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Home My WebLink About190-144 WA STATE OF ALASKA 11) 7'l1 ld ALASKA L AND GAS CONSERVATION COMMISSI WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Q Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑., Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Aband.: 10/27/2010 ,, 190 -144 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, Alaska, 99519 11/16/1990 _ 50- 133 - 20256 -01— 0 L3 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1058 FSL, 1497 FEL, Sec5, T7N, R9W S.M. 1/71/91 • Soldotna CK Unit (SCU) 24A -05 Top of Productive Horizon: 8. KB (ft above MSL): 25.85 15. Field /Pool(s): N/A GL Ground (ft MSL): Swanson River Field Total Depth: 9. Plug Back Depth(MD +TVD): Hemlock Oil Pool 1107 FSL, 2308 FEL, Sec5, T7N, R9W S.M. Surface Tyonek Undefined Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 340,855 y- 2,457,088 Zone- 4 10,790'MD (10,761 'TVD) FEDA028996 [Soldotna Creek Unit] TPI: x- N/A y- N/A Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 340,510 y- 2,457,129 Zone- 4 N/A N/A 18. Directional Survey: Yes ✓ No 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: N/A N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. TOP BOTTOM TOP BOTTOM GRADE HOLE SIZE CEMENTING RECORD PULLED 18" 104 B Surface 91' Surface 90' Driven Driven 10 -3/4" 40.5 K -55 Surface 3,390' Surface 3,389' 15" 1263 sxs 7-5/8" 26.4, 29.7, N -80, Surface 7,090' Surface 7,077 9 -7/8" stage one 395 sxs, 33.7 P -110 stage two 359 sxs 5 -1/2" 20 N -80 6,722' 10,175' 10,148' 6 -1/2" 250 sxs 15.8 ppg cement 2 -7/8" 6.5 N -80 9,699' 10,790' 1 10,761' 4 -5/8" 17 bbl 15.7 ppg cement 24. Open to production or injection? Yes[:] Noa If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. C�� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6,622'- 7,723' 31 bbl 15.6 ppg cement 3,309- 3,500' 22 bbl 15.6 ppg cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Abandoned Well N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: N/A 24 Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate ---► 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 laboratory analytical results per 20 AAC 25.071. RBDMS NOV 19 20 11j 0 /./3 s�. i . � 6 Form 10-407 Revised 12/2009 ✓ Ld L � i CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested Y es es , No If list intervals and formations tested Y briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Current Schematic, Operations Summary, Directional Survey, Abandonment Pictures 32. 1 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: Drillig Manager Signature: Phone: 276 -7600 Date: 11/17/2010 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 1b: 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 W Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 24A -05 SOLDOTNA CK UNIT 24A -05 FEDA028996 5013320256 QA7582 164.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Abandon Well - Permanent Abandon 9/17/2010 10/5/2010 Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 24 -05 501332025600 1901440 , AM 'i. Operations Summary R/U pumping equipment. Pump down 7 -5/8" x 10 -3/4" annulus to establish injectivity. Pumped a total of 65 bbl of lease water injecting at 1,020 psi and 2 bpm. R/D pumping equipment. RU slickline, pressure tested lubricator 250psi low /4,500psi high. RIH w/ 2.0" GR & 1.75" brush, encountered paraffin, worked tools to 438'. SDFN. 9121/2010 00:00 - 9/22/2010 00:00 Operations Summary R/U Johnson tank to flow back well. Flowed back diesel cap, parraffin, and 68bbl water holding 1,100psi back pressure. RU slickline, pressure tested lubricator 250psi low /4,500psi high. RIH w/ 2.35" GR and tagged sliding sleeve at 7,580'RKB SLM. RIH w/ 2.0" GR and tagged top of TCP guns at 7,723'RKB SLM. RIH w/ 2.13" West tool and set in BXN profile nipple at 7,608'RKB SLM. Pressure tested tubing to 4,300psi for 30min, good test. RIH and unable to engage N -test tool due to sand, bailed same, latched and pulled N -test tool on third attempt. SDFN. 3010' X3/2 Operations Summary Perform injectivity test into formation. Pumped a total of 68 bbl of lease water injecting at 2,400 psi and 2 bpm. 912312010,06 - 912412010 00:00 Operations Summary RU wireline, pressure test lubricator 20psi low /3,000psi high. RIH w/ 2 -7/8" EZ Drill squeeze packer and unable to set same, problem with setting tool, POOH. RIH & set 2 -7/8" EZ Drill squeeze packer at 7580' RKB, Rig back wireline. Performed injection test w/ lease water into formation at 2,730psi and 2bpm. RU slickline, pressure test lubricator 250psi low /3,000psi high. RIH and open sliding sleeve at 7,571'. RD slickline. Established circulation through open sliding sleeve. Operations Summary RIH w/ wireline and set EZ Drill squeeze packer at 6,622' RKB WLM, good indication of firing setting tool, no indication of packer sheared, pulled out of weak point, POOH. Rigged up slickline and pressure test lubricator to 250psi low /3000 psi high. RIH, latched, and retrieved E -Line packer setting tool string at 6,622'. RD slickline. Notified AOGCC and BLM of upcoming cementing operations w/ tag and pressure test to follow. 9/26/20'10 00:00.9/2712010 00:00 M Operations Summary Established circulation through upper retainer & sliding sleeve into annulus at 2bpm and 400psi. RU cement pumping equipment. Pump 1 Obbl chemical wash followed by 31 bbl 15.6ppg EasyBlock cement, dropped top plug, and displace w/ lease water. Circulated cement down tubing into tubing x casing annulus and attempted to squeeze last 9bbl cement below lower retainer & packer. Reached max allowable surface casing pressure of 2,350psi after 3bbl cement squeezed below packer, circulated remaining 6bbl cement into tubing x casing annulus. Total displacement of cement with 39.5bbl lease water, did not see plug bump. Shut down pumps trapping 1,070psi on annulus and 1,290psi on tubing. RU slickline, pressure tested lubricator to 250psi low /2,500psi high. RIH w/ 2.0" GR and tag upper retainer /cement at 6,630' RKB SLM. Ran Pressure Temp. survey to 6,625'RKB SLM. P/T survey indicates top of cement in 2- 7/8 "x7 -5/8" annulus at 6,450'. Estimated 3.3bbi cement squeezed below packer at 7,586'. 9127/2010`00:00 - 9/28/2010 00:00 Operations Summary Bled off tubing and annulus pressure to Opsi for negative test. Performed charted pressure test of 2 7/8" tubing and 7 5/8 "x 2 7/8" annulus to 2000 psi for 30min, good tests. Tests witnessed by AOGCC Bob Noble. RU wireline. RIH w/ 2 -1/4" jet cutter, tie in, and cut 2 -7/8" tubing at 6,368'RKB SLM. RD wireline. Established circulation down tubing into annulus through tubing cut. End of pre -rig abandonment operations. ai m Operations Summary MIRU Key Energy #3 rig. Rig up surface equipment. ND tree, Begin NU of 13 -5/8" BOPE. Notified BLM & AOGCC of upcoming BOP test. 913012010 00:00 - 10/1/2010 00:00;' ''�° Operations Summary Test BOPE 250psi low /3,000psi high. AOGCC Lou Grimaldi witnessed test. Pulled hanger off seat and begin POOH with 2 -7/8" completion. 1013 190 0140.00 - 1012)2010 00:90 ' � Operations Summary Continued to POOH with 6,368'2-7/8" tubing.RIH with 7 -5/8" scraper assembly and tagged tubing at 6,369' RKB DPM. Displaced well to 12.5ppg mud, POOH with 7 -5/8" scraper assembly. 1 2010`0 6011* s „,s Operations Summary rta RIH and set Baker 7 -5/8" bridge plug at 6,332' on workstring. Mix and pump 10bb1 14.Oppg mud push, 10bbl 15.6ppg EasyBlock cement and 2.5bbi 14.0 ppg mud push for 225' balanced plug on top of BP, reverse circulate and POOH. RIH and set Baker bridge plug at 3,500'RKB on workstring, POOH. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 24A -05 SOLDOTNA CK UNIT 24A -05 FEDA028996 5013320256 OA7582 164.00 4*00 rb = r' It 10/3/201Q.,00:00- '0/410'10, Operations Summary RIH w/ 4 -5/8" 21 spf Big shot perf guns and perforate 7 -5/8" casing from 3,405'- 3,420', POOH. Perforate same interval twice. Well static. Circulate down 7 -5/8" casing, up 7 -5/8 "x10 -3/4" annulus w/ 12.5ppg mud, had 12.5ppg returns after 155bbl pumped (12bb1 over calculated annular volume). RIH and set 7 -5/8" retainer at 3,309' RKB, set 10k on retainer to verify set. Sting into retainer, mix and pump 25bbl Chemical wash, 25bbl 14.Oppg mud push, and 22bbl 15.6ppg EasyBlock cement below retainer. Unsting from retainer and lay 5bbl 15.6ppg cement (100') plug on top of BP, reverse circulate and POOH. Lou Grimaldi of AOGCC waived witness of the upcoming 10 -3/4" annulus pressure test. Calculated 13.2bb1 cement circulated into annulus, estimated TOC in 7 -5/8 "x10 -3/4" annulus at 3,175'. 101412010 00:00 - 10161,01 .00100 Operations Summary Wait on Cement. Performed charted pressure test of 10 -3/4" annulus and 7 -5/8" casing each to 750psi, for 30min, 0 pressure loss for both tests. RIH and set 7 -5/8" Cavins BP at 474' on slickline. RIH and punch casing from 463' -469', same interval twice (46 total shots). Circulate out 12.5ppg mud in 7 -5/8 "x10 -3/4" annulus with lease water. Mix and pump 1 Obb1 chemical wash, and 42bb1 15.8ppg Class G Neat cement, had 15.Oppg cement returns to surface. ND BOPE, NU dry hole tree. Begin rig down of Key Energy rig #3. 101'_1, Q.10 00:00 - 1011212010 00:00 h w Operations Summary Cleaning out cellar. Prep to excavate cellar. 1011212010 00:00.101112010.00:00 ..' Operations Summary Completed clean out of cellar. Prep to excavate cellar. 10/1612010 66 t 46147120 Operations Summary Dug out cellar & surface concrete around cellar before wellhead removal and abandonment. 1 l 2070 00:00 - 10123/2010 <00:00 Operations Summary Cut off wellhead with Wachs Guillotine saw 5.4' below average grade level. Cement level at surface in 7 -5/8 "x10 -3/4" annulus and +/ -6' down inside 7 -5/8" casing. 10/23/2010 00:00 10124120,1 00:00.r Operations Summary Notified the AOGCC to witness for cap installation. 1101241 Q Q00- 10/251201;000 „.00=r.';, "` Operations Summary No activity. 10t_2010 00.00 - 1012612010 00:00 Operations Summary AOGCC inspector Bob Noble witnessed cement level in casing, filled casing to surface w/ cement, and verified writing on abandonment cap is correct. Permission to weld on cap after cement cures. 1012612010 >00: =10'1 7f ;01!00 Operations Summary Installed abandonment plate. "1r2010r >0 `00,:10/2 1 8/201000:00 Operations Summary Backfilled cellar and finished demobe. O anson River ALASKA VL7tiL`1■� Well SCU 24A -05 U N O CAL 76 Abandonment C a s i n g & T u b i n RKB= 25.85 Size Type Wt Grade ID Top Btm Hole Cmt Cmt To 18" Conductor Surf 91' Yes Surf. 10 ?/" Surf Csg 40.5 K -55 10.050 Surf 3 15" 1263 sx Surf. * 7 -5/8" 26.4 6.969 Surf 34' 12.5 ppg 7 - /EP' 33.7 6.765 34' 117' 359 sx BL C Mud 7 -5/8" Prod Csg 26.4 N -80 6.969 117' 3945' 9 -7/8" Thm DV Q 7 -5/8" 29.7 6.875 3945' 5878' 7438• BL 7 -5 /E" 33.7 P -110 6.765 5878' 7027' 7 -5/8" Window. Cut on 11/14/90 7027' 7090' 5 -1/2" Liner 20 N -80 4.778 6722' 10,175' 6 -1/2" 250 sxs CBL CBL 12.5 ppg 2 -7/8" Liner 1 6.5 N -80 2.441" 9699' 10 790' 4 -7/8" 9740' Mud Tubin 2'/", Mod Butt 1 6.4 L -80 2.441 Surf 7649' } t I JEWELRY DETAIL Aq TUC in M a 2-7/8".7-5,8" NO. De th ID OD Item amuha eQ Via; ' • w • 6450' 474' 7 -518" Bridge Plug TOC = Surface 3,309' 7 -518" Cement Retainer Est. TOC = 3,209' g 3,500' 7 -5/8" Bridge Plu ` r 6,332' 7 -5/8" Bridge Plug Est. TOC = 6 6,368' Cut 2 -7/8" tubin C 6,622' 2 -7/8" Cement Retainer TOC = 6,622 D 7,580' 2 -7/8" Cement Retainer 1 6,574' TIW Liner Top Pkr. Stuck while RIH E A. 2,424' 2.367 Chemical Injection Mandrel B. 7,571' 2.313 Sidg Slve C. 7,586' Baker 450 -237 HS Ret Pkr +t D. 7,602' 2.25 BXN Profile Nipple, size 2.313" w/ 2.25" No Go F E. 7,649' Auto Release a ca F. 7,723' HES TCP Guns/top of cut tb GLM #6. 8,842' 1 2.347 1 4.5 GLM, 2 -7/8 ", BST, GLMAX, 1 ", BK -2 Latch F is GLM V. 9,613' 2.347 4.5 GLM, 2 -7/8 ", BST, GLMAX, 1 ", BK -2 Latch `s, r ►' ToC�ae,r 1. 9,651' Packer, Baker Mod. F - Size 40 - Cmt AT ®9B9 c � I �® 2 Brief Histor 10/9/73 Originally Drilbd and completed as a Hemlock Producer f 2 1:2/24/90 ReDrilled as a Hemlock Producer. Pressure tested liner la to 3100 psi. Negative test FAILED. ` 1 FISH Tbg Plug 10,677' roC X9740' Ll bb PERFORATION HISTORY Interval Accum. Date Zone TOP Btm Amt s f Comments SgzHoles 7626 7632 6 4 SgzPafs j 77-3 7630 7640 10 6 77 -3 Said Perfs/P &A 10/ 10 SgzHoles 7666 7672 6 4 SgzPafs 4 4 Mar-00 H -2 10,344' 10,354' IV 6 Poweget HC, 60 deg. /P&A 10/04 Mar-00 H -3 10,378' 10,388' 10' 6 jPowjet HC, 60 deg. /P&A 10/04 i Mar -00 H4 10,392' 10,445' 53' 6 Power et HC, 60 deg. /P&A 10/04 Apr -91 H-6 10,453' 10,465' 12' 4 P&A 10/04 I Apr -92 H-6 10,453' 10,465' 12' 4 Repeif /P&A 10/04 NW-00 H-8 10,476' 10,486 10' 6 Poweget HC, 60 deg. /P&A 10/04 Feb 91 H-8 10,486' 10,512' 26' 4 P&A 10/04 Mar 00 H-8 10,512' 10,554' 42' 6 Poweijet HC, 60 deg. /P&A 10/04 Jan-91 H9 10,566' 10,582' 16' 4 P&A 10/04 Mar -99 H -10 10,601' 10,640' 39' 4 2 -1/8" HC, 0 deg./P&A 10/04 TD= 10,790' PB'I D= -8,800 Deo-98 H -10 10 10 28' 1 4 2 -1/8" HC 0 de JP&A 10/04 Max Deviation =11.2° @ 6,900' SCU 24A -05 ABD Schematic 11- 16- 10.doc Revised: 11/16/10 CVK Report Name Well Date Created Position Log SCU 24A -05 6/2/2004 KB Surf X Surf Y Well Name CURRENT STATUS API (ft) (ft) (ft) SCU 24A -05 OIL 501332025601 154 340,855 2,457,088 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 154 0 0 340,855 2,457,088 0 0 100 99 55 0 0 340,855 2,457,088 0.5 312 200 199 -45 0 0 340,855 2,457,0881 0.4 311 300 299 -145 -1 1 340,854 2,457,089 0.5 303 400 399 -245 -2 1 340,853 2,457,089 0.5 299 500 499 -345 -3 2 340,852 2,457,090 0.6 304 600 599 -445 -3 2 340,852 2,457,090 0.5 303 700 699 -545 -4 3 340,851 2,457,091 0.4 311 800 799 -645 -5 3 340,850 2,457,091 0.5 299 900 899 -745 -5 4 340,850 12,457,092 0.5 291 1,000 999 -845 -6 4 340,849 12,457,092 0.3 294 1,100 1,099 -945 -6 4 340,849 2,457,092 0.2 335 1,200 1,199 -1,045 -6 5 340,849 2,457,093 0.2 2 1,300 1,299 -1,145 -6 5 340,849 2,457,093 0.3 16 1,400 1,399 -1,245 -6 5 340,849 2,457,093 0.2 331 1,500 1,499 -1,345 -6 6 340,849 2,457,094 0.2 7 1,600 1,599 -1,445 -6 6 340,849 2,457,094 0.2 25 1,700 1,699 -1,545 -6 7 340,849 2,457,095 0.3 324 1,800 1,799 -1,645 -6 7 340,849 2,457,095 0.2 21 1,900 1,899 -1,745 -6 7 340,849 2,457,095 0.3 19 2,000 1,999 -1,845 -6 8 340,849 12,457,096 0.3 7 2,100 2,099 -1,945 -6 8 340,849 2,457,096 0.2 25 2,200 2,199 -2,045 -6 9 340,849 2,457,097 0.2 66 2,300 2,299 -2,145 -5 9 340,850 2,457,097 0.3 28 2,400 2,399 -2,245 -5 9 340,850 2,457,097 0.2 25 2,500 2,499 -2,345 -5 10 340,850 12,457,098 0.2 59 2,600 2,599 -2,445 -5 10 340,850 2,457,098 0.3 36 2,700 2,699 -2,545 -5 10 340,850 2,457,098 0.2 2 2,800 2,799 -2,645 -5 10 340,850 2,457,098 0.1 273 2,900 2,899 -2,745 -5 10 340,850 2,457,098 0.1 44 3,000 2,999 -2,845 -5 11 340,850 2,457,099 0.2 335 3,100 3,099 -2,945 -5 11 340,850 2,457,099 0.1 349 3,200 3,199 -3,045 -5 11 340,850 2,457,099 0.3 59 3,300 3,299 -3,145 -4 12 340,851 2,457,1001 0.5 1 61 3,400 3,399 -3,245 -3 12 340,852 2,457,100 0.4 62 3,500 3,499 -3,345 -3 12 340,852 2,457,100 0.4 81 3,600 3,599 -3,445 -2 12 340,853 2,457,100 0.3 43 3,700 3,699 -3,545 -2 13 340,853 2,457,101 0.4 52 3,800 3,799 -3,645 -1 13 340,854 2,457,1011 0.4 37 3,900 3,899 3 74 5 -1 14 340,854 2 0.4 33 4,000 3,999 -3,845 0 15 340,855 2,457,103 0.5 48 4,100 4,099 -3,945 0 16 340,855 2,457,104 1 23 4,200 4,199 -4,045 1 17 340,856 12,457,105 1.1 38 4,300 4,299 -4,145 2 19 340,857 2,457,107 1.3 39 4,400 4,399 -4,245 3 21 340,858 2,457,109 1.4 41 4,500 4,499 -4,345 5 23 340,860 2,457,111 2 34 4,600 4,599 -4,445 7 26 340,862 2,457,114 2.1 38 4,700 4,699 -4,545 10 29 340,865 2,457,117 2.1 35 4,800 4,799 -4,645 12 32 340,867 12,457,120 2.2 33 4,900 4,899 -4,745 14 35 340,869 2,457,123 2.3 36 5,000 4,999 -4,845 16 39 340,871 2,457,127 2.3 27 5,100 5,099 -4,945 18 42 340,873 2,457,130 2.4 34 5,200 5,199 -5,045 21 46 340,876 2,457,134 2.6 34 5,300 5,299 -5,145 23 50 340,878 12,457,138 3 27 5,400 5,398 -5,244 26 55 340,881 12,457,143 3.3 33 5,500 5,498 -5,344 29 60 340,884 2,457,148 3.5 31 5,600 5,598 -5,444 33 65 340,888 2,457,153 4.1 28 5,700 5,698 -5,544 36 72 340,891 2,457,160 4.4 29 5,800 5,798 -5,644 40 79 340,895 2,457,167 4.5 24 5,900 5,897 -5,743 43 86 340,898 2,457,174 5.1 23 6,000 5,997 -5,843 47 94 340,902 2,457,182 5.2 29 6,100 6,096 -5,942 52 102 340,907 2,457,190 5.2 29 6,200 6,196 -6,042 57 110 340,912 2,457,198 5.3 30 6,300 6,295 -6,141 61 118 340,916 12,457,206 5.4 32 6,400 6,395 -6,241 66 126 340,921 2,457,214 5.5 21 6,450 6,445 -6,291 66 131 340,921 2,457,219 5.5 352 6,500 6,495 -6,341 65 135 340,920 2,457,223 5.2 323 6,550 6,544 -6,390 61 138 340,916 2,457,226 5.3 291 6,600 6,594 -6,440 56 139 340,911 2,457,227 6.5 275 6,650 6,644 -6,490 50 139 340,905 2,457,227 7.5 264 6,700 6,693 -6,539 43 139 340,898 2,457,227 8.4 266 6,800 6,792 -6,638 27 139 340,882 2,457,227 10.1 272 6,900 6,890 -6,736 9 140 340,864 12,457,228 11.2 275 7,000 6,988 -6,834 -9 140 340,846 2,457,228 10.2 260 7,050 7,038 -6,884 -17 138 340,838 2,457,226 9 262 7,100 7,087 -6,933 -25 137 340,830 2,457,225 8.2 262 7,200 7,187 -7,033 -36 136 340,819 2,457,224 5.2 262 7,300 7,286 -7,132 -45 135 340,810 12,457,223 5.3 1 260 7,400 7,386 -7,232 -54 133 340,801 2,457,221 5.2 258 7,500 7,485 -7,331 -63 132 340,792 1 2,457,220 5 263 7,600 7,585 -7,431 -71 131 340,784 2,457,219 5 273 7,700 7,684 -7,530 -81 131 340,774 2,457,219 5.5 268 7,800 7,784 -7,630 -90 130 340,765 12,457,218 6 252 7,900 7,883 -7,729 -100 126 340,755 2,457,214 5.5 243 8,000 7,983 -7,829 -109 122 340,746 2,457,210 6.1 246 8,100 8,082 -7,928 -118 118 340,737 2,457,206 5.3 241 8,200 8,182 -8,028 -126 114 340,729 2,457,2021 5.5 248 8,300 8,282 -8,128 -135 111 340,720 2,457,199 5.5 255 8,400 8,381 -8,227 -145 108 340,710 2,457,196 5.3 255 8,500 8,481 -8,327 -153 106 340,702 2,457,194 5.1 258 8,600 8,580 -8,426 -162 102 340,693 2,457,1901 6.1 221 8,700 8,680 -8,526 -169 94 340,686 2,457,182 6.2 228 8,800 8,779 -8,625 -177 87 340,678 2,457,175 6.2 230 8,900 8,879 -8,725 -186 81 340,669 2,457,169 5.5 239 9,000 8,978 -8,824 -193 77 340,662 2,457,165 4.5 241 9,100 9,078 -8,924 -200 74 340,655 2,457,162 4 255 9,200 9,178 -9,024 -207 73 340,648 2,457,1611 4.3 267 9,300 9,277 -9,123 -216 73 340,639 2,457,161 5.4 267 9,400 9,377 -9,223 -226 71 340,629 2,457,159 6.3 254 9,500 9,476 -9,322 -236 67 340,619 2,457,155 6.4 243 9,600 9,576 -9,422 -246 63 340,609 2,457,151 6.2 248 9,700 9,675 -9,521 -256 59 340,599 2,457,1471 5.6 244 9,800 9,775 -9,621 -264 55 340,591 2,457,1431 5.4 243 9,900 9,874 -9,720 -272 50 340,583 2,457,138 5.3 239 10,000 9,974 -9,820 -280 46 340,575 2,457,134 5.2 242 10,100 10,073 -9,919 -288 42 340,567 2,457,130 5 246 10,200 10,173 - 10,019 -296 39 340,559 2,457,127 4.5 246 10,300 10,273 - 10,119 -303 36 340,552 2,457,124 4.2 248 10,400 10,372 - 10,218 -310 36 340,545 2,457,124 4 286 10,500 10,472 - 10,318 -318 37 340,537 2,457,125 5.6 270 10,600 10,572 - 10,418 1 -3281 38 340,527 2,457,126 5.4 280 10,833 10,804 - 10,650 1 -349 1 42 340,506 2,457,130 5.4 280 10,883 10,853 - 10,699 1 -3541 43 340,501 12,457,1311 5.4 280 m C l . �• ` *- `� ti ' � t S , i l � I' y i b r s � 1 I i Jr I S i , *t tvbf t , q "aq? p ¢ 4 a 4 � 4 3 s } y Y � a7! ° r y f . � m }y v MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l6�Zr��g DATE: 10/25/2010 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector Union Oil Co. of California SCU 24A -05 PTD 190 -144 October 25, 2010: 1 traveled to Union's Swanson River Field and met with Rep Clint Chanley to inspect the surface abandonment of SCU 24A -05. Clint had called earlier in the day telling me that the cement in the 7 5/8" was 5 feet down. I told him to top it off with cement and I would come out. Upon arrival I found the 7 5/8" cement was gelling nicely and all other strings to have good hard cement in them. The well had been cut 5+ feet below ✓ the grade line. The 3/8" thick marker plate was found to be the right size and had the correct AOGCC and BLM markings on it. It also had a' /4" hole drilled in it (as per BLM requirements). I instructed Clint to make sure the cement in the 7 5/8" got good and hard, take pictures of it and then they he could cover the well up. I also made sure Clint understood the mounding process. Attachments: photos (2) k#jJWX NOV 1 8 ZUk SCU 24A -05 Surface Abandonment 10 -25 -10 noble SCU 24A -05 (Union) Surface P &A PTD 190 -144 Photos by AOGCC Inspector B. Noble 10/25/2010 a � a Casing cut -off; w cement to surface; SCU 24A -05 s Marker Plate for SCU 24A -05 SCU 24A -05 Surface Abandonment 10 -25 -10 noble • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �17,j l ij i l DATE: 9/27/10 P. 1. Supervisor FROM: Bob Noble SUBJECT: Abandonment Plug Petroleum Inspector Union Oil Company of California SCU 24A -05 PTD 190 -144 September 27 2010; 1 traveled to Union Oil's SCU 24A -05 and met with Union Oil's Rep. Mr. Joe Dalebout. I was there to witness a pressure test on the tubing and the IA to 2000 psi. Joe informed me that they had opened a sliding sleeve and pumped 31 barrels of Schlumberger's 15.6 ppg Easy Block cement. Joe told me that TOC in the 2 7/8" tubing was 6630' determined by wireline. He also told me TOC in the 7 5/8" casing was 6450' determined with a temperature survey. Then 7/8" tubing was pressured up to 2000 psi. with 0 pressure loss in 30 min. It was then bled to 0 psi. Then the 7 5/8 "casing was pressured up to 2000 psi. with 0 pressure loss in 30 min. It was then bled to 0 psi. NC aj 1 8 Z IL'r Attachments: none Non - Confidential SCU 24A -05 P &A 9 -27 -10 noble ) ..." '~ Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263~ 7828 E-mail: oudeand@unocal.com 1ft;, 0 - 01- « 19()-~'~è Q~c)-- ~ UNOCAL. Debra Oudean G & G Technician Date: March 10, 2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SCANNED ~JUN 1 ''I' 20D5 ~1.dIl-SCU " " " ' ',' '. ,: , lOG INTERVAL B· , ,WELL, VEND~R, ", LOG TYPE SCALE DATE LOGGED LINE FILM CD NOTES J 'scu ;ÚA-OS" .. Schl~mbergedsL¡MëiMENi'MÞiTOOL .'''' '.." , ,.. '--"'.~ '''---''15 iNCH r"'12t7Î20Ö:¡ ,i30Ö~7-7ÖÔ-T--'1~ ---"'1T·-1'~"·--'-'·! ,j ]SCÜ24¡ÕS- r&;hlu~b~rge;IGAMMÃ RAY LÔGTO-SPOT-TëP-Gur~is -.----- T51ÚCHÎ 12/12/2õ-å:ij23öõ:75IO i11" 1 ¡ 11 .., " j jscu 312-09· SChlu';'berger ~~;LEilON RECORD II IF LA 1ABLE BRIDG E 15 II JC H 111117/200417300-7400 -, 11 1 ¡ 0 I NO CD .I ¡S¿Uà1-2~Ò9- -lsc¡'ïu~b;g~'~lCOMPLETiÓN RE-éoRD2 HSDPowËFÚET 6'SPF.Î5INCH 02no/200<1ll3ì90.ìVÄ I -11 11 , r - --, , ' ,f'f"\F'""'\r-'-"f""'I-r-r'!I'''''''''''--' RE: seu 24A-05, 10-407 dated 2/18/05 ) p1D /9¿l"1f~¢"O Su.þjéct:·..Í{Ê¡·..·.Sê1.1.Z4A.-05, 1.0-407·datecl.gl1·$/05 . E~()ni:"]JUt1h(t1!1'. Diat}e E" <dµn~al1}~~4ho¢ätcº111¿> ;~~~i~¡¡~iti;r¡m~~~.~~J~~¡i1~¡!~¡!¡!¡Ji¡..···· Bob- Please note that the 10-407 filed on 2/18/05 lists well SCU 24A-05 as an oil well. The well was actually recompleted as Tyonek gas and should be noted as such. Thanks Diane ~~ 1.;J/17~~ [&r"Ó) , F'~ I~ ()S--(~ t()-L/.07 p~J~, - I I , . ~_E\DJ JAM 2 $ 2.DDô 1 of 1 1/23/2006 9:34 AM 1(') ~~. 00".. (" STATE OF ALASKA I' ¡~ '\ t: ° t:,~ ALASKJ jL AND GAS CONSERVATION COMMIs( )N r- WELL COMPLETION OR RECOMPLETION REPORT AN6Efèê 2005 ~ ! - . . .... Oil0 GasD Plugged 0 Abandoned0 SuspendedD WAGD 1b. Well-011:ìSs:' (, '. ~\!¡: rr:n.. .,' 20AAC 25.105 20AAC 25.110 Development 0 " I' ¡~xp!~!atory 0 No. of Completions 0 Other Recomplete Service 0 Strätigrapnierest 0 5. Date Comp., Susp., or 12. Permit to Drill Num~jr: . ?J . ~ ./ Aband.: 12/17/04 90-144 c..";¡;;J't -~'Ø "",...., 6. Date Spudded: 13. API Number: n/a 50-133-20256-01 7. Date TD Reached: 14. Well Name and Number: n/a 24A-05 8. KB Elevation (ft): 15. Field/Pool(s): 25.85' Swanson River Field 9. Plug Back Depth(MD+ TVD): Tyonek 8,800'/8,779' 10. Total Depth (MD + TVD): 16. Property Designation: 10,790'/10,761' Soldotna Creek Unit 11. Depth Where SSSV Set: 17. Land Use Permit: n/a 19. Water Depth, if Offshore: 20. Thickness of Permafrost: n/a feet MSL n/a 1 a. Well Status: GINJD WINJD WDSPLD 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 4a. Location of Well (Governmental Section): Surface: 1058ISL, 1497 FiL, S5, T7N, R9W Top of Productive Horizon: þW Total Depth: 1107 ffi-, 2308 F&, S5, T7N, R9W ~ 4b. Location of Well (State Base Plane Coordinates): Surface: X = 340,855, Y = 2,457,088 TP/: X = 340,781, Y = 2,457,219 Total Depth: X = 340,510, Y = 2,457,129 18. Directional Survey: Yes 0 No 0 21. Logs Run: GR/CCL 22. CASING WI. PER GRADE FI. 18" 10-3/4" 40.5 K-55 7 -5/8" 26.4 N-80 5-1/2" 20 N-80 2-7/8" 6.5 N-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE o 91' 0 90' o 3,390' 0 3,389' o 7,090' 0 7,077' 6,722' 10,175' 6,715' 10,148 9,699' 10,790' 9,674 10,761 2ß. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): pe(,~ember 17,2004 Flowing DatE:~ of Test: Hours Tested: Production for Oil-Bbl: 12/1-l/2004 Test Period ..... Flow Tubing Casing Press: Calculated Oil-Bbl: Press. 24-Hour Rate -. -;¡:¡:-- CORE DATA Brief deÚcription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): Perforation too numerous to list in space provided. Refer to schematic attached for perforation detail. Form 1 0-407 Revised 12/2003 CEMENTING RECORD AMOUNT PULLED 15" 9-7/8" 6-1/2" 4-7/8" See Schematic for Cement Detail 24. TUBING RECORD DEPTH SET (MD) 7,649' PACKER SET (MD) 9,651'; 7,586'; SIZE 2-7/8" 25. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Gas-MCF: Water-Bbl: Produced Water Water-Bbr: Choke Size: Gas-Oil Ratio: Gas-MCF: Oil Gravity - API (carr): none SCANNED JUL 2 5 2005 I \~ \.t. ORIGINAL RBDMS BFl FEB 2 4 2005 CONTINUED ON REVERSE NAME GEOLOGIC MARKE~ TVD 29. " FORMATION TESTS Include and briefly sJ. drize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". ,28. 77-3 HKT H1T H4 TD 7,626' 10,254 10/256 10,449 10,833 7,611' 10,227 10/229 10/421 10,804 none 30. List of Attachments: Daily summary of operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: Neil MaQee Title: . Signature: ,-(). ~eF Phone: 907-276-7600 Date: ~ II f5 j ;1òo5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~r Swanson River Well SCD 24A-05 As Completed on 12/17/04 UNOCALe Casing Grade ID & Tub Top Surf n 9 Btm 91' RKB =25.85' Size 18" Hole Cmt Cmt Top Yes Surf. 15" 1263 sx 1450' Calculated 359 sx 6130' 9-7/8" Thru DV @ CBL 743R' 6-1/2" 250 sxs 8800' CBL 4-7/8" 9740' Type Conductor Wt 1- - ~1 ~)' , u o I- - -b. Surf Csg I o-:y. " 40.5 K-55 10.050 Surf 3,390' 6.875 Surf 34' N-80 6.765 34' I] 7' 6.875 I] 7' 3945' 6.875 3945' 5878' P-IIO 6.765 5878' 7027' 7027' 7090' N-80 4.778 6722' 10,175' N-80 2.441" 9699' 10,790' N-SO 2.441 Surf 7649' 7-5/8" ~ 7-5/8" 33.7 7-5/8" Prod Csg 26.4 7-5/8" 29.7 7-5/8" 33.7 7-5/8" Window. Cut on 11/14/90 ~ A 5-1/2" Liner 20 2-7/8" Liner 6.5 Tubin~ 2 VI", Mod Butt 6.4 ê . I I JEWELRY DETAIL OD Item Tubing Hanger, Shaffer, 3-1/2" EVE 8rd Mod. Lift Thread x 3-1/2" EVE 8rd Mod. Suspension Threads, Type "H" BPV Profile 4.5 GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch Packer, Baker Mod. F-I, Size 40-30 Crossover, 4' 10 rd Box x 2-7/8" EVE 8rd Pin X Nipple, (2.313" 1.0.) Baker Overshot X Nipple, (2.313" 1.0.) => .... ~~ g :~~~: I- ~),' ~~(~ ~~~~ :~~f~ ,~~~, . :~~~ :,), . Roe @ ,,~. 7200' eRr: t"'~ NO. Depth 25.85' GLI\1 #6. 8,842' GLM #7. 9,613' 1. 9,651' 2. 9,659' 9,691' 3. 9,698' 4. 10,463' I 6574' A. 2424' B. 7571' C. 7586' D. 7602' E. 7649' F. -8800' ID 2.347 2.347 C 2.441 2.313 2.45 2.313 E~ TIW Liner top pkr. Stuck while RIH. Chemicallnjedion Mandrel Sldg Slve Baker 450-237 HS Ret Pkr BXN Profile Nipple, size 2.313" w/ 2.25" No Go Auto Release HES TCP Guns/top of cut tbg ,~,~ 2.313 2.25 TOC@.88U· Cm! RT @ 9635' Brief History 10/9/73 Originally Drilled and completed as a Hemlock Producer 12/24/90 ReDrilled as a Hemlock Producer. Pressure tested liner lap to 3100 psi. Negative test FAILED. FISH Tbg Plug @ 10,677' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments Sqz Holes 7,626' 7,632' 6' 4 Sqz Perfs 77-3 7,630' 7,640' 10' 6 77-3 Sand Perfs Sqz Holes 7,666' 7,672' 6' 4 Sqz Perfs Mar-DO H-2 10,344' 10,354' 10' 6 Poweljet HC, 60 deg.lP&A 10/04 Mar-DO H-3 10,378' 10,388' 10' 6 Poweljet HC, 60 deg.lP&A 10/04 Mar-DO H-4 10,392' 10,445' 53' 6 Poweljet HC, 60 deg.lP&A 10/04 Apr-91 H-6 10,453' 10,465' 12' 4 P&A 10/04 Apr-92 H-6 10,453' 10,465' 12' 4 Reperf/ P&A 10/04 Mar-DO H-8 10,476' 10,486' 10' 6 Poweljet HC, 60 deg.lP&A 10/04 Feb-91 H-8 10,486' 10,512' 26' 4 P&A 10/04 TD= 10,790' PBTD= -8,800 Mar-DO H-8 10,512' 10,554' 42' 6 Poweljet HC, 60 deg.lP&A 10/04 Max Deviation = 11.20 @6,900' Jan-91 H-9 10,566' 10,582' 16' 4 P&A 10/04 Mar-99 H-I0 10,601' 10,640' 39' 4 2-1/8" HC, 0 deg.lP&A 10/04 Dec-98 H-I0 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg.lP&A 10/04 . SeD 24A-05 Schematic 121704 REVISED: 6/3/2004 by SL T 12/17/04 by CRW 10/14/04 ( ( PJSM, RU Pollard slickline and pressure test to 3000 psi. RIH with 2.81" GR to 440', Tools slowed down and stopped at 460' (KB), Very sticky. Pumped diesel and worked tools down to 520' (KB). POOH and tool string was packed with paraffin. Waited on Hot oil truck to mobe and load oil. Started pumping oil and after 5 bbls, RIH with 2.81 GR down to 525'. Cut paraffin while pumping hot oil down to 2300' KB where tools fell free. Went down to 6497 KB. POOH. RIH with 2. 31 GR to 9789' KB. Started out of hole and tools hung up at 9645' KB. Worked tools loose and POOH. RIH with 2 1/2" Daniels KOT with 1-1/4" PT to 8827' KB. Pulled valve and POOH. Secured well. 1 0/15/04 PJSM, pressure test Pollard lubricator to 3000 psi. RIH w/1 1/4" Daniels pulling tool and pulled GLV at 9613'. POOH (#7); RIH w/1 1/4" Daniels pulling tool and pulled GLV at 7825' POOH (#5); RIH with 1 1/4" Daniels pulling tool and pulled GLV at 6691'. (drawing had GLV at 6499" it was a typo) POOH (#4); RIH w/2" JDC pulling tool and pulled GLV at 5416'. POOH (#3); RIH w/2" JDC pulling tool and pulled GLV at 3989'. POOH (#2); RIH w/2" JDC pulling tool and pulled GLV at 2375'. POOH (#1) RIH with 1 1/2" dummy valve and set it in GLM #2 at 3989'. POOH Rig lub back and secured well. 10/16/04 PJSM, RU, pump 2 Bbls Diesel. RIH with Dummy Gas Lift Valve on 3" Daniels and set at GLM # 3 at 5408' RKB; RIH with Dummy Gas Lift Valve on 3. 5" OM1 and set at GLM # 1 at 2348' RKB; RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 4 at 6675' RKB; RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 5 at 7790' RKB; RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 6 at 8801' RKB. RIH with same to GLM # 7 at 9579' RKB and could not get set; RIH with same to GLM # 7 at 9579' RKB and could not get set 2nd time. RIH with same to GLM # 7 and set valve at 9579' RKB. RD Pollard. 10/20/04 Void tested to 5, OOOpsi. Pack off tested to 3, OOOpsi. All good test RU hardline and pump truck to MIT and perform injectivity test Circulate fluid through lines and pressure test to 4500 psi. Start 1, 060 psi. tubing pressure. 1, 000 psi. 7 5/8 x tubing pressure 90psi. 7 5/8 x 10 3/4 psi. Started pumping down annulus. No press increase on annulus tubing. Press increased. Confirmed communication with tubing. Try to fluid pack well annulus on vac, Oil and gas returns, RU to pump down tubing. for injectivity test Tubing. went on vac. RD pump truck and choke skid, hard line. RU pollard wireline. Press test lubricator, good test 1500 psi. RIH With 2 1/2" Daniels KOT with 1" Impression block set down @ 6699' - POOH Impression of Valve. RIH With 2 1/2" Daniels KOT with 1"; Impression block set down @ 9603' POOH Impression of empty pocket RIH With 2. 31 G. R. TO 9, 684' POOH. RD and stage equipment back @ P&S yard. RU Coil. 10/21/04 Operation Suspended. PJSM spot equipment and set up BOPE. E-line spot equipment RU. Test lubricator to 1,500psi. (Coil tubing crew continuing RU). RIH with 2 7/8" EZSV log mandrels on the way in hole, log tubing anchor and GLM #7, set EZSV at 9635', POH RD E-line. (Coil tubing RU). RU Coil tubing. 10/22/04 RU and Test BOPE Equipment With State Man. Review Coil Tubing. Check list TIH With Coil Tubing. 250psi tubing. Press, 250psi. Annulus Press. Pump. 25 bbls per min. Check every 1, 000'. Check Wt @ 9, 500' Check Tubing, For press 0 psi. Check Annulus 0 psi. Tag Retainer @ 9, 626' KB set 3, 000 psi. Down weight test seals - Pumped 50 bbls down back side showed 50 psi. Increase at well head. Tubing. No press or flow. Unstung from retainer Annulus went on vac. Wait till well went to neutral. Sting back into retainer put 3,000 # on retainer. Injectivity test, 1 bpm 1,050 psi. Pumped 10bbls Shut down press went to 0 psi. 1050 psi friction press. Pumped 5bbls more Check for vac. No vac. or press. Pump cement detail. 5bbls water-25bbls 15. 8 Cement -5bbls water - 24 bbls lease water. Pumped 15bbls below retainer pulled up. Laid in 10 bbls cement above retainer. Over Displaced 5 bbls. SD/POOH, End of job, Tubing. and Annulus 7 518 x Tubing. were not on vac. Shut master Circ. 2 coil volume to Johnson tank Blow coil down W with N2. RD Coil Tubing. Move off to build up pad for Rig. Shut down Operations 12hrs wait on Cement CMT in Place @ 18:43hrs. SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 1. ( 10/23/04 RU Pollard, test lubricator, Ran 1.9 GR Tagged @ 8, 034' wlm - kb 8, 050' RD. 10/24/04 Operations Suspended. PJSM, RU on tubing and annulus. Test to 4500 psi. Started pumping down tubing. Pumped 23 bbls press up to 2,300psi. Hold 5 min no loss. Hold Press on tubing. While pumping on annulus 7 5/8 x tubing. Pumped 96 bbls. Press up to 1500 psi. Bleed back, to 500 psi. Press up to 4200 psi. 30min. Tubing press 2600 psi. Annulus press. 4, 200 psi for 30 min. loss 80 psi. Bleed down annulus and tubing. RD secure well. 10/27/04 NU BOP had problems getting connections on either side of single gate tight due to studs being somewhat long and finding wrench that would fit Change rams in both the single gate and top double gate to 3.5" NU choke and kill line valves along with HCR. Function test using both remote and koomey, Test Annular BOP 250 PSI low and 3500 PSI high had leak on high side found collar connection in center of annular. Pulled test joint and reconfigured. Pressured up to 250 PSI low and 3500 PSI high held good. Continue BOP test at 250 PSI low and 5000 PSI high, next test found several different flange leaks chased same. 10/28/04 Test floor and IBOP valves using blind ported sub to 250 PSI low and 5000 PSI high. Perform draw down test on koomey, 3000 PSI initial, 1800 PSI draw down, 21 sec first 200 PSI, 1 minute 28 second final 3000 PSI, N2 au 1700, 1900, 1975, 2000 PSI. RU 3. 5" handling equipment PU landing joint and MU in hanger, PU and unseat hanger, pull 58M to move pipe, RIH 45' and set down on paraffin, attempt to work down with no luck POOH and dump in 5 gallons diesel, RIH and was able to work through. RIH W 2. 25" GR to 3000 PSI Pooh. RIH With Jet cutter to 8000' and cut pipe good indication of firing, POOH and RD. PU on tubing to verify tubing is cut. Set back down on hanger. RU circulating spool on top of bag, install hand rails on rig floor and safety chains. Hook up flow line hose to shaker, pull hanger above rig floor. Close bag and CBU. RD tubing hanger and lay down. Conduct PJSM on changing well bore fluids over from lease water to 12. 5 mud displacing through the super choke. Pump 12.5 mud thru choke displacing H20 13700 strokes, maintaining pump schedule. 10/29/04 Condition and circulate mud in pits weighting up, continue to pump taking returns to rig pits monitoring weight until had 12.4 heavy returns. Pull 1 joint of 3. 5" EUE tubing, came to 2 pup joints and while working them well started to u tube again. Stab floor valve and secured well. Took water on in pits and start to mix a 12. 5 PPG mud system. Circulate 60 BBL of 12.5 mud, monitoring returns. Repeated until 12. 5 PPG going in and 12. 4H returning. RU SWS, RIH with HSD-WL-DP 2", 2006 Pj, HMX, 6 SPF Gun. Dropped down and using Atlas Segmented CBL dated 12-20-90 to correlate, perforate below the 77-3 sand at 7666' to 7672', log up into position above the 77-3 sand and perforate at 7626' to 7632'. POOH all shots fired, RD SWS. Perform injectivity test pumping at. 5 BPM rate, pumped a total of 20 BBLs, with it breaking over at 2885 PSI. One minute after pump shut down pressure had fell back to 1922 PSI, has a total of 7 BBL flow back. POOH laying down 3. 5" EUE tubing, first GLM did not have any pups had to lay down GLM with joint. 10/30/04 POOH laying down 3. 5" tubing. Recovered a total of 204 joints, 3 pup joints, and the tubing hanger. Recovered 3- 3. 5" GLMs (6482. 25'). XO hanger to 2 7/8" EUE and land with TWC installed, RI LDS. Change upper and lower rams from 3. 5" to 27/8" and test same to 250 PSI low and 5000 PSI high. POOH laying down 2 7/8" tubing. Recovered 48 joints 2 7/8" tubing, cut off joint 15. 50' long, and 2 GLMs (1511. 41). RU Schlumberger WLU and RIH with 4.56" gauge ring and a junk basket. Set down at 7492' picked up with no additional drag, to 7300" set back down at 7492', picked up again with no additional drag set down a little harder this time went through. RIH to 7625' pick up and POOH to 7300', RIH to 7622' did not see any bobble at 7492'. POOH and LD junk basket and gauge ring. RU Halliburton EZ Drill cement retainer, conduct pre arming safety meeting. RIH with EZ Drill cement retainer, correlate and set top of retainer at 7600' with the bottom of retainer at 7602. 30'. Fired setting tool slow burn type took 55 seconds for tool to fire and scope out Pinched up 20 feet with no additional weight and set back SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 2. · ,. ( down on retainer to verify that it Jas set POOH and RD. Change upper and lower pipe rams from 2 7/8" to 3 1/2", add 2 1/16" 5M valve to inlet side of choke manifold. Test rams and valves to 250 PSI low and 5000 PSI high. 10/31/04 Change upper and lower pipe rams from 2 7/8" to 3 1/2", add 2 1/16" 5M valve to inlet side of choke manifold. Test rams and valves to 250 PSI low and 5000 PSI high. Blow down Choke Skid, BO Lds and pull hanger wih TWC used as a test plug. PIU HES Polished Stinger With Centralizer. (Rig Tongs Down 1 hr,). PU PH-6 pipe, had problems with back up on Foster tongs biting. RIH with 88 joints, drifting each joint, monitor displacement, and noticed that the stinger must have plugged off. RU to pump down tubing, pressure up to 1800 PSI with no luck, attempt reverse circulating, No-Go, Circulate down tubing again pressure up to 2800 PSI broke circulation free plug. Blow down choke and all pump lines, . Trip in with 3. 5 tubing, stop several time to break circulation. Came to area were tubing was u-tubing again, 181 Joints in, circulated bottoms up continued to u-tube mixed 13.2 pill and pumped down tubing to complete running into hole trip in hole with 3.5" tubing. 11/1/04 Trip in hole with 3. 5" tubing. RU to circulate with stinger 1 joint off bottom, circulate and condition mud 12.3 ppg all way around. Hang kelly hose that was not hung during 4. 5 hours of circulate MU XO for TIW valve to install in string to circulate down and stab in to eliminate flow back. RIH circulate 2 joints down to tag at 7632'. Press up annulus to 2000 psi. Press up annulus to and hold 2000 psi. Injectivity test pressure up to 2800 psi at 2 bbls per min. Slow to .5 bbls min. walk press and rate up final injectivity 1.5 bbls per min at 3,450 psi. Spot and RU cement equipment. PJSM Pump 3 bbls water, Press test lines to 5,000 psi. Pump 2 bbls water, Pump 15 bbls 15.8 ppg, Pump 5 bbls water, holding 400-600 psi on annulus. Pump 31 bbls 12.3 mud stab into retainer press up annulus to 2,000 psi, squeeze 20 bbls into perfs, monitor pressure from 3,600 psi to 3050 after 3 min, Pull out of retainer to Pull 60' and reverse bleed press monitor. Reverse out 13' above retainer BU 4 bbls water trace of cement Pump one more BU. Clean LD 2 jts. Blow down all hoses. 11/2/04 Blow down Dowell and all RD lines, Pull 5 stands rack back in derrick. Reconnect kill line and stand pipe line, RU to fill hole with charge pump. POOH rack back 15 stands. Blow down kill line and charge pump, suck pits out, inspect suction lines for plugging, (Found Rag), RU tarps and heaters for attempted winterization, clean up tongs, slips, and elevators. RU Vac truck to fill hole through annulus valve. POOH rack back 24 stands. Inspect carrier engine, (lack of engine power), found prime mover overfilled with oil, drained 2, 5 gallons engine oil. Pull 2 more stands, RU Swaco pump for retainer test, RU and finish filling BOP with mud for test Pressure up and perform 3000 PSI PT against retainer held for 30 minutes. Blow down choke, kill line, standpipe line and pump. TIH 3. 5" tubing to 7620, tag plug, LD 3 joints and PU tube hanger. Land hanger RI LDS at depth of 75421. Start nipple down, pull upper and lower rams, disconnect Koomey lines, RD tubing tongs and slips, clear all equipment off floor, 11/3/04 ND BOP. NU tree and test hanger void to 5000 PSI, remove 3" CIW type "H" BPV and install, 3" CIW TWC, pressure test tree for 20 minutes 500 PSI low and 5000 PSI high. Bleed pressure off and remove BPV. Secure well. NU injection line on annulus valve, run hose from wing to possum belly, ensure suction lines are free from ice on pump, continue to haul water to Johnson tank and pit 2 and 3 on rig mud system. Conduct PJSM go over roles and responsibilities prior to turning wellbore over from 12. 5PPG mud to lease water. Reverse circulate, pumping lease water from Johnson tank taking returns into pit 1. Initial circulating pressure 200 PSI, at 105 SPM (2 BPM), pumped from surface to surface + 1 BU for a total of 350 BBL. Maximum pressure seen was 1800PSI. RU and pump 5 BBL diesel down backside, RU and filled approximately 40' of tubing with diesel. Install BPV. Start removing tarps, RD, storing Koomey hoses, choke panel, and storing same. Blow down all lines. Suck out remainder of fluid in Johnson tank, clean pits. Go with TP and survey next pad, have felt and liner spread, haul over light plants, rearrange berm, haul in extra mat boards. Disconnect choke and kill lines. Clean and remove floor bleed hydraulic cylinders. 11/30/04 MI/RU. SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 3. 12/1/04 ( ( Rig was accepted at 06:00 hrs. Continued site prep. 12/2/04 Install blind rams and 3. 5" in middle and top; check on 3.5" rams in bottom; function each set of rams. Hook up flow line to shaker. Lower drill floor and build frame and hang tarp walls around cellar. Pull BPV and install 2-way check valve. RU to test BOPs. Test 250/3500 f/Hydril; 250/5000 on Rams, choke and kill valves, floor valve (OK). Test Koomey unit valves and pressures (OK). RD testing equipment, blow down lines. Pull 2-way check valve. Prep for pulling hanger; MU landing jt in hanger; pull hanger to rig floor; LD landing jt. ; 56K PU weight RU to displace hole to mud; round up extra chicsans needed for tying into Johnson tank and coil tank. PJSM. Displace hole to 12.1 ppg mud on back pressure choke schedule taking returns to Johnson tank until mud back; clean crossover; 300 Bbls lease water returned to surface. Blow down choke, hoses, mud lines; RD chicsans; prep to POOH w/DP. RU power tongs, pipe racking boards, and derrick board; check crown-o-matic. 12/3/04 POOH 120 Stands and 1 single of 3 1/2" PH6 with DP and rack back. LD Halliburton cement stinger. PJSM for BHA. PU Mill, XO, String Mill, and 3 1/8 DC w/lift subs. PJSM; PU 2-3 1/8 DC, XO and 1 jt of PH-6 DP. RIH w/DP to 5858' monitoring displacement 12/4/04 RIH from 58581 to 7596' monitoring pipe displacement RU pump in sub and Kelly hose on work string. Circulate and condition mud. Increase mud wt from 12.1 ppg to 12.5 ppg while circulating @ 7596', Circulate and condition 12.5 ppg mud until even all around, hook up Epoch and air compressor. Blow down lines and RD circulating head. Hold PJSM, RU power swivel lines in derrick. PJSM. Thaw controls for power swivel, and blowout water and mud , RU stiff arm, screen up shakers, hook up steam heater in choke house and plumb in. 12/5/04 Pick up first Stiff Arm for power swivel and run up and down sand line. Install stiff arm on power swivel and test on sand line. MU power swivel on drill pipe stump. Break circulation on well. Found mud line to shakers froze in low spot. Circulate and condition mud, work pipe, while waiting on welder to modify stiff arm. Record slow pump rates, 550 psi @ 56 spm, 600 psi @ 66 spm, and 650 psi @ 76 SPM. MW @ 12. 6 ppg, depth 75961. Install stiff arm on power swivel/test-good. Make connection, RIH kelly down. Picking up the first joint to make connection. IF threads broke instead of PH-6 on subs and floor valve, break out PH-6 and remake up IF (fight first connection for 2 hours). Start rotating, establish PU, SO. and Rotating weights. Rotating 60 RPM, pumping 115 strokes at 2.5 BPM and 800 psig with torque limit on power swivel controls set at 1100#. RIH and set down 76021 on heavy mud and barite solids 18' above cement top. Having problems with RPMs on power pack for power swivel falling off and losing hydraulics pressure. Pick up and circulate. Tag @ 7613', wash and ream to 7621', gain 200 psi pressure and torque up when putting 2-3K WOB. Mill cement to retainer top @ 7627' DP measurement. Drill retainer @ 7626' and cement to 7680' adjusting weight on bit and rotary speed as needed for best ROP. CBU before casing test. Strung in 5 sacks of Disco and 5 sacks of Bicarb. 12/6/04 Finish CBU at 7680 mw @ 10. 8 vis @ 85. RU and attempt to test casing and squeezed perfs @ 7969' to 7576', RU test pump and methanol tank, test to 2575 psi. pressure dropped to 2250' after 30 minutes. Last 10 minutes lost approx 40 - 50 psi. Mill cement from 7680 to 7713', break through cement, wash to 7720', pick up every 10' drilled while rotating, rotate @ 75, pump @ 3 bbl/minute. Circulate and condition mud, mw @ 12. 7, vis @ 80. Pressure test casing for 30 minutes using triplex test pump. Lost 200 psi first 10 min. lost 150 psi next 10 minutes and 60 psi the last 10 minutes. Circulate and batch treat mud (due to pump and pit limitations) to reduce viscosity and treat for cement contamination. RU to test casing, ensure all lines exposed to cold are blown down or drained. Test casing to 2500 psi using rig pump, (2. 5 Bbls required to increase pressure from 0-2500 psi, had to bump up pressure 3 times), on final test, pressure bled off 125 psi the first 10 minutes of test, 75 psi the next 10 minutes, then 15-20 psi every 5 minutes for the next 20 minutes, Total pressure lost was 240 psi over 40 minutes, 2600 psi to 2360 psi-good test. LD power swivel, hydraulic lines, stiff arms, control panel and rig tongs. RU power SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 4. · " ( tongs and clean rig floor. Mix dry(JuO. Reciprocate pipe when possible during work. PJSM on using pit # 2 alone for trip tank and running trip sheet. Tight liner watch for Swabbing hole. 12/7/04 Monitor well, pump slug. Drain and blow down lines. POOH from 7720' standing back DIP in Derrick. Filling hole every stands 10 stands. Monitor well when out of liner and @ 70 stands out Held PJSM, LD 3 1/8 DCs and milling assembly. Clear rig floor and catwalk, RU Schlumberger wireline. RIH with wireline, log squeezed interval with SCEMENT Monitor well by circ. over top of hole thru choke. RD Schlumberger Wireline, blow down choke and pump lines. PJSM, PU Champ Packer assembly, RIH 32 stands, monitor well. RU circulating head, fit test to 6' bails. RIH total 1 01 jts drill pipe. PU rig elevators, XOs, make up surge valve assembly. 12/8/04 Make up HES surge valve. Continue RIH with DP. Auto J Champ packer and set slips. Stab floor valve and pick up Lake Charles Head and stab. Pick up and make up manifold on rig floor. Proceed to test manifold and lines and get 3500# test on lines manifolds and test against all valves (OK). PJSM. Pressure annulus up to 500# (OK). Pressure annulus to 1500# and felt drill pipe surge. Surge valve opened. Performed walk thru change out of rig, and reviewed with their relief alignment of valves, and choke. Pump down tubing 32 bbls to fill, PU on string to port in packer to equalize pressure from annulus to tubing, reverse CBU x 1. 5 thru choke. Prepare to blow down lines and lay down drill pipe. Break out and lay down Lake Charles head, RD tongs RU power tongs, break out and LD valve manifold. LD ph-6 DP. To 6000'. Shut in well after irregular fill up, no pressure, no flow, open well, observed vacuum on tubing with trickle from annulus, monitor well 10 minutes while ensuring all lines blown down, after 10 minutes no annular flow and no vacuum on tubing. LD ph-6 DP. To 4400'. 12/9/04 POOH, LD 3. 5" PH-6 work string (wet). Build slug, monitor well. POOH, LD work string. Monitor well. RIH 2 stands from derrick, LD. Clean floor, rig area and BOPs with pressure. Drain stack, land hanger with TW check installed, run in 2 lockdowns. Pressure cellar dress elevators and tongs from 2. 875", cover production tubing, apply heat, drain stack, change out rams from 3. 5" to 2. 875" Make up test jt for BOP test. Run in test jt, RU test pump, function test rams, fill stack and choke, hold PJSM for BOP test 12/10/04 Finish testing BOPs (250 Low and 5000 high), Pull test joint and lay down. PJSM. Picked up Production tubing BHA. PU and RIH tubing to 2530' (76) joints. CBU @ 2500'. 72 SPM at 250 PSIG. PU tubing and RIH to joint # 161. Break circulation and CBU at 5320', joint # 163.86 SPM at 500 PSIG. PJSM. RU Pollard wireline. Pick up Chemical mandrel and test control line to 5000 #. RIH w/Tubing and control line to tubing joint # 193. Production tubing out of balance. Set slips to circulate. Well U-tubing circulate to balance. 12/11/04 CBU @ 87 spm 500 psi. Blow down pump lines, Pick up 2718 tubing to 7650'. RU and CBU, 700 psi @ 95 spm. PJSM, with Schlumberger wireline crew, RU to log. RIH with GRICCL, locate RA marker, log back up from 7504' to 6700' and tie in bond log from SLB and Western Atlas segmented bond log from 12/29/90. tied in and found RA marker to 21. 5' high to put gun on depth from 77-3 sand, POOH w. with found wireline zero off 30'. RD wireline. Review logs with Schlumberger engineer. Had concern with Western Atlas bond log correlated to open hole log. Make up hanger, pick up landing jt, test chemical injection line, hold pressure 5 minutes, run hanger thru stack land and lock down. RD pollard control line and sheave. RU to reverse and displace well from 12.5 mud to 8.5 lease water, Transfer mud from active pits to ISO tanks. Freeze protect upper annulus with 5 bbls diesel, blow down kill line and pump. 12/12/04 PJSM. RU Pollard wireline and pressure tested lubricator to 3500# (OK). RIH. Pollard landed N-Test Tool on No- Go nipple at 7608'.5' deeper than Tally. Pressure up tubing to 3515 psig. At 1800 # we had a good indication that Packer set. After 15 minutes pressure was 3015 psig. Test is good. Bleed tubing pressure to 1500 psig while leaving Pollard on No-Go with test tool. Pressured casing up to 3010 psig. Test good after 15 minutes and was SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 5. still 3015 psig and surface casin{ ",as still zero. Bleed casing pressure off. B~eed tubing. POOH with slickline and LD same. Set BPV. Cleaned pits, RD pumps and pit service lines. Remove rams from BOPs and wash cavities and break nuts on BOPs. Finish removing frame work from rig floor and raise the rig floor. ND BOPS, break kill line valves, manual choke and HCR off stack, remove Hydril, double and single gate. NU tree and test void (test no good). Perform diagnostics on surface. Tested production annulus to 3000 psig for one hour with test void, chemical port and production tubing open (no psi loss, test good). Pulled wellhead and tested chemical line to chemical mandrel and dummy valve (test good). Measured casing hanger bowl to casing hanger neck seals. 12/14/04 Pulled tree and installed new hanger bonnet. Pressure tested void to 5000 psig with tubing and chemical port open. Void took proper amount of fluid to pressure up and held for 15 minutes (test good). Tested hanger seals from top down and lower neck seal from bottom up. Hooked pump up to chemical injection port and tested to 5000 psig for 15 minutes (tested good). This tested lower neck seal from top down and upper neck seal from bottom up; control line and chemical mandrel to dummy valve packing in mandrel. Bleed chemical port and void cavity is still open. Pull BPV and install two way check valve. Pressure tested tree to 5000 psig. Found one wing valve stem packing leaking and adjusted same. Pressure back up to 5000 psig (tested good for 15 minutes). This tested the top neck seal from the top down and all flanges on surface. (Modified bonnet tested good.) PJSM. Peak hands found and chg/out tree cap to 3" Bowen. Finish RU and attempt to test lubricator block leaked, Wing valve steam leaked and tree cap leaked tightened bolts and Got tree cap and block test bottom Master valve only opening 16 turns out of 18. Unable to RIH Heat well head. RIH with 2" JUC to 7608' RKB WLM and set "N" test tool in no-go nipple (5' deeper then tally and had to pump tool thru sleeve) pressure up tubing to 5000 psi to 4980 psi in 30 min bleed off pressure and POOH. RIH with 2" JDC to 7608' RKB wlm catch and Jar "N" test tool free - POOH (had to work tool thru sleeve) continue POOH and recovered "N" test tool but missing two 2.313" X 1/4" thick packing. RIH with BO shifting tool to 7560' RKB wlm - Apply 200 psi to tubing and shift open Sleeve (lost the 200 psi and able to run up and down thru same), RD 12/15/04 PJSM with Pollard, SLB and Peak. RU wire line. RIH with 2-1/2" GS and A02 slip stop catcher sub to 2551' RKB wlm and set stop and pooh. RIH with 2-1/2" Daniels KOT and 1-1/4" jds to 2429' RKB wlm and pulled dummy valve and POOH. RIH with 2-1/2" KOT JK and 1-1/4" Chemical injection valve to 2429' RKB wlm and set valve and POOH. RIH with GS to 2551' RKB wlm and pull catcher sub. Pump 6 bbls diesel down tubing with tri-plex and returns from annulus thru choke skid to Johnson tank. PJSM with Pollard, SLB and Peak and go over N2 job. Pump 460 gal of N2 @ 500 scfm down tubing taking returns thru choke skid into Johnson tank shut down N2 @ 40 bbls gauged whp = 2620 psi. RIH with 42 BO shifting tool and confirm fluid level @ 6500' and pull up hole to 6300' and pump More N2 and gauge 3 more bbls of returns and down N2 pump whp @ 2750 psi and RIH and check fluid level @ 7415' RKB wlm run down to 7583' kb locate sleeve and jar down and close CMU sleeve and was able to run up and down thru same-POOH. Check pins ok and confirmed closed. RD. 12/17/04 PJSM. Pressure test flow lines with open well, check pressure 3,490 psi Tested 250 low ok, @ 1200 psi surface safety stem seal tattle tail leaking (DSM serviced same and tested to 2500 psi ok. used N2 from well to test flow line). RU lubricator to cover firing bar drop and test same with N2 (Leek @ Bowen "0" ring) Change out 0 ring and re test (ok) installed spider on Choke skid and test line and choke skid with N2 (ok) - Bleed N2 from well to 3242 psi (Spider) for correct under balance. Drop bar and herd Gun detonation 1 min 42 see later (Perforate 77-3 sand from 7630' to 7640' with HOWCO 3-3/8" millennium 6 spf TCP gun with auto release) and turned well over to Production for Test- Pressure built from 3242 psi to 3385 in 7 min. SCU 24A-05 (162909; 162951) morning report summary, CONFIDENTIAL: last revised 2/17/2005, Page 6. >Information >Well >Directional Surveys >F( ...,urvey ( Select Well: SCU 24A-05 ,- ~1r:iJ~ Report Name Well Date Created Position Log SCU 24A-05 2/17/2005 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) . ·ïiïterpolatel SCU 24A-05 OIL 501332025601 154 340/855 2/457/088 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 154 0 0 340,855 2,457,088 0.0 0 100 99 55 0 0 340,855 2,457,088 0.5 312 200 199 -45 0 0 340,855 2/457,088 0.4 311 300 299 -145 -1 1 340,854 2,457/089 0.5 303 400 399 -245 -2 1 340,853 2,457/089 0.5 299 500 499 -345 -3 2 340,852 2/457,090 0.6 304 600 599 -445 -3 2 340/852 2/457,090 0.5 303 700 699 -545 -4 3 340,851 2,457,091 0.4 311 800 799 -645 -5 3 340,850 2,457/091 0.5 299 900 899 -745 -5 4 340/850 2,457/092 0.5 291 1,000 999 -845 -6 4 340/849 2,457/092 0.3 294 1,100 1,099 -945 -6 4 340,849 2,457/092 0.2 335 1,200 1,199 -1,045 -6 5 340,849 2,457/093 0.2 2 1,300 1,299 -1/145 -6 5 340/849 2,457,093 0.3 16 1,400 1/399 -1/245 -6 5 340,849 2,457/093 0.2 331 1,500 1,499 -1/345 -6 6 340,849 2/457,094 0.2 7 1/600 1,599 -1/445 -6 6 340/849 2,457/094 0.2 25 1,700 1/699 -1/545 -6 7 340/849 2,457/095 0.3 324 1,800 1,799 -1/645 -6 7 340/849 2,457/095 0.2 21 1,900 1,899 -1,745 -6 7 340/849 2,457/095 0.3 19 2,000 1,999 -1,845 -6 8 340,849 2/457,096 0.3 7 2,100 2,099 -1,945 -6 8 340,849 2/457/096 0.2 25 2/200 2,199 -2,045 -6 9 340/849 2/457,097 0.2 66 2,300 2,299 -2,145 -5 9 340,850 2/457,097 0.3 28 2,400 2,399 -2,245 -5 9 340,850 2/457,097 0.2 25 2,500 2,499 -2/345 -5 10 340,850 2,457/098 0.2 59 2,600 2,599 -2/445 -5 10 340,850 2/457/098 0.3 36 2,700 2,699 -2/545 -5 10 340,850 2/457,098 0.2 2 2,800 2,799 -2,645 -5 10 340,850 2/457,098 0.1 273 2,900 2,899 -2,745 -5 10 340,850 2/457,098 0.1 44 3,000 2,999 -2,845 -5 11 340,850 2,457/099 0.2 335 3,100 3/099 -2,945 -5 11 340,850 2/457/099 0.1 349 3,200 3,199 -3,045 -5 11 340,850 2,457/099 0.3 59 3,300 3,299 -3,145 -4 12 340/851 2/457/100 0.5 61 3,400 3,399 -3,245 -3 12 340,852 2,457,100 0.4 62 3,500 3,499 -3,345 -3 12 340,852 2/457,100 0.4 81 3,600 3,599 -3,445 -2 12 340,853 2/457/100 0.3 43 3,700 3,699 -3,545 -2 13 340/853 2/457/101 0.4 52 3,800 3,799 -3,645 -1 13 340/854 2,457/101 0.4 37 3,900 3,899 -3,745 -1 14 340/854 2/457,102 0.4 33 4,000 3,999 -3,845 0 15 340/855 2/457,103 0.5 48 4,100 4,099 -3,945 0 16 340/855 2,457/104 1.0 23 4,200 4,199 -4,045 1 17 340/856 2,457/105 1.1 38 4/300 4/299 -4,145 2 19 340,857 2/457,107 1.3 39 4,400 4,399 -4/245 3 21 340,858 2,457/109 1.4 41 , 4,500 4,499 -4/345 5 23 (' 10,860 2,457/111 2.0 34 ( 4,600 4,599 -4,445 7 26 ,j40,862 2/457,114 2.1 38 4,700 4,699 -4/545 10 29 340/865 2/457/117 2.1 35 4,800 4,799 -4,645 12 32 340,867 2,457,120 2.2 33 4/900 4/899 -4,745 14 35 340/869 2,457,123 2.3 36 5,000 4,999 -4,845 16 39 340,871 2/457,127 2.3 27 5,100 5,099 -4,945 18 42 340/873 2,457,130 2.4 34 5,200 5,199 -5/045 21 46 340/876 2,457,134 2.6 34 5,300 5,299 -5,145 23 50 340/878 2,457,138 3.0 27 5,400 5,398 -5,244 26 55 340,881 2/457,143 3.3 33 5,500 5,498 -5/344 29 60 340,884 2/457,148 3.5 31 5,600 5,598 -5,444 33 65 340,888 2,457/153 4,1 28 5,700 5/698 -5/544 36 72 340/891 2/457/160 4.4 29 5,800 5,798 -5/644 40 79 340,895 2/457,167 4.5 24 5/900 5,897 -5/743 43 86 340,898 2/457/174 5.1 23 6,000 5,997 -5,843 47 94 340,902 2/457/182 5.2 29 6/100 6,096 -5,942 52 102 340,907 2/457,190 5.2 29 6/200 6,196 -6,042 57 110 340,912 2/457,198 5.3 30 6/300 6,295 -6/141 61 118 340/916 2,457,206 5.4 32 6,400 6/395 -6,241 66 126 340/921 2,457,214 5.5 21 6,450 6,445 -6,291 66 131 340/921 2,457/219 5.5 352 6,500 6,495 -6/341 65 135 340,920 2,457,223 5.2 323 6,550 6/544 -6,390 61 138 340/916 2,457,226 5.3 291 6,600 6/594 -6,440 56 139 340/911 2,457,227 6.5 275 6,650 6,644 -6,490 50 139 340/905 2,457,227 7.5 264 6,700 6,693 -6,539 43 139 340/898 2,457,227 8.4 266 6,800 6,792 -6,638 27 139 340/882 2/457,227 10.1 272 6,900 6,890 -6,736 9 140 340,864 2/457/228 11.2 275 7,000 6,988 -6,834 -9 140 340,846 2/457/228 10.2 260 7,050 7,038 -6/884 -17 138 340/838 2/457/226 ' 9.0 262 7,100 7,087 -6/933 -25 137 340,830 2,457,225 8.2 262 7,200 7,187 -7/033 -36 136 340,819 2/457/224 5.2 262 7,300 7,286 -7,132 -45 135 340/810 2/457,223 5.3 260 7/400 7,386 -7,232 -54 133 340,801 2,457,221 5.2 258 7/500 7,485 -7,331 -63 132 340,792 2,457/220 5.0 263 7,600 7/585 -7/431 -71 131 340,784 2,457,219 5.0 273 7,700 7,684 -7/530 -81 131 340/774 2,457,219 5.5 268 7,800 7,784 -7,630 -90 130 340/765 2,457,218 6.0 252 7/900 7,883 -7,729 -100 126 340/755 2/457/214 5.5 243 8,000 7/983 -7/829 -109 122 340,746 2,457,210 6.1 246 8,100 8,082 -7/928 -118 118 340,737 2,457,206 5.3 241 8,200 8/182 -8/028 -126 114 340,729 2/457/202 5.5 248 8,300 8,282 -8,128 -135 111 340,720 2,457,199 5.5 255 8,400 8/381 -8/227 -145 108 340,710 2,457,196 5.3 255 8/500 8,481 -8,327 -153 106 340,702 2,457/194 5,1 258 8,600 8/580 -8/426 -162 102 340,693 2/457,190 6.1 221 8/700 8,680 -8,526 -169 94 340/686 2,457/182 6.2 228 8,800 8,779 -8/625 -177 87 340,678 2/457/175 6.2 230 8,900 8,879 -8/725 -186 81 340,669 2,457/169 5.5 239 9,000 8/978 -8,824 -193 77 340,662 2/457,165 4.5 241 9,100 9,078 -8,924 -200 74 340,655 2/457,162 4.0 255 9,200 9/178 -9,024 -207 73 340,648 2/457/161 4.3 267 9,300 9,277 -9,123 -216 73 340,639 2/457/161 5.4 267 9,400 9/377 -9,223 -226 71 340/629 2/457,159 6.3 254 9,500 9,476 -9/322 -236 67 340/619 2/457/155 6.4 243 9,600 9,576 -9,422 -246 63 340/609 2/457,151 6,2 248 9,70Ò 9,675 -9,521 -256 59 l 1-0/599 2/457/147 5.6 244 ( 9,800 9,775 -9,621 -264 55 AO/591 2,457,143 5.4 243 9,900 9,874 -9/720 -272 50 340/583 2/457/138 5.3 239 10,000 9,974 -9,820 -280 46 340,575 2,457,134 5,2 242 10,100 10,073 -9,919 -288 42 340/567 2/457,130 5.0 246 10,200 10,173 -10,019 -296 39 340,559 2,457,127 4.5 246 10,300 10,273 -10/119 -303 36 340/552 2,457/124 4.2 248 10,400 10,372 -10,218 -310 36 340,545 2,457/124 4.0 286 10,500 10,472 -10,318 -318 37 340/537 2/457/125 5,6 270 10,600 10/572 -10/418 -328 38 340,527 2,457/126 5.4 280 10,833 10,804 -10,650 -349 42 340/506 2/457/130 5.4 280 10,883 10,853 -10/699 -354 43 340,501 2,457,131 5.4 280 ) ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unoca1.com ~~~ -->1,~1'! Date: November 29, 2004 UNOCAL Debra Oudean G & G Technician To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 JI""j¡:þ ~" " .....; ",,¡\f~ .~.." ....,",.,. , \..../j ·f..·' I I . '/ \".;:~:,'~. . . 'INTERVAL Boo .' . WELL .' LOG TYPE . SCALE LOG DATE LOGGED. LINE CD .000..of:>t ~KGSF-7A PERFORATING RECORD33/8 HSDGUN ¡SINCH 1.10/24/200416100-64so'l· 1 / /¡SCU 24A-OS IPLUG SET RECORD 2 7/8 HALLIBURTON EZSV Is INCH I 1 0/21/2004 1963S-963S1 1'1' I l ~o ~'-\ " ;SC.U 24A-,OS. ISQUEEZE PERFO~~TION RECORD 2 HS~ 2006 PJ 6Sflf ,.15 INCH. .1 10/29,/200.1 /ì626-ì8,00' I 11 : \ _--.~CU 24A-OS IHALLlBURTON CEMENT RETAINER Is INCH 110/30/200417100-7600 I 1 11: 'to-:1>1.t1jSCU'312-09 'ISÙ'~J'-CEMËNT-MA-PTÖOL------ . .-.- ._. -- - ---:!SINCH' '-1-10/2-1/2Õ0414300~7300--r 1-'¡1-' tCeo <-olJtl?CU ~12-09 JgOMPLETI9~ RE(;O~D 2HSD-PO~_ER~ËT--_=---=-==.[~I~-ªH 111/m()Ò¡r699õ=634Ò__J 1 r-11 - ( í .) SCU 32-08 COMPLETION RECORD 2.5 HSD POWERET 6 SPF 60 5 INCH 10/3/2004 10200-1 OS65. 1. 1 i. {¡;o-0'15 DEGREE PHASED '. . ¡ ?O -IS ¡ [SCU 43B-08 ¡COMPLETION RECORD 2.5 HSD POWERJETS . ¡5INGH.· . ¡ ·i 1I31200415857-5867j 1 . 11. ¡ ,"^ -0 dt,jlSRU 23-27 ".HALLlBURTON GUN CORRELATION LOG RESERVOIR .5INCH 10/17/20045100-7760 1 1 ¡ lVV ì SATURATION TOOL ...! ~,05t W~~.~~ET~.]~"~~,~~i~"~~y§~·~·.~g~y~v.:ª~ª~~.="'~':'·':~··.":::·:::=.~lfi75·iÑcH-r-¡¡Î27i2õo4Õ-96ôo·-·~·~n~-r;J IfÀq ,.,auSRU 32A-15 COMPLETION RECORD 2 HSD POWERJET 6SPF 60 .5 INCH .' 9/30/200.1 7280- ì600 1 1 .: -, "'(/{J, DEGREE PHASED .. ¡ r"·.."'·,",·"·"·,·""..".."''',·"·,,,·,....,..;'',,..,,,..,·,·,,·,,,,··,,,,.,,.,,,,,,,,,,,,,,,,,,,.,..,,,,.,,,,,,.,,,,,,..,.,,.,,,,,,..,,,...,,,,,,,,.,,,,,""",,,,,,.,,,,.,.,,,,,,,,,,,..,,,,,,,,.,,,,,,,,,,,,,,,,,,,,.,,,,.,,,,...,,,.,,,,.,,,.,...,..,.",,,.,,,,,,,,,,,,,.,,..,,,,.,,,,.,.,,,,,.,.,,,,,,,,,,,.,,,.,,,,,.,,"",,,.,,,,.,,,,,,,,,,,,.,,,,,,,,,,.,,,,,,,,,,,.,,,'" "",.,.,.,."",,,,,.,,..,.. ..,,,.,,,.,...,,,,,,,,,,.:.,.,,,,,,,..,...,,,.,,,,.,.,,,..,,.,.,,j ~~_:~~~A-15. ~~~~i~I~~:E?~g~l~c :R~g;~~~~ET 6SPF .5 INCH....... ..1..~~~~~.~~6830-7345 . 1,1.1 c.....!í''"' ,. ':\\ '\'¡ e~f'\. 1\ '0 I.': ~ 'I n í1 i-~ ,~\-,,§.~~~~~t.L' .'-~A ;1 _t :0 ¿.u...' Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: /~? ¡: ~ ) ) Iff) - 1'f1 ~ FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Swanson River 24A-05 Sundry Number: 304-473 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. ~cerelY, D~t, Jr. Commissioner DATED this.2day of December, 2004 Enc!. SCANNED DEC 1 3 2004, 1. Type of Request: \ STATE OF ALASKA, ALAS~ ,-OIL AND GAS CONSERVATION COMMI... ~bN APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 'rI6*" §I II'''': ¡ii' Operational shutdown-b:- Perforate U Waivød..J . Plug Perforations D Stimulate D Time Extension D Perforate New Pool D 4. Current Well Class: Development Stratigraphic 0 D Service Exploratory 0 0 \ - ;_. - ,¡:" ,"' Annular Disp~s. U Other ~ WG Resume Operations 5. Permit to Drill Number: ~L..-/ 90-0111-0 // IW~Wtfj) 6. API Number: 50-133-20256-01 / Abandon U Alter casing D Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 25.85' RKB Suspend U Repair well 0 Pull Tubing 0 8. Property Designation: Soldotna Creek Unit 11. 9. Well Name and Number: SCU 24A-05 / 10. Field/Pools(s): Swanson River Field/ Tyonek, Hemlock Total Depth MD (ft): 10,790' Casing Structural Total Depth TVD (ft): 10,761 Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9,740' 9,715' Plugs (measured): Junk (measured): Size MD TVD 91' 90' 3,390' 3,389' 7,090' 7,077' 10,175' 10,148' 10,790' 10,761' Burst Collapse Conductor Surface Liner 91' 18" 3,390' 10-314" 7,090' 7-5/8" 3,453' 5-1/2" 1,091' 2-7/8" Perforation Depth TVD (ft): 10,317 to 10,640 Baker Mod F-1 size 40-30 3,130 psi 6,020 psi 9,190 psi 1,580 psi 3,400 psi 8,830 psi Production Liner Perforation Depth MD (ft): 10,344 to 10,668 Packers and SSSV Type: Tubing Size: 3-1/2"; 2-7/8" Tubing Grade: N-80/L-80; N-80 Packers and SSSV MD (ft): Tubing MD (ft): 6,498'; 9,650' 9,651' 12. Attachments: Description Summary of Proposal GJ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 6/10/2004 Oil 0 Gas 0 WAG 0 GINJ 0 0 Service 0 Plugged WINJ 0 0 Abandoned WDSPL D D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim C. Brandenburg Title Drilling Manager Signature 7 ' c. Þ ¿ Phone 9O~~:~::ON USE ONLY Date Contact Steve Tyler (907-263-7649) 12/3/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30"-~7..3 Plug Integrity D BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: 'T'es t- ßO P E to ~ c?oG rç / , RBDMs 8Fl DEC 0 6 2004 Subsequent Form Required: ¡ CJ - 4 \2"1 ' OR\G\NAL - .. '.-'-' 0 J vl,..,;::R OF ~ Approved bY:,{j /' I Form 10-403 Revised 12/ 003 COMMISSIONER THE COMMISSION Date: / 2/3( 4- INSTRUCTIONS ON REVERSE Submit in Duplicate ) UNOCAL8 I CURRENT I ) Swanson River Well SCU 24A-05 ' As Suspended on 11/02/04 ( Casing & Tubing Top Btm Hole Cmt Cmt Top Surf 91' Yes Surf Surf 3,390' 15" 1263 sx 1450' Calculated Surf 34' 34' 117' 359 sx 6130' 117' 3945' 9-7/8" Thru DV @ CBL 3945' 5878' 7438' 5878' 7027' 7027' 7090' 6722' 10,175' 6-1/2" 250 sxs 8800' CBL 9699' 10,790' 4-7/8" 9740' I Surf I 7542' ~.~1æJI RKB =25.85' Size Type Wt Grade ID 11- - - -~ 18" Conductor " 1O-%" Surf Csg 40.5 K-55 10.050 1 ~:' 7-5/8" 26.4 6.875 7-5/8" 33.7 N-80 6.765 @) ~ 7-5/8" Prod Csg u ~ 6,875 0 ... 7-5/8" 29.7 6,875 7-5/8" 33.7 P-II0 6.765 7-5/8" Window. Cut on 11/14/90 5-1/2" Liner 20 N-80 4.778 2-7/8" Liner 6.5 N-80 2.441" Tubin~ 3-1/2", PH-6 I 12.95 I P-ll0 I 2.75 ,..¡ = u . .1 A 2.441 2.313 2.45 2.313 JEWELRY DETAIL OD Item Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Type "H" BPV Profile GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch Packer, Baker Mod. F-l, Size 40-30 Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin X Nipple, (2.313" LD.) Baker Overshot X Nipple, (2.313" LD.) 4.5 4.5 ~ ~I / NO. Depth 25.85' GLM #6. 8,842' GLM #7. 9,613' 1. 9,651' 2. 9,659' 9,691' 3. 9,698' 4. 10,463' I 6574' A. 7542' B. 7632' TM ID 2.347 2.347 TIW Liner top pkr. Stuck while RIH., HES stinger assy 5-1/2" FasDrill Retainer /1 Toe@88I1' 11/1/04 8,000' Brief History Pumped 19.5 bbls ofG neat cmt below retainer. Left Y, bbl ofcmt on top of retainer. Tagged @ 7620'. Tested to 3000 psi f/ 30min Cut 2-7/8" tbg on 10/28/04 Tbg stub @ 9699' has been problematic to enter Tbg Plug @ 10,677' FISH PERFORATION HISTORY (DIL Depths) Interval ACCUDL Date Zone Top Btm Amt spf Comments Sqz Holes 7,669' 7,675' 6' 4 Sqz Perfs Sqz Holes 7,697' 7,703' 6' 4 Sqz Perfs Mar-DO H-2 10,344' 10,354' 10' 6 PoweIjet HC, 60 deg. Mar-OO H-3 10,378' 10,388' 10' 6 PoweIjet HC, 60 deg. Mar-OO H-4 10,392' 10,445' 53' 6 PoweIjet HC, 60 deg. Apr-91 H-6 10,453' 10,465' 12' 4 Apr-92 H-6 10,453' 10,465' 12' 4 Reperf Mar-DO H-8 10,476' 10,486' 10' 6 PoweIjet HC, 60 deg. Feb-91 H-8 10,486' 10,512' 26' 4 Mar-DO H-8 10,512' 10,554' 42' 6 PoweIjet HC, 60 deg. TD= 10,790' PBTD= 10,745' Jan-91 H-9 10,566' 10,582' 16' 4 Max Deviation = 11.2° @ 6,900' Mar-99 H-I0 10,601' 10,640' 39' 4 2-1/8" HC, 0 deg. Dec-98 H-I0 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. SCD 24A-05 Current Schematic 110304 REVISED: 11/3/2004 by SL T seD 24A-Oi WO ) ) 12/01104 Workover Summary: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. RU Nabors Rig 26 RIG - ND tree. NU BOPE. PT Same. Pull BPV. MU Land joint. RIG - CO to 12.5 ppg mud. POOH. RIG - PU/MU drilling assy RIH drill/CO Ret and Cmt to 7640', PT cmt sqz to 2000 psi. RIH /' drill/CO to 7720'. PT emt sqz to 2000 psi. POOH. EL - RU Eline. RIH w/ SCMT to 7700'. POOH Logging to 4700'. POOH. RD. RIG - PU/MU 5-1/2" RTTS pkr. RIH 50 stands. PU/MU HES Surge Valve. Continue RIH. Set RTTS @ 7550'. Pressure test pkr: Open sUJge valve to negative test sqz perfs. Monitor well. POOH LD workstring and BHA. ~ RIG - PU/MU TCP guns, completion pkr and jewelry. RIH on 2-7/8" tb¿~line eorrelate/space- out from TCP guns wI top shot at 7630' and CIM @ 2500'. Land tbg in hngr. WL - RU slickline. RIH wI N test tool to BXN Nipple. Set Pkr. Test tbg to 3000 psi. Test pkr annulus to 3000psi. POOH wI plug. RD. RIG - Install BPV. ND BOPE.NU tree. Test same. Demobe Rig. WL - RU slickline. RIH open CMU sliding sleeve. POOH. Mix/pump annular volume of lease water w/CRW 132@ 1 % w/ Oxygen Scavenger, followed wI 5 bbls of diesel. N2 - RU N2 equipment. Displace fluid in tbg wI N2 through CMU sldg slve. RI close sleeve. Trap pressure. RD Slickline, pump & N2 equipment. / Drop bar. Perforate 77-3 sand @ 7630' to 7640'. Secure operations. Turn well over to production. ) ~~fÆ~E 'I F fÆ~fÆ~~«fÆ AT,ASIiA. OIL AND GAS CONSERVATION COMMISSION Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Swanson River SCU 24A-05 Sundry Number: 304-415 Dear Mr. Brandenburg: ) FRANK H. MURKOWSK/, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 qó-/lfLf 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 requeste BY ORDER OF THE COMMISSION DATED thisL2...àay of November, 2004 /' Encl. SCANNE.D NOV 1 5 2004 91' 18" 3,390' 10-3/4" 7,090' 7-5/8" 3,453' 5-1/2" 1 ,091' 2-7/8" Perforation Depth TVD (ft): 10,317 to 10,640 Baker Mod F-1 size 40-30 12. Attachments: Description Summary of Proposal L:J Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: 1. Type of Request: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 25.85' RKB 8. Property Designation: Soldotna Creek Unit 11. Total Depth MD (ft): 10,790' Casing Structural Total Depth TVD (ft): 10,761 Length Conductor Surface Production Liner Liner Perforation Depth MD (ft): 10,344 to 10,668 Packers and SSSV Type: 16. Verbal Approval: - .. STATE OF ALASKA. ALAS. )oIL AND GAS CONSERVATION COMM\, JON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 . - / O~~kl shutdown M Plug Perforations D Perforate New Pool D 4. Current Well Class: \¡J6Á- III f-¿/ ¿o°t Suspend..~ Repair well D Pull Tubing D Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other D Development Stratigraphic [2] D 5. Permit to Drill Number: Exploratory 0 90-0144-0 / Service D 6. API Number: 50-133-20256-01 ~ 9. Well Name and Number: SCU 24A-05 / 10. Field/Pools(s): Swanson River Field/ Tyonek, Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9,740' 9,715' Plugs (measured): Junk (measured): Size Burst Collapse MD TVD 91' 90' 3,390' 3,389' 7,090' 7,077' 10,175' 10,148' 10,790' 10,761' 3,130 psi 6,020 psi 9,190 psi 1,580 psi 3,400 psi 8,830 psi Tubing Size: 3-1/2"; 2-7/8" Tubing Grade: N-80/L-80; N-80 Packers and SSSV MD (ft): 9,651' Tubing MD (ft): 6,498'; 9,650' Date: 13. Well Class after proposed work: Exploratory 0 Development [2] 15. Well Status after proposed work: 6/10/2004 Oil 0 Gas [2] .yRly,g~ed 0 Abandoned WAG 0 GINJ 0 (V\iINJ{ '. . '"WDSPL Î/'i {,\ "",. . 7 .,} Contaqt i. . St~ye Tyler (901.;26'i.!tPf9) f' ':.' D D Service D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim C. Brandenburg Title Drilling Manager Signature ~ cþ _fi~'one 907-276-7600 Date /- COMMISSION USE ONLY 11/5/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: joy -L/¡0 Plug Integrity D BOP Test D Other: Approvffii by:.. Mechanical Integrity Test 0 0 Location Clearance ({9 ~ 40 '~ SCANNEr-j NO\! 1 5 2004 d +- ~.ç~,f'f ð-IU¥&\...-þ~Ç.. KfJtM. ò.( 'f-</ . ,- COMMISSIONER Daæ: su1!itf RBDMS BFL NOV 1 5 2004 BY ORDER OF THE COMMISSION / INSTt1~r~ tM~EL ) ') Swanson River Well SCU 24A-05 As Suspended on 11/02/04 UNOCAL8 I CURRENT I & Tub in g Top Btm Surf 91' Surf 3,390' Surf 34' 34' 117' 117' 3945' 3945' 5878' 5878' 7027' 7027' 7090' 6722' 10,175' 9699' 10,790' I Surf I 7542' Casing RKB =25.85' Hole Cmt Cmt Top Yes Surf. 15" 1263 sx 1450' Calculated 359 sx 6130' 9-7/8" Thru DV @ CBL 7438' Grade ID Size 18" Type Conductor Wt œ - - it 0 ""' - - L 10.050 6.875 6.765 6.875 6.875 6.765 Surf Csg 40.5 K-55 1O-%" 7-5/8" 26.4 7-5/8" 33.7 7-5/8" Prod Csg ~ 7-5/8" 29.7 7-5/8" 33.7 7-5/8" Window. Cut on 11/14/90 N-80 ~ P-110 ~;~Ji~.¡j:~1!ì~~.~f 8800' CBL 9740' 250 sxs 6-1/2" 4-7/8" 5-1/2" Liner 20 N-80 4.778 2- 7/8" Liner 6.5 N-80 2.441" Tubin!!; 3-112", PH-6 I 12.95 I polIO I 2.75 ~~: I frI ... = u JEWELRY DETAIL OD Item Tubing Hanger, Shaffer, 3-1/2" EVE 8rd Mod. Lift Thread x 3-1/2" EVE 8rd Mod. Suspension Threads, Type "H" BPV Profile GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch Packer, Baker Mod. F-l, Size 40-30 Crossover, 4' lOrd Box x 2-7/8" EVE 8rd Pin X Nipple, (2.313" I.D.) Baker Overshot X Nipple, (2.313" I.D.) !~ u ~j."::" g~ BOC @ :~~~~ 7200' CB~ ìIIìIII.SiiII," .' ".".' 'r... ". ~~~..~:tr ~~:; B :.':J~~~~~~ ~Q ~Q 0:00 ...;¡OO =@ Uu :r ~~~ ~~I."'..'....':... e~ ~ ~~ NO. Depth 25.85' GLM #6. 8,842' GLM #7. 9,613' 1. 9,651' 2. 9,659' 9,691' 3. 9,698' 4. 10,463' I 6574' A. 7542' B. 7632' TM ID 2.347 2.347 4.5 4.5 2.441 2.313 2.45 2.313 A TIW Liner top pkr. Stuck while RIH. HES stinger assy 5-112" FasDriII Retainer Toe@88I1' SCANNED NOV 1 5 2.004 Brief History Pumped 19.5 bbls of G neat cmt below retainer. Left Y2 bbl of cmt on top of retainer. Tagged @ 7620'. Tested to 3000 psi f/ 30min Cut 2-7/8" tbg on 10/28/04 Tbg stub @ 9699' has been problematic to enter Tbg Plug @ 10,677' 11/1/04 8,000' FISH .!.~. M~;l fII'~ 4,. I ;'~I:. i~,.., ,~:.~,...~ ,t":;.~".~- :,)~ : ~.~./ ;5:::~ JI ,..._,,;¡'C. ,'; I ~ ~ ',} ;, '. . . .~ , J::."" .::.1'.. .'- . .-t. .<.~ ,L '~- ~ ~.:,,:.~:: L~:¡ ~ '"'.x;,' .1t~~~:.~~,""o/,").~ ,. .- ~ "-- '..-.¡¡¡t,' ., . ~.. -1-,: .-~... YS:""'4 . "':.'" .... r.o ' ~,:h~ . ~ V::\,~..'" '1.' .... .""\' "',:"';.,l.'Qt"",-. \"., "..". .~.,. - fY ::-~ ~~=:~ 3 ~",.''i;,?~ . "';;'.'..1""'. ~ 1:'-4"\~ ',..., :t"""~ J-t...,goj IC..' -~ ,....}"!,!J:'.J¡.-! -",~,"'¡-"'I1~~". "'~', ~ ":~, - "f'. ;*-~ ~'~'Þ.' ~.' ,}.'-:-'; ~..~tf,;;~; !r{~' PERFORATION HISTORY (DIL Depths) Interval ACCUßL Top Btm Amt spf 7,669' 7,675' 6' 4 7,697' 7,703' 6' 4 10,344' 10,354' 10' 6 10,378' 10,388' 10' 6 10,392' 10,445' 53' 6 10,453' 10,465' 12' 4 10,453' 10,465' 12' 4 10,476' 10,486' 10' 6 10,486' 10,512' 26' 4 10,512' 10,554' 42' 6 10,566' 10,582' 16' 4 10,601' 10,640' 39' 4 10,640' 10,668' 28' 4 Comments Sqz Perfs Sqz Perfs Poweljet HC, 60 deg. PoweJjet HC, 60 deg. Poweljet HC, 60 deg. Zone SqzHoIes Sqz Holes H-2 H-3 H-4 H-6 H-6 H-8 H-8 H-8 H-9 H-lO H-lO Date Mar-OO Mar-OO Mar-OO Apr-91 Apr-92 Mar-OO Feb-91 Mar-OO Jan-91 Mar-99 Dec-98 Reperf Poweljet HC, 60 deg. Poweljet HC, 60 deg. TD= 10,790' PBTD= 10,745' Max Deviation = 11.20 @ 6,900' 2-1/8" HC, 0 deg. 2-1/8" HC, 0 deg. REVISED: 11/3/2004 by SL T SCU 24A-05 Current Schematic 110304 10/13/04 ) ") Remarks PJSM, Rig Pollard slickline up, and pressure'test to 3000 psi. Job suspended. Rig down Pollard and move to SRU 32-15 10/14/04 Remarks . PJSM, Rig up Pollard slickline and pressure test to 3000 psi. RIH with 2.81" GR to 440'. Tools slowed down and stopped at 460'(KB). Very sticky. Pumped diesel and worked tools down to 520' (KB). Mobe Hot oil truck and load oil. Pump 5 bbls of oil, RIH with 2.81 GR. Cut paraffin while pumping hot oil down to 2300' KB where tools fell free. Went on down to 6497 KB. RIH with 2.31 GR to 9789' KB. RIH with 2 1/2" daniels KOT w/1 1/4" PT to 8827' KB. Pulled valve POOH. Secured well and SDFN. 10/15/04 Remarks PJSM, pressure test Pollard lubricator to 3000 psi. RIH w/1 1/4" daniels pulling tool and pulled GLV at 9613'. POOH (#7) RIH w/1 1/4" daniels pulling tool and pulled GLV at 7825' POOH (#5) RIH wI 1 1/4" daniels pulling tool and pulled GLV at 6691'. (drawing had GLV at 6499', it was a typo) POOH (#4) RIH w/2" JDC pulling tool and pulled GLV at 5416'. POOH (#3) RIH w/2" .JDC pulling tool and pulled GL V at 3989'. POOH (#2) RIH w/2" JDC pulling tool and pulled GLV at 2375'. POOH.(#1) RIH with 1 1/2" dummy valve and set it in GLM #2 at 3989'. POOH Rig lub back and secured well. 10/16/04 Remarks PJSM, rig up, pump 2 Bbls Diesel. RIH with Dummy Gas Lift Valve on 3" Daniels and set at GLM # 3 at 5408' RKB RIH wittfDummy Gas Lift Valve on 3.5" OM1 and set at GLM # 1 at 2348' RKB RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 4 at 6675' RKB RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 5 at 7790' RKB RIH with Dummy Gas Lift Valve on 2 1/2" Daniels and set at GLM # 6 at 8801'RKB RIH with same to GLM # 7 at 9579' RKB and could not get set! RIH with same to GLM # 7 at 9579' RKB and could not get set 2nd time. Discuss options. RIH with same to GLM # 7 and set valve at 9579' RKB. Valve wobble lock ring doesn't want to lock Rig down Pollard and send home. Schedule pump truck for MIT after coil work. 10/20/04 Remarks Void tested to 5,000psi. Pack off tested to 3,000psi. All Good test. RlU hard-line and pump truck to MIT and perform injectivity test Circ. fluid through lines and press test to 4500psi. Start 1,060psi. Tbg. Press. 1,000psi. 7 5/8 x Tbg. Press, 90psi. 7 5/8 x 10 3/4 psi. Started RID pump truck and choke skid, hard line Clean out pump truck. Call pollard wireline for crew. Suspend operations. Pollard in field mobilize equipment to 24a-05, RlU pollard wireline. Press test lubricator to 1500psi. Rih WI 2 1/2" Daniels KOT w/1" Impression block set down @ 6699' - POOH Impression of Valve. Rih W/2 1/2" Daniels KOT w/1" Impression block set down @ 9603' POOH Impression of empty pocket. Rih WI 2.31 G.R. TI 9,684'. RID and stage equipment back @ P&S yard Suspend Operations SCANNEr NO\! l 5 200t; SCU 24A-05 morning report summary, CONFIDENT AL: last revised 11/10/2004 Page 1 10/21/04 ) ) Remarks PJSM Spot Equipment and set up BOPE E-line Spot equipment RlU Pjsm Reviewed Unocal Explosive check list, Test Lubricator T/1 ,500psi. ( Coil tubing crew continuing rig up ) RIH with 2 7/8" EZSV log mandrels on the way in hole, log tubing anchor and GLM #7, set EZSV at 9635', POH rig down E-line. ( Coil tubing rigging up ) Rig up Coil tubing Operation suspended 10/22/04 Remarks RlU and Test Bope Equipment WI State Man. Review Coil Tbg. Check list TIH WI Coil Tbg. 250psi tbg. Press, 250psi. Annulus Press. Pump .25 bbls per min. Check weights every 1,000'. Check Wt @ 9,500' Check Tbg. For press 0 psi. not on vac. Check Annulus 0 psi. not on vac. Tag Retainer @ 9,626' KB set 3,000psi. Down wt. Test seals - Pumped 50 bbls down back side showed 50psi. Increase at well head. Tbg. No press or flow. Unstung from retainer Annulus went on vac. Wait till well went to neutral. Sting back into retainer put 3,000# on retainer. Injectivity test, 1 bpm 1,050 psi. Pumped 10bbls Shut down press went to Opsi.1050psi friction press. Pumped 5bbls more Check forvac. No vac. or press. Pum p Cmt. Detail. 5bbls water-25bbls 15.8 Cmt -5bbls water - 24 bbls lease water. Pum ped 15bbls below retainer pulled up Laid in 10 bbls cement above retainer. Over Displaced 5 bbls. Shut down Pulled out of hole. End of job, Tbg. & Annulus 7 5/8 x Tbg. were not on vac. Shut master Circ. 2 coil volume to Johnson tank Blow coil down W I N2. Rig Down Coil Tbg. Move off to build up pad for Rig. Shut down Operations 12hrzs wait on Cmt. CMT in Place @ 18:43hrs Mobilized 420 bbls mud 12.4 from Happy Valley G&I to storage set up on SCU-24A-05 10/23/04 Remarks Rigged up pollard Test Lubricator, Ran 1.9 G.R. Tagged @ 8,034' wlm - kb 8,050' Rig Operations Suspended 10/24/04 Remarks PJSM, RlU on Tbg. And annulus. Test T/4500psi. Started Pumping down tbg. Pumped 23bbls press up T I 2,300psi. Hold 5min no loss. Hold Press on Tbg. While pumping on Annulus 7 5/8xTbg. Pumped 96bbls Press up T/1500psi. Bleed back, T/500psi. Press up TI 4200psi. 30min. Tbg. Press 2600psi. Annulus press. 4,200psi. F I 30min. loss 80psi.Bleed down Annulus & Tbg. RID secure well. Mobilize Johnson Tank and Choke Manifold TI SCU 312-09. Mobilize Pump truck to SRU 10/26/04 Remarks Move rig and all related equipment from 21-3 to 24A-05 pads. Layout boulderson and spot carrier, removed stand pipe. Move camp and generator, level and hook up same. Remove gas lift line from tree and blind same. Run power cables from generator and hook up. Start to raise derrick Sc.AN~!Er' NnV SCU 24A-05 morning report summary, CONFIDENTAL: last revised 11/10/2004 Page 2 10/27/04 ) Remarks Derrick in air and scoped out, moved in and spotted all 11" BOP equipment Move in and spot conex's, Continue to hook up electrical lines, ND Tree, inspect lift Set 9 x 11" Single gate, Double gate, Annular, DSA F/choke and kill. Set Swaco NU BOP had problems getting connections on either side of single gate tight due to studs Function test using both remote and koomey. Test Annular BOP 250 PSI low and 3500 Continue BOP test at 250 PSI low and 5000 PSI high. 10/28/04 Remarks Pulled test joint, removed BPV, installed TWC and tested blind rams to 250 PSI low and 5000 PSI high, bled pressure, open blinds and installed test joint with ported sub on bottom, closed lower pipe rams, and tested to 250 PSI low and 5000 PSI high, at the same time testing kill line valves. Bleed pressure off, remove test joint and pull TWC. Test floor and IBOP valves using blind ported sub to 250 PSI low and 5000 PSI high. Perform draw down test on koomey, 3000 PSI initial, 1800 PSI draw down, 21 sec first 200 PSI, 1 minute 28 second final 3000 PSI, N2 BU 1700, 1900, 1975, 2000 PSI. Pull TWC, Change out ported sub on bottom of test joint to make pulling joint, screw into hanger Layout herculite for containment at cellar area of rig, spot APRS unit, move drillersconsole to the upper level along with tugger controls, set stairs ,stair landing, v-door and catwalk rig up. Move and RU 3.5" handling equipment PU landing joint and MU in hanger, PU and unseat hanger, pull 58M to move,pipe, PU an additional 10M to 68M and set slips FIJet cut run RU APRS F jet cut run RIH 45' and set down on paraffin, attempt to work down with no luck POOH and dump in 5 gallons diesel, RIH and was able to work through. RIH W 2.25" GR to 3000 PSI Pooh RIH WI Jet cutter to 8000' and cut pipe good indication of firing, POOH and rig down PU on tubing to verify tubing is cut, all appears to be OK. Set back down on hanger RU circulating spool on top of bag, install hand rails on rig floor and safety chains Hook up flow line hose to shaker, pull hanger above rig floor Close bag and circulate BU to clean hole with lease water, had some dirty water coming back. Rd tubing hanger and lay down, clean pits and Johnson tank, install new stand pipe Pump 12.5 mud thru choke displacing H2O 13700 strokes, maintaining pump schedule. 'Conditioned and .. circulated in pits 10/29/04 (P&A) Remarks Condition and circulate mud in pits weighting up, continue to pump taking returns to rig pits monitoring weight until had 12.4 Heavy returns Set cat walk and pipe racks, prep to pull and lay down 14 joints of 3.5" eue tubing, had some u tubing, Mix dry job and pump Pull 1 joint of 3.5" EUE tubing, came to 2 pup joints and while working them conditioned and circulated in pits Took water on in pits and start to mix a 12.5 PPG mud system. Batched up approximately 60 BBL of 12.5 mud and circulate it monitoring returns with varied weights returning. Continued to repeat this process until we had 12.5 PPG going in and 12.4H returning. Broke kelly hose from floor valve and opened with a slight vacuum RU Foster tongs and start to pull 13 more joints of 3.5" EUE tubing laying down Transfer work over to recompletion AFE 162909 10/29/04 (Recomplete) Remarks Work on AFE 162951 RU SWS, RIH with HSD-WL-DP 2", 2006 Pj, HMX, 6 SPF Gun. Dropped down and using Atlas Segmented CBL dated 12-20-90 to correlate, perforate below the 77-3 sand at 7666' to 7672', log up into SCANNEL, NOV 1. 5 2004 SCU 24A-05 morning report summary, CONFIDENT AL: last revised 11/10/2004 Page 3 position above the 77-3 so..) and perforate at 7626' to 7632'. POOH Q)Shots fired, RD SWS Perform injection test at 0.5 BPM rate, pumped a total of 20 BBL's, with it breaking over at 2885 PSI. One minute after pump shut down pressure had fell back to 1922PSI, has a total of 7 BBL flow back POOH laying down 3.5" EUE tubing, first GLM did not have any pups had to lay down GLm with joint and break out on catwalk. 10/30/04 Remarks POOH laying down 3.5" tubing, GLM did not have pups, took some time to negotiate GLM's Recovered a total of 204 joints, 3 pup joints, and the tubing hanger. Recovered 3- 3.5" GLM's (6482.25') XO hanger to 2 7/8" EUE and land with TWC installed, RI LDS. Change upper and lower rams from 3.5" to 2 7/8" and test same to 250 PSI low and 5000 PSI high. POOH laying down 2 7/8" tubing. Recovered 48 joints 2 7/8" tubing, cut off joint 15.50' long, and 2 GLM's (1511.41) RU Schlumberger Wireline Services and RIH with 4.56" gauge ring and a junk basket. Set down at 7492' picked up with no additional drag, to 7300" set back down at 7492', picked up again with no additional drag set down a little harder this time went through. RIH to 7625' pick up and POOH to 7300', RIH to 7622' did not see any bobble at 7492'. POOH and lay down junk basket and gauge ring. RU Halliburton FasDrill cement retainer, conduct pre arming safety meeting. RIH with FasDrill cement retainer, correlate and set top of retainer at 7600' with the bottom of retainer at 7602.30'. Fired setting tool slow burn type took 55 seconds for tool to fire and scope out. Pinched up 20 feet with no additional weight and set back down on retainer to verify that it was set. POOH and rig down . Change upper and lower pipe rams from 27/8" to 3 1/2", add 2 1/16" 5M valve to inlet side of choke manifold. Test rams and valves to 250 PSI low and 5000 PSI high. . SCANNED NO\! 1 5 2004 SCU 24A-05 morning report summary, CONFIDENTAL: last revised 11/10/2004 Page 4 ~.l ri'& YUrt. ~L. ... ~uì ! ~ rv ¡ Un \ ! I......, \ .....} ¡ I '-;;;.,/. '-" ~ _:.....! r(lJ ~~ r' ) ,,~.;' /flJ~ /~'-/ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 w. "JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 22,2004 Mr. Philip J. Krueger Drilling Manager U nocal Alaska PO Box 196247 Anchorage AK 99509-3330 RE: Swanson River Field W orkover HOPE Configuration Dear Mr. Krueger: Per 20 AAC 25.285 (h), the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska ("Unocal")'s request for variance from the workover blowout prevention equipment ("BOPE") requirements of 20 AAC 25.285 (c) and ( e), during operations on wells in the subject field. This variance is applicable to Swanson River Field wells SCU 32-08, SCD 33-33, SCU 312-09, SCU 24A-05, SCU 21-03, SRU 23-27, and SRU 32A-15. AOGCC finds that Unocal's requested variance provides at least an equally effective means of ensuring well control as that required by regulation. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a h<1Ü.day or weekend. A person may not appeal a Commission decision to Superior Court y1Ílesj,rehearing has been requested. ( SCANNED OCT 10 2Q04 ~ ~ ~1f~1fŒ (ID~ ~~~~[K\!Æ AI,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Philip J. Krueger Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Swanson River SCU 24A-05 Sundry: 304-348 Dear Mr. Krueger: 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 followíng 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. BY ORDER OF THE COMMISSION DATED this /" day of September, 2004 Enc!. ~ STATE OF ALASKA ~ ALASK )IL AND GAS CONSERVATION COMMI~ IN APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 \N4~ 'I I \4-( z-oo'{ p~ 11!rf-/Cf- 1. Type of Request: Abandon ~ Suspend U Operational shutdown U Perforate U Waiver U Annular Dispos. U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 / Perforate_~ew Pool [] Recomplete 77-03 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: J't:V Union Oil Company of California Development [] Exploratory 0 ~O111 e ~/ « 3. Address: Stratigraphic 0 Service 0 6. API Number: .' PO Box 196247, Anchorage, AK 99519 50-133-20256-01 / 7. KB Elevation (ft): 9. Well Name and Number: 25.85' RKB SCU 24A-05 / 8. Property Designation: 10. Field/Pools(s):,~ ;:) Soldotna Creek Unit Swanson River Field/';YÔ~~k, Hemlock 11. PRESENT WELL CONDITION SUMMA~ ---- Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,790' 10,761 9,740' 9,715' Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 18" 91' 90' Surface 3,390' 10-3/4" 3,390' 3,389' 3,130 psi 1,580 psi Production 7,090' 7-5/8" 7,090' 7,077' 6,020 psi 3,400 psi Liner 3,453' 5-1/2" 1 0, 175' 10,148' 9,190 psi 8,830 psi Liner 1,091' 2-7/8" 10,790' 10,761' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,344 to 10,668 10,317 to 10,640 3-1/2"; 2-7/8" N-80/L-80; N-80 6,498'; 9,650' Packers and SSSV Type: Baker Mod F-1 size 40-30 Packers and SSSV MD (ft): 9,651' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [] Service 0 14. Estimated Date for ~004 15. Well Status after proposed work: Commencing Operations: Oil 0 Gas [] Plugged 0 Abandoned 0 16. Verbal Approval: Date: -=' WAG 0 GINJ 0 WINJ 0 WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler (907-263-7649) Printed Name Philip J. Krueg~ Title Drilling Manager Signature C dA. ~ ~..t" PhnnA 907-276-7600 Date 9/13/2004 7' ,;- ./ { COMMISSION USE ONLY , Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .30c{ - 3'-1~ Plug Integrity D BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RECEIVED Other: RBDMS BF l SEP 1'6 ~ SEP 1 3 2004 S,b""",tF", Rh I 0 - 40 7 Alaska Oil & Gas Cons. Commission Anchorage ,(4 " BY ORDER OF '¡¡/o'l / Approved by: l) 'If COMMISSIONER THE COMMISSION Date: t ~-4¥eviSed INSTRUCTIONS ON REVERSE ~ bmit i~ Dup~cate Forr' 2003 ORIGINAL /" \(?~1'\~ ~ ~ Workover Summary seu 24A-O5 . MIRU Slickline. co GL V's to Dummies. RI GR to ETD. RD. . MIT csg to 1500 psi. / . MIRU Production hoist. . ND tree. NU BOPE. PT Same. / . Pull BPV. MU Landjoi~. PU on tbg string. Rotate anchor out ofpkr. CBU. . RU Dowell. Mfx 25 ~.. 25 s ofG Neat cmt. Circ/lay-in cmt below EOT. Sqz cmt away to P&A Hemloc~ . POOH stand-back tbg string (LD GLM's). . Jug test P&A to 1500 psi. RU slickline. RIH tag TOC. RD. / . PU Retrievable BP, 6' pup & Champ pkr. RIH w/ 2-7/8" tbg. Continue RIH w/ 3-1/2" tbg to 7700'. Set BP. PU to 7640'. Set pkr. test same. . RU Eline. RIH perf sqz holes @ 7697' - ~7 669' - 7675'. Establish injection rate & pressures. Mix/pump/sqz 500sx~s) of cmt out sqz holes.. . WOC 3 ills. RI reverse circulate excess cmt out to BP @ 7700'. PU to 7600'. Set pkr. WOC f/ 8 ills more. Pressure test sqz perf. If applicable, identify failed sqz perfs. / Isolate same. Perf and re-squeeze if necessary. RI latch BP. Unset same. . POOH LD tbg. . RU Eline RIH log sqz interval w/ CBL. POOH RD. . RIH w/ completion. Land tbg. Set FH pkr @ 7570'. . ND BOPE. NU Tree. Pressure test same. /' . RD Demobe rig. . MIRU Slickline & N2. Open SS. POOH. Displace fluid in tbg w/ N2. RI w/ SL. Close SS. POOH. N2 & SL.. . RU Eline RIH perf 77-3 sand @ 7676' - 7686'. POOH RD Eline. UNOCALti> ~ ~ Swanson River Well SCD 24A-05 As Completed on 9/13/02 Hole Cmt Cmt To Yes Surf. Surf 3,390' 15" 1263 sx 1450' Calculated Surf 34' 34' 117' 359 sx 6130' 117' 3945' 9-7/8" Tbru DV @ CBL 3945' 5878' 7438' 5878' 7027' 7027' 7090' 6722' 10,175' 9699' 10790' RKB =25.85' e Wt ...¡ .. u @ @ ~ ~. .g .." ..¡" ,,@ "'u g )~ "' . '" . '" ~~ ¡g "'.. TD= 10,790' PBTD= 10,745' Max Deviation = 11.20 @6,900' Size 18" Cas i n Grade ID T Conductor 10-W' 40.5 K-55 10.050 6.875 N-80 6.765 6.875 6.875 polIO 6.765 SurfCsg 7-5/8" 26.4 7-5/8" 33.7 7-5/8" Prod Csg 26.4 7-5/8" 29.7 7-5/8" 33.7 7-5/8" Window. Cut on 11/14/90 5-112" 2-7/8" Liner JEWELRY DETAIL NO. O~h ID 00 Item 25,85' - - Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, TVDe "H" BPV Profile GLM #1. 2,375' 2.867 5.968 GLM, 3-1/2" Otis, "Thru Guide", 1-1/2". RA Latch GLM #2. 3,989' 2.867 5.968 GLM, 3-1/2" Otis, "Thru Guide", 1-1/2" RA Latch GLM #3. 5,416' 2.867 5.968 GLM. 3-1/2" Otis, "Thru Guide", 1-1/2" RA Latch 1. 6,497' 2.410 4.44 Crossover, 3-1/2" EUE 8rd Box x 2-7/8" EUE 8rd Pin GLM #4. 6,499' 2.347 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch GLM #5. 7,825' 2.347 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch GLM #6. 8,842' 2.347 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch GLM #7. 9,613' 2.347 4.5 GLM. 2-7/8", BST, GLMAX, I", BK-2 Latch 2. 9,650' 2.440 3 Tubing Anchor, Baker Mod. EBH-22 3. 9,651' - - Packer, Baker Mod. F-I, Size 40-30 4. 9,659' 2.441 - Crossover,4' 10 rd Box x 2-7/8" EUE 8rd Pin 5. 9,691' 2.313 - X Nipple, (2.313" 1.0.) 6. 9,698' 2.45 - Baker Overshot 7. 10,463' 2.313 - X Nipple, (2.313" 1.0.) I 6574' TIW Liner top pkr. Stuck while RIH. 10/9/73 12/24/90 FISH PERFORATION HISTORY (DIL Depths) Interval AcCUßL Date Zone Top Btm Amt spf Conunents Mar-OO H-2 10,344' 10,354' 10' 6 Powetjet HC, 60 deg. Mar-OO H-3 10,378' 10,388' 10' 6 Powetjet HC, 60 deg. Mar -00 H4 10,392' 10,445' 53' 6 Powetjet HC, 60 deg. Apr-91 H-6 10,453' 10,465' 12' 4 Apr-92 H-6 10,453' 10,465' 12' 4 Reperf Mar-OO H-8 10,476' 10,486' 10' 6 Powetjet HC, 60 deg. Feb-91 H-8 10,486' 10,512' 26' 4 Mar-OO H-8 10,512' 10,554' 42' 6 Powetjet HC, 60 deg. Jan-91 H-9 10,566' 10,582' 16' 4 Mar-99 H-IO 10,601' 10,640' 39' 4 2-1/8" HC, 0 deg. Dec-98 H-IO 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. seD 24A-05 Actual Schematic 913022 REVISED: 6/3/2004 by SL T UNOCAL8 RKB =25.85' A TD= 10,790' PBTD= 10,745' Max Deviation = 11.20 @ 6,900' / ~ .~ Swanson River Well SeD 24A-05 As Completed on 9/13/02 Hole Cmt Cmt To Yes Surf. Surf 3,390' IS" 1263 sx 1450' Calculated Surf 34' 34' 117' 359 sx 6130' 117' 3945' 9-7/8" Thru DV @ CBL 3945' 5878' 7438' 5878' 7027' 7027' 7090' 6722' 10,175' 9699' 10790' 7000' I PROPOSED I Cas i n Size T e Wt Grade ID 18" Conductor 10-%" SurfCsg 40.5 K-55 10.050 7-5/8" 26.4 6.875 7-5/8" 33.7 N-80 6.765 7-5/8" Prod Csg 26.4 6.875 7-5/8" 29.7 6.875 7-5/8" 33.7 P-IIO 6.765 7-5/8" Window. Cut on 11/14/90 5-1/2" 2-7/8" Liner Liner Tubin 2 y,", Mod Butt JEWELRY DETAIL NO. Depth ID OD Item 25.85' - - Tubing Hanger, Shaffer, 3-1/2" EVE 8rd Mod. Lift Thread x 3-1/2" EVE 8rd Mod. SusDension Threads, Tvne "H" BPV Profile 1. 9,651' - - Packer, Baker Mod. F-I, Size 40-30 2. 9,659' 2.441 - Crossover,4'IOrdBoxx2-7/8"EVE8rdPin 3. 9,691' 2.313 - X Nioole, (2.313"1.0.) 4. 9,698' 2.45 - Baker Overshot 5. 10,463' 2.313 - X Nioole, (2.313"1.0.\ I 6574' TlW Liner lop pkr. Sluck while RIH. A. 2400' Chemical Injection Mandrel B. 7560' 2.313 Sldg Sive C. 7570' Hyd Rei Pkr D. 7608' 2.313 X Profile Nipple E. 7640' WLEG 10/9/73 12/24/90 to 3100 si. Ne ative test FAILED. FISH PERFORATION HISTORY (D I L Denths) Interval ACCUßL Date Zone Top Btm Amt spf Comments I Sqz Holes 7,669' 7,675' 6' 4 Pr Perfs 77-3 7,676' 7686' 10' 6 PrnnrniHI 77-3 Sand Perls I Sqz Holes 7,697' 7,703' 6' 4 P Perls Mar-oo H-2 10,344' 10,354' 10' 6 PoweJjet HC, 60 deg. Mar-OO H-3 10,378' 10,388' 10' 6 Powerjet HC, 60 deg. Mar-OO H-4 10,392' 10,445' 53' 6 Powerjel HC, 60 deg. Apr-91 H-6 10,453' 10,465' 12' 4 Apr-92 H-6 10,453' 10,465' 12' 4 Reperf Mar-oo H-8 10,476' 10,486' 10' 6 PoweJjel HC, 60 deg. Feb-91 H-8 10,486' 10,512' 26' 4 Mar -00 H-8 10,512' 10,554' 42' 6 Powerjet HC, 60 deg. Jan-91 H-9 10,566' 10,582' 16' 4 Mar-99 H-IO 10,601' 10,640' 39' 4 2-1/8" HC, 0 deg. Dec-98 H-IO 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. seD 24A-05 Proposed Rig WO _060304 REVISED: 6/3/2004 by SL T Workover Summary: ) I qo -- 144- so4~ ~4.f ) 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Prep-Work- RU sliekline retrieve Dummy from GLM#11 @ 9613'. Gauge tbg to 9650'. RD. Prep-Work- RU Eline RIH set HES EZ Drill emt retainer wI Dual eheek valves @ 9,630'. RD Eline. Establish injection rate and pressures down tbg through cmt retainer. CT- RU Coil equip. PT BOPE. RIH wI cmt stinger on 1-1/2" CT. stab into retainer @ 9630', CT - RU cementers. Mix/pump 25 bbls of "G" Neat cmt. Displace 13 bbls of cmt below retainer with lease water. PU above retainer. Lay-in remaining 12 bbls of cmt above pkr. POOH. RD CT. (estimate TOC @ 8811') Prep-Work- WOC 12 hrs. RU Slickline. Gauge tbg to TOC. Pressure test P&A to 2000 psi. MIT tbg x csg annuli to 4200 psi while maintaining 2000 psi on tbg. woe - 12 hours SWITCH TO RECOMPLETION AFE Mobe Nabors Rig #26 to Location. Mobe/Spot WO Rig & equip. on liner. Berm in same. RIG - Install BPV. ND tree & flowline. Inspect hngr threads. NU BOPE w/3-1/2"x2-7/8" VBR. RIG - MU 3 1/2", 8rd landing joint. Test rams, choke/killlines & accumulator. BO landing joint. RIG - Recover BPV. Install TWC valve & test blind rams. Recover TWC. MU landing joint to hngr. BO hold down pins. Unseat hngr. RIG - RU Eline. RIH cut tbg @ :1:8000'. POOH. RD. PU CBU. Displace wellbore wI 12.5 ppg mud. Pull EOT up to 7600'. EL - RU Eline. RIH Correlate/Perf sqz holes @7666'- 7672' & 7626'-7632' Establish injection rates and pressures. RD Eline. Monitor well. RIG - POOH. LD 3 %" tubing and 2 7/8" tbg string. (LD GLMs) EL - RU Eline. RIH with FasDrill Retainer. Set @7660'. RD Eline. CMT -PU/MU stinger. PU 3-1/2" PH-6 workstring. RIH. Stab into Ret. Mix/pump/sqz 250sx (50bbls) of cmt out sqz holes. PU above Ret. Reverse CBU. POOH. WOC 12 hrs. RIG - PU/MU drilling assy RIH drill/CO Ret and Cmt to 7720'. PT emt sqz to 2000 psi. POOH. EL - RU Eline. RIH wI SCMT to 7700'. POOH Logging to 4700'. POOH. RD. RIG - PU/MU 5-1/2" RTTS pkr. RIH 17 stands. PU/MU HES Surge Valve. Continue RIH. Set RTTS @ 7550'. Pressure test pkr. Open surge valve to negative test sqz perfs. Monitor well. POOH LD workstring and BHA. RIG - PU/MU TCP guns, completion pkr and jewelry. RIH on 2-7/8" tbg. Eline correlate/space- out from TCP guns wI top shot at 7676' and CIM @ 2500'. Land tbg in hngr. WL - RU slickline. RIH wI N test tool to BXN Nipple. Set Pkr. Test tbg to 4500 psi. Test pkr annulus to 2000psi. POOH wI plug. RD. RIG - Install BPV. ND BOPE.NU tree. Test same. Demobe Rig. WL - RU slickline. RIH open CMU sliding sleeve. POOH. Mix/pump annular volume (270 bbls) of lease water w/CRW 132@ 1% wI Oxygen Scavenger. N2 - RU N2 equipment. Displace fluid in tbg wI N2 through CMU sldg slve. RI close sleeve. Trap pressure. RD Slickline, pump & N2 equipment. Drop bar. Perforate 77-3 sand @ 7630' to 7640'. woe -12 hours Secure operations. Turn well over to production. RKB =25.85' II ~I ~) ~ ) I PROPOSED I Casing & Tubing Size Type Wt Grade ID Top Btm ~ 18" Conductor Surf 91' 10-3;4" Surf Csg 40.5 K-55 10.050 Surf 3,390' 7-5/8" 26.4 6.875 Surf 34' 7-5/8" 33.7 N-80 6.765 34' 117' ~ 7-5/8" Prod Csg 26.4 6.875 117' 3945' 7-5/8" 29.7 6.875 3945' 5878' 7-5/8" 33.7 P-ll0 6.765 5878' 7027' 7-5/8" Window. Cut on 11/14/90 7027' 7090' 5-1/2" Liner 20 N-80 4.778 6722' 10,175' 2-7/8" Liner 6.5 N-80 2.441" 9699' 10,790' Tubing 2 ',',". '1nti BUll I to.'¡ :\ .;;;0 I 2.'¡~1 I ..;.lIrf I Îh-lO' ; II I I u NO. Denth 25.85' 1. 9,651' 9,659' C 2. 9,691' 3. 9,698' tin 4. 10,463' .. ¡: 6574' A. 2400' ..., ß. 7560' C. 7570' D. 7608' :E. 7640' :F. Swanson River Well seu 24A-05 As Completed on 9/13/02 Hole Cmt Cmt Top Yes Surf 15" 1263 sx 1450' Calculated 359 sx 6130' 9-7/8" Thru DV @ CBL 7438' ="'''^"''' ~ I !tj!Uf~~I~I!I!i';~Ji]lill¡~ 6-112" 250 sxs 8800' CBL 9740' :-. :~;~:~:.t.:.t~ .{:.*~~}::~. f:~~~, ~H~~~~~~~~.~~.t~~r~:~:~~ . ;'.:':¡t::: ~:..:~ ~\~ ~biF~;~~~:;t~i~~~:. 4-7/8" JEWELRY DETAIL on hem Tubing Hanger, Shaffer, 3-112" EUE 8rd Mod. Lift Thread x 3-112" EVE 8rd Mod. Suspension Threads, Type "H" BPV Profile Packer, Baker Mod. F-l, Size 40-30 Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin X Nipple, (2.313" I.D.) Baker Overshot X Nipple, (2.313" I.D.) II) 2.441 2.313 2.45 2.313 2.313 nw Liner top pkr. Stnc.!,; while JU.H. Chemical Injection Mandrel Sldg Slve BOT "I"H" Ref Pkr 2.25 XN Protile Nipple, size 2.313" \VLEG HES TCP GUllS 10/9/73 12/24/90 BrIef History Originally Drilled and completed as a Hemlock Producer ReDrilled as a Hemlock Producer. Pressure tested liner lap to 3100 psi. Negative test FAILED. Tbg stub @ 9699' has been problematic to enter Tbg Plug @ 10,677' FISH PERFORATION HISTORY (nIL Depths) Interval Accum. Date Zone Top Btm Amt spf Comments Sqz Holes 7,669' 7,675' 6' 4 Proposed Sqz Perfs 77-3 7,676' 7,686' 10' 6 Proposed 77-3 Sand Sqz Holes 7,697' 7,703' 6' 4 Proposed Sqz Perls Mar-OO H-2 10,344' 10,354' 10' 6 Powerjet HC, 60 deg. Mar-OO H-3 10,378' 10,388' 10' 6 Powerjet HC, 60 deg. Mar-OO H-4 10,392' 10,445' 53' 6 Powerjet HC, 60 deg. Apr-91 H-6 10,453' 10,465' 12' 4 Apr-92 H-6 10,453' 10,465' 12' 4 Reperf Mar-OO H-8 10,476' 10,486' 10' 6 Powerjet HC, 60 deg. Feb-91 H-8 10,486' 10,512' 26' 4 1D= 10,790' PB1D= 10,745' Mar-OO H-8 10,512' 10,554' 42' 6 Powerjet HC, 60 deg. Max De\iation =11.20 @6,900' Jan-91 H-9 10,566' 10,582' 16' 4 Mar-99 H-10 10,601' 10,640' 39' 4 2-118" HC, 0 deg. Dec-98 H-I0 10,640' 10,668' 28' ! 4 2-1/8" HC, 0 deg. seD 24A-05 Proposed Rig WO_060304-1.doc REVISED: 6/3/2004 by SL T Swanson. River Well seu 24A-05 As Completed on 9/13/02 ) ) Casing & Tubing RKß =25.85' Size Type Wt Grade ID Top Btm I - -L 18" Conductor Surf 91' 10-%" SurfCsg 40.5 K-55 10.050 Surf 3,390' 1 <:. 7-5/8" ~ 6.875 Surf 34' ~ 7-5/8" 33.7 N-80 6.765 34' 117' ~ 7-5/8" Prod Csg 26.4 6.875 117' 3945' ~ 7-5/8" 29.7 6.875 3945' 5878' 7-5/8" 33.7 P-11O 6.765 5878' 7027' 7-5/8" Window. Cut on 11/14/90 . 7027' 7090' 5-112" Liner 20 N-80 4.778 6722' 10,175' 2-7/8" Liner 6.5 N-80 2.441" 9699' 10,790' Tubing 3-Yz", EUE 8rd Mod. I 9.3 I N-801L-80 I ~ 99~ I 'urt" I 6.195;' ...:I 2 Ys", EUE 8rd Mod. 6.4 N-80 ~.-I'¡I ~-I99. 9650 e => '" ~ @) u 0 ¡.. I I I Hole Cmt Cmt Top Yes Surf 15" 1263 sx 1450' Calculated 359 sx 6130' 9-7/8" ThruDV@ CBL 7438' il1Hf ]¡ÎJf:llj~EJII Tnmn¡8¡ 6-1/2" 250 sxs 8800' CBL 4-7/8" 9740' I;'¡:~:~;f;~!r~.:' ';'ÛJ;~:,,~!~f11ii~;;; JEWELRY DETAIL on hem Tubing Hanger, Shaffer, 3-112" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Type "H" BPV Profile 5.968 GLM, 3-112" Otis, "Thru Guide", 1-112", RA Latch 5.968 GLM, 3-112" Otis, "Thru Guide", 1-112" RALatch 5.968 GLM, 3-112" Otis, "Thru Guide", 1-112" RA Latch 4.44 Crossover, 3-1/2" EUE 8rd Box x 2-7/8" EUE 8rd Pin 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch 4.5 GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch 4.5 GLM, 2-7/8", BST, GLMAX, I", BK-2 Latch 3 Tubing Anchor, Baker Mod. EBH-22 Packer, Baker Mod. F-1, Size 40-30 Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin X Nipple, (2.313" LD.) Baker Overshot X Nipple, (2.313" LD.) NO. Ucpth 25.85' IO 2,375' 3,989' 5,416' 6,497' 6,499' 7,825' 8,842' 9,613' 9,650' 9,651' 9,659' 9,691' 9,698' 10,463' 6574' GLM #1. GLM #2. GLì\1 #3, 1. CLiVI #4. G.L.M #5. GLrH #6. (;L\1 #7. 2. 3. 2.867 2.867 2.867 2.410 2.347 2.347 2.347 2.347 2.440 ~'8 oqg oj@) Uu :~, ~~,~~ ,;.- ~.'J' ,,~ ~~,~ - -I -.... -; ~." :'~, ~ ~ ~5 ~~:t: ~ ~ 2.441 2.313 2.45 2.313 4. 5. 6. TIW Liner top pkr. Stuck while RIH. I BrIef History 10/9/73 Originally Drilled and completed as a Hemlock Producer 12/24/90 ReDrilled as a Hemlock Producer. Pressure tested liner lap to 3100 psi. . Negative test FAILED. Tbg stub (â), 9699' has been problematic to enter PERFORATION HISTORY (niL Depths) Interval Accum Top Btm Amt spf 10,344' 10,354' 10' 6 10,378' 10,388' 10' 6 10,392' 10,445' 53' 6 10,453' 10,465' 12' 4 10,453' 10,465' 12' 4 10,476' 10,486' 10' 6 10,486' 10,512' 26' 4 10,512' 10,554' 42' 6 10,566' 10,582' 16' 4 10,601' 10,640' 39' 4 10,640' 10,668' 28' 4 Conunents Powerjet HC, 60 deg. Powerjet HC, 60 deg. Powetjet HC, 60 deg. Date Mar-OO Mar-OQ Mar-OO Apr-91 Apr-92 Mar-OO Feb-91 Mar-OO Jan-91 Mar-99 Dec-98 Zone H-2 H-3 H-4 H-6 H-6 H-8 H-8 H-8 H-9 H-1O H-10 Reperf Powetjet HC, 60 deg. Powerjet HC, 60 deg. 2-118" HC, 0 deg. 2-118" HC, 0 deg. TD= 10,790' PBTD= 10,745' Max Deviation = 11.20 @6,900' REVISED: 6/3/2004 by SL T seD 24A-05 Actual Schematic 91302-2.doc r , II II I I ~'1 ~SA ~ =R"~~ m - - I ,_.. I I ~ II Pipe Ram II I I I UNOCAL SWANSON SCU 24A-05 ~ ~ ~ , ~ ~ I I II Pipe Ram I I II Blinds I II !!m!w 11" SM Hydril Annular BOP !¡!¡!¡~r 11" SM Shaffer LWS Double BOP :¡:::¡:~: 11" SM Drilling Spool wI 2 ea 4" SM OTL !¡!!!!~r 2 1/16 SM Manual Gate Valve ))))'1'1: !t!!~l2 1/16 SM Manual Gate Valve !i¡j¡illi: DSA 4" 5M x 3" SM ¡!¡!¡!~¡ DSA 4" SM x 2" 5M j'j'j'jïj'j- !!!!!!!a.! 2 1/16 5M Manual Gate Valve :!:!i!~: 21/16 5M HCR Valve ¡¡ï¡\~r 11" SM Shaffer L WS Single BOP 1]11" SM Hydril Annular SM Studded Top and Flanged Bottom ~ ~ [1]11" 5M Shaffer LWS DBL ~ 3111" SM Drilling Spool w/2 ea 4" SM OTL ~ D11" 5M Shaffer lWS DBl .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unoin Oil Company of California (UNOCAL) Development: X 164' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519-6247 Service: Soldotna Creek Unit 4. Location of well at surface Conductor #21 8. Well number 1,058' FSL, 1,497 FEL, Sec. 5, T7N,R9W,SM SCU 24A-5 At top of productive interval 9. Permit number/approval number 1,104' FSL, 2,277' FEL, Sec. 5, T7N, R9W SM 73-21,90-144 At effective depth 10. APl~.~ber 50-J-74:3.-20256-01 At total depth 11. Field/Pool 1,107' FSL, 2,308' FEL, Sec. 5, TTN, R9W SM Soldotna Creek Field / Hemlock 12. Present well condition summary Total depth: measured 10,790' feet Plugs (measured) true vertical 10,762, feet Effective depth: measured 10,745' feet Junk (measured) true vertical 10,717' feet Casing Length Size Cemented Measured depth True vertical depth Structural 18" Driven 91' 91' Conductor Surface 3,390' 10-3/4" 1,236 sx 3,390' 3,390' Intermediate 7,027' 7-5/8" 395 sx 7,027' 7,014' Production 3,453' 5-1/2" 250 sx' 6,722'-10,175' 6,715'-10,147' Liner 1,092' 2-7/8" 17 bbls Class G 9,698'-10,790' 9,672'-10,762' PeRoration depth: measured 10,453'-10,463'; 10,486'-10,512'; 10,564'-10,580'; 10,640'-10,668' true vertical 10,425'-10,435'; 10,458'-10,484'; 10,536'-10,552'; 10,611 '-10,639' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 6,473' R cCI IVED 2-7/8", 6.5~, N-80 6,473'-9,698' Packers and SSSV (type and measured depth) TIW Liner Top Packer 6,522'; OCT 2 1 ~002 Baker F-1 Packer 9,651' 13. Stimulation or cement squeeze summary none ~aSl(~l 0it & Gas Cons. Commission Intervals treated (measured) ,i~[rlc[10ra0e none Treatment description including volumes used and final pressure none 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 87 0 31 1100 250 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: .,,. _ _ - Title: C ~,.~'!',,J ~ ~,,'~'.X~,~'"~i Date: / ~'* "- / & - (~-~ Form 10-404 Rev 06/15/88 £UU~ SUBMIT IN DUPLICATE ~..~. D ate 8/12/02 9/10/02 9/11/02 9/12/02 9/13/02 9/14/02 9/15/02 9/16/02 9/17/02 9/18/02 .Summary_ Daily Report of Well Operations SCU 24A-5 Workover to Install Gas Lift String AFE #156467 RU Slickline. Install PX Plug and prong in X-Nipple at 9691' (below permanent production packer). Dump Bail Calcium Carbonate on top of prong. RD Slickline. Rig moved to Well SCU 24A-5 AFE at 19:00 hrs on 9/10/02. RU Nabors Rig 126. Pressured tested BOPs to 250 psi low 3000 psi high. Chuck Scheve, AOGCC Petroleum Inspector, waived the State requirement to witness the test. Prep to pull tbg. Rotate anchor out of packer at 9650'. POOH with 3-1/2" and 2-7/8" tbg. Install new anchor. RIH with 2 7/8" & 3 ½" tbg & new gas lift mandrels. RIH and locate packer for space out. Installed hanger & land 6k down on anchor when hanger seated. RU & tested tbg & seal asSembly to 1000 psi for 15 min. Test hanger & seals to 1500 psi for 15 min. ND BOPs. Cont ND BOPs. NU tree. Prep rig for release. Release rig at 12:00 hrs. 9/14/02. Prepare to move to Well SCU 43B-8. RU Slickline. Bail Calcium Carbonate off of plug. SDFN. Cont. bailing. Latch prong, unable to pull. Shear off. Gas lift well to lessen differential pressure across prong. Recover prong and Plug Body. RD Slickline. Return well To Production. UNOCAL Tubing stub problematic to enter! 9 10~ 11 12 13 14 15 H6 H6 H8 H9 H10 Swanson River Well SCU 24A-5 Actual Completion 9/13/02 CASING AND TUBING DETAIL SIZE XVT GRADE CONN ID TOP BTM. 18" 10--3/4" 40.5 K-55 BTC 7-5/8" 26.4 N-80 BTC 7-5/8" 33.7 N-80 BTC 7-5/8" 26.4 N-80 BTC 7-5/8" 29.7 N-80 8rd LTC 7-5/8" 33.7 P-110 8rd LTC 5-1/2" 20 N-80 FL4S 2-7/8" 6.5 N-80 ? Tubing 3-1/2" 9.3 N-80 (Re-ran) EUE 8rd Mod 2-7/8" 6.5 N-80 (Re-mn) EUE 8rd Mod. 91' Surface 3,390' Surface 34' 34' 117' 117' 3,945' 3,945' 5,878' 5,878' 6,722' 6,722' 10,175' 9,699' 10,790' 2.881 25.85 6,499' 2.441 6,473' 9,650' JEWELRY DETAIL NO. Depth II) OD Item 1 25.85' 2 2,375' 2.867 3 3,989' 2.867 4 5,416' 2.867 5 6,497' 2.410 6 6,499' 2.347 7 7,825' 2.347 8 8,842' 2.347 9 9,613' 2.347 10 9,650' 2.440 11 9,651' - 12 9,659' 13 9,691' 2.313 14 9,698' 2.45 15 10,463' 2.313 5.968 5.968 5.968 4.44 4.5 4.5 4.5 4.5 3 Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Type "H" BPV Profile GLM, 3-1/2" Otis, "Thru Guide", 1-1/2", RA Latch GLM, 3-1/2" Otis, "Thru Guide", 1-1/2" RA Latch GLM, 3-1/2" Otis, "Thru Guide", 1-1/2" RA Latch Crossover, 3-1/2" EUE 8rd Box x 2-7/8" EUE 8rd Pin GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch GLM, 2-7/8", BST, GLMAX, 1", BK-2 Latch Tubing Anchor, Baker Mod. EBH-22 Packer, Baker Mod. F-I, Size 40-30 Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin X Nipple, (2.313" I.D.) Baker Overshot X Nipple, (2.313" I.D.) With PX Plug Notes NO. Depth Item I +/- Liner Top Packer, TIW, Stuck when RIH ~q ~'TA' PERFORATION HISTORY (DIL Depth) I ] I Interval Accum. Date Zone Top I Btm Amt spf Comments 4/91 H-6 10,45Y I 10,465' 12' 4 4/92 H-6 10,453' 10,463' 10' 4 Reperf 2/91 ] H-8 10,486' 10, 512' 26' 4 1/91I H-9 10,566' 10,582' 16' 4 12/13/98 H-10 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. PBTD = 10,745' TD = 10,790' MAX HOLE ANGLE = 11.2 deg. ~ 6,900' SCU 24A-5 Act Draw 9-13-02.doc DRAWN BY: tcb REVISED: 10/2/02 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCALe) Tuesday, September 3, 2002 Commissioner Cammy Taylor AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Swanson River Form 10-403 SCU 24A-5 Gas Lift Install Dear Commissioner Taylor: Please find the enclosed 10-403 for the installation of additional gas lift mandrels in SCU 24A-5. The well is completed in the Hemlock with a 2-7/8" x 3-1/2" tubing string and two gas lift mandrels. The workover will consist of pulling and standing back the existing tubing and then re-running the same pipe with additional gas lift mandrels. The workover will be performed with a plug in place at 9691' MD (above the Hemlock perforations) and the well loaded with fluid to surface. The Hemlock Reservoir pressure in this area is estimated at 1,400 psi at 10,400' TVD. Attached you will find the procedure, schematics and the proposed BOPE configuration. The BOPE configuration proposed is the same as recently approved for use on SRU 32-33 and is currently being employed on SCU 33-33. If you have any questions, please contact me at 263-7657. Sincerely, Tim Brandenburg scANNED SEP STATE OF ALASKA ; ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: X Perforate: Other: ;~. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 164' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface ~/" ,¢ ~-' 8. Well number 1,058' FSL, 1,497 FEL, Sec. 5, T7N,R9W,SM SCU 24A-5 At top of productive interval 9. Permit nJ,I/nber 1,104' FSL, 2,277' FEL, Sec. 5, T7N, R9W SM ,~, ~"~ t C~O ""' ~,L~LI~ ~ At effective depth 10. APl number ~/" 50- 133-20256-01 At total depth 11 ' Field/Pool 1,107' FSL, 2,308' FEL, Sec. 5, T7N, R9W SM Swnason River Field / Hemlock 12. Present well condition summary Total depth: measured 10,790' feet Plugs (measured) true vertical 10,762, feet Effective depth: measured 10,745' feet Junk (measured) true vertical 10,717' feet Casing Length Size Cemented Measured depth True vertical depth Structural 91' 18" Driven 91' 91' Conductor Surface 3,390' 10-3/4" 1,236 sx 3,390' 3,390' Intermediate 7,027' 7-5/8" 395 sx 7,027' 7,014' Production 3,453' 5-1/2" 250 sx 6,722'-10,175' 6,715'-10,147' Liner 1,092' 2-7/8" 17 bbls Class G 9,698'-10,790' 9,672'-10,762' Perforation depth: measured 10,453'-10,463'; 10,486'-10,512'; 10,564'-10,580'; 10,640'-10,668' true vertical 10,425'-10,435'; 10,458'-10,484'; 10,536'-10,552'; 10,611'-10,639' ! . ' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 6,473' 2-7/8", 6.5#, N-80 6,473'-9,698' Packers and SSSV (type and measured depth) TIW Liner Top Packer 6,522'; Baker F-1 Packer 9,651' 13. Attachements Description summary of proposal: Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 9/7/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify-'"'-~ ,- that the forego,~s true and ~~o the best of my knowledge. Signed:' ~---~'~-' ///~~ Title: (~-~" ~ ~ ~,~L~'T"- Date: ~- ~ ~'"__ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represe.ntative may witness %~. ¢.. O,,~ ~k~'-~ ~¢,~,,r,.?~ IApproval No. Plug integrity BOP Test '~ Location clearance ~,.~..~._. II ~.~ ~_.... ~ ~_.~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Commissioner . ..: .; ;.::-::,'-~'.% ~T".~. . . ~.l'lf"l~) Form 10-403 Rev 06/15/88 ORIGINAt SEi 002 SUBMIT IN TRIPLICATE BOPE Variances Unocal Swanson River Unit August - September 2002 In order to operate Nabor's Well Service Rig 26 in Alaska, Unocal requires several variances to the requirements at 20 AAC 25.285. This approval is specific to the wells listed below. Due to the specific well type or work performed in advance, the chance to encounter hydrocarbons that can flow to surface is remote. Work on other well types using these specific waivers is not approved. SRU 32-33 WD WO SCU 13-34 WO SCU 33-33 WO ~ SCU 24A-5 WO SCU 43B-8 WO SCU 21B-16 WO SRU 32A-15 WO - Replace Tubing/Packer - Replace Rod Pump - Repair Rod Pump - Install additional gas lift ~ -Abandon Hemlock (?) Recomplete in Tyonek - Abandon Hemlock and recomplete in Tyonek - Replace corkscrewed tubing Unocal requested an exception to 20 AAC 25.066 to allow using a single LEL gas meter. Gas detection must comply with 25.066 for methane and H2S detectors (if necessary). This request is denied. Unocal proposed using high-pressure line(s) and hose with 1502 threaded connections which requires an exception to 20 AAC 25.285 (c) (9) and (e) (6). The waiver request is approved as provided by 20 AAC 25.285 (e) (6). With regard to the actual lines, hose (flexible, continuous) may be used. Steel pipe and traditional chicksan may not be employed. All of the valves Unocal plans to employ are manual. 20 AAC 25.285 (9) (C) requires that the outer choke valve must be a hydraulic valve. For the planned application with calculated pressures likely well below 2000 psi, this is acceptable and the waiver is approved as provided by 20 AAC 25.285 (h). The choke manifold does not have a bypass line per 20 AAC 25.285 (9) (D). The request for waiver should be approved as provided by 20 AAC 25.285 (h). Your approval of these recommendations is requested. I propose that a copy of this document with the appropriate well identified be attached to the workover Sundries as they are processed. A copy of this document is included as an attachment to the sundry approval for the respective well work. SCANNED SEP 1 g 2002 Unocal Alaska Business Unit Swanson River Well No. SCU 24A-5 Workover to install additional gas lift 9/3/2002 UNOCAL No. Preliminary Procedure Prep for Workover Set PX Plug and Prong in X Nipple at 9,691' (Done). Load well with lease water (Done). Workover 1 MIRU Pulling Unit. 2 ND Tree, NU 11" BOP and Test 250/3000psi. 3 Attempt to rotate anchor out of production packer. Contingency if Unable to Release Anchor. A RIH with Chemical Cutter and cut tubing above anchor. POOH. B POOH with completion. C RIH with 2- 7/8" Drill Pipe Work String and Overshot. D Engage Anchor and rotate out. E POOH. 4 POOH standing back tubing. 5 Prep to run Completion. 6 RIH with New Seals and Gas Lift Completion. 7 Stab into packer, space out and land hanger. 8 ND BOP's. 9 NU Tree, Test. 10 RD Pulling Unit. 11 Recover Prong and Plug Body. 12 Return the well to production. ,SCANNED SEP 1 2002 UNOCAL Tubing stub problematic to enter! 11 10 SIZE WT ! 8" 10--3/4" 40.5 7-5/8" 26.4 7-5/8" 33.7 7-5/8" 26.4 7-5/8" 29.7 7-5/8" 33.7 5-1/2" 20 2-7/8" 6.5 Tubing 3-1/2" 9.3 2-7/8" 6.5 Depth, .I_D_ I 25.85' 2 26.85' 2.992 3 2,011' - 4 6,473' - 5 9,606' - 6 9,650' - 7 9,651' - 8 9,653' 4" 9 9,659' - 10 9,691' 2.313 11 9,698' 2.45 12 10,463' 2.313 Swanson River Well SCU 24A-5 Actual Completion 1/19/91 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 91' K-55 BTC Surface 3,390' N-80 BTC Surface 34' N-80 BTC 34' 117' N-80 BTC 117' 3,945' N-80 8rd LTC 3,945' 5,878' P-110 8rd LTC 5,878' 6,722' N-80 FL4S 6,722' 10,175' N-80 ? 9,699' 10,790' N-80 EUE 8rd Mod. 2.992 25.85 6,473' N-80 EUE 8rd Mod. 2.441 6,473' 9,698' JEWELRY DETAIL OD Item Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Unknown BPV Profile 3.5 Pup, 3-1/2", 9.3#, N-80, EUE 8rd Mod. 1.62' Long GLM, Camco MMG, 3-1/2", 1-1/2" Crossover, 3-1/2" 8rd Mod. Box x 2-7/8" 8rd Mod. Pi~ GLM, Camco, KBMG-II, 2-7/8", 1" Tubing Anchor, Baker Mod. EBH-22 Packer, Baker Mod. F-l, Size 40-30 Baker iMillout Extension, 4", 10rd Pin x Pin - Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin - X Nipple, (2.313" I.D.) - Baker Overshot - X Nipple, (2.313" I.D.) With PX Plug Notes NO. Depth Item I +/- 6,574' Liner Top Packer, TIW, Stuck when RIH 12 H6 H6 H8 H9 H10 PERFORATION HISTORY (DIL Depth) Interval Accum. Date ---Zone Top Btm Amt spf Comments 4/91 H-6 10,453' 10,465' 12' 4 ___ 4/92 H-6 10,453' 10,463' 10' 4 Reperf 2/91 H-8 10,486' 10,512' 26' 4 1/91 H-9 10,566' 10,582' 16' 4 12/13/98 H-10 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. -- _-- -- .-- PBTD = 10,745' TD = 10,790' MAX aOL~ ANGL~ = 6.S deg.SCANNEC) S [ P ~. g 2[}[32 .. SCU 24A-5 12-13-98 DRAWN BY: tcb REVISED: 12/21/98 UNOCAL 4 Tubing stub problematic to enter! 6 7 8 9 10 11 12 H6 H6 H8 H9 H10 SIZE WT Swanson River Well SCU 24A-5 Proposed Completion CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 18" 10--3/4" 40.5 7-5/8" 26.4 %5/8" 33.7 7-5/8" 26.4 7-5/8" 29.7 7-5/8" 33.7 5-1/2" 20 2-7/8" 6.5 Tubing 2-7/8" 9.3 2-7/8" 6.5 - 91' K-55 BTC Surface 3,390' N-80 BTC Surface 34' N-80 BTC 34' 117' N-80 BTC 117' 3,945' N-80 8rd LTC 3,945' 5,878' P-110 8rd LTC 5,878' 6,722' N-80 FL4S 6,722' 10,175' N-80 ? 9,699' 10,790' N-80 EUE 8rd Mod 2.881 25.85 6,473' N-80 EUE 8rd Mod. 2.441 6,473' 9,698' NO. Depth Il) JEWELRY DETAIL OD Item 1 25.85' 2 26.85' 2.992 3 TBD - 4 6,473' - 5 TBD - 6 9,650' - 7 9,651' - 8 9,653' 4" 9 9,659' - 10 9,691' 2.313 11 9,698' 2.45 12 10,463' 2.313 3.5 Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Unknown BPV Profile Pup, 3-1/2", 9.3#, N-80, EUE 8rd Mod. 1.62' Long GLMS 3-1/2", 1" Crossover, 3-1/2" EUE 8rd Box x 2-7/8, EUE 8rd Pin GLMS 2-7/8", 1" Tubing Anchor, Baker Mod. EBH-22 Packer, Baker Mod. F-l, Size 40-30 Baker Millout Extension, 4", 10rd Pin x Pin Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin X Nipple, (2.313" I.D.) Baker Overshot X Nipple, (2.313" I.D.) With PX Plug Notes I +/- 6,574' Liner Top Packer, TIW, Stuck when RIH PERFORATION HISTORY (DIL Depth) Interval Accum. 'Date Zone Top Btm Amt spf Comments 4/91 H-6 10,453' 10,465' 12' 4 4/92 H-6 10,453' 10,463' 10' 4 Reperf 2/91 H-8 10,486' 10,512' 26' 4 1/91 H-9 10,566' 10,582' 16' 4 12/13/98 H-10 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. PBTD = 10,745' TD = 10,7~it~ANhlEB' SEP J_ g 2002 MAX HOLE ANGLE = 6.5 deg. SCU 24A-5 Prop Draw II DRAWN BY: tcb REVISED: · o ...-. ';:.'% · · · . Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-marl: childersd@.unocal, cam UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 To: Lori Taylor 3001 Porcupine A..nchorage, AK 99501 Alaska Oil & Gas ii From: Debra Childers 909 W. 9th Avenue Anchorage, AK Unocal 99519-6247 Transmitting the following items: ~,.,. ..... ,..,~.' ~:~:', .,, ... ,,~, .' z~.'¥,~ ~,,,~;~t~,;.;~ ~:'~:, ~ ~' "'~. ~,~-~"';~ ~'~,~.,~..~..'~,~t.~:.~ ~" ~,'~,;'. Z~~5~'-'3~':'~:i'{~ rq,~a~ De~a~ 'rime Log 5~~~==~,'~05T-" ! 916199 i--'"'-----'~h~O~ 07~'~:'-~~' !~ B..Line~~~ ~'~f~'~'~i'"'5;~'~"fi~'~"G~ ............................... ~"i~ ........... F~ .......... ~)~'F'~'~6:~-6'~i~ ............ 1 ...................................................... i'~"~i~h .................... ' .............................................................................................................................................................................. ~ ......................................... t ............................................. ~ ....................................................................... , .............................................................................. ~ ............................................ og~SGU 12-9 ~Pedoratin~ Record ~Sinch : N3/00 10150-10330 liB-Line ~CU 12A-3 ~PedoratingRecorECorrelation Log ~5inch i 3115100110200-10550 j liB-Line SCU 12A-3 ) Pedoratmn Recor~Correlabon Log '] 5 ~nch ~ 3/15/00110200-10550 l~lm [SCU 12A-3 lPossiset Plug 5'Cement ~5 inch ~ 3/11/00110200-10545 i liB-Line SCU 12A-3 IPossiset Plug 5 Cement ~5 inch ~ 3/11/00 10200-10545 ~ llFilm .................................... ~ .................................... i ......................................................................... ~ ............................................................................................................................ ~'SCU 14-4 Pedoratin Recor~CorrelationLo ~5inch ~ 1/14/00~10000-10610 ' 1 B-Line ............................................................ I .................................... : .............................................................................. : .......................................... : ............................... l ............................................. l ......................................... ' ......... ~ ' 'SOU 21A-9 Pefloratiqg...~.~.qg.[~.............................................................. ~j.~.~,~ ............ NI/00~ 10500-10700 [ 1 .~.:~.~.~ ................ ~-~.-~,~,.X-:~-. ........ :"~;'~;'~i'i'~ Rocord 5 inch ................... ~'i'~"~6:¥6~ .......... i, ................................................................ i'" Film o~U22-4 MDCom~ositeField~rint 5inch 10/8/~0 10a40-11140 ~ 1 ~-Une SOU 22-4 TVD Composite Field Print 15 inch i 10/8/99110340-11140 i ltB-Line ............................................................ , .......................................... ,.... ......................................................................................................... ~ .......................................................................................... ~ ........................................................................ i ................................................................................ , .............................................. 'SCU24A-5 !Completion Record 15inch t 3/13/00110200-10640 I liB-Line F~'~'0'"~S'~:~ .......... l"~;'~i$i'i~h'"~'$~fiJ';~ ............................................................... F~"'ih'~fi ............................. ~"2'~"~¢66T'5'"6~66:~'6~g76 ............ 1 ............................................................. ¥1''~':~i'~$ SCU 43B-8 ~ Pedorating Record/Correlation Lo~ inch' 3/16/00i 10200-10500 1 ~~9.----ine ) ....................................................... ............................................. ................................................................... , ............................... ............................ Please ocknowledge r~ipt ~y si~ning ond returnin0 one copy of this tronsmtHol 07) 263-7828. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Thursday, March 30, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 24A-5 APl No. 50-133-20256-01 10-404 Perforate H2, 3, 4 & 8 benches Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H2, 3, 4 & 8 benches in well SCU 24A-5. The following intervals were perforated on 3/14/00: Bench Top Bottom Feet H2 10,344 10,354 10 H3 10,378 10,388 10 H4 10,392 10,445 53 H8 10,476 10,486 10 H8 10,512 10,554 42 Total: 125 Ol lGllqAL RECEIVED If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager ,---., STATE OF ALASKA .- ALASKA OIL AND GAS CONSERVATION C . MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 154' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1058' FSL, 1497' FEL, Sec. 5, T7N, R9W, SM SCU 24A-5 At top of productive interval 9. Permit number/approval number 1094' FSL, 1770' FEL, Sec. 5, T7N, R9W, SM 92-073 At effective depth 10. APl number 1121' FSL, 1798' FEL, Sec. 5, T7N, R9W, SM 50-133-20256-01 At total depth 11. Field/Pool 1125' FSL, 1800' FEL, Sec. 5, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10790 feet Plugs (measured) true vertical 10762 feet Effective depth: measured 10745 feet Junk (measured) true vertical 10717 feet Casing Length Size Cemented Measured depth True vertical depth Structural 30' 18" Driven 91' 91' Conductor Su trace 3390' 10-3/4" 1263 sx 3390' 3390' Intermediate 7027' 7-8/5" 395 sx 7027' 7014' Production 3453' 5-1/2" 250 sx 6722'- 10175' 6715'-10147' Liner 1092' 2-7/8" 17 bbls 9698'-10790' 9672'-10762' Perforation depth: measured 10344-10354, 10378-10388, 10392-10445, 10453-10463, 10476-10554, 10564-10580 · . true vertical 10317-10327, 10351-10361, 10365-10418, 10425-10435, 10448-10526, 10536-10552 Tubing (size, grade, and measured depth) 3-1/2", 9.3# @ 6473'; 2-7/8", 6.5# @ 9698' Packers and SSSV (type and measured depth) Baker"F-l"@ 9651' 0 R1 GiI~ A L RECEIVED 13. Stimulation or cement squeeze summary ~p~ 10 2~ Intervals treated (measured) A~m Oil & Gas Cans. Comm~ion Treatment description including volumes used and final pressure Anchoratte 14o Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 82 3976 18 1000 1160 Subsequent to operation 62 5528 18 1020 1190 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas'. Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~(/~;'/~ ~~(,/~Yl Title: /~/~/[/ /~ ,~/f~/~ Date: .~7~./(]/~-~ r~ Form 10-404 Rev 06/15/88 , . - ,~'%, SUBMIT IN DUPLICA~~_~X~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X RKB 164' GL 138' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 1,058' FSL, 1,497 FEL, Sec. 5, T7N,R9W,SM SCU 24A-5 At top of productive interval 9. Permit number 92-073 At effective depth 10. APl number 50- 133-20256-01 At total depth 11. Field/Pool 1,058' FSL, 1,497 FEL, Sec. 5, T7N,R9W,SM Swnason River Field / Hemlock "~ ~'~'~ fO 12. Present well condition summary Total depth: measured 10,790' feet Plugs (measured) true vertical 10,762, feet Effective depth: measured 10,745' feet Junk (measured) true vertical 10,717' feet Casing Length Size Cemented Measured depth True vertical depth Structural 30' 18" Driven 91' 91' Conductor 22" Yes 37' 37' Surface 3,390' 10-3/4" 1,236 sx 3,390' 3,390' Intermediate 7,027' 7-5/8" 395 sx 7,027' 7,014' Production 3,453' 5-1/2" 250 sx 6,722'-10,175' 6,715'- 10,147' Liner 1,092' 2-7/8" 17 bbls Class G 9,698'-10,790' 9,672'-10,762' Pen'oration depth: measured 10,453'-10,463'; 10,486'-10,512'; 10,564'-10,580'; 10,640'-10,668' true vertical 10,425'-10,435'; 10,458'-10,484'; 10,536'-10,552'; 10,611'-10,639' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 6,473' 2-7/8", 6.5#, N-80 6,473'-9,698' Packers and SSSV (type and measured depth) TIW Liner Top Packer 6,522'; Baker F-1 Packer 9,651' 13. Stimulation or cement squeeze summary N/A INn/t~rvals treated (measu red) ORIGINAL Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11129198 13 2,252 1 20 200 Subsequent to operation 12/20/98 136 3,907 3 480 1,350 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil:X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Anchomq~ Signed: ~:~.~/'~.__ Dan Williamson Title: Drilling Manager Date: ,~-~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ELECTRIC LINE JOB RECORD Well: SCU 24A-5 Facility: Swanson River Field: Swanson River APl No: 50-133-20256-01 AFE No: Service Co: Schlumberger Service Co. Rep: Ray Ambrose Unocal Witness: Shane Hauck Date Completed: 12/13/98 COMMENTS See Perforating record UPDATE RECORD Document I Date Well History: Wellbore Diagram: Sundry (AOGCC): Sundry (BLM): Bench I Top IB°tt°m I H10 10,640 10,668 INTERVALS PERFORATED (DIL) FeetI I sPe IPhaseI Gun Type 28 4 0 2-1/8" Hollow Carrier Total' 28 INTERVALS LOGGED Top Bottom Type of Log Reason 10,550 10,668 GR / CCL Correlation & tie-in WELL TEST DATA Before After Date: t~ate: Gross: Gross: Oil: Oil: 'Gas (P): Gas (P): Water: Water: Tbg. psi Tbg. psi Csg. Psi. Csg. Psi Cut %: ELJ ]¢~R~[C..XLS Fill tagged at: Size gauge run: Fish left in hole? E-line cost: UNOCAL RKB = See Notes Tubing stub problematic to enter! 11 10 12 H6 H6 H8 H9 H10 Swanson River Well SCU 24A-5 Actual Completion 1/19/91 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 18" - 91' 10--3/4" 40.5 K-55 BTC Surface 3,390' 7-5/8" 26.4 N-80 BTC Surface 34' 7-5/8" 33.7 N-80 BTC 34' 117' 7-5/8" 26.4 N-80 BTC 117' 3,945' 7-5/8" 29.7 N-80 8rd LTC 3,945' 5,878' 7-5/8" 33.7 P-110 8rd LTC 5,878' 6,722' 5-1/2" 20 N-80 FL4S 6,722' 10,175' 2-7/8" 6.5 N-80 ? 9,699' 10,790' Tubing 3-1/2" 9.3 N-80 EUE 8rd Mod. 2.992 25.85 6,473' 2-7/8" 6.5 N-80 EUE 8rd Mod. 1.995 6,473' 9,698' JEWELRY DETAIL NO. Depth I__~D OD Item i 25.85' - - 2 26.85' 2.992 3 2,011' - 4 6,473' - 5 9,606' - 6 9,650' - 7 9,651' - 8 9,653' 4" 9 9,659' - 10 9,691' 2.313 11 9,698' 2.45 12 10,463' 2.313 Tubing Hanger, Shaffer, 3-1/2" EUE 8rd Mod. Lift Thread x 3-1/2" EUE 8rd Mod. Suspension Threads, Unknown BPV Profile 3.5 Pup, 3-1/2", 9.3#, N-80, EUE 8rd Mod. 1.62' Long - GLM, Camco MMG, 3-1/2", 1-1/2" - Crossover, 3-1/2" 8rd Mod. Box x 2-7/8" 8rd Mod. PiT - GLM, Camco, KBMG-II, 2-7/8", 1" - Tubing Anchor, Baker Mod. EBH-22 - Packer, Baker Mod. F-l, Size 40-30 - Baker Millout Extension, 4", 10rd Pin x Pin - Crossover, 4' 10 rd Box x 2-7/8" EUE 8rd Pin - X Nipple, (2.313" I.D.) - Baker Overshot - X Nipple, (2.313" I.D.) With PX Plug Note: All the above depths are relative to the re-drill rig Grace 154 RKB. Arco did not use the original RKB of 17' when running the completion! Notes NO. Depth Item I +/- 6,574' Liner Top Packer, TIW, Stuck when RIH PERFORATION HISTORY (DIL Depth) Interval Accum. Date Zone Top Btm Amt spf C3~6nts 4/91 H-6 10,453' 10,465' 12' 4 4/92 H-6 10,453' 10,463' 10' 4 Reperf 2/91 H-8 10,486' 10,512' 26' 4 1/91 H-9 10,566' 10,582' 16' 4 12/13/98 H-10 10,640' 10,668' 28' 4 2-1/8" HC, 0 deg. PBTD = 10,745' TD = 10,790' MAX HOLE ANGLE = 6.5 deg. SCU 24A-5 12-13-98 DRAWN BY: tcb REVISED: 12/21/98 ARCO Alaska, inc. Post Office Bo× 100360 Anchorage, Alaska 99510=036~ Telephone 907 276 1215 June 23, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 24A-5 Dear Mr. Smith: ARCO Alaska Inc. successfully completed the reperforation of SCU 24A-5, H6 sands, from 10453'-10463' on 4/1/92. Please refer to the attached Subsequent Report and Well Service Report for details of this operation. If you require any further information in this regard, please call Jim Zernell at 263-4107. Sincerely, J.C. Wren Acting Regional Engineer JCW:DRH:jIg: 0153 Attachment cc' Mr..4, R~ Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation Anchorage' ARCO Alaska, lrm. is a Sul:~diary of Atlantic Rtchf~d Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Pull tubing ~ Alter casing ~ Repair well Z. Name of Operator ~ 5. Type of Well: Development X ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic __ P. O. Box 100360~ Anchora~le~ AK 99510 Service Plugging~ Perforate X ReDerforate Pull tubing ~ Other 6. Datum elevation (DF or KB) RKB 164' GL 138' 7. Unit or Property name Soldotna Creek Unit fe~t 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, Rgw, SM At top of productive interval At effective depth At total depth 125' FSL~ 1800' FELr Sec. 5~ T7Nr R9W~ SM Present well condition summary Total Depth: measured 10,790' true vertical 1 0,762' feet Plugs (measured) feet 8. Well number SCU 24A-5 9. Permit number/approval number 10. APl number 50-133-20256-01 1 1. Field/Pool Swanson River/Hemlock 10463' MD 13. Effective depth: measured 10,745' true vertical 10,71 7' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Current: feet Junk (measured) feet Length Size Cemented Measured depth 30' 18" Driven 91' MD 3390' 10-3/4" 1263 sx Class G 3390' MD 7027' 7-5/8" 395sx Class G 7027' MD 3453' 5-1/2" 250 sx Class G 6722'-10175' MD 1092' 2-7/8" 17 bbls Class G 9698'-10790' MD measured 10453' -10463' (reperf), 10486' - 10512', 10564'-10580' MD true vertical 10425'- 10435' 10458'- 10484', 10536'-10552' TVD Tubing (size, grade, and measured depth) 3-1/2" to 6473' MD; 2-7/8" from 6473'-9698' MD Packers and SSSV (type and measured depth) Packers: Liner Packer @ 6522'~ Baker F-1 Pet. Prod. Packer @ 9651' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A True vertical depth 91' TVD 3390' TVD 7014' TVD 6715'-10147' TVD 9672'-10762' TVD J U N ?.' I 92 Alaska 0ii & Gas Cons. 60mmissi0i Anchora~/~ 14. Re_Dresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 142 4233 3 500 1220 Subsecluent to operation 1 67 4438 3 200 625 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 1 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Cook Inlet Regional Engineer Form 10-404 Rev 06/15/88 Date ~'/~'.~/¢Z- SUBMIT IN DUPLICATE Arco 'a...a inc. - Swanson River -'~' i gell- sou 24A-5 APl#: 50-133-20256-01 Well Type:Proclucer Spud Date: S.T. 11/90 Completion Date: S.T. 1/91 Last Workover: <~riglnal RKB: 32' Hanger Type' Shaffer Hanger' /Dp of Hemlock' Max. Hole Angle: 6.5° Angle @Hemlock· 5.5° All Depths are RKB MD to Top of Equipment. q 6 7 8 Jewelry 1 2011' 2 6473' 3 6574' 4 9607' 5 9651' 6 9651' 7 9654' 8 9659' 9 9691' 10 9698' 11 10,463'~ Camco GLM MMG 8 -1/2' x 1-1/2" X-Over 3-1/2' Mod. Box, 2-7/8' Mod. Pin Liner -Top Paci~er (set above Liner Top) Camco GLM KBMG-II, 2-7/8" x 1" Baker EBH-22 2-7/8'Anchor Seal Assy. Baker F-1 Pet. Prod. Packer Baker Millout Estension 4' 10 RD Pin x Pin X-Over 4' NH 10 RD Box x 2 7/8' Offs 'X' Lancling Nipt31e 2-7/8' I.D,?..313' Tri-State Overshot, 2.45' (TBG I:ie~r~lon Pre#nt) Otis "X" Nipple 2-7/8" I.D. 2.313' ~ ~.~o , ¢1¢',1~ Casing and Tubing 20" 10" 40.5# K-55 7-5/8" Mixed N-80 5-1/2" 23# N-80 3-1/2' 9.3# N-80 2 7/8' 6.5# N-80 2-7/8' 6.5# N-80 Bottom Deaerlatlan 0 30' Concluctor Pipe 0 3390' Surface Casing 0 7027' Production Casing 6722' 10,175' Liner 0 6473' Tubing 6473' 9698' Tubing/Liner 9699' 10,790' Liner Perforation Data Interval COIL1 Zone FT SPF 10,453'- 10,465' H6 1 2 4 10,486'-10,512' H8 26 4 10,566'- 10,582' H9 1 6 4 4/91 Open p 2/91 Below t~.~ 1/91 Below B. PBTO = 10,745' TD = 10,790' ~aS~., Oil & (-~as Colis. bo~'iirnisston Anct]orage .. Well SCU 24A~5 JLB 10/11/91 Revised RCO Alaska, Inc. Su~lcllmry of Atl~la Rl=hfleld GOml:~n~ iF'BDT SWANSON RIVE~ ~ODUCT:ON ~_ WI~I,,I,, ~I--HVI~i= rll-I~Vl'l ! DAYS iOATE - I F~LD ' DI'TRICT · STA% ~? ~ c ~ I~OPE~TION AT RE.AT TIME --r ___ - CHECK THIS BLOCK I. SUMMA~~INUED ON Weather ] Temp.Rel~rt ! 'F lchill Fm~tm' j vlmlblllty'~' j milea JWIn41 Vel.. knota Glgn%r h_ ~., ~ ( 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ Pull tubing _ 2. Name of Operator 5. Type of Well: Development Exploratory _ Stratigraphic _ STATE OF ALASKA ~ OILAND GAS O(~~VATIm OOMMISSION APPLICATION FOR SUNDRY APPROVALS 99510 Operation Shutdown _ Re-enter suspended well_ Plugging _ Time extension _ Stimulate _ Variance_ Perforate X Other_ 6. Datum elevation (DF or KB) RKB 164 '. Gl_ 138' 7. Unit or Property name Soldotna Creek Unit feet /~RCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, Rgw, SM At top of productive interval At effective depth 8. Well number SOIl 24A-5 9. Permit number. 10. APl number 50-133-20256-01 11. Field/Pon~ - -- Swanso~El-~_~' .~E D 12. 13. At total depth 1125' FSL, 1800' FEL, Sec. 5, T7N, Rgw, SM Present well condition summary Total Depth: measured Effective depth: 10790' true vertical 1 0762' measured 1 0745' true vertical 1 071 7' Length Size 30' 18" feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven 10466' MD MAR 1 1992 Alaska 0il & 8as Cons. 130mmissio~ Anchorage Measured depth True vertical depth 91' MD 91' TVD 3390' 1 0-3/4" 1263 sx Class G 3390' MD 3390' TVD 7027' 7-5/8" 395 sx Class G 7027' MD 7014' TVD 3453' 5-1/2" 250 sx Class G 6722'-10175' MD 6715'-10147' TVD 1 092' 2- 7/8" 17 bbls Class G 9698'-10790' MD 9672'-10762' TVD measured Proposed Reperf: 10453'-10465' MD Proposed Reperf: 10425'-10437' TVD BOP sketch X Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: 10453'-10465', 10486'-10512', 10564'-10580' MD true vertical Current: 10425'-10437', 10458'-10484', 10536'-10552' TVD Tubing (size, grade, and measured depth 3-1/2" @ 6473' MD; 2-7/8" from 6473'-9698' MD Packers and SSSV (type and measured depth) Packers: Liner Packer ~ 6522', Baker F-1 Pet. Prod. Packer ~ 9651' Attachments Description summary of proposal X Detailed operation program 14. Estimated date for commencing operation Date approved 15. Status of well classification as: Oil _~_ Gas __ Suspended Service _ 16. If proposal was verbally approved Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .i.~~(",.(,,. ~ Title Cook Inlet Regional En~r. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IAppro_val No. Plug integrity m BOP Test Location clearance Mechanical Integrity Test -- Subsequent form r--;quire 10-x'~~ ~ '(.".'i:'~ !:.",',.'~ OR!G!~.,]AL S!GiL!ED BY ~/- Approved by the order of the Commission LONNIE C.S..r';~!TH COmmission-ei Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE SCU 24A- 5 Re-perf the H-6 #SR 284 Well Status: Producing from the H-6 sand. Recently tested in the 150# system with a minimal rate gain for the corresponding drop in FTP. Last test March 8, 1992:173 BOPD 178 BFPD, GOR 25,939, Gas 4,487 Mcf~FTP 600psi. When put back into the 900# system showed an oil rate of 148 BOPD at a FTP of 1,230 psi. Objective: Increase oil production and minimize solids production by increasing perforation density of the producing H-6 interval. Minimum Restriction: 2.313" ID in Otis 'X' Nipple at 9,691'. Also previous restriction in the Overshot at 9,698' which was milled out 11/29/91. Procedure: Hold safety meeting with all personnel involved. Obtain tool string schematic prior to running tools in the well. , , . o Make slickline 2.20" GR run to top of fill. Last run in the well was to set the prong in the 'PX' plug at 10,463' MD (located at 10,468' PDK-100 1/9/91: H-6 perfs are at 10,453-465' PDK-100). Tie GR into profile or cross over to determine fill level depth with respect to perforations. (Note: If 2.20" gauge ring fails to pass through the Overshot at 9,698' run a 1.75" GR for 1-11/16" strip guns). If fill level is above bottom of perforation contact Jim Zernell at x4107 prior to proceeding. Shoot fluid level and if necessary load the tubing with lease crude to ensure that guns will be fired in liquid. MIRU E-line unit. Test lubricator. RIH with CCL, 2-1/8" hollow carrier guns loaded at 4 SPF, 0° phasing, decentralized with shots oriented 45° from low side of the hole. (Note: If 2.20" GR would not pass in step #1 perforating will be done with 1-11/16" strip guns in lieu of 2-1/8" hollow carrier). page 2. SCU 24A-5 Re-perf H-6. . Tie-in log to PDK-100 dated 1/9/91. Perforate the H-6 sand from 10,453'-10,465'. POOH with guns and verify all shots fired. Re-run guns if required. Interval Run # PDK-100 (1/9/91) Footage Sand SPF Phasing 1 10,453'-10,465' 12 H6 4 0° Guns available: 2-1/8" Hollow Carrier: Based on Berea Sandstone data (Section II). Company Gun EHD TT P Schlumberger Domed Scallop 0.34" 7.92" Western Arias Jumbo Jet III 0.30" 8.24" Halliburton (2") E-jet 0.27" 10.2" 1-11 / 16" Strip Guns: Company Schlumberger Western Arias Halliburton Based on Berea Sand data (Section II). Gun EHD TTP Enerjet 0.34" 7.35" Silver Jet 0.33" 8.09" Tornado Jet 0.37" 6.35" , Return well to production and obtain well test at constant FTP's in the 900# system on days 1, 3, and 5. Depending on the test results additional testing of the well into the 150# system may be warranted. RECEIVED MAR 5 1 1992 Alaska Oil & Gas Cons. Cornmissior~ Anchorage ' Arco, .ska Inc. - Swanson River .... ,id a/ell- SCU 24A-5 APl#: 50-133-20256-01 Well Type:Producer Spud Date: S.T. 11/90 Completion Date' S.T. 1/91 Last Workover: '-'~riginal RKB: 32' Hanger Type: Shaffer Hanger' .,bp of Hemlock: Max, Hole Angle: 6.5° Angle @Hemlock' 5.5° All Depths are RKB MD to Top of Equipment. 6 7 8 Jewelry I 2011' 2 6473' 3 6574' 4 9607' 5 9651' 6 9651' 7 9654' 8 9659' 9 9691' 10 9698' 11 10,463'~ Camco GLM MMG 8 -1/2' x 1-1/2" X-Over 3-1/2" Mod. Box, 2-7/8' Mod. Pin Liner -Top Packer (set above Liner Top) Camco GLM KBMG-II, 2-7/8" x 1" Baker EBH-22 2-7/8"Anchor Seal Assy. Baker F-1 Pet. Prod. Packer Baker Miliout Estension 4" 10 RD Pin x Pin X-Over 4" NH 10 RD Box x 2 7/8' Otis 'X' Landing Nipple 2-7/8" I.D.2.313' Tri-State Overslx)t, 2.45' (TBG Reatrlctlon Pr#om) Otis 'X' Nipple 2-7/8' I.D. 2.313' Casing and Tubing 20' 10' 40.5# K-55 7-5/8' Mixed N-80 5-1/2' 23# N-80 3-1/2" 9.3# N-80 2 7/8' 6.5# N-80 2-7/8' 6.5# N-80 Bottom Description 0 30' Conductor Pipe 0 3390' Surface Cas~g 0 7027' Production Casing 6722' 10,175' Liner 0 6473' Tubing 6473' 9698' Tubing/Liner 9699' 10,790' Liner Perforation Data Ipterval (DILl Zone FT SPF Date 10,453'-10,465' H6 12 4 4/91 10,486'-10,512' H8 26 4 2/91 10,566'-10,582' H9 16 4 1/91 Open Below B.P~ p~. ~ I~.~ Below B.P. 11 PBTD = 10,745' TD = 10,790' Well SCU 24A-5 JLB 10111/91 Revised ! GR-.~. SCU 24A-5 PDK-100 1-9-91 E-L~e BOPE's RECEIVED AIask~ Oil & G~ Con~. Coremis~i'°~ - Anchora~l~ Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ARCO Alaska, Inc. Post Office E~o× Anchorage, Alaska Telephone 907 276 C~k in~e~ Engtne~'tng March 27, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval SCU 24A-5 Dear Mr. Smith: Attached is an Application for Sundry Approval to reperforate the H6 interval m SCU 24A-5. We propose to reperforate 12' of the H6 sand (10,453'-10,465' MD). Please refer to the enclosed Perforating Procedures for details of this operation. If you require further information in this regard, please do not hesitate to call Jim Zemell at 263-4107. Sincerely, Acting Regional Engineer JCW:DRH:czm:0124 Attachment cc: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a SubSidiary of A~3~tc Richfield Cor~p~ny STATE OF ALASKA !: :" ALASKA OIL AND 6AS CONSERVATION COMIdl SS ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown~ Stimulate PluggingX Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO AlaSka, I I~. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, R9W, SM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Servi ce At effective depth At total depth 1125' FSL, 1800' FEL, Sec.5, T7N, Rgw, SM 6. Datum elevation (DF or KB) RKB 16zt' GL 138' 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 24A-5 9. Permit number/approval number ~90-144 / ~'~//~, · 10. APl number 50-133-20256-01 11. Field/Pool Swanson River/ Hemlock 12. Present well condition summary Total Depth: measured true vertical 10,790' 10,762' feet feet Plugs (measured) 10466' MD Effective depth: measured 10,745' true vertical 10,717' feet feet Junk (measured) Casing Length Size Structural 30' 18" Conductor Surface 3390' 10-3/4" Intermediate 7027' 7-5/8" Production 3453' 5- 1/2" Liner 1092' 2-7/8" Perforation depth: measured Current: 10453' - 10465' 10486' - 1 true vertical Current: Cemented Driven Measured depth 91' MD 1263 sx Class G 395sx Class G 250 sx Class G 17bbls ClassG 3390'MD 7027'MD 6722'-10175'MD 9698'-10790'MD 0512', 10564'-10580'MD 10425'- 10437'10458'- 10484', 10536'-10552'TVD Tubing (size, grade, and measured depth) 3-1/2" to 6473' MD; 2-7/8" from 6473'-9698' MD Packers and SSSV (type and measured depth) Packers: Liner Packer @6522',BakerF-1 Pet. Prod. Packer @9651' True vertical depth 91' TVD 3390'TVD 7014'TVD 6715'-lO147'TVD 9672'-10762'TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A Alaska.Oil & Gas Cons. Commiss[ Anchoraqe 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 70 20000 11 800 1 26 4925 2 350 Tubing Pressure 850 2150 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Cook Inlet Regional Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~ 8uI;;~tdllry of Atl~u~tic Richfield C~mpany WELL CONTRACTOR REMARKS WELL SERVICE REPORT · [FIELD. DISTRICT. STATE DAYS IOPERATION AT REPORT TIME ~0 0,9: iD' ~ lo'cC t.O: ~5 ' R.ECEI. V'ED SEP 0'4 i99i Alaska Oil & 6as Cons. CommiSStOtt Anchoragu m CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wealhel' ' Teml~. j Chill Factor ! Vlslbillly [WindVel, Report '= ' °F milo..: ~,.~,. ., . .,, ,.,__, ) m' .-'" CONTRACTOR REMARKS I FIELD. DISTRICT-STATE ,X~,~<,,,. ~: ~. IOPERATION AT REPORT TIME WELL SERVICE REPORT 1 IL'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~/emtl~r' ] Temp. Chill FaVor (Visibility JWifld Vel. Arco, .aska Inc. - Swanson River ~_~el~- SCU 24A-5 APl#' 50-133-20256-01 SISud Date' S.T. 11/90 Completion Date: S.T. 1/91 Original RKB: 32' Hanger Type' Shaffer Top of Hemlock: aid Well Type' Producer Last Workover: Hanger: Max. Hole AnGle: 6.5° AnGle @Hemlock* 5.5° All Depths are RKB MD to Top of Equipment. 5 6 7 8 10 Jewelry 1 2011' 2 6473' 3 6574' 4 9607' 5 9651' 6 9651' 7 9654' 8 9659' 9 9691' 1 0 9698' 11 10,463' 12 10,466' Camco GLM MMG 8 -1/2" x 1-1/2" X-Over 3-1/2" Mod. Box, 2-7/8" Mod. Pin Liner -Top Packer (set above Liner Top) Camco GLM KBMG-ll, 2-7/8" x 1" Baker EBH-22 2-7/8"Anchor Seal Assy. Baker F-1 Pet. Prod. Packer Baker Millout Estension 4" 10 RD Pin x Pin X-Over 4" NH 10 RD Box x 2 7/8" Otis"X" Landing Nipple 2-7/8" I.D.2.313" Tri-State Overshot, 2.45' Otis "X" Nipple 2-7/8" I.D. 2.313" Bridge Plug (set 4/12/91) Casing and Tubing Size Weight Grade ~ Bottom 20" 0 30' 10" 40.5# K-55 0 3390' 7-5/8" Mixed N-80 0 7027' 5-1/2" 23# N~80 6722' 10,175' 3-1/2" 9.3# N~80 0 6473' 2 7/8" 6.5# N-80 6473' 9698' 2-7/8" 6.5# N-80 9699' 10,790' Description Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing/Liner Liner Perforation Data Interval Zone FT SPF Date 10,453'-10,465' H6 12 4 4/91 10,486'-10,514' H8 28 4 2/91 10,566'-10,582' H9 16 4 1/91 Comments Open Below B.P. Below B.P. H8 11 12 RECEIVED S EP 0 ~ !991 Alaska Oil & Gas Cons. Commission PBTD = 10,745' Anchorage TD = 10,790' Well scu 24A-5 JLB 8/29/91 Revised ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering August 30, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 24A-5./f,-,-,.,'-~.z~ Dear Mr. Smith: On 4/13/91 ARCO Alaska, Inc. successfully completed perforating SCU 24A-5 H6 Sands from 10,453'-10,465'. A bridge plug was also set at 10,466' MD. Please refer to the attached submittal of the Subsequent Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, T. Wellman TW:JTZ:czm:0127 Attachment CC' Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR(~O Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Weliman Regional Engineer Cook Inlet Engineering March 28, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to set a plug over the H8 and H9 intervals and perforate the H6 interval in SCU 24A-5. We propose to perforate 12' of the H6 sand (10,453'-10,465' MD) using I 11/16" hollow carrier perforating guns @ 4 spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact David A. Pursell at 263-4258. Sincerely, T..Wellman Regional Engineer TW:jkw:0003 Attachment cc: Mr. A~ 1~ Kukla Mr.B.C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Alter casing _ Change approved program_ ARCO Alaska. Inc.. 3. Address P. O. Box 100360, Anchorage, AK 99510 Suspend _ Operation Shutdown _ Re-enter suspended well Repair well _ Plugging ~ Time extension _ Stimulate _ Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic Service Variance Perforate X Other_ 6. Datum elevation (DF or KB) RKB 164 '..GL 15~' 7. Unit or Property name Soldotna Creek Unit feet 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, R9W, SM At top of productive interval At effective depth At total depth 1125' FSL, 1800' FEL, Sec. 5, T7N, Rgw, SM 8. Well number SCU 24~,-~ 9. Permit number 90-144 10. APl number 50-1 33-20256-01 11. Field/Pool Swanson River/Hemlock 12. 13. Present well condition summary Total Depth: measured true vertical 10,790' 10,762' Effective depth: measured 10,745' true vertical 1 0,71 7' Casing Length Size Structural 3 0' 1 8" Conductor Surface 3390' 1 0-3/4" Intermediate 7 0 2 7' 7 - 5 / 8" Production 3453' 5- 1/2" Uner 1 092' 2-7/8" Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven Measured depth True vertical depth 91' MD 91' TVD Current: 10486'-10512', 10564'-10580' MD Proposed: true vertical Current: 10458'-10484', 10536'-10552' TVD Proposed: Tubing (size, grade, and measured depth 3-1/2" @ 6473' MD; 2-7/8" from 6473'-9698' MD Packers and SSSV (type and measured depth) Packers: Liner Packer ~ 6522', Baker F-1 Pet. Prod. Packer @ 9651' Attachments Description summary of proposal X Detailed operation program _ 1263 sx Class G 3390' MD 3390' TVD 395 sx Class G 7027' MD 7014' TVD 250 sx Class G 6722'-10175' MD 6715'-10147' TVD 17 bbls Class G 9698'-10790' MD 9672'-10762' TVD 10453'-10465' MD 10425'-10437' TVD }~.,~ BOP sketch X_ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '7'/A/~~ Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- Date IApproval No. / Approved by the order of the Commission Form 10-403 Rev 5/03/89 Ot~i~iNAL SIGNED BY L$~:NIE C. SM)TH Commissioner Date '~-//'~' /~'~ --~/ Approved Copy Ret._ur~n~ed., SUBMIT IN TRIPLICATE Well SCU 24A-5 H8 Sand Perforation Procedure SR 222 Revision Objective Perforate H6 Sand in order to increase oil production. Current Status SCU 24-5 is shut in due to high GOR. Tubing loaded w/ produced water following PITS. Minimum Restriction: X Nipple at 10,463' MD (ID = 2.318") Pressures: TP 350 psi PC 0 psi SC 0 psi Procedure · Setting & Testing Plu_q 1. RU slickline and tag with 2.2" gauge ring. RD slickline. (NOTE: Last gauge ring had to work to get past overshot at 9690' WLM). 2. Contact Anchorage office to verify sundry approval before setting plug. . RU pump truck and load tubing with 65 bbls of lease crude. (Field engineer should perform packer calculations with a surface pressure limit of 3000 psi when liquid packed). 4. RU E-line and tie in. Set 2.16" teledyne plug at 10,476' MD, which is below the 'X' profile (ref PDK- 100). RD E-line. . Pressure test plug. Perform negative pressure test by bleeding surface pressure (expect 1200 psi after loading tubing with lease crude) and monitor until pressure stabilizes. Perform positive pressure test by applying 2700 psi to the surface and monitor until pressure stabilizes. 6. Proceed with perforating if the plug holds. Perforating 1. MIRu E-Line Unit. Pressure test lubricator. 2. RU pump truck and apply 1400 psi to the surface to ensure overbalance (tubing should be loaded with lease crude). Expected BHP is -4900 psi. 3. RIH w/ I 11/16" perf gun/CCL. Gun orientation should be 90° rotated off bottom. Tie-in to perf the following interval: Interval Run No. {PDK- 100 1-9-91) Footage (ft) Sand SPF Phasing 1 10,453-465 12 H6 4 180© 4. POOH. Confirm that all shOts have fired. RD E-Line Unit. RD pump truck. 5. RTP using adjustable choke. Test well on days 1,3, 5 following re- perforation. E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead SCU- 2: PROPOSED I $2 I 1497' FEL A-5 ]SIDETRA~ I 8 18 19 Le,e I 17 16 I I L I ,~att Cr~lt CERTIFICATE OF SURVEYOR I$4 I I I I TSN TTN I I [- I I 12 14 I I I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a proposed drilling location. Dimensions and other details furnished by Arco -Alaska Inc. · Date Surve~/or I SCALE: I"= I MILE PROPOSED ~JDETRACK SCU- 2.4 A- 5 Locoted in Sec 5 Alaska for ARCO ALASKA INC. RO. 80X I005~0 ~NOHOR~OF~ ~K. ~lO-O~O R.¢. DA¥1S t~ g$$0¢. LAND & MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH.tAK. 99516 STATE OF ALASKA ~ AI-~oKA OIL AND GAS CONSERVATION COMMISSION .... ~ ~'~:r WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [~] SUSPENDED ~] ABANDONED r-'] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-144 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-133-20256-01 4 Location of well at surface ~ ..... 9 Unit or Lease Name 1058' FSL, 1947' FEL, SEC 5, T7N, R9W SM 1104' FSL, 2277' FEL,SEC 5, T7N, ROW SM : /L!:!,~i': i - SCU 24A-5 AtTotal Depth i' '~'.. !i .... 1~ Field and Pool 1107' FSL, 2308' FEL, SEC 5, T7N, ROW SM SWANSON RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. HEMLOCK OIL POOL RKB 164', PAD 138'I A-028996 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 11/16/90. 1/7/91. 2/4/91. *I NA feet USL 1 17 Total Depth (MD+'rVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 10831' MD & 10800'TVD 10767' MD & 10736'TVD YES ~ NO r-]I NONE feetMDI 0' APPROX 22 Type Electric or Other Logs Run I EL/N DL/BHC-AL/GR/CAL/SP/SCBL/GYRO/PD K- 100 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18 SURF 91' 10-3/4" SURF 3390' 1263 SX CLASS G 7-5/8" 33.7# N-80 MILLED F/7027'-7090' 395 SX CLASS G 5-1/2" 20# N~80 6707' I 10175' 6-1/2" 250 SX CLASS G 2-7/8" 6.5~ N~80 9699'I 10831' 4-5/8" 2 SX CLASS G 24 Perforations open to Production (MD+'rVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" X 2-7/8" 9699' 9682' 10,520'-10,536' MD W/2" JJ @ 4 SPF 10,491 '-10507' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. DRLG RR 1/20/91 Form 10-407 Submit in duplicate Rev. 7-1-80 CONT1NUEDON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH HEMLOCK TOP 10189' 10165' HEM LOCK BO'FI'OM 10610' 10585' ! 31. LIST OF ATTACHMENTS GYRO, SUMMARY OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title AREA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil _.,d Gas Company Well History - Initial Report - Daily Inslructions: Prepare and su~)mit the "Initial Rel~Ort" on the first Wednesday after a well is spudded or workover operations are slatted. Daily woN( prior to spudding should be summarized on the form giving inclusive dates only. District !County. parish Or borough IState ARCO ALASKA INC. KENAI J AK Field Lease or Unit Iweu no. SWANSON RIVER ADL: A-028996 SC~ 24A-5 Auth. or W,O. no. ITitle AD7087 J DRILLING, COMLETE, PERF Operator IARCO W I ARCO I 48. 4864 Spudded or W.O. begun IOate IHour Prior st .....,a W.O. SPUD I 11/16/90 I 15:30 Date and depth Complete record for each day reported as of 8:00 a.m. GRACE 154 11/b6/90 (1) TD:10962' (10962) SUPV:EB 11/07/90 (2) TD:10962' ( 0) SUPV:EB 11/08/90 (3) TD:10962' ( 0) SUPV:EB 11/09/90 ( 4) TD:10962' ( 0) SUPV:EB The above is correct Signature NU BOPE MW: 9.0 VIS: 0 MOVE RIG FROM SCU 33A-8 TO SCU 24Ai5,ACCEPT RIG AT 20:00 HRS TBG PRESS=0 PSI, ANNULUS=450 PSI,ATTEMPT TO BLEED OFF A/TNULUS,TIE IN ANNULUS TO CHOKE MANIFOLD AND BLEED RAW GAS TO GAS BUSTER, SET 3" COSASCO TWO-WAY CHECK VALVE AND NIPPLE DOWN TREE,NU 9" 5M X 13-5/8" 5M ADAPTER AND BOPE DAILY:S100,200 CUM:S100,200 ETD:S100,200 EFC:$1,960,000 ATTEMPT TO PULL 3-1/2" PLUG MW: 9.0 VIS: 0 NU 13-5/8" 5M BOPE,CHANGE OUT BAD 3-1/2" RAM RUBBERS ON UPPER SET OF RAMS, TEST BOPE, TBG HANGER 3-1/2" BTC, PULL COSASCO TWO-WAY CHECK, RU SLICKLINE/PUMPIN SUB/LUBRICATOR BOP AND RIH,ATTEMPT TO LATCH 3-1/2" OTIS D BRIDGE PLUG AT 10236 POOH AND STRAIGHTEN PRONG, RIH W/PULLING TOOL, COULD NOT LATCH POOH,RIH AND WORK HYDROSTATIC BAILER ON TOP OF PLUG, POOH INSPECT BAILER, FULL OF CLEAN FLUID,RIH W/GS PULLING TOOL W/O EQUALIZING PRONG DAILY:S23,010 CUM:$123,210 ETD:S123,210 EFC:$1,960,000 C/O 2-3/8" TBG W/CTU MW: 9.0 VIS: 0 ATTEMPT TO PULL OTIS 3-1/2" 'D' BRIDGE PLUG @ 10236' W/'GS' PULLING TOOL, KEEP SHEARING PINS ON PULLING TOOL, RIH W/ 'GS' PULLING TOOL WITHOUT EXTENSION, LATCH AND PULL PLUG,POOH SLOW RECESSED POCKET ON PLUG FULL OF GLM DUMMY SHEAR PIN PIECES RIH W/1.75" GAUGE RING, TAG FILL @ 10276',POOH,GAUGE RING HEAVILY COATED WITH ASPHALTENES,RD SLICKLINE,REPAIR AND TEST HCR VALVE ON CHOKE LINE, TEST TO 250 PSI AND 4500 PSI,WO CTU MIRU CTU, WARM AND TRY TO START TRIPLEX PUMP,PRIME PUMP AND PERG CT TO TEST MTR, ICE PLUGS IN CT, RELEASE PRESSURE AND BRK OFF MTR, ATTEMPT TO CLEAR ICE PLUGS FROM 1.25" CT, RIH OPEN ENDED W/500 PSI'ON CT TO 500',ICE PLUG BROKE LOOSE,POOH,MAKE UP MTR AND 1-3/4" BIT, PRESSURE TEST CTU BOPE TO 2000 PSI,RIH AND CLEAN OUT 2-3/8" TBG DAILY:S22,522 CUM:$145,732 ETD:S145,732 EFC:$1,960,000 PU SQUEEZE PERF GUNS MW: 9.1 VIS: 0 CO 2-3/8" TBG, W/CTU TO 10770, REAM & CONT TO WASH TBG TO HARD FILL @ 10820CTM CIRC, POOH WHILE CIRC @ 1/8 BPM, DISP CT SPOOL AT SURFACE TO DIESEL, BRK OFF INJECTOR HD, LOST BIT & MTR IN HOLE WHILE CIRC, RD INJECTOR HD, MOVE OUT CTU, RU SLICKLINE RIH W/1.85 GR TO 10836 WLM, POH, RIH W/ 2-3/8" PS PLUG & SET IN S-3 NIPPLE @ 10795 WLM, POOH, RIH W 2-3/8" B SHIFTING TOOL & TRY & LOCATE, TIGHT @ 10321, JAR LOOSE, PULL TO 10261 WLM, ATTEMPT TO OPEN XA SLEEVE, POOH, RD, PRESS TO 1200 PSI ON TBG, SLEEVE NOT OPEN, RU ATLAS RIH W/ 1-11/16" PERF GUNS & PERF 2-3/8" TBG W/4 SPF @ 10490'-10500', ATTEMPT TO CIRC, PLUGGED, POOH CHECK GUNS, PRESS UP ON BACKSIDE, BROKE LOOSE, REV CIRC W/ 10 BBLS, CIRC DOWN TBG UP ANNULUS & CUT 9.6 BRINE T~ag.l#, MONITOR ~L, STABLE, PREPARE TO RIH W PERF GUNS FORICMT SQUEEZE For form preparation and distribution, DAILY: $46,563 CUM: $192,295 ETD: $192,295 ~i~l iPn ~o~7.S e c~,~ n 10 AR3B-459-1-D EFC:$1,960,00 INumber all daily well history forms consecutively as they are prepared for each well. ARCO Ok ,J G'as Company,~,,'"~' Daily Well History--lnterir Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Pro(:lucing Section will be reported on "Interim" sheets until fina[ coml~letion. 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 is set. Submit weekly for workovers and following setting of oil string until comptetlon District ICounty or Parish IState ARCO ALASKA INC I KENAI AK Well FJe~d ILease or Unit /30. . SWANSON RIVER J ADL: A-028996 SCU 24A-~ Date and deptl'l Complete record for each day while drilling or workover in progress <~s of 8:00 a.m. GRACE 154 11/10/90 (5) TD:10962' ( 0) SUPV:EB 11/11/90 ( 6) TD:10962' ( 0) SUPV:EB 11/12/90 (7) TD:10094' ( 0) SUPV:EB . POH-LD COMP ASSY MW: 9.1 VIS: 0 RIH W/AWLS 1-11/16" HOLLOW CARRIER PERF GUNS (26' LONG) COULD NOT GET BELOW 10620',POOH,RIH W/10' 1-11/16" SINKER BAR TO RESTRICTION AT 10635',SUSPECT ASPHALTENES F/CIRC PERFS AT 10500,SPUD DN TO 10645',POOH, PRESS UP ON TBG T0 2500 PSI,ATTEMPT INJ RATE THRU XA SLEEVES AT 10721' AND 10772',UNABLE TO INJ., PU 1-11/16" HOLLOW CARRIER GUN AND TIH TO FILL AT 10730',PERF 2-3/8" TBG W/ 4 SPF/180 DEG PHASING 10695-10705',WELL STABLE,POOH AND CHANGE GUNS,TEST LUBR. TO 2000#,TIH W/GUNS TO 10830',PERF 10750-10760',POOH AND CHANGE GUNS, TEST LUBR. TO 2000#,TIH AND PERF 10575-10585',MONITOR HOLE-STABLE,POH, EST. INJ RATE AT 2 BPM @ 2300 PSI,RUN 1-11/16" TEMP LOG FROM SURFACE TO 7200' CHANGE TOOLS RIH W/1.718" JET CUTTER AND CUT 2-3/8" TBG AT 10500',POOH & RD AWLS,PULL TBG HANGER LOOSE W/120K,CIRC HOLE TO 9.1 PPG, LD .LANDING JT AND HGR, POOH LAYING DN 3-1/2" BTC COMPLETION STRING DAILY:S4'2,761 CUM:$235,056 ETD:S235,056 EFC:$1,960,000 TIH W/5-1/2" CSG SCRAPER MW: 9.1 VIS: 0 CONT POOH AND LD 3-1/2" COMP. & 2-3/8" TAIL PIPE F/TBG CUT AT 10500',MONITOR HOLE, RD POWER TONGS AND TBG TOOLS, PU 4-1/8" MILL AND 5-1/2" 23# CSG SCRAPER ON 2-3/8" TBG STINGER AND DP,TIH (SLM) DAILY:S27,157 CUM:$262,213 ETD:S262,213 EFC:$1,960,000 TIH W/7-5/8" CSG SCRAPER ~;: 9.1 VIS: 0 CONT TO PU 3-1/2" DP,TIH W/5-1/2" CSG SCRAPER TO 2-3/8" STUB AT 10481' DPM, CBU TIGHTEN KELLY, POOH, LD SCRAPER, MU BAKER 5-1/2" K-1 MECH. CMT RETAINER, LD 1 JT 2-3/8" TBG, TIH TO 10470',CIRC STRING VOL, SET RETAINER, TEST BACKSIDE TO 2500#, RE-EST INJ RATE 2.4 BPM @ 2600 PSI,RELEASE FROM RETAINER, CIRC AND BATCH MIX 150 SX CLASS G CMT BLEND W/.9% FL-28/.2% CD-31/1 GHS FP-6L @ 15.8 PPG,PUMP 5 BBLS H20,TEST LINES TO 3000 PSI,PUMP 7 BBLS H20 FOLLOWED WITH 30.7 BBLS CMT, DISPLACE W/2.5 BBLS H20 AND 41 BBLS NACL BRINE WHILE HOLDING 1400 PSI ON BACK- SIDE, STING INTO CMT RETAINER AND DISPLACE 15.4 BBLS CMT BELOW RETAINER, REDUCE PRESS ON BACKSIDE TO 750 PSI,UNSTING FROM RETAINER AND SET 15.3 BBL BALANCED CMT PLUG ON TOP OF RETAINER, RELEASE CHOKE PRESSURE, POOH 10 STDS,CIP @ 2100 HRS ESTIMATED TOC=10094',REVERSE OUT DP,BLOW DN CHOKE MANIFOLD AND RD BJ, POOH, LD 95 JTS DP,CONT POOH AND LD 4 JTS TBG AND TOOLS,MU 6-1/2" BIT AND 7-5/8" CSG. SCRAPER AND TIH TO 7300' DAILY:S35,106 CUM:$297,319 ETD:S297,319 EFC:$1,960,000 The above is correct For fo~:m I~re~ar~lior~and distri6ujJon sea Proceo'fl~"e'~Manl~,al Section Drilling, Page~.~l 87 Date/, AR3B-459-2-B Number all dally well hl$1ory forms conseculively as they are prepared for each well. ARCO Oil· Gas Company ,~., '~' Daily Well History--lnterirr Inslructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attsch description of all cores. Work performed by Producing Section wilt be reported on "interim" sheets until hnal 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 is set. Submit weekly for workovers and following setting Of oil strmcj until completion. District Field Date and depth as of 8:00 a.nl. J County Or Parish IState A~ AT,A~KA TN~ ] KEHAT I Lease or-Unit ~WA~ RTVRR I ADT,: A-028qq6 'Complete record for each day while orilling or workover in progress ~RACE 154 11/13/90 ( 8) MILL CSG SECTION @ 7020' MW:10.0 VIS:100 TD: 7200' ( 0) FIN TIH W/7-5/8" CSG SCRP TO 7329' (SLM),POOH,LD SCRP SUPV:EB SERVICE RIG, PU 7-5/8" BAKER N-1 BRIDGE PLUG, TIH TO 7200',SET SAME,TEST CSG TO 2500 PSI,FINISH MIXING MUD, PUMP 100 BBLS H20 PREFLUSH AND DISP WELL W/ 10 PPG HI-VIS MUD,MIX AND PUMP PILL, LD 12 JTS DP,POOH, SET WEAR BUSHING, CALIPER AND PU MODEL D SECTION MILL/15 4-3/4" DC, STRAP WELD ON FISH TAIL BIT AND BLADE STAB,TIH, INITIATE CUT AT 7020' MILL 7-5/8" 33.7# Pll0 CSG TO 7027' DAILY:S34,387 CUM:$331,706 ETD:S331,706 EFC:$1,960,000 11/14/90 ( 9) POOH MW:10.1 VIS:ll0 TD: 7200' ( 0 SECTION MILL 7-5/8" 33.7# Pll0 CSG F/7027-7090',CBU, HOLE NOT SUPV:EB CLEAN, MONITOR WELL FOR FLOW, STABLE,POOH, LAY DN ALL TRI-STATE TOOLS,PU BIT & DRLG JARS,TIH TO 7-5/8" STUMP @ 7090',COULD NOT GET INTO STUMP,CIRC, ROTATE AND WORK PIPE TO BTM OF WINDOW AND CLEAN UP HEAVY METAL CUTTINGS,PUMP PILL, BLOW DN KELLY,POOH DAILY:S34,980 CUM:$366,686 ETD:S366,686 EFC:$1,960,000 11/15/90 (10) RIH TO TAG CMT MW:10.1 VIS: 47 TD: 7200' ( 0 FIN POOH, STRAP AND PU 2-3/8" TBG, RIH TO 7090',CIRC, RU BJ AND SUPV:WH BATCH MIX CMT, PUMP 17 BBLS CAUSTIC PREFLUSH/3 BBLS FRESH WATER, TEST LINES TO 3000#,PUMP 16 BBLS CLASS G BLEND W/.9% A-2/1% CD-31/.47% R-11/.l% A-7/1 GHS FP-6L, DISP W/ 4 BBLS FRESH WATER AND MUD, PULL 10 STDS,ATTEMPT TO REVERSE OUT PLUGGED OFF, CIRC LONG WAY AROUND, POOH, LD 2-3/8" TBG, PULL WEAR BUSHING, SET TEST PLUG, TEST BOPE 250-3000 PSI/250-5000 PSI,HAD TROUBLE RETR. TEST PLUG, PULL PLUG AND SET WEAR BUSHING, PU 6-1/2" BIT AND 4-3/4" DC'S,TIH TO TAG CMT. DAILY:S28,293 CUM:$394,979 ETD:S394,979 EFC:$1,960,000 11/16/90 (11) POOH MW:10.1 VIS: 43 TD: 7200' ( 0 DRLG CMT STRINGERS F/6570-6600',FIN DRLG TO 6905',WOC,DRLG SUPV:WH SOFT CMT 6926-6940' WOC,DRLG MED SOFT CMT 6940-7020',FIRM CMT 7020-7033',CIRC AND PUMP PILL, POOH TO PU KICKOFF ASSY DAILY:S21,590 CUM:$416,569 ETD:S416,569 EFC:$1,960,000 11/17/90 (12) DRILLING MW:10.1 VIS: 40 TD: 7058'( 0 GIH W/ KO ASS'Y. DRLD 29' CMT. POH SLM. 31' CORRECTION. SUPV:WH GIH W/ KO ASS'Y AND DRILLED TO 7058'. (TOP OF SECTION @ 7020'.) DAILY:S22,793 CUM:$439,362 ETD:S439,362 EFC:$1,960,000 AK I Weil no. SCU ~aA-5 The above is correct FOr form prepareS/on a4d distributian ~ \ see Proced~res~4anual~,Section 10 ~ Dril ng, Pages 8~..~' ' AR3B-459-2-B Number all dally well hislory forms consecutively as Ihey are prepared for each well. ARCO Oil, Gas Company Daily Well History--Interim Instl~ctiona: This form is used during drilling or workover operations. If testing, Coring, or perforating, show formation name in clescrlbing work performed. Number all drill stem tests sequentially, Attach description oT all cores. Work performed by Producing Section will be reported on "lnterirll" sheels until Iinal completion. Report official or representative test on "Filial" form. 1) Submit "lnfe~'Jm" sheets when filled out but not less frequently than every 30 days. or (2) On Wednesday o! the week in which oil string is set. Submit weekly for workovers and following setting of oH strin~i until comptelion. District ICounty or Parish ARCO ALASKA INC- J KENAI AK . Field ILea~e or Unit lWe'l no. _ SWANSON RIVER / APL: A-028996 Date and depth IComplete record for each day while drilling or workover in progress as of 8:00 a.m. I I GRACE 1.54 . 11/18/90 (13) I DRILLING MW:10.1 VIS: 39 TD: 7115' ( 57)I DRILLED TO 7096'. TRIP FOR BHA. PERFORMED PIT=14.5 PPG. SUPV:WH DRILLED TO 7115'. 2 E D 4 DAILY:S28,660 CUM:$468,02 T :$ 68,022 EFC:$1,960,000 11/19/90 (14) TD: 7185' ( 70) SUPV:WH 11/20/90 (15) TD: 7267' ( 82) SUPV:WH 11/21/90 (16) TD: 7357'( 90) SUPV:WH 11/22/90 (17) i TD: 7440' ( 83~ SUPV:WH 11/23/90 (18) TD: 7556' ( 1161 SUPV:WH 11/24/90 (19) TD: 7637' ( 81] SUPV:WH 11/25/90 (20) TD: 7715' ( 78] SUPV:WH DRILLING DRILLED AND SURVEYED TO 7122'. 7185'. DAILY:S28,805 CUM:$496,827 MW:10.1 VIS: 40 TRIP FOR BHA. DRILLED TO ETD: $496,827 EFC:$1, 960, 000 DRILLING MW:10.2 VIS: 41 DRILLED TO 7190'. TRIP FOR BHA. DRILLED TO 7267'. DAILY:S35,014 CUM:$531,841 ETD:S531,841 EFC:$1,960,000 POH MW:10.1 VIS: 40 DRILLED TO 7357'. RUN GYRO SURVEY. POH. DAILY:S26,154 CUM:$557,995 ETD:S557,995 EFC:$1,960,000 DRLG AHEAD MW:10.1 VIS: 40 FIN POOH,TEST BOP,TEST ANNULAR 250-3000 PSI/RAM LINES 250-5000 PSI,PULL TEST PLUG AND INSTALL WEAR RING,CHANGE BHA AND PULSER SUB,RIH,WASH 30' BOTTOM, NO FILL, DRLG FROM 7357-7440' DAILY:S39,729 CUM:$597,724 ETD:S597,724 EFC:$1,960,000 DRLG AHEAD MW:10.2 VIS: 43 DRLG F/7440-7500',SHORT TRIP,HOLE IN GOOD CONDITION, DRLG F/7500-7556' DAILY:S26,452 CUM:$624,176 ETD:S624,176 EFC:$1,960,000 CHANGE BIT/PU MUD MTR MW:10.5 VIS: 46 DRLG F/7556-7577',SURVEY, POOH, SERVICE RIG,CHANGE BIT, LD CHOKE SUB,CHECK MWD, RIH TO 6937',CUT DRLG LINE 100',SLIP 50',FIN TIH, JETS PLUGGED,PULL BACK INTO CASING AND UNPLUG JETS,RIH,DRLG TO 7637',SURVEY,POOH,CHANGE BIT, PU MOTOR DAILY:S34,145 CUM:$658,321 ETD:S658,321 EFC:$1,960,000 DRLG AHEAD MW:ll.8 VIS: 52 RIH,FILL PIPE EVERY 10 STANDS,ORIENT,DRLG F/7637-7675',PICK UP TO MAKE CONN., WELL FLOWING, SHUT WELL IN,PRESS STABILIZED AT SIDPP 100/SICP 300,RAISE MW TO 11.0 PPG,CIRC OUT KICK CIRC AND RAISE MW TO 11.8 PPG, SURVEY, BLOW DOWN CHOKE DRLG F/7675-7715' DAILY:S46,982 CUM:$705,303 ETD:S705,303 EFC:$1,960,000 T~e above is correct s ;ua,%ction ,o Drilling, Pages ~ AR3B-459-2-B INumber all daily well hislOry forms Consecutively as they are prepared for each well. ARCO Oil & ,.~as Company,~,"~' Daily Well History--Interim Inalructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show tormation name ~n describing work pertormed. Number all drill stem tests sequentially. Attach description of all cores. Work .oerformed by Producing Section ',,,,ill be reported on "lnlerim" sheets until linal 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 Field Date and depth as of 8:00 a.m. J County or Parish TtgC I KENAI I Lease or Unit ADT,: A-028996 Complete record for each day while drilling or workover in progress 11/26/90 (21) TD: 7820' ( 105 SUPV:WH 11/27/90 (22) TD: 7880'( 60 SUPV:WH 11/28/90 (23) TD: 7940' ( 60 SUPV:WH 11/29/90 (24) TD: 8053'( 113 SUPV:EB 11/30/90 (25) TD: 8103' ( 50 SUPV:EB 12/01/90 (26) TD: 8184' ( 81 SUPV:EB 12/02/90 (27) TD: 8297'( 113 SUPV:EB GRACE 154 JSlate .AK [ We!l no. $CU £4A-f DRLG AHEAD MW:12.0 VIS: 51 DRLG F/7715-7750',DRLG BREAK @ 7729',MUD CUT TO 11.4 PPG WELL FLOWING, RAISE MW TO 12.0 PPG, SHORT TRIP,HOLE IN GOOD CONDITION, DRLG F/7750-7820' DAILY:S29,885 CUM:$735,188 ETD:S735,188 EFC:$1,960,000 DRLG AHEAD MW:12.0 VIS: 51 DRLG 7820 TO 7848,MUD MOTOR FAILED, SURVEY,PUMP PILL, POOH CHANGE BHA, CHECK MWD, RIH, FILL PIPE @ 4977',FIN IN HOLE,WASH OUT 5' FILL TO 7848',CHECK FOR FLOW, WELL FLOWING, CIRC OUT GAS,GAS CUT TO 11.5 PPG,DRLG F/7848 TO 7880' DAILY:S40,154 CUM:$775,342 ETD:S775,342 EFC:$1,960,000 DRLG AHEAD MW:12.3 VIS: 50 DRLG 7880-7932',PUMP PILL,POOH, LD CHOKE SUB, INSPECT HWD SERVICE RIG, RIH,FILL PIPE @ 3500' AND 7000',CIRC OUT TRIP GAS (LOW CUT 11.7 PPG),DRLG 7932-7940' DAILY:S28,691 CUM:$804,033 ETD:S804,033 EFC:$1,960,000 SHORT TRIP MW:12.3 VIS: 50 DRLG 7940-8022',MWD FAILED, RUN WIRELINE SURVEY,DRLG 8022-8053' DAILY:S26,795 CUM:$830,828 ETD:S830,828 EFC:$1,960,000 DRLG AHEAD MW:12.3 VIS: 53 SHORT TRIP TO 7-5/8" CSG, NORMAL,DRLG F/8053-8100',DROP SURVEY,PUMP DRY JOB, BLOW OUT MUD LINES,POOH,NORMAL HOIST WEIGHT AND FILL, RETRIEVE SURVEY, PULL WB, TEST BOPE, SET WB SERVICE RIG, CHANGE OUT ~ND AND CHOKE SUB, RIH W/BHA AND TEST MWD, TIH TO 7-5/8" SECTION @ 7030',SLIP DL AND FILL PIPE, CONT TIH, BRK CIRC, WASH 8075-8103',BTMS UP CUT 11.8 PPG @ KELLY DAILY:S35,924 CUM:$866,752 ETD:S866,752 EFC:$1,960,000 POOH MW:12.2 VIS: 48 DRLG 8103-8115',MIX AND PUMP DRY JOB, POOH, 30K EXCESS @ 7155' NORMAL HOLE FILL, CHANGE BIT & TIH,FILL PIPE @ 5000',CONT TIH,BRIDGE @ 7115',BRK CIRC & SET BIT PATTERN, BTMS UP CUT TO 11.6 PPG, DRLG 8115-8184',SURVEY, PUMP DRY JOB, POOH DAILY:S30,450 CUM:$897,202 ETD:S897,202 EFC:$1,960,000 POOH MW:12.3 VIS: 47 CONT POOH,BIT CHANGE, FUNCTION BOP'S,TIH W/BIT,CHANGE OUT JARS & PU 6 JTS HWDP, CONT TIH, FILL AT 3000' & 6000',BRIDGE @ 8133',BRK CIRC AND WASH/REAM TO 8184', CHANGE OUT 4" UNION ON MUD LINE, BRK IN BIT, DRLG AHEAD,BTMS UP CUT TO 10.0 PPG, W/WATER AND GAS,DRLG AHEAD AND INCREASE MUD WT TO 12.3 PPG DRLG 8184-8297', SURVEY,PUMP DRY JOB, BLOW OUT MUD LINES The above is correct ~U',.)i-I. Signature~.F~ ~4"lk'~"C'%~ ,.-., ~ '\ ,IJ,P,. J..L,,[: $ 30, For form prepa, ia~on a~d distribu'Jior~ \ see Procedure~..Manual~Section 10, ~ Drilling, Pages 8~ E~C: $i, 960, 000 AR3B-459-2-B JNumber all dally well history forms conseculively as [hey are prepared for each well. ARCO Oii, ~ G'as Company Daily Well History--lnterir_ Instructions: This form is used during drilling or workover operations. If lesting, coring, or perforating, show formation name in describing work perlormed. Number all drill stem tests sequentially. Altach description of all Cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "'Final" form. 1) Submit "lnlerim" sheets when filled out bul not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State ADt",,~ AT.Z~qI,4A T~C' ~A][ AK Field ............. I Lease or Unit C~ANqD~4 RTL~ ADL: A-028996 Date and-depth - - Complete record for each day while drilling or workover in progress as of 8:00 a.m. 12/03/90 (28) TD: 8392' ( 95) SUPV:EB 12/04/90 (29) TD: 8521' ( 129 SUPV:EB 12/05/90 (30) TD: 8606' ( 85 SUPV:EB .12/06/90 (31) TD: 8666' ( 60 SUPV:EB 12/07/90 (32) TD: 8740' ( 74 SUPV:EB GRACE 154 SCU ~4A-5 DRLG AHEAD MW:12.3 VIS: 47 FIN POOH, BIT CHANGE,TIH W/BIT,FILL @ 3000' & 6000',WASH & REAM 8260-8297',NO FILL, SET PATTERN & DRLG AHEAD @ 8297' BTMS UP CUT TO 11.8 PPG,DRLG TO 8371', CHANGE SWIVEL PACKING DRLG 8371-8381',SURVEY,MIX AND PUMP DRY JOB, POOH,NORMAL DRAG AND FILL, BIT CHANGE,FILL DP @ 3000' AND 6000',WASH AND REAM 30' TO BTM, NO FILL, BRK IN BIT,DRLG 8381-8392',BTMS UP CUT TO 11.8 PPG DAILY:S28,793 CUM:$956,422 ETD:S956,422 EFC:$1,960,000 ORIENT/DRLG WITH MOTOR MW:12.3 VIS: 46 DRLG F/8392-8519',SURVEY,MIX AND PUMP DRY JOB, BLOW OUT MUD LINE,POOH,NORMAL DRAG AND HOLE FILL, LD STABS,BRK BIT, PU DRILEX 1 DEG BENT HOUSING MUD MTR & NEW BHA, TEST MWD & MTR TIH TO 7-5/8" SECTION,CUT DRLG LINE,SERVICE RIG, CONT TIH TO 8500',NORMAL, BRK CIRC,WASH 10' TO BTM, SURVEY & ORIENT MTR DRLG F/ 8519-8521', BTMS UP CUT TO 11.0 PPG DAILY:S37,972 CUM:$994,394 ETD:S994,394 EFC:$1,960,000 SHORT TRIP MW:12.3 VIS: 46 ORIENT DRLG W/MTR F/8521-8581',ROTRAY DRLG W/MTR F/8581-8606' DAILY:S36,521 CUM:$1,030,915 ETD:S1,030,915 EFC:$1,960,000 DRLG AHEAD MW:12.4 VIS: 46 SURVEY,PUMP DRY JOB, SHORT TRIP TO 7-5/8" WINDOW, NORMAL DRAG t~ATE REBUILT ELECT DC TRACTION MTR TO DWKS COMPOUND, RIH ROTARY DRLG W/STEERABLE MTR 8606-8647', BTMS UP CUT TO 11.6 PPG, DROP SURVEY, PUMP DRY JOB, POOH,NORMAL DRAG & FILL, RETR. SURVEY, BRK BIT, FLUSH & LD MUD MTR, PULL WB, TEST BOPE, SET WB BLOW OUT CHOKE MANIFOLD & MUD LINE, SURVEY MATCHED MWD, CHANGE BHA/LD MWD,TIH,BRK CIRC. & REAM 8625-8647',NO FILL, SET BIT PATTERN, DRLG 8647-8666' BTMS UP GAS CUT TO 11.6 PPG DAILY:S30,155 CUM:$1,061,070 ETD:S1,061,070 EFC:$1,960,000 DRLG AHEAD MW:12.4 VIS: 46 DRLG 8666-8717',DROP SURVEY, PUMP DRY JOB, POOH,NORMAL DRAG & HOLE FILL, RETRIEVE SURVEY, BIT CHANGE,COULD NOT READ SURVEY TIH SERVICE RIG, CONT TIH TO 8700',WASH & REAM 17' TO BTM, SET BIT PATTERN, DRLG 8717-8727',RUN WIRELINE SURVEY,DRLG TO 8736',REPLACE SWIVEL WASHPIPE &PACKING, DRLG 8736-8740',BTMS UP CUT 11.5 PPG DAILY:S31,962 CUM:$1,093,032 ETD:S1,093,032 EFC:$1,960,000 The above Js correct For form prepa~ ~lnd distributi~on see Procedure~',~anua~ Section 10. ~.. \ Drilling, Pages 86-"¢rm¢87 AR3B-459-2-B Number all daily well h~story forms conseculively as they are prepared for each well. ARCO Oil Gas company {~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or oerforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "Interim" sheets unljl final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when lilled out but not less frequenUy than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following selling of oil string until completion. District ~ate an'd ' We'Ct'a .... as of 8:00 a.m. 12/08/90 (33) TD: 8832' ( 92) SUPV:EB 12/09/90 (34) TD: 8922' ( 90) SUPV:EB 12/10/90 (35) TD: 9007' ( 85 SUPV:EB 12/11/90 (36) TD: 9103' ( 96 SUPV:EB 12/12/90 (37) TD: 9210'.( 107 SUPV:EB 12/13/90 (38) TD: 9325'( 1151 SUPV:EB 12/14/90 (39) TD: 9404'( 791 SUPV:WH ILease or Unit A~T,~* A-(]?RqqR Complete record for each day while drilling or workover in progress DRLG AHEAD MW:12.4 VIS: 48 DRLG 8740-8752',REPAIR SWIVEL PKG, DRLG 8752-8761',REPAIR SWIVEL PKG, DRLG 8761- 8805',PUMP PILL, POOH (SHORT TRIP) TIGHT AT 7331',TOP STAB @ 7144',CIRC & WORK TIGHT HOLE 7331-7320',CONT OUT TO WINDOW, TIH,NORMAL THRU TIGHT SPOT WASH 23' TO BTM, 5' OF FILL, DRLG 8805-8822',BTMS UP LOW CUT 11.8 PPG, RUN WIRELINE SURVEY DRLG 8822-8832' DAILY:S23,361 CUM:$1,116,393 ETD:SI,iI6,393 EFC:$1,960,000 Well no. DRLG AHEAD MW:12.4 VIS: 48 DRLG 8832-8870',PUMP PILL & SHORT TRIP TO WINDOW, NORM. AL CHANGE OUT SWIVEL & TEST SAME, TIH,DRLG 8870-8917',CIRC, RUN WIRELINE SURVEY,DRLG 8917-8922' DAILY:S22,964 CUM:$1,139,357 ETD:S1,139,357 EFC:$1,960,000 DRLG AHEAD MW:12.4 VIS: 48 DRLG 8922-8951',SHORT TRIP TO WINDOW, NORMAL, TIH, BTMS UP LOW CUT TO 12 PPG, DRLG 8951-8972',CHANGE OUT SWIVEL WASH PIPE AND PACKING, DRLG 8972-9007' DAILY:S24,274 CUM:$1,163,631 ETD:S1,163,631 EFC:$1,960,000 PUMP DRY JOB MW:12.3 VIS: 47 DRLG-9007-9012',CIRC & RUN WIRELINE SURVEY, KINK SLICKLINE 100' OFF LANDING BAFFLE,POOH W/SURVEY TOOL, SHORT TRIP TO 7-5/8" WINDOW, TIGHT @ 8038',TIH,BRIDGE @ 8038',CIRC, ROTATE& WORK TIGHT HOLE 8038-8075',CONT TIH,NORMAL,DRLG 9012- 9050' RUN WIRELINE SURVEY,DRLG 9050-9103' DAILY:S27,524 CUM:$1,191,155 ETD:S1,191,155 EFC:$1,960,000 PUMP DRY JOB MW:12.3 VIS: 47 PUMP DRY JOB, POOH TO 7-5/8" WINDOW,NOP_HAL, CONT POOH,GAGE STABS,LD MDC, CHANGE BIT,PU MWD & TEST,TIH, SERVICE RIG,CONT TIH,FILL @ 2500',5000',7500',CONT TIH TO 9075',NORMAL,WASH & REAM 9075-9103',NO FILL, SURVEY W/MWD, SET BIT PATTERN, DRLG 9103-9210' DAILY:S28,883 CUM:$1,220,038 ETD:S1,220,038 EFC:$1,960,000 POOH MW:12.4 VIS: 47 SURVEY AND PUMP PILL, POOH, LD LEAD COLLAR AND STAB, SERVICE RIG, RIH,FILL PIPE @ 3500' & 7000',SLIP DRLG LINE 50',FIN RIH WASH 5' TO BTM, DRLG 9210-9325',PUMP DRY JOB, POOH DAILY:S24,246 CUM:$1,244,284 ETD:S1,244,284 EFC:$1,960,000 DRLG MW:12.4 VIS: 50 FIN POOH,TEST BOP,HYDRIL 250-2500 PSI,RAMS,LINES AND VALVES 250-5000 PSI,PU STEERABLE MTR, CHECK MWD,RIH,WASH AND REAM 9270-9325',ROTATE 9325-9356',SLIDE 9332-9356',DRLG 9~5b-9~U~' The above is correct For form prepar. Eation ~J'~d disfribuho, n \ 'see Procedure~4anua~ Sect on 10,(,,,. Drilling, Pages 8~7 Number all daily well hislory Iorms conseculively as they are prepared for each well. .. AR3B-459-2-B ARCO Oil ~ Gas Company Daily Well History--lnterirr Inslructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets unlil final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less Irequently Ihan every 30 days, or (2) on Wednesday of the week in which oil string ie set. Submit weekly for workovers and following setting of oil string until completion. ,,~.: - District Field ~D~'n _AT,AC:~'A TNt Date depth as of 8:00 a.m. ILease or Unit ADT,: A-02~996 Complete record for each day while drilling or workover in Progress IWell no. SCU 12/15/90 (40) TD: 9504' ( 100) SUPV:WH 12/16/90 (41) TD: 9618' ( 114) SUPV:WH 12/17/90 (42) TD: 9689' ( 71 SUPV:WH 12/18/90 (43) TD: 9777' ( 88) SUPV:WH 12/19/90 (44) TD: 9880' ( 103) SUPV:WH 12/20/90 (45) TD: 9968' ( 88 SUPV:WH 12/21/90 (46) TD:10123' ( 155 SUPV:WH 12/22/90 (47) TD:10175' ( 521 SUPV:WH 12/23/90 (48) TD:10175' ( SUPV:WH DRILLING AHEAD ~:12.4 VIS: 46 DRLG TO 9450',SHORT TRIP,HOLE IN GOOD COND.,DRLG TO 9504' DAILY:S27,704 CUM:$1,307,335 ETD:S1,307,335 EFC:$1,960,000 DRILLING AHEAD MW:12.4 ~IS: 47 DRLG TO 9577',SHORT TRIP,HOLE IN GOOD COND.,SERVICE RIG,DRLG TO 9618 DAILY:S23,237 CUM:$1,330,572 ETD:S1,330,572 EFC:$1,960,000 DRILLING AHEAD MW:12.4 VIS: 47 DRLG TO 9662',SHORT TRIP,HOLE IN GOOD COND.,DRLG TO 9689' DAILY:S23,239 CUM:$1,353,811 ETD:S1,353,811 EFC:$1,960,000 DRILLING AHEAD MW:12.4 VIS: 46 DRLG TO 9700',POOH, LD 8 HWDP/JARS/MUD MTR, PU BIT/4 STABS TEST MWD,PU JARS/8 HWDP, RIH,DRLG 9700-9777' DAILY:S26,736 CUM:$1,380,547 ETD:S1,380,547 EFC:$1,960,000 DRILLING ~W:12.4 VIS: 46 DRLG TO 9792',CHANGE SWIVEL PACKING, DRLG TO 9827',SHORT TRIP & WORK TIGHT HOLE AT 7341',7250',7220',7201',RIH,WORK TIGHT HOLE AT 8890',DRLG TO 9880' DAILY:S24,316 CUM:$1,404,863 ETD:S1,404,863 EFC:$1,960,000 DRILLING AHEAD MW:12.4 VIS: 46 DRLG TO 9893',SHORT TRIP (TIGHT HOLE @ 7253' & 7154'),CUT DRLG-LINE 100',SLIP 50',FIN POOH, SERVICE RIG, TEST MWD,RIH (4' FILL),DRLG TO 9968' DAILY:S28,746 CUM:$1,433,609 ETD:S1,433,609 EFC:$1,960,000 DRILLING AHEAD MW:12.4 VIS: 46 DRLG TO 10004',SHORT TRIP TO 7-5/8" SECTION, TIGHT SPOTS,PULL 25K, RIH, NO FILL, DRLG TO 10123' DAILY:S23,343 CUM:$1,456,952 ETD:S1,456,952 EFC:$1,960,000 TEST BOP MW:12.4 VIS: 46 DRLG TO 10175,SURVEY, PUMP PILL, SHORT TRIP TO 7-5/8" SECTION CIRC, POOH, SLM, RU ATLAS WIRELINE,RUN CAL.-GR, TEST BOPE,HYDRIL 250-2500,RAMS,LINES AND VALVES 25Q -5000 PSI. DAILY:S75,690 CUM:$1,532,642 ETD:S1,532,642 EFC:$1,960,000 CIRC. MW:12.4 VIS: 47 RIG DOWN TEST JT,RIH,NO FILL, CBU, LOW CUT 11.6 PPG,CIRC, PULL TO SHOE,WAIT ON LINER HGR, RIH,NO FILL,CBU, LOW CUT 10.9 PPG DAILY:S72,589 CUM:$1,605,231 ETD:S1,605,231 EFC:$1,960,000 The above is correct For form pr~Par~tio~ and distrib~Jtion see Proced~%s Manual Section 10.' Drilling, Page 86-~ 87 AR3B-459-2-B Number all daily well h~s(ory forms conseculively as Ihey are prepared for each well. ARCO Oil ;~ . Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If lesting, coring, or perforating, show formalion name in describing work cerlormed. Number aH drill stem tests sequentially. Attacll description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until tinal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out bul not less Irec]uenlly Ihan every 30 days, or (2) on Wednesday of the week in which oil string Js set. Submit weekly for workovers and following selling of oil str~ng until completion. District ICounty or Parish ISlate Z~C'm AT,A.qKA TN(' ~ KENAI AK Field ..... JLease or Unit I cw:~4q~ RTVER I ADL: A-028996 SCU Date and-deptl~ - 'Complete record for each day while drilling or workover in progress as of 8:00 a.m. 12/24/90 (49) TD:10175' ( 0 SUPV:WH 12/25/90 (50) TD:10175' ( 0 SUPV:WH 12/26/90 (51) TD:10175' ( SUPV:WH 12/27/90 (52) TD:10175' ( SUPV:WH 12/28/90 (53) TD:10175' ( SUPV:EB GRACE The above is correct Signature For form preparation and distribution POOH MW:12.4 VIS: 47 FIN CIRC, SHORT TRIP TO 7-5/8" SECTION, TIGHT HOLE @ 8626' 7600',30K OVER, RIH,NO FILL,CIRC, SPOT BARATROL PILL, DROP RABBIT, POOH, SLM, RU CASING CREW, PU 5-1/2" 20~ N80 FL4S LINER & TIW LINER HGR, RIH,FILL DP EVERY 5 STANDS,CIRC 1.5 LINER VOL @ SECTION, FIN IN HOLE W/LINER, CBU, RECIPROCATE LINER, CMT LINER W/250 SX CLASS G CMT,SET HGR AND POOH DAILY:S27,814 CUM:$1,633,045 ETD:S1,633,045 EFC:$1,960,000 SET RTTS MW:12.4 VIS: 47 FIN POOH, LD LINER RUNNING TOOL,CLEAR FLOOR OF RUNNING TOOLS PU BIT,RIH TO 1865 SLIP DRLG LINE 50',FIN IN HOLE,TAG LINER TOP AT 6717',CIRC, POOH, LD MONEL STAB AND HWDP,SERVICE RIG,PU RTTS AND CIRC VALVE, RIH TO 6616',CIRC,WOC, LD 78 JTS 3-1/2" S135 DP,CIRC AND SET RTTS AT 6500' DAILY:S99,860 CUM:$1,732,905 ETD:S1,732,905 EFC:$1,960,000 RIH W/BIT MW:12.4 VIS: 49 SET RTTS @ 6481',PUMP INTO WELL @ 2 BPM 2900 PSI,BATCH MIX 250 SX CLASS G CMT @ 15.8 PPG, I.15 YIELD, 4.95 GAL/SX, 52 BBLS SLURRY, 26 BBLS CONTAMINATED, PUMP 10 BBLS WATER, 26 BBLS CMT, 5 BBLS WATER, 44 BBLS MUD @ 2900 PSI,SHUT IN 2150 PSI WOC PRESSURE BLED TO 1500 PSI,BLEED PRESSURE OFF, RELEASE RTTS CBU,POOH AND LD RTTS,PU BIT AND RIH DAILY:S21,899 CUM:$1,754,804 ETD:S1,754,804 EFC:$1,960,000 POOH MW:12.4 VIS: 47 FIN TIH, TAG CMT @ 6547',DRLG FIRM CMT 6547-6723',CIRC HOLE CLEAN, TEST LINER LAP TO 3100 PSI,PUMP DRY JOB, POOH, SLM, LAY DN 3 DC,TOL CORRECTION TO 6722',PU 7-5/8" HOWCO RTTS TOOL W/BYPASS AND TIH SLOW TO 6500',SET RTTS & TEST ANNULUS TO 2500 PSI,OPEN BYPASS & DISPLACE DP W/42 BBLS H20, CLOSE BYPASS,MONITOR WELL, 1.5 GPH NEG. FLOW, OPEN BYPASS & REVERSE CIRC OUT H20, PUMP PILL,POOH, LAY DN RTTS TOOL, PU 4-5/8" CMT MILL & TIH, DRLG CMT STRINGERS F/6723-6743',CBU, POOH DAILY:S23,818 CUM:$1,778,622 ETD:S1,778,622 EFC:$1,960,000 TIH MW:12.4 VIS: 46 FIN POOH & LD 4-5/8" DRLG ASSY,PU TIW POLISH MILL W/7-5/8" CSG SCRP POSITIONED 6' ABOVE MILL, TIH TO 5-1/2" LINER TOP @ 6722',CIRC, POLISH TIE BACK SLEEVE, POOH AND LD TOOLS,PU TIW 7-5/8" X 5-1/2" LINER TOP PACKER AND TIH SLOW, PKR TOOK 20K ADDITIONAL DOWN WEIGHT AT 6500' STOPPED AT 6534',FAILED , ATTEMPT TO CIRC DN DP, PRESSURE UP ANNULUS WITH BAG CLOSED TO 2000 PSI AND WORK PKR DOWN HOLE 40' JAR DN WITH AND W/O , PUMP,FAILED TO MOVE PKR DEEPER, RELEASE PRESSURE AND ATTEMPT TO PULL PKR UP HOLE, SLIPS SET, RELEASE RUNNING TOOL, PUMP PILL L~ 27 J~S 3-1/2~ D~, CUT DRLG Li::~,POOX! & LD TI~': · OOL,?OOL HE~LY COATED ;;,'C~e2-2~ A$~||ALT ~U AND W/3-1/8"DC &/129 JTS 2-7/8" ~P,PU JARS & CONT TIH W/3-1/2" t~V~e I I no. I Number all daily well h~sJory forms consecutively as they are prepared for each well. AR3B-459-2-B ARCO Oil ~. Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "'Final" form. 1) Submit "Interim" sheets when filled out but not less frecluently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setling of oil string until completion. District Field .qWAN.~N RTVER Date and depth as of 8:00 a.m. I County or Parish ALASKA TNC ~ KENAI JLease or Unit I ADZ.: A-028996 Complete record for each day while drilling or workover in progress 12/29/90 (54) TD:10175' ( SUPV:EB 12/30/90 (55) TD:10175' ( 0 SUPV:EB 12/31/90 (56) TD:10196' ( 21 SUPV:EB 01/01/91 (57) TD:10250'( 54 SUPV:EB 01/02/91 (58) TD:10330' ( 80 SUPV:EB 01/03/91 (59) TD:10411' ( 811 SUPV:EB 01/04/91 (60) TD:10500' ( 89 SUPV:EB GRACE 154 IState AK J Well no. SCU 214A-5 DP DAILY:S37,196 CUM:$1,815,818 ETD:S1,815,818 EFC:$1,960,000 LOGGING 5.5" LINER MW:ll.6 VIS: 46 CONT. TIH W/ 4.625 DRLG ASSY, TAG CMT 10032', DRLG FIRM CMT F/ 10032 T/ 10084 DRLG PLUGS AND FC, DRLG HARD CMT F/10085 T/10129,TEST CSG T/ 3000#,DRLG FC AND CMT F/10129 T/10149, CBU, POH,RU AWLS AND RUN GR/CCL/SBT IN 5.5" LINER DAILY:S29,330 CUM:$1,845,148 ETD:S1,845,148 EFC:$1,960,000 TIH MW:10.6 VIS: 43 LOG LINER, RUN GYRO, TIH SET STORM PCKR, C O BO?E. DAILY:S57,991 CUM:$1,903,139 ETD:S1,903,139 EFC:$1,960,000 TIH MW:10.2 VIS: 42 CONT TIH, DRLD CMT FS 6' NEW FORMATION, POH, PU BHA 23, TIH DRLG W/ MOTOR BIT QUIT POH, INSPECT BIT AND MOTOR, PU MILL SUSPECT BIT 26 TOOTH IN HOLE. DAILY:S33,275 CUM:$1,936,414 ETD:S1,936,414 EFC:$1,960,000 POH MW:10.1 VIS: 43 CONT TIH, WORK TIGHT SPOT AND MILL, POH, PU 3.5" DRILEX MOTOR AND RIH, WASH 20' TO BOTTOM, DRILL F/ 10196 T/10250, MOTOR QUIT, POH DAILY:S26,382 CUM:$1,962,796 ETD:S1,962,796 EFC:$1,960,000 DRLG MW:10.0 VIS: 43 POH, CHECK MOTOR...BROKEN SHAFT,PU 12 ADDITIONAL DC'SAND RIH WASH 20' TO BOTTOM DRLG FROM 10250 TP 10330 (ADT=16HRS) DAILY:S23,554 CUM:$1,986,350 ETD:S1,986,350 EFC:$1,960,000 POH MW:10.1 VIS: 44 DRLD F/ 10330 T/ 10411 (ADT 13.5),POH, PU NEW DRILEX MOTOR TIH, COULD NOT GET MOTOR TO DRILL, POH DAILY:S30,988 CUM:$2,017,338 ETD:S2,017,338 EFC:$1,960,000 DRLG MW:10.0 VIS: 43 CONT POH;SURFACE TEST MOTOR, CHANGE OUT BHA, TIH, REAM 11 FEET DRLG AHEAD WITH EXCESSIVE TORQUE DAILY:S21,537 CUM:$2,038,875 ETD:S2,038,875 EFC:$1,960,000 The above is correct Signature, ~ j~h, For form prepara. J~h ar~ distributJ'on . see Procedures .Manual Section 10, Drilling, Pages AR3B-459-2-B Number ali daily well hislory forms consecutively as ~hey are prepared for each well. ARCO Oil. · G'as Company Daily Well History--lnterirr Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until linal 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 is set. Submit weekly for workovers and following setting of oil strinG until completion. District ICounty or Parish IStale ................... iLease or Unit IWed no. Date an"d"de~fl%" .......... Complete record for each day while drilling or workover in progreSS as of $:00 a.m. 01/05/91 (61) TD:10650' ( 150) SUPV:EB 01/06/91 (62) TD:10689' ( 39) SUPV:EB 01/07/91 (63) TD:10820' ( 131) SUPV:EB 01/08/91 (64) TD:10831' ( 11 SUPV:EB 01/09/91 (65) TD:10831' ( 0 SUPV:EB 01/10/91 (66) TD:10831' ( 0 SUPV:WH 01/11/91 (67) TD:10831' ( SUPV:WH 01/12/91 (68) TD:10831' ( SUPV:WH G~ACE ] 54 DRILLING MW:10.0 VIS: 43 DR;G F/ 10500 T/ 10559, SHORT TRIP INTO CSG, SRLG F/ 10559 T/10650, VERY HIGH TORQUE AT TIMES - DAILY:S22,765 CUM:$2,061,640 ETD:S2,061,640 EFC:$1,960,000 TRIPPING MW:10.0 VIS: 42 DRLG 10650 T/ 10657, POH(NORMAL DRAG),CO BIT AND SERVICE RIG TIH,C&S DRLG LINE CONT. TIH,NO FILL, DRLG 10657 T/10688,HIGH TORQUE, DRLG 10688 T/10689 LOW TORQ TRY TO GET BIT TO DRILL POH, DAILY:S27,508 CUM:$2,089,148 ETD:S2,089,148 EFC:$1,960,000 DRILLING MW:10.0 VIS: 41 FUNCTION TEST BOPE,TIH, SWEEP BOTTOM W/ HIGH VIS PILL, DRLG 10689 T/10820 DAILY:S28,433 CUM:$2,117,581 ETD:S2,117,581 EFC:$1,960,000 POOH HW:10.0 VIS: 44 DRLD 10820 T. 10831,CIRC, SHORT TRIP, CBU, POH,LOG 4.625" HOLE, TIH WITH RR#30, 2' FILL,CBU, POH. DAILY:S65,466 CUM:$2,i83,047 ETD:S2,183,047 EFC:$1,960,000 CEMENTING 2-7/8"@10831' HW:10.0 VIS: 46 CONT. POH,CO PIPE RAMS,RIG UP TO RUN 2.875" TBG LINER, RIH W/ SAME,CIRC AND RECIPROCATE,RIGGING UP BJ AND BATCH MIXING. DAILY:S31,240 CUM:$2,214,287 ETD:S2,214,287 EFC:$1,960,000 RUNNING GYRO 2-7/8"@10831' MW: 9.6 VIS: 0 FIN BATCH MIX, PUMP CMT,CMTD 2.875" TBG LINER, WOC 12 HOURS RUN GYROS DAILY:S66,080 CUM:$2,280,367 ETD:S2,280,367 EFC:$1,960,000 CIRC 2-7/8"@10831' MW: 9.6 VIS: 0 FIN, RUNNING GYRO, RUN FREE POINT PIPE FREE AT 9740,RUN HOWCO CHEMICAL AND STUCK IT AFTER A MISFIRE,ATTEMPTED BLIND BACK OFF, BACKED OFF AT 2500', SCREWED BACK IN, WO AWS,RU AWS AND RUN JET CUTTER, CUT PIPE AT 8822'WLM, POH WITH AWS, CIRC PRIOR TO POH. DAILY:S55,974 CUM:$2,336,341 ETD:S2,336,341 EFC:$1,960,000 FISHING WIRELINE 2-7/8"@10831' MW: 0.0 VIS: 0 FINISH DISP BRINE, LD TBG, TEST BOPE, RU PRECISION WIRELINE, RIH W/ PULLING TOOL, JAR ON FISH,MOVE FISH FROM 8982 T/ 8950, ATTEMPT TO RELEASE FROM PULLING TOOL, WIRELINE ?ARTED,W OWL FISHING TOOL, R U TO FISH WIRELINE DAILY:S19,545 CUM:$2,355,886 ETD:S2,355,886 EFC:$1,960,000 The above is correct For form preP~"~ati~n an'~ distributior~ see Procedures I~nual ~ection 10, ~. ~ Drilling, Pages --....._.j AR3B-459-2-8 Number all daily well history torres consecutively as they are prepared for each well. ARCO Oil. . Gas Company ~, Daily Well History--lnterirr. Instructions: This form is used during drilling or workover operations. If testing, Coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnferlm" sheets unlil 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 is set. Submit weekly for workovers and following setting pt oil string unlil completion. District Field .............. INC. Date a n'r8' Wgl~ fl~'~'' as pt 8:~ a.m. 01/13/91 (69) TD:10831' ( SUPV:WH o) 01/14/91 (70) TD:10831' ( SUPV:WH 01/15/91 (71) TD:10831' ( SUPV:WH 01/16/91 (72) TD:10831' ( 0 SUPV:WH 01/17/91 (73) TD:10831' ( SUPV:WH 01/18/91 (74) TD:10831' ( SUPV:WH The above is correct Signature For form preparation and distribution sDer~lliPnr~,c~da .... M .... I Sges 86 and 8~eot on, 10~ I County or Parish J State KENAI Lease orUnit AP~T. · A-N?Rqq~ Complete record for each day while drilling or workover in progress GRACE 1 54 RIH W/ OVERSHOT 2-7/8"@10831' MW: 0.0 VIS: 0 RIH W/ WIRELFINDER TO 200'AND GRAB WIRE, PULL TO FLOOR, DROP WIRE CUTTER BAR RETRIEVED 8500' OF WIRE, RIH W/ OVERSHOT TO RETRIEVE CUTTER BAR, 3 ATTEMPTS, NO LUCK, RIH W/ 2.5" IMPRESSION BLOCK,NO IMPRESSION, ASSUME FILL ON TOP OF FISH PU TRISTATE 1.625" OVERSHOT AND 30'OF 2.25" PRT PIPE, RIH,WORK DOWN TO TOF, CIRC. MIX PILL,POH,LD PRT PIPE,WO FISHING TOOLS PU 4.25"OVERSHOT W/l/5" GRAPPLE, RIH... DAILY:S23,849 CUM:$2,379,735 ETD:S2,379,735 EFC:$1,960,000 PU ROTARY SHOE 2-7/8"@10831' MW: 0.0 VIS: 0 RIH W/4.25"OVERSHOT W/1.5"GRAPPLE,WORK OVER TOF TO 8963' (TOL),POH, LD 4.25" OVERSHOT, SERVICE RIG, SLIP DRLG LINE PU 2.25"PRT PIPE W/1.5"OVERSHOT,RIH, ATTEMPT TO GET INSIDE LINER TOP(8963),COULD NOT GET INSIDE, POH,MULESHOE BROKE OFF OF FISHING ASSY, LD ORT PIPE,PU 4"IMPRESSION BLOCK, RIH, SET IMPRESSION BLOCK, POH,PU 4.25" ROTARY SHOE W/ OVERSHOT BOWL W/2.875" GRAPPLE DAILY:S23,758 CUM:$2,403,493 ETD:S2,379,735 EFC:$1,983,758 MILLING 2-7/8"@10831' MW: 0.0 VIS: 0 PU ROTARY SHOE AND RIH (TORQUING EACH JOINT),MILL OVER STUB (8963-8965),CBU, POH,LD MILL, PU IMPRESSION BLOCK, RIH, SET BLOCK,POH,LD IMP. BLK, PU 4 5/8 FLAT BOTTOM MILL, RIH,MILL ON LINER STUB. DAILY:S20,462 CUM:$2,423,955 ETD:S2,423,955 EFC:$1,960,000 LD PRT PIPE 2-7/8"@10831' MW: 0.0 VIS: 0 MILL ON LINER STUB (8963-8968),REVERSE OUT, POH,LD MILL, PU PRT PIPE W/ 2.25"OVER SHOT,RIH,ATTEMPT TO WORK OVER FISH,POH CHANGE GUIDE (2 5/16" CUT LIP GUIDE, RIH,C&S DRLG LINE, FIN RIH,WORK OVER FISH, POH,NO FISH,CUT LIP GUIDE BROKE OFF, LD 2.25" PRT PIPE DAILY:S21,077 CUM:$2,445,032 ETD:S2,445,032 EFC:$1,960,000 FILTERIMG BRINE 2-7/8"@10831' MW: 0.0 VIS: 0 MU 4.25" OVERSHOT W/ 2.875" GRAPPLE, RIH,WORK OVER FISH ENGAGE OVERSHOT, WORK TORQUE DOWN STRING,BACKOFF TBG@9699' POH, LD FISH (731'OF TBG, CHEM CUTTER, WL TOOLS,MULESHOE),RIH W/ MILL AND SCRAPER, CIRC & FILTER BRINE. DAILY:S25,473 CUM:$2,470,505 ETD:S2,470,505 EFC:$1,960,000 POH 2-7/8"@10831' MW: 9.6 VIS: 0 CIRC AND FILTER BRINE,POH W/ MILL AND SCRAPER, TIGHT THRU TIE-BACK PKR, LD SCPR PU 4-5/8 MILL, RIH T/ 6575,WORK STRING MILL THRU PKR, POH, LD MILL, PU FB MILL AND 5.5"SCRAPER, RIH T/ 9680',WASH DOWN TO 9698 (TOP OF LINER STUB=9699), CIRC AND FILT~.K D~{INm, W(2H. DAILY:~'ZU, ! !9~Date CUM: $2,~9i,2~f~e~.ru:$2,491,284 E~C: $i, 960, 000 AK I We!l no. gC[~ 214A- ~ AR3B-459-2-B INumber all dally well history forms consecutively as Ihey are prepared for each well ARCO Oil._ .J Gas Company Daily Well History--lnterirr Instructions: This form is used during drilling or workover operations. If lesting, coring, or perforating, show tormation name in describing work 0ertormed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently Ihan every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ot oil strin§ until completion. District County or Parish State Field ................... IL ...... Unit I'//ell no. Date a~'~fb- .......... Complete record for each day while dril]ing or workover im progress as of 8:~ a.m. 01/19/91 (75) TD:10831' ( SUPV:WH RIH W/COMPLETION 2-7/8"@10831' MW: 9.6 VIS: 0 FPOH, LD JARS, SERVICE RIG, PU & RIH W/BAKER F-1 PACKER, SETTING TOOL & TBG TAIL ASSY, SLIP OVER TBG STUMP AND SET PKR @ 9682', TEST PKR TO 2000 PSI FOR 10 MIN, RELEASE FROM PKR, POOH LD DP & 3-1/2" DC, PULL WEAR BUSHING AND BREAK KELLY, CLEAR FLOOR, AND RIG UP TO RUN TBG STRING, PU BAKER ANCHOR LATCH SEAL ASSY AND RIH W/COMPLETION STRING DAILY:S31,272 CUM:$2,522,556 ETD:S2,522,556 EFC:$1,960,000 The above is correct Signature/,/~~ t,.,~~.A._~ h~Ioat.~ ~'~/~[ For(,orm preparation~ dis~ibution ' see Procedures Ma~91_~ect~ 10 Drilling,-Pages 86 an~ AR3B-459-2-B I Number all daily well history lorms consecuhlcely as they are prepared for each 'well ARCO O. and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel3Ol't" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whell operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completioI1 and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish ARCO ALASKA INC. I KENAI Field Lease or Unit SWANSON RIVER IT,tie ADL: A-028996 Auth. or W.O. no~ I ' AD7087 ~ DRILLING, COMPLETE IAccounting cost center code State AK _l Well no. SCU ~4A-5 Operator I AR.Co. W.I. I ARCO IDate 48. 4864 Spudded or W.O. begun SPUD I 11/16/90 Date and depth as of 8:00 a.m. 01/20/91 ('76) TD:10831 PB:10767 SUPV:WH Complete record for each day reported GRACE 154 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior stalus if a W.O. I 15:30 RIG RELEASED 2-7/8"@10831' TEST TO 5000 PSI, RELEASE RIG DAILY:S137,717 MW: 9.6 MaC1 CUM:$2,660,273 ETD:S2,660,273 EFC:$1,960,000 Old TD I New TO Released rig J Date I Classifications (oil, gas, etc.) Producing method IPB Depth Kind of rig IType completion (single, dual, etc.) Official r~servoir name(s) Potenlial test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective da~e corrected _. The above is correct For form p;e'pa"rati~ and Oistri'butigJ:~, ~)er ,~, ,Pn;O.C ~~,~ 7S. e c t, o n AR3B-459-3-C Number all daily well histo~ forms consecutively I aage ~o as hey are prepared for each well. Division of AflanticRJchfleldCompany D I~! I I--I-- I IM I~ SEFI%/ICE S Mr. Bill Matthews ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 January 14, 1991 Re: Boss Gyroscopic Survey Job No. BO-00166/LB-10005 Well: 24A-5 Field: Swanson River Survey Date: 12-29-90/1-10-91 Operator: Harger/McGuire Dear Mr. Matthews: Please find enclosed two (2) copies of our Boss Gyroscopic Survey tied in with our Level Rotor Gyroscopic on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Region Manager Enclosure 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Baroid Company PAGE SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -- ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -154.00 100 100.00 -54.00 200 199.99 45.99 300 299.98 145.98 400 399.97 245.97 0 0 0 47 0 44 0 48 0 50 N .00 E .00 .00 .00 N 48.50 W .79 .46N .52W N 48.70 W .05 1.34N 1.52W N 56.60 W .13 2.16N 2.59W N 61.40 W .08 2.90N 3.83W .0( 1.6~ 2.8~ 4.1~ 500 499.95 345.95 600 599.94 445.94 700 699.93 545.93 800 799.92 645.92 900 899.91 745.91 0 55 0 52 0 45 0 51 0 46 N 56.00 W .12 3.69N 5.14W N 56.60 W .05 4.56N 6.44W N 49.10 W .16 5.41N 7.56W N 60.00 W .19 6.21N 8.71W N 68.90 W .16 6.83N 9.99W 5.5! 7.0( 8.2: 9.4~ 10.8: 1000 999.91 845.91 1100 1099.90 945.90 1200 1199.90 1045.90 1300 1299.90 1145.90 1400 1399.90 1245.90 0 33 0 21 0 22 0 27 0 22 N 66'.40 W .22 7.26N ll.05W N 24.60 W .37 7.73N 11.62W N 2.10 E .17 8.33N 11.73W N 16.10 E .13 9.03N ll.61W N 29.40 W .33 9.70N 11.67W 11.9. 12.5' 12.7 12.7. 12.8' 1500 1499.89 1345.89 1600 1599.89 1445.89 1700 1699.89 1545.89 1800 1799.89 1645.89 1900 1899.88 1745.88 0 18 0 23 0 31 0 23 0 31 N 7.40 E .23 10.25N ll.80W N 25.00 E .14 10.82N 11.62W N 36.50 W .49 ll.50N 11.75W N 21.10 E .46 12.19N ll.90W N 18.70 E .13 12.93N 11.63W 13.0'. 12.9' 13.2: 13.4, 13.3( 2000 1999.88 1845.88 2100 2099.88 1945.88 2200 2199.87 2045.87 2300 2299.87 2145.87 2400 2399.87 2245.87 0 31 0 15 0 21 0 33 0 19 N 6.50 E .11 13.81N 11.44W N 25.40 E .29 14.47N 11.29W N 56.40 E .19 14.85N 10.93W N 27.80 E .29 15.45N 10.44W N 25.10 E .22 16.13N 10.10W 13.2 13.1 12.8 12.4 12.2 2500 2499.87 2345.87 2600 2599.86 2445.86 2700 2699.86 2545.86 2800 2799.86 2645.86 2900 2899.86 2745.86 3000 2999.86 2845.86 3100 3099.86 2945.86 3200 3199.86 3045.86 3300 3299.85 3145.85 3400 3399.84 3245.84 0 15 0 30 0 19 0 7 0 11 0 17 0 12 0 30 0 51 0 36 N 58.50 E .18 16.51N 9.79W N 35.50 E .30 16.98N 9.35W N 1.80 E .30 17.63N 9.08W N 87.30 W .35 17.93N 9.17W N 44.10 E .28 18.05N 9.16W N 24.90 W .28 18.40N 9.15W N 10.80 W .10 18.81N 9.30W N 59.20 E .48 19.22N 8.95W N 60.80 E .35 19.81N 7.91W N 61.60 E .26 20.43N 6.79W 11.9 11 .5 11.4 11.5 11.5 11.5 I1.7 11.5 10.5 9.5 PAGE SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -" ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDI DEGREES DG/100 NORTH/SOUTH EAST/ NATES VERT~ WEST SECT: 3500 3499.83 3345.83 3600 3599.83 3445.83 3700 3699.82 3545.82 3800 3799.81 3645.81 3900 3899.81 3745.81 0 43 N 81.40 E .26 20.77N 5 0 32 N 42.60 E .45 21.21N 4 0 40 N 51.60 E .16 21.92N 4 0 43 N 37.30 E .18 22.78N 3 0 43 N 33.30 E .05 23.81N 2 .71W 8.5] .77W 7.6~ .00W 6.9", .16W 6.2{ .43W 5.61 4000 3999.80 3845.80 4100 4099.78 3945.78 4200 4199.76 4045.76 4300 4299.73 4145.73 4400 4399.69 4245.69 0 49 N 48.00 E .22 24.83N 1 1 4 N 23.40 E .47 26.16N 1 14 N 37.80 E .33 27.87N 1 30 N 38.60 E .26 29.75N 1 1 40 N 40.80 E .19 31.88N 3 .54W 4.9- .64W 4.2: .39E 3.4'~ .87E 2.2,~ .65E .7~ 4500 4499.64 4345.64 4600 4599.57 4445.57 4700 4699.50 4545.50 4800 4799.43 4645.43 4900 4899.33 4745.33 2 2 N 34.30 E .42 34.46N 5 2 10 N 38.00 E .19 37.43N 7 2 8 N 35.00 E .12 40.46N 10 2 19 N 33.00 E .21 43.70N 12 2 35 N 36.00 E .30 47.23N 14 .61E -.8~ .78E -2.5' .02E -4.3r .20E -6.0! .64E -8.0~ 5000 4999.23 4845.23 5100 5099.13 4945.13 5200 5199.01 5045.01 5300 5298.87 5144.87 5400 5398.70 5244.70 2 33 N 27.40 E .39 51.05N 17 2 40 N 33.90 E .32 54.98N 19 2 58 N 34.30 E .29 59.06N 22 3 2 N 26.70 E .40 63.57N 24 3 34 N 32.50 E .63 68.56N 27 .00E -9.8~ .33E -11.6( .10E -13.7~ .75E -15.7~ .61E -17.9~ 5500 5498.49 5344.49 5600 5598.25 5444.25 5700 5697.95 5543.95 5800 5797.62 5643.62 5900 5897.24 5743.24 3 51 N 30.90 E .31 74.07N 31 4 7 N 28.30 E .33 80.13N 34 4 37 N 29.00 E .50 86.83N 38 4 46 N 24.40 E .40 94.15N 41 5 10 N 22.70 E .44 102.10N 45 .02E -20.5{ .45E -23.1; .llE -25.8: .79E -28.4r .25E -30.8( 6000 5996.82 5842.82 6100 6096.38 5942.38 6200 6195.93 6041.93 6300 6295.44 6141.44 6400 6394.93 6240.93 5 18 N 29.20 E .61 l10.30N 49 5 24 N 28.90 E .09 118.46N 53 5 33 N 30.30 E .21 126.77N 58 5 45 N 32.00 E .26 135.20N 63 5 48 N 21.00 E 1.11 144.18N 68 .25E -33.6~ .78E -37.0( .50E -40.5- .60E -44.4: .07E -47.6: 6450 6444.68 6290.68 6500 6494.45 6340.45 6550 6544.24 6390.24 6600 6593.96 6439.96 6650 6643.55 6489.55 5 49 N 8.10 W 5.84 149.06N 5 21 N 37.50 W 5.74 153.43N 5 25 N 69.00 W 5.85 156.13N 6 46 N 85.50 W 4.39 157.21N 7 48 S 84.00 W 3.37 157.09N 68.62E -47.5~ 66.84E -45.1, 63.21E -41.1~ 58.07E -35.9~ 51.75E -29.6! SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDI DEGREES DG/100 NORTH/SOUTH EAST/ NATES VERT. WEST SECT. 6700 6693.04 6800 6791.68 6900 6889.90 7000 6988.12 7050 7037.40 6539 6637 6735 6834 6883 .04 .68 .90 .12 .40 8 36 S 85.60 W 1.64 156.44N 44 10 15 N 88.00 W 1.95 156.18N 28 11 22 N 84.80 W 1.27 157.39N 9 10 22 S 80.40 W 2.95 156.78N 9 9 2 S 81.70 W 2.72 155.46N 17 .64E -22.74 .30E -6.58 .59E 12.11 .12W 30.5~ .44W 38.62 7100 7086.82 7200 7186.10 7300 7285.66 7400 7385.23 75OO 7484.82 6932 7032 7131 7231 733O .82 .10 .66 .23 .82 8 23 S 81.50 W 1.30 154.35N 24 5 16 S 82.00 W 3.11 152.63N 36 5 25 S 79.60 W .27 151.14N 45 5 16 S 78.20 W .20 149.34N 55 5 2 S 82.50 W .45 147.83N 63 .94W 45.85 .71W 57.32 .92W 66.24 .08W 75.06 .94W 83.62 7600 7584.43 7700 7683.98 7800 7783.45 7900 7882.92 8OO0 7982.37 7430 7529 7629 7728 7828 .43 .98 . :1- 5 .92 .37 5 4 N 87.50 W- .88 147.45N 72 5 46 S 87.60 W .84 147.43N 82 6 1 S 72.20 W 1.60 145.61N 92 5 48 S 63.00 W .97 141.TiN lO1 6 i1 S 66.10 W .51 137.23N ill .72W 92.27 .17W 101.64 .20W 111.32 .71W 120.2] .16W 128.9f 8100 8081.85 8200 8181.37 8300 8280.85 8400 8380.36 8500 8479.93 8600 8579.47 8700 8678.87 8800 8778.26 8900 8877.70 90O0 8977.27 7927 8027 8126 8226 8325 8425 8524 8624 8723 8823 .85 .37 .85 .36 .93 .47 .87 .26 .70 ~27 5 28 S 61.00 W .89 132.73N 120 5 46 S 67.50 W .70 128.49N 129 5 50 S 74.60 W .72 125.22N 138 5 28 S 75.10 W .38 122.64N 148 5 l0 S 77.80 W .39 120.46N 157 6 14 S 41.00 W 3.74 ll5.40N 165 6 16 S 47.60 W .72 107.61N 172 6 22 S 49.70 W .25 100.34N 181 5 48 S 58.60 W 1.10 94.12N 189 4 47 S 60.70 W 1.03 89.44N 197 .27W 137.3~ .08W 145.5( .64W 154.5£ .16W 163.5~ .17W 172.22 .14W 179.42 .74W 185.8~ .01W 193.07 .56W 200.6~ .51W 207.9: 9100 9076.97 9200 9176.69 9300 9276.29 9400 9375.71 9500 9475.05 8922 9022 9122 9221 9321 .97 .69 .29 .71 .05 4 4 S 74.60 W 1.29 86.46N 204 4 27 S 86.60 W .97 85.28N 211 5 43 S 86.90 W 1.26 84.78N 220 6 34 S 73.90 W 1.63 82.92N 231 6 39 S 62.70 W 1.29 78.68N 241 .57W 214.52 .87W 221.5~ .73W 230.2& .21W 240.41 .86W 250.38 9600 9574.41 9700 9673.84 9800' 9773.33 9900 9872.86 10000 9972.42 9420.41 9519.84 9619.33 9718.86 9818.42 6 15 S 67.90 W .70 73.97N 5 56 S 64.00 W .52 69.65N 5 40 S 62.60 W .31 65.10N 5 26 S 58.60 W .45 60.36N 5 22 S 62.10 W .34 55.70N 252.06W 259.83 261.77W 268.85 270.81W 277.19 279.25W 284.89 287.43W 292.35 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -- PAGE ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10100 10072.01 9918.01 5 0 10200 10171.64 10017.64 4 49 10300 10271.32 10117.32 4 15 10400 10371.08 10217.08 4 4 10500 10470.68 10316.68 5 55 S 66.02 W .51 51.74N 295.54W 299.8ff S 65.82 W .17 48.25N 303.37W 307.12 S 68.24 W .61 45.15N 310.65W 313.91 N 74.22 W 2.68 44.74N 317.51W 320.6~ N 89.77 W 2.27 45.73N 326.09W 329.2ff 10600 10570.17 10416.17 5 40 N 80.19 W 1.00 46.59N 336.12W 339.33 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 339.33 FEET AT NORTH 82 DEG. 6 MIN. WEST AT MD = 10600 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 277.89 DEG. PAGE 5 ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA CObIPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA - DATE OF SURVEY: 12-29-90/1-10-91 1/14/91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL blEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -154.00 .00 .00 .00 1000 999.91 245.91 7.26 N 11.05 W .09 2000 1999.88 1845.88 13.81 N 11.44 W .12 3000 2999.86 2245.86 18.40 N 9.15 W .14 4000 3999.80 3845.80 24.83 N 1.54 W .20 .09 .03 .02 .06 5000 4999.23 4845.23 51.05 N 17.00 E .77 6000 5996.82 5842.82 '110.30 N 49.25 E 3.18 7000 6988.12 6834.12 156.78 N 9.12 W 11.88 8000 7982.37 7828.37 137.23 N 111.16 W 17.63 9000 8977.27 8823.27 89.44 N 197.51 W 22.73 .56 2.41 8.70 5.75 5.10 10000 9972.42 9818.42 55.70 N 287.43 W 27.58 10600 10570.17 10416,17 46.59 N 336.12 W 29.83 4.85 2.25 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 12-29-90/1-10-91 1/i4/9i JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 54 54.00 154 154.00 254 254.00 354 354.00 -154.00 .00 .00 -100.00 .06 N .07 W .00 .95 N 1.07 W 100.00 1.80 N 2.06 W 200.00 2.57 N 3.24 W .00 .00 .00 .01 .01 .02 .01 .03 .01 454 454.00 554 554.00 654 654.00 754 754.00 854 854.00 300.00 400.00 500.00 600.00 700.00 3.29 N 4.53 W 4.18 N 5.85 W 5.01 N 7.10 W 5.86 N 8.12 W 6.60 N 9.41 W .04 ,01 .05 .01 .06 .01 .07 .01 .08 .01 954 954.00 1054 1054.00 1154 1154.00 1254 1254.00 1354 1354.00 800.00 900.00 1000.00 1100.00 1200.00 7.08 N 10.64 W 7.48 N 11.48 W 8.04 N 11.74 W 8.69 N 11.71 W 9.43 N 11.53 W .09 .01 .10 .01 .10 .00 .10 .00 .10 .00 1454 1454.00 1554 1554.00 1654 1654.00 1754 1754.00 1864 1854.00 1954 1954.00 2054 2054.00 2154 2154.00 2254 2254.00 2354 2354.00 1300.00 10.01 N 11.82 W 1400.00 10.54 N 11.74 W 1500.00 11.16 N 11.52 W 1600.00 11.89 N 11.99 W 1700.00 12.55 N 11.77 W 18Oo.oo 1900.00 2000,00 2100.00 2200.00 13.40 N 11.49 W 14.27 N 11.38 W 14.69 N 11.16 W 15.07 N 10.65 W 15.88 N 10.22 W .11 .00 .11 .00 .11 .00 .11 .00 .12 .00 .12 .00 .12 ,00 .13 .00 .13 .00 .13 .00 2454 2454.00 2554 2554.00 2654 2654.00 2754 2754.00 2854 2854.00 2300.00 2400.00 2500.00 2600.00 2700.00 16.39 N 9.96 W 16.67 N 9.58 W 17.36 N 9.10 W 17.91N 9.08 W 17.95 N 9.26 W .13 .00 .13 .00 .14 .00 .14 .00 .14 .00 2954 2954.00 3O54 3054.0O 3154 3154.00 3254 3254.00 3354 3354.00 2800.00 2900.00 3000.00 3100.00 3200.00 18.19 N 9.07 W 18.64 N 9.26 W 19.01 N 9.27 W 19.48 N 8.49 W 20.19 N 7.23 W .14 .00 .14 .00 .14 .00 .15 .00 .16 .01 ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE' SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ~ PAGE DATE OF SURVEY: 12-29-90/1-10-91 1/14/91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 OPERATOR: HARGER/MCGUIRE FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3454 3454.00 3554 3554.00 3654 3654.00 3754 3754.00 3854 3854.00 3300.00 3400.00 3500.00 3600.00 3700.00 20.67 N 6.27 W 20.91N 5.08 W 21.59 N 4.41W 22.33 N 3.51W 23.33 N 2.75 W .16 .01 .17 .01 .18 .00 .18 .01 .19 .01 3954 3954.00 4054 4054.00 4154 4154.00 4254 4254.00 4354 4354.00 3800 3900 4000 4100 4200 .00 .00 .00 .00 .00 24.38 N 2.02 W .20 .01 25.40 N .99 W .21 .01 27.09 N .20 W .23 .02 28.82 N 1.13 E .25 .02 30.87 N 2.78 E .29 .03 4454 4454.00 4554 4554.00 4654 4654.O0 4754 4754.00 4854 4854.0O 4300 4400 4500 4600 47O0 .00 .00 .00 .00 .00 33.14 N 4.69 E 36.07 N 6.72 E 39.07 N 9.04 E 42.15 N 11.20 E 45.58 N 13.44 E .33 .04 .39 .06 .47 .07 .54 .07 .62 .08 4954 4954.00 5054 5054.00 5154 5154.00 5255 5254.00 5355 5354.00 4800.00 49.26 N 16.06 E 4900.00 53.22 N 18.17 E 5000.00 57.14 N 20.79 E 5100.00 61.45 N 23.67 E 5200.00 66.22 N 26.14 E .72 .1'0 .82 .10 .94 .11 .07 .13 .21 .14 5455 5454.00 5555 5554.00 5655 5654.00 5756 5754.00 5856 5854.00 5300.00 71.51 N 29.48 E 5400.00 77.33 N 32.94 E 5500.00 83.73 N 36.40 E 5600.00 90.85 N 40.28 E 5700.00 98.50 N 43.74 E 1.41 .20 1.64 .23 1.90 .27 2.23 .33 2.58 .35 5956 5954.00 6057 6054.00 6157 6154.00 6258 6254.OO 6358 6354.OO 5800.00 106.83 N 47.32 E 5900.00 114.96 N 51.84 E 6000.00 123.24 N 56.44 E 6100.00 131.66 N 61.39 E 6200.00 140.30 N 66.57 E 2.99 .41 3.43 .43 3.88 .45 4.35 .48 4.86 .51 6459 6454.00 6559 6554.00 6660 6654.00 6761 6754.00 6863 6854.00 6300.00 6400.00 6500.00 6600.00 6700.00 149.98 N 68.45 E 156.46 N 62.35 E 156.94 N 50.32 E 155.94 N 35.11 E 156.73 N 16.78 E 5.36 .51 5.80 .44 6.55 .75 7.71 1.16 9.38 1.67 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE HEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6965 695'4.00 7066 7054.00 7167 7154.00 7268 7254.OO 7368 7354.00 6800.00 157.51 N 2.83 W 11.30 1.92 6900.00 155.08 N 20.04 W 12.80 1.51 7000.00 153.10 N 33.47 W 13.73 .93 7100.00 151.68 N 42.96 W 14.19 .46 7200.00 149.93 N 52.26 W 14.64 .45 7469 7454.00 7569 7554.00 7669 7654.00 7770 7754.00 7870 7854.00 7300.00 148.18 N 61.24 W 15.06 .42 7400.00 147.33 N 70.01 W 15.45 .39 7500.00 147.56 N 79.14 W 15.87 .42 7600.00 146.57 N 89.24 W 16.39 .52 7700.00 143.05 N 99.09 W 16.93 .55 7971 7954.00 8072 8054.00 8172 8154.00 8273 8254.00 8373 8354.00 7800.00 138.47 N 108.34 W 17.47 .53 7900.00 134.02 N 117.93 W 18.03 .56 8000.00 129.55 N 126.52 W 18.49 .47 8100.00 125.95 N 135.98 W 19.01 .51 8200.00 123.29 N 145.72 W 19.52 .51 8473 8454.00 8574 8554.00 8674 8654.00 8775 8754.00 8876 8854.O0 8300.00 120.95 N 154.87 W 19.96 .45 8400.00 117.27 N 163.25 W 20.39 .43 8500.00 109.46 N 170.72 W 20.98 .58 8600.00 102.09 N 178.95 W 21.58 .61 8700.00 95.37 N 187.50 W 22.18 .59 8976 8954.00 9076 9054.00 9177 9154.00 9277 9254.00 9378 9354.00 9478 9454.00 9579 9554.00 9680 9654.00 9780 9754.00 9881 9854.00 8800.00 90.40 N 195.81 W 22.65 .47 8900.00 86.89 N 203.00 W 22.97 .32 9000.00 85.39 N 210.11 W 23.24 .27 9100.00 84.90 N 218.50 W 23.60 .36 9200.00 83.62 N 228.81 W 24.14 .54 93'00.00 79.81 N 239.68 W 24.81 .67 9400.00 74.81 N 249.99 W 25.47 .66 9500.00 70.56 N 259.91 W 26.05 .58 9600.00 65.99 N 269.11 W 26.57 .53 9700.00 61.30 N 277.71 W 27.05 .48 9981 9954.00 10081 10054.00 10182 10154.00 10282 10254.00 10382 10354.00 9800.00 56.51 N 285.90 W 27.50 .45 9900.00 52.38 N 294.10 W 27.93 .42 10000.00 48.86 N 302.01 W 28.30 .37 10100.00 45.62 N 309.45 W 28.63 .33 10200.00 44.49 N 316.34 W 28.88 .25 PAGE SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA '--~ ARCO ALASKA, INC. SCU 24A-5 SWANSON RIVER ALASKA COMPUTATION DATE: 1/14/91 DATE OF SURVEY: 12-29-90/1-10-91 JOB NUMBER: BO-00166/LB-10005 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: HARGER/MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10483 10454.00 10300.00 10600 10570.17 10416.17 45.72 N 324.36 W 29.23 .35 46.59 N 336.12 W 29.83 .60 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering February 25, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is a subsequent report of operations for the perforating of SCU 24A-5. SCU 24A-5 was perforated in the H8 interval from 10,486' to 10,512' MD on February 17, 1990. The well is currently producing approximately 81 BOPD, 24,477 MCFPD and 2 BWPD. Sincerely, RECEIVED T. Wellman Regional Engineer TW:jkw:00045 -- - .... Oil ,& .Gas Cons. C~m~issi~ Attachment cc: Mr. A. 1~ Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering February 12, 1991 Mr. L, Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H8 interval in Well SCU 24A-5. We propose to perforate 26' of the H8 sand (10,486' - 10,512' MD) using 2 1/8" perforating guns @ 4 spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact David A. Pursell at 263-4258. ly Sincere , :.. ,. T. Wellman Regional Engineer TW:jkw:0042 Attachment cc' Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED FEB 2 ? 1991 Alaska 0il .& Oas Cons. Co.m~llssl0-n ~horage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend__ Alter casing __ Repair well Change approved program __ Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate -., Pull tubing __ Variance _ Perforate ~ Other 2. Name of Operator ARGO :Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, R9W, SM At top of productive interval At effective depth At total depth 1125' FSL, 1800' FEL, Sec. 5, T7N, Rgw, SM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ $. Datum elevation (DF or KB) RKB 164 '. G1 138' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 24A-5 9. Permit number 90-144 10. APl number 50-133-20256-01 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total Depth: measured true vertical 10,790' 10,762' Effective depth: measured 1 0,745' true vertical 1 0,71 7' Casing Length Size Structural 3 0' 1 8" Conductor Surface 3390' 1 0-3/4" Intermediate 7 0 2 7' 7 - 5 / 8" Production 3453' 5- 1/2" Uner 1092' 2-7/8" Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven 1263 sx Class G 395 sx Class G 250 sx Class G 17 bbls Class G Current: 10564'-10580' MD Proposed: 10486'-10512' MD true vertical Current: 10536'-10552' TVD Proposed:. 10458'-10484' TVD Tubing (size, grade, and measured depth 3-/2" @ 6473' MD; 2-7/8" from 6473'-9698' MD Packers and SSSV (type and measured depth) Packers: Liner Packer @ 6522', Baker F-1 Pet. Prod. Packer ~ 9651' 13. Attachments Description summary of proposal X Measured depth True vertical depth 91' MD 91' TVD 3390' MD 3390' TVD 7027' MD 7014' TVD 6722'-10175' MD 6715'-10147' TVD 9698'-10790' MD 9672'-10762' TVD REEEIVED FEB 2 7 t991 Alaska 0il & Gas Cons. C0.rnmissi0 t ;Anchorage Detailed operation program _ BOP sketch X 14, Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Cas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned /'77,,u'~~ Title Cook Inlet Regional En~]r. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance m Mechanical Integrity Test _ Subsequent form require 10- Approved by the order of the Commission Original Signed David W. Johns Commissioner Form 10-403 Rev 5/03/89 Approved Copy . i Rejturned SUBMIT IN TRIPLICATE Attachment #1 Well SCU 24A-5 H8 Sand Perforation Procedure Objective Perforate H8 Sand in order to increase oil production. Current Status SCU 24-5 is shut in due to hydrates. Minimum Restriction: X Nipple at 10,463' MD (ID = 2.318") Pressures: FTP 1200 psi PC 300 psi SC 0 psi Procedure .Prior to Perforating 1. RU slickline and tag with 2.2" gauge ring. RECEIVED FEB ~ 7' 199~ Alaska 0il .& (;as Cons. C0mmiS~i0u Anchorag~ 2. Shoot fluid level in tubing to verify liquid level is several hundred feet above perforated interval. 3. Contact Anchorage of_rice to verify sundry approval before proceeding. Perforating 1. MIRU E-Line Unit. Pressure test lubricator. 2. RIH w/ perf gun/GR/CCL. Gun orientation should be 90° rotated off bottom. Tie-in to peri the following interval in 2 gun runs: Interval Run No. [PDK- 100' 1-9-91) Footage [ft) Sand SPF Phasing 1 10,499-512 13 H8 4 180° 2 10,486-499 13 H8 4 180° -- * The original field print was off depth by -43'. The depths indicated are based on the corrected prints. Contact the Anchorage office if a corrected copy is not in the field. 3. POOH. Confirm that all shots have fired. RD E-Line Unit. · 4. RTP using adjustable choke. Test well on days 1,3, 5 following re- perforation. E-Line BOPE's _ Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves - Wellhead ARCO ALASKA INC. Cook Inlet Engineering #504 TRANSMISSION TO:. COMMISSIONER FROM: Victoria Ferguson COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: 2/22/91 WELL NAME: SCU 24A-5 Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled Mylar listing IEL-GR 1 1 4-ARM CAL \~-,n ~, -a{O 1 1 BHC-AC-GR 1 1 CN-GR 1 1 SBT 1 1 4-ARM CAL ~- ~"1 .a~ \ 1 1 Receipt Acknowledgement: ~&l,,vx ~ Return reciept to ARCO ALASKA, Inc. ATI'N: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: Western Atlas International ATLAS WIRELINE SERVICES A L~on/Dresser Company Judy Boegler Arco Alaska Inc. P.O. Box 100360 Anchorage, Ak. 99510-0360 February 21, 1991 RE: FINAL PRINT DISTRIBUTION ON WELL SCU 24A-5, SOLDOTNA CREEK UNIT, API# 50-133-20256-01 Enclosed you will find a full distribution of final prints. These final prints have been depth shifted to correct for a depth error that existed on the field prints. The first final print distribution had been depth shifted but a comment in the remarks section describing the depth shift had been omitted. The final prints included with this letter do include a comment in the remarks section describing the depth shift. Ail field prints on this well display data that has not been depth shifted. Those field prints should be discarded and replaced with prints labeled FINAL PRINT on the heading. LOGS THAT REQUIRED DEPTH SHIFTING: 4-Arm Caliper/Gamma Ray ...... 12-21-90 Segmented Bond Log- Induction Electrolog- Compensated Neutron BHC- Acoustilog- 4-Arm Caliper/Gamma Ray ...... PDK-100/Gamma Ray- .... 12-29-90 1-07-91 1-07-91 1-07-91 1-07-91 1-09-91 I appreciate your patience in this matter. If I can be of any additional service to you please do not hesitate to call me at any time. My office telephone number is 907-563-3233. Peter--'~n6h~Ster ~, Log Analyst The Atlas Advantage 5600 B Street, Suite 201, Anchorage, Alaska 99518, (907) 563-3233 ARCO ALASKA INC. Cook Inlet/New Ventures Engineering #496 TRANSMISSION TO: COMMISSIONER FROM: Victoria Ferguson COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: 2/7/91 WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia rape & lane Folded Rolled Mylar :listing SCU 24A-5 x 4-ARM CALIPER 12/21/90 (final) 1 1 ~ COMP. NEUTRON GR (final) 1 1 ,, BHC ACOUSTILOG GR (final) 1 1 '~ INDUCTION ELEC (final) 1 1 ~, PDK-100 1 1 \ 4-ARM CALIPER 1//7/91 1 1 '~ q'?~;3 ' PDK-100 1 ~'h~7~'% t OPEN HOLE 1 Receipt Acknowledgement: Remm reciept to ARCO ALASKA, Inc. ATI'N: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: ARCO ALASKA INC. Cook Inlet/New Ventures Engineering g485 TRANSMISSION TO:. COMMISSIONER COMPANY: AOGCC DATE: 117/91 FROM: Victoria Fer~son COMPANY: ARCO Alaska, Inc WELL NAME: SCU 24A-5 Transmitted herewith are the following Blue Sepia Sepia Fape & Dne Folded Rolled Mylar listing PDK- 100/GR/CCL 1 Receipt Acknowledgement: Date: Return reciept to ARCO ALASKA, Inc. ATYN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED r,,laska Oil & ,Oas Cor~s. Uomrnisslon Ancl~orage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 21, 1990 Mr. Lonnie Smith A(X3(3C 3001 Porcupine Drive Anchorage, AK 99501 Re: SCU 24A-5 Dear Mr. Smith: Enclosed is an application for Sundry Approvals for the above referenced well. ARCO Alaska requests to change the approved drilling permit, ADP 90-144, by setting a 2-7/8" liner at total depth. The approximate timeframe for setting this liner is early January 1991 so a timely response would be appreciated. If you have any questions, please call Bill Mathews at 263-4607 or Steve Edwards at 263-4608. Thank you, Steve Edwards Drilling Operations Aide STATE OF ALASKA · ,:. '.-,, ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program.X. Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1058' FSL, 1497' FEL, Sec. 5, T7N, RgE, SM At top of productive interval At effective depth At total depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 164,' GL 138' 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 24A-5 9. Permit number 90-144 10. APl number 50-133-20256-01 11. Field/Pool Swanson River Field Hemlock Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 9777' feet Plugs (measured) feet feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Size 18" 1 0-3/4" 7-5/8" Cemented Measured depth Driven 91' md 1263 sxs Class G 3399' md 395 sx Class G 7100' md True vertical depth 91' tvd 3399' tvd ARCO requests to change the approved drilling program by setting a 2-7/8" liner at total dept. procedure for details. Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal · - & 6as Cons. Detailed operation program _ ' ' I~¢l~{& 14. Estimated date for commencing operation January 1, 1 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~/'t~~~ Title Area Drilling] Engineer / FOR COMMISSION USE ONLY Date /~.-/~//'~O Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance~ Mechanical Integrity Test _ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Commissioner IApproval N¢~:~) I Date /' 4~¢~'/~ Form 10-403 Rev 06/15/88 Approved ~J':: ~:~' - RetUi'ne¢ SUBMIT IN TRIPLICATE ~;CU 24-5 Gen~r~al Procedure , Ensure well is dead. Wellbore should be full of 9.0 ppg brine. RU slickline and pull Otis 3-1/2" bridge plug set at 10,236'. 1 RU pumping unit. RIH w/ slickline and set "PS" plug in Otis position #3 "S" nipple at 10,795'. Open "XA" sleeve at 10,267'. RD slickline. Circulate 9.2 ppg NaC1 kill weight brine down tubing up annulus. . RU E-line and perforate tubing at 10,740'-10,750', 10,685'- 10,695', and 10,575'-10,585'. RIH with E-line and set 2-3/8" retainer at +10,530'. RD E-line. . RU CTU. GIH circulating 9.2 ppg NaC1 kill weight brine. Shut in annulus and sting into retainer. Establish injection rate. Squeeze H7, H5 and H1-4 perforations with +__75 sx 'G' cmt. 5. Pull out of retainer and circulate out excess cement. 6. POOH w/CT and RD. Install BPV. 7. Move in rig and rig up. . Pull BPV. Ensure that tubing is filled with brine and well is dead. 9. ND tree, NU BOPE, and test same. 10. RIH w/jet cutter and cut 2-3/8" tubing just above retainer. Pull present completion assembly and LD same. 1 1. Make bit and scraper run to top of tubing stub. 12. GIH and spot a 65 sx class'G' balanced cement plug on top of packer and tubing stub. POOH 7 stands and reverse out any excess cement. Top of cement should be +10,150' 13. POOH and stand back work string. RIH with slickline and set 7-5/8" bridge plug at +__7,150'. Build Hi-Vis 10 ppg mud system suitable for section milling. Displace wellbore with mud. 14. GIH w/ Tri-State Metal Muncher section mill for 7-5/8" 33.7# casing and mill 60' section from 7,000' to 7,060'. Monitor well for flow. CBU and POOH. 15. GIH open ended with 500' 2-3/8" tubing stinger. Spot balanced cement plug f/bridge plug to 200' above top of casing section. POOH 7 stands and attempt to squeeze 2-3 bbls into formation. Reverse out and apply 1500-2000 psi on cement for 1.5 times the tested thickening time. Release pressure and POOH. 16. GIH w/ 6-1/2" bit and dress off kick-off plug to 10' below top of casing section. POOH. 17. Sidetrack the well out of the casing section dropping angle @ 1 degree per 100' and turning 1.40 degree to the right per 100'. TD=+/-10150' TVD, +/-10172' MD. 18. Log open hole and make conditioning trip prior to running casing. 19. Run 5-1/2" production liner and cement same. 20. Clean out to TOL and test same to 2500 psi. Clean out inside of liner and retest to 2500 psi. 21. Run cased hole logs per logging program. 22. PU 4-5/8" cmt mill and clean out float equipment and 5-10 ft. of new hole. Perform LOT. 23. PU 4-5/8" bit and BHA and drill hole to 10805' TVD, 10831' MD per directional program. New BHL is 1800' FEL, 1125' FSL, Section 5. Condition hole for logging. POOH. 24. Run open hole logs. Condition hole for running 2-7/8" liner. 25. PU 2-7/8" liner, RIH and cement in place. Run cased hole logs, ~~~jI~Ilo~int 2-7/8" and cut just above free point. 26. 27. Install storm packer just below well head. Change out pack-off i big p 1 n tun soo .... Retrieve packer. .~nchoraf:;a '"'- 29. Run completion assembly. 30. ND BOP's, NU tree, and test same. 31. RD and MO rig. 32. Displace tubing with lease crude. P~x_ate with E-line and turn well over to Production Supervisor. SCU 24A-5 Completion Schematic Legend 10 12 13 14 15 (65 Jts.) Tubing, 3-1/2", N80, 9.38, EUE 8rd AB Mod (1 Ea.) Pup, 3-1/2" x 6', NS0, 9.38, EUE 8rd AB Mod (1 Ea.) GLM, Camco MMG, 3-1/2" x 1-1/2", EUE 8rd AB Mod., with dummy and latch (1 Ea.) Pup, 3-1/2" x 6', N80, 9.38, EUE 8rd AB Mod (146 Jts.) Tubing, 3-1/2", NS0, 9.38, EUE 8rd AB Mod (1 Ea.) X-over, 3-1/2" x 2-7/8", N80, EUE 8rd AB Mod (99 Jts.) Tubing, 2-7/8", N80, 6.58, EUE 8rd AB Mod (1 Ea.) Pup, 2-7/8" x 6', N80, 6.58, EUE 8rd AB Mod (1 Ea.) GLM, Camco KBMG-2, 2-7/8" x 1", EUE 8rd AB Mod., with dummy and latch, Max OD--4.631" (1 Ea.) Pup, 2-7/8" x 6', N80, 6.5#, EUE 8rd AB Mod (1 Ea.) Baker Mod. F-1 Packer, 5-1/2" x 2-7/8", with Tubing Anchor (1 Ea.) Pup, 2-7/8" x 6', N80, 6.58, EUE 8rd AB Mod (1 Ea.) Otis 'X' Nipple, 2-7/8", EUE 8rd AB Mod with 2.313" Profile ID (1 Ea.) Pup, 2-7/8" x 6', N80, 6.58, EUE 8rd AB Mod (1 Ea.) Tri-State Overshot Seal Assembly 16 17 18 Bottom Liner (26 Jts.) Tubing, 2-7/8", N80, 6.5#, EUE 8rd AB Mod (1 Ea.) Otis 'X' Nipple, 2-7/8", EUE 8rd AB Mod with 2.313" Profile ID (14 Jts.) Tubing, 2-7/8", N80, 6.58, EUE 8rd AB Mod with Baker Float Equipment Liner Top @ 6750' Setting Depths TVD MD 18" 91 91 10-3/4" 3399 3399 7-5~8" Window 7008 7020 5-112" Liner 10127 10150 2-7/8" Liner 10805 10831 Liner Top @ 9650' H1-5 H8-10 10770' PBTD 10831' TD ...... Above Depths Are Measurea October 31, i990 Telecopy No. (907) 276-7542 A W McBride Area Drilling ~nglnee_ ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Soldotna Creek Unit 24A-5 A~.CO Alaska Inc Permit ~ 90-144 Surf Loc 1058'FSL, .... !49_7!~L-,~S~c 5, T7N, R9W, SM Btmhole Loc 1125'FSL,~-.-iS00'FEL, Sec 5, T7N, R9W, SM ..... ~ Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and doe~ not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, David W Johnsto~y? C ommi s s ioner BY ORDER OF THE CO~iISS!ON jo enci C: Dept of Fish & Game, Habitat Section - w/o encl Dept o~ Environmental Conservation - w/o encl a' ~ OIL AND GAS C(~SERVATION ~ PERMIT TO DRILL 20 AAC 25.005 i la. Type of Work Drill ~ Redrill __ ~ lb. Type of Well Exploratory._.. Straligraphic Test __ Development Oil Re-Entry ~ Deepen ~] Service __ Development Gas -- Single Zone__ Multiple Zone_ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10.,.. Field and P~I r-- ARCO Ala. ske,, Irlg, RKB 164. Pad 138' Gl. feet -K-Gi.,~, u~ ..... 3. Address 6. Property Designation ~,,,.,~.,~" .............. ,.,r~ n~v~ ,..~,,' P. O. Box 100360, Anchora~]e, AK 99510-0360 A-028996 ,.¢,._,,,,~.,,~ £,~,~,/ 4. Location of well at surface ~f 7. Unit or I~'operty Name 11. Type Bond (see 20 AAC 25.025) 1058' FSL, 1497' FEL, Sec. 5, T7N, RgI~; SM Soldotqa Creek Statewide At top of produclive interval 8. Well number Number SCU 24A-5 #UG30610 At total depth W/ 9. Approximate spud date Amount 1125' FSL, 1800' FEL, Sec 5, T7N, RgI~, SM Nov 5, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVD) property line 14A-5 10,950' MD SCU @ 1000' feet 1600' ~ TD feet 3,640 10,920' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25,035(e)(2)) kickoff depth 7060' feet Maximum hoie annie 30° Maximum ~ur~ac,, 3752 p,~ At total depth (TVD) 5000 psi~l 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Lenc~th I~) TVD I~) 'I'VD (include sta~e dataI existin,7-3/8" 33.7# N-80 Section Mil from 7)00'-706~f , 6.5" 5-1/2" 20.0# N-80 4175' 6775' 10950' '~320Sxs ClassG , 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition Summary Total depth: measured 10,996' feet Plugs (measured) 24-5 pwill be P&A @ 7100' true verticaJ 10,575' feet 24A-5 will be sidetracked from 24-5 Effective depth: measured 10,953' feet Junk (measured true vertical 1 0,71 8' feet Casing Length Size Cemented Measured depth True Vertical depth Structural 1 8" Driven 91' 91 ' Conductor Surface 1 0-3/4" 1263 Sxs Class G 3390' 3390' Intermediate 7-7/8" 395 Sxs Class G 10565' 10365' Production 1~~,,~' Liner 5-1/2" 359 Sxs Class G 10359'-10996' 10176'- Perforation depth: measured 10570'-10886' (gross) @ 4 spf ~.. 20. Attachments Filing fee X Property plat _ BOP Sketch .2{,. Diverter Sketch -- Drilling ~/~.~~.. "25, "o ii ments X Drilling fluid program 'ri Time v,s depth plot __ Refraction analysis __ Seabed report 21. I herebycert~y~a~ the foregoing is true and correct to the besl of my knowledge Sign~(~ '~'-~,~.~.., ~~~.~ Title Area Drilling Engineer Date t.._..x' ~ ~/~P"I Commission use ~Nc~m '~/AP]-numi:~er I Approval date.] I See cover letler for Permit _b~,,~,~ I S0-/,_~.~- .~,~..Z ~.~_-~'/ 0/3.]/90 other ro,lu,reme.ts Candit*ions of approVal Samples required ~Y e s ,~ N o Mud log required~ Ye s ~ N o Hydrogen sulfide measures__ Y e s .,~ N o Directional survey required ,.~'Yas ~ N o Required working pressure for BOPE ~2M; ~ 3M' ~ 5M' ~ 10M' ~ 15M Other: Approved Commissioner the commission Date //'~ Form 10-401 Rev. ~ Submit in triplicate · J . 0 . . · . SCU 24-5 General Proc{~dure Ensure well is dead. Wellbore should be full of 9.0 ppg brine. RU si,oki,ne and pull Otis 3-1/2" bridge plug set at 10,236'. · RU pumping unit. RIH w/ slickline and set "PS" plug in Otis position #3 "S" nipple at 10,795'. Open "XA" sleeve at 10,267'. RD slickline. Circulate 9.0 ppg NaC1 kill weight brine down tubing up annulus. RU E-line and perforate tubing at 10,740'-10,750', 10,685'- 10,695', and 10,575'-10,585'. RIH with~.E-line and set 2-3/8" retainer at +10,530'. RD E-line. RU CTU. GIH circulating 9.0 ppg NaC1 kill weight brine. Shut in annulus and sting into retainer. Establish injection rate. Squeeze H7, H5 and H1-4 perforations with +._75 sx 'G' cmt. Pull out of retainer and circulate out excess cement. POOH w/CT and RD. Install BPV. Move in rig and rig up. RECEIVED OCT 2 19.90 , s .Ojt.a aas Cons, o ]miss! Pull BPV. Ensure that tubing is filled with brine and wdil~e~_~hor_a~ dead· · 10. 11. 12. 13. ND tree, NU BOPE, and test same. RIH w/jet cutter and cut 2-3/8" tubing just above retainer. Pull present completion assembly and LD same. Make bit and scraper run to top of tubing stub. GIH and spot a tot:)sx class'G' balanced cement plug on top of packer and tubing stub. POOH 7 stands and reverse out any excess cement. Top of cement should be +10,1~-0'. POOH and stand back work string. RIH with slickline and set 7-5/8" bridge plug at +7,150'. Build Hi-Vis 10 ppg mud system suitable for section milling. Displace wellbore with mud. 14. GIH w/ Tri-State Metal Muncher section mill for 7-5/8" 33.7# casing and mill 60' section from 7,000' to 7,060'. Monitor well for flow. CBU and POOH. 15. GIH open ended with 500' 2-3/8" tubing stinger. Spot balanced cement plug f/bridge plug to 200' above top of casing section. POOH 7 stands and attempt to squeeze 2-3 bbls into formation. Reverse out and apply 1500-2000 psi on cement for 1.5 times the tested thickening time. Release pressure and POOH. 16. GIH w/ 6-1/2" bit and dress off kick-off plug to 10' below top of casing section. POOH. 17. Sidetrack the well out of the casing section dropping angle @ 1 degree per 10ft and turning 1.40 degree to the right per 10ft. TD=+/-10920' TVD SS, +/-10950' MD. New BHL is 1800' FEL, 1125' FSL, Section 5. 18. Log open hole and make any additional necessary rat hole on the conditioning trip prior to running casing. 19. Run 5-1/2" production liner and cement same. 20. Clean out to TOL and test same to 2500 psi. Clean out inside of liner and retest to 2500 psi. 21. Run cased hole logs per logging program. 22. Install storm packer just below well head. Change out pack-off in tubing spool. 23. Retrieve packer. 24. Perforate w! TCP. POOH and LD drill pipe. 25. Run completion assembly. 26. ND BOP's, NU tree, and test same. 27. RD and MO rig. 28. Displace tubing with lease crude and turn well over to Production Supervisor. SCU 24A-5 5.-1/2" Liner D¢~i_~n Factor~ Casing 5-1/2", 20#/ft, N80, FL4S, R3 Collapse (psi) Burst (psi) Pipe Body Yield (M lb) Joint Strength (M lb) Make up Torque Tube I.D. Joint I.D. Drift I.D. 8,830 9,190 466 303.2 5,000 4.778 4.703 4.653 (minimum parting load) Capacity (BPF) (ft3/ft) 0.0221 0.1245 Setting Depths (ft) Total Footage (ft) 6,775 to 10,950 MD (10,860' PBTD) (6,765 to 10,920 TVD) 4,160 TENSION (Air Wt.) .loint Strength String Weight = 303,200/(4,160)(20.0) = 3.6 4 Pipe Body Yield String Weight = 466,000/(4,160)(20.0) = 5.6 0 COLLAPSE (Void Csg.) 1. ~ Assume 12 ppg mud weight maximum 2. Annulus full of mud Collapse (TD) Annular Pressure = 8,830/(10,920)(12.0)(.052) = 1.3 0 Collapse (TOL) = 8,830/(6,765)(12.0)(.052) = 2.09 Annular Pressure BURST (Top and Bottom) Too Burst -- 1. Worst case during production . 3. 4. 5. 6. Backup gradient of 8.9 ppg BHP = 5,000 psi @ TVD w/gas column to surface Tubing leak at surface. Oil packer fluid = 7 ppg Gas gravity = 0.65 SITP = BHP · 1/e (~ * TVD · 0.0000347) where: B HP = Bottom hole pressure ¥ = Gas gravity TVD = Total vertical depth SITP = (4,800)(1/e(0'65x10,920x0.0000347)) = 3,752 psi Top Burst = Burst Ratine + Backun -- _ SITP + Packer Fluid 9.190 + (8.9}(.052~(6,7~;0) 3,752 + (7.0)(.052)(6,750) = Bottom Burst 1. Worst case during treating or frac-away 2. Max treating pressure = 5,000 psi 3. Fluid weight = 8.9 ppg 4. Backup gradient = 8.9 ppg Bottom Burst = Burst Ratine + Backuo _ -- Surface Pressure + Fluid Gradient 9.190 + (8.9}(.052}(10.920) = 1.42 5,000 + (8.9)(.052)(10,920) SCU 24-5 7-5/8" CASING CALCULATION OPTIONS SOUR C-.-.-.-.-.-.-.-.-~ NOT CONSIDERED BUOYANCY NOT CONSIDERED EXISTING DESIGN - NO OPTIMIZATION PRODUCTION CASING O.D.,INCHES 7.625 CASING DEPTH,FT 10585. SHUTIN,PSI 5000 BURST BACKUP GRAD.,PSI/FT 0.465 INSIDE MUD WT,LB/GAL 12 OUTSIDE MUD WT,LB/GAL DESIGN FACTORS 12.00 C= 1.000 B=1.100 TJ= 1.800 TPB= 1.500 ***CASING SELECTION*** CASING DEPTH FT 10585 5878 3945 TYPE LB/FT FT/SEC S/SEC P-110 LTC 33.7 4707 125253 N- 80 LTC 29.7 1 933 391 24 N- 80 BTC 26.4 3945 75665 TOTAL COST MINIMUM DRIFT IS 6.640 INCHES 240042 ***CUMULATIVE LOADS*** CASING DEPTH RUNNING FT CLPSE BURST TENSION TENSION 10585 6592 6670 0 0 5878 3661 5928 158626 158626 5878 3661 5928 158626 458626 3945 2457 5623 216036 216036 3945 2457 5623 216036 216036 0 0 5000 320184 320184 ***DESIGN FACTORS - CALCULATED*** CASING DEPTH FT C B TJ TPB RTJ RTPB 5878 10585 1.19 1.63 5878 2.06 1.83 5,68 6.74 5.68 6.74 3945 1.22 1.16 3.62 4.31 3.62 4.31 3945 1.74 1.23 2,66 3.16 2.66 3,16 0 1,24 1.07 3.05 2.79 3.05 2.79 999.99 1.2 2.06 1.88 2.06 1.88 BURST RATING FACTORS (NOTE: NO SAFETY FACTOR INCLUDED) CRITICAL IVILD SURFACE SHUT-IN DEPTH WEIGHT CASING RUPTURE FEET LB/GAL PSI 3945 9 6012 3945 10 5807 3945 1 1 5602 3945 12 5397 3945 1 3 5193 3945 14 4988 3945 1 5 4783 3945 1 6 4578 3945 1 7 4374 5878 18 4132 DESIGN FACTOR(S) REDUCED TO CALCULATE DESIGN 1 -5/8 $000 PSI BOP STA DIAGRAM ACCUMULATOR CAPACITY TEST I I REYENTER/ C 3 II PIPE RAHS BLIND RAHS DRILLING SPOOL PIPE RAHS / · I TBo POOL 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3500 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE 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 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BO]rOM PIPE RAMS. TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 5,000 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 5,000 PSI. 11. RECORD TEST INFC~MAT~ ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 12. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BUND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED SCU 24A-5 Liner Schematic ,~_ 18"@91' 10-3/4" @ 3,399' Top of SCU 24A-5 5-1/2" Liner @ +/-6,775' 7-5/8" Window milled @ +/- 7,040'-7,100' Kickoff Cement Plug 7-5/8" Bridge Plug set @ +/-7,150' Top of Cement @ +/-10,150' Top of SCU 24-5 5-1/2" Liner @ 10,368' 7-5/8" @ 10,574' SCU 24-5 Abandoned Wellbore For Fish Detail See Attachment #3 PBTD @ 10,860' TD @ 10,950' Note: All depths are measured, corrected to RKB=164', G.L.=138',RKB-G.L.=26' (Original RKB-G.L.=17') K.I. TO I. UlDZI~ ~mXIJ~, o,.,,' o~ -7%' ^· t. '7,,0 L/~, .... ].C,?~, S],l' ,e,,,,' - :].0,72.1..95' '- - )""' 2t" ~0,/lI "C,"" $&lrt~ JT. 1 9L,~T JT. ].C62" -- 2J" 0725 'IA" ]. BLAST d?. 3.06~" OD ], SL.LS? J?. - q. n~ .cc' I M,.AST J?. ).C~:2" OD -, 2~j" .07~ "Lt," 3. BL,~? J F. ].O02" OD · e · ./ - 6,~.~" ~6,77~.~2' · - _ -, 10, ~2.08' tO,SI'O" ,o,,or_ ~,0,&~:~.83" lO,iii' I0,1~1' If. I. ?0 LA#DXIiG ".tUOIti;L ..Vl, z &. ~IDIG T.,ll ~ ~. ~0 BLFW. PVP JTS, · "C? SAF['L'~. JT. 1_ BLAST JT..].C62" 3. BLAST JT. 3, BI.~ST JT. "S" t,[PPLF., r~o$3*%:Lon "CC" $,L.F L"~ X ~L~T 3. 9TbL~T JT. "S" NJ:PPI. Z, Pos].%l, on X B~T JT. 3.C6~ ; OD OD OD OD OD OD OD o ;..'ri' t --2:k." OTXS "S" ~i/PPL~, pos3, r.:Lon ~2 1, BLAST JT. ;3.062" OD 2.G,86~.87' BAiteR STGP 'e'?~'~-( :LC,866-07' -- )" SO.R.F. 9AX':,R "t-L" PACKER v/2;ir" St-iL ,'w:Trr--~tO,572.t~/' )- CAPtGO "13" NIPPLE L ~LA~T JT. 2.~75" O0 B£VgtZD ' S.C.'U. 24 '- :5' CASING 8t TUBING Di SECTION 5 T. TN., R. 9~I STANOARO OIL. COMPANY OF P. ALI w~lT~ll# Op(R&ttOIqS mC.~/~' lO, O00j~ C:IIOICZ KK~.orOL, D ~,~t IKZDDiD _ (1)' (3) (4) (S) 10,000t LZlIB,~~I 10,000! ~ 4" 10,000! VZqlZ,~ 3' 10,000! YALVBI 10,000! I~DIU~ULZ¢CHOEB8 3' S000! VAr, VII 3' x S000I ~~t 3" X SOQOJ LZ~ 4" X S000J ~ Grace 154 Drilling Fluld. System %/.! ti L ti Il SCU 24A-5 Drilline Fluids Proeram _ -- From Sidetrack Point to Total Depth Density 10.0-10.5 Funnel Viscosity 38 - 46 PV 12-18 YP 8-12 Initial Gels 2- 10 10 minute Gels 5-20 Fluid Loss 15- 5 * pH 8.5-9.5 % Solids 6-12 * = Maintain fluid loss at 10cc or less below 10,400' TVD Drilling Fluid System - Dual tandem shale - Mud cleaner - Centrifuge - Degasser - Pit level indicators - Trip tank - Fluid flow sensor - Fluid agitators shakers (visual and audio alarm) EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes all earlier versions. Updated versions are available, f¥om EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) Comoonents Maximum Allowable Concentration 1. Seawater/Freshwater/Potassium/ Polymer Mud KCI 50 Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed 4. Nondispersed Mud Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As Needed 5. Spud Mud 2. Lignosulfonate Mud . Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome Treated 10 Caustic 5 Lime Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed Lime Mud Lime 20 Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or Freshwater As needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. The following additives have been approved by EPA in Alaska. Not all of these additives will necessarily be used during the redrills. Product Nnm? Maximum Allowable Ge.n_eric Description Concentration (Ib/bbl) Aktaflo-S Aqueous solution of non-ionic modified phenol (equivalent of DMS) Aluminum stearate - - 0.2 Ammonium nitrate 200 mg/1 nitrate or 0.O5 lb/bbl Agua-Spot Sulfonated vegetable ester formulation 1% by volume Bara Brine Defoam Dimethyl polysiloxane in an aqueous emulsion 0.1 Ben-Ex Vinyl acetate/ma!eic anhydride copolymer Bit Lube II Fatty acid esters and alkyl phenolic sulfides in a solvent base Calcium Carbide As needed Cellophane flakes As needed Chemtrol-X Polymer treated humate Con Det Water solution of anionic surfactants 0.4 D-D Blend of surfactants 0.5 DMS Aqueous solution of nonionic modified phenol Desco CF Chrome-free organic mud thinner containing 0.5 sulfo-methylated tannin Duovis Xanthan gum 2 Product Name Generic Description ,~laximum Allowable Concentration (Ib/bbl) Durenex Lignite/resin blend Flakes of silicate mineral mica -- 45 Gelex Sodium polyacrylate and polyacrylamide Glass beads LD-8 Aluminum stearate in ropoxylated oleylalcohol 10 gal/1500 bbl Lube -106 Oleates in mixed alcohols Lubri-Sal Vegetable ester formulation 2.0% (by volume) MD (IMCO) Fatty acid ester 0.25 Milchem MD Ethoxylated alcohol formulation 0.04 gal/bbl or 0.3 Ib/bbl MiI-Gard Basic zinc carbonate As needed Nut hulls, crushed granular As needed Phosphoric acid esters and triethanolamine 0.4 Plastic spheres Poly RX Polymer treated humate 4 Resinex Reacted pheno-formaldehydeurea resin containing no free phenol, urea, or formaldehyde Selec-Floc High molecular weight poly- acrylamide polymer packaged in light mineral oil 0.25 Sodium chloride 50,000 mg/! chloride Sodium nitrate 200 mg/I nitrate or 0.05 Ib/bbl Product Name Generic Description -. ,vlaximum Allowable Concentration (Ib/bbl) Sodium polyphosphate-- 0.5 Soltex Sulfonated asphalt residuum Sulf-X ES Zinc oxide As needed Therma Check Sulfono-acrylamide copolymer Therma Thin Polycarboxylic acid salt 4 Torq-Trim II Liquid triglycerides in vegetable oil Vegetable plus polymer fibers, flakes, and granules 5O VG-69 Organophilic clay 12 XC Polymer Xanthan gum polymer XO2 Ammonium bisulfite 0.5 Zinc carbonate and lime -- As needed GREAT LAND DIRECTIONAL DRILLING, INC. Client .... : ARCO ALASKA, INC. Field ..... : Swanson River Well ...... : $CU 24-5 Section at: S,78.10,W Engineer..: S MEAS INCLN C DEPTH ANGLE 8 476 1.00 1 991 0.50 1 1668 0.00 1 2138 0.50 I 2743 0.25 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD RECORD OF SURVEY (Calculated from a tie-in station at 476 ~D) 10/22/90 Computation...: R/~DIUS OF CURVATURE Survey Date...: 10/22/90 RKB Elevation : 155 08 ft Reference · Magnetic Dcln.: 2~.00 E 475.9 320.8 6.2 N 60.00 W 4.2 N 7.2 990.9 835.8 10.7 N 49.00 W 8.1 N 12.7 1667.9 1512.8 11.4 N 0.00 E 10.7 N 13.9 2137.9 1982.8 11.7 N 46.00 W 12.5 N 14.6 2742.8 2587.8 12.7 N 5.00 W 16.0 N 16.3 CLOSURE DL DISTNCE BEARING /100 8.3 N 60.01 W <TIE 15.0 N 57.54 W 0.10 17 5 N 52 42 W 0 07 19.3 N 49.50 W 0.11 22 8 N 45 54 W 0 04 ' ' ' 3249 O. 75 3535 0.75 3938 0.75 4369 I. 00 4841 2.00 3248.8 3093.7 9.7 N 77.00 E 19.3 N 13.9 W 3534.8 3379.7 6.0 N 60.00 E 20.6 N 10.5 W 3937.8 3782.7 1.1 N 51.00 E 23.6 N 6.1 W 4368.7 4213.6 -4.0 N 29.00 E 28.6 N 1.9 W 4840.5 4685.5 -13.3 N 44.00 E 38.5 N 5.4 E 23.8 N 35.85 W 0.10 23.1 N 26.86 W 0.00 24.4 N 14.51 W 0.00 28.7 N 3.81 W 0.06 38.9 N 8.00 E 0.21 I 5OO0 2.75 t 53~2 3.00 1 5536 3.75 1 5777 4.75 I 6163 5. O0 6380 5.50 6480 5.50 6543 4.75 6605 6.50 6702 8.50 1 6797 9.50 4999.4 4844.3 -18.6 N 42.00 E 43.4 N 9.9 E 5311.0 5155.9 -31.0 N 38.00 E 55.3 N 20.0 E 5534.6 5379.5 -40.4 N 30.00 E 66.3 N 27.3 E 5775.0 56t9.9 -52.9 N 35.00 E 81.3 N 36.9 E 6159.6 6004.5 -76.9 N 35.00 E 108.2 N 55.7 E 6375.7 6220.6 -91.5 N 36.00 E 124.4 N 67.3 E 6475.2 6320.1 -96.0 N 2.00 W 133.4 N 70.0 E 6537.9 6382.9 -94.7 N 50.00 W 138.3 N 67.6 E 6599.6 6444.6 -89.8 N 85.00 W 140.6 N 62.1 E 6695.8 6540.7 -77.5 N 90.00 W 141.1N 49.5 E 6789.6 6634.6 -63.1 N 85.00 W 141.8 N 34.6 E 44.5 N 12.88 E 0.47 58.8 N 19.84 E 0.08 71 7 N 22 42 E 0 34 89.3 N 24.42 E 0.42 121.7 N 27.26 E 0.06 141.4 N 28.41 E 0.23 150'.6 N 27.70 E 0.35 153.9 N 26.06 E 1.30 153.7 N 23.84 E 2.91 149.5 N 19.32 E 2.O6 145.9 N 13.72 E 1.06 'Survey Codes: 1/SINGLE SHOT 8/TIE-IN ( SCU245 ) SCU 24-5 MEAS INCLN DEPTH ANGLE 6923 11.25 7048 10. O0 7142 10.25 7148 10,37 7248 12,35 RECORD OF SURVEY (Calculated from a tie-in station at 476 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 691.3,6 6758,5 -41,7 N 80,00 W 144,7 N 12,1 E 7036,4 6881,3 -19,1 S 74,00 W 143,5 N 10,7 W 7129.0 6973,9 -3,0 S 60,00 W 137,1 N 25,9 W 7134,9 6979,8 -1,9 8 60,33 W 136,6 N 26,8 W 7232,9 7077,8 17.1 S 65,89 W 127,6 N 44,4 W Page 2 I0/22/90 CLOSURE DL D I STNCF. BEARING / 1 C 145,2 N 4,79 R 1,40 143,9 N 4,26 W 1,18 139,5 N 10,68 W 0,54 139,2 N 11.10 W 1,99 135,1 N 19.16 W 2,00 7268 12,75 7348 14,39 7390 15,25 7448 16,42 7452 16.50 N 7548 16,37 1 7643 16,25 1 7696 15,25 1 7915 16,50 1 8031 18,00 7252,4 7097,3 21,3 S 67,00 W . 125,9 N 48,3 W 7330,2 7175,1 39,8 S 70,28 W 119,1 N 65,8 W 7370,8 7215,7 50,5 S 72,00 W 115,6 N 76.0 W 7426,6 7271,5 66,3 S 72,94 W 110,8 N 91,1 W 7430,4 7275,3 67,4 S 73,00 W 110,5 N 92,2 W 7522,5 7367,4 94,4 S 73,00 W 102,6 N 118,1 7613.7 7458,6 121.0 S 73,00 W 94,8 N 143.7 7664,7 7509,6 135,4 S 77.00 W 91,0 N 157,5 7875,3 7720,2 195,3 S 76,00 W 77,1 N 215,8 7986,1 7831.0 229,6 S 82.00 W 70,5 N 249,5 134.9 N 21.00 W 2.00 136.1 N 28.93 W 2.06 138,3 N 33,32 W 2,07 143.5 N 39.41 W 2.02 143.9 N 39.83 W 2.02 156,4 N 49,04 W 0,13 172,1 N 56,59 W 0,13 182 0 N 59 98 W 1 96 229.1 N 70.35 W 0.5' 259,3 N 74,23 W 1,3~ 8169 18.75 8248 18.75 8398 19.00 8525 18.75 8680 18,50 8117,1 7962,0 273,0 S 82.00 W 64,4 N 292,6 W 8191,9 8036,8 298.4 S 82,00 W 60,9 N 317,8 W 8333,8 8178.7 346,7 S 85,00 W 55,4 N 366.0 W 8454.0 8298,9 387,5 S 85,00 W 51.8 N 406.9 W 8600,9 8445,8 436,5 S 87,00 W 48,4 N 456,3 W 1 8792 18,O0 1 8854 18,00 1 8973 18,00 1 9171 17,00 1 9337 17,50 8707,2 8552,1 471.0 N 90,00 W 47,5 N 8766.2 8611,1 489.7 N 90,00 W 47,5 N 8879,4 8724,3 525.7 N 89,00 W 47.8 N 9068.2 8913.1 584.7 S 79,00 W 42,6 N 9226,7 9071,7 633,4 S 64,00 W 27.0 N 1 9476 18.75 9358,8 9203.8 675.4 S 65,00 'Survey Codes: 1/SINGLE SHOT N/INTERPOLATED 8.4N 299,6 N 77.58 W 0.54 323,6 N 79.15 W 0,00 370,1 N 81,39 W 0,27 410 2 N 82 74 W 0 20 458,8 N 83,95 W 0,21 491.3 W . 493.6 N 84.46 W 0.51 510,5 W 512,7 N 84,69 W 0,00 547.3 W 549,4 N 85.01 W 0,08 606.5 W 608,0 N 85.98 W 0,72 653.0 W 653,6 N 87.63 W 0,87 692 1 W 692 1 N 89 30 W 0 90 · . · - SCU 24-5 MRS INCLN DEPTH ANGLE 9649 9765 10035 10149 10317 21.50 21,00 21,50 21,00 22,50 10143,3 Page 3 10/22/90 RECORD OF SURVEY (Calculated from a tie-in station at 476 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 9521,3 9366,2 733,2 $ 63.00 W 17,7 E 745.5 W 745.8 9629,4 9474,3 773,6 S 61.00 W 37,4 S 782,7 W 783,6 S 87,26 W 0.48 9881 0 9725 9 868 0 S 65 O0 W 81 8 S 869 8 W 873 7 '~ · ' · ~' ' ' ' 9987 3 9832,2 908 3 8 65 00 W 99 3 S 907 3 W 912 7 S 83 75 W 0 44 · . . · 9988,2 968,8 S 64.00 W 126.1 $ 963.5 W 971.7 S 82.54 W 0.90 1 10420 1 10620 1 10684 I 10996 23.00 10238.3 10083.2 23.25 10422.2 10267.1 25.00 10480.6, 10325.5 25,00 10763.4 10608.3 'Survey Codes: 1/SINGLE SHOT 1007,2 8 62.00 W 1082,7 S 62,00 W 1107,9 S 63,00 W 1236.3 8 67.00 W 144.2 S 999.0 181,1S 1068,3 193,1 S 1091.5 248.8 S 1211.0 1009.3 S 81.79 W 0.57 1083,5 S 80.38 W 0.12 1108.5 $ 79,97 W 2,75 1236.3 S 78.39 W 0.23 0 GREAT LAND DIRECTIONAL DRILLING, INC · lO/22/9o Client .... : ARCO ALASKA, INC. Field ..... : SWANSON RIVER UNIT Well ...... : SCU 24-5 Section at: S, 75.40,W Engineer... - Computation...: RADIUS OF CURVATURE Survey Date...: 10/22/90 RKB Elevation.: 164.00 ft Reference ..... : Magnetic Dcln.: 25.00 E STATION IDENTIFICATION SIDETRACK KOP/TURN 1.40 DE~ TO RI~l:l'r/ DRO~ 1.00/100 RECORD OF SURVEY (Calculated from a tie-in station at 7048 MD) MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES DL DEPTH ANGLE BKB SUB.- SEA DI ~TNCE BEARING FROM-WE~.L-HEAD / 100 7048 10.00 7036.4 6872.4 -25.8 S 74.00 W 143.5 N 10.7 W <TIE END 0F TURN 7148 9.00 7135.0 6971.0 -9.3 S 75.40 W 139.1N 26.6 W 1.00 7248 8.00 7233.9 7069.9 5.5 S 75.40 W 135.4 N 40.9 W 1.00 7348 7.00 7333.1 7169.1 18.5 S 75.40 W 132.1N 53.6 W 1.00 7448 6.00 7432.4 7268.4 29.8 S 75.40 W 129.3 N 64.5 W 1.00 END OF DROP TARGET TD 7548 5.00 7532.0 7368.0 39.4 $ 75.40 W 126.9 N 7600 4.48 7583.8 7419.8 43.7 S 75.40 W 125.8 N 10580 4.48 10554.7 10390.7 276.5 S 75.40 W 67.1 N 10831 4.48 10804.9 10640.9 296.1 S 75.40 W 62.2 N 73.8 W 1.00 77.9 W 1.00 303.2 W 0.00 322.2 W 0.00' (SCU245ST) O C Z C FROM:GREAT LAND DIREC ~AL TO:KRU?CI/NU DRILLING S:53PM P. 09 PLAN VIEW ARCO ALASKA, INC. SOU 24-5 CLOSURE ..... : 328 ft. N 79.07 DECL~'NATION.: 25.00 E SCALE ' ! inch- 200 feet DRANN '10/2~./90 7OO 60O 5OO 4O0 30O ~00 ~00 tO0 3OO 4O0 5OO 600 7OO tO00 900 BO0 700 600 BO0 400 300 EO0 '100 0 tO0 ~:-. WEST: EAST -> FROM:GREAT LAND DIRECTIONAL TO:KRU/CI×NU DRILLING - OCT 22, 1998 5:54PM P.08 and Directional Dp/ll/n~. Inc. 65O t95o 2800 VERTICAL SECTION VIEW ARCO ALASKA, INC. Section at: S 75,40 W 'TVD Scale.: t inch - 1300 feet Dep Scale.: ! inch - ~300 feet Drawn .....: tO/82/gO Al KB ST KOP/TURN/DROP END OF TURN END OF DROP TARGET F) TO HO TVD SECTN IN~LN 0 0 0 0,00 7048 7036 -2~ iO,O0 7i4e 7i3§ -9 9,00 7600 7584 44 4.48 10560 ~0555 278 4.48 i063! t0605 296 4.48 3900 455O T §~ V D 6500 7150 7900 84~0 9tOO g7§o tO400 ttTO0 650 65O i300 im~O =*6O0 3~50 39O0 Sect[on Departure 4~0 §~00 5850 6500 CKEC~ LEST FOE NE~ ~ P_=R/~_T$ IT~---~ APPROVE DAT=, (2 u=ru 8) (9 uhru i3) (10 and i3). (14 :hru 22) (5) BoP=- (2.3 uk_--~ 28) (29 =b.z-u 31) rev: 01/30/89 6.0IL · Company YES I. Is :he per=it fee auuached .,. ..... .................................. ". 2. Is well to' be located i= a defimed pool ............................. 3. Is we!! located proper ~isuamce from property line .................. 4. Is we!! located proper distance from other wells ........ ~ ........... 5. Is sufficient undedica:ed acreage available in :his pool ............ 6. Is well :o be deviated and is wellbore plat included ................ 7. Is operator the o~ty affected parry. ......... i ....................... 8. Cam permi: be approved before fifteeu-day wait ...................... NO L:'MARr,.S 9. Does operator have a bond in force .................................. ~ 10. is a conserve=ion order needed ...................................... ~ 1!. Is adz~.:istrative approval needed ................................... '"' 12.' is :he lease nmber appropriate ..................................... T 13. Does the we!! have a n~i~que marne a~d n=mber ......................... 14. IS a6nductor strimg provided ........................................ 15. Will surface casing protect all zones reasonably e.xp. ectad to serve as a~ u~derground source of drinking water ..................... 16. Is enough cement used to circula=a on conductor and su~ace ......... 17. W~i!! cemen: tie in surface and intermediate or production strings ... 18. Wi/.l cement cover ~ known productive horizons ..................... ~ 19. Will all casimg give adequate safety in collause, temsion amd burs=.. 20. Is this well =o be kicked off from a~ e-~_sti:g we!lbore ............. 21. Is old wellbore abandommen: procedure included on 10-403 ............ ~ 22. is adequa=e wellbore separation proposed ..................... ' ...... ~ 23. Ts a d~ver=er system ret=ired. ....................................... ~ 24. Is :he dri!limg fluid program schematic and lis: of equipment adequate ,,~,~,,' 25. Are necessary d.iagrmm_~ and descriptions of ~i.e.i"~-~ BOP=. at=ached. ~ 26. Does BOP=_ have s~ufficie:t pressure rati=g -Tes: :o ~'OOo psig .. ~ 27. Does :he choke manJ. fold comply w/API R~-$3 (May 84) .................. ~ 28. Is :he presence of ]i25 gas probable ............................. ;... ,, ~ 29. Are data presented om potential overpressure zones? ................. 30. Are seismic analysis ~ata presented om shallow gas zones .............. 31. If am offshore lot., are ~rvey resets of seabed conditions prese.:uad 32. Additio:~l req~.iremen:ts .................................... iNITLAL { GE0- { UNIT i ON/OFF POOL CLASS STATUS AREA NO. S~OP, E , , , , , ~ , Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. -.. · .. PROdRAM:' LISCAN REVISION: 5.2 PART NUMBER: W5790-MICRO Start of execution: Fri 1 FEB 91 3:45p **** REEL HEADER **** LIS 91/ 2/ 1 AWS 01 **** TAPE HEADER **** LIS 91/ 2/ 1 01 FILE # 1 LIS . OO1 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 24A-5 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * API NO. 50-133-20256-01. LOG DATE 01-09-91 FILE 1 : INTERVAL 7956 - 5450 FT. ' FILE 2 : INTERVAL 10660 - 9500 FT. FILE 3 : REPEAT 10660 - 10300 FT, * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME 1 BKL 2 BKS 3 CCL 4 CSS 5 G1 6 G2 7 GElS 8 GR 9 ISS 10 LS 11 MON 12 MSD 13 RATO 14 RBOR 15 RICS 16 RIN 17 SGMA 18 SPD 19 SS CODE SAMPLE# UNIT BYTES 68 1 CPS 4 68 1 CPS 4 68 1 DIM 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 SU 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 SU 4 68 1 F/MN 4 68 1 CPS 4 * DATA RECORD DEPTH G1 LS RICS (TYPE# O) BKL G2 MON RIN 966 BYTES * BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 7956.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7906.000 10924.16 1785.228 13.33274 55.12601 3321.920 2001.027 13.00707 241.8460 104620.9 0.3102068 17.95663 0.0000000E+00 17.81192 18.91754 25.55550 21929.79 290872.2 1.518798 33723.14 7856.000 10616.59 1624.075 13.85794 62.20801 3249.942 2003.106 13.41159 222.6370 101816.0 0.3143209 17.96068 0.0000000E+00 23.33539 20.15866 25.40370 21134.02 286168.1 1.539742 32764.55 7806.000 8234.441 1259.463 14.35513 74.90802 2000.360 2001.346 13.63061' 212.9120 99450.81 0.7626948 22.27533 0.0000000E+00 25.71552 23.70451 25.40370 19154.08 278068.1 1.509873 29863.53 7756.000 10774.13 62.20999 3210.306 217.3290 106372.2 0.0000000E+00 17.02803 21885.17 292569.5 1815.735 13.26426 7706.000 7147.164 1177..154 15.07234 7656.000 7067.562 1168.913 15.45553 7606.000 9372.562 1434.488 13.89685 7556.000 10860.05 1709.853 13.79108 7506.000 8996.21i 1436.270 14.54972 7456.000 7853.402 1303.441 14.22063 7406.000 7827.715 1249.805 14.48671 7356.000 12607.15 2000.199 13.12125 7306.000 10755.04 1682.041 13.37855 7256.000 8667.648 2002.218 12.76913 72.47400 1654.319 2002.981- 13.48221 92.50700 1497.011 2003°757 14.05275 56.70200 2670.246 2002°787 13.12140 63.47801 3372°824 2151.708 13.51504 87.86401 2089.134 2151.599 13.39025 53.46800 1879.539 2149.015 12.02268 70.70801 1803o372 2149.808 14.28760 50.19601 4198.496 2153.817 13.34808 59.07001 3251o248 2153. 011 13.22552 93.53000 1955.657 0.4799533 18.34996 199.1780 91200.19 0.3705257 22.79100 253.0250 99794.50 0.4980738 23.92155 203.6240 103826.6 0.2465109 19.54218 217.4840 105666.7 0.1552225 17.97183 275.9321 109608.2 0.2327781 22.18597 177.2160 91639.75 0.4732321 21.85468 227.5210 98480.94 0.2693917 22.35924 258.2000 102597.4 0.2580560 16o42717 200.8330 104208.2 0.2758952 18.52707 233.8940 104394.4 18.49725 25.43350 0.0000000E+00 21.58202 23.03261 25.99150 0.0000000E+00 36.82860 24.65121 25.96170 0.0000000E+00 23.13663 21.51743 25.99741 0.0000000E+00 22.98647 19.32399 25.99741 0.0000000E+00 26.08633 22.54590 25.99741 0.0000000E+00 15.19444 21.72491 25.99741 0.0000000E+00 30.91957 23.49146 25.99741 0.0000000E+00 18.77689 17.42661 25.99741 0.0000000E+00 20.82532 19.46062 25.99741 0.0000000E+00 28.33621 1.517959 33584.56 17305.05 257811.9 1.522125 27128.53 18358.93 276774.0 1.575566 28857.85 20225.20 287217.2 1.618202 30770.89 21684.62 297182.2 1.584869 32990.12 20842.85 296378.6 1.595144 32338.12 17924.00 257088.6 1.530106 28322.09 18679.70 286577.1 1.588048 29291.55 22730.49 296739.1 1.539724 34769.61 21475.38 287459.4 1.529569 32702.00 20033.00 294896.1 1358.307 15. 12544 7206.000 9035.828 1338.322 14.12477 7156.000 8425.266 1228.517 14.83955 7106.000 7368.309 1196.516 14.25513 7056.000 10360.72 1590.251 13.11273 7006.000 5644.645 818.0920 17.27071 6956.000 6506.887 964.8291 17.29552 6906.000 6461.652 1054.297 18.27127 6856.000 8417.289 1352.889 16.75035 6806.000 4359.949 667.3389 19.36986 6756.000 5436.129 2151.850 14.52865 98.48502 2194.870 2153.596 14.35558 70.20801 1931.361 2151.424 13.83860 79.26900 1572.985 2152.044 14.00711 48.06001 2840.567 2150.204 13.96534 40.67401 1449.531 2152.449 16.31966 38.74001 1773.617 2151.667 16.57242 21.80101 1892.424 2152.019 16.55775 39.96600 3061.000 2154.070 15.79427 55.08900 928.9651 2151.707 17.12535 49.79100 1298.602 0.4774993 22.50748 249.5190 105026.1 0.5098433 21.87465 244.6830 96215.12 0.4327589 21.96689 252.4540 100947.9 0.7326654 24.09500 211.2510 104130.5 0.2339048 19.65727 152.6460 90311.81 0.8237795 21.22931 191.8070 95223.69 0.4068301 20.04631 189.9330 102357.5 0.8022473 18.97322 200.8340 104089.5 0.3485312 15.50256 183.2220 89136.06 015996557 24.30742 167.4990 94683.37 23.20490 25.99741 0.0000000E+00 29.04182 24.09996 25.99741 0.0000000E+00 30.36763 24.77716 25.99741 0.0000000E+00 29.60909 25.06955 26.95570 0.0000000E+00 18.64948 20.39865 26.99141 0.0000000E+00 18.32202 26.63382 26.39771 0.0000000E+00 13.16459 24.69325 26.99730 0.0000000E+00 14.05349 21.73041 26.99730 0.0000000E+00 14.92154 18.82678 26.03900 0.0000000E+00 16.37749 29.35880 26.99730 0.0000000E+00 13.76484 1.539961 31417.48 20530.29 291981.0 1.514175 32223.80 19054.40 277176.9 1.522521 30401.73 18907.83 278547.4 1.563904 29995.02 21202.25 289289.6 1.523217 32370.15 15131.02 280452.8 1.711282 21637.18 16470.36 281015.7 1.697651 23868.84 16651.44 296889.0 1.803080 22877.81 18576.98 308115.0 1.739610 25421.38 13894.20 273040.7 1.787454 19643.15 15430.70 280779.9 850.3660 18.65614 6706.000 7246.254 1288.872 13.85500 6656.000 7359.227 1220.099 13.96949 6606.000 6992.805 1260.904 14.43744 6556.000 7622.812 1365._695 14.60968 6506.000 8953.242 1498.897 12.86481 6456.000 10037.11 1679.444 12.96278 6406.000 7080.730 1209.593 14.25080 6356.000 10187.34 1835.181 13.54439 6306.000 9894.332 1741.130 13.50769 6256.000 8211.293 2152.373 15.95126 32.07800 1556.460 2152.679 12.76939 27.80901 1599.987 2153.252 12.58416 52.58701 1289.757 2153.007 12.61304 101.4270 1508.824 2150.690 12.73436 63.12201 2192.461 2154.957 12.43353 50.40401 3000.632 2149.337 12.03180 45.63501 1349.716 2148.311 12.01116 58.33900 3220.464 2150.988 13.18205 55.77501 2920.265 2146.588 12.65211 27.63399 2249.485 0.3327402 21.97873 166.1170 112613.5 0.4987862 24.38184 210.5120 96891.62 0.3258024 24.14482 210.1100 109450.8 0.5302821 26.68158 209.9710 108671.3 0.4072289 25.49817 236.0700 108820.9 0.3885493 21.81267 244.4330 106979.6 0.2405385 18.80115 202.6770 95191.94 0.2109185 25.19550 293.5120 124794.2 0.1971548 17.78760 246.9360 122781.2 0.4612886 18.96852 226.6150 115025.2 25.42386 27.54941 0.0000000E+00 21.53055 24.63083 26.00330 0.0000000E+00 13.16386 24.69807 27.55530 0.0000000E+00 24.11235 25.15108 27.03300 0.0000000E+00 27.05492 23.55777 26.96161 0.0000000E+O0 18.01500 22.97398 26.99730 0.0000000E+00 15.10209 20.40312 26.99730 0.0000000E+00 8.876009 24.02563 26.99730 0.0000000E+00 20.38399 19.40219 22.59151 0.0000000E+00 14.64008 19.96786 21.99780 0.0000000E+00 16.48407 1.719921 21737.90 20242.82 297177.7 1.546622 31587.27 18700.70 263267.4 1.496433 30185.59 19819.44 282918.7 1.523561 31648.54 20210.71 285154.9 1.500400 32290.60 21437.46 287296.6 1.497414 34442.46 21961.33 288665.6 1.513892 34154.20 18049.48 257278.1 1.504062 29025.14 23757.41 320951.4 1.525806 35488.87 23209.89 316352.0 1.542297 34740.96 20736.57 309168.7 1432.589 14. 13707 2149.324 13. 10544 0.5525253 21.57722 21.97713 22.99181 1.587984 31199.68 6206.000 6481.984 1086.248 15.10402 86.33501 1172.824 2148.169 12.54506 193.3780 104506.1 0.3961661 26.68585 0.0000000E+00 22.39235 27.18890 22.59740 18649.03 281800.4 1.530243 29595.78 6156.000 9378.437 1621.648 13.90572 44.89600 2416.665 2148.727 12.61540 242.3860 112954.4 0.9998757E-01 20.96361 0.0000000E+00 17.30975 21.16196 21.99780 21955.59 303180.6 1.532364 34263.89 6106.000 9515.656 1677.279 13.51416 44.02000 2657.334 2147.918 13.10882 219.4750 109582.0 0.4261605 19.51782 852.5999 16.68457 19.70078 22.99770 21470.21 296459.7 1.532771 33016.60 6056.000 10179.71 1678.044 13.62220 71.77301 3323.460 2149.547 12.72820 258.6931 111252.7 0.3567401 17.49509 0.0000000E+00 17.70981 20.31195 22.39810 22287.75 304520.7 1.564072 34088.63 6006.000 7729.316 1300.218 14.79823 80.10800 1516.801 2147.537 13.30061 265.2390 112298.4 0.5505297 24.73567 0.0000000E+00 24.30486 24.55992 22.03940 20407.19 300431.9 1.594176 32013.60 5956.000 7313.437 1315.671 14.69699 61.18301 1410.052 2147.637 12.87319 201.5870 112409.4 0.4428181 25.68752 0.0000000E+O0 21.99442 24.24582 22.99770 20266.45 297541.2 1.549263 31952.74 5906.000 8906.590 1546.067 13.90311 42.82901 2378.133 2147.424 12.60647 237.6050 108328.8 0.6047848 20.22980 0.0000000E+00 16.47530 21.35229 22.99770 21082.04 294463.5 1.528191 33058.28 5856.000 7179.996 1291.402 14.44131 85.21901 1310.890 2149.695 12.50807 237.3370 112672.4 0.5512780 26.69751 0.0000000E+00 22.70097 24.94194 22.59740 20339.40 292709.3 1.518273 32183.07 5806.000 7793.199 1446.122 13.80325 51.87900 1617.019 2148.024 12.27995 264.0261 111209.2 0.4973186 24.36508 0.0000000E+00 19.55695 22.66043 23.59731 20624.44 291711.6 1.523982 32732.85 5756.000 6972.375 57.33501 1377.452 237.6910 111747.6 0.0000000E+00 19.71892 19993.48 292856.3 12~8.266 14. 37572 2147.385 12.46564 0.3855029 25.93591 24.08002 23.40390 1.545717 31213.91 5706.000 7261.117 1223.792 14.26713 94.10400 1397.032 2149.353 12.24292 231.6210 103099.4 0.3853553 25.58437 0.0000000E+00 22.30574 25.75880 23.52000 19430.62 274496.8 1.531941 31528.03 5656.000 7291.875 1338.800 14.21785 62.86501 1347.349 2148.125 12.55179 325.6960 110830.6 0.9040256 26.10762 0.0000000E+00 25.42067 24.38025 23.03340 20307.10 290105.8 1.528589 32690.56 5606.000 8198.277 1345.212 13.93026 51.60701 1842.194 2147.577 12.57002 272.8311 108340.7 0.3494141 23.32787 0.0000000E+00 21.35951 24.98639 22.99770 20790.42 292686.9 1.520716 33656.42 5556.000 8010.480 1357.421 14.18505 58.40800 1691.730 2147.868 12.59095 211.7340 108543.9 0.3856342 23.91711 0.0000000E+00 20.68105 24.13202 24.36220 20513.36 291290.4 1.510357 32735.77 5506.000 0.0000000E+00 950.0000 -7.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.OOO0OO 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.0000000E+00 5456.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 418 7956.00 ENDING TAPE DEPTH = 5450.00 **** REEL HEADER **** LIS 91/ 2/ i AWS 01 **** TAPE HEADER **** LIS 91/ 2/ 1 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 24A-5 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 20 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 BKL 68 1 CPS 4 2 BKS 68 1 CPS 4 3 CCL 68 1 DIM 4 4 CSS 68 1 API 4 5 G1 68 1 CPS 4 6 G2 68 1 CPS 4 7 GElS 68 1 CPS 4 8 GR 68 1 API 4 9 GRAC 68 1 4 10 ISS 68 1 CPS 4 11 LS 68 1 CPS 4 12 MON 68 1 CPS 4 13 MSD 68 1 SU 4 14 RATO 68 1 DIM 4 15 RBOR 68 1 DIM 4 16 RICS 68 1 DIM 4 17 RIN 68 1 DIM 4 18 SGMA 68 1 SU 4 · 19 SPD 68 1 F/MN 4 20 SS 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH G1 ISS RBOR SS 10676.000 -999.2500 -999.2500 -999.2500 -999.2500 10626.000 21423.15 303190.0 1.350631 48887.61 10576.000 17317.48 303549.1 1.362911 45991.78 10526.000 20975.64 297448.3 1.372860 48794.73 10476.000 15407.32 303214.6 1.418238 44217.94 10426.000 21453.73 303789.7 1.358152 48619.33 10376.000 13229.08 299897.7 1.402962 42724.77 10326.000 7657.879 287956.4 1.498302 33285.62 10276.000 12011.28 281126.7 1.399724 40535.67 BKL G2 LS RICS -999.2500 -999.2500 -999.2500 -999.2500 195.7810 8168.957 3095.571 9.814882 177.0800 5384.793 2543.770 10.39921 216.5780 7892.980 2860.712 10.16327 210.4450 4587.328 2345.892 12.23160 84.39301 8148.441 3194.179 9.856613 159.5740 3097.374 1919.232 11.90497 221.0400 1231.853 1206.534 13.76942 127.9870 2905.665 1753.373 11.85129 BKS GElS MON RIN -999.2500 -999.2500 -999.2500 -999.2500 418.4089 105719.6 2000.433 11.68402 327.2100 108098.6 2000.677 12.38766 337.0830 105244.6 2004.284 12.18129 361.8140 108396.9 2003.032 12.95865 287.3350 106895.1 2000.609 11.77439 371.4880 112408.4 1999.521 12.67967 358.2051 106336.1 2000.906 13.80428 274.5430 106783.7 2000.778 13o09477 CCL GR MSD SGMA -999.2500 -999.2500 -999.2500 -999.2500 556.5000 83.71037 0.2010849 14.64656 0.0000000E+00 81.24287 0.3157057 17.67152 0.0000000E+00 66.00854 0.1945708 14.93678 384.0000 54.03014 0.3237432 18.63074 0.0000000E+00 36.54445 0.2040328 14.69052 0.0000000E+00 59.07610 0.3792456 21.75293 0.0000000E+00 83.55081 0.7431277 27.15691 0.0000000E+00 40.32021 0.3893385 21.52116 CSS GRAC RATO SPD -999.2500 75.60721 -999.2500-999.2500 30889.54 66.64403 15.81052 20.99791 28193.69 84.21748 18.07582 20.65291 30742.14 63.69841 17.03027 20.34300 26859.13 80.88957 18.75340 20.65291 30936.32 68.92355 15.16527 20.88870 25580.40 112.7508 22.26982 20.99791 20267.59 149.7004 27.57919 20.99791 24154.11 79.20944 23.05511 20.99791 10226.000 15391.72 307297.9 1.415778 45619.07 10176.000 9296.988 290857.6 1. 524019 33016.51 10126.000 8447.977 277074.2 1.535097 28999.49 10076.000 11025.63 284820.1 1.558774 31840.61 10026.000 7540.266 284661.7 1.563330 28989.76 9976.000 12311.61 296706.7 1.559710 33821.90 9926.000 8894.258 289195.9 1.527209 30584.55 9876.000 11230.33 283702°0 1.559904 33335.72 9826.000 6852.781 290556.4 1.583795 28067.80 9776.000 7383.852 282152.7 1.584976 28333.98 117.2720 4040.909 2276.444 11.89508 93.53601 1943.938 1389.792 14.45418 72.24200 2030.724 1232.945 14.57676 69.38701 3219.276 1512.458 13.73441 64.76001 1554.509 1160.432 15.16292 50.78601 4179.156 1899.946 13.32230 62.86699 2049.014 1323.535 14.75207 71.87401 3387.470 1691.113 13.43618 117.2740 1362.431 1081.684 15.49966 101.9840 1619.698 1101.175 15.41344 373.7871 115281.9 2001.047 13.50366 321.9221 103998.9 2002.102 15.25264 226.9750 95816.06 2002.502 15.52592 221.9180 97281.75 2002.338 14.67672 217.0360 100340.6 2001.236 15.62806 240.6470 105261.9 2001.229 14.33067 234.5770 101451.4 2000.475 15.89121 291.4351 101498.3 1998.571 14.21181 224.0270 102476.9 2001.316 15.59098 228.3700 98728.62 1999.094 16..15002 0.0000000E+00 36.85510 0.4841505 20.30714 49.64999 40.12962 0.3817517 23.63567 0.0000000E+00 28.29672 0.4725053 21.77057 0.0000000E+00 24.52563 0.3098345 18.84332 0.0000000E+00 34.63420 0.3658725 24.08023 385.8000 19.52675 0.3078429 16.54610 0.0000000E+00 31.32397 0.4944977 22.17801 0.0000000E+00 20.45052 0.2597264 18.16183 0.0000000E+00 41.98491 0.3029488 24.97794 0.0000000E+00 30.87950 0.4213833 23.41675 27650.61 65.85875 19.94133 20.99791 20694.96 65.16078 23.80939 21.65280 18690.32 49.98784 23.49734 21.99780 20683.99 47.58911 21.07469 20.99791 18602.96 62.71065 25.00943 20.99791 22598.87 35.30272 17.80232 21.88860 19752.40 -999.2500 23.14938 20.99791 21505.88 -999.2500 19.58080 20.99791 18201.61 -999.2500 25.91725 21.99780 18264.63 -999.2500 25.79706 21.99780 9726.000 11689.74 297840.6 1.536639 33388.83 9676.000 8188.121 297095.1 1.575199 30756.20 9626.000 6710.191 262703.9 1.627841 25242.35 9576.000 8534.945 291287.6 1.558667 29711°46 9526.000 14167.13 332367.0 1.596097 38657°50 9476.000 -999.2500 -999.2500 -999.2500 -999.2500 50.05101 3782°320 1783.306 13.17246 89.35400 1848.425 1263.429 14.99286 52.90900 1538o619 1029o250 15.21179 60.67902 1980.388 1286.057 15.20777 65.61801 4646.766 2498.824 12~.95183 -999.2500 -999.2500 -999.2500 -999.2500 267.2219 104471.8 1998.944 14.38237 207.8930 107814.4 2272.585 14.44980 217.3130 87355.75 1994.423 14.25622 208°4870 103420.9 2303.808 14.05808 252.4230 123974.0 1997.285 13.63679 -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 18.32637 0.1270425 17.06300 0.0000000E+00 29.17694 0.4093357 22.87100 0.0000000E+00 16.23444 0.3033285 22.48701 0.0000000E+00 28.79958 0.4940540 21.64357 0.0000000E+00 16.63564 0.2531524 16.89789 -999.2500 -999.2500 -999.2500 -999.2500 22055.14 -999.2500 18.72275 21.99780 19911.79 -999.2500 24.30980 21.99780 16298.61 -999.2500 24.43553 22.10699 19403.09 -999.2500 23.07758 21.99780 26057.89 -999.2500 15.39510 21.99780 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 207 10676.00 ENDING TAPE DEPTH = 9440.00 **** REEL HEADER **** LIS 91/ 2/ 1 AWS 01 LIS 91/ TAPE HEADER **** 2/ 1 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 24A-5 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME CODE SAMPLE# UNIT 1' BKL 68 1 CPS 2 BKS 68 1 CPS 3 CCL 68 1 DIM 4 CSS 68 1 API 5 G1 68 1 CPS 6 G2 68 1 CPS 7 GElS 68 1 CPS 8 GR 68 1 API 9 ISS 68 1 CPS 10 LS 68 1 CPS 11 MON 68 1 CPS 12 MSD 68 1 SU 13 RATO 68 1 DIM 14 RBOR 68 1 DIM 15 RICS 68 1 DIM 16 RIN 68 1 DIM 17 SGMA 68 1 SU 18 SPD 68 1 F/MN 19 SS 68 1 CPS BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# O) 966 BYTES * DEPTH BKL BKS CCL CSS G1 G2 GElS GR ISS LS MON MSD RATO RBOR RI~S RIN SGMA SPD SS 10676.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10626.000 21688.43 3089.511 9.692638 242.0410 8147.992 2168.012 11.39458 396.4231 105267.1 0.8565044E-01 14.71015 0.0000000E+00 83.26898 16.07817 25.99741 31192.50 302281.0 1.375501 49649.53 10576.000 17225.64 2467.625 10.25515 193.6610 5333.164 2069.141 12.06065 370.3940 107784.2 0.1790084 17.76292 0.0000000E+00 73.15279 18.66313 24.99750 28200.90 299935.1 1.370007 46121.68 10526.000 21075.54 3037.009 10.16045 102.1960 7911.992 2006.277 12.13647 265.6069 106741.5 0.1366272 14.86124 0.0000000E+00 37.20592 16.17363 24.99750 30978.91 297456.7 1.334885 49218.36 10476.00© 16619.00 2444.882 11.90166 146.0260 5226.281 2005.076 12.29605 342.7581 111999.6 0.3164413 17.68288 0.0000000E+00 45.18677 18.37579 24.99750 27933.46 308210.7 1.414292 45154.41 10426.000 21375.20 3184.014 9.832787 106.3700 8079.051 2006.160 11.57212 295.2971 106440.7 0.1502329 14.65750 0.0000000E+00 38.93329 15.37667 25.99741 31075.09 304963.9 1.318907 49180.05 10376.000 13349.45 1972.180 11.80004 131.9160 3109.089 2004.879 12.86345 314.8250 111744.0 0.5597814 21.96848 0.0000000E+00 58.46913 21.44678 25.95580 25474.34 298024.8 1.369039 42325.62 10326.000 0.0000000E+00 950.0000 -2.000000 0.O000000E+00 O.O000000E+00 O.O000000E+00 5.000000 0.0000000E+00 0.0000000E+00 Oo0000000E~O0 O.0000000E+00 0.0000000E+00 76.61362 O.O000000E+00 0.O000000E+00 O.O000000E+O0 O.O000000E+O0 -1.000000 O.O000000E+O0 10276.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : 70 .. STARTING TAPE DEPTH = 10676.00 ENDING TAPE DEPTH = 10260.00 **** FILE. TRAILER **** **** TAPE TRAILER **** LIS 91/ 2/ 1 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 716 **** REEL TRAILER **** LIS 91/ 2/ 1 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 717 TOTAL R~O~.DS IN THIS ~v~T~ ~ = .............. : 717 End of execution: Fri 1 FEB 91 3:46p Elapsed execution time = 51.03 seconds. SYSTEM RETURN CODE = 0 PROGRAM: LISCAN REVISION: 5.2 PART NUMBER: W5790-MICRO Start of execution: Mon 4 FEB 91 2:14p **** REEL HEADER **** LIS 91/ 2/ 4 AWS 01 **** TAPE HEADER **** LIS 91/ 2/ 4 01 FILE # LIS .001 1024 CN WN FN COUN STAT 1 **** FILE HEADER **** : ARCO ALASKA INC. : SCU 24A-5 : SOLDOTNA CREEK UNIT : KENAI : ALASKA R F C , _lV F... b I ~! ,.! Alaska Oil & Cas Corm, (;ornmissior~ Anchorage * COMMENT RECORD * API NO. 50-133-20256-01. LOG DATE : RUN 1 12021-90, RUN 2 01-07-91. FILE 1 : MAIN PASS RUN 1 10190 - 6920. FILE 2 : MAIN PASS RUN 2 10827 - 9940. FILE 3 : REPEAT SECTION RUN 1 10190 - 9940. FILE 4 : REPEAT SECTION RUN 2 10460 - 10130. NOTE : CURVE GRCN IN FILE 2 IS GAMMA RAY FROM DIFL - CN. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F CURVES : NAME CODE SAMPLE# UNIT 1 C13 68 1 IN 2 C24 68 1 IN 3 CAL 68 1 IN 4 CHT 68 1 LBF 5 GR 68 1 API 6 SPD 68 1 F/MN 7 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 * DATA RECORD DEPTH GR 10190.000 -999.2500 10140.000 48.45334 10090.000 65.38516 (TYPE# C13 SPD -999.2500 -999.2500 7.041311 64.55161 7.097743 59.58780 o) 998 BYTES * C24 TTEN -999.2500 -999.2500 6.843288 3700.824 6.824996 3608.106 CAL -999.2500 6.942300 6.961370 CHT -999.2500 1587.211 1588.757 10040.000 66.56462 7.229105 59.99400 6.902110 3610.317 7.065608 1586.590 9990.000 46.58879 7.726242 60.40021 7.125141 3606.335 7.425692 1590. 189 9940.000 59.99954 7.645608 60.99391 6.845052 3559.464 7.245330 1594.812 9890.000 63.72069 8.562128 61.95811 7.057291 3514.981 7.809711 1599.536 9840.000 74.87451 7.092543 61.99380 8.413256 3509.381 7.752899 1600.101 9790.000 66.93927 7.038574 61.99971 8.161303 3507.694 7.599939 1599.964 9740.000 51.43359 7.669217 61.84201 7.914523 3464.290 7.791870 1596.476 9690.000 71.80682 9.153755 62.99960 7.048615 3416.321 8.101189 1605.306 9640.000 68.15721 8.985432 85.02721 7.047956 3456.880 8.016693 1609.268 9590.000 52.98709 8.620089 84.99741 7.036592 3567.419 7.828341 1614.870 9540.000 63.29199 9490.000 30.33568 9440.000 43.66751 9390.000 46.79269 9340.000 69.13426 9290.000 55.50130 9240.000 37.76666 9190.000 69.43437 9140.000 74.60867 9090.000 81.71576 9040.000 68.26355 8990.000 73.86487 8940.000 79.27403 8890.000 66.03505 8840.000 62.06581 8790.000 44.22612 8740.000 54.88431 8690.000 58.46594 8640.000 77.45518 8590.000 52.07356 10.46834 85.99141 10.09217 88.14890 8.467028 88.59079 9.215698 87.99120 9.611967 88.99701 10.05494 88.02690 9.070843 87.39751 8.611380 88.94951 9.439325 88.54919 9.395462 88.54919 10.37477 88.96130 10.12136 89.99100 10.59946 89.95531 12.09444 89.99100 12.69933 90.95520 12.22603 90.98500 12.60526 91.59050 11.90772 91.55479 7.415675 90.99089 9.845800 93.43262 7.286080 3424.667 7.211381 3430.235 7.261450 3385.162 7.291216 3402.919 7.120790 3392.571 6.838167 3364.998 7.248130 3425.662 7.730548 3370.377 6.892007 3358.296 6.454155 3366.850 6.690056 3432.959 7.095235 3265.967 6.899534 3317.877 7.266174 3258.335 6.982780 3212.292 7.085605 3180.548 7.701010 3163.588 8.295366 3191.323 12.04269 3194.779 9.432751 3129.688 8.877205 8.651772 7.864239 8.253456 8.366379 8.446556 8.159485 8.170967 8.165665 7.924809 8.532410 8.608299 8.749496 9.680305 9.841057 9.655823 10.15314 10.10155 9.729187 9.639275 1608.430 1611.712 1614.425 1618.053 1607.143 1610.397 1626.024 1617.060 1625.548 1625.480 1613.861 1630.685 1623.374 1631.997 1623.519 1632.445 1635.409 1634.183 1643.649 1651.095 8540.000 67.74879 8490.000 59.92178 8440.000 70.26930 8390.000 61.22490 8340.000 37°94746 8290.000 60.35338 8240.000 70.18127 8190.000 70.60539 8140. 000 62. 30617 8090.000 74.88252 8040. 000 69.75563 7990.000 71.97830 7940.000 45.47237 7890.000 68.66055 7840.000 41.39322 7790.000 63.84120 7740.000 58.34604 7690.000 59.88704 7640.000 65.17621 7590.000 68.55214 17.02068 93.58441 11.92990 93.95491 12.05314 93.95491 12.92307 93.99651 12.31970 94.99051 12.83004 94.39679 13.76466 95.02620 12.90607 95.39081 13.59118 96.95461 13.04123 96.99031 12.62409 97.58401 12.91750 97.39651 11.05036 97.95450 12.54966 97.43222 9.639347 98.58389 11.09863 97.99611 12.67949 97.99611 15.83576 100.0257 14.05960 101.0138 9.119947 100.9840 6.446095 3133.517 6.950768 3064.252 9.471888 3121.179 7.941875 3063.230 8.126318 3023.095 8.380445 3052.339 8.594435 2964.208 9.072224 3019.337 8.111073 2995.796 8.471884 2942.046 7.860842 2907.455 7.886916 2929.056 8.814329 2919.444 9°589880 2873.125 9.915083 2825.964 10.94868 2840.754 7.844231 2824.871 6.988086 2746.379 7.086277 2736.972 9.518358 2781.429 11.73338 9.440338 10.76251 10.43247 10.22301 10.60524 11.17955 10.98915 10.85113 10.75656 10.24246 10.40221 9.932343 11.06977 9.777214 11.02366 10.26186 11.41193 10.57294 9.319153 1644.672 1655.211 1641.892 1640.749 1655.658 1653.132 1647.605 1643.877 1664.627 1658.453 1652.865 1661.609 1659.897 1664.294 1665.107 1657.018 1669.766 1669.125 1679.005 1648.519 7540.000 8.446299 16.01422 12.23026 82.95947 101.5479 2743.693 7490.000 6.756602 12.01216 9.384384 62.83229 101.5895 2678.843 7440.000 7.863355 15.70384 11.78360 48.57988 101.5895 2660.609 7390.000 8.884706 11.68724 10.28597 59.88924 101o9898 2665.314 7340.000 9.902967 11.26189 10.58243 58.14905 102.3842 2647.190 7290.000 13.51841 7.770905 10.64466 70.30273 102o9540 2621.981 7240.000 12.03092 7.020131 9.525528 47.25725 102.9897 2598.059 7190.000 14.62225 7.657856 11.14005 33.17967 103o3526 2570.607 7140.000 19.05756 6.826125 12.94184 74.81277 104.9836 2570.691 7090.000 17.78773 6.887378 12.33755 51.16557 104.0312 2562.261 7040.000 16.58603 7.026395 11.80621 51.81462 93.99062 2519.931 6990.000 7.088476 6.846167 6.967321 30.02153 94.39679 2487.976 6940.000 -999.2500 4.000000 4.000000 4.000000 0.0000000E+00 2000.000 1670.010 1685.498 1696.898 1679.200 1687.816 1686.519 1673.325 1671.780 1685.219 1684.250 1664.804 0.0000000E+00 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 211 10190.00 ENDING TAPE DEPTH = 6920.00 **** REEL HEADER **** LIS 91/ 2/ 4 AWS 01 **** TAPE HEADER **** LIS 91/ 2/ 4 01 FILE ~ 2 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 24A-5 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 18 CURVES : NAME CODE SAMPLE# UNIT 1 AC 68 1 US/F 2 C13 68 1 IN 3- C24 68 1 IN 4 CAL 68 1 IN 5 CN 68 1 % 6 CNC 68 1 % 7 CNRA 68 1 DIM 8 COND 68 1 MMHO 9 GR 68 1 API 10 GRCN 68 1 11 LSN 68 1 CPS 12 RT 68 1 OHMM 13 SN 68 1 OHMM 14 SP 68 1 MV 15 SPD 68 1 F/MN 16 SSN 68 1 CPS 17 TEN 68 1 LBF 18 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD DEPTH CN (TYPE# 0 ) AC CNC 994 BYTES * C13 CNRA C24 COND CAL GR GRCN SPD 10870.000 -999.2500 -999.2500 -999.2500 10820.000 15.36632 166.0131 36.55441 10770.000 18.49379 96.56178 36.99040 10720.000 23.13023 147.1625 36.99631 10670.000 20.17633 83.21872 37.00221 10620.000 14.84338 55.30455 36.99631 10570.000 19.47691 84.14139 37.59590 10520.000 9.884478 70.95432 37.40250 10470.000 21.11954 126.1740 37.03200 10420.000 16.42369 68.81670 37.43820 10370.000 21.61938 101.8639 37.56020 10320.000 24.27710 LSN SSN -999.2500 -999.~2500 -999.2500 -999.2500 72.46637 24.95889 203.7302 449.1794 84.16096 28.70677 171.8619 422.7551 78.19400 34.14616 130.1683 369.0610 84.25764 30.69682 139.6494 362.6135 90.29555 24°32602 212.0120 458.3721 82.78236 29.87180 152.1784 386.5034 67.86172 18.23648 347.8987 609.8604 81.81812 31.80438 123.4962 330.1113 97.34518 26.23312 169.5374 388.4336 81.64169 32.38898 114.6409 311.0759 81.24533 35.47012 RT TEN -999.2500 -999.2500 -999.2500 -999.2500 4.587192 1.000000 7.501567 973.8218 4.452572 1.000000 3.609593 370.6792 4.553726 1.000000 6.329750 128.0387 4.916813 1.000000 5.882941 27.01538 4.663472 1.000000 14.53509 -12.46504 4.887252 1.000000 9.482864 -28.39610 4.677458 1.000000 12.49757 -40.43323 5.770236 1.000000 6.430907 -47.14751 4.795550 1.000000 19.74176 -49.94038 5.118484 1.000000 8.509922 -45.78934 5.044580 1.000000 SN TTEN -999.2500 -999.2500 -999.2500 -999.2500 4.560576 133.3055 12.83091 3930.523 4.507029 277.0396 7.609071 3907.828 4.751980 157.9841 9.801128 3886.774 4.812206 169.9830 10.46415 3867.577 4.804375 68.79903 22.24742 3833.824 4.796218 105.4534 17.52812 3820.544 4.776830 80.01556 19.33766 3803.922 4.869016 155.4991 10.44082 3784.104 4.733816 50.65405 28.91843 3753.322 5.127294 117.5099 12.50017 3738.209 5.320069 152.0018 SP -999.2500 -999.2500 -999.2500 4.573884 0.0000000E+00 77.94791 4.479801 67.88910 42.63383 4.652853 140.1805 84.33458 4.864510 80.52625 59.60011 4.733924 55.86040 42.37886 4.841735 78.07593 52.63734 4.727144 66.49635 61.50394 5.319626 125.5935 82.86829 4.764684 64.11440 57.38181 5.122890 105.6740 72.57440 5.182325 118.2680 116.6615 37.99622 10270.000 65.08080 55.57327 38.55420 10220.000 27.88828 70.91548 37.99622 10170.000 36.41072 50.37691 37.99622 10120.000 26.98550 37.55284 37.99622 10070.000 34.98506 42.44279 37.99622 10020.000 48.26854 62.78764 37.99622 109.3691 320.1377 116.7805 77.02083 29°89410 154.6943 110.3598 39.58319 96.39922 309.5764 127.5014 48°95457 53.10251 203.2621 -999.2500 38.56288 69°45010 218.1579 -999.2500 47.41971 63.39320 236.5587 -999.2500 61.20947 38.30531 172.5930 6.578869 -41.48151 5.073377 1.000000 4.130822 -45.59535 5.572061 1.000000 4.512602 -46.65675 4.678483 1.000000 11.55657 -44.67731 -999.2500 1.000000 41.73427 -47.00476 -999.2500 1.000000 27.72432 -46.13307 -999.2500 1.000000 33.29608 -45.30501 11.94634 3716.895 6.581903 242.0826 7.485508 3693.402 5.812149 221.6017' 6.386069 3674.401 4.807821 86.53085 0.9092599E-01 3655.021 -999.2500 23.96112 0.8095115E-01 3619.977 -999.2500 36.06941 0.8894861E-01 3607.888 -999.2500 30.03357 0.8756429E-01 3593.288 9970.000 -999.2500 -999.2500 -999.2500 27.27998 38.89627 1.000000 18.20006 38.70114 68.59830 54.94489 0.7476968E-01 37.99622 217.0577 -48.81006 3581.259 81.57016 5.827640 56.22191 83.68076 5.692105 80.83282 86.50311 4.743153 51.04094 7.369836 -999.2500 -999.2500 -3.598048 -999.2500 -999.2500 -12.02860 -999.2500 -999.2500 -25.38200 -999.2500 -999.2500 7.090151 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 145 10870.00 ENDING TAPE DEPTH = 9930.00 **** REEL HEADER **** LIS 91/ 2/ 4 AWS 01 **** TAPE HEADER **** LIS 91/ 2/ 4 01 FILE # 3 LIS .001 FILE HEADER **** 1024 CN : WN : FN : COUN : STAT : ARCO ALASKA INC. SCU 24A-5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F CURVES : NAME CODE SAMPLE# UNIT 1 C13 68 1 IN 2 C24 68 1 IN 3 CAL 68 1 IN 4 CHT 68 1 LBF 5 GR 68 1 API 6 SPD 68 1 F/MN 7 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 * DATA RECORD DEPTH GR 10190.000 -999.2500 10140.000 47.63989 10090.000 67.39085 10040.000 65.40289 (TYPE# 0) C13 SPD -999.2500 -999.2500 7.028540 57.95851 7.226143 58.98820 7.063730 58.55811 998 BYTES * C24 TTEN -999.2500 -999.2500 6.704273 3635.616 7.031770 3555.828 6.862414 3586.764 CAL -999.2500 6.866406 7.128957 6. 963073 CHT -999.2500 1551.100 1558.004 1568.676 9990.000 7.679010 7.137914 7.408463 0.9999999E-04 58.59380 3561.687 9940.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.9999999E-04 -999.2500 TOTAL DATA RECORDS : 17 STARTING TAPE DEPTH = 10190.00 ENDING TAPE DEPTH = **** FILE TRAILER **** **** REEL HEADER **** LIS 91/ 2/ 4 AWS 01 9940.00 **** TAPE HEADER **** LIS 91/ 2/ 4 01 FILE # 4 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INCo WN : SCU 24A-5 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 15 CURVES : NAME 1 AC 2 CN 3 CNC 4 CNRA 5 COND 6 GR 7 GRCN 8 LSN 9 RT 10 SN 11 SP 12 SPD 13 SSN 14 TEN 15 TTEN CODE SAMPLE# UNIT BYTES 68 1 US/F 4 68 1 % 4 68 1 % 4 68 1 DIM 4 68 1 MMHO 4 68 1 API 4 68 1 4 68 1 CPS 4 68 1 OHMM 4 68 1 OHMM 4 68 1 MV 4 68 1 F/MN 4 68 1 CPS 4 68 1 LBF 4 68 1 LBF 4 * DATA RECORD DEPTH COND SN TTEN 10460.000 -999.2500 -999.2500 -999.2500 10410.000 26.95041 36.21942 3936.663 10360.000 148.0779 10.58420 3930.936 10310.000 159.5425 10.34024 3948.088 10260.000 224.1163 7.035435 3916.427 10210.000 319.0085 5.127427 3903.205 10160.000 35.52139 (TYPE# 0 ) AC GR SP 84.87885 73.65274 -999.2500 98.95700 55.40765 56.41606 82.26622 119.6780 78.00496 85.39880 129.4613 77.64854 100.3234 95.57291 82.64926 79.25623 76.33939 85.19057 77.86011 31.76399 966 BYTES * CN GRCN SPD -999.2500 -999.2500 -999.2500 12.02995 61.39331 29.99701 22.91902 132.3894 30.10620 25.61180 131.3235 30.99690 25.80447 96.51511 30.99690 25.79166 75.29630 30.99690 18.03424 32.60968 CNC LSN SSN -999.2500 -999.2500 -999.2500 20.89072 245.5373 474.1289 33.90141 109.4033 308.3293 37.00020 109.0598 330.8020 37.22011 104.3620 318.1416 37.20549 100.6832 306.8252 28.16005 124.1902 CNRA RT TEN -999.2500 -999.2500 -999.2500 1.000000 37.10519 626.1902 1.000000 6.753201 193.5694 1.000000 6.267920 53.43387 1.000000 4.461969 -8.691278 1.000000 3.134712 -26.78021 1.000000 28.15205 0.8297652E-01 3872.061 24.94031 30.99690 300.8433 -35.14240 TOTAL DATA RECORDS : 45 STARTING TAPE DEPTH = 10460.00 ENDING TAPE DEPTH = 10130.00 **** FILE TRAILER **** **** TAPE TRAILER **** LIS 91/ 2/ 4 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 444 **** REEL TRAILER **** LIS 91/ 2/ 4 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 445 TOTAL RECORDS IN THIS PHYSICAL REEL: 445 End of execution- Mon 4 FEB 91 2:14p Elapsed execution time = 31.80 seconds. SYSTEM RETURN CODE = 0 PROGRAM: LISCAN REVISION: 5.2 Start of execution: Mon 14 JAN 91 2:45p **** REEL HEADER **** LIS 91/ 1/14 AWS 01 PART NUMBER: W5790-MICRO 8FCEIVED J '-xN 1 8 1991 Oil ~ e~s Oon$. Oommi8$ion Anohorage **** TAPE HEADER **** LIS 1/14 01 FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 24A-5 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME CODE SAMPLE# UNIT 1 BKL 68 1 CPS 2 BKS 68 1 CPS 3 CCL 68 1 DIM 4 CSS 68 1 API 5 G1 68 1 CPS 6 G2 68 1 CPS 7 GElS 68 1 CPS 8 GR 68 1 API 9 ISS 68 1 CPS 10 LS 68 1 CPS BYTES 4 4 4 4 4 4 4 4 4 4 11 MON 12 MSD 13 RATO 14 RBOR 15 RICS 16 RIN 17 SGMA 18 SPD 19 SS 68 1 CPS 4 68 1 SU 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 SU 4 68 1 F/MN 4 68 1 CPS 4 * DATA RECORD DEPTH G1 LS RICS (TYPE# BKL G2 MON RIN o) 966 BYTES * BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 10630.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10580.000 21423.15 3095.571 9.814882 195.7810 8168.957 2000.433 11.68402 418.4089 105719.6 0.2010849 14.64656 556.5000 83.71037 15.81052 20.99791 30889.54 303190.0 1.350631 48887.61 10530.000 17317.48 2543.770 10.39921 177.0800 5384.793 2000.677 12.38766 327.2100 108098.6 0.3157057 17.67152 0.0000000E+00 81.24287 18.07582 20.65291 28193.69 303549.1 1.362911 45991.78 10480.000 20975.64 2860.712 10.16327 216.5780 7892.980 2004.284 12.18129 337.0830 105244.6 0.1945708 14.93678 0.0000000E+00 66.00854 17.03027 20.34300 30742.14 297448.3 1.372860 48794.73 10430.000 15407.32 2345.892 12.23160 210.4450 4587.328 2003.032 12.95865 361.8140 108396.9 0.3237432 18.63074 384.0000 54.03014 18.75340 20.65291 26859.13 303214.6 1.418238 44217.94 10380.000 21453.73 3194.179 9.856613 84.39301 8148.441 2000.609 11.77439 287.3350 106895.1 0.2040328 14.69052 0.0000000E+00 36.54445 15.16527 20.88870 30936.32 303789.7 1.358152 48619.33 10330.000 13229.08 1919.232 11.90497 159.5740 3097.374 1999.521 12.67967 371.4880 112408.4 0.3792456 21.75293 0.0000000E+00 59.07610 22.26982 20.99791 25580.40 299897.7 1.402962 42724.77 10280.000 7657.879 1206.534 221.0400 1231.853 2000.906 358.2051 106336.1 0.7431277 0.0000000E+00 83.55081 27.57919 20267.59 287956.4 1.498302 13.76942 13.80428 27.15691 20.99791 33285.62 10230.000 12011.28 1753.373 11.85129 10180.000 15391.72 2276.444 11.89508 10130.000 9296.988 1389.792 14.45418 10080.000 8447.977 1232.945 14.57676 10030.000 11025.63 1512.458 13.73441 9980.000 7540.266 1160.432 15.16292 9930.000 12311.61 1899.946 13.32230 9880.000 8894.258 1323.535 14.75207 9830.000 11230.33 1691.113 13.43618 9780.000 6852.781 1081.684 15.49966 9730.000 7383.852 1101.175 127.9870 2905.665 2000.778 13.09477 117.2720 4040.909 2001.047 13.50366 93.53601 1943.938 2002.102 15.25264 72.24200 2030.724 2002.502 15.52592 69.38701 3219.276 2002.338 14.67672 64.76001 1554.509 2001.236 15.62806 50.78601 4179.156 2001.229 14.33067 62.86699 2049.014 2000.475 15.89121 71.87401 3387.470 1998.571 14.21181 117.2740 1362.431 2001.316 15.59098 101.9840 1619.698 1999.094 274.5430 106783.7 0.3893385 21.52116 373.7871 115281.9 0.4841505 20.30714 321.9221 103998.9 0.3817517 23.63567 226.9750 95816.06 0.4725053 21.77057 221.9180 97281.75 0.3098345 18.84332 217.0360 100340.6 0.3658725 24.08023 240.6470 105261.9 0.3078429 16.54610 234.5770 101451.4 0.4944977 22.17801 291.4351 101498.3 0.2597264 18.16183 224.0270 102476.9 0.3029488 24.97794 228.3700 98728.62 0.4213833 0.0000000E+00 40.32021 23.05511 20.99791 0.0000000E+00 36.85510 19.94133 20.99791 49.64999 40.12962 23.80939 21.65280 0.0000000E+00 28.29672 23.49734 21.99780 0.0000000E+00 24.52563 21.07469 20.99791 0.0000000E+00 34.63420 25.00943 20.99791 385.8000 19.52675 17.80232 21.88860 0.0000000E+00 31.32397 23.14938 20.99791 0.0000000E+00 20.45052 19.58080 20.99791 0.0000000E+00 41.98491 25.91725 21.99780 0.0000000E+00 30.87950 25.79706 24154.11 281126.7 1.399724 40535.67 27650.61 307297.9 1.415778 45619.07 20694.96 290857.6 1.524019 33016.51 18690.32 277074.2 1.535097 28999.49 20683.99 284820.1 1.558774 31840.61 18602.96 284661.7 1.563330 28989.76 22598.87 296706.7 1.559710 33821.90 19752.40 289195.9 1.527209 30584.55 21505.88 283702.0 1.559904 33335.72 18201.61 290556.4 1.583795 28067.80 18264.63 282152.7 1.584976 15.41344 16.15002 23.41675 21.99780 28333.98 9680.000 11689.74 1783.306 13.17246 9630.000 8188.121 1263.429 14.99286 9580.000 6710.191 1029.250 15.21179 9530.000 8534.945 1286.057 15.20777 9480.000 14167.13 2498.824 12.95183 9430.000 -999.2500 -999.2500 -999.2500 9380.000 -999.2500 -999.2500 -999.2500 9330.000 -999.2500 -999.2500 -999.2500 9280.000 -999.2500 -999.2500 -999.2500 9230.000 -999.2500 -999.2500 -999.2500 9180.000 -999.2500 -999.2500 50.05101 3782.320 1998.944 14.38237 89.35400 1848.425 2272.585 14.44980 52.90900 1538.619 1994.423 14.25622 60.67902 1980.388 2303.808 14.05808 65.61801 4646.766 1997.285 13.63679 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 267.2219 104471.8 0.1270425 17.06300 207.8930 107814.4 0.4093357 22.87100 217.3130 87355.75 0.3033285 22.48701 208.4870 103420.9 0.4940540 21.64357 252.4230 123974.0 0.2531524 16.89789 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 18.32637 18.72275 21.99780 0.0000000E+00 29.17694 24.30980 21.99780 0.0000000E+00 16.23444 24.43553 22.10699 0.0000000E+00 28.79958 23.07758 21.99780 0.0000000E+00 16.63564 15.39510 21.99780 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 22055.14 297840.6 1.536639 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14.04099 7780.000 9595.430 1508.748 13.92020 7730.000 8019.777 1365.435 14.57294 7680.000 10825.90 1738.360 13.49158 7630.000 11291.82 1696.238 13.42186 7580.000 8742.273 1371.069 14.64346 7530. 000 14951.15 3004.650 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 74.53801 1964.223 2002.827 14.23066 71.08000 2194.136 2001.746 13.14095 55.75401 2534.503 2002.036 13.10376 76.81601 1973.883 2003.709 13o58521 46.79401 3407.356 2002.880 13.09277 54.94200 3762.423 2001.539 13.23064 81.83200 2052.594 2002.074 13.54209 62.34401 5528.109 1999.173 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 215.0620 101931.9 0.5805353 22.10710 227.8450 102137.2 0.4769965 21.59383 238.2460 100936.5 0.1858304 20.36989 237.1520 100426.2 0.4989464 21.43279 253.4650 100178.4 0.3676869 17.41762 217.5180 99003.37 0.4056429 16.84677 217.0540 104362.9 0.4200113 21.86180 248.4050 138950.4 0.2157888 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 32.12981 22.91196 25.99741 0.0000000E+00 29.31404 21.23845 25.96170 0.0000000E+00 23.89546 20.85460 25.43941 287.0999 26.93280 21.65454 25.56140 0.0000000E+00 18.58957 18.26709 25.03320 0.0000000E+00 17.57220 19.29753 25.55550 0.0000000E+00 22.54687 22.52991 25.99741 0.0000000E+00 17.82515 13.76404 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 19323.62 285859.9 1.553346 30149.45 19977.04 284007.7 1.549093 31155.50 20334.44 281689.7 1.522352 31489.07 19035.45 276828.8 1.551470 29632.74 21047.71 281645.3 1.536869 31738.06 21369.79 286608.3 1.529449 32690.47 19895.53 288503.9 1.613838 30884.87 28503.50 344156.4 1.573580 11.94185 12.47581 15.19594 25.96170 41382.40 7480.000 8901.617 1389.998 14.43955 7430.000 8114.605 1259.612 14.58836 7380.000 13551.11 2203.839 12.50978 7330.000 8088.816 1298.371 14.81567 7280.000 10694.35 1645.358 13.61479 7230.000 7908.707 1206.943 14.89126 7180.000 12899.11 1878.168 12.73327 7130.000 7890.613 1242.363 15.10041 7080.000 10285.55 1512.216 14.03724 7030.000 9356.035 1323.729 13.43502 6980.000 7490.504 1062.562 65.37201 2045.600 2150.794 13.46169 88.24400 1835.413 2151.554 13.76246 71.08400 4639.449 2146.543 13.47150 54.76199 1857.213 2152.682 11.82933 60.25000 3091.817 2151.045 13.22886 86.63602 1688.167 2153.304 14.14518 62.72801 4388.371 2153.883 14.31302 68.66200 1679.706 2150.385 14.78186 79.69801 2779.091 2152.560 14.19068 50.06900 2657.315 2153.331 14.42724 80.28601 1728.195 2140.528 231.6790 104759.5 0.5874140 22.49080 280.7109 104840.7 0.5285957 22.86183 215.6060 118477.2 0.2894537 16.28833 158.5540 95916.50 0.6703824 22.89746 214.3560 102332.6 0.3767057 19.05833 264.4089 106035.5 0.4304865 23.54767 189.8110 106821.1 0.2836820 16.36728 328.6660 103345.4 0.3376500 23.54817 219.2960 107080.1 0.3374321 20.09819 231.8340 92799.12 0.2903672 19.24796 187.7390 94600.81 0.5733225 0.0000000E+00 22.60257 22.87395 25.99741 0.0000000E+00 25.55344 24.37556 25.99741 0.0000000E+00 20.97987 16.96629 25.99741 0.0000000E+00 22.37950 23.01027 25.99741 0.0000000E+00 20.07780 19.85892 25.99741 0.0000000E+00 31.58737 24.81459 25.99741 0.0000000E+00 18.52846 18.35977 25.99741 0.0000000E+00 30.17368 24.71202 25.96170 0.0000000E+00 20.90555 22.42368 26.96161 0.0000000E+00 13.79303 22.60678 26.56131 0.0000000E+00 18.74522 27.17801 20261.30 292344.0 1.577677 31740.77 19711.01 289896.9 1.536808 30807.07 25066.99 323869.9 1.563846 37377.49 18794.11 267846.7 1.547354 29794.91 21214.75 288339.8 1.534719 32826.09 19491.43 296323.1 1.573877 30068.46 23093.26 304714.1 1.548972 34291.97 19475.35 292116.1 1.562186 30797.43 21672.20 304232.2 1.518155 33822.48 19175.16 269328.2 1.513333 29878.93 18240.01 264158.2 1.623982 16.41728 14.98206 22.31471 26.03900 29078.82 6930.000 5438.039 834.6340 19.48650 ~6880.000 7241.566 1118.503 16.89261 6830.000 6291.910 991.7070 17.74742 6780.000 5161.340 846.8870 18.79138 6730.000 4561.789 717.4722 18.90460 6680.000 4635.195 788.8149 17.87801 6630.000 8589.711 1490.651 13.93627 6580.000 6768. 687 1169.740 14.24878 6530.000 4497.066 748.4241 17.20747 6480.000 6659.160 1148.931 14.68211 6430.000 6802.117 1100.106 41.76001 1255.437 2152.990 17.43854 31.74300 2227.976 2151.147 15.77552 51.01199 1718.136 2151.704 16.35510 38.98601 1187.294 2152.892 16.49783 44.06601 1032.985 2153.713 16.46631 54.27202 863.2280 2153.634 15.95181 82.81001 2095.503 2153.164 12.87929 74.36600 1224.362 2152.418 12.79045 70.50801 807.0081 2149.630 14.95096 79.87201 1026.923 2153.288 12.70829 37.01599 1283.726 2150.937 180.5390 94737.62 0.6391393 22.77945 222.4140 97400.94 0.5292376 17.87155 221.4540 100361.0 0.3037712 19.99931 186.5300 96467.62 0.5512897 22.81241 214.6330 90044.62 0.6622248 23.93340 180.8160 97037.12 0.6180722 26.02263 204.7770 108261.6 0.4925728 21.90504 243.9780 103913.7 0.3868057 26.71643 191.0560 95450.69 0.4121341 27.62944 263.1321 107936.2 0.3682188 28.55675 217.0970 96375.56 0.3359036 0.0000000E+00 15.37305 25.98082 26.43341 0.0000000E+00 10.31332 21.18559 26.96161 0.0000000E+00 15.28857 23.79562 26.96161 0.0000000E+00 18.06256 25.93034 25.99741 0.0000000E+00 16.01744 28.24628 26.55540 590.2500 16.62662 28.50345 26.59111 0.0000000E+00 23.71811 22.50577 25.99741 0.0000000E+00 24.37653 26.46933 26.59111 0.0000000E+00 24.68224 30.44896 26.43930 0.0000000E+00 31.35527 27.14160 26.59700 0.0000000E+00 11.33037 26.26978 15363.21 282284.2 1.714515 21635.41 16943.72 295659.9 1.771128 23617.63 16616.62 296067.0 1.750677 23544.41 15343.98 285942.4 1.773038 21889.49 14184.85 272503.8 1.701816 20208.86 15412.05 280373.8 1.672640 22501.33 21067.66 289659.2 1.502166 33521.33 19198.27 279571.4 1.483214 31042.26 15361.76 280581.6 1.641327 22849.67 19426.58 288741.2 1.531054 31181.07 17950.54 259279.3 1.523318 14.49910 12.34475 25.42691 26.99141 28861.37 6380.000 7625.238 1306.358 14.72597 6330.000 9055.496 1550.931 13.83939 6280.000 6510.992 1239.988 14.71070 6230.000 8591.238 1493.837 14.50855 6180.000 7317.070 1311.245 14.69144 6130.000 10202.72 1939.506 13.59015 6080.000 10404.31 1712.997 13.52993 6030.000 10493.27 1786.726 13.26147 5980.000 10988.73 2049.768 13.54486 5930.000 7134.492 1224.520 14.18292 5880.000 8228.934 1421.114 76.75400 1435.731 2149.937 13.40245 56.40102 2345.247 2150.249 12.98237 92.09100 1190.528 2149.029 12.94389 56.53000 2055.317 2147.607 13.10875 63.70900 1324.285 2148.685 12.97560 31.41699 2980.954 2150.026 12.94482 53.13199 3068.212 2146.655 12.62167 46.56000 3470.409 2148.529 13.17487 47.91200 3384.550 2145.846 12.41536 17.79900 1546.833 2148.375 12.13635 44.70500 1930.438 2148.719 291.9380 105955.6 0.3748708 25.21053 226.1190 116390.6 0.4520361 20.68237 249.1800 121078.0 0.4879369 25.74680 260.0881 115548.9 0.2935729 21.88885 277.0181 115666.4 0.4611693 26.13126 225.8950 128698.4 0.2439409 19.12369 227.2090 107914.2 0.3277804 18.99515 221.6050 108951.5 0.2304817 16.87296 254.9070 122644.2 0.2702629 18.27214 182.3300 95916.87 0°1811609 23.88188 268.1670 111111.5 0.5959250 0.0000000E+00 27.78909 24.37762 27.43330 0.0000000E+00 21.59099 21.82521 22.40401 0.0000000E+00 32.44197 25.36211 22.03351 0.0000000E+00 23.46622 22.15065 22.99770 0.0000000E+00 22.75981 24.48834 22.03351 0.0000000E+00 14.65016 18.18555 22.43970 0.0000000E+00 16.22478 20.17551 23.95601 0.0000000E+00 14.98611 18.29788 22.99181 0.0000000E+00 13.57200 17.90918 22.56171 0.0000000E~00 6.398126 23.65532 23.39801 0.0000000E+00 19.09761 22.84924 19885.15 285289.9 1.503625 31840.60 21942.54 305220.6 1.543701 33823.24 20523.38 309341.5 1.593810 31453.23 21468.85 309121.7 1.586151 33137.71 20504.02 301522.7 1.538576 32060.20 23834.36 333447.7 1.587334 35182.02 22242.18 299040.6 1.532936 34572.90 21885.41 304320.2 1.570444 32748.50 24192.12 321439.9 1.575393 36615.03 18147.36 258663.2 1.504108 28998.87 20735.76 296906.5 1.526480 14.18239 12.55374 22.22775 22.56171 32564.86 5830.000 6907.281 1225.638 14.57878 78.38301 1457.061 2147.617 12.82768 176.1900 109585.0 0.5946274 24.94916 0.0000000E+00 16.34363 24.75980 22.43970 19444.77 293910.2 1.539875 30305.84 5780.000 6956.863 1227.329 14.20518 114.2230 1320.069 2149.039 12.75157 251.2750 100576.8 0.5083249 25.88992 905.2498 22.03389 24.61415 23.99760 18747.55 272272.9 1.508336 30275.91 5730.000 7229.547 1255.059 14.54964 92.17101 1401.983 2149.351 12.45939 223.3370 109426.2 0.6445370 25.78653 0.0000000E+00 22.06239 25.54730 22.99770 20130.55 290708.6 1.512841 32039.77 5680.000 7518.039 1303.747 14.09493 62.62199 1396.157 2148.478 12.22590 228.4270 107724.9 0.4834377 26.25465 0.0000000E+00 22.47841 24.99518 23.96190 20157.85 286568.3 1.479612 32576.14 5630.000 8659.594 1450.521 14.97979 49.66400 2012.968 2148.783 13.36123 234.7850 110797.4 0.2693648 22.21243 0.0000000E+00 20.77953 22.91296 22.99770 21171.22 294410.4 1.571866 33326.36 5580.000 7381.824 1322.602 14.01134 53.84601 1520.827 2149.859 12.12816 179.1600 100116.2 0.3915637 25.09497 0.0000000E+00 11.42776 23.46117 23.99760 19117.14 262155.9 1.501814 31066.16 5530.000 10564.74 1730.727 13.23299 55.90501 3086.290 2148.919 12.32005 261.1699 108838.9 0.2329996 18.96950 0.0000000E+00 16.60199 20.37433 24.54970 22562.25 297652.2 1.486727 35304.42 5480.000 7472.387 1271.586 -7.000000 74.61301 1425.527 2146.703 5.000000 262.8110 107434.8 0.5707148 25.56445 0.0000000E+00 21.90363 25.25554 22.99770 20055.94 289680.2 -1.000000 32186.18 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 864 10630.00 ENDING TAPE DEPTH = 5450.00 **** REEL HEADER **** LIS 91/ 1/14 AWS 01 **** TAPE HEADER **** LIS 91/ 1/14 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 24A-5 FN : COUN : STAT : * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 BKL 68 1 CPS 4 2 BKS 68 1 CPS 4 3 CCL 68 1 DIM 4 4 CSS 68 1 API 4 5 G1 68 1 CPS 4 6 G2 68 1 CPS 4 7 GElS 68 1 CPS 4 8 GR 68 1 API 4 9 ISS 68 1 CPS 4 10 LS 68 1 CPS 4 11 MON 68 1 CPS 4 12 MSD 68 1 SU 4 13 RATO 68 1 DIM 4 14 RBOR 68 1 DIM 4 15 RICS 68 1 DIM 4 16 RIN 68 1 DIM 4 17 SGMA 68 1 SU 4 18 SPD 68 1 F/MN 4 19 SS 68 1 CPS 4 * DATA RECORD DEPTH (TYPE# 0 ) BKL 966 BYTES * BKS CCL CSS G1 LS RICS G2 MON RIN GElS MSD SGMA GR RATO SPD ISS RBOR SS 10630.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10580°000 21688.43 3089.511 9.692638 242.0410 8147.992 2168.012 11.39458 396.4231 105267.1 0.8565044E-01 14.71015 0.0000000E+00 83.26898 16.07817 25.99741 31192.50 302281.0 1.375501 49649.53 10530.000 17225.64 2467.625 10.25515 193.6610 5333.164 2069.141 12.06065 370.3940 107784.2 0.1790084 17.76292 0.0000000E+00 73.15279 18.66313 24.99750 28200.90 299935.1 1.370007 46121.68 10480.000 21075.54 3037.009 10.16045 102.1960 7911.992 2006.277 12.13647 265.6069 106741.5 0.1366272 14.86124 0.0000000E+00 37.20592 16.17363 24.99750 30978.91 297456.7 1.334885 49218.36 10430.000 16619.00 2444.882 11.90166 146.0260 5226.281 2005.076 12.29605 342.7581 111999.6 0.3164413 17.68288 0.0000000E+00 45.18677 18.37579 24.99750 27933.46 308210.7 1.414292 45154.41 10380.000 21375.20 3184.014 9.832787 106.3700 8079.051 2006.160 11.57212 295.2971 106440.7 0.1502329 14.65750 0.0000000E+00 38.93329 15.37667 25.99741 31075.09 304963.9 1.318907 49180.05 10330.000 13349.45 1972.180 11.80004 131.9160 3109.089 2004.879 12.86345 314.8250 111744.0 0.5597814 21.96848 0.0000000E+00 58.46913 21.44678 25.95580 25474.34 298024.8 1.369039 42325.62 10280.000 0.0000000E+00 950.0000 -2.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 76.61362 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 62 10630.00 ENDING TAPE DEPTH = 10260.00 **** TAPE TRAILER **** LIS 91/ 1/14 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 939 **** REEL TRAILER **** LIS 91/ 1/14 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 940 TOTAL RECORDS IN THIS PHYSICAL REEL: 940 End of execution: Mon 14 JAN 91 2:46p Elapsed execution time = 1 minute , 9.4 seconds. SYSTEM RETURN CODE = 0