , ; Form lck4o3 Rev o0/1~88 0 .. ...... . ...... . . ' . SUBMIT IN TRIPL. IOATE. ... :: .'"'"~ ..: .'. : ,. __ i 11 i i ,. i ii · . i i i i ! :~R U_ 23,33 Casln_a Dellll Conductor Pipe -- Suflace Casing - Production Casing - ~Tublng: Del,Il (Depths WLM- RKB) 22' @ 36' 11-3/4", 47#,J55 @ 2035' 7", 29#&26~&23~,NS0&P110. @ 10,895' I I 3-1/2', 9.3.t, J55 Tublng FiopetroI-Johnson 3xl GLM 4693 2.992' 4693 3 3-1/2', 9.3~, J55 Tubing .Flopel~oI-Johnson 3xl GLM 4708 2.992' 7205 .. to ~/~// io~o? 3-1/2', 9.~, J55 Tubing FlopetzoI-Johnson 3xl GLM '3:1/2., 9.~, J55 Tubing Otis 'LBX' 3-1/2'xl GLM 3-1/2' Otis 'X' Nipple Baker SC1-L Gravel Packer 3-1/2" Baker 'GP Safely Joint 3-1/2',4.6#, N-80 Blank Pipe 3-1/2' 4.6~, N-80 Bakerweld 0.020 Gravel Pack Screens ,,~,// ,=~ ,,~/'..r~../ 3'1/2" O- Ring Seal Sub 7220 2.992' 9001 2,992' 10391 10433 2.750" · 1 O467, 4.00' 10490 10491 10609 10727 2.600' ~o~7 PBTD- 10,795 3-1/2' 4.6/, N-80 Bakerweld 0.020 Telltale Screens B~er 'DB Sump Packer Perforation_ Betal! (Depths WLM"RKB) H1 -10,630'- 10,657' 18 SPF H2 -10',659' - 10,688' 16 SPF -H3-10,69T- 10,701' 16 SPF H4 -10,720'-10,723' 4 SPF 10728 10740 ! ,NVR. : Unocal Corporation P.O. Box196247 Anchomge, AK 99501 Telephone(907)263-7660 UNOCALe) Dan Williamson Drilling Manager 'May 1, 2002 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Tom Maunder Subject: Swanson River Unit Well 23-33 APl No. 50-133-10163 10-403 Perforate G-zone Dear Mr. Maunder: Unocal requests approval to perforate the G-zone in Well SRU 23-33 and commingle the production with the current Hemlock Perforations. The proposed G-zone perforations are from 10552 to 10570'. Form 10-403 is attached. If You have any questions, please contact Gary Orr at 263-7858. Sincerely, Drilling Manager Anchora:~e, Thanks for the reply Gary. We will consider the request for SCU 21B-16 as cancelled. I will move the SRU 23-33 on for approval. Tom Maunder "Orr, Gary A" wrote: Tom, As it tums out I submitted the request for SCU 21B-16 too soon, so please disregard it. I have been told to hold off on the project as it makes more since to change out the tubing to 2-3/8" vs the existing 3-1/2" tubing to help with unloading of fluids. The change out would not be economic with a drilling rig but since we are still evaluating the pulling unit options for the field, it makes since to wait. The proposed perforations ~[~~ are13elow the packer. A number of the wells at SwanSon River have commingled G-zone and Hemlock production. Thanks, Gary ..... Original Message ..... From: Tom Maunder [mailto:tom maunder~,admin.state.ak, us] Sent: Tuesday, May 07, 2002 2:25 PM To: Gary Orr Subject: Swanson Work Gary, I have received two work requests for work at Swanson and I have a couple of questions. 1. On 21-B-16 you propose to perforate the tubing and casing to access the 64-5s sand. Although you propose to produce up the tubing, the new perforations will not be isolated by a packer as required by 25 AAC 200 (d). Variances have been allowed in other fields, but only in cases where the reservoir pressures are around 300 psi or so. Please provide further information with regard to the expected sand pressures. 2. The perforations you plan in 23-33 will be below the packer. I presume the G and Hemlock are already commingled in Swanson as is the case in other fields? Thanks in advance. Tom Maunder, PE AOGCC 1 of 1 5/9/02 11:43 AM Ralph P. Itolm~n Engineer Technician Unocal P.O. Box 196247 Anchorage. Alaska 99519-6247 April 4, 1995 Mr. Russ Douglas Commi._o~ionex Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 On March 20, 1995 the following intervals were perforated in well SRU-23-33 (AP150-133-10163-00) in the Swanson River Field: BENCH __TOP .(MD) BO ,'!'TOM (MD) ~ HB1 10,630 10,657 27 TOTAL 27 Sincerely, RECEIVED APR 20 1995 Alaska 0il & Gas Cons. Commission Anchora~.',~ ALASKA OIL AND ~' ~I~ISE~:6JA'J'ION COMMISSION. REPO OF SUNDRY WELL RATIONS 1. Operations performed: Opera~on-~hutclown ~ Sllmula~ ~ Plugging ~ Perforate X__ Pull tubing AJter easing Repair well Pull tubing __ Other__ 5. Type of W";~ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1660' FSL, 1670' FWL, Sec. 33, T8N, R9W, SM At top of productive Interval 1660' FSI., 1670' FWL, Sec. 33, T8N, R9W, SM At effective depth 1660' FSI., 1670' FWL, Sec. 33, T8N, R9W, SM At total depth 1660' FSI., 1670' FWL, Sec. 33, T8N, Rgw, SM 6. Datum elevation (DF or KB) KB.' 154' 7. Unit or Property name Swanson River Unit 8. Well number SRU 23-33 feet 9. Permit number/~~ number 7-487 10. APl number 50-133-10163-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Uner Length 28' 1756' 10895' Perforation depth: measured 10895 feet 10895 feet 10797 feet 10797 feet Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth 20" To surface 28' 28' 11-3/4" 1150 sx 1756' 1756' 7" 2500 sx 10895' 10630-10657,10669-10701,10720-10725 true vertk:al 10630-10657,10669-10701,10720-10725 Tubing (size, grade, and measured depth) 3-1/2', N-80/J-55 @ 10753' Packers and SSSV (type and measured depth) Baker SG-1L pkr. @ 10484', Model 'D' sump 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description Including volumes used and final pressure APR 2 0 1995 Uil & Gas Cons. Commission Anch0ra, ~ 14. Prior to well operation Subsequent to operation Representative Dally Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 66 1015 37 600 76 -'" 793 36 6O0 Tubing Pressure 25O 280 15. Attachments Copies of Logs and Surveys run_ Dally Report of Wel Operations 16. Status of well classification as: Oil X_ Gas _ Suspended _ Service 17. I h~y ~e:,tiltihe~~_.re(~go(~u~and correct to the best of my knowledge. Form 16-404 Rev 06/15/88 SUBMIT IN DUPUOATE - STATE OF ALASKA ~ ALA~'"'"~I OIL AND GAS CONSERVATION COME~ !ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging _ _ Perforate Pull tubing _ _ Alter casing__ Repair well Pull tubing 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X__ Exploratory _ _ Stratigraphic_ _ Service 4. Location of well at surface 1660' FSL, 1670' FWL, Sec. 33, T8N, R9W, SM At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole ORIGINAL 12. Present well condition summary Total depth: measured true vertical 10,895' 10,895' feet feet Plugs (measured) Other X 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Swanson River Unlt feet 8. Well number SRU 23-33 9. Permit number/approval number 10. APl number 50-133-10163 11. Field/Pool Swanson River-Hemlock Effective depth: measured true vertical 10,795' 10,795' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 28' 20" Cemented Measured depth True vertical depth To Surface 28' MD 28' TVD 1756' 11-3/4" 10,895' 7" 1150 SX 1756' TVD 700 sx @ shoe & 1800 sx thru DV @ 700 measured 10630'-10657'; 10659'-10688'; 10,697'-10,701'; 10,720'-10,723' 1756' TVD 10,895' TVD 13. true vertical Straight Hole Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55, 10,391' 3-1/2", 4.6#, N-80, Gravel Pack 10,728' Packers and SSSV (type and measured depth) Baker SC 1 -L Gravel Packer 10,467'; Baker DB Sump Packer @ 10,740' Stimulation or cement squeeze summary ~ Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 0CT - 7 t994 Alaska 0il & Gas Cons, Commission Anch0ra~.ie 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 80 800 35 1610 Tubing Pressure 450 Subsequent to operation 80 800 35 1610 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x _ 450 16. Status of well classification as: Oil x_ Gas __ Suspended _ _ Service 17. I hereby certify that the fc~oi~., i~.~a~d~o the best of my knowledge, Signed G. Russell Schmidt/~...[.~.~itle Drilling Manager Form 10-404 Rev 06/15/88 Date 10/04/94 SUBMIT IN DUPLICATE SWANSON RIVER SRU 23-33 DAY 1-2 (8/19 - 20/94) 3-1/2" TBG TO 10,740' INSTALLED INJECTION HEAD, BOPE AND TESTED TO 5000 PSI. RIH WITH 2.25" NO77LE ON 1-1/2" C.T. TAGGED AT 10,651'. WASHED TO 10,658', HARD. POOH FOR MUD MOTOR. RIH AND CLEANED OUT INTERMITTENT OBSTRUCTIONS F/10,445'-10,649' AND REAMED TO 10,750'. CLEANED OUT TO T.D. (10,804' CTM) WTH NO INDICATION OF FILL. POH W/COIL TBG. AND RELEASED COIL TBG. UNIT. OCT --' 7 '~994 AISs~ 0ii & Gas Cons. Commission Anchor~.~e SRU 23.33 13aslna Oetltl Conductor Pipe - Surface Casing - Produ~on Casing - Tublna Detail (Depths WLM- RKB) 22' @ 36' 11-3/4', 47#,J55 @ 2035' 7', 29#&26#&23~,N80&P110 @ 10,895' J 3-1/'Z', 9.3~, J55 Tubing FiopetroI-Johnson 3xl GLM 4693 2.992' 4693 3-1/'Z', 9.3l, J55 Tubing FiopetroI-Johnson 3xl GLM 4708 2.992' 7205 3-1/2', 9.3J, J55 Tubing FlopetroI-Johnson 3xl GLM 3-1/2", 9.3~, J$5 Tubing Otis 'LBX' 3-1/2'xl GLM 3-I/2' Otis 'X' Nipple Baker ,~I-L Gravel Packer 7220 2.992' 9001 2.992' 10391 10433 2.750" · 1O467 4.0O" 3-I/2" Baker 'GP Safety Joint 10490 3-I/2'.4.6#, N-80 Blank Pipe 10401 3-1/2'- 4.61. N-80 Bakerweld 0.020 Gravel Pack Screens /~,// a~.-/~ ~"..r'~/ 3-1/2" O- Fling Seal Sub 10609 10727' 2.500' 3-1/2' 4.6l, N-80 Bakerweld 0.020 Telltale Screens 10728 Baker 'DB Sump Packer 10740 0CT - 7 ~994 PBTD. 10,795 Gas Cons· Commission Anchorc~ Perforation Detail (Depths WLM-RKB) H1 - 10,630'- 10,657' 16 SPF H2 - 10,659'- 10,688' 16 SPF H3 - 10,697'- 10,701' 16 SPF H4 - 10,720' . 10,723' 4 SPF I "-', STATE OF ALASKA ' ALA~. . OIL AND GAS CONSERVATION COMMI. ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Alter easing__ Repair well _ _ Change approved program __ Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension Stimulate Pull tubing __ Variance PerfOrate Oth-~r~. -- 6.'-~'atum eleVation (DF or KB) 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE. AK 99519 5. Type of Well: Development X_ Exploratory __ Strafig raphic __ Service 4. Location of well at surface 1660' FSL, 1670' FWL, Sec. 33, T8N, R9W, SM At top of productive interval 1660' FSL, 1670' FWL, Sec. 33, T8N, R9W, SM At effective depth 1660' FEL, 1670' FSL, Sec. 33, T8N, R9W, SM At total depth 1660' FEL, 1670' FSL, Sec. 33, T8N, R9W, SM ORIGINAL 7. Unit or Property name Swanson River Unit 8. Well number SRU 23-33 9. Permit number 10. APl number 50-133-10163 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10,895'M D feet Plugs (measured) None 10,895"rVD feet Effective depth: measured true vertical 10,797'M D feet Junk (measured) None 10,797'TVD feet Casing Length Structural 28' Conductor Surface 1756' Intermediate Production 10,895' Liner Size Cemented Measured depth True vertical depth 20" To surface 28' MD 28' 3VD 11-3/4" 1150 sx in two stages 1756' MD 7" 700 sx @ above shoe ,10,895'MD & 1800 sx thru DV (.~ 7000 Perforation depth: measured 10985'-10,966'; 10,956'-10,949'; 10,933'-10,908'; 10,886'0-10,872' true vertical 10,701 '-10,682'; 10,672'- 10,665'; 10,649'- 10,624'; 10,614'-10,600' 1756' 'IVD 10,895' 'IVD RECEIVED Tubing (size, grade, and measured depth) Gee attached schematic Packers and SSSV (type and measured depth) 1 5 1994 Gas Cons. Comn Anchnm,je 13. Attachments Description summary of proposal _ _ Detailed operations program_ x BOP sketch x_ 14. Estimated date for commencing operation August 24, 1994 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby certify that th~er~, lng/iii tr~nd~t to the best of my knowledge. Signed G. Russell SchrfllBt' ' ....... -Title Drilling Manager FOR COMMISSION USE ONLY Date 08/10/94 Conditions of approval: Noti[y Commission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test_ S-~bsequent form required 1-~- _~4_~___ Approved by the order of the Commission Form 10-403 Rev 06/15/88 I Approval No~, ,pproved Copy. Returned Original Signed By David W, Johnston ..... Commissioner sion Swanson River Unit 23-33 Coiled Tubing Clean Out Procedure 1. Clear and grade location. · Move in and rig up the coiled tubing unit. The coiled tubing rig up is to include an environmental liner and a complete BOPE inspection. Place a flow tank and a return tank. Build an earthen/gravel berm around both tanks to contain fluid in the unlikely event of a spill. 3. RIH with 1-1/4" coiled tubing and a wash shoe. Attempt to wash fill from 10,656' (the last wireline tag) to 10,740' (the gravel pack sump packer). Wash using lease water and taking returns to an open topped tank. If the washing is slow or impossible pick up a 2-1/2" mill and motor. 4. Once cleaned out to TD POOH and place the well on production. 5. Verify that the well is flowing. 6. Rig down and move the coiled tubing unit off location. 7. Clean the location and release the well to the production foreman. RECEIVED AUG ] 5 1994 Amska Oil & Gas Cons. Commission Anchorage J L SRU 23.33. 2_ Calina Detail Conductor Pipe - Surface C~sing - Production Ca~ing - 22' @ 36' 11-3/4', 47#,J55 @ 2035' 7', 29#&26#&23~,NS0&P110 @ 10,895' PBTD - 10,795 Tublna Del,Il (Deptl~s WLM- RKB) 3-1/2', 9.3,l, J55 Tubing FlopetroI-Johnson 3xl GLM 4693 2.992' 4693 3-1/2', 9.3,e, J55 Tubing F1opetroI-Johnson 3xl GLM 4708 2.992' 7205 3-1/2', 9.3a, J55 Tubing Flopetrol-Johnson 3xl GLM 3-1/2', 9.3#, J55 Tubing Otis 'LBX' 3-I/2'xl GLM 3-1/2' Otis 'X' Nipple 7220 2.992' 9001 2.992' 10391 10433 2.750' Baker SC1-L Gravel Packer 10467-' 4.00' 3-1/2" Baker 'GP Satety Joint 10490 3-1/2%4.6tl, N-80 Blank Pipe 3-1/2, 4.61, N-80 Bakerweld 0.020 Gravel Pack Screens ,,--.;',// ,=~... /~-_r-~./ 3-1/2~-O- Ring Seal Sub. 10491 10609' 10727- 2.500' 3-1/2,_ 4.6,l, N-80 Bakerweld 0.020 Telltale Screens 10728 Baker 'DB Sump Packer 1074~ ~ C: ~ J~' ~ D Perforation Detail .. (Depths WLM-RKB) AUG '~ 5 1~994 H1 10,630' 10,657' 16 SPF i · · - & Gas Cons. Commts H2 10,659' 10,688' 16SPF Anchora e H3 - 10,69T- 10,701' 16 SPF Jw~. H4 - 10,720' - 10,723' 4 SPF TEXAS' TOOLS-- """ 1'058 l'OOnSerles DS322 L-2S!~erles DS323 T U I R,ECEIVED AUG ~ ,.fi. 1994 Ata~ka 0il & Gas C~ons. Anchorade T P.O. Box ?gT2T'Hou, ton, Texal T Telex: 7g0905 TX TOOLS:NOU P hone:-.( 7' I'-3 ~620 6 ,si ARCO Alaska, Inc. Post Office Box ~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 14, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Subsequent Sundry Notice for SRU 23-33 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations for SRU 23-33. This well was stimulated with hydrochloric acid on August 12, 1988. Sincerely, T. S. McCorkle Engineering Manager TSM:WMP:cmk:0016 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /-~ STATE OF ALASKA ~--~. ALAS OIL AND GAS CONSERVATION COM, 'SION REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns performed: Operation shutdown [] Stimulate [~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Op. erator 5. ]Dse4l~levation (DF or KB) ARCO AlaSka Inc. Feet 3. Address 6..Unit or P.r. operty name Post Office Box 100360 Anchorage, AK 99510-0360 ~wanson myer t~mt 7-5-~ 2r~..~er 4. Location of well ,a,t surface 1,660' FSL, 1,670 FWL, Sec. 33, T8N, R9W, SM At tgp' of oroduc,t, ive interval 1,660' FSL, 1,670 FWL, Sec. 33, TSN, R9W, SM At eff,,eCtive deoth 1,660 FEL, 1,670' FSL, Sec. 33, T8N, R9W, SM At total depth ' , 1,660 FEE, 1,670 FSL, Sec. 33, T8N, R9W, SM 8. ~_~oval number 9. APl number 50-- ol 10. ~wanson River-Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,895' MD 10,895' TVD 10,797' MD 10,797' TVD feet feet feet feet Plugs (measured) Junk(measured) none none Casing Structural Length2 8' S iZ2eO" Cemented To surface Mea~gd~pth Conductor Surface Intermediate Production Liner 1,756' 11-3/4" 10,895' 7" 1,150 SX 1,756' MD in two stages 700 SX @shoe 10,895' MD & 1,800 sx thru DV @ 7000' Perforation depth: MD: 10,630'-10,657' 10'669',10,701' 10,720-10,725' TVD: 10,630'-10,657' 10,669'-10,701' 10,720'-10,725' True Verti~[ ~ 1,756' TVD 10,895' TVD Tubi~_~9, ra n m asured e th ~-~!(~/~-~5 ~g W/fm~ ~ ~0,753' Pack.e. rs. and .,$~Sy.(tyl~e a. qd.~e~re~ ~e~tb),,~ ,, ~er ~,m p~ ~u,~ ~oae~ ~ sump p~ 10,75Y & SSSV none 12. Stimulation or cement squeeze summary tr t e ,_ t~t,~¢3i~- ~0,~ ~,~ 10,701' 10,720'- 10,725' r~atmen,t,descrij3tio, ,inol~din~/olumes used a__nf~f(~{essure DIS INl-14~l; /4~ DDIS-l-l~Jl; I~lnal pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 160 1300 42 250 500 160 1750 42 250 500 14. Attachments x Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge /..,~ Signed~ ~0~-~. ~ Form 10-404 Rev. 12-1-85 Cook Inlet Engineering Manager Date Submit in Duplicate I D: clI.,.IANSCtN TEL NO: :1. 3:33 ARCO Alaska, inc. Su~si~srX Of Aflamlc Richfield Company CONTRACTOR REMARKS WELL SERVICE REPORT IFIEI. C.) · DISTRIGT- ~,TATE IOAY$ l DATE i1 , lull , i pi i - __ 0700, - m.r.~, o ............ ~=.u.,,aa = 6 5Z~, fro, ..... ARCO Al~iska, Inc. ,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering August 5, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Notice for SRU 23-33 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to acidize Well SRU 23-33. We propose to acidize the H1-H5 interval from 10630' to 10723' MD with 2,000 gal 7-1/2% HCL with additives. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Tom Wellman at 263-4304. Sincerely, Tom Wellman Interim Manager TW:WMP:ch:0012 Attachment Mr. F. Hallmark Mr. W. D. Kirchner Mr. S. Lambert Chevron U. S. A., Inc. Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany 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 [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, InC. 3. Address ~ Post Office Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1660' FSL, 1670' FWL, Sec. 33, T8N, Rgw, SM At top of productive interval 1660' FSL, 1670' FWL, Sec. 33, T8N, R9W, SM At effective depth 1660' FSL, 1670' FWL, Sec. 33, TSN, RgW, SM At total depth 1660' FSL, 1670' FWL, Sec. 33, T8N, Rgw, SM 11. Present.well condition summary Total depth: measured 10,895' MD feet true vertical 10,895' TVD feet Plugs (measured) None 5. Datum elevation (DF or KB) 154' RKB feet 6. Unit or Property name Swanson River Unit 7. Well number SRU 23-33 8. Permit number 9. APl number 50-- 10. Pool Swanson R i ver-Hemlock Effective depth: measured 10,797' MD feet true vertical 10,797' TVD feet Junk (measured) None Casing Length Structural 28 ' Surface 1,756 ' Production 10,895 ' ~X Perforation depth: MEASURED: 10,630- 10,657 '; TRUE VERT I CAL: 1 O, 630-10,657 '; Size Cemented Measured depth True Vertical depth 20" to surface 28' MD 28' TVD 11-3/4" 1,150 sx 1,756' MD 1,756' TVD 7,! 10,669-10,701'; 10,669-10,701'; Tubing (size, grade and measured depth) 3-1/2", N-80/J-55, tbg w/ tail @ 10,753' Packers and SSSV (type and measured depth) 700 sx @ shoe & 1,800 sx thru DV @ 7,000! 10,720-10,725' 10,895' MD 10,895' TVD 10,720-10,725' Baker SG-1L pkr e 10,484' 12.Attachments , Model "D" sump pkr ~ 10.753' & SSSV: none Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August, 1988 14. If proposal was verbally approved Name of approver SuBseqzmnt Work BeportexJ ('~_.~/~ ~ Fm~m No. ~ Dated-(:~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ t)O~ Title Cook I n let Inter i m Manager Commission Use Only Date Sl $ t ,~"~ Conditions of approval Notify commissiOn so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved by ,pproved Copy <~l~etur0ed Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 NO, by order of ,::~ l~i,~ ,/ the commission Date Submit in triplicate¢ SRU 23-33 ACID STIMULATION PROCEDURE NOTE: Confmn with Engineering that Sundry approval has been obtained prior to pumping job. WELLHEAD PRESSURES (8/ 3/88): 275/575/95 (Tubing/PC/SC) 1. Safety meeting with all personnel involved in the treatment. 2. Titrate acid on location to ensure proper acid concentration: A. ARCO personnel should witness onsite titration. B. Add 1 ml HC1 to 20 ml distilled water. Add 3 to 4 drops mixed red indicator. Titrate with 0.1 Normal NaOH. The mixed red indicator will change color to turquoise. 3. Flush clean pump truck, vac truck, hoses and lines. 4. MIRU pump truck. Pressure test lines to 4000 psi. 5. Establish injection rate into formation with 8 Bbls 2% NH4C1 water + 1.0% L53W (clay stabilizer). . Pump 2000 gal. of 7-1/2% HC1 with additives. Surface injection pressure should not exceed 4000 psi. NOTE: When tubing is full of liquid, surface injection pressure should not exceed 2500 psi. 7. Displace with 93 Bbls lease crude. 8. Rig down pump truck and vac truck. . Put Well back on production immediately after job. (NOTE: Acid may not be completely spent when it is produced to the surface. Soda ash should be used to neutralize any unspent acid). 10. Gauge the well after approximately 24 hours of production and initiate post treatment gauging schedule (days 1, 3, 5, 9, and 14). Acid System: 7-1/2% HC1 0.4% A250 (inhibitor) 20g/1000 gal. L58 (iron stabilizer) 0.5% F75N (surfactan0 0.5% W35 (non-emulsifier) 100g/l(XX) gal. LA1 (chelating agent) ARCO Alaska Inc. is a subsidiary oq Atlantic Richfield Company AR3B-6OO1-A ARCO ALASKA, l~C. Cook Inlet/New Ventures Engineering LOG TRAHSI,4]TTAL TO: ADDRESS: Please find the following logs en FROM: DATE: Blue *** SepJa *** Line Folded Rolled Receipt Acknowledgment: ,~: ~ Return' Receipt tO:' ARco"Alaska,'''Inc, o.~ & ATTH' '-':,lUdy Boegler A~-J~9 PoSt Office BOX 100360 ~CE IVED Anchorage, AK 99510 DEC 1 8 1987 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, Cook .~nlet//Ve~ Ventures £ngJneerjng TO: COHPA~y. ~ FROH: I,I£LL IVAr,1£ : ?ransrn~tted herewith are ~: BL=B]uelin~~thef°ll°~'/ing~ [~ ~~a~~' Fi 1~, = PC ~ PhotOcopy Receipt Ackno~'ledgment: DkC 9 ,, · A~ 9il & Gas Cons. Commissio~ Return Receipt to: ARCO Alaska Anchorage ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering RECEIVED - Transmitted herewith are the following: PLEASE NOTE: BL : Blueline~ DEC 1 8 1987 Alaska Oil & Gas Cons. Con~Jsslon ~chorage = Film, T = Tape, PC = Photocopy ~aslc~Oil & Gas Cons. Commission Rece i pt Ac knowl edgment: ua te :Anchorage Return Receipt to: ARCO Alaska, Inc. AT.TN: Judy Docgler ATG-i;io~-~c~s~ g~_l~,tp.~,.~l~,A. Po~[ Of fi ce Box 100360 Anchorage, AK 99510 .. ARCO ALASKA, IltC. Cook Inlet/New Ventures Engineering LOG TRANSMITTAL · TO: ~-/7z4~ M.,,:Z-,m_Z~4._C~L..~ ADDRESS: //~ ~ ~_. ~-____. Please find the following logs enclosed' Log ~/~ bc ~'2-.y_~ . . · B)ue *** Sepia *** Line' Folded Rolled Mylar Tape Receipt Acknowledgment: Return Receipt to: ARCO A1 aska,~ ..qs? ' ATTN: Judy ~e~ Post Office Box Anchorage, AK 99510 Anc~orag~ . ~ ~ , ~ ~' STATEOF ALASKA " · , ALASKAOIL AND 'GAS CO!NSERVATION .sOMM.ISSION WELL'COMPLETION :RECOM'PLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS[-] SUSPENDED [] A;BANDONED [] .SERVICE [] 2. Name' of Opera~or .......... 7. Permit Number ARCO Alaska, Inc. N/A ~/. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 9951.0-0360 50- N/A , 4..Location of well at surface 9. Unit or Lease Name 1660' FSL, 1670' FWL, Sec.33, T8N, R9W, SM Swanson River Unit qtG~p~ Producin~q Interval ' 10. Well Number FSL, 1670' FWL, Sec.33, T8N, Rgw,'-SM 23-33 At Total Depth 11. Field and Pool 1660' FSL, 1670' FWL, Sec.33, TSN, Rgw, SM Swanson River Field 5. Elevation .in feet (indicate KB, DF, etc.) ] 6. Lease-Designation and Serial No. Hemlock RKB 154'I A-028399 12. Date Spudded 13. Date T.D. Reached 14. ~Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/08/61 06/02/61 06/10/61'I N/A feet MS LI 1 1'7. Total Depth (MD+TvD) 18. Plug Back Depth (MD-I-T~D) 19'. Directio'nal Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10895'MD & TVD 10797'MD & TVD YES [] NO [~I N/A feet MD N/A .... 22. Type Electric or Other Logs Run lES, Sonic, Dipmeter, Micro-Cai, Neutron-Collar Log, CBL, CCL-Perf. Records, Gravel Pack Log, C~]T,/C-R/CCT, 23. CASING, LINER AND CEMENTING RECORD .... SETT1NG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:: ' -- ' ' Surf "'28' -' To surface , , 11-3/4" 47.0# -- Surf 1756' 16" 1150 sx cmt 7" 23/26/29# N-80/P-11( Surf 10895' 9-7/8" 700 sx cmt ~ shoe & 1801) sx cmt thru DV ~ 7000' , , , 24. Perforations open to Production (MD+T'VD of Top and Bottom and 25. TUBING REC6F~D interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , , **10630'-10657' MD & TVD 3-1/2" 10753' 10484' & 10753' **10669 ' -10701 ' 10720' -10725 ' '26'. ACI D, FRACTUR E, cEMENT SQUEEZE, ETC. .DEPTH INTERVAL (MD) AMOUN:I'& KIND OF'MATERIAL USED **Reperforated w/12 spf Stimulated 1/23/74 w/12-10 ac.id dump "'stimulated ....... 1/19/77 w/50/50 65% HC1-DAD dump Fractured 10/14/87 (see attached Well 27.N/A PRODUCTION TEST Date First Production I Method .of Operation (Flowing, gas lift, etc.) I , , Date of Test Hours Tested ',pRoDucTION FoR 61L;B'BL "' GA$-I~/I~F WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I , Flow Tubing C'asing Pressure CALCULATED OIL-BBL GAS-MCF WATI~R-BBL blL GRAVITY-APl (c'orr) Press. 24~HOUR RATE ~ 28.'I ' CORE DATA ............. r. ' Brlief description of I'ithology, porosity, fractures, apparent dips and presence of oil, gas or wate Submit chips. None ~Note; Workover performed 8/14/72. Workovers performed & well reperforated 2/3/63 & 10/17/87. ,, Form 10-407 WC3/91 :DAN I Submit in duplicate Rev. 7-1,80 ,CONTINUED ON ~REVERSE SIDE /'"'~_ 29. 30. 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. N/A Wireline formation tests Halliburton casing tests Data previously submitted. 31. LIST OF ATTACHMENTS Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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- lng and the location of the cementing tool. r- · Well Hlltory- InIIlIl on tl~ flrlt WIdn~igly Iftaf · well ia IgUdded or wort<over operItlona are I~lrtId. Ih~l~ld bt luramlrlzIcl on the form giving Inclulive datla only. or borough~enai IEitlta IL.... or U.lt ADL N/A ITitle ~O rkover 9/29/87 Alaska Fill ~. 23-33 ;~ ,..u,., w.o. 56.24Z lo,89s' 10,797', Stump cst blind r-m- ,' Leased ~r ~cept ri~. 0 0100 hfs, 9/25/87. 7" @ 10,895' 10,797' PBTD, POOH w/3~" DP 8.4+ Leased wtr ND tree, NU & tst HOPE. Pull & LD 2-7/8" tbg. RIH w/DPs tas TOF @ 10,496' DPM, CBU, POOH w/3½" DP. RIH w/RBP, tag TOF @ 10,496', set RBP @ 10,481' & tst to 2000 psi. PU BTTS & set 3' below tbg spool. ND BOPE. Nil tbg spool & Cst packoff to 3000 psi. Pull & LD RTTS. Tst csg to 2500 psi; OK. RIH to 10,481', unseat RBP. RIH , tag TOF @ 10,496', POOH w/3½" DP & RBP. 7" @ 10,895' 10,797' PBTD, RIH w/wsh pipe 8.4+ Leased wtr Fin POOH; no rec'y. RIH w/retrv'g tl, latch onto RBP @ 10,496', POOH; no rec'y. RIH w/OS, tag RBP @ 5008', latch, POOH, LD RBP. PU FTA #1 & RIH. RIH w/OS to 10,496' RIH w/new OS assy. , att 7" @ 10,895' 10,797' PBTD, RIH 8.4+ Leased wtr Wsh over fsh, circ, POOH, LD wshpipe. to wrk fsh loose w/o success, POOH. 9/30/87 10/01/87 7" @ 10,895' 10,797' PBTD, POH 8.4+ Leased wtr RIH w/5-3/4" OS, wrk over fsh, rel pkr; hole started taking fluid. Fill & moniter to determine static fluid level, POH, LD top pkr, 1 jt tbg & string of Gearhart jet cutter tls. fsh. MU wsh pipe, RIH, wrk over TOF @ 10,577' WLM, rev CBU, POH. The above Is correct For ~rm-prepamtlon ~d~iltHbutlon, ' s~ Procedures Manual, ~lon 10, Drilling, Pages ~ and 87. Date Title Drilling Superintendent · AtlanticRichfieldCompany ~ Daily Well History-Interim Illlll'li~.;~,r,;: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ell drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will tie reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled OUt but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil String until completion. District A, lask.~ lCounty or Parish Ken. al !State Field -_ ~l.eaee or Unit "Swanson River ] ADL N/A Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 10/02/87 10/03/87 ~hru 10/05/87 10106/87 10107/87 10108187 10/09/87 Alaska Well no. 23-33 7" @ 10,895' 10,797' PBTD, RIH 8.4+ Lease~ wtr POH, LD wsh pipe. MU OS, RIH, latch fsh, POH; rec'd 115.32' w/new TOF @ 10,697'. 2-7/8" EUE 8RD colt up & possibly split. MU BHA, RIH. 7" @ 10,895' 10,797' PBTD, Repair rig 8.4 Leased wtr RIH w/bskt grapple, att to wrk over fsh, POH; no rec'y. RIH w/double OS to 10,567', sport pill & att to circ & rotate over fsh, POH; rec'd DA tls & split colt. RIH w/sizing mill, mill on junk @ 10,698', POH; left mill & OS in hole w/TOF @ 10,690'. RIH w/spear & att to spear fsh, POH; rec'd OS & left XO bushing & rotary shoe in hole. Redress spear, RIH, latch fsh & POH; rec'd XO & sizing mill. Repair crown sheve & restrin$ blocks to 6 lns. 7" @ 10,895' 10,797' PBTD, RIH 8.4 Leased wtr RIH, wsh over fsh to top of pkr @ 10,707', POH. RIH w/OS, POH w/fsh; rec'd ail prod string. MU pkr plucker & RIH. 7" @ 10,895' 10,797' PBTD, Rm csg @ 10,684' 8.4 Leased wtr Cont RIH w/shoe & pkr plucker, tag pkr @ 10,707'. Mill & latch pkr, wrk loose, POOH & LD pkr & fsh'g assy. RIH w/BHA, att to wrk string. Mill thru tight csg @ 10,68&' 7" @ 10,895' 10,797' PBTD, POOH 8.4 Leased wtr CO to PBTD, circ, 20 std short trip. pits & POOH. Pmp sweep & rev circ. Cln 7" @ 10,895' 10,797' PBTD, Prep [o perf well 8.4 Leased wtr POOH w/3½" DP. RU Schl, rn CNL/GR/CCL f/10,795'-9975' RIH w/perf assy, set pkr. Prep co perf & flow well. , RD Schl. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 anti 87 =ate ,' Driilin~ Superintendent _, ARCO Oil and Gas Company Daily Wall History--Interim Inltnlclblil: This form ia used during drilling or workover operations. If testing, coring, dr perforating, show formation name in describing work performed. Number all drill stem testa sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheetl until final completion. Rel)ort official or representative test on "Filial" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovera and following setting ol oil string until completion. District Field Alaska ICounty or Parish JStata [enai Alaska Lease or Unit IWell no. ~OL ~/~ i 23-33 Swanson River Date and depth aa of 8:00 a.m, 10/10/87 thru 10/12/87 10/13/87 10/14/87 10/15/87 Complete record for each day while drilling or workover in progress 7" @ 10,895' 10,797' PBTD, CuC drl in 8.4 Leased wCr Perf 10,630'-10,657' & 10,669'-10,701' w/Bkr 5" TC guns @ 12 spf. Open well Co tank & att Co flow well; no indication of flow & unable co circ. POOH Co 4192' & scab TIW vlv w/oil & wCr in DP. RU Schl, short circ holes @ 4120' WLM. Circ DP & POOH w/perf assy. Guns, pkr & 1.5 JCs filled w/sand & debris. LD perf assy. MU bit & csg scrpr, RIH, tag fill @ 10,793'. Rev circ& filter fluids. POOH w/cs$ scrpr. PU 2-7/8" tailpipe & pkr, RIH, rev out 2 wrk string volumes, sec pkr @ 10,270' & tsC co 1000 psi. RU Howco & cst. Bullhead Xylene co btm perfs& allow co soak. Bullhead pre-pack co formation w/calculated cop of sand @ 10,549' Rel pkr & rev circ. RIH, tag sand @ 10,716', wsh to 16,795' & est'd 1763# 12-20 ISP into formation. POH w/DP & pkr. RU Schl, make GR/3B rn to 10,776'. Rn & set sump pkr @ 10,740' WLM, RD Schl. PU gravel pack assy, slip & cut DL. 7" @ 10,895' 10,797' PBTD, Rev circ 8.4 Leased wtr POOH w/gravel pak assy. RIH w/5 jts, 2-7/8" tbg & pkr, set pkr @ 10,445'. RU hard in to choke, open well to surf tank; no indication of flow @ surf. SI; no pressure. Rel pkr, rev circ; 27 bbls of fluid entry. RIH to 10,675', rev circ. 7" @ 10,895' 10,797' PBTD, Prep to wsh sand f/csg 8.4 Leased wtr Rev circ & filter fluid, POH. RIH w/surge assy, sweep well & circ out; gained 18 bbls f/surge. GIH to sump pkr, rev CBU, stab thru sump pkr; OK. PU above same & rev circ & filter fluid, POOH. POOH to 10,325' pkr depth, pmp pre-pack. Pump 3 bbls xc gel pad, 14 bbls xc w/10 ppg 12-20 HS proppant, 3 bbls xc pad followed by filtered lease water (bullhead slurry). Screen out @ 1BPM, 2500 psi w/9.5 bbls slurry sqz'd in perfs. GIH to wsh out sand. 7" @ 10,895' 10,797' PBTD, Batch mx slurry f/GP 8.4 Leased wtr TIH, tag sand @ 10,715', rev out sand to 10,760', circ& filter fluid, POOH. PU gravel pak assy, TIH, space out, locate in sump pkr. Att to set pkr; ball would not seat. Rev circ 2 DP vol's, drop ball & set pkr. Batch mx slurry. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent ARCO Oil and Gas COmpany Daily Well History-Final Report Inetr~-ttoae: Prepare and submit the "Flail Report" on the first Wednesday after allowable has been assigned or well is Plugged, Ablndoned. or ~old. "Flail Rlp~rr' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovere when an official tilt II not required upon completion, repo~t completion and representative teat data in blocks provided. The "Flail Report" form may be used for repo~lng the entire operation if space is available. District ICounty or Parish Field lLease or Unit .. Swanson River ] A~E AD6013 Ro11'N 5 Operltor I A.R.Co. W.i. ARCO Alaska, Inc. [ 56.241 Spudded or W.O. begun I Date Workovez i 9 / 25 /87 Com01ete record for each day reported 10/16/87 Date and depth as of 8:00 a.m. 10/17/87 10/19/87 Kenai ADL N/A Workover m~ N/A I Accountlng State COlt center code Alaska Iw.,i ~,o3_3 3 Iotal number of wells (active or inactive) on thi~, est center prior to plugging end / bandonment of this well our [ Prior ItltUl if a W,O. 0100 hrs. I 7" @ 10,895' 10,797' PBTD, Tally 3½" tbg 8.4 Leased wtr Perform gravel pek; no screen out. Over displ, rev out. Gravel Pak #2, pmp gravel pak screen out, rev, tst pack; OK. POH, LD DP. Tally tbg f/compl. 7" @ 10,895' 10,797' PBTD, RR 8.4 Leased wtr Rn 33 its, 3½" 9.2#, N-80 BTC AB Mod R-2 CA tbs & 297 its, 3½", 9.3#, J-55 8RD AB Mod R-2 CA tbS w/SC-IL Pkr @ 10,484', Sump pkr @ 10,753'. ND BOPE. NU &tst tree. RR @ 1030 hfs, 10/17/87. Old TD New TD PB Depth Kind of rig 10,795' PBTD Released rig Date 1030 hrs. 10/17/87 Rotary Classifications (oil, gas, otc.) Type completion fsmgle, dual, etc.) Oil Single Producing method Officiat reservoir namels) Flowing Hemlock Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time i Production OH on test Gas per day Pump size, SPM X length Choke size T F C P. Water % GOR Gray,fy Allowable EIfective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle / /'- Drilling Superintendent STATE OF ALASKA .~ AL. KA OIL AND GAS CONSERVATION CC ~IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P,0, Box 100360 Anchorag% AK 99510'0360 4. Location of well at surface 1660' FSL, 1670' FWL· 5ec.33, T8N· At top of productive interval 1660' FSL, 1670' FWL, 5ec.33, T8N, At effective depth 1660' FSL, 1670' FWL, sec.33, T8N· At total depth 1660' FSL; 1670' FWL~ sec.33~ TSN, 11. Present well condition summary Total depth: measured true vertical R9W, SM R9W, SM R9W, SM R9W, SM 10895'MD 10895'TVD 5. Datum elevation (DF or KB) RKB 154' 6. Unit or Property name Swanson River Unit 7. Well number 23-33 8. Approval number 7-487 9. APl number 50-- N/A 10. Pool Swanson River Field Feet Effective depth: measured 10797 'ND true vertical 10797'TVD feet feet Plugs (measured) None feet feet Junk (measured) None Casing Length Size Structural 28' 20" Surface 1756' 11-3/4" Production 10895 ' 7" Cemented Measured depth To surface 28 'MD 1150 sx 1756'MD 700 sx ~ shoe & 10895'MD 1800 sx thru DV ~ 7000' True Vertical depth 28'TVD 1756 'TVD 10895 ' TVD Perforation depth: measured 10630'-10657', 10669'-10701', 10720'-10725' true vertical 10630'-10657' 10669'-10701' 10720'-10725' · · .Tubing (size, grade and measured depth) 3-1/2", N-80/J-55, tbg w/tail @ 10753' Packers and SSSV (type and measured depth) Baker SG-1L pkr ~ 10484'· Model "D" sump pkr ~ 10753' · & SSSV: none RECEIVED 12. Stimulation or cement squeeze summary See attached Well History for fracture data Intervals treated (measured) Treatment description including volumes used and final pressure NOV - 1987 Alaska Oil & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)~U~(Jc~J~q~ , Title Associate Engineer Form 10-404 Rev. 12-1-85 Date (Dani) SW03/6 Submit in Duplicate 9/29/87 9/30/87 10/01/87 o~ Ihe fl~ Wednisdly mft~r - well ti ~pudd~d or wortK)v~r operetione ere Mlrlid. bi .untm~riz~l on the form giving Inclullv~ d~til only. L:::_ or Unit Title sim A~L ~/A Vorkover Alaska ell ~. 23-33 ~'i da~ rePorled I Hour 912.5/87 0100 242 ?. @ 10,895' -.~': I0,797', SCueq) Cst bllnd r~_ .. 8;4+ Leased vcr .' ' Accept rl~ @ 0100 hfs, 9/25/87. 7~@ 10,895' 10,797' PBTD, POOH w/3½" DP 8.4+ Leased wtr ~TD tree, ~ & cst BOPE. Pull & ~ 2-7/8" cbs. RZR v/DP, ~F ~ 10,496' DPH, CBU, POOH v/3~" DP. RI~ v/~P, Ca~ ~F 10,496', sec ~P ~ 10,481' & Cst Co 2000 psi. PU R~S i sec belov cb8 spool. ~ BOPE. ~ obi spool i Cst pac~f~ Co 3000 psi. Pull & LD ~TTS. TsC csg co 2500 psi; O1. RIH Co 10,481', unseat ~P. RI~ , rag TOF ~ 10,496', POOH v/3~" DP & ~BP. 7" @ 10,895' 10,797' PBTD, RIH w/wsh pipe 8.4+ Leased wtr Fin POOH; no rec'y. RIH w/retrv'g ti, latch onto RBP @ 10,496', POOH; no rec'y. RIH w/OS, tag RBP @ 5008', latch, POOH, LD RBP. PU FTA #I & RIH. 7" @ 10,895' 10,797' PBTD, RIH 8.4+ Leased wtr Wsh over fsh, circ, POOH, LD wshpipe. to wrk fsh loose w/o success, POOH. RIH w/OS to 10,496', att R[H w/new OS assy. 7" @ 10,895' 10,797' PBTD, POH 8.4+ Leased wtr RIH w/5-3/4" OS, wrk over fsh, rei pkr; hole started taking fluid. Fill & moniter to determine static fluid level, POH, LD top pkr, 1 jt tbg & string of Gearhart jet cutter tls. fsh. MU wsh pipe, RIH, wrk over TOF @ 10,577' WLM, rev CBU, POH. RECEIVED Alaska Oil & Gas Cons, Commission Anchorage The abo~ I$ correct For t~rm-prep~rllllon ang'~lMrlb~llon, ' ~ee Procedures blinuli, Section 10, Drilling, Pages 88 -,nd 87. Drill£ng Superintendent · ,' AtlantlcRichfleldCompany Daily Well HIMory-lnterlm ;~&;,%~,~,;;,;: Thte form is u~4d during drilling or workover operations. If testing, coring, or perforat ag, show formation name in describing work Performed, Number ell drill Item te~ts Se~luentielly. Attach description of all cores. Work performed by Producing Section will be reported on "la.rim" shlltl until flnII completion. Repor~ offtciel or representative test on "Flail" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 dlyl, or (2) Off Weaneadly of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. DJltrjct A, laska lCouflty or Parish menai Jstate Field ILeaSe or Unit .... ~anson ~iver I ~L N/A ' Comple~ record for each day while drilling or workover in progre~ Date end depth a~ o! 8:00 e.m, 10/02/87 10/03/87 thru 10/05/87 10/06/87 10107187 lO/O8/87 10/09/87 7" @ 10,895' 10,797' PBTD, RIH 8.4+ Leased' wtr POH, LD wsh pipe· HU OS, RIH, latch fsh, POH; rec'd 115.32' w/new TOF @ 10,697'. 2-7/8" EUE 8RD colt up & possibly split. I~ BHA, RIH. 7" @ 10,895' 10,797' PBT9, Repair rig 8.4 Leased wtr RIH w/bskt grapple, att to wrk over fsh, POH; no rec'y. RIH w/double OS to 10,567', sport pill & att to circ & rotate over fsh, POH; rec'd DA tls & split colt. RIH w/sizing mill, mill on Junk @ 10,698', POH; left mill & OS in hole w/TOF @ 10,690'. RIH w/spear & att to spear fsh, POH; rec'd OS & left XO bushing & rotary shoe in hole. Redress spear, RIH, latch fsh & rec'd XO & sizing mill. Repair crown sheve& restring blocks to 6 ins. 7" @ 10,895' 10,797' PBTD, RIH 8.4 Leased wtr RIH, wsh over fsh :o top of pkr @ 10,707', POH. RIH w/OS, POH w/fsh; rec'd all prod string. MU pkr plucker & RIH. 7" @ 10,895' 10,797' PBTD, Rm csg@ 10,684' 8.4 Leased wtr Cont RIH w/shoe & pkr plucker, tag pkr @ [0,707'. Mill & latch pkr, wrk loose, POOH & LD pkr & fsh'g assy. RIH w/BHA, att to wrk string. Mill thru tight csg@ 10,684'. 7" @ 10,895' 10,797' PBTD, POOH 8.4 Leased wtr CO to PBTD, circ, 20 std short trip. pits & POOH. Pmp sweep & rev circ. Cln 7" @ 10,895' 10,797' PBTD, Prep to perf well 8.4 Leased wtr POOH w/3½" DP. RU Schl, rn CNL/GR/CCL f/10,795'-9975' RIH w/perf assy, set pkr. Prep to perf & flow well. , RD Schl. Alaska Well no, 23-33 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Oate D r i ll$_ng Superintendent NECEIVED NOV .... 6 Alaska Oil & Gas Cons. Commission Anch0ra~e ARCO Oil and Gas Company <~ Dally Wall History--Interim : ' ' rlllin or workover operations. If testing, coring, Or perforating_, show formation name in describing work performed. .l~S .tl.~etle?.s_T,.h. la.fo_rm._?._u__s_e~_.._d_u.r,i_n,,g.o d .... ?~ .... r-ti~,n of all cores' Work nerformed by Producing ~ectlon will be reported on "Interim" sheets until final completion Report official or representative test on "F. iaal for.re. 1.) Subs. It InleH.m..s. heets wh.e..n fi led .o. ut but not I.ess freq. uently than every 30 days, or (2) Oll Wednesday of the weak in which oil string ia set. Suomit weekly lor worv. overs an(I lOllowing seuing o! oil string until completion. District Field Date and depth' ss of 8:~X) a.m. ICounty or Parish Alaska ! Kenai I Lease or Unit .... Swanson River ADL N/A Complete record for each day while drilling or workover in progress 10/10/87 thru 10/12/87 10/13/87 10/14/87 10/15/87 ISlets Alaska IWell no. 23-33 7" @ 10,895' 10,797' PBTD, Cut drl in 8.4 Leased wtr Perf 10,630'-10,657' & 10,669'-10,701' w/Bkr 5" TC guns @ 12 spf. Open well to tank & att to flow well; no indication of flow & unable to circ. POOH to 4192' & stab TIW vlv w/oil & wtr in DP. RU Schl, short circ holes @ 4120' WLM. Circ DP & POOH w/perf assy. Guns, pkr & 1.5 its filled w/sand & debris. LD perf assy. MU bit & csg scrpr, RIH, tag fill @ 10,793'. Rev circ & filter fluids. POOH w/csg scrpr, PU 2-7/8" tailpipe & pkr, RIH, rev out 2 wrk string volumes, set pkr @ 10,270' & tat to 1000 psi. RU Howco & sst. Bullhead Xylene to btm parrs & allow co soak. Bullhead pre-pack to formation w/calculated top of sand @ 10,549'. Rel pkr & rev circ. RIH, tag sand @ 10,716', wsh to 10,795' & est'd 1763# 12-20 ISP into formation. POH w/DP & pkr. RU Schl, make GR/JB rn to 10,776'. P,n & set sump pkr @ 10,740' WLM, RD Schl. PU gravel pack assy, slip & cut DL. 7" @ 10,895' 10,797' PBTD, Rev circ 8.4 Leased wtr POOH w/gravel pak assy. RIH w/5 jts, 2-7/8" tbg & pkr, set pkr @ 10,445'. RU hard in to choke, open well to surf tank; no indication of flow @ surf. SI; no pressure. Rel pkr, rev cart; 27 bbls of fluid entry. RIH to 10,675', rev circ. 7" @ 10,895' 10,797' PBTD, Prep to wsh sand f/csg 8.4 Leased wtr Rev circ & filter fluid, POH. RIH w/surge assy, sweep well & circ out; gained 18 bbls f/surge. GIH to sump pkr, rev CBU, stab thru sump pkr; OK. PU above same & rev circ & filter fluid, POOH. POOH to 10,325' pkr depth, pmp pre-pack. Pump 3 bbls xc gel pad, 14 bbls xc w/10 ppg 12-20 HS proppant, 3 bbls xc pad followed by filtered lease water (bullhead slurry). Screen out @ 1BPM, 2500 psi w/9.5 bbls slurry sqz'd in perfs. GIH to wsh out sand. 7" @ 10,895' 10,797' PBTD, Batch mx slurry f/GP 8.4 Leased wtr TIH, tag sand @ 10,715', rev out sand to 10,760', circ & filter fluid, POOH. PU gravel pak assy, TIH, space out, locate in sump pkr. Att to set pkr; ball would not seat. Rev circ 2 DP vol's, drop ball'& sec pkr. Batch mx slurry. The al:)ove is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Oate ~' ]Td~e Drilli~ F, Ek. L ! v Alaska Oil & Gas Cons, Commission Anchorage ARCO Oil and Gas Company Daily Well History-Final Report Inat~tiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or ~old. "Final ReDo~t" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workover~ when an official test Is not required upon completion, report combletlon and representative test data in blocks provided. The "Final Report" form may be u#d for reporting the entire operation if space is available. District ~County or Parish Alaska I Kenat Field ILease or Unit Swanson River I ADL N/A AUth. or W.O. no. ITItle ~ AD6013 I Workover Roll'N 5 Operator ~ A, R. Co. ARCO Alaska, Inc. Spudded or W.O. begun ] Date Workover lO/16/87 Date and depth aa of 8:00 a.m. 10/17/87 thru lO/19/87 Complete record for each day reported Accounting coat center code m~ ~/A 56.24% 9/25/87 Iotal number of wells (active or inactive) on this, Dst center prior to plugging and / bandonment of this well our 0 IPdor ltltUl If a W.O. 100 hrs. I 7" @ 10,895' 10,797' PBTD, Tally 3½" tbg 8.4 Leased wtr Perform gravel pak; no screen out. Over displ, rev out. Gravel Pak ~2, pmp gravel pak screen out, rev, tat pack; OK. POE, LD DP. Tally tbg [/compl. 7" @ 10,895' 10,797' PBTD, RR 8.4 Leased war Rn 33 its, 3½" 9.2#, N-80 BTC AB Mod R-2 CA tbg & 297 its, 3½", 9.3#, J-55 8RD AB Mod R-2 CA tbS w/SC-IL Pkr @ 10,484', Sump pkr @ 10,753'. ND BOPE. NU & cst tree. RR @ 1030 hfs, 10/17/87. RECEIVED Jw,,, ~o3_33 aaska Oil & Gas Cons. Commission Anchoragfi Old TD Released rig 1030 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data [New TO IPBDep,h 10,795' PBTD Date JKind of rig 10/17/87 J Rotary JType completion fsmgie, dual, etc.) Single Official reservoir name.~s) Hemlock W'gll no. Date Reservoir Producing !nterval ]Oil or gasTest t~me Production Oil on test Gas Der day I~u'mp size, gPM X length Choke size TP. C.P. Water % GOR Gray,ay Allowable Effective date corrected _~' The above is correct For form preparation and distribution, sea Procedures Manual, Section 10, Drilling, Pages 86 and 87. lOate '~ [Title Drilling Superintendent /~,~ STATE OF ALASKA AL KA OIL AND GAS CONSERVATION C(. VlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate X;] Pull tubing Alter Casing [] Other ~ 2. Name of Operator 5. ARCO Alaska. I ne. 3. Address 6. P.O. Box 100360 Anchoragem AK 99510-0360 4. Location of well at surface 7. 1660' FSL, 1670' FWL, Sec.33, T8N, At top of productive interval 1660' FSL~ 1670' FWL~ 5ec.33~ T8N~ At effective depth 1660' FSL, 1670' FWL~ Sec.33, T8N~ At total depth 1660' FSL~ 1670' FWL~ sec.33, T8Nt R9W~ SN 11. Present well condition summary Total depth: measured 10895 'MD true vertical 10895'TVD Rgw, SN Rgw~ SM R9W~ SN Datum elevation (DF or KB) RKB 15~, Unit or Property name Swanson River Unit Well number 23-33 8. Approval number 7-487 9. APl number 50-- N/A 10. Pool ~wan§on River Fteld Feet feet feet Plugs (measured) None Effective depth: measured 10797 'MD true vertical 10797'TVD feet feet Junk (measured) None Casing Length Size Structural 28' 20" , Surface 1756' 11-3/4" Production 10895' 7" Cemented Measured depth To surface 28'MD 1150 sx 1756'MD 700 sx-~ shoe & 10895'MD 1800 sx thru DV ~ 7000' True Vertical depth 28 'TVD 1756'TVD 10895 ' TVD Perforation depth: measured 10630 ' -10657 ' ~ 10669 ' -10701 ', 10720 ' -10725 ' 12. true vertical 10630'-10657', 10669'-10701 ', 10720'-10725' Tubing (size, grade and measured depth) 3-1/2", N-80/J-55, tbg w/tail (~ 10753' Packers and SSSV (type and measured depth) Baker 5G-1L pkr (~ 10~+84'~ Model "D" sump pkr @ 10753' , & SSSV: none Stimulation or cement squeeze summary See attached Well History for fracture data Intervals treated (measured) RECEIVED ~ .";. (t. ¢ Anchora.:n.,e Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover We] 1 Hi stor~) Daily RepOrt of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,,~/~I,(/~J.q..,t . Title Associate Engineer Form 10-404 Rev. 12-1-85 (~ (Dani) 5W03/6 Date /0'~)'~ 7 Submit in Duplicate Inetrtmtk~t's:Prepare and subm'l~ the "lnl#al I~rt" on the fl~t Wednesday i~ef a well 18 a~udded or wo~r o~mtlona l~d. Dally wo~ pdor ~ s~n~u~d be summarized on the fo~ giving inclull~ dates only. Swanson ~ver Auth. or W.O. no. ITM ~g ~6013 I Workover I aa of _ Roll'N 5 AP1 N/A Operator ARCO Alaska, Inc. Spudded Oi' w.O. begun Workover 9 / 25/87 Complete record for each day ~/2~/87 9/26/8'7 9/28/87 9/29/87 Dally IWell no. 23-33 9/30/87 10/01/87 ARCO w.I. otoo~ ~ ,,, w.o. 56.24% 7" @ 10,89.5' 10,797', Stump tat blind rams 8.4+ Leased w~r Accept ri~ ~ 0100 hfs, 9/25/8~.. 10,797' PB~, POOH w/3~" DP 8.4+ Leased ~r ~ tree, ~ a Cs~ BOPE. Pull w/DP tag TOF ~ 10,496' DPH, CBU, POOH w/3%" DP. 10,496*, set ~P ~ 10,481~ & Cs~ ~o 2000 psi.~ PU R~S & set 3' below tbg spool. ~ BOPE. ~ tbg spool ~ ~st pac~ff ~o 3000 psi. Pull & LD RTTS. TsC cs~ ~o 2500 psil OK. RIH ~o 10,481', unseat ~P. RIH , tag TOF ~P. 7" @ 10,895' 10,797' PBTD, RIH w/wsh pipe 8.4+ Leased wtr Fin POOH; no rec'y. RIH w/retrv'g tl, latch onto RBP @ 10,496', POOH; no rec'y. RIH w/OS, tag RBP @ 5008', latch, POOH, LD RBP. PU FTA #1 & RIH. 7" @ 10,895' 10,797' PBTD, RIH 8.4+ Leased wtr Wsh over fsh, circ, POOH, LD wshpipe. RIH w/OS to 10,496' to wrk fsh loose w/o success, POOH. RIH w/new OS assy. , att 7" @ 10,895' 10,797' PBTD, POH 8.4+ Leased wtr RIH w/5-3/4" OS, wrk over fsh, tel pkr; hole started taking fluid. Fill & monster to determine static fluid level, POH, LD top pkr, 1Jt tbg & string of Gearhart Jet cutter tls. fsh. MU wsh pipe, RIH, wrk over TOF @ 10,57R ~ E~?E ~H. Alaska Oil & Gas Cons. The above is correct Signatu~ . ..~ __ / For t~rm~preparation and--distribution, ' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent AR3B-459-1-D Number all daily well history forms conlecutivelyno. · , they are prepared for each well. ' gllPSle Atl"ntiCRIchfleldCompa"Y: ~ l:M,y Well Hlotory-I~m ;_:=:--_£~£_:=} Tllll ,~.'~.. ii ':'_?'~ ~.~,F,~ d~.;::~.~ or '~,?_,~.¥&r ?l~rittona. If testing, coring, or_l~rforetlng, ,how fortuities ~lime in ~Jelcrit}ln . Numl~o. r. MI ~_~11_ .it~_..t._~e~? ms4ueatlllly.. ~ttlt~_.4 _o_l_c_ r~p_t!_o?.,.o,. ,11 co_rl~_..Wo~ ~erformecl by ~'rocluctng Sec,oh will Oe recoiled on "fntmM,~ ?,~ I~,.~, mm~_~ ¢Ollt.~t. MlOft. Iqlf;OFl OITIClII or rOprlllfll&tlvO ~.Oe~ On _ l?1111 TOrrfl. 1) 5uomit "Interim" ~l~Ot, when fille(~ out bu, not lesl fre-,=-~tI- .~';----~--T'~'~q'~- u.,s~, ,m~ Oll WldflOldly O! till qo'~tk in which Oil ItrJng ii lit. :5uomlt weekly for workovlrl end following setting of oH string until cemeterieS.~ ,... every ~g ~, Or (2) OltlrJOtploi(i~'- SWSI~O~A~aS~'J RJLver !cOuntyLlm or°'u..P"i*" ADLKenaiH/A ' is'"' ~Om01otl rlcord for oeGh oily while drilling or wo,kover in pro0f'eli ms of 8:00 to/o2/87 ~0/0~/87 chL'~t 10/05/87 10/06/87 10/07/87 lO/O8/87 10/09/87 7" @ 10,895' 10,797' PBTD, Repair 8.~ Leased w~r · IH w/bskt &rapp~e, att to vrk over fsh, POH; no rec*y. ~IH w/double OS to 10,~67', sport pill & a~t to circ & rotate over fsh, POH; rec'd DA tls & split colt. RIH w/sizin$ m:LI~, mill on lunk @ 10,698', POH; le~t mill i OS in bole v/TOF @ 10,690'. RIH ~/spear & att to spear fsb, POH; rec'd OS & left XO bushinS & rotary sboe in bole. Redress spear, RIH, latcb ~8h & POH; rec'd XO & sizint mill. Repair cro~n sheve & restrin$ blocks to 6 Ins. 7" @ 10,895' 10,797' PBTD, RIH 8.4 Leased wtr RIH, wsh over fsh ~o ~op of pkr @ 10,707', POH. RIH w/OS, POH w/fsh; rec'd all prod string. MU pkr plucker & RIH. 7" @ 10,895' 10,797' PBTD, Rm csg,~ ~ 10,684' 8.4 Leased wtr Cont RIH w/shoe & pkr plucker, tag pkr ~ 10,707'. Mill & latch pkr, wrk loose, POOH & LD pkr & fsh'g assy. RIH w/BHA, att to wrk string. Mill thru tigh~ csg .~ i0,~4'. 7" @ i0,895' 10,797' PBTD, POOH 8.4 Leased wtr CO to PBTD, circ, 20 std short trip. pits & POOH. Pmp sweep & rev circ. Cln 7" @ 10,895' 10,797' PBTD, Prep ~o perf well 8.4 Leased wtr POOH w/3½" DP. RU Schi, rn CNL/GR/CCL f/[0,795'-9975' RIH w/perf assr, se~ pkr. Prep to perf& flow well. , RD Schl. Alaska IWell The above is correct For form Dreoeration and clistribution see Procedure, Manual Section 10, Drilling, Page~ 86 &nO 87 Driilin~ ~,u~r~Ir~e~n~_ ~% Alaska Oii& G~s Cons, C,?:} ,.'?: .-: ! ~-:., " · ARCO 041and n_.__~ __Corn_ pany 4) Dilly Well Hl~tory--IntMIm I duri drilling or woriuwer ooeretiont If to,ting, coring.,_rir_Perf, or0tlng, tl?.ow formetlon ~&~,,® in ~,;.;,~;4b. lnt} work Igee~al,~l~: Thll fom~ I u~e(I .i.~] ................. ,,~ -, ,-,~ - W,,rk Mrform~ Dy F, rooucsng 84etlon will be reported on "lgelMdOl" ~ Numl~r Iii drill ~ .t..l~l. IIqL~MttlMly: .~,un~s~ow~__-",?~,~,¥"foii~l .~ub~it "~IM~II" shNtl when §lllri out but not lell flTqUMltly thin ever 30 (~IWa, or completion, f~.~ omcl,il .or ?,_~l~_. t?jl~ve__ ~.wm,_u,- .ql~'~t ~1~ ~r'~i~orkoverl /nd following setting of oil string until completlon. on W~IIIlIdly Of ~ W Iff WfllCI! Oil I~l'lrlV ge N, ~" SwJ~on R.tver 10/10/87 chou 10/12/87 10/13/87 ~d ii M 8.'00 a.m. 10/15/87 ¢ounw or Pad~ ~ [~ Kenai J Alaska ~ or Unit Iwe" ~' ADL N/~ ] 23-33 ~omplltt re(:ol~l fOr ea~h day while refilling or workover in p;~;~ 7# S 10,895' 10,797' PBTD, Cut drl In 8.4 Leasedwcz Per, 10,630'-10,657' & 10,669'-10,701' w/Bkr 5" TC ~ @ 12 spf. Open well co tank & aCC co flow well; no indication of flow i unable co circ. POOH co 4192' & scab TZV vlvv/oil & vcr in DP. RU Schl, short circ holes @ 4120' WLM. Circ D~ & ~OOH w/parr assy. Guns, pkr & 1.5 Jcs filled w/sand & debris. LD perf assy. MU bic &cs$ scrpr, RIH, tag fill @ 10,793'. R~v circ& filter fluids. POOH v/cs$ scrpr. PU 2-?/8# ~ailpipe & pkr, RIH, rev dUC 2 wrk sCrin$ volumes, sec pkr @ 10,270' & ~sc co 1000 psi. RU Rowco& Cst. Bullhead Xylene Co bc~ per£s & allow to soak. Bullhead pre-pack to formation w/calculated Cop of sand @ 10,549'. Rel pkr & rev circ. RIH, cas sand @ 10,716', ~sh to 10,795' & esc'd 1763~ 12-20 1SP into formation. POH w/DP & pkr. RU Schl, make GR/JB rn Co 10,776'. lin & sec sump pkr @ 10,740' WLM, RD $chl. PU gravel pack assy, slip & cut DL. 7" @ 10,895' 10,797' PBTD, Rev circ 8.4 Leased wtr POOH w/gravel pak assy. RIH w/5 jts, 2-7/8" tbg & pkr, set pkr @ 10,445'. RU hard in to choke, open well to surf tank; no indication of flow @ surf. SI; no pressure. Rel pkr, rev circ; 27 bbls of fluid entry. RIH to 10,675', rev circ. 7" @ 10,895' 10,797' PBTD, Prep to wsh sand f/csg 8.4 Leased wtr Rev circ & filter fluid, POH. RiH w/surge assy, sweep well & circ out; gained 18 bbls f/surge. ~!{ ~ sump pkr, rev CBU, stab thru sump pkr; OK. PU above same & rev circ& filter fluid, POOH. POOH to 10,325' pkr depth, pmp pre-pack. Pump 3 bbls xc gel pad, 14 bbls xc w/10 ppg 12-20 HS proppant, 3 bbls xc pad followed by filtered lease water (bullhead slurry). Screen out @ 1BPM, 2500 psi w/9.5 bbls slurry sqz'd in perfs. GIH to wsh out sand. 7" @ 10,895' 10,797' PBTD, Batch mx slurry f/GP 8.4 Leased wtr TIH, tag sand ~ ,'0,715', rev out sand to 10,760', circ & filter fluid, POOH. PU gravel pak assy, TIH, space out, locate in sump pkr. Att to set pkr; ball would not seat. Rev circ 2 DP vol's, drop ball & set pkr. Batch mx slurry. The above is correct For for~ preparation and clistribution see Procedures Manual Section 10, Drilling, Pages 86 and 67 Drilling SuRerintendgr~ ~, O: ARCO OII and Gas Company Daily Well HIItol?-Flnel Report k. Ifllill4lMl~: Pmplrt Ind submit the "PMM RelMt" on the first Wedneldly iftef allowable hit been Illlgned or weft ia Plugged. AI)M,IMtML Or ~ld. "~M ~' ~ould ~ ~Omt~ed i1~ when o~rltionl Im ~l~nded for ~ indefinite or Ipp~llble I~gth of time. On wo~ ~ ~ o~clM ~ Il nm ~utM u~n com~etion, m~ comMetlon mhd m~t~l~ tett dlil tn blocks provided. The "F~ RMV' lorn rely be u~ for m~ning me ~ti~ ~o/~6/87 # M I:QO &m. 1o/17/87 thru 10/19/87 w.,, ~-33 for eich ally ripened Iotal number of Wit (MWVl M' inl~ttve) oe th& oat center prior to pl.~lal lad / bindonmint of thll well our IPflo~ ItlIM If · W.O. OlO0 hrs. [ 7" @ 10,895' 10,797' PBTD, T&lly 3¥' tbs 8.4 Leasedvcr Perform sravel pak; no screen out. Over dtspl, rev out. Gravel Pak ~2, pup sravel pak screen DUC, rev, Cst pack; POH, LD DP. Tally cbs 7"'@ 10,895' 10,797' PBTD, RR 8.4 Leased wtr Rn 33 its, 3½" 9.2#, N-80 BTC AB Hod R-2 CA tbs & 297 its, 9.3~, J-55 8RD AB Mod R-2 CA tbg w/SC-IL Pkr @ 10,484', Sump pkr @ 10,753'. ND BOPE. NU & cst tree. RR @ 1030 hrs~ 10/17/87. Alaska 0il & Gas Cons. Old TO New TO GB Oecth ].0,79.5 t ?BI'D Released ng Date K~nd of rig 1030 hrs. 10/17/87 Rotary Classifications (oil, gas, etc.) Type comc,e::o.~ s,-~q,e ~ua!. etc 1 Oil Single Producing method Offlcia! rese,,,c,r ~']~e: s Flowing Hemlock Potential test data Well no Date Fteseao~r I~-c:,.:,,~g Interval C~ Or ;35 Te$: :,me Production Otl on test Gas Der day · Pump size, SPM X lengti~ Choke size i r .~ C ~ ;,a:er % GOR G~a~,ty AIIowal:)le Effective date coffee:ed i The above is correct For form preparation and dietribution, ~ee Procedures Manuel, Section 10, Drilling, Paget 86 and 87. Date ]Title Drtllin$ Superintendent ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 ~12 ! 5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph:~ Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories' 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in- inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to.determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, o ~"T/-,~- .,?" K_~-~ ~-.~'.~' H, F, Blacker Regional Engineer Cook Inlet/New Ventures HFB' JWR' ch' 0006 Attachment CC: C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Con~nission Form 3160--5 {November 1983) (Formerly 9--331) uNITED STATES ,um.,T m T,,,,-u¢Ir-. (Other Instr~tetions sa re- DEPARTMENT OF THE INTERIOR .rse-'d.) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ this form for proposals to ~flRI or to deepen or plug back to · different r~rvolr. Use "APPLICATION PERMIT--" for such pr~pomlL) WELL WELL OTHER 2. NASda or OPERATOR ARCO Alaska,, Inc. ADDaieaa or oPaaiToa P. O. Box 100360 Soldotn~ Anchora~a. AK qOqiO-O3RO LOCATION OP WELL (Report location clearly and f'fi n~eordnnce with nay State requlrementa.® See also space 17 below.) At su. rfaee Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. PSRMIT NO. 16. Et~VATSONS (Show whether DP. sr. mt. ete.) Form approved. Budget Bureau No. 1004-0135 Expires, August 31, 1985 5. Lm`iam oaato~iTsow `aWe mn*aL aG. O. I~ IMDI`IW, `ALLOTTEE OI TIIBll NAMI ?. 0MIT AoaBBMBMT IWAMI CreekTSwanson River Unit 8. 'AIM 011 LBAII NAMI O. WELL 10. ,IBLD `IND POOL, OB WILDC`IT Swanson River Field 112 toe. ~. L, Bf., OS m~. Aim · UIVB! Om ARB& Kenai I Alaska lC. Check Appropriate Box To Indicate Nature o[ Notice, Report, or Olher Data N(~TICB OJ* INTBNTION TO: TEST WATER SHUT-Orr FRACTURE TREAT RFIOOT OR ACIDIZI REPAIR WELL (Other) PULL OR ALTER CASINO MULTIPLB COM PI,EVE ABANDON® CHANGE PLAN8 Temporarily abandon W ATBI SHUT-Or, ~ BB,`I~.,1NO WELL ~'~ raac~Ual TII&TMBNT 1~1 , AL%lBIMO C&llNO l~ SHOOTING OB AClDIBINO I (Other) ..... (NOTS: RePort results or multiple eompletiou on Weft Completion or Reeompletton Report and Lof form.) 17. o~;scRtu£ f.RovosEo OR COMPLETED OPERATION.e. (Clearly state all perttne,t details, and give pertinent dates, Ineludln~ estimated date of Ittrtlnl any proposed work. If well ia direetionally drilled, give subsurface loe~tluns and mens,red and true vertical depths got nil markers and sones patti- neat to t~is work.) ~ As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON'RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 SRU 34-10 SRU 22-23WD SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 %%~%~t%~q SCU 33-5 SCU23B-3 SRU 34-15 SRU 34-28 SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 - ~ SCU21A-4 SRU43A-15 SRU 24-33 ,,-~\~ 'Z ( ~''~-O~S$/0~ SRU312-22 SRU 12-34 SRU 21-22 SRU 21-34 [~IB~-~-0I~'~ 18. [ hereby cert~._tJ~,at the for, t%,oiflg l~/~ue and eorrect TITLE _weg!on_.! En$~_neer (This spaee for Federal or State oflee use) APPROVED BT CONDITION~ OF APPROVAL, LF ANY: TITLE DATE *See InWuctions on Revme Side Title 18 U.S.C. Section lOOt, makes it a crime for any person knowingly and willfully to make to any department or agency of the ................. [ .... J--' ....................... *.*:----,, am e,. ,.,,,.~mteJp u~itt~i~q It~ iltri_qvli~tjflfl_ TABLE Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B 1 owdown 43A-15 314-27 331-27 343-33 STATE OF ALASKA '~""~ AL/-,_ .,A OIL AND GAS CONSERVATION CO~,..,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing Abandon [] Suspend [] Operation Shutdown [-] Re-enter suspended well [] Alter casing [] '~Amend order ~ Perforate~g~. Other/~ Anchorage, AK 9951 0-0360 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 4. Location of well at surface 1660' FSL, 1670' FWL, Sec.33, T8N, Rgw, SM At top of productive interval 1660' FSL, 1670' FWL, 5ec.33, T8N, Rgw, SM At effective depth 1660' FSL, 1670' FWL, Sec.33, T8N, Rgw, SM At total depth 1660' FSL, 1670' FWL, Sec.33, T8N, Rgw, SM 5. Datum elevation (DF or KB) RKB 154' feet 6. Unit or Property name So]dotna Creek Unil; 7. Well number 23 -33 8. Permit number N/A 9. APl number 50-- N/A 10. Pool Swanson River Field 11. Present well condition summary Total depth: measured 1 0895 ' ND feet true vertical 1 0895 ' TVD feet Plugs (measured) None Effective depth: measured I 0797 ' MD feet true vertical 1 0797 ' TVD feet Casing Length Size Structural 28 ' 20" Conduct;or Surface Production .Junk (measured) None Cemented To surface 1756' 11-3/4" 1150 sx 10895' 7" 700 sx @ shoe 1800 sx thru DV ~ 7000' Measured depth Perforation depth: measured 10630'-10657', 10669'-10688', 10697'-10701' true vertical 10630'-10657', 10669'-10688', 10697'-10701' Tubing (size, grade and measured depth) 2-7/8" N-80 (~ 10727' Packers and SSSV (type and measured depth) HS-16-1 pkrs ~ 10557'j 10660': Mod "F" (~ 1~3707'_ nn .q.q~/ 12.Attachments , 10720'-10725' , 10720'-10725' 28'MD Rue Verticaldepth 28'TVD 1756'MD 1756'TVD 10895'MD 10895'TVD RI CEIIfED JUL 1 1987 Alaska 011 & 8as O~m~. Cornmlssio,,~ Anchorage Description summ~ry of proposal~ Detailed operations program [] BOP sketch/~ 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,/~ ~./~.~., Title Associate Drilling Engineer Commission Use Only (SRS) SA2/63 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~" , ~,,~ ~ Commissioner Approved by I Approval No. ..~..,,~.~.~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate General Procedure SCU 23-33 Recomplete With A Gravel Pack 1. Prior to moving in workover rig, the well will be killed with ±9.0 ppg brine and the tubing cut. (Anticipated BHP = ±4800 psi or 8.7 ppg EMW) 2. Move in rig up workover rig. Test BOPE. 3. Pull present completion and clean out wellbore to PBD. 4. Reperforate the same zones underbalanced with tubing conveyed guns. Flow well to clean up perfs. 5. Kill well & POH with guns. 6. Gravel pack and run completion. 7. Release rig. Estimated total days - 20 JUL 1987 Anchorage SR/57 ih 4712' 6541' 8411' ! '. o 0 15' 205.00 ' 1,882.66' 3,378'96' 4,590.43 ' 5' 454.45 ' 6,39'i .47' · _ --.- --6,65'2'83 ,10,521.97' -- '~ 10,556.81 ' 650' R~ pEl~llr. ;~,?'- 10,656.39' .10,6~59.56' le~-T' .10;6o5.56' leaS' i'~5-1o,?o3,/+o' ]~ _ 10~?07,00~ 10~10,80~ ~zo' ~5' ,, 10 ~726.?01 X.B. 154' G.L. 139' TUBING HANGER 6 JTS. 2~,' EUE 8rd TBG. OTIS REMO~ABL~ B~T.I. VALVE 53 JTS. 2%" EUE 8rd TBG. CAMCO MM MANDREL 47 JTS. 25," EUE 8rd TBO. ~ CAMCO PR4 MANDREL 38 JTS. 2~'a" EUE 8rd TBQ..; CAMCO I~4 MANDREL .' 2'/ JT~.2¥' E~ 8rd TI~. CAI~O l~i MANDREL 17 JT$ 2~" E~E 8rd TBG. CAMCO ~ MANDREL 12 ~s. 2~~ E~E 8~ TBS. CAMCO MM M~OBEL 8 JTS. 2¥ EUE 8rd ...... ,. CAMCO MM MANDREL .50' 189.50 ' 5.42' 1672.24, o 13.04' 1483,26' 13.12' · 1~9~,35' 13.02 ' 851.00' 13.05' 533.19' 13.08' 37?. 70 ' 13.13' 253.23 14.04 122 JTS. 2~" EUE 8rd TBS,L 3 1 19.1~7 · · OTIS XA SLEEVE. A~ask~ 0i~ ~ G~s ~s. commiss,o~ .. ~chomge 3.15' : =. sm BROWN 'HS-16-1 2%" x 7" 2c~ PACKER 2 JTS. 2%" EUE 8rd .TBG. I BLAST J~l~. OT~ XA BR~ }k~-~6-1 2¥ x 7" 29~ PAC~ OT~ "S" N~P~, Position ~3 2 B~ST JTS. ~P JT. 2~," E~ 8~ T~. 1 B~T ~. OT~ XA S~E~ · , .... ." STOP SUB ' ZE~k~. ~;S~E.M~'. 'F".PAC~ c~0 "~" .~m . TOP OF PLUG 10,797 6.00 t 63.20 ' 30.38' 3.17 6.00 t'~9 25.11 2.13 9.01 3.15 .45 3.80 .90 lira i ii i i iii S RU 23-33 CASING Ell TUBING DETAIL SECTION 755 1'. 8N.,gW. /ob?7-/o-~/ WELL PROFILE _co. Am' ARCO ALASKA, INC ..~SIN0 2~ 26 ST~T[ ALASKA CO,PLET I ON DETAI L I. Tubing, 3-1/2" 9~e N-BO ABM BTC (*/- /oc:x::) 2. GLM, 3- !/2" O-r~ 'L.~ w/ !- 1/2' ck valve, 3. ~Yct" Otis "X' nipple, 4. Locator tublng seal esseemblg, Baker model 'S-22, w/ additional seal units to allow for I0' of seal movemer 5. Gravel packer, 7" Baker SC1- L ( 70-32 ) 6. Gravel pack extention, Baker 80-32 with lower extention to accomodate 10' of seal movement. ._. "7. Safty joint, Baker model 'GP', 3-1/2' NU lOrd. 8. 3-1/2" 9.2~ N-80 NU lOrd blank pipe w/welde& blade centralizers for 7" 29~' csg. . · - 3-1/2" 9.2"' N-80 NU I ()rd .012 gage Bakerweld screen w/welded blade centralizers f/7' 29~ csg. I0. O-Ring seal sub' Baker, 3-I/2" NU lOrd 2.§" ID. i i I I 11. I0' - 3-1/2" telltale screen. 12. Baker model 'S' snap latcl3 including 2, 80-32 seal uni~5 13. Sump packer, Baker model 'D' ('84-32) ?"e /o~c~5'' ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAHS S ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. A,,S&URE THAT ACCUMULATOR PREB~,URE I& :5000 PSI WITH 1500 PS1 DOWNSTREAM OF THE REGULATOR. 3. OB,SERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT' IS 45 SECONDS CLOSING TIME AND 1200 P,SI REMAININI3 PRESSURE. , , , . 1. /i.3/~t ,, SURFACE CASINO 10. 2. '7" CASI NO HEAD l p, ,, _ 3000 PSI FLANGE 3 12"- 3000 PSI X 4?- 5000 PSI TUBING HEAD 12. '~, (~" - 5000 PSt X I 1" - 5000 PSI 1 CROSS-OVER SPOOL. 5. 11" - 5000 PSi BLIND RAMS 6. 11" - 5000 PSI PIPE RAMS ?. 11"- 5000 PSI ANNULAR BOP ST ACK TEST RE. CEIVEI) FILL BOP STACK AND MANIFOLD WITH BRINE. JUL 3 1 ]987 CHECK THAT ALL HOLD-DOWN ,SCREWS ARE FULLY RETRA(;TED.. . . PREDETERMINE DEPTH THAT TEST PLUe WlL~~ ~~t: uommiss,o,~ IN WELLHEAD. RUN IN LOCK-DOWN ,SCREWS IN HEAD'Ancn°T~ge- CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCRF. A,SE PRESSURE TO 5000 PSi AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWN,STREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES. IF ANY, WITH 5000 PS1 UPSTREAM OF VALVE AND WITH ZERO PSI DOWN,STREAM. BLEED ,SYSTEM TO ZERO PSI. OPEN PIPE RAMS. BACKOFF RUNNING,JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PS1 FOR 10 MINUTE& BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE ,SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI, TEST KELLY COCKS AND INSIDE BOP TO ,5000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SION AND SEND TO DRILLING SUPERVISOR. DM MARCH 9, 1987 . Form 10-403 ~ Submit"Intentions" in Triplicate x-~, ~!_i'COMM~. REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA 5. APl NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS : (DO not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT~' for such proposals.) A-028399 J ~ Fkl':: ...... ~ GAS ~ ~. IF INDIAN, ALLOTTEE OR TRIBE CEOL .... ~L WELL OTHER ~ J 2 ~Fnl ...... NAME OF OPERATOR 8. UNIT, FARMOR LEASE NAME ~/ ~ ~O~__ Chev~o~ ~.S,~. S~a~so~ ~ve~ : . ~ I S~TTEC ~DDRESS Or OPERATOR ~. WELL ~0. ~'j' STAT TEC- ~.0. Bo~ 7-83~, ~aho~ge~ A~ ~SZ0 ~U ~3-3~ ~-' or WEL mELD POOL, OR W,LDC Z~0' ~o~¢~ ~ Z~70~ ~ ~ ~. SEC.,T., R., ~., (BOTTO~ HOb~ ~O~h~eS~ co~e~ o~ ~ea¢&o~ E~EV~TIO~S(Showw~et~erD~, RT, GR, etc.) ]2. PER~IT ~O. .... 14. CheCk Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF-' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 1. Installed w±reline lubricator. . Ran 2-1/4" O.D. B~-wire 22.7 gram jet perforator with collar locator. Reperforated 7" casing with two 0.30 holes per foot 10720' - 10725'. Perforated 7" casing with four 0.30 holes per foot 10725' - 10730'. 3. Returned well to production. 16. I hereby certify that the for~olng is true an,~orrect SIGNED~~ DATE.. March 28, 1979 (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form P--3 / ~\ $1abrnit "Intentions" in Triiolioate ' ~ STATE OF A~KA ~..P~ N~ca co~E' OIL AND GAS CONSERVATION: COMMI~EE .... f ~ ~a..~ ' 6. ~E D~GNA~ON ~D SEmi SUNNY NOTICES AND REPORTS ~ W~ (Do ~ot use this fo~ for proposals ~ drill or lo deegen Use "~P~ICAT~ON'~o~ ~'~i'i~='' ~or suc~ 'p~o~osa~0 A-028399 j 5 ENG"~ ..... J'2 'GEOL 01, ~ ~,~ ~LL W~LL ~ OTHER 2. NAME OF OPE~TOR 8. UNIT, F~ O~ ~SE HAME S~a~da~d Oi~ Co~a~7 of ga~i~or~ia~ ~0~ S~a~o~ Rive~ .... J. REV , ....... 3. ADD~SS OF OPE~ATO~ 9. ~L HO. J ~. LOCATION OF W~L 10. F~ ~D P~L, O~ WI~CA ., ,... ~t,,r~ ~660' ~o~h and ~670' ~as~ ~rom Sou~h~es~ S~son River corne~ o~ Section 33~ T.8N.~ R.9~.~ SBa~ l~.S~c..~..a.,~..(Bo~o~o~ Sec. 33~ TS~ Rg~ 12 ELRVATION'~ IShaw wh~t.h~r DP. RT. GR. etc. 12. P~ ~O. 14. KB 154' Check Appropriate Box To I,ndJcat~ Nature of N~ti'ce, Re NOTICE OF INTENTION TO : I I TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT ~J MULTIPLE COMPI,ETE 8HOOT OR ACIDIZE --[ ABANDONs REPAIR ',','ELL CHANOE PLA~S tOther) tort, or Other D~a ' SUBSEQUENT RI[POETOF : WATER SHUT-OFF REPAIRING WI~ILL ~} FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* (Other> Install p~¢kers (NoTe.: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work, 1. Killed well with 71 pcf mud on August 9, 1972. 2. Removed tree and installed Class III:BOME. 3. Pulled and recovered tubing. 4. Set Baker "F" packer at 10,707. 5. Ran 2 7/8" tubing to 10,727 with Brown HS 16-1 packers at 10,660 and 10,557. 6. Removed BOPE. 7. Installed tree and pressured to 5000 psi. 8. Released rig at 8:00 p.m. on August 14, 1972. DIVISION Ot~ OIL AND GA,J TITLE District Superintendent DATE August; 28:1972 · (This space for State office use) APPROVED BY C0NDITION8 OF APPROVAL, IF ANY: TITLE DATE See I, nstructions On Reverse Side Form P- 7 SUBMIT IN DL CATE* STATE OF ALASKA (Se,,other ~,~- s~ ructions on reverse side~ OIL AND GAS CONSERVATION COmmITTEE i ii m i ii i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0F WELL: WELl. WELL DRY ~ Other b. TYPE OF COMPLE~ON: W ELL OVER EN BACK EESVR. , , ,. 2.NAME OF OPERATOR .. 3. ADDRESS OF OPERATOR 4.LOCATION OF wELL '-(-Report location c~early and in accordance with any State requirements)* At surface At top prod. Interval reported below At total depth 13. DATE SPUDDED .~14. DATE T.D,. RE~CHED ~I§.'.DATE' CO,tVLP SUSP O1{ ABAND. 18. TOTAL DEPTH, ~LD & TVD[ID. PLUG, BACK MD & TVD~0. IF iViULT~PLE COM, PL., 21. =. v~oouciNg :~TER~'^~(S), OF TInS OOMP~TIO~--TO,V, BOTTOM, ~AME (~m a~D W~,. '5.' API NI/M.C,H/CA'~ CODE 6. LEASE DESIGNATION A. ND ~EI~IAJ_, NO. 7. 1F INDIA.N, ALLOTTEE OR TRIBE NA1VIE 8. UNIT,FAR/V/ OR LEakSE NAME 9. WE~,L NO. 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PER~IT NO. i 16. ELEVAT~[ONS (DF, RKB, I{T, GR, El'C)* 117. ELEV. CASINGHEAD ! INTERVALS DRILLED BY CABI,E T001,S 23. WAS DIRECTIONAL SURVEY MADE 1 24. TY~PE ELECTRIC A. ND OTHEI% LOGS I:~UN · CA~SLNG SIZE WEIGHT, CASING RECORD (Report all strings set in well) . DEPTH SET (5/LD) HOLE SIZE CESILNTING RECO}LD PULLED 26. LINER i:LEC O~ 28. PEI~FORATiONS OP~-LNI TO PRODUCtiON (interval, size and number) ~" ~: TUBING BEC OPJD DEPTtt SE/' (MD) ~ PACIfiER SET (MD) 27. SCi-[EEN (MD) SIZE ACID, Si!OT, FilAC'I'0'RE, C~.',IEMT SQUE2'~..~, ETC, 1NTE~V.A.L (MD) .tkMOUN£ AND I-i!ND OF MA'I~2?',AL USED I V~ELL STATUS (Producing or :;,~ u k- in ) iWA'fER~BBL. 1 GAS-OIL It.kTIO 30. PRODUCTION DATE FIRST Pi%ODUCTION ' I ' pRODUCTION MEI.k[OD (Flowi~g, gas lifL pumping--size and type of pump) t TI~ST, Iq-OURS TESTED 'l '[PEOD'N FOR DATE 0t CI-1OXE SIZE OIL,---BBL. '~1. DISPOSITION Or GAS (Sold, used lor ]uel, vented, etc.) sa. ~s~ ol;' AT;~kC~MiSTS WATER--BBL. [OIL GRAVITY-A.PI (COlq~R,) 1 tTEgT WITNESSED BY 33. I hereby certify that the foregoing and attached information is complete and correct as determined from'all-available records SIGNED " TITLE DATE __~_~/'_._~,~ ~ *(See Instructions and Spaces [or Additional Data on Reverse Side) II INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end Io9 on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any at~achmer~Is. Items 20, and 22:: If this well is cornpleted for separatc- preduction from more than or~e ~terval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJuc~r~,9 interval, or ~tervc~ls, 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 interval to be seperately produceJ, show- ing the ad~ditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMA.H.¥ OF' F'ORMATION TESTS IN(.'LUI)IN(; INTEIZVAL TESTED. PI'tE.'CSURE DATA. A.N'D P, ECOVERIES OF OIL. GAS. WATER AND MUD 36. C~E DATA. A'I'I'ACI[ I~-I~I'Eg'" ~ES'~"II~S O.F,, E, ITI:IOLOG¥. laOI'i.O.,'~l~l~Y. FI'IA.CT70~ II'F_,,S. A.pI?'A'B2;'I'¢~. ~ AN12Y, t'~]~I~EC~I,~EI',)' $II()~S OF' {.)'IL,. GAS O;1R WA'I'ER~. 35, GEOLOGIC M AR Kl~q,~c~ NAM~ MEA$. Completion Report Swanson River Unit SRU 23-33 Se~. 33, T-·SN., R- 9 W.,...~Seward B& M Standard Oil Co, of Calif., W.O.I., Operator Page 2 Summary,· Cont. ,., PERFORATION RECORD: 2 - 3/8,, holes @ 10,644, 10,673, 10,679 & 10,723'. 4 - 1/2" holes/ft., the interval 10,$57' - 10,630'. 4 - 1/2" holes~ft., the interval 10'669' - 10,688'. 4 1/2" holes/ft., the interval 10,697 ' 10,701'. 4 - 1/2" holes/ft., the interval 10,720' - 10,725'. 1. Schlumberger I-ES Log, interval 2022 ' - 100 '. 2. Schlumberger Sonic Log, interval 2019' - 100'. 3. Schlumberger I-ES Log, interval 10895' - 2022'· 4. Schlumberger Sonic Log, interval 10892' - 2019'. 5. Schlumberger Continuous Dipmeter, interval 10895' - 9300'. 6. Schlumberger Microlog-Caliper, interval 10895 ' - 9800'. 7. Schlumberger Continuous Dipmeter, interval 9000' - 1756'. Schlumberger Neutron-Collar Log, interval 10790' - 9780'. 9. Schlumberger Cement Bond Log, interval 10774' - 2000'. 10. Schlumberger Casing Collar Log & Perf. Records, interval 10760' - 10500'. FORMATION TESTS: 1. Schlumberger Wire Line Formation Tests at: 10723', 10670', 10644' 10673' · , · 2.Halliburton Casing Test, interval 10720' - 10725'. Completion Report Swanson River Unit SRU 23-33 Sec, 33, T'_8 N., R.~9 W., Seward B &M Standard Oil C°. of Calif., W.O.I., ~erator Page Spudded at 12:00 Noon, May 8, 1961. Drilled 16~~'' hole: Drilled 16" hole: 0 - 220' 220' - 808' 808' Drilled 80 pcf. Mud 11 3/4" 47# 8R Equipped with Baker Shoe and Differential Float Collar. Drilled 16" hole: 808' - 2025' 1217 ' Drilled Attempted to Run I-ES Log. Stopped at 700'. Circulated and conditioned mud with open ended drill pipe. Ran I-ES Log, interval 2022' - 100'. Sonic Log, interval 2019 ' - 100 '. Reamed 15½" hole: 355' - 986' 631' Reamed May 10, .1961 Reamed 15½" hole: 986 ' - 2025' 1039 ' Reamed Ran 43 joints of 11 3/4" casing. Casing froze at 1756'. Cemented 11 3/4" casing at 1756' in single stage around shoe with 1200 sacks of cement treated with HR-4 using Halliburton power equipment, Used 1 top and 1 bottom rubber plug. Pumped 30 bbls. of water ahead, mixed 1200 sacks of cement in 35 m_ins, using Halliburton truck, displaced in 17 mins. usin~ rig pum~s. Average slurry weight 116~. Bumped plug with 1500 psi. Full circulation. Cement in place at 3:00 P.M. CASING DETAIL 43 Joints or 1759.66 Feet Above K.B. .... 3. O0 1756.66 Casing Landed @ 1756' Flanged up. Tested landing flange with 3000 psi. for 15 mins. OK. Tested C.S.O. with 1500 psi for 15 mins. OK. Tested pipe rams and hydrill with 2000 psi for 15 mins. OK Drilled 10 5/8'" hole: 2025' - 2531' 506 ' Drilled 80 pcf. Mud 80 pcf. Mud Completion Report Swanson River Unit SRU 23-33 Sec. 33, T. 8. N....~ R. ,9 W..~., ~Se~ard .~B~ .& M Standard Oil Co. of Calif., W.O.I., Operator Page 4 Drilled 10 5/8" hole: Drilled 9 7/8" hole: May !3 _- May 16, 1961 Drilled 9 7/8" hole: May 17~ 1961 2531' - 3336' 3336' - 4084' 805 ' Drilled 748 ' Drilled 4084' - 6877' 2793 ' Drilled 78 pcf Mud 75 pcf. Mud Changed over from Gel Mud to Gyp Mud and increased mud weight. Drilled 9 7/8" hole: 6877 ' - 7150 ' 273 ' Drilled 83 pcf. Mud M~ 18 - June 2~..~19.61 Drilled 9 7/8" hole: 7150' - 10895' June 3~ 196! Conditioned hole. Ran Schlumberger I-ES Log, interval 10895' - 2022' and Sonic Log, interval 10892' - 2019'. Circulated and conditioned mud for Dip- meter. Repaired engine compound. June 4, 1961 Ran Continuous Dipmeter, Run #1, interval 10895' - 9300'. Conditioned Mud. Ran Schlumberger Micro-Log, interval 10895 ' - 9800'. Ran Continuous Dipmeter, Run #2, interval 9000' - 1756'. June 5 - 6, 196~ Conditioned mud for 7" casing. Ran 263 joints 7" casing including Marker aud X-over, with Baker Differential shoe and Float Collar and Halliburton D.V. for a total of ll, O02'. Cemented 7" casing at 10895' in 2 stages with 2500 sacks of cement treated with 0.3% HR-4 using Halliburton power equipment. Used I top rubber plug. 1.st..Stage around shoe with 700 sacks of cement. Pumped 50 bbls. of water ahead, mixed 700 sacks of cement in 18 rains, using Halliburton truck, displaced in 43 rains, using rig pum~s. Average slurry weight ll6~. Bumped plug with 2000 psi. Full circulation. Completion Report Swanson River Unit SRU 23-33 Sec. 3.3.~ T. 8 N.., R. 9. W.,.Seward B & M ~t~ndard Oil Co. of Calif., W.O.I., Operator Page 5 June 5 - 6~. 1961~ Cont. 2nd Stage through DV at 7000'o Dropped DV bomb, opened DV ports in 30 mins. ~ed 50 bbls. of water ahead, mixed 1800 sacks of cement in 43 rains, using Halliburton truck, displaced in 30 rains, using rig pumps. Average slurry weight 116~. Closed DV ports with 3000 psi. Full circulation. Cement in place at 5:35 A.M., June 6, 1961. HOokloadweight of casing before cementing 225,O00~ after cementing before landing casing 218,000~ CASING DETAIL Top 2 Jts. 87.51 Ft. 7" 29# N. 80 B.T. Next 22 Jts. 938.20 Ft. 7" 26~ N. 80 B.T. " 87 Jts. 3692..87 Ft. 7" 23~ N. 80 B.T. " 43 Jts. 1829.42 Ft. 7" 26~ N. 80 B.T. " 10 Jts. 433..96 Ft. 7" 29# N. 80 B.T. 6981.96 Ft. ,, D.V. ~.. 8,60 Ft. 6990.56 " 34 Jts. 1427.31 ,, X-Over 6.60 " 50 Jts. 2095.02 7" 29# N. 80 B.T. 7" 29# P.110 7" 29# ?.110 L8R 10519.49 " Marker Joint 12.63 10532.12 Bottom 9 Jts. . ~369.. 76 7" 29# P.110 L8R Landing Joint Up 10901.88 - 6.88 Casing Landed At 10895. Marker Joint (Bottom) @ 10,525'. D.V. @ 6990.28'. Tested Head with 35OO~ psi. OK. 2 7/8" tubing.. Tested BOPE with 1500~ psi. OK. Picked up Completion Report Swanson River Unit SRU 23-33 Standard Oil Co. o£ Calif., W.O. I., Operator Page 6 J~une 7, 1961. Drilled out D.V. Collar and tested to 2500 psi. OK. Hit top of cement @ 10797'. Conditioned mud for Logs. Ran Schlumberger Neutron-Collar Log, interval 10790' - 9780'. Ran Cement Bond Log, interval 10774' - 2000'. Ran Schlumberger Wire Line Formation Test #1: 10,723' Recovered: 10,000 cc Water No Gas Rw = 0.9 Ohms/Meter @ 55° F. (Baroid) 1.21 Ohms/Meter @72° F. (Schlumberger) 1.20 Ohms/Meter @ 58° F. (S. O. Co. ) Rm = 1.49 Ohms/Meter @ 70° F. (Schlumberger) 1.75 Ohms/Meter @ 60° F. (S.O. Co.) Rmf = 0.6 Ohms/Meter @ 74° F. Pre ssures: ICIP- 5300; IF - 3800; FF - 4200; FCIP- 5150; FH - 680O PSIG Ran Schlumberger Wire Line Formation Test #2: 10,679' Gun Fired - ICIP #1200 PSIG. Pressure. Bled Down to + 500 PSIG. No additional pressure increase on flow or FCIP. FH 6300 PSIG. Test Inconclusive Ran Schlumberger Wire Line Formation Test #3: 10,644' Recovered: 9,800 cc Water 200 cc Oil 0.5 Cu. Ft. Gas Rw = 1.6 Ohms/Meter @ 61° F. (Baroid) 2.21 Ohms/Meter @ 70° F. (Schlumberger) 2.24 Ohms/Meter @ 62° F. (S.O. Co.) Pressures: ICIP- 5500; IF -4400; FF - 3600; FCIP- 5400; FH - 6800 PSIG Ran Schlumberger Wire Line Formation Test #4: 10,673' Test results same as Test #3 Results. Test Inconclusive. Completion Report Swanson River Unit SRU 23-33 Sec. 33, T. 8 N,, R. 9 W.~ Seward B & M ~tandard Oil cO"' 'of Calif.', W' 0~ i'., Sjrator Page 7 8, 196 Shot ~ - 1/2" holes/foot from 10720 ' 10725'. Ran Halliburton Casing Test on the interval 10720' - 10725'. Tool Assembly: 2 outside BT recorders, 4' of 2 7/8" perforated tail pipe, 7" type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorder, hydrospri~ tester, and dual closed in valve. Used 2745' of W.C. Ran on 10657', 2 7/8" EUE tubing. Set packer at 10685', with 17' of tail to 10702'. Opened tester at 7:50 P.M. for 10 min. flow period. Immediate faint blow, slightly increasing until closed in. Closed in tool at 8:00 P.M. for 30 min. ISI pressure. Opened tool to surface at 8:30 P.M. for 122 min. flow test. Immediate very faint blow lasting throughout fl°w period. Shut in tool at 10:32 P.M. for 59 min. FSI pressure. Pulled packer loose at 11:31 P.M. Recovered 465' net rise, all thin drilling fluid with scum of oil. Samples of Rise: (1) Top of 4th Stand (2) Single above tool (3) At Tool (4) Ditch (360') (30') ( 0') 1.12 @ 62° F. 360 ~g 1.0 @ 60° F. 395 g/g .52 @ 80° F. 540 g/g .58 @ 82° F. 490 g/g Pressure Data: (Final Pressures) Top inside Bottom inside IH ISI IF _ 6795 5154 1177-1305 6747 5126 1255-1298 EF FSI FH _ , . , 1279-1491 4925 6573 1277-1480 4895 6611 Top outside Bottom Outside 6823 5161 918-1279 6795 5163 884-1299 1248-1463 4923 6766 1661-1478 4921 6712 Pulled loose with 70,000#. Charts indicate tool open. Test Diagnostic. June 9, 1961 Ran Casing Collar Log & Perf. Record, interval 10760' - 10500'. Perforated through 7" casing for production with 4 - 1/2" holes per foot the intervals: 10701' - 10697 '; 10688 ' - 10669'; 10657 ' - 10630 '. Completion Report Swanson River Unit SRU 23-33 Sec. 33~ T.. 8 N,~ R. 9.W.~. Seward B.& M. Standard Oil Co. of Calif., W.O.I., Operator Page 8 June 9.,. 196.!~ ,C,ont.~., Installed X-Mas tree and tested with 3500~ psi. OK. Ran 2 7/8" tubing and landed @ 10681' with Venturi shoe on bottom. Commenced displacing mud with oil at 12:15 A.M. Pumped 50 bbls. of water ahead, followed by 420 bbls. of crude oil. Stopped circulating at 3:15 A.M. Formation oil to surface at 4:45 A.M. Flowed oil to sump until 3:40 A.M. Started flowing to trap at 4:45 A.M. Representative flow rate and cuts as follows: FLOW RATES BEAN TBG. CSG. TRAP FLG~ PERIOD OIL GAS SIZE PRESS. PRESS. PRESS. , ~,,. _ :: ~ ~ ~: ~ _ _ , ,,.~ · _ _ 1. 1/2 Hr. 1650 B/D 230 MCF/D 32/64" 325# 10~ 80# 2. 1/2 Hr. 1120 B/D 150 MCF/D 16/64" 800# 450~ 60~ 3. 1/2 Hr. 336 B/D 56 MCF/D 8/64" ll30# 875# 55# TOTAL CUT % WATER % EMULSION ~,,SAND & ,~gJD CORR. GRAVITY _ 1. 243 1.7 0.4 0.2 35-4 2. 1.6 1.1 0.6 0.1 36.1 3. 1.6 0.8 0.8 Trace 36.0 Shut well in at 9:00 A.M. Shut in pressures; Tbg. pressure 1350~ psi, Csg. pressure 1075~ psi. Produced estimated 200 bbls. formation oil. Flowed 260 bbls. to tank snd estimated 60 bbls. to sump. Installed cosasco plug. Rig released lO:O0 A.M., June 10, 1961. SRH: jm Completion Report Swanson River Unit SRU 23-33 Sec. 33, T. 8 N.~ R. 9 W.~ Seward B & M Standard Oil b0.-~0f caii-f,, w.o.I., Operator Page 9 Depbh 220 ' 1271 ' 2025 ' 4084' 6187' 7O83 ' 8124' DEVIATION DATA Degrees 1° O' 1° 0 ' 0° 45' 0° 15' 2° O' 2° 15' 1° 30' COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION SWANSON RIVER ~T 23-33 Section 33 T. 8 N., R. 9. W.~ Seward B & M STAE~ OIL COMPANY OF CALIFORNIA, %~ESTER~ OPERATIONS, INC. - Operator J~uary 29,,... .1963 Commenced rigging up at 10:00 AM. January 30~ !963 Conditioned Black Magic ~ud. Killed well, removed x-mas tree and installed BOPE. Pulled tubing loose and tagged bottom at 10,793' before pulling out of hole. january 31~ 1963_ Ran casing scraper, circulated and conditoned mud. Pulled scraper and ran Schlumberger perforating gun. February. 1, 1963 Reperforated with 4 - 1/2" Jet holes per foot 10630' - 10657' and 10,669' - 10,683'. Reran casing scraper. Reran a total of 334 joints 2 Y/8", 6.5#, N-80, EUE, 8R Rg 2 tubing equipped with packer and mandrels. TUBING DETAIL K.B. to landing head Donut One 2 7/8" pup Joint 44 Joints 2 7/8" tubing Camco MM Mandrel w/RDO (~l) 36 joints 2 7/8" tubing Camco IVIM Mandrel w/RDO 28 Joints 2 7/8" tubing Camco MM Mandrel w/RDO (~3) 21 Joints 2 7/8" tubing Camco MM Mandrel w/RDO (~'~) 15 joints 2 7/8" tubing Camco ~..~ Mandrel w/RDO (~) 11 Joints 2 7/8" tubing mco 8 Joints 2 7/8" tubing cm. o 15 joints 2 7/8" tubing Camco ~ Mandrel 23 Joints 2 7/8" Camco MM M~ndrel jolts 2 7/8" Camco MM Mandrel tubing ~/~ (~ tubing K.B. Depth 15.00' · 78' '15.78' 1.64' 17.42' 1388.65' 1406.07' 13.09' 1419.16' 1136.47' 2555.63' 13.10' 2568.73' 883.71' 3452.44' 13.09' 3465.53' 66e.76, 41e8.e9, 13.o6' 4141.35' 473.50' 4614.85' 13.02' 4627.87' 347.39' 4975.26' 14.06' 4989.32' ese. 31 5241.63, 13.15' 5254.78' 473.o5' 5727.83' 13.o8' 574o.91' 72~.1o' 6463.o1' 13.o~' 6476.05' 977.18' 7453.23' 13.10' 7466.33' COMPLETION REPORT - PACXER ~J~) GAS LIF~ INSTALLATION SWANSON RIVER Section 33 T' 8 N.~ R' ~9 S~~ OIL CO~' OF C~IFO~A, ~.~S~ o~TIONS~INC. - ~e~tor 48 Joints 2 7/8" tubing Camco ~ ~ndrel w/RD (~11) 48 Joints 2 7/8" tubing Camco Sleeve Valve 1 Joint 2 7/8" tubing Brown CC Safety joint One 2 7/8"~ pup joint Brown 2 7/8" X 7" NS-16-1 packer 2 joints 2 7/8" tubing · Camco "D" Nipple 3 Joints 2 7/8" tubing Venturi Shoe Tubing landed at 1514.72' 1~.05' 1516.69' 2.10' 31.46' 1.07' 10.07' 6.00' 63.26' · 92' 93.58' .67' 8~81.05' lO, 51o. 79' lO, 512.89' ].0,544.35' 10,545.~2' 10,561. ~9' 10,624.7.5' 10,625.67' 10,719.25' 10,719. ~' Removed BOPE, reinstalled x-mas tree and displaced mud with oil. February. 3, 196~ set packer at 10,555' and returned well to ~roduction. Rig released at 7:0OAM. S.R. HANSEN sat WELL RECORD INVENTORY Field: Locati on Swanson River unit TSN-RgW, sec..33, S.M. Ope~'ato~, & Well Name Standard 0il Co, _ _Unit ~#_23-33 .......... l. Drilling Pemit: 2, Survey Plat: No. Pa. ges 3, Monthly Reports (P-3): 4,. Completion Report (P-7): 5, Well History: 6. Other: 7, Mi s cel 1 aneous: Total Pages: 8. Deviation Survey(s): 9. Well Logs: (l) ~ (2) SL _(3) FT , (4) IEL (5) CD. (6) _(7) _(8) _(9) (lo) COMPLETION REPORT - NEW k~LL STANDARD OIL COMPANY OF CALIFORNIA - %~TERN OPERATIONS INC. - OPERATOR AREA: Kenai peninsula, Cook-Inlet Area, Alaska LAND OFFICE: Anchorage Lease No: 028399 Swanson River Unit PROPERTY: WELL NO: SRU 23-33 Sec. 33, T. 8 N., R. 9 W., Seward Base & Meridian LOCATION: SURFACE: 1660' north and 1670' east from southwest corner of Section 33, T. 8 N., R. 9 W., Seward Base & Meridian. ELEVAT ION: 154 ' K.B. DATE: September 26, 1961 BY: K.B. is 153 above ground. C. V. CHATTERTON, 'DiSt: Superintendent DRILLED BY DATE COMMENCED DRILLING: DATE COMPLECTED DRILLING: DATE OF INITIAL PRODUCTION: PRODUCTION: Coastal Drilling Company May 8, 1961 June 10, 1961 June 13, 1961 Daily Average ... 153 B/D .. ........... Water.... ........ 2 B/D aas .... ........ . 51 CF/D Flowing Gravity ..... . 36.1® TP ........... . 850 psi Bean 6/64" .el.el... TOTAL DEPTH: JUNK: None CAS ING: SUMMARY lO, 895 ' PLUGS: 10,797 ' - 10,895' 20" conductor pipe cemented at 28 '. 11 3/4" casing cemented at 1756', in one stage w/l150 sacks. 7" casing cemented at 10,895' in two stages w/2500 sacks, 700 sacks around shoe and 1800 sacks through D.V. @ 7,000'. COMPLETION REPORT - PACKER AND GAS LIFT INSTALIATION STANDARD OIL COMPANY OF CALIFORNIA, ~'~STERN OPERATIONS, INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: SWANSON RIVER '~NIT LA~ OFFICE: Anchorage LEASE NO.: A-028399 WELL NO.: SRU 23-33 Section 33 T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 1660' North and 1670' East from Southwest Corner of Section 33. ELEVATION: 154' K. DATE:. July l, 1963 Be BY: K.B. is 15' above ground. C.V. ~~~N, ~str~ct ~per~.nte~ent ' 11' 111 ' 1- ' ~",, illI 11 , ~ ' 1~, i 11 , - ' 11 ' , , ' CONTRACTOR: Santa Fe Drilling Company, Rig ~r35 DATE COMMENCED REMEDIAL WORK: January 29, 1963 DATE COMPLETED RF24EDIAL WORK: February 3, 1963 TOTAL DEPTH: 10,89~' CASING: 20" cemented at 28' 11 3/;4" cemented at 1756' 7" cemented at 10~895' P~t~s: lO,797' - lO,895' UNITED STATES GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS · ~ . / .p rat~ and ~roduet,o~ ~,o~ .... ~. 7~6~01 .... ,_ - .......... ~i~,~,~ _ -- ................................. .ffe'enF~ titl~ D~$2~e~ ho~s p~ foot lO~, . 1~6o, ~ ,~., al ~th ~ - ~' ~Itb pa~er a~d ~n~--,2 ..... =-, ~/9 tubl~ e~p~ed c~l ~d ~lnS~lled x-m~ t~e. S ~t paek~ ~eed ~ with Flle'~ - ~u D~v~sio. of I Mine$ and' /v~inm'ai~ Ai~ka Depl*[ o~ N, rural NoT~..--There were ..................................... rum or saJes of oil; ............. ................................. M cu. ft. of gas sold; ................................. , ........... runs or sales of gasoline dnming the month. (Write "no" where a ~ 1' NorE.~R~ort on th~ fo~ ~ requ~ for each calendar month, re,arieso ~t ,~ ...... I ~. l~ble.) duplicate wRh tho superviso~ by the 6th of t~ sacoe~ing month, u~ o~e~e dimet~ by the supervisor. * ~ ~- ~u a~aI, US Or operations, and musg bo filed in Fo~ 9-3~9 UNITED STATES DEPARTMENT OF THE INTER)OR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS T'~e followin.~ i.~ a correot report of operations anj pro,'luclfon (inchtdinj ~lrillin~' and prottzt, cin¢' · wells) for t~e ;~.ont!~ of ~ge~t's address 8~c. ANO 8N 9W OaAVIYT CU. FT. OF OaS GAL:4)N": OF , BAP. ItELS OS REMARKS (ln tho~$~,Is) (}A~OLINR XYAT~R (If (11 drilling, depth: If .~hut ~al&~ ~rk oo~need~Ja~~ 29, 1~3. ~Kllle& ~ell a~ pu~d ~ abl~, ~ casifig semper. Pre~lng 'uo ~e~o~e. CC >yste~ (2) ifc - J. B. Haka Perry Ritte ~ Sowar ~s No~n.--There were ........................................ rum or sales of oil; ........................................... M ou. f~. of gas sold; .- ................ runs or sales of gasoline during the month. (Write "no" where applicable.) ...NoTll.---Repor¢ on thi~ form is required for each calendar month, regardles~ of the status of operations, and must be filed in dulaliel{~o with tho supervisor by ~ho Gth of tho succeeding month, unions otherwLse directed by the supervisor. l~U 9'S29 P. O. BOX 7-839 · ANCHORAGE ° ALASKA PRODUCING DEPARTMENT TELEPHONE BR. 7--620! C. V. CHATTERTON DISTRICT SUPERINTENDENT October 3, 1961 Mr. D. D. Brmce State Dept. of Natural Resources 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for Swanson River Unit Well 23-33 (20), for your information and files. Very truly yours, C. V. CHATTERTON Enclosure UNITED-STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval exptrom 12-31-60. LESSEE'S MONTHLY REPORT OF OPERATIONS Th.e followin~ is a correct report of operations and production (includin~ drillin~ arid producir~ ~.~un for ~ ,~o,.~/~ o/ ............. ~_~ ........................ ~ :~.~_., _ ............ ~_~??~__~_Y_~.~...~ ........................... ~en~'s address' ......... P.._0_.__ BOx__7~_~39 ................................ CompaT~!/__~T~-~__~_ ~____._ __.~._.. ~....0~_.~_~~A P~one ......................... ~o~y__~2~ ............................. ~:e~' s ~i..~ ~_.. ~C AND ~ .... ~~ELL ~ ' i ~ i~ ~:U I~'~ OF ~AS ~: "'1' I SRU 23-33 (20). _ i ~ : 33 a hole o.h3 ' - Logs, from 10,8~ - 17~6~. ~ ~cro Log froa NE~ ana DiP'meter from I0,8~5' - 9300' ~d frc:a 9,000~i- 1756~ ~ a~ cemented ?" casing ~ 10~8~5~ in t~o stages~wi~h ?~ sacks ar~d Shoe ~d 18~ s~km ~rougt~ DV co11~ at 7000 . Inst~le~ ~. tested BOPB. Ole~out a~ te~ted DV co11~r. 0~. G~ RAy Neutron ~Log 10,790~ - 9780~. Rmn CBL 10~?74~ - 2000~, 10~6~ ~nd 10,673~o ~et perforated 4-~'q holes~f~ot, 10,720' - zoO?eS,~, HC~ ~O,f~O, - ~o,?e~,~ ~e ~. ~o. week blOWo Recovered n6t rise h6~;'. ~i~ drilli~ fluid w/,c~ o~ SAlinities qompare w/~d fi.~trate s~inities~ Jet perfo ated 7"{ casi~ ~th 4-~" hol~s/foot ov{,r inte~s 10,751~ - 10,6~7'~ te~ted X-~s tree-~w/350~ psi - 0]~. Displace mud ~/c~de oil. tbg. press~e, 45~ casing pressu]'e, 60~ ~ap pressureo ~o~1 cut 1~6~, 1.1% wa~er, 0.6% eElsi(~n, O.1% ~s~d and~Ed. Co~ 36.1°API Rig rel~sed 10~O0 ~, J~e iO, 1961e t gravity i t CC{ U.~.G.S - Mcr Ri¢~hfield Oil Ohio Oil Co. Union Oil Co Files: win H. Soyster { 2) CC - 9.D. Brucel , Corp° _ C. ~,,,:. ~erry ~ R.R. Ritter - George SowardS , - C.iE. Smith Produ.c ing Expl~,ratio,h Land Nor~.~There were ....................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or ~ales of gasoline during the month. (Write "no'! where applicable.) NoT~.~Report on this form is required for each calendar month, regardless of the status of operations, and mua~ 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) ~ 16--25760-8 U.s.c. OV~.Ss~;Sr PalNTIN(; Ol~rlC£ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Burem~ No. 42-1{3,56.5. Approval e~pires 12-31-60o L,,,.o o~-,c~ .... .Anchor~e ~ ~,,~ _.0_2839.~ ................. U~,T ...... ~~p~._~i~r. ............. LESSEE'S MONTHLY REPORT OF OPERATIONS State ...... A_lo..sk_a_ .................. Co~.n~y ~_e__n___ag__._P__en_Ln_~:~'_a__ ..... F~e~ ....... S_.w.~_o..n....R..iy.e..r__ ................................ 2'h,e followi~ is a correct report of operatio-~s an, d prod~etion (includin~ drillino~ and produ, ei,,~ wells)/or the men. th of ............. __]~__~ .................. 73_6_._!__, Swanson River Unit · -~-~ .............. ............. ,..__0.. _ro . ................ ., ............................................. ......... 33 I SRU_ 2)-33 ,(20) , , SpUdded St 12.00 N~on M~¥ 8, 1961. Drilled 16. hole 220' -{2025'. Ran induction, Elec,trical and Sonic Logs· R~amed hole',355' ~- 2055'~ 1] 3/4" Gasing frbze and cemented at i1756~i with 12OO sackS. Drilled 10 5/8" hole 202~' - 3336'. Drilled 9 7/8" hole 333~' - 10,435~. ~ cc:; UoS.G.S. - Me I "~.~__0 _& O.~ Richfield Oil · Soyster CorD. - C. W. P I R.R. R Ohio Oil Co. Geo~g~ Soward~ Union Oil Co. - C.|E. Smith Fil~s: ProduCing { Explo mtio~ Land ;try ltter NoTE.~There were ........................................ run. s or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "~,~," where al)l>licable.) NoTE.~I{eport on this form i~ required for each calendar' month, regardless of tho. si~:l us of operation::, and must bo filed in duplicate with the supervisor by the 6th of the succeeding month, artless otherwise directed by the supervi:q,~r. Form 9-3'29 (January lO50) 16-- 2.5766-8 u. $. GO¥~RNM~NT P~I'ITINa O~rlC£ PRODUCING DEPARTMENT TELEPHONE BR, 7--620I C. V. CHATI'ERTON DISTRICT SUPERINTENDENT P. O. BOX 7-839 ° ANCHORAGE · ALASKA Original signed C. V. CHATTERTON ZIP: SUNDRY NoTIcES AND REPORTS ON WT. LI~ DETAILS OF WOIW~ 3. ~.. 6. ~el~i .~1~ ~et lmrf~mte &t~t~Jl~ ~ ~i teat aa naees~. ama APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLI~G BACK APPLICATION.TO DRILL ~ DEEPEN [~ PLUG BACK NAME OF'COMPANY OR OPERATOR Address - : .... ' City "- DATE State Name of lease 'DESCRIPTION OF 'WELL AND LEASE '~Vell number Proposed depth: Number of acres in lease: Well location (give footage from section lines) Section--township--range or block & survey . Field~& res:e~oi~;~~(if ~wildcat,.~~so:st~te)~_ ~i ;'-~ ~::,; :-; ~? ~.- .- _ - J County , ~ ~ Distance, in miles, and direction from nearest town or post office Nearest fliatance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: ] Rotary or cable tools ]Approx. date work will sta,'i Number of wells on lease, including this well, completed in or drilling to this reservoir: ' If lease, purchased with one or more wells drilled, from whom purchased: Name Address i '" Status of bond Remarks: (If this is an application to deepen or plug :back, briefly describe work to be done, giving present producing zone and expected new producing zone) MAY 6 196'1 Oil ,?; Alaska Dept. of CERTIFICATE: I, the undersigned, state that I am the ~~~'_ of the (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: A. proval Date- Approved By:' ]//~ ~/V~&/~ ' Notice: Before se ,~g a~ ~formation requested. Much unneeessarx correspond- ence will thus be avoided. See Instruction on Reverse si~e of ~orm Original signed C. V. CHATTERTON Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 $.~ UAI~T SRo 23~33 S', (:, uWi7
